Ae94.3a Gas Turbine

Project MC: Owner:
MAZANDARAN II 450 MW SINGLE

SHAFT COMBINED CYCLE POWER
Consultant:
PLANT PROJECT MAH-TAAB CASPIAN POWER
GENERATION CO.
DOCUMENT TITLE: OPERATION AND MAINTENANCE MANUAL

Serial
Project Initiator Island System Disc. Cat. Rev.
No.
DOCUMENT NO.: Page 1 of 685
MAZ AEN 01 MB* PR MNL 001 C
\
ELECT.SIGN D:Rosellini C:Pizzimenti A1:Perpiglia A2:Capotos A3:Pesce (13/11/2018)
08-Dec-2018
GAS TURBINE
MAZ-UED-GNS-TT-1223
OPERATION AND MAINTENANCE

MANUAL
OWNER DOCUMENT REVISION

2
0
DEPARTMENT/OFFICE DEPARTMENT/OFFICE DEPARTMENT/OFFICE DEPARTMENT/OFFICE DEPARTMENT/OFFICE
Rev. DATE DESCRIPTION PREPARATION CHECKED VERIFIED VERIFIED APPROVED
IN-HOUSE DOCUMENT REVISION

C 25/10/2018 General revision F. ROSELLINI F. PERPIGLIA L. PIZZIMENTI T. CAPOTOS P. PESCE
PEM/GTE PEM/GTE - TC PEM/GTE PEM/PRE - PE PEM/GTE
B 27/02/2018 According to MAZ-UED-AEN-E-0213-GT F. ROSELLINI F. PERPIGLIA L. PIZZIMENTI T. CAPOTOS P. PESCE

A 22/03/2017 FIRST EMISSION M. CUGINO B. SANTOLINI L. PIZZIMENTI T. CAPOTOS P. PESCE

Doc. No.: 0558S1MB*S071

Contractor Sub-Contractor
Rev.: C
United Energy Job No: 0558
Confidential Class: 2
Developers Subcontractor
Document Type: OPM
Documentation
(UED) Information
Document Scope: I
Teamcenter Issuer Code: GPFO
Department Issuer Code: PEM/GTE
Language: E
Basic Eng. Doc. □ Detailed Eng. Doc.X Subsupl Eng. Doc. □
AE94.3A GAS TURBINE
Operating &Maintenance
MANUAL
O&M MANUAL TGO1-0000-E71000

TABLE OF CONTENTS
0558 S1 MB#S071_B GT OPERATING AND MAINTENANCE......................................................1
GENERAL....................................................................................................................................6
TGO1-0030-E00003 Preface .....................................................................................................7
TGO1-0040-E00003 Notes on the use of the manual ...............................................................8
TGO1-0045-E00003 Safety notice ..........................................................................................10
TGO1-0046-E00000 Safety warning .......................................................................................27
TGO1-0200-E00003 Technical assistence ..............................................................................28
TGO1-0300-E00000 List of hazardous materials ....................................................................30
TGO1-0400-E00000 KKS-Power plant identification system...................................................34
TGO1-0500-E00000 Instrument list .........................................................................................39
TGO1-0510-E00000 Electrical load list....................................................................................70
TGO1-0520-E00000 Equipment list.........................................................................................82
TGO1-0530-E00000 Set point list..........................................................................................111
TGO1-1000-E710000 Process interface data........................................................................145
DESCRIPTION .........................................................................................................................161
DESCRIPTION: Technical data .............................................................................................162
TGO2-0020-E71558 Rating plate data ..................................................................................163
TGO2-0100-E71558 Design data ..........................................................................................164
TGO2-0114-E72000 Determination of temperatures limits in the exhaust duct ....................165
TGO2-0116-E70005 Setting of start up paramenters ............................................................168
TGO2-0120-E71000 Automatic loading and unloading .........................................................171
TGO2-0124-E71000 Power output as function of ambient temperature................................172
TGO2-0130-E71001 Dimensions and weight ........................................................................174
TGO2-0160-E71001 Requirements for gas turbine working fluids ........................................177
TGO2-0171-E00000 Turbine oil specifications ......................................................................197
TGO2-0172-E00003 Hydraulic oil specifications ...................................................................204
DESCRIPTION: Turbine_compressor ...................................................................................206
TGO2-0300-E71000 Gas turbine description ........................................................................207
TGO2-0310-E70000 Rotor and blades ..................................................................................212
TGO2-0330-E71000 Stator and vanes ..................................................................................216
TGO2-0340-E71000 Variable guide vanes............................................................................223
TGO2-0500-E70000 Outer casing .........................................................................................225
TGO2-0520-E70001 Exhaust gas diffusers ...........................................................................229
TGO2-0530-E70000 Bearing housing (compressor and turbine) ..........................................231
TGO2-0540-E70000 Compressor bearing.............................................................................236
TGO2-0560-E70000 Turbine bearing ....................................................................................238
TGO2-0600-E70001 Intermediate shaft ................................................................................239
TGO2-0610-E70001 Manual turning gear .............................................................................241
TGO2-0620-E70001 Hydraulic turning gear ..........................................................................244
DESCRIPTION: Combustion Chamber .................................................................................246
TGO2-0700-E70001 Combustion Chamber ..........................................................................247
TGO2-0760-E70006 Burner assembly for liquid and gaseous fuels......................................250
DESCRIPTION: Cooling air system.......................................................................................253
TGO2-0800-E00000 P&ID Turbine cooling and seal air system ...........................................254
TGO2-0801-E70002 Turbine cooling and seal air system, description .................................256
DESCRIPTION: Hydraulic system .........................................................................................260
TGO2-2002-E00000 P&ID Hydraulic oil system ....................................................................261
TGO2-2003-E70001 Hydraulic oil system description ...........................................................265
TGO2-2004-E00000 P&ID Hydraulic oil for fuel valves and HP purging control valve ..........272
TGO2-2005-E72005 Hydraulic oil system for fuel valves ......................................................279
TGO2-2010-E71000 P&ID Hydraulic IGV/CV1......................................................................289
TGO2-2011-E71005 Hydraulic oil system for IGV/CV1, description......................................292
DESCRIPTION: Measuring and Supervisory Equipment ......................................................294
TGO2-2600-E00000 P&ID Gas turbine instrumentation........................................................295
TGO2-2601-E71002 Gas turbine instrumentation .................................................................297
TGO2-2602-E00000 P&ID Combustion chamber instrumentation ........................................303
TGO2-2603-E70003 Combustion chamber instrumentation..................................................305
TGO2-2660-E00000 Speed measurement ............................................................................308
TGO2-2700-E72000 Temperature measuring points at gas turbine......................................310
TGO2-2750-E72000 Measuring instrument, compressor bearing .........................................313
TGO2-2800-E72000 Measuring instrument, turbine bearing.................................................315
DESCRIPTION: Fuel Supply System ....................................................................................318
TGO2-3000-E00000_0 P&ID fuel gas system .......................................................................319
TGO2-3001-E70006_1 Natural gas system description ........................................................321
TGO2-3004-E00000 P&ID Fuel oil system ............................................................................328
TGO2-3005-E70002 Fuel oil system description ...................................................................333
TGO2-3006-E00000 P&ID Purging system ...........................................................................347
TGO2-3007-E72000 Purging water system...........................................................................350
TGO2-3410-E00000 P&ID Ignition gas system .....................................................................358
TGO2-3411-E72000 Ignition gas system...............................................................................360
DESCRIPTION: Safety and protective system ......................................................................362
TGO2-4380-E72000 Flame monitoring arrangement ............................................................363
TGO2-4410-E00000 P&ID Blow off system...........................................................................365
TGO2-4411-E72000 Blow Off system description .................................................................367
DESCRIPTION: Other auxiliares ...........................................................................................370
TGO2-4961-E00000 P&ID Compressor cleaning system......................................................371
TGO2-4962-E00001 Compressor cleaning system, description............................................373
TGO2-4965-E00000 P&ID drainage system..........................................................................374
TGO2-4966-E70001 drainage system, description................................................................376
TGO2-5000-E00000 P&ID Fuel oil seal air cooling system ...................................................379
TGO2-5001-E70000 Fuel oil seal air cooling air system .......................................................381
TGO2-6000-E00000 P&ID Rotor displacement system.........................................................384
TGO2-6001-E70003 Rotor displacement system (RDS) ......................................................387
TGO2-7000-E72000 P&ID Pneumatic station system ..........................................................398
TGO2-7001-E72002 Pneumatic station system ....................................................................400
TGO2-7002-E72000 P&ID Pneumatic actuators for Blow off system....................................402
TGO2-8000-E00000 P&ID Air intake system.........................................................................404
TGO2-8001-E71558 Air intake system description................................................................406
TGO2-8002-E00000 Anti-icing system ..................................................................................410
TGO2-9000-E00000 P&ID Exhaust gas system....................................................................411
TGO2-9001-E00000 Exhaust gas system .............................................................................413
OPERATION............................................................................................................................414
TGO3-0030-E00003 Duties of the operating personnel ........................................................415
TGO3-0031-E72001 General start up conditions ..................................................................416
TGO3-0032-E72001 Functional test prior to start up.............................................................420
TGO3-0033-E70003 Cooling procedure - general operating instruction ...............................422
TGO3-0034-E70001 SFC Emergency turning .......................................................................425
TGO3-0045-E70004 GT Starting - Master sequence ............................................................426
TGO3-0046-E70001GT Starting - Fuel gas sequence ..........................................................437
TGO3-0047-E70001 GT Starting - Lube and turning sequence ............................................442
TGO3-0048-E72001 GT Starting - Fuel oil sequence............................................................448
TGO3-0049-E70002 BHS Turning sequence ........................................................................459
TGO3-0050-E00000 RDS Sequence ....................................................................................463
TGO3-0051-E72000 GT Starting - Purging sequence...........................................................478
TGO3-0055-E00000 Control system operation .....................................................................493
TGO3-0060-E70001 Unusual operating conditions ...............................................................496
TGO3-0070-E00000 RDS system adjusting ..........................................................................501
TGO3-0100-E70001 Exhaust gas temperature control .........................................................503
TGO3-0110-E72003 Exhaust gas temperature protection ....................................................505
TGO3-0119-E70001 Evaluation temperatures distribution at turbine outlet ..........................509
TGO3-0126-E72000 Equivalent operating hours...................................................................511
TGO3-0200-E70001 Safety procedure during very long standstill ........................................515
TGO3-0210-E70002 Activation of the fuel oil system during prolonged fuel gas operation ..520
TGO3-0220-E72001 Operation at very low ambient temperature .........................................524
OPERATION: Fault tracing .....................................................................................................526
TGO3-0300-E00002 Fault tracing, general remarks..............................................................527
TGO3-1708-E00003 Instruction for filling a problem report ...................................................528
TGO3-1780-E00002 Vibrations .............................................................................................529
TGO3-2500-E00002 Measuring equipment - Fault rectification ............................................544
TGO3-2600-E72000 Supervisory and protective equipment - Fault rectification...................545
TGO3-3000-E72001 Fuel oil system - Fault rectification .......................................................548
TGO3-3050-E72001 Purging water system - Fault rectification ............................................553
TGO3-3100-E72006 Fuel gas system - Fault rectification.....................................................555
TGO3-3400-E72000 Ignition gas system - Fault rectification ................................................558
TGO3-4400-E70001 Blow off system - Fault rectification......................................................560
TGO3-4966-E72000 Drainage system - Fault rectification ....................................................563
TGO3-5000-E70001 Measurements at combustion chamber - Fault rectification.................564
TGO3-6000-E72000 Cooling air system - Fault rectification .................................................567
TGO3-7040-E00000 Gas turbine bearings - Fault rectification..............................................569
TGO3-8100-E00000 Exhaust gas system - Fault rectification...............................................573
TGO3-9000-E72000 Pneumatic station system - Fault rectification ......................................574
TGO3-9110-E00000 Hydraulic oil system - Fault rectification ...............................................575
TGO3-9120-E72000 Hydraulic oil for fuel oil valves actuators - Fault rectification................582
TGO3-9130-E70002 Hydraulic oil for fuel gas valves actuators - Fault rectification..............585
Hydraulic oil for IGV/CV1 actuator - Fault rectification...........................................................586
TGO3-9400-E00000 Lube oil system - Fault rectification ......................................................587
TGO3-9600-E00000 Rotor displacement system (RDS) - Fault rectification.........................602
TGO3-9700-E70000 Seal fan system - Fault rectification .....................................................607
MAINTENANCE ......................................................................................................................608
TGO4-0032-E71001 Inspection and maintenance intervals ..................................................609
TGO4-0049-E70000 Intervals for cleaning filters and strainers.............................................618
TGO4-0052-E71000 Lubrication chart...................................................................................621
TGO4-1000-E70001 Endoscopic inspection doors................................................................624
TGO4-1001-E70001 Rotor disassembling device .................................................................626
TGO4-1004-E00002 Nord-lock permanently tight washers ...................................................632
TGO4-1005-E00004 Cleaning agents for compressor cleaning ............................................635
TGO4-1006-E00002 Oil filling and maintenance - Hydraulic oil system ................................638
TGO4-1510-E00002 Oil filling and maintenance - Lube oil system .......................................640
TGO4-1600-E72001 Measures following compressor surge.................................................645
TGO4-1700-E70001 Measures following humming/acceleration phenomena ......................647
TGO4-4550-E70001 Cleaning of filtering equipment.............................................................648
TGO4-4961-E00000 Determination of time for compressor cleaning....................................651
TGO4-4962-E00000 Manual compressor cleaning procedure ..............................................653
TGO4-5009-E72001 Flame monitoring system .....................................................................659
TGO4-5016-E72001 Pneumatic system maintenance ..........................................................662
TGO4-6000-E72000 Fuel oil skid drainage procedure ..........................................................664
INSPECTION ...........................................................................................................................666
TGO5-0022-E70001 Maintenance.........................................................................................667
TGO5-0230-E00003 General component test .......................................................................682
GENERAL
PREFACE
This manual includes information required for the operation and maintenance of the gas turbine.
The authors assume that the operators and maintenance personnel are familiar with power plant
engineering and the operation of power plants.
An understanding of the configuration of the gas turbine plant and thorough training of operating
and maintenance personnel are prerequisites for proper operation and maintenance.
It is absolutely essential for the safe operation of the gas turbine that the personnel have read
and understood the section on safety, and that all of the safety instructions in this manual are
always observed.
The content of this manual has been adapted in line with the stipulations of the supply contract.
In the event that information given in the manual deviates from the contractual stipulations, the
contract shall always take precedence.
Page 1 of 1
PREFACE TGO1-0030-E00003
20.11.14
NOTES ON THE USE OF THE MANUAL
This manual consists of separate documents (sections), whose index is reported in Section TGO1-
0010.
Each section is classified according to a number which is shown on the right bottom of the page.
Below the section number the issue date of the single document is reported (day.month.year)
The section number is related to the subject of the manual and it is the same also for different gas
turbine type. After the section number, another number indicate the specific version of the subject,
i.e. the document applied to a specific gas turbine type or to a specific gas turbine project.
Exemplum:
this section is named : TGO1-0040-0003
Section number
Ex. TGO1-0040-E00003
The first number is linked to the general subject:
TGO1 General indication
TGO2 GT and its auxiliaries description
TGO3 Operation
TGO4 Fault rectification and day by day maintenance
TGO5 Base information of planned maintenance
The second number is progressive.

Ex. TGO1-0040-E00003, is this section: “Notes on the use of the manual”.
Sections are filed in the manual by ascending section number. For organizational reasons, not every
section number is used and there may be gaps between the section numbers of adjacent sections.
Each section has its own page number. There is no sequential continuous numbering of the page of
the whole manual. This makes the manual more flexible, i.e. revision to one section only does not
lead to a revision of the other sections.
Page 1 of 2
NOTES ON THE USE OF THE MANUAL TGO1-0040-E00003
20.11.14
The third number represents the version applicable to that specific subject.
Ex. TGO1-0040-E00003
For instance, few descriptions are possible to be associated to a particular system or item but only
one is the applicable one for the specific configuration order related. The configuration is chosen by
the GT Manufacturer basing on the contractual requirements or the functional requirements of the
system.
Cross References
References to other sections of this manual are given when necessary (e.g. see section TGO1-3000);
the title is generally omitted.
Other information
KKS identifier is always used. No other labels and codes are used in the O&M manual.
For detailed information on the installed equipment see the specific manual of the Vendor, here
indicated as “Outside Vendor Parts”.
Variables appear in capital letters (e.g. TT.ATK.02). The value is reported in the Set Point List. The
name of the variables (e.g. TT.ATK.02) is necessary since the setting value occasionally change.
Please refer to Set Point List specifically made for your gas turbine.
Page 2 of 2
NOTES ON THE USE OF THE MANUAL TGO1-0040-E00003
20.11.14
SAFETY NOTICES
About this Section

This section must be carefully read by the gas turbine operator and his maintenance and operating
personnel. The main important information regarding the safe operation and maintenance of a gas
turbine can be found in this section.
The gas turbine has been designed in accordance with the state of the art and basing on the present
internationally recognized safety regulations. Operation and maintenance of the GT, however,
involve storage of hazardous substances (e.g. fuels, lubricants and cleaning agents) as well as use of
fluids at high temperatures and under high pressure. Consequently risks to personnel, equipment
and the environment can occur—steps were taken wherever possible during the design phase to
minimize such hazards.
For your own safety, read this section carefully and thoroughly and follow the notices and
regulations to the letter. Only in this manner can you protect yourself from injury and prevent
damage to the gas turbine.
All information included in this section is of a general nature or applies to a number of different
turbine types. Further safety notices appear in the later sections of the operating manual and apply
in addition to that information presented here.
In cases where items supplied by third parties are used, the respective manufacturer's
documentation shall be complied with (Outside Vendor Parts Manual). As used in this section,
"technical documentation" refers to both product and operating documentation.
As used in the technical documentation, the term "gas turbine" (GT) also refers to the auxiliary
systems.
This section only includes dangers deriving from the GT and its auxiliary systems. Other parts of the
plants or interaction with other systems and other factors at the GT installation site are not taken
into account.
Page 1 of 17
SAFETY NOTICES TGO1-0045-E00003
20.11.14
Safety Notice Structure
Various safety notices are used in the GT technical documentation to indicate information of
particular importance. Safety notices always have the same structure.
Each safety notice is identified by a symbol (pictogram) to the left of the safety notice. Furthermore,
the safety notice text is printed in bold type.
A signal word (e.g. Caution!) indicates the level of danger which can result if the notice is not
observed.
The nature of the danger is then described (e.g. Risk of injury from suspended loads).
Measures to avoid the danger are indicated whenever possible.
The order in which the dangers are listed is in no way indicative of the degree of danger.
Signal Words
All safety notices are introduced by means of a signal word. The signal words danger, warning and
caution facilitate clear, prompt recognition of the meaning of the warning notices:
"Danger" is used when death or severe personal injury will occur if the safety notice in question is
ignored or not sufficiently complied with.
"Warning" is used when severe personal injury or severe damage to equipment could occur if the
safety notice in question is ignored or not sufficiently complied with.
"Caution" is used when personal injury or damage to equipment of minor to intermediate severity
can result if the safety notice in question is ignored or not sufficiently complied with.
"Attention" is used when there is only a danger of minor damage to equipment if the safety notice in
question is ignored or not sufficiently complied with.
"Note!" is used to highlight important information.
Page 2 of 17
20.11.14
Pictograms
To highlight the safety information contained in the text, safety notices are combined with
pictograms and the text is printed in bold ty
pe:
There are three categories of pictograms:
Warning signs (outlined triangles with symbols in the middle) e.g.
Risk of injury!
This pictogram precedes information, orders and prohibitions intended to prevent
personal injury.
Risk of equipment damage!

This pictogram precedes information, orders and prohibitions intended to prevent
damage to equipment.
 Prohibitive signs (circles outlined in red with black symbols on white background) e.g.
No smoking!
Do not touch!
 Prescriptive signs (white circles with white symbols on blue background) e.g.
Hearing protection required!
Isolate before commencing work!
Additional pictograms can be found in the technical documentation. The meaning of these pictogram
can be determined from the brief description of the type of danger which is presented at the
beginning of the safety notice. Many pictograms indicate a specific danger (e.g. suspended loads or
an explosion hazard) and are used in place of the general pictograms listed above.
Page 3 of 17
20.11.14
In many cases, there is a risk of both personal injury and damage to equipment. In this case, only the
pictogram indicating the risk of personal injury is used to avoid excessive use of pictograms.
Additional pictograms are not used to indicate the dangers (e.g. risk of personal injury) resulting from
the failure to comply with prohibitions and prescriptions.
In the interest of clarity, warning notices presented in tables are not accompanied by pictograms.
The signal effect of bold type is lost due to the sheer number of safety notices in this section. The
remaining safety notices in this section are therefore in plain text to enhance readability.
Other manuals (e.g. operating manual) may in some cases use other pictographs or signal
words.
Identification of Important Information

Tips on procedures, notes regarding necessary tools and materials, etc. or special information
regarding economical operation of the gas turbine are identified as follows:
This pictogram precedes tips on economical and effective work on the gas turbine.
Proper Use of the Gas Turbine

The following process sequence outlines proper use of a gas turbine: Air is heated by combustion of
fuel in the gas turbine. The hot air creates an air flow within the turbine which then causes the gas
turbine shaft to rotate, thus driving a machine (generator).
Proper use requires compliance with the technical documentation and with inspection and
maintenance procedures. Proper use also requires sufficiently trained personnel (i.e. personnel
assigned to the gas turbine must have sufficient training to ensure safe operation of the gas turbine,
even in extraordinary situations).
Any other use of the gas turbine which goes beyond the scope outlined here, such as operation using
fuels or operating media other than those contractually stipulated, shall not be considered proper
operation and is prohibited.
Risk of injury!
Improper use of the gas turbine can adversely affect the (operational) safety of the GT and
result in personal injury and equipment damage.
Page 4 of 17
20.11.14
Organizational Measures
Organizational measures to ensure safe, reliable operation are described below.
The following measures reduce or eliminate the risk of injury:

 Make certain that personnel have understood and comply with all safety and hazard
notices.
 Comply not only with the technical documentation, but also with applicable local laws
and regulations regarding occupational safety, accident prevention, fire and
environmental protection, etc.
 Comply with local regulations when storing, transporting and disposing of fuels,
operating media, cleaning agents, etc.
 Install signs indicating orders and prohibitions within the turbine building, at the access
points and on the turbine itself. Ensure compliance with these orders and prohibitions
by all personnel.
 Use protective gear wherever prescribed or necessary. Always wear the correct size.
 Ensure that all protective gear used is in proper condition for its intended use. This also
means that protective gear must be kept clean at all times and that the prescribed usage
durations (e.g. in the case of respirator filters) are not exceeded.
 The operator is obliged to provide requisite protective gear in the sizes and quantities
needed. Protective gloves must have sufficient gauntlet length to prevent hazardous
substances from flowing or trickling into the gloves.
 Any irregularities during operation must be reported directly to the supervisor and the
gas turbine shut down immediately, if necessary.
 Prior to commencing work, personnel who are assigned to work on the gas turbine shall
familiarize themselves with the appropriate sections of the technical documentation,
and in particular with the section on safety. This applies in particular to personnel who
work on the turbine only occasionally, e.g. during maintenance.
 The operator is obliged to prepare operating procedures. The technical documentation
serves as a basis for this. Include supplementary operating instructions to account for
operational peculiarities such as work sequences and schedules.
These operating procedures must cover actions to be taken in the event of injuries, fire,
accidents and equipment damage. Also bear in mind that the source of danger must be
eliminated/secured as soon as possible.
 Identify on-scene incident commanders for such emergency situations and provide
requisite training. Ensure that an on-scene incident commander is always on the
premises even when a reduced number of employees is on duty (e.g. weekends).
 Regularly perform emergency response drills involving all power plant employees.
Page 5 of 17
20.11.14
 It is the operator's responsibility to ensure that all hazardous materials on site are
properly labeled and safely stored and handled. It must also be ensured that all persons
who come into contact with these materials are informed as to the associated dangers
as well as the appropriate protective/safety and first aid measures.
 Hazardous areas shall be clearly marked as such and access restricted or prevented as
appropriate.
 It shall be stipulated which employees are authorized to enter restricted access areas
(e.g. explosion hazard areas) and what protective measures are to be implemented.
 Always keep the technical documentation accessible at the point where it is required.
 Comply with local regulations when working in explosion hazard zones.
 Persons entering explosion hazard areas shall only wear protective clothing which
prevents the build-up of static charges: clothing with specified conductivity and shoe
soles with a maximum resistance of 108 Ohm.
 A supervisor must be designated prior to beginning work on the gas turbine. The
supervisor is responsible for coordination and supervision of the work. The supervisor
must ensure full compliance with all safety aspects relevant to personnel and
equipment, including auxiliary systems.
 The supervisor must also ensure that all systems containing or carrying hazardous media
are sufficiently washed/purged/inerted prior to the start of work on these systems.
Additional safety measures (e.g. respirators, protective clothing) must be prescribed, if
necessary. Also note that special safety measures may in some cases be required for
washing/purging/inerting.
 If work is being performed on several systems or at several locations of one system at
the same time, the work must be coordinated so as to prevent work on one system from
creating a hazard to other systems or those working on these systems.
 The "buddy system" shall always be used when work in hazardous areas so that rescue
measures can be promptly initiated if necessary. This also applies when working in
confined spaces (e.g. combustion chamber).
 Ensure that emergency exits, escape routes, fire extinguishers and emergency switches
are accessible at all times.
 Ensure that all safety, protective and rescue equipment is fully functional at all times.
Perform regular inspections to confirm this. Protective equipment also includes
grounding connections.
 Equipment designed for use as climbing aids (e.g. ladders) and which is in proper
working order shall be used whenever work is performed a great height. This may
require erecting scaffolds or work platforms.
Cellular phones, two-way radios and CD players prohibited!

 To prevent possible interference with the GT control system, the use of two-way radios,
cellular phones, and CD players is prohibited in the vicinity of the GT and GT control
Page 6 of 17
20.11.14
equipment.
Personnel
Requirements regarding personnel who are assigned to work on the gas turbine are described below:

 Make certain that only authorized personnel who have been duly trained and instructed
work on the gas turbine.
 Deploy only reliable personnel.
 Clearly delineate the responsibilities of personnel for all activities to be performed.
 Do not allow personnel still in training or taking part in a general training course to work
on the gas turbine without constant supervision by an experienced person.
Work on the electrical, pneumatic, hydraulic or fuel systems of the gas turbine shall be
performed only by workers specially trained for, or instructed in, the system in question,
or by duly instructed persons working under the direction and supervision of such a
specialist.
 Work on the gas system shall be performed only by officially certified specialists. The
Operator must obtain information regarding applicable local regulations and ensure
compliance therewith.
 Conduct of the personnel working on the GT must be such that any risks are prevented/
reduced as far as possible. This also includes checking one's own work on completion. In
addition, checks of whether all requisite safety measures have been taken must be
made/called for prior to performance of work.
 New hazards (e.g. leaks) detected by personnel must be immediately reported to the
responsible party.
 Any employee who discovers while performing work that associated hazards are greater
than previously assumed (e.g. loss of forced ventilation) shall discontinue this work and
immediately consult the responsible party.
Modifications and Alterations to the Turbine

Do not make any alterations, additions or modifications to the gas turbine. Alterations to the gas
turbine and its equipment must be approved by Ansaldo Energia.
Risk of injury!
Unauthorized modifications can adversely affect the (operational) safety of the GT and
result in injury or equipment damage.
Page 7 of 17
20.11.14
Spare Parts
Spare parts must satisfy the technical requirements defined by Ansaldo Energia. This can be ensured
only through the use of original replacement parts.
The following measure eliminates the risk of equipment damage:
 Always refer to the Spare Parts Catalog when ordering spare parts. The wrong parts or
parts with improper settings may be delivered if spare parts are ordered on the basis of
the manufacturer's documentation .
 Spare parts must be stored so as to ensure their quality and functionality.
 Parts packed in plastic sheeting often include a desiccant which must be periodically
replaced or regenerated (frequency of desiccant renewal is a function of local conditions).
Safety Notices Regarding Certain Phases in the Service Life of your Gas Turbine
Transport
The following safety notices pertain to the safe transport of loads (these notices apply to all
transports over the service life of the GT, i.e. also to the handling of spare parts, etc.).
 Do not walk or stand under suspended loads. Falling loads can cause personal injury.

 Use only suitable or specified and technically sound lifting gear and hoisting equipment.
 Use only lifting gear and hoisting equipment having adequate load capacity.
 Inspect lifting gear and load attachment rigging for damage (cracks, deformation) prior to
use. Only use lifting gear which is in perfect condition.
 Protect turbine shafts against damage from wire ropes. Place leather pads between the
slings and the attachment points.
 Allow only experienced personnel to attach loads and direct crane operators. The person
giving directions shall be visible to the operator or be in verbal contact with him.
 Prior to transporting heavy components within buildings, ensure that the building has a
sufficient load-bearing capacity over the entire transport path and at the installation or
storage site.
 Always use lifting gear to lift/transport heavy items.
 Secure items being handled to reliably prevent rolling, sliding and dropping.
 Always take appropriate safety precautions when transporting hazardous materials.
The following measures reduce or eliminate the risk of equipment damage:
 Apply supports and attach slings to turbine components at the intended points only.
 Do not remove packaging materials and protective wrapping during transport. If
necessary, provide items to be transported with suitable packaging and wrapping
Page 8 of 17
20.11.14
materials.
Please refer to the shipping documents for the dimensions and weight of turbine
components.
To ensure full compensation in the event of transport damage:

 Check all items (including spare parts) for signs of transport damage upon receipt.
Immediately report such damage to the transport company in writing.
 Meticulously check individual parts for signs of damage. Report any damage to the
manufacturer in writing.
Assembly/Installation
The following safety notices pertain to the assembly and installation of plant equipment:
The following measures reduce or eliminate the risk of explosion or fire:
 Work on piping shall only be performed by authorized personnel. Improper
installation/removal of piping can cause cracking. Fuel at high pressure (e.g. 80 bar) can
escape through such cracks and explode or ignite on contact with the hot gas turbine.
The following measures minimize or eliminate health hazards:
 Dust containing Ni, Cr or Co, either in compounds or in elemental form, can cause cancer.
An approved industrial vacuum must be used to extract the dust when grinding materials
containing Ni, Cr or Co (e.g. heat shields). Respirators (class "P2" or "P3" particle-filtering
half facepiece type) must be worn if dust extraction is not possible.
Eating, drinking and smoking while grinding is prohibited. Avoid contact with skin and
avoid stirring up dust (e.g. by sweeping). Wash hands thoroughly before eating, drinking
or smoking.

 Rotate turbine shaft only by applying torque at the clutch. Do not apply force to the
blades.
 Do not remove protective transport fixtures until immediately prior to final installation of
these items.
 Check the building blueprints prior to the beginning of installation.
 Remove preservation agents from items prior to their installation using a suitable
cleaning agent (e.g. a room temperature degreaser or similar cleaning agent). Use
products generally recognized as safe and environmentally compatible whenever
possible. Refer to the manufacturer's documentation in the case of outside vendor parts.
 Determine setdown points for heavy loads only on the basis of the floor loading plan.
 Locking elements and seals are generally disposable (i.e. the locking or sealing function
cannot be guaranteed if reused). This applies in particular to locking elements which
deform plastically (e.g. lock washers and locking strips for compressor and turbine blades)
and to soft iron seals (e.g. manhole seals).
Page 9 of 17
20.11.14
Locking elements/seals must be replaced after use with new ones. Used locking elements
and seals must be accounted for and disposed of immediately to prevent their reuse.
Turbine Startup
The following safety notices pertain to startup of the GT:
The following measure eliminates the risk of injury:

 Before starting up the gas turbine, make certain that there is no risk of injury due to
rotating parts.

 Perform prescribed tests (dust emissions, exhaust emissions, etc.).
 Before starting up the gas turbine, make certain that there are no tools or other foreign
objects inside the turbine. This applies particularly to the intake ducts.
 Check all components and I&C equipment for proper function and settings.
 Check changes made to the burner design and cooling air flow at all load levels by
temperature measurements.
 Do not attempt to start the GT if the rotor cannot be turned.
Mandatory Documentation:
 Record all operating parameters after an adequate period of steady-state operation.
 Prepare a report on the startup operation.
Operation
The following safety notices pertain to operation of the gas turbine:
The following measure eliminates the risk of burns:

 Do not touch hot surfaces. During operation and after shutdown, many gas turbine parts
are at temperatures exceeding 100 °C.
 The GT is operated from the control room. Remaining in the immediate vicinity of the GT
when it is running is only permitted in the case of inspection and maintenance work
required for GT operation.
 Also comply with the safety notices and operating instructions in the operating manual.
 In the event of safety-related gas turbine faults, immediately press the trip button and, if
necessary, also press the fire protection button. Do not restart the gas turbine until the
faults have been eliminated.
 Check the gas turbine at regular intervals for external signs of damage and deficiencies.
Page 10 of 17
20.11.14
Immediately report any changes (including changes in operating behavior) to the
responsible department/person. Shut down GT immediately, if necessary. Consult
Ansaldo Energia if you have any questions.
 Ensure compliance with legal codes on noise abatement.

 All drain valves must be closed prior to starting the GT. Otherwise hot gas would escape
there.
 If the three-phase power supply fails, the turning gear is also no longer functional. This
results in uneven cooling of the rotor and safe, reliable startup can no longer be
guaranteed. The GT may only be restarted after all of the conditions stipulated in Section
TGO2-1501 have been satisfied.
 In case of fault to three-phase power, the emergency oil pumps automatically starts and
it should not be shut down unless in case of fire (see section TGO2-1501). Otherwise the
turbine bearings could overheat (ambient heat of the exhaust casing).
 Opening of one or more blowoff valves during zero-load or power operation is not
permissible as this would induce vibration in the compressor blading. Operation with one
or more blowoff valves open is only permissible during runup, normal shutdown or in the
event the GT trips. If one or more blowoff valves close because of a fault, the GT must be
shut down immediately using the control system.
Hearing protection required!

 Wear hearing protection when near the gas turbine whenever it is running. Failure to do
so could result in permanent hearing loss due to GT operating noise.
Page 11 of 17
20.11.14
Service/Repair/Maintenance/Fault Rectification
The following safety notices pertain to service, repair and maintenance work, as well as GT fault
rectification.

 Safe and reliable operation of the GT can only be achieved by regular performance of
inspection and maintenance work. Further details can be found in the Section
"Maintenance".
 No work shall be performed on the GT until after authorization has been given by the
responsible party.
 Do not work on the gas turbine until it has come to a complete stop. Also ensure that
interval turning of the GT is blocked. Do not start up gas turbine until all work has been
completed. Prior to start-up, make certain that the turbine is in a condition safe for
operation.
 Before commencing any work, completely shut down the GT (disconnect the power
supply as well) and secure it against unauthorized or inadvertent restart. Exceptions are
only permissible if the work requires the operation of a (sub)system. In this case,
particular care is required to prevent accidents and equipment damage.
 Before restarting the gas turbine, make certain that this poses no threat of personal
injury.
 Prior to commencing work on pressurized systems (pneumatic, hydraulic, fuel, etc.), shut
down the system and depressurize segments to be opened-beware of internal pressures.
Always exercise due caution when opening pipe unions. Failure to do so could result in
injury from escaping media.
 Fault rectification may only be performed by personnel familiar with maintenance work
as the documentation (manual section 3.3, Fault Rectification) only includes brief
warnings of a few specific dangers.
 Tools and equipment for inspection and major inspection may only be used by Ansaldo
Energia personnel or under the supervision of an Ansaldo Energia supervisor.
 Only use tools and devices for their intended purpose. Observe load limits.
 Never use damaged tools or devices—immediately repair or scrap such items.
 Allow only trained personnel to work on the gas turbine.
 Inform operating personnel prior to the commencement of maintenance or repair work.
Designate supervisory personnel.
 Should safety devices be removed, reinstall them immediately after work has been
completed and check for proper function.
 Hydraulic hoses must be replaced every 6 years–regardless of how long the plant is
actually in operation–(i.e. storage times must also be taken into account).
Page 12 of 17
20.11.14
 Wear appropriate protective gear when working with solvents, products containing
solvents or other hazardous substances. Follow manufacturer's instructions. Use products
generally recognized as safe whenever possible.
 Dust containing Ni, Cr or Co, either in compounds or in elemental form, can cause cancer.
An approved industrial vacuum must be used to extract the dust when grinding materials
containing Ni, Cr or Co (e.g. heat shields). Respirators (class "P2" or "P3" particle-filtering
half facepiece type) must be worn if dust extraction is not possible.
Eating, drinking and smoking while grinding is prohibited. Avoid contact with skin and
avoid stirring up dust (e.g. by sweeping). Wash hands thoroughly before eating, drinking
or smoking.
 No welding work shall be performed on the gas turbine without the prior approval of
Ansaldo Energia. The applicable welding procedures must be obtained and observed.
 If work is being performed on several systems at the same time, the work must be
coordinated so as to prevent work on one system from creating a hazard to other systems
or those working on these systems. This is particularly relevant to interconnected systems
(e.g. fuel systems and combustion chamber/exhaust duct). When opening a section of the
fuel system, for example, steps must be taken to prevent fuel gas from entering the
combustion chamber and exhaust duct while these are being worked on (toxic hazard).
 Repairs to fuel-bearing components may be performed by Ansaldo Energia or
manufacturer personnel only, not the customer. The components in question include the
fuel control and emergency stop valves, fuel pumps and ball valve assemblies.
 Only Ansaldo Energia personnel may perform major inspections.
 If any work (temporarily) blocks traffic routes, appropriate signs and barricades shall be
put up to alert personnel.

 Work on piping must be performed by authorized personnel only. Improper
installation/removal of piping can cause cracks. Fuel at high pressure (e.g. 80 bar) can
escape through the cracks and can explode or ignite on contact with the hot gas turbine.
 Risk of falling and/or explosion and fire hazard: Never use piping or valves as handholds
or footholds. Pipes can break or stresses may be transmitted internally at flange
connections, which in time can cause cracks through which fuel may escape.
If a pipe was used as a handhold in an emergency situation (e.g. to prevent an accident),
detach both the connecting flanges and check the alignment of the piping or valves,
making any necessary corrections. Both the piping and the connecting flanges in question
must also be inspected for external damage. Parts exhibiting external damage or
substantial deformation must be replaced.
 Ensure that explosion protection remains functional when removing explosion-protected
components.
Page 13 of 17
20.11.14
 Under certain circumstances, explosion protection can be lost if explosion-protected
components are disassembled. Ensure that explosion protection remains functional
during reassembly-in some cases this is only possible at the manufacturer's plant.
Observe all manufacturer instructions regarding explosion protection.
 Before commencing work on the fuel system, the respective segment must be drained
and inerted.
Fire, open flames and smoking prohibited!

 Explosion and/or fire hazard: Do not smoke or use open flames when working on systems
which contain flammable media (e.g. fuel systems).
 Prior to commencing work on the GT or GT auxiliary systems, the respective segment
must be isolated (deenergize, depressurize, inert, etc.).
The following measures eliminate the risk of burns:

 Do not touch hot surfaces. During operation and after shutdown, many parts of the gas
turbine and its auxiliary systems are at temperatures exceeding 100 °C.
Allow gas turbine to cool to room temperature before working on it.
The following measure reduces or eliminates the risk of electric shock:

 Only qualified electricians shall perform work on electrical systems and equipment.
 Before work is performed near the capacitors, these items must be discharged by
qualified electricians.

 Remove tools and other foreign objects from the gas turbine immediately after use.
 If system sections are opened to perform work, cover these openings immediately. This
applies in particular to systems with direct access to the compressor or turbine. Covers
used for this purpose must be sufficiently close fitting and strong to reliably prevent the
ingress of foreign objects.
 Ensure compliance with the prescribed maintenance and inspection intervals and the
scope of work as laid down in the technical documentation.
 Locking elements and seals are generally disposable (i.e. the locking or sealing function
cannot be guaranteed if reused). This applies in particular to locking elements which
deform plastically (e.g. lock washers and locking strips for compressor and turbine blades)
and to soft iron seals (e.g. manhole seals).
Locking elements/seals must be replaced after use with new ones. Used locking elements
and seals must be accounted for and disposed of immediately to prevent their reuse.
Cellular phones, two-way radios and CD players prohibited!

 To prevent possible interference with the GT control system, the use of cellular phones,
two-way radios and CD players is prohibited in the vicinity of the GT and GT control
Page 14 of 17
20.11.14
system equipment. Such devices may also disturb electronic measurements.
Shutting Down the Gas Turbine

The following safety notices pertain to shutdown of the gas turbine:

 Before commencing any work, completely shut down the GT (disconnect the power
supply as well) and secure it against unauthorized or inadvertent restart. Wait until the
GT has come to a complete stop. Do not remove safety devices before this time.
 Observe turbine coastdown time. Failure to do so could result in injury from rotating
parts.

 Apply preservation agents to the turbine.
Mandatory Documentation:
 Perform and record the results of inspections prescribed during shutdown.
 Prepare a report on the shutdown operation.
Waste Disposal
Whenever there is waste of any kind (e.g. lubricants) to be disposed of, ensure compliance with
applicable local codes governing waste disposal procedures and methods.

 Place waste which cannot be directly disposed of in appropriately marked containers and
store temporarily in such a way as to ensure that there is no danger of personal injury or
harm to the environment.
 Neutralize all acids and bases prior to storage.
Page 15 of 17
20.11.14
Indications of Special Types of Hazard
The following safety information and regulations on conduct to the special hazard types stress
fractures, electrical energy, heat and noise.
Stress Fractures

 Work on piping must be performed by authorized personnel only. Incorrect
installation/removal of piping can cause cracks. Fuel at high pressure (e.g. 80 bar) can
escape through the cracks and explode or ignite on the hot gas turbine.
 Risk of falling and/or explosion and fire hazard: Never use piping or valves as handholds
or footholds. Pipes can break or stresses may be transmitted internally at flange
connections, which in time can cause cracks through which fuel may escape.
If a pipe was used as a handhold in an emergency situation (e.g. to prevent an accident),
detach both the connecting flanges and check the alignment of the piping or valves,
making any necessary corrections. Both the piping and the connecting flanges in question
must also be inspected for external damage. Parts exhibiting external damage or
substantial deformation must be replaced.
Heat
The following measures eliminate the risk of burns:

 Do not touch hot surfaces. During operation and after shutdown, many gas turbine parts
are at temperatures exceeding 100 °C.
Hot surfaces can cause severe burns.
Electrical Energy
The following measures reduce or eliminate the risk of electric shock:

 Work on the gas turbine’s electrical system shall be performed only by a qualified
electrician or by trained personnel instructed and directly supervised by an electrician
and in compliance with the codes governing work on electrical equipment.
 Check the gas turbine’s electric system at regular intervals. Rectify deficiencies
immediately.
 Before work is performed near the capacitors, these items must be discharged by
qualified electricians.

 Isolate all equipment on which maintenance or repair work is to be performed. Check to
ensure that isolated components are deenergized, then ground them and isolate any
adjacent components which are still live.
Page 16 of 17
20.11.14
NOISE Hearing protection required!
 Wear hearing protection when near the gas turbine whenever it is running. Failure to do
so could result in permanent hearing loss due to GT operating noise.
Page 17 of 17
20.11.14
I trasgressori saranno responsabili per i relativi danni. Tutti i diritti, inclusi quelli derivanti da concessione di un brevetto o da registrazione di modelli o progetti, sono riservati.
AVVERTENZE
SAFETY SULLA SICUREZZA
WARNING
Su questa Sezione
Questa sezione si rivolge all’operatore della turbina a gas e al suo personale operativo e di
IT IS FORBIDDEN
manutenzione. TO ENTER
In esso troverete THE GAS
informazioni TURBINE
importanti ENCLOSURE
riguardanti le operazioniWHEN
sicure e
La riproduzione, la trasmissione od uso di questo documento o del suo contenuto non saranno consentiti senza espresso consenso scritto.
la manutenzione di una turbina a gas.

GAS TURBINE IS IN OPERATION
La turbina a gas è stata progettata secondo lo stato dell’arte e con i regolamenti di
sicurezza riconosciute. Le operazioni e la manutenzione della TG tuttavia coinvolgono lo
stoccaggio
Any di sostanze pericolose
maintenance/repair (perinspection
intervention, es. carburanti, agenti lubrificanti
or surveillance in the gaseturbine
pulenti)compartment
ed il loro
uso ad alte temperature e sotto forte pressione. Di conseguenza i rischi
(inside enclosure) can be carried out only when the gas turbine is not in operation.per il personale, le
attrezzature
Before e l’ambiente
entering può(when
the enclosure avvenire – misure
gas turbine sonoin state
is not prese itove
operation) possibile
must durante
be ensured thatlathe
fase di progettazione per minimizzare
fire fighting system is switched off. tali pericoli.
Per la vostra sicurezza, leggere questa sezione attentamente e totalmente seguendo le
avvertenze e i regolamenti alla lettera. Solo in questo modo potete proteggere voi stessi da
The same
lesioni e evitareprohibition is extended
danni alla turbina a gas. also to all the other enclosures
Tutte le informazioni incluse in questa sezione sono di natura generale e si applica al
numerooperating
Before di tipi diversi di turbine
the gas turbine. or
Ulteriori
to haveavvertenze
access to sulla sicurezza
gas turbine andappaiono nelle ultime
its equipment area the
sezioni delshall
personnel manuale operativoread
have carefully e si the
applicano oltre alle
O&M manual andinformazioni quisafety
shall know all presenti.
notices of section
TGO1-0045
Nei casi inincui
order to befornite
le parti fully awarded
da terzi about the utilizzate,
vengano conditions la
which may result
rispettiva during gas turbine
documentazione del
operation.
fabbricante sarà osservata. Come usato in questa sezione, la “documentazione tecnica” si
riferisce sia alla documentazione del prodotto che operativa.
Come usato nella documentazione tecnica, il termine “turbina a gas” (TG) si riferisce
anche ai sistemi ausiliari.
Questa sezione include anche i pericoli che nascono dalla TG. Non sono inclusi qui altri
pericoli che possono nascere dalla interazione con altri sistemi e altri fattori sul luogo
dell’installazione della TG.
Pagina 1 di 1
SAFETY WARNING TGO-0046-E00000
20.11.14
AVVERTENZE SULLA
REFERENCE SICUREZZA
ADDRESSES
Su questa Sezione
Questa sezione si rivolge all’operatore della turbina a gas e al suo personale operativo e di
TECHNICAL
manutenzione. ASSISTENCE
In esso troverete DURING
informazioni THE WARRANTY
importanti riguardanti lePERIOD
operazioni sicure e
la manutenzione di una turbina a gas.

La turbina
During a gas èperiod,
the warranty stata the
progettata
Technicalsecondo loService
Assistance stato dell’arte
is availablee 24
con i regolamenti
hours a day, 7 daysdiper
sicurezza riconosciute. Le operazioni e
week for fault signaling and technical support.la manutenzione della TG tuttavia coinvolgono lo
stoccaggio di sostanze pericolose (per es. carburanti, agenti lubrificanti e pulenti) ed il loro
The technical Assistance Service is available by phone or fax or mail address as below indicated
uso ad alte temperature e sotto forte pressione. Di conseguenza i rischi per il personale, le
attrezzature e l’ambiente può avvenire – misure sono state prese ove possibile durante la
fase di progettazione per minimizzare tali pericoli.
ANSALDO ENERGIA
ASSISTENZA
avvertenze TECNICA
e i regolamenti / TECHNICAL
alla lettera. ASSISTANCE
Solo in questo modo potete proteggere voi stessi da
lesioni
VIA eN.
evitare danni alla
LORENZI 8, turbina a gas.
Tutte le informazioni incluse in questa sezione sono di natura generale e si applica al
16152 GENOVA
numero di tipi diversi di turbine. Ulteriori avvertenze sulla sicurezza appaiono nelle ultime
ITALY
sezioni del manuale operativo e si applicano oltre alle informazioni qui presenti.
Nei casi in cui le parti fornite da terzi vengano utilizzate, la rispettiva documentazione del
riferisce
Tel. ++sia 39010
alla documentazione
655 6564del prodotto che operativa.
faxai++sistemi
anche 39 010 655 3872
ausiliari.
E-Mail: CustomerSupport@ansaldoenergia.com
Pagina 1 di 2
TECHNICAL ASSISTENCE TGO1-0200-E00003
01.12.16
AVVERTENZE
RETURNING PARTS FORSULLA
REPAIR SICUREZZA
OR SUBSTITUTION
Su questa Sezione
To ensure proper handling when returning parts to the factory, be sure to use the proper address for
Questa
the sezione
chosen mode si
of rivolge
shipmentall’operatore della
and to include the turbina a gas
necessary e al suo personale
supplementary operativo e di
information.
manutenzione. In esso troverete informazioni importanti riguardanti le operazioni sicure e
la manutenzione
Use di una turbina a gas.
the following address:
La turbina a gas è stata progettata secondo lo stato dell’arte e con i regolamenti di
ANSALDO ENERGIA
sicurezza riconosciute. Le operazioni e la manutenzione della TG tuttavia coinvolgono lo
stoccaggio di sostanze pericolose
SERVICE (per es. DI
– UNITA’ carburanti, agenti lubrificanti
PRODUZIONE RICAMBIe pulenti) ed il loro
uso ad alte temperature e sotto forte pressione. Di conseguenza i rischi per il personale, le
VIA–N.
attrezzature e l’ambiente può avvenire LORENZI
misure 8 prese ove possibile durante la
sono state
fase di progettazione per minimizzare tali pericoli.
16152 GENOVA
avvertenze e i regolamenti alla lettera. SoloITALY
in questo modo potete proteggere voi stessi da
lesioni e evitare danni alla turbina a gas.
Tutte
All partslereturned
informazioni
must beincluse
markedin
forquesta sezione
identification sonoshipper
of the di natura generale e si applica al
as follows:
numero di tipi diversi di turbine. Ulteriori avvertenze sulla sicurezza appaiono nelle ultime
 Company, department and name of the Customer responsible.
sezioni del manuale operativo e si applicano oltre alle informazioni qui presenti.
 Machine Number (see rating plate of gas turbine)
Nei casi in cui le parti fornite da terzi vengano utilizzate, la rispettiva documentazione del
 Ansaldo Energia department which has been informed of the return
riferisce
Reasonsia
foralla
return.
documentazione del prodotto che operativa.
anche ai sistemi ausiliari.
Pagina 2 di 2
TECHNICAL ASSISTENCE TGO1-0200-E00003
01.12.16
LIST OF HAZARDOUS MATERIALS
Hazardous materials are considered in areas where potential explosion mixtures can form due to the
presence of gas, dust or fluid vapors.
The hazardous media encountered on gas turbines for dual fuel operation are the following:
 NATURAL GAS
 FUEL OIL
 IGNITION GAS
 LUBE OIL
 HYDRAULIC OIL
 HYDROGEN
Note: this section gives only information regarding the hazardous materials. Adequate ventilation
and protection concepts are applied on gas turbine on the basis of the hazardous areas classification
in order to avoid any risk deriving from the hazardous materials.
In particular, the hazardous areas a re subdivided into three zones:

Zone 0: “Part of a Hazardous area in which a flammable atmosphere is continuously present or
present for long periods”.
Zone 1: “Part of a Hazardous area in which a flammable atmosphere is likely to occur in normal
operation”.
Zone 2: “Part of a Hazardous area in which a flammable atmosphere is not likely to occur in
normal operation and, if it occurs, it will exist only for short period”.
In gas turbine plant, no Zone 0 and Zone 1 areas are present, but only some areas classified as zone
2. Refer to the Hazardous Area Classification drawing and reports relevant to order.
Page 1 of 4
LIST OF HAZARDOUS MATERIALS TGO1-0300-E00000
20.11.14
Hazard evaluation according to the fluids
The gas or vapour density identifies the hazard degree.

A gas which is lighter than air dissipates faster in the atmosphere, except than in closed space, and
rarely makes and explosive mixture.
A gas which is heavier than air, in stagnant conditions has a slow diffusion and, without a natural
forced ventilation, can make an explosive mixture.
An explosive gas (vapour) atmosphere cannot exist if the flash point is significantly above the
relevant maximum temperature.
For the definition of explosion protection measures of the fluids, the following table is used:
IGNITION FLASH
FLUID TEMPERATURE POINT TEMPERATURE CLASS DENSITY
[°C] [°C]
NATURAL GAS 482 - IIAT1 < than air
FUEL OIL 330 55 T2 > than air
IGNITION (propane) 470 - IIAT1 > than air
LUBE OIL 370 > 170 IIAT2 > than air
HYDRAULIC OIL 400 > 185 IIAT2 > than air
HYDROGEN 560 - IICT1 < than air
Page 2 of 4
20.11.14
FUEL GAS
Possible leakage from:
- gas piping flanges connection
- instrument connections
- burners connections
- valves
- filter
The fuel gas skid and the gas turbine itself are equipped with enclosures to ensure forced adequate
ventilation in order to classify the areas as Zone 2. All instrumentation in the above mentioned
enclosures are according to Zone 2.
See detailed report: “Hazardous area classification” order related.
FUEL OIL
The fuel oil is handled at a temperature which is below the flash point so an explosive gas (vapour)
atmosphere cannot exist and as a consequence the zone is not hazardous and no protection is
required. As a conservative safety measure, the fuel oil drainage pits are classified as Zone 2 even if
the fuel oil operating temperature is below the flash point.
IGNITION GAS
The ignition gas tank is located outside the gas turbine building so it is not considered
Normally, propane gas is used. Possible release source of ignition gas is the piping and instrument
connection on the ignition gas skid.
The gas in the system is handled at a pressure of about 12 bar(g) and a temperature of 40 °C.
Although for the new installation leakages do not occur, it is assumed that after prolonged operation
structural leakages con occur or occasional leakage due to a gasket failure.
The structural leakage is calculated to be negligible and occasional leakage leads to Zone 2
classification. All instrumentation in the ignition gas skid is as required as per Zone 2. The ignition
skid is located inside the fuel gas skid (same enclosure).
Page 3 of 4
20.11.14
LUBE OIL
The flash point of lube oil is > 170 °C while its design temperature is ≤ 80 °C. An explosive gas
(vapour) atmosphere cannot exist if the flash point is significantly above the relevant maximum
temperature. As a consequence the zone is not hazardous and no protection is required.
HYDRAULIC OIL
The flash point of hydraulic oil is > 185 °C while its design temperature is ≤ 70 °C. An explosive gas
(vapour) atmosphere cannot exist if the flash point is significantly above the relevant maximum
temperature. As a consequence the zone is not hazardous and no protection is required.
HYDROGEN
Hydrogen is present as medium in the batteries. Battery room can be interested of hydrogen gas
release while the batteries are in stand-by and during the battery charging operation. Although the
experience did not record explosion in the battery room, it is normal procedure to classify this area
as Zone 1 due to the possibility of hydrogen release. Battery room is equipped with an adequate
ventilation. See “Hazardous area classification” order related.
Page 4 of 4
20.11.14
KKS – POWER PLANT IDENTIFICATION SYSTEM
KKS identifiers are used to designate parts in the PID diagrams, equipment, instrument and electrical
lists, functional and terminal diagrams. In this connection the power plant unit designation is not
quoted.
Most of the, valves, units and measuring instruments etc. are provided with a nameplate showing
the complete KKS identifier, this including the power plant unit number.
In the event of technical queries, the KKS designation should always be quoted since this clearly
identifies which part is implied.
The KKS designation cannot be used for ordering the spare parts.
Structure of the identifier

The KKS system lays down the method by which identifier consists of letters and numerals. The
significance of the letters is laid down by the KKS system whereas the significance of the numerals is
defined by the GT supplier.
The build-up of an identifier is explained with the following example.
Es: MBP 21 AA 001-S01
In case of several units in the same plant, a progressive number can be put before the KKS label, e.g.
11MBP21AA001-S01. This portion of the identifier is omitted when the power plant only has one
unit. It does not appear in P&ID diagrams.
MB: (GAS TURBINE).

All parts of the gas turbines are designated “MB” with the exception of parts invite belong to a higher
level system, e.g. a subdistributor.
Es: MBP 21 AA 001-S01
P: (Auxiliary system)
This letter identifies the auxiliary system to which the part belongs. “P” stands for the fuel gas
system.
Page 1 of 5
KKS – POWER PLANT IDENTIFICATION SYSTEM TGO1-0400-E00000
10.03.16
The following letters are employed.
A: For compressor and turbine
D: For bearings
K: For coupling, gear systems, shaft turning gear.
L: For air intake system
M: For combustion chambers
N: For liquid fuel system
P: For gas fuel system
Q: For ignition system
R: For exhaust system
U: For water and steam injection
V: For lubrication oil system
X: For non-electrical hydraulic, pneumatic system
Y: For electrical control system
Es: MBP 21 AA 001-S01
21:
This 2 digit number identifies a system section. In general this number increases with the direction of
flow.
Es: MBP 21 AA 001-S01
AA: (Equipment Unit)

This combination of letters indicates the function of a part. In this example, the identifier “AA”
indicates a valve. The type of device (plug-type, slide-type, or damper-type) is not designated by this
letter, neither is the type of actuation (by hand, electrical, hydraulic, pneumatic, check valve).
Page 2 of 5
10.03.16
Neither in the case of measuring instruments. For example is not possible to determine for the
designation “CT” whether it refers to a thermocouple, a resistance thermometer or a temperature
switch.
The following combinations of letters are used:
AA: for valves (including actuators);
AE: for turning, lifting and swivel gear
AH for heaters and coolers
AM: for mixer
AN: for fans and blowers
AP: for pumps
AS: for adjusting devices
AT: for filters and strainers
AV: for burners
AX: for test devices
AZ: for other units
BB: for tanks, vessels, accumulators
BP: for orifices
BQ: weight scales
BS: for silencers
BY: for mechanical control devices
BZ: for other units
CF: for flow meters
CG: for position measuring instruments
CL: for level measuring instruments
CP: for pressure measuring instruments
CQ: for quality variables (analysis)
CR: for flame detectors
CS: for speed measuring devices
CT: for temperature measuring instruments
CY: for vibration measuring instruments
GC: reference point
GF: for sub-distributors (junction boxes)
GQ: for power sockets
GS: for push buttons
GT: for transformers
Es: MBP 21 AA 001-S01
Page 3 of 5
10.03.16
001: (Equipment unit)
This three digit number is a serial number designating a function key. Certain ranges of numbers are
allocated to certain functions in case of valves and measuring instruments. This scheme is as follows.
In the case of valves:
001 to 099 Valves in main flow of fluid with automatic actuators (electrical, hydraulic,
pneumatic), on / off type.
151 to 159 Control valves with automatic actuators, (electrical, hydraulic, pneumatic)
201 to 249 Drainage valves
251 to 299 Vent valves
301 to 339 Hand-operated shut-off valves in front of measuring instrument with one
connections
401 to 369 Hand-operated shut-off valves in front of the plus pole connection of measuring
instrument with 2 connections
371 to 399 Hand-operated shut-off valves in front of the minus pole connection of measuring
instrument with 2 connections.
401 to 499 Hand operated shut-off valves in front of optional measuring point (test point)
For measuring instruments:

001 to 099 Measuring instruments for remote transmission of measured values, switch (on / off)
101 to 199 Measuring instruments for remote transmission of measured values, transmitters
401 to 499 Tapping points for inserting test measurement (optional).
501 to 599 Measuring instrument for local indication.
Page 4 of 5
10.03.16
Note: an additional letter can be inserted to specify:
a) Pilot valves have the same overall identifier as the main valve but with the addition of the suffix
“A”, “B” and “C” etc.
Example: In case an hydraulically operated stop valve MBN03AA001 is actuated by a solenoid the
complete identifier can be: MBNI3AA001A.
b) In the case of measuring instrument with several sensors., the individual sensors can be
distinguished by letters:
Example: In case of triple thermocouple for the bearing temperature measuring, the complete
identifier can be: MBD11CT101A, ...CT001B and ...CT001C.
In these cases there is no “Component Key” (see next section identifier is then “-“ if a measuring
instrument for remote electrical transmission of the measured value is involved, e.g. the position of a
valve.
Es: MBP 21 AA 001 –S01
- S01: (Additional specification)

The following identifiers are optional and generally not indicated in the P&ID:
-A For flame detectors

-B For transducers
-M For electric motors
-P For measuring instruments
-S For switches
-U For converters from electrical measure
-X for terminals, plugs, power sockets
-Y For solenoids.
Page 5 of 5
10.03.16
INSTRUMENT LIST
See the attached list.
Page 1 of 1
INSTRUMENT LIST TGO1-0500-E00000
24.11.14
Project MC: Owner:

Consultant:
PLANT PROJECT MAH‐TAAB CASPIAN POWER
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
MAZ AEN 01 MB* ME LIS 001 D
GAS TURBINE AE94.3A

INSTRUMENT LIST

2
0
IN‐HOUSE DOCUMENT REVISION

D 01/03/2018 REVISED WHERE INDICATED GALANTE ALECCI PERPIGLIA CAPOTOS PESCE
PEM/GTE/GFCA PEM/GTE/GFCA PEM/GTE ‐ TC PEM/GTE ‐ PE PEM/GTE
C 06/03/2017 REVISED WHERE INDICATED GALANTE ALECCI SANTOLINI CAPOTOS PESCE

PEM/GTE/GPFO PEM/GTE/GPFO PEM/GTE/GPFO ‐ TC PEM/GTE ‐ PE PEM/GTE
B 06/12/2016 REVISED WHERE INDICATED GALANTE TUO SANTOLINI CAPOTOS PESCE

Doc. No.: 0558 S1MB*M001

For Construction.
Contractor Sub‐Contractor
Rev.: D
Document Type: MPI
Documentation
(UED) Information
Document Scope: I
Language: E
Basic Eng. Doc. X Detailed Eng. Doc.□ Subsupl Eng. Doc. □
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
Revision Record
PAGE 0 A B C D PAGE 0 A B C D
1 X 27 X X
2 X 28 X
3 X 29 X X
4 X 30
5 X 31
6 X 32
7 X X X 33
8 X X X X 34
9 X X X 35
10 X X X 36
11 X X X X 37
12 X X X 38
13 X X 39
14 X X X 40
15 X X X X 41
16 X X X 42
17 X X X 43
18 X X 44
19 X X 45
20 X X
21 X X
22 X X X
23 X X X
24 X X X
25 X X X
26 X X
Doc. No.: 0558 S1MB*M001

Rev.: D
Document Type: MPI
Documentation
(UED) Information
Document Scope: I
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
FIELD DENOMINATION
PSD Power Supply Distribution
GTCMPS = supply from control system
RN Revision index item
IDENTIFICATION N° KKS
DESCRIPTION Instrument description
TYPE Instrument type (see Denomination of Field “TYPE”)
RANGE Operating range
SETTING Setting of rating and intervent point
VOLTAGE Power supply (if present)
USE Function for automation system (see Denomination of Field “USE”)
DESTINATION System for internal processing of the instrument signal
GTCMPS = Gas Turbine Control Monitoring and Protection System
SAMH = Ansaldo System for Humming Monitoring
TSI = Turbine Supervisor Instrumentation
P&ID No. Process drawing
JUNCTION BOX No. Terminal board (if not expected ‘----‘ or DIRECT for direct
connection)
Doc. No.: 0558 S1MB*M001

Rev.: D
Document Type: MPI
Documentation
(UED) Information
Document Scope: I
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
DENOMINATION OF FIELD “TYPE”

AMPL Amplifier/Amplificatore
CSE Compression Sensor (Load Cell)/Sensore di compressione (Cella di carico)
DPI Diff. Pressure Indicator/indicatore pressione differenziale
DPSE Diff. Pressure Sensor/sensore pressione differenziale
DPSW Diff. Pressure Switch/pressostato differenziale
DPSWI Diff. Pressure Switch with led local indicator/pressostato differenziale con indicatore locale a led
FI Flow Indicator/Indicatore di portata
FLDT Flame Detector/rilevatore di fiamma
FLSE Flame Sensor/sensore di fiamma
FLSW Flow Switch/flussostato
FOSW Force Switch/interruttore di coppia
FSE Flow Sensor Element/sensore di portata
LI Level Indicator/indicatore di livello
LSE Level Sensor/sensore di livello
LSW Level Switch/livellostato
LVDT Linear Voltage Detector Transducer/trasduttore voltmetrico lineare di posiz.
MES Moisture Electrical Separator/Separatore elettrico di umidità
P Pressure Tap (Test point)/presa di pressione
PI Pressure Indicator/indicatore di pressione
POSE Position Sensor/sensore di posizione
POSI Position Indication/indicatore di posizione
Doc. No.: 0558 S1MB*M001

Rev.: D
Document Type: MPI
Documentation
(UED) Information
Document Scope: I
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
POSW Position Switch/fine corsa di posizione
PRSW Proximity Switch/fine corsa di prossimità
PSE Pressure Sensor/sensore di pressione
PSEI Pressure Sensor Indicator/indicatore del sensore di pressione
PSW Pressure Switch/pressostato
PSWI Pressure Switch Indicator/pressostato e indicatore
Q Quality (Test point)/presa per analisi
QSE Quality measuring Sensor Element/sensore per misura analisi ambiente
QSW Quality measuring Switch/Interruttore per misura analisi ambiente
RTD1 Resistence Temperature Detector/termoresistenza
RTD2 RTD (dual element)/termoresistenza doppio elemento
SSE Speed Sensor/sensore di velocità
T Temperature Tap (test point)/presa di temperatura
TC1 Thermocouple (single element)/termocoppia (singolo elemento)
TC2 Thermocouple (dual element)/termocoppia (doppio elemento)
TC3 Thermocouple (triple element)/termocoppia (triplo elemento)
TI Temperature Indicator/indicatore di temperatura
TSE Temperature Sensor/sensore di temperatura
TSW Temperature Switch/termostato
VSE Vibration Sensor/sensore di vibrazione
Doc. No.: 0558 S1MB*M001

Rev.: D
Document Type: MPI
Documentation
(UED) Information
Document Scope: I
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
DENOMINATION OF FIELD “USE”

D Display
S Sequence
CTR Control
AL Alarm
BL Trip
I Interlock
Doc. No.: 0558 S1MB*M001

Rev.: D
Document Type: MPI
Documentation
(UED) Information
Document Scope: I
Language: E
MAZANDARAN (II) - CCPP GT INSTRUMENT LIST AEN DOC.N. S1MB*M001
JOB N. 0558 CLIENT DOC. N. MAZ-AEN-01-MB*-ME-LIS-001
REV.D
PSD RN Identification Description Type Range Settings Voltage Use Destination P & ID Junction Box Note
MBA10AT001-XB01 Air Dryer (Command On) Digital Input DC 24 D,S GTCMPS S1MBAS002 DIRECT
MBA10AT001-XB03 Air Dryer (Available) Digital Input DC 24 D,S GTCMPS S1MBAS002 DIRECT
MBA10AT001-XB04 Air Dryer (Selector in Remote Control) Digital Input DC 24 D,S GTCMPS S1MBAS002 DIRECT
MBA10AT001-XB05 Air Dryer (General Alarm) Digital Input DC 24 D,S GTCMPS S1MBAS002 DIRECT
MBA10AT001-YB01 Air Dryer (Air Dryer Start Command - External Remote Start) Digital Output AC 24 D,S GTCMPS S1MBAS002 DIRECT
C MBA10CG001 Safety Switch for Intermediate Shaft Cover POSW [-] CLOSED DC 24 S GTCMPS S1MBAS002 MBY25GF001 Permission to start-up
MBA10CG101-B01 Rotor Axial Displacement (for RDS System) VSE [1,2-13,2mm] [1,2-13,2] 4÷20 mA D,AL,BL,CTR,S GTCMPS S1MBAS002 MBA10CG101-U01
1,33 mV/μm
MBA10CG101-U01 Rotor Axial Displacement (for RDS System) AMPL
(sensitivity)
DC 24 S1MBAS002 DIRECT
MBA10CG102-B01 Rotor Axial Displacement (for RDS System) VSE [1,2-13,2mm] [1,2-13,2] 4÷20 mA D,AL,BL,CTR,S GTCMPS S1MBAS002 MBA10CG102-U01
1,33 mV/μm
MBA10CG102-U01 Rotor Axial Displacement (for RDS System) AMPL
(sensitivity)
B MBA10CS101 Turbine Speed SSE [0-12000Hz] [0-12000] DC 24 D,AL,BL,CTR,S GTCMPS S1MBAS002 MBY40GF001
B MBA10CS107 Turbine Overspeed SSE [0-12000Hz] [0-12000] DC 24 BL S1MBAS002 MBY40GF001
MBA10CY101-B01 Rotary Shaft Position (0-90°) VSE [0.4-4.4mm] 1,2 mm S GTCMPS S1MBAS002 MBA10CY101-U01
0÷300 μm peak-peak
MBA10CY101-U01 Rotary Shaft Position AMPL
4mV/μm (sensitivity)
MBA10CY102-B01 Rotary Shaft Position (0-90°) VSE [0.4-4.4mm] 1,2 mm S GTCMPS S1MBAS002 MBA10CY102-U01
MBA10CY102-U01 Rotary Shaft Position AMPL
Position Transmitter of Adjustment Turbine Blade First Stage (Inlet Guide

MBA11AS001-B01 POSE [0-150mm] 0-100% = 4-20mA DC 24 D,CTR GTCMPS S1MBAS002 MBY38GF001
Vanes IGV)
Position Transmitter of Adjustment Turbine Blade First Stage (Inlet Guide
Vanes IGV)
Limit Switch Fully Open of Adjustment Turbine Blade First Stage (Inlet
MBA11AS001-S11 POSW [-] OPEN DC 24 CTR GTCMPS S1MBAS002 MBY38GF001
Guide Vanes IGV)
Position Transmitter of Adjustment Turbine Blade First Stage (Compressor
Vane 1 CV1)
Position Transmitter of Adjustment Turbine Blade First Stage (Compressor
Vane 1 CV1)
Limit Switch Fully Open of Adjustment Turbine Blade First Stage
MBA11AS002-S11 POSW [-] OPEN DC 24 CTR GTCMPS S1MBAS002 MBY38GF001
(Compressor Vane 1 CV1)
MBA11CG001 Limit Switch Open of Adjustment Turbine Blade First Stage (IGV Ring) POSW [-] OPEN DC 24 CTR GTCMPS S1MBAS002 MBY38GF001
MBA11CG002 Limit Switch Closed of Adjustment Turbine Blade First Stage (IGV Ring) POSW [-] CLOSED DC 24 CTR GTCMPS S1MBAS002 MBY38GF001
MBA11CG011 Limit Switch Open of Adjustment Turbine Blade First Stage (CV1 Ring) POSW [-] OPEN DC 24 CTR GTCMPS S1MBAS002 MBY38GF001
Sheet 7 of 30
REV.D
MBA11CG012 Limit Switch Closed of Adjustment Turbine Blade First Stage (CV1 Ring) POSW [-] CLOSED DC 24 CTR GTCMPS S1MBAS002 MBY38GF001
MBA11CG501 Position Indicator of Adjustment Turbine Blade First Stage (IGV Ring) POSI +5° ÷ -40° S1MBAS002 ----------
MBA11CG502 Position Indicator of Adjustment Turbine Blade First Stage (CV1 Ring) POSI +5° ÷ -40° S1MBAS002 ----------
MBA11CP001 Compressor Air Inlet Differential Pressure DPSW [2-700mbar] < 30 +10 DC 24 AL,BL GTCMPS S1MBAS002 MBY21GF001
MBA11CP101 Compressor Air Inlet Absolute Pressure PSE [43-1300mbar] [700-1100] 4-20mA DC 24 D,AL,CTR GTCMPS S1MBAS002 MBY21GF001
MBA11CP102 Compressor Air Inlet Absolute Pressure PSE [43-1300mbar] [700-1100] 4-20mA DC 24 D,AL,CTR GTCMPS S1MBAS002 MBY21GF001
B MBA11CP103 Compressor Air Inlet Differential Pressure DPSE [1-60mbar] [0-30] 4-20mA DC 24 D GTCMPS S1MBAS002 MBY21GF001
RTD2
MBA11CT101A Compressor Air Inlet Temperature PT100 Ohm
[-60 ÷ +650°C] [-20 ÷ +50] D,CTR GTCMPS S1MBAS002 MBY38GF001
RTD2
B MBA11CT101B Compressor Air Inlet Temperature (Available) PT100 Ohm
[-60 ÷ +650°C] [-20 ÷ +50] D,CTR S1MBAS002 MBY38GF001
RTD2
RTD2
RTD2
RTD2
RTD2
RTD2
MBA12CP101 Compressor Air Discharge Pressure PSE [1÷30bar] 0÷25 bar = 4÷20mA DC 24 D,CTR GTCMPS S1MBAS002 MBY20GF001
MBA12CP102 Compressor Air Discharge Pressure PSE [1÷30bar] 0÷25 bar = 4÷20mA DC 24 D,CTR GTCMPS S1MBAS002 MBY20GF001
C MBA12CP103 Compressor Air Discharge Pressure (Available) PSE [1÷30bar] 0÷25 bar = 4÷20mA DC 24 D,CTR S1MBAS002 MBY20GF001
MBA12CP401 Compressor Air Outlet Test Point for Pressure P [0-25bar] S1MBAS002 ----------
TC2
MBA12CT101A Compressor Air Outlet Temperature NiCr-Ni type K
[0-650°C] [0-450] D GTCMPS S1MBAS002 MBY39GF001
TC2
D MBA12CT101B Compressor Air Outlet Temperature NiCr-Ni type K
[0-650°C] [0-450] D S1MBAS002 MBY39GF001
TC2
MBA12CT102A Compressor Air Outlet Temperature NiCr-Ni type K
[0-650°C] [0-450] D GTCMPS S1MBAS002 MBY39GF001
TC2
[0-650°C] [0-450] D S1MBAS002 MBY39GF001
TC2
D MBA12CT103A Compressor Air Outlet Temperature NiCr-Ni type K
[0-650°C] [0-450] D S1MBAS002 MBY39GF001
TC2
[0-650°C] [0-450] D S1MBAS002 MBY39GF001
MBA12CT401 Compressor Air Outlet Test Point Temperature T [0-600°C] S1MBAS002 ----------
MBA18CL501 Compressor Cleaning Water Tank Level Indicator LI ---- ---- S1MBAS003 ----------
GTCMPS MBA22AA001-S21 Inductive Proximity Switch Drain Valve for Compressor Exhaust Line PRSW [-] CLOSED DC 24 D,S GTCMPS S1MBAS004 MBY19GF001
GTCMPS MBA22AA002-S21 Inductive Proximity Switch Drain Valve for Compressor Exhaust Line PRSW [-] CLOSED DC 24 D,S GTCMPS S1MBAS004 MBY19GF001
RTD1
B MBA25CT101 Temperature for vent of drain lines header PT100 Ohm
[-40 ÷ +150°C] tbd D,AL GTCMPS S1MBAS004 MBY19GF001
TC3
C MBA26CT101A Exhaust Gas Temperature (Available) NiCr-Ni type K
[0-800°C] [0-720] D,CTR,AL,BL S1MBAS002 MBY02GF001
TC3
MBA26CT101B Exhaust Gas Temperature NiCr-Ni type K
[0-800°C] [0-720] D,CTR,AL,BL GTCMPS S1MBAS002 MBY02GF001
Sheet 8 of 30
REV.D
TC3
C MBA26CT101C Exhaust Gas Temperature NiCr-Ni type K
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
Sheet 9 of 30
REV.D
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
TC3
Sheet 10 of 30
REV.D
TC3
TC3
MBA41AA051-S11 Limit Switch for Blow-Off Valve Extraction Line 1.1 (Fully Open) POSW [-] OPEN DC 24 D,BL GTCMPS S1MBAS001 MBY39GF001
MBA41AA051-S21 Limit Switch for Blow-Off Valve Extraction Line 1.1 (Fully Closed) POSW [-] CLOSED DC 24 D,BL GTCMPS S1MBAS001 MBY39GF001
MBA43AA051-S11 Limit Switch for Blow-Off Valve Extraction Line 2 (Fully Open) POSW [-] OPEN DC 24 D,BL GTCMPS S1MBAS001 MBY39GF001
MBA43AA051-S21 Limit Switch for Blow-Off Valve Extraction Line 2 (Fully Closed) POSW [-] CLOSED DC 24 D,BL GTCMPS S1MBAS001 MBY39GF001
MBA51AA251-S11 Supply System RDS Limit Switch for Isolating Valve Upstream Pump 1 POSW [-] OPEN - D,AL,BL GTCMPS S1MBAS005 MBY15GF030
MBA51AA252-S11 Supply System RDS Limit Switch for Isolating Valve Upstream Pump 2 POSW [-] OPEN - D,AL,BL GTCMPS S1MBAS005 MBY15GF030
MBA51CP001 Supply System RDS Pressure for Gear Pump n.1 PSW [0-400bar] 110 bar ↓ DC 24 CTR,AL GTCMPS S1MBAS005 MBY15GF030
MBA51CP002 Supply System RDS Pressure for Gear Pump n.2 PSW [0-400bar] 110 bar ↓ DC 24 CTR,AL GTCMPS S1MBAS005 MBY15GF030
MBA51CP003 Supply System RDS Differential Pressure for filter …AT001 DPSW DC 24 AL GTCMPS S1MBAS005 MBY15GF030
MBA51CP101 Supply System RDS Pressure Downstream Gear Pumps PSE [0-250bar] [0-250bar] 4÷20mA DC 24 D,AL,BL,CTR,S GTCMPS S1MBAS005 MBY15GF030
MBA51CP102 Supply System RDS Pressure Downstream Gear Pumps PSE [0-250bar] [0-250bar] 4÷20mA DC 24 D,AL,BL,CTR,S GTCMPS S1MBAS005 MBY15GF030
D MBA51CP103 Supply System RDS Pressure Downstream Gear Pumps PSE [0-250bar] [0-250bar] 4÷20mA DC 24 D,AL,BL,CTR,S S1MBAS005 MBY15GF030
MBA51CP401 Supply System RDS Test Point for Pressure at Bladder Accumulator n.1 P S1MBAS005 ----------
MBA51CP402 Supply System RDS Test Point for Pressure at Bladder Accumulator n.2 P S1MBAS005 ----------
MBA51CP501 Supply System RDS Pressure Downstream Gear Pumps PI ---- S1MBAS005 ----------
MBA51CP502 Supply System RDS Pressure Indication Downstream Gear Pump 1 PI [0-250bar] ---- S1MBAS005 ----------
MBA51CP503 Supply System RDS Pressure Indication Downstream Gear Pump 2 PI [0-250bar] ---- S1MBAS005 ----------
MBA53AA001-S21 Return Line Main Thrust Valve Position Switch POSW [-] CLOSED DC 24 S,I,D,AL GTCMPS S1MBAS005 MBY15GF030
Sheet 11 of 30
REV.D
MBA53AA002-S11 Supply Line Main Thrust Valve Position Switch POSW [-] OPEN DC 24 S,I,D,AL GTCMPS S1MBAS005 MBY15GF030
MBA53AA004-S21 Supply Line Reverse Thrust Valve Position Switch POSW [-] CLOSED DC 24 S,I,D,AL GTCMPS S1MBAS005 MBY15GF030
MBA53AA005-S11 Return Line Reverse Thrust Valve Position Switch POSW [-] OPEN DC 24 S,I,D,AL GTCMPS S1MBAS005 MBY15GF030
MBA53CP101 Supply System RDS Pressure Return Line Main Thrust PSE [0-250bar] [0-250bar] 4÷20mA DC 24 D,AL,BL,S GTCMPS S1MBAS005 MBY15GF030
MBA53CP102 Supply System RDS Pressure Return Line Main Thrust PSE [0-250bar] [0-250bar] 4÷20mA DC 24 D,AL,BL,S GTCMPS S1MBAS005 MBY15GF030
MBA53CP103 Supply System RDS Pressure Return Line Reverse Thrust PSE [0-250bar] [0-250bar] 4÷20mA DC 24 D,AL,BL,S GTCMPS S1MBAS005 MBY15GF030
MBA53CP104 Supply System RDS Pressure Return Line Reverse Thrust PSE [0-250bar] [0-250bar] 4÷20mA DC 24 D,AL,BL,S GTCMPS S1MBAS005 MBY15GF030
D MBA53CP105 Supply System RDS Pressure Return Line Main Thrust PSE [0-250bar] [0-250bar] 4÷20mA DC 24 D,AL,BL,S S1MBAS005 MBY15GF030
D MBA53CP106 Supply System RDS Pressure Return Line Reverse Thrust PSE [0-250bar] [0-250bar] 4÷20mA DC 24 D,AL,BL,S S1MBAS005 MBY15GF030
MBA53CP401 Supply System RDS Test Point for Pressure Return Line Main Thrust P S1MBAS005 ----------
MBA53CP402 Supply System RDS Test Point for Pressure Feed Line Main Thrust P S1MBAS005 ----------
MBA53CP404 Supply System RDS Test Point for Pressure Feed Line Reverse Thrust P S1MBAS005 ----------
MBA53CP405 Supply System RDS Test Point for Pressure Return Line Reverse Thrust P S1MBAS005 ----------
MBA54CP402 Supply System RDS Test Point for Pressure Return Line Main Thrust P S1MBAS005 ----------
TC3
MBD11CT101A Bearing Temperature Turbine Side NiCr-Ni type K
[0-200°C] [0-200] D,AL,BL GTCMPS S1MBAS002 MBY18GF001
TC3
MBD11CT101B Bearing Temperature Turbine Side NiCr-Ni type K
TC3
MBD11CT101C Bearing Temperature Turbine Side NiCr-Ni type K
TC3
MBD11CT102A Bearing Temperature Turbine Side NiCr-Ni type K
TC3
MBD11CT102B Bearing Temperature Turbine Side NiCr-Ni type K
TC3
MBD11CT102C Bearing Temperature Turbine Side NiCr-Ni type K
B MBD11CY101-B01 Bearing Absolute Vibration Turbine Side VSE 0,01 g to 400 g peak D,AL,BL vibromiter S1MBAS002 MBD11CY101-U01
B MBD11CY101-U01 Bearing Absolute Vibration Turbine Side AMPL [0-25mm/s] DC 24 TSI S1MBAS002 DIRECT
B MBD11CY102-B01 Bearing Absolute Vibration Turbine Side VSE 0,01 g to 400 g peak D,AL,BL vibromiter S1MBAS002 MBD11CY102-U01
B MBD11CY102-U01 Bearing Absolute Vibration Turbine Side AMPL [0-25mm/s] DC 24 TSI S1MBAS002 DIRECT
MBD11CY111-B01 Bearing Relative Vibration Turbine Side VSE [0.4-4.4mm] 2,2 mm D,AL,BL vibromiter S1MBAS002 MBD11CY111-U01
MBD11CY111-U01 Bearing Relative Vibration Turbine Side AMPL
DC 24 vibromiter S1MBAS002 DIRECT
MBD11CY112-B01 Bearing Relative Vibration Turbine Side VSE [0.4-4.4mm] 2,2 mm D,AL,BL vibromiter S1MBAS002 MBD11CY112-U01
MBD11CY112-U01 Bearing Relative Vibration Turbine Side AMPL
DC 24 vibromiter S1MBAS002 DIRECT
TC3
MBD12CT101A Load Bearing Temperature Compressor Side NiCr-Ni type K
TC3
MBD12CT101B Load Bearing Temperature Compressor Side NiCr-Ni type K
TC3
MBD12CT101C Load Bearing Temperature Compressor Side NiCr-Ni type K
TC2
MBD12CT102A Compressor Main Thrust Bearing Temperature Upper Part NiCr-Ni type K
Sheet 12 of 30
REV.D
TC2
MBD12CT102B Compressor Main Thrust Bearing Temperature Upper Part NiCr-Ni type K
TC2
MBD12CT103A Compressor Main Thrust Bearing Temperature Lower Part NiCr-Ni type K
TC2
MBD12CT103B Compressor Main Thrust Bearing Temperature Lower Part NiCr-Ni type K
TC2
MBD12CT104A Compressor Secondary Thrust Bearing Temperature Upper Part NiCr-Ni type K
TC2
MBD12CT104B Compressor Secondary Thrust Bearing Temperature Upper Part NiCr-Ni type K
TC2
MBD12CT105A Compressor Secondary Thrust Bearing Temperature Lower Part NiCr-Ni type K
TC2
MBD12CT105B Compressor Secondary Thrust Bearing Temperature Lower Part NiCr-Ni type K
TC2
MBD12CT112A Compressor Main Thrust Bearing Temperature Upper Part NiCr-Ni type K
TC2
MBD12CT112B Compressor Main Thrust Bearing Temperature Upper Part NiCr-Ni type K
TC2
MBD12CT113A Compressor Main Thrust Bearing Temperature Lower Part NiCr-Ni type K
TC2
MBD12CT113B Compressor Main Thrust Bearing Temperature Lower Part NiCr-Ni type K
TC2
MBD12CT114A Compressor Secondary Thrust Bearing Temperature Upper Part NiCr-Ni type K
TC2
MBD12CT114B Compressor Secondary Thrust Bearing Temperature Upper Part NiCr-Ni type K
TC2
MBD12CT115A Compressor Secondary Thrust Bearing Temperature Lower Part NiCr-Ni type K
TC2
MBD12CT115B Compressor Secondary Thrust Bearing Temperature Lower Part NiCr-Ni type K
B MBD12CY101-B01 Compressor Bearing Absolute Vibration VSE 0,01 g to 400 g peak D,AL,BL vibromiter S1MBAS002 MBD12CY101-U01
B MBD12CY101-U01 Compressor Bearing Absolute Vibration AMPL [0-25mm/s] DC 24 TSI S1MBAS002 DIRECT
B MBD12CY102-B01 Compressor Bearing Absolute Vibration VSE 0,01 g to 400 g peak D,AL,BL vibromiter S1MBAS002 MBD12CY102-U01
B MBD12CY102-U01 Compressor Bearing Absolute Vibration AMPL [0-25mm/s] DC 24 TSI S1MBAS002 DIRECT
MBD12CY111-B01 Compressor Bearing Relative Vibration VSE [0.4-4.4mm] 2,2 mm D,AL,BL vibromiter S1MBAS002 MBD12CY111-U01
MBD12CY111-U01 Compressor Bearing Relative Vibration AMPL
MBD12CY112-B01 Compressor Bearing Relative Vibration VSE [0.4-4.4mm] 2,2 mm D,AL,BL vibromiter S1MBAS002 MBD12CY112-U01
MBD12CY112-U01 Compressor Bearing Relative Vibration AMPL
B MBD12CY115-B01 Compressor Secondary Thrust Bearing Load Cell Upper Part CSE [0÷15500N] [0÷15500N = 0÷20mV] S1MBAS002 MBD12CY115-U01
B MBD12CY115-U01 Compressor Secondary Thrust Bearing Load Cell Upper Part AMPL 0÷20mV = 4÷20mA DC 24 D,AL GTCMPS S1MBAS002 MBD12GF002
B MBD12CY116-B01 Compressor Secondary Thrust Bearing Load Cell Upper Part CSE [0÷15500N] [0÷15500N = 0÷20mV] S1MBAS002 MBD12CY116-U01
B MBD12CY116-U01 Compressor Secondary Thrust Bearing Load Cell Upper Part AMPL 0÷20mV = 4÷20mA DC 24 D,AL GTCMPS S1MBAS002 MBD12GF002
B MBD12CY117-B01 Compressor Secondary Thrust Bearing Load Cell Lower Part CSE [0÷15500N] [0÷15500N = 0÷20mV] S1MBAS002 MBD12CY117-U01
B MBD12CY117-U01 Compressor Secondary Thrust Bearing Load Cell Lower Part AMPL 0÷20mV = 4÷20mA DC 24 D,AL GTCMPS S1MBAS002 MBD12GF002
B MBD12CY118-B01 Compressor Secondary Thrust Bearing Load Cell Lower Part CSE [0÷15500N] [0÷15500N = 0÷20mV] S1MBAS002 MBD12CY118-U01
B MBD12CY118-U01 Compressor Secondary Thrust Bearing Load Cell Lower Part AMPL 0÷20mV = 4÷20mA DC 24 D,AL GTCMPS S1MBAS002 MBD12GF002
B MBD12CY125-B01 Compressor Main Thrust Bearing Load Cell Upper Part CSE [0÷15500N] [0÷15500N = 0÷20mV] S1MBAS002 MBD12CY125-U01
B MBD12CY125-U01 Compressor Main Thrust Bearing Load Cell Upper Part AMPL 0÷20mV = 4÷20mA DC 24 D,AL GTCMPS S1MBAS002 MBD12GF001
B MBD12CY126-B01 Compressor Main Thrust Bearing Load Cell Upper Part CSE [0÷15500N] [0÷15500N = 0÷20mV] S1MBAS002 MBD12CY126-U01
Sheet 13 of 30
REV.D
B MBD12CY126-U01 Compressor Main Thrust Bearing Load Cell Upper Part AMPL 0÷20mV = 4÷20mA DC 24 D,AL GTCMPS S1MBAS002 MBD12GF001
B MBD12CY127-B01 Compressor Main Thrust Bearing Load Cell Lower Part CSE [0÷15500N] [0÷15500N = 0÷20mV] S1MBAS002 MBD12CY127-U01
B MBD12CY127-U01 Compressor Main Thrust Bearing Load Cell Lower Part AMPL 0÷20mV = 4÷20mA DC 24 D,AL GTCMPS S1MBAS002 MBD12GF001
B MBD12CY128-B01 Compressor Main Thrust Bearing Load Cell Lower Part CSE [0÷15500N] [0÷15500N = 0÷20mV] S1MBAS002 MBD12CY128-U01
B MBD12CY128-U01 Compressor Main Thrust Bearing Load Cell Lower Part AMPL 0÷20mV = 4÷20mA DC 24 D,AL GTCMPS S1MBAS002 MBD12GF001
MBH22AA101-B01 Air Cooling System Turbine Stage 2 Control Valve Position POSE [0-90°] 17°-80° = 4-20mA DC 24 D,AL,CTR Local Positioner S1MBHS001 DIRECT
Air Cooling System Turbine Stage 2 Control Valve Thermostat for

MBH22AA101-S41 TSW [-] DC 24 AL Local Positioner S1MBHS001 DIRECT
Protection Motor
MBH22AA101-XB01 Air Cooling System Turbine Stage 2 Control Valve (Fault Signal) Digital Input DC 24 GTCMPS S1MBHS001 MBH22AA101-A01
Air Cooling System Turbine Stage 2 Control Valve (Available Signal) - not
MBH22AA101-XB03 Digital Input DC 24 GTCMPS S1MBHS001 MBH22AA101-A01
used if signal is provided from MCC
MBH22AA101-XB04 Air Cooling System Turbine Stage 2 Control Valve (Automode) Digital Input DC 24 GTCMPS S1MBHS001 MBH22AA101-A01
MBH22AA101-XQ01 Air Cooling System Turbine Stage 2 Control Valve (Feedback Position) Analog Input DC 24 GTCMPS S1MBHS001 MBH22AA101-A01
MBH22AA101-YQ01 Air Cooling System Turbine Stage 2 Control Valve (Position Demand) Analog Output DC 24 GTCMPS S1MBHS001 MBH22AA101-A01

Protection Motor
MBH22CP102 Air Cooling System Turbine Stage 2 Pressure PSE [1÷30bar] 0÷25 bar = 4÷20mA DC 24 D,CTR,AL,BL GTCMPS S1MBHS001 MBY20GF001
D MBH22CP104 Air Cooling System Turbine Stage 2 Pressure PSE [1÷30bar] 0÷25 bar = 4÷20mA DC 24 D,CTR,AL,BL S1MBHS001 MBY20GF001

Protection Motor

Protection Motor
Sheet 14 of 30
REV.D
D MBH23CP104 Air Cooling System Turbine Stage 3 Pressure PSE [1÷30bar] 0÷25 bar = 4÷20mA DC 24 D,CTR,AL,BL S1MBHS001 MBY20GF001
MBH24CP501 Air Cooling System Pressure at Balance Piston PI [0-6bar] [0-6bar] ---- S1MBHS001 ----------
MBH40CP401 FO Seal Air Test Point for Pressure Inlet Cooler P [0-25bar] S1MBHS003 ----------
MBH40CP402 FO Seal Air Test Point for Pressure Outlet Cooler P [0-25bar] S1MBHS003 ----------
RTD2
MBH40CT101A FO Seal Air Temperature Outlet Cooler PT100 Ohm
[0-600°C] [0-600] D,AL,BL GTCMPS S1MBHS003 MBY02GF001
RTD2
D MBH40CT101B FO Seal Air Temperature Outlet Cooler PT100 Ohm
[0-600°C] [0-600] D,AL,BL S1MBHS003 MBY02GF001
RTD2
RTD2
RTD2
RTD2
MBH40CT404 FO Seal Air Temperature Inlet Cooler T [0-600°C] S1MBHS003 ----------
GTCMPS C MBK21AU001-S11 Turning Gear Limit Switch Pinion Down Engaged PRSW [-] ENGAGED DC 24 S GTCMPS T1MAVS001 MBY45GF001
GTCMPS C MBK21AU001-S21 Turning Gear Limit Switch Pinion Disengaged PRSW [-] DISENGAGED DC 24 S,BL GTCMPS T1MAVS001 MBY45GF001
C MBK22CS101 Turning Gear Speed Probes Pinion SSE [0,5-25000Hz] [0,5-25000] DC 24 S GTCMPS T1MAVS001 MBY45GF001
C MBK22CS102 Turning Gear Speed Probes Pinion SSE [0,5-25000Hz] [0,5-25000] DC 24 S GTCMPS T1MAVS001 MBY45GF001
MBL10CM101 Gas Turbine Inlet Air Filtration System Ambient Humidity QSE [0÷100% UR] [0÷100%] 4÷20 mA DC 24 D,CTR GTCMPS S1MBLS001 MBL10GH003
B MBL10CM102 Gas Turbine Inlet Air Filtration System Ambient Humidity QSE [0÷100% UR] [0÷100%] 4÷20 mA DC 24 D,CTR GTCMPS S1MBLS001 MBL10GH003
Gas Turbine Inlet Air Filtration System - Differential Pressure Filters (dirty
B MBL10CP001 DPSW [0÷2000Pa] 1550 Pa ↑ DC 24 D,AL,BL GTCMPS S1MBLS001 MBL10GH003
filter alarm switch high-high)
B MBL10CP002 DPSW [0÷2000Pa] 1550 Pa ↑ DC 24 D,AL,BL GTCMPS S1MBLS001 MBL10GH003
Gas Turbine Inlet Air Filtration System - Air Pressure from Auxiliary
B MBL10CP003-S01 PSW [0,5÷8bar] 4,5 bar ↓ DC 24 D,AL,BL GTCMPS S1MBLS001 MBL10GH003
Compressor Downstream Filter/Regulator (alarm low)
B MBL10CP003-S02 PSW [0,5÷8bar] 7,5 bar ↑ DC 24 D,AL,BL GTCMPS S1MBLS001 MBL10GH003
Compressor Downstream Filter/Regulator (alarm high)
B MBL10CP005 PSW [0,5÷8bar] 4 bar ↓ DC 24 D,AL,BL GTCMPS S1MBLS001 MBL10GH003
Compressor (alarm low)
MBL10CP101 Gas Turbine Inlet Air Filtration System Ambient Pressure PSE [0÷1030mbar] [0÷1030mbar] 4÷20 mA DC 24 D GTCMPS S1MBLS001 MBL10GH003
B MBL10CP102 Gas Turbine Inlet Air Filtration System - Differential Pressure Filters DPSE [0-2000Pa] [0÷2000Pa] 4÷20 mA DC 24 D,AL GTCMPS S1MBLS001 MBL10GH003
Gas Turbine Inlet Air Filtration System - Differential Pressure Indication

MBL10CP501 DPI [0-2000Pa] S1MBLS001 ----------
Filters
Gas Turbine Inlet Air Filtration System - Air Pressure Indication from
B MBL10CP502 PI [0÷10bar] S1MBLS001 ----------
Auxiliary Compressor Downstream Filter/Regulator
MBL10CT101 Gas Turbine Inlet Air Filtration System Ambient Temperature TSE [-30÷+70°C] [-30÷+70°C] 4÷20 mA DC 24 D,CTR GTCMPS S1MBLS001 MBL10GH003
B MBL10CT102 Gas Turbine Inlet Air Filtration System Ambient Temperature TSE [-30÷+70°C] [-30÷+70°C] 4÷20 mA DC 24 D,CTR GTCMPS S1MBLS001 MBL10GH003
Sheet 15 of 30
REV.D
B MBL10CU001 Gas Turbine Inlet Air Filtration System - General Fault Alarm Digital Input DC 24 D,CTR,AL GTCMPS S1MBLS001 MBL10GH003
B MBL10CU002 Gas Turbine Inlet Air Filtration System - Pulse System Ready Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL10GH003
B MBL10CU003 Gas Turbine Inlet Air Filtration System - Pulse System Automatic Mode Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL10GH003
B MBL10CU004 Gas Turbine Inlet Air Filtration System - Pulse System Fault Digital Input DC 24 D,CTR,AL GTCMPS S1MBLS001 MBL10GH003
B MBL10CU005 Gas Turbine Inlet Air Filtration System - Pulsing in Progress Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL10GH003
B MBL10CU006 Gas Turbine Inlet Air Filtration System - Pulse System ON Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL10GH003
Gas Turbine Air Filtration System - Electrical Distribution Panel

B MBL10GH001-XB01 Digital Input DC 24 D,CTR,AL GTCMPS S1MBLS001 MBL10GH001
MBL10GH001 General Fault
Gas Turbine Air Filtration System - Electrical Distribution Panel
B MBL10GH001-XB02 Digital Input DC 24 D,CTR,AL GTCMPS S1MBLS001 MBL10GH001
MBL10GH001 Anti-Ice Anti Impl. Fault
MBL11CP001 DPSW [0÷2000Pa] 1550 Pa ↑ DC 24 D,AL,BL GTCMPS S1MBLS001 MBL10GH003
MBL11CP002 DPSW [0÷2000Pa] 1200 Pa ↑ DC 24 D,AL,BL GTCMPS S1MBLS001 MBL10GH003
filter alarm switch high)
MBL11CP101 Gas Turbine Inlet Air Filtration System - Differential Pressure Filters DPSE [0÷2000Pa] [0÷2000Pa] 4÷20 mA DC 24 D,AL,BL GTCMPS S1MBLS001 MBL10GH003
MBL11CP102 Gas Turbine Inlet Air Filtration System - Differential Pressure Filters DPSE [0-2000Pa] [0-2000Pa] 4-20 mA DC 24 D,AL GTCMPS S1MBLS001 MBL10GH003
Contact CLOSED = door CLOSED

MBL12CG001A Anti Implosion Door 1 Limit Switch POSW [-]
Contact OPEN = door OPEN
DC 24 D,BL GTCMPS S1MBLS001 MBL10GH002

MBL12CG001B Anti Implosion Door 1 Limit Switch POSW [-]

MBL12CG001C Anti Implosion Door 1 Limit Switch POSW [-]

B MBL12CG002A Anti Implosion Door 2 Limit Switch POSW [-]

B MBL12CG002B Anti Implosion Door 2 Limit Switch POSW [-]

B MBL12CG002C Anti Implosion Door 2 Limit Switch POSW [-]
Gas Turbine Inlet Air Filtration System - Limit Switch for Anti-ice Stop
MBL13AA051-S11 POSW [-] OPEN DC 24 D,CTR GTCMPS S1MBLS001 MBL10GH005
Valve
Gas Turbine Inlet Air Filtration System - Limit Switch for Anti-ice Stop
MBL13AA051-S21 POSW [-] CLOSED DC 24 D,CTR GTCMPS S1MBLS001 MBL10GH005
Valve
Gas Turbine Inlet Air Filtration System - Position for Anti-ice Control Valve
MBL13AA151-XQ01 Analog Output [0-100%] [0-100%] 4-20 mA DC 24 D,AL,BL GTCMPS S1MBLS001 MBL10GH005
(Command Signal)
Gas Turbine Inlet Air Filtration System - Position for Anti-ice Control Valve
MBL13AA151-YQ01 Analog Input [0-100%] [0-100%] 4-20 mA DC 24 D,AL,BL GTCMPS S1MBLS001 MBL10GH005
(Position Feedback)
MBL20CG001A Damper Motor Valve Limit Switch (Damper A) POSW [-] Contact CLOSED = damper CLOSED DC 24 I,S,BL GTCMPS S1MBLS001 MBL10GH004
B MBL20CG001B Damper Motor Valve Limit Switch (Damper B) POSW [-] Contact CLOSED = damper CLOSED DC 24 I,S,BL GTCMPS S1MBLS001 MBL10GH004
MBL20CG002A Damper Motor Valve Limit Switch (Damper A) POSW [-] Contact CLOSED = damper OPEN DC 24 I,S,BL GTCMPS S1MBLS001 MBL10GH004
B MBL20CG002B Damper Motor Valve Limit Switch (Damper B) POSW [-] Contact CLOSED = damper OPEN DC 24 I,S,BL GTCMPS S1MBLS001 MBL10GH004
D MBL20CG003A Damper Motor Valve Limit Switch (Damper A) POSW [-] Contact CLOSED = damper OPEN DC 24 I,S,BL GTCMPS S1MBLS001 MBL10GH004
D MBL20CG003B Damper Motor Valve Limit Switch (Damper B) POSW [-] Contact CLOSED = damper OPEN DC 24 I,S,BL GTCMPS S1MBLS001 MBL10GH004
MBL20CG004A Damper Motor Valve Limit Switch (Damper A) POSW [-] Contact CLOSED = damper OPEN DC 24 I,S,BL GTCMPS S1MBLS001 MBL10GH004
B MBL20CG004B Damper Motor Valve Limit Switch (Damper B) POSW [-] Contact CLOSED = damper OPEN DC 24 I,S,BL GTCMPS S1MBLS001 MBL10GH004

MBL20CG011 Inspection Door Limit Switch Upstream Silencer POSW [-]
DC 24 I GTCMPS S1MBLS001 MBL10GH002

MBL20CG012 Inspection Door Limit Switch Upstream Expantion Joint POSW [-]

MBL20CG013 Inspection Door Limit Switch Downstream Damper POSW [-]
MBL20CP401 Gas Turbine Air Filtration System Pressure Tapping Point P [-] S1MBLS001 ----------
Sheet 16 of 30
REV.D
MBL20CT401 Gas Turbine Air Filtration System Temperature Tapping Point T [-] S1MBLS001 ----------
B MBL20CU001 Gas Turbine Inlet Air Filtration System - Electrical Fault Alarm Inlet Flap Digital Input DC 24 D,CTR,AL GTCMPS S1MBLS001 MBL20GH001
B MBL20CU002 Gas Turbine Inlet Air Filtration System - Flap Available Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL20GH001
B MBL20GH001-XB01 Damper Control Panel - Auxiliary Circuits On Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL20GH001
B MBL20GH001-XB02 Damper Control Panel - General Alarm Digital Input DC 24 D,CTR,AL GTCMPS S1MBLS001 MBL20GH001
B MBL20GH001-XB03 Damper Control Panel - Damper Running Response (Opening) Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL20GH001
B MBL20GH001-XB04 Damper Control Panel - Damper Running Response (Closing) Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL20GH001
B MBL20GH001-YB01 Damper Control Panel - Damper Open Command Digital Output DC 24 D,CTR GTCMPS S1MBLS001 MBL20GH001
B MBL20GH001-YB02 Damper Control Panel - Damper Close Command Digital Output DC 24 D,CTR GTCMPS S1MBLS001 MBL20GH001
B MBL21AP001-XB01 Pulse Jet System Panel - Fan Motor 1 Running Response Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL21GH002
B MBL21AP001-XB03 Pulse Jet System Panel - Fan Motor 1 Available Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL21GH002
B MBL21AP002-XB01 Pulse Jet System Panel - Fan Motor 2 Running Response Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL21GH002
B MBL21AP002-XB03 Pulse Jet System Panel - Fan Motor 2 Available Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL21GH002
MBL21CQ001-S01 Ice Detector, Ice Alarm Output QSW [0-5Vdc] DC 24 D,AL,BL GTCMPS S1MBLS001 MBY80GF001
MBL21CQ001-S02 Ice Detector, OK Output QSW [0-5Vdc] DC 24 S GTCMPS S1MBLS001 MBY80GF001
Ice Detector, Indication of Ice Thickness (F/U Output) (available but not
MBL21CQ101 QSE [0,2-2mm] 0,2-2mm = 4,9-6,2Vdc DC 24 D S1MBLS001 MBY80GF001
acquired from GTCMPS)
B MBL21GH001-XB01 Gas Turbine Inlet Air Filtration System - Compressor General Alarm Digital Input DC 24 D,CTR,AL GTCMPS S1MBLS001 MBL21GH001
B MBL21GH002-XB01 Pulse Jet System Panel - Cleaning Cycle Running Response Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL21GH002
B MBL21GH002-XB03 Pulse Jet System Panel - Auxiliary Circuits On Digital Input DC 24 D,CTR GTCMPS S1MBLS001 MBL21GH002
C MBL21GH002-XB05 Pulse Jet System Panel - Panel Failure (Watch Dog) Digital Input DC 24 D,CTR,AL GTCMPS S1MBLS001 MBL21GH002
C MBL21GH002-XB06 Pulse Jet System Panel - Cumulative Alarm Relay (High DP+Watchdog) Digital Input DC 24 D,CTR,AL GTCMPS S1MBLS001 MBL21GH002
B MBL21GH002-XB07 Pulse Jet System Panel - Extractor Dampers Cumulative Fault Digital Input DC 24 D,CTR,AL GTCMPS S1MBLS001 MBL21GH002
B MBL21GH002-XQ01 Pulse Jet System Panel - DP Signal to Remote Logic Analog Input [0÷2000Pa] [0÷2000Pa] 4÷20 mA DC 24 D,CTR GTCMPS S1MBLS001 MBL21GH002
B MBL21GH002-YB01 Pulse Jet System Panel - Force Cleaning Cycle (if required pulse signal) Digital Output DC 24 D,CTR GTCMPS S1MBLS001 MBL21GH002
Pulse Jet System Panel - Remote Cleaning Start Inibition (shunt if not
B MBL21GH002-YB02 Digital Output DC 24 D,CTR GTCMPS S1MBLS001 MBL21GH002
used)
B MBM10CP101 Compressor Air and Turbine First Stage Differential Pressure DPSE [50÷5000mbar] 0÷2500 mbar = 4÷20mA DC 24 D,AL GTCMPS S1MBMS001 MBY20GF001
MBM10CY101-B01 High Absolute Vibration Combustion Chamber for Pulsating Over Pressure VSE 0,001 g to 200 g peak 0÷20 g = 4÷20mA D,AL,BL GTCMPS/SAMH S1MBMS001 MBM10CY101-U01
MBM10CY101-U01 High Absolute Vibration Combustion Chamber for Pulsating Over Pressure AMPL DC 24 S1MBMS001 DIRECT
Sheet 17 of 30
REV.D
0,01 - 1 bar
D MBM11CP101-B01 Humming Detector Combustion Chamber PSE 0,00035 - 50 bar
(effective measuring range)
DC 24 D,AL,BL GTCMPS/SAMH S1MBMS001 MBM11CP101-U01
MBM11CP101-U01 Humming Detector Combustion Chamber AMPL DC 24 S1MBMS001 DIRECT
0,01 - 1 bar
D MBM11CP102-B01 Humming Detector Combustion Chamber PSE 0,00035 - 50 bar
DC 24 D,AL,BL GTCMPS/SAMH S1MBMS001 MBM11CP102-U01
MBM11CP102-U01 Humming Detector Combustion Chamber AMPL DC 24 S1MBMS001 DIRECT
0,01 - 1 bar
D MBM12CP107-B01 Humming Detector Burner PSE 0,00035 - 50 bar
DC 24 D GTCMPS/SAMH S1MBMS001 MBM12CP107-U01
MBM12CP107-U01 Humming Detector Burner AMPL DC 24 S1MBMS001 DIRECT
0,01 - 1 bar
0,01 - 1 bar
MBM12CP401 Test Point for Humming Detector Burner of the Combustion Chamber P [-] S1MBMS001 ----------
GTCMPS MBM13CR101-B02 Flame Detector (Optoelectronic Converter n.1 for Fuel Gas Function) FLDT [350-2700nm] [350-2700] DC 24 D,AL,BL TSI S1MBMS001 DIRECT
GTCMPS MBM13CR101-B03 Flame Detector (Optoelectronic Converter n.2 for Fuel Oil Function) FLDT [350-2700nm] [350-2700] DC 24 D,AL,BL TSI S1MBMS001 DIRECT
MBM13CR101-U01 Flame Detector (Sensor Head) FLSE DC 24 S1MBMS001 MBM13CR101-B02/B03
Sheet 18 of 30
REV.D
GTCMPS MBM13CR102-B02 Flame Detector (Optoelectronic Converter n.1 for Fuel Gas Function) FLDT [350-2700nm] [350-2700] DC 24 D,AL,BL TSI S1MBMS001 DIRECT
GTCMPS MBM13CR102-B03 Flame Detector (Optoelectronic Converter n.2 for Fuel Oil Function) FLDT [350-2700nm] [350-2700] DC 24 D,AL,BL TSI S1MBMS001 DIRECT
MBM13CR102-U01 Flame Detector (Sensor Head) FLSE DC 24 S1MBMS001 MBM13CR102-B02/B03
MBN11CF501 Fuel Oil Flow Indication by-pass Feed Line towards Return Line FI [-] S1MBNS001 ----------
MBN11CP001 Fuel Oil Differential Pressure for Filter Feed Line DPSW [0.05-1.2bar] 0.6 ↑ DC 24 AL GTCMPS S1MBNS001 MBY07GF001
MBN11CP401 Test Point for Pressure Fuel Oil Feed Line Upstream Filter P [0-16bar] S1MBNS001 ----------
MBN11CP501 Fuel Oil Differential Pressure Indication for Filter Feed Line DPI [0-1bar] S1MBNS001 ----------
MBN11CT501 Fuel Oil Temperature Indication Feed Line Upstream Filter TI [0-100°C] S1MBNS001 ----------
MBN12AA402-S11 Limit Switch for Intercepting Valve Upstream Fuel Oil Injection Pump POSW [-] OPEN D,AL,BL GTCMPS S1MBNS001 MBY06GF001
MBN12CP101 Fuel Oil Pressure Feed Line Upstream Injection Pump PSE [0.16-16bar] [0.16÷16] = 4÷20mA DC 24 D,AL,BL GTCMPS S1MBNS001 MBY07GF001
MBN12CP501 Fuel Oil Pressure Indication Feed Line Upstream Injection Pump PI [0-10bar] S1MBNS001 ----------
MBN12CP502 Fuel Oil Pressure Indication Feed Line Downstream Injection Pump PI [0-160bar] S1MBNS001 ----------
RTD2 100°C (alarm)

MBN12CT101A Fuel Oil Injection Pump Bearing Temperature PT100 Ohm
[-20 +150°C] / PT100
110°C (stop)
D,AL,BL GTCMPS S1MBNS001 MBY06GF001
RTD2 100°C (alarm)

MBN12CT101B Fuel Oil Injection Pump Bearing Temperature PT100 Ohm
[-20 +150°C] / PT100
110°C (stop)
RTD2 100°C (alarm)

MBN12CT102A Fuel Oil Injection Pump Bearing Temperature PT100 Ohm
[-20 +150°C] / PT100
110°C (stop)
RTD2 100°C (alarm)

MBN12CT102B Fuel Oil Injection Pump Bearing Temperature PT100 Ohm
[-20 +150°C] / PT100
110°C (stop)
RTD1 145°C (alarm) Motor Junction Box

MBN12CT105 Fuel Oil Injection Pump, Motor Winding Temperature Phase U PT100 Ohm
[0-160°C] / PT100
155°C (stop)
D,AL,BL GTCMPS S1MBNS001
MBN12AP001-X01
MBN12CT106 Fuel Oil Injection Pump, Motor Winding Temperature Phase V PT100 Ohm
[0-160°C] / PT100
155°C (stop)
MBN12AP001-X01
MBN12CT107 Fuel Oil Injection Pump, Motor Winding Temperature Phase W PT100 Ohm
[0-160°C] / PT100
155°C (stop)
MBN12AP001-X01
MBN12CT108 Fuel Oil Injection Pump, Motor Winding Temperature Phase W PT100 Ohm
[0-160°C] / PT100
155°C (stop)
MBN12AP001-X01
MBN12CT109 Fuel Oil Injection Pump, Motor Winding Temperature Phase U PT100 Ohm
[0-160°C] / PT100
155°C (stop)
MBN12AP001-X01
MBN12CT110 Fuel Oil Injection Pump, Motor Winding Temperature Phase V PT100 Ohm
[0-160°C] / PT100
155°C (stop)
MBN12AP001-X01
MBN13CP101 Fuel Oil Pressure Feed Line Downstream Injection Pump PSEI [1.6-160bar] [1.6÷160] = 4÷20mA DC 24 D,AL,BL GTCMPS S1MBNS001 MBY07GF001
MBN13CP102 Fuel Oil Pressure Feed Line Downstream Injection Pump PSEI [1.6-160bar] [1.6÷160] = 4÷20mA DC 24 D,AL,BL GTCMPS S1MBNS001 MBY07GF001
C MBN13CP103 Fuel Oil Pressure Feed Line Downstream Injection Pump (Available) PSEI [1.6-160bar] [1.6÷160] = 4÷20mA DC 24 D,AL,BL S1MBNS001 MBY07GF001
GTCMPS MBN14AA051-S11 Limit Switch Fuel Oil Valve Diffusion Feed Line (ESV) PRSW [-] OPEN DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
GTCMPS MBN14AA051-S21 Limit Switch Fuel Oil Valve Diffusion Feed Line (ESV) PRSW [-] CLOSED DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
MBN14AA151-B01 Position Fuel Oil Valve Diffusion Feed Line (CV) POSE [0-75mm] 0-100% = 20-4mA DC 24 D,AL,CTR,BL GTCMPS S1MBNS001 MBY08GF001
Sheet 19 of 30
REV.D
MBN14AA151-B02 Position Fuel Oil Valve Diffusion Feed Line (CV) POSE [0-75mm] 0-100% = 20-4mA DC 24 D,AL,CTR,BL GTCMPS S1MBNS001 MBY08GF001
MBN14AA401-S11 Limit Switch Fuel Oil Manual Valve for Drain Diffusion Feed Line POSW [-] OPEN DC 24 D,AL GTCMPS S1MBNS001 MBY07GF001
GTCMPS MBN14AA501-S21 Limit Switch Fuel Oil Shut-off Valve for Drain Diffusion Feed Line PRSW [-] CLOSED DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
GTCMPS MBN14AA501-S22 Limit Switch Fuel Oil Shut-off Valve for Drain Diffusion Feed Line PRSW [-] CLOSED DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
MBN14CP101 Fuel Oil Pressure Diffusion Feed Line Downstream CV PSEI [1.6-160bar] [1.6÷160] = 4÷20mA DC 24 D,AL,BL GTCMPS S1MBNS001 MBY07GF001
MBN17CF101 Fuel Oil Flow Diffusion Feed Line FSE [100-2000l/min] 100-2000 = 4-20mA DC 24 D GTCMPS S1MBNS001 MBY07GF001
MBN17CT101A Fuel Oil Temperature Diffusion Feed Line RTD2 [0-150°C] / PT100 [0-150°C] D GTCMPS S1MBNS001 MBY07GF001
MBN17CT101B Fuel Oil Temperature Diffusion Feed Line RTD2 [0-150°C] / PT100 [0-150°C] D GTCMPS S1MBNS001 MBY07GF001
GTCMPS MBN23AA051-S11 Limit Switch Fuel Oil Valve Premix Line (ESV) PRSW [-] OPEN DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
GTCMPS MBN23AA051-S21 Limit Switch Fuel Oil Valve Premix Line (ESV) PRSW [-] CLOSED DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
MBN23AA151-B01 Position Fuel Oil Valve Premix Line (CV) POSE [0-75mm] 0-100% = 20-4mA DC 24 D,AL,CTR,BL GTCMPS S1MBNS001 MBY08GF001
MBN23AA151-B02 Position Fuel Oil Valve Premix Line (CV) POSE [0-75mm] 0-100% = 20-4mA DC 24 D,AL,CTR,BL GTCMPS S1MBNS001 MBY08GF001
MBN23AA401-S11 Limit Switch Fuel Oil Manual Valve for Drain Premix Line POSW [-] OPEN DC 24 D,AL GTCMPS S1MBNS001 MBY07GF001
GTCMPS MBN23AA501-S21 Limit Switch Fuel Oil Shut-off Valve for Drain Premix Line PRSW [-] CLOSED DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
GTCMPS MBN23AA501-S22 Limit Switch Fuel Oil Shut-off Valve for Drain Premix Line PRSW [-] CLOSED DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
MBN23CP101 Fuel Oil Pressure Premix Line Downstream CV PSEI [1.6-160bar] [1.6÷160] = 4÷20mA DC 24 D,AL,BL GTCMPS S1MBNS001 MBY07GF001
MBN25CF101 Fuel Oil Flow Premix Line FSE [100-2000l/min] 100-2000 = 4-20mA DC 24 D GTCMPS S1MBNS001 MBY07GF001
MBN25CT101A Fuel Oil Temperature Premix Line RTD2 [0-150°C] / PT100 [0-150°C] D GTCMPS S1MBNS001 MBY07GF001
MBN25CT101B Fuel Oil Temperature Premix Line RTD2 [0-150°C] / PT100 [0-150°C] D GTCMPS S1MBNS001 MBY07GF001
B MBN31CP101 Fuel Oil Differential Pressure for Filter Diffusion Feed Line DPSEI [50-5000mbar] [0÷3000] = 4÷20mA DC 24 D,AL GTCMPS S1MBNS001 MBY39GF001
MBN34AA001-S11 Seal Air Ball Cock Fuel Oil Diffusion Feed Line Limit Switch POSW [-] OPEN DC 24 D,AL,BL Local Positioner S1MBNS001 DIRECT
MBN34AA001-S21 Seal Air Ball Cock Fuel Oil Diffusion Feed Line Limit Switch POSW [-] CLOSED DC 24 D,AL,BL Local Positioner S1MBNS001 DIRECT
Sheet 20 of 30
REV.D
MBN34AA001-S41 Seal Air Ball Cock Fuel Oil Diffusion Feed Line TSW [-] DC 24 D,AL,BL Local Positioner S1MBNS001 DIRECT
MBN34AA001-S81 Seal Air Ball Cock Fuel Oil Diffusion Feed Line FOSW [-] DC 24 D,AL,BL Local Positioner S1MBNS001 DIRECT
MBN34AA001-S91 Seal Air Ball Cock Fuel Oil Diffusion Feed Line FOSW [-] DC 24 D,AL,BL Local Positioner S1MBNS001 DIRECT
Seal Air Ball Cock Fuel Oil Diffusion Feed Line (Position switch for valve
MBN34AA001-XG01 Digital Input DC 24 GTCMPS S1MBNS001 MBN34AA001-A01
open)
closed)
MBN34AA001-XG03 Seal Air Ball Cock Fuel Oil Diffusion Feed Line (Remote -Automode-) Digital Input DC 24 GTCMPS S1MBNS001 MBN34AA001-A01
MBN34AA001-XG04 Seal Air Ball Cock Fuel Oil Diffusion Feed Line (Available) Digital Input DC 24 GTCMPS S1MBNS001 MBN34AA001-A01
open)
closed)
not open)
not closed)
MBN34AA001-XG53 Seal Air Ball Cock Fuel Oil Diffusion Feed Line (Local) Digital Input DC 24 GTCMPS S1MBNS001 MBN34AA001-A01
MBN34AA001-XG54 Seal Air Ball Cock Fuel Oil Diffusion Feed Line (Collective fault signal) Digital Input DC 24 GTCMPS S1MBNS001 MBN34AA001-A01
not open)
not closed)
GTCMPS MBN34AA002-S11 Limit Switch for Leakage Oil Solenoid Valve Diffusion Feed Line PRSW [-] OPEN DC 24 D,AL,BL GTCMPS S1MBNS001 MBY07GF001
MBN34CF501 Fuel Oil Flow for Leakage Motor Ball Valve Diffusion Feed Line FI [-] S1MBNS001 ----------
MBN34CP001 Fuel Oil Pressure for Leakage Diffusion Feed Line PSW [0,5÷4bar] 1,5 bar ↑ -0,5 DC 24 D,AL,BL GTCMPS S1MBNS001 MBY39GF001
B MBN41CP101 Fuel Oil Differential Pressure for Filter Premix Line DPSEI [50-5000mbar] [0÷3000] = 4÷20mA DC 24 D,AL GTCMPS S1MBNS001 MBY39GF001
MBN44AA001-S11 Seal Air Ball Cock Fuel Oil Premix Line Limit Switch POSW [-] OPEN DC 24 D,AL,BL Local Positioner S1MBNS001 DIRECT
MBN44AA001-S21 Seal Air Ball Cock Fuel Oil Premix Line Limit Switch POSW [-] CLOSED DC 24 D,AL,BL Local Positioner S1MBNS001 DIRECT
MBN44AA001-S41 Seal Air Ball Cock Fuel Oil Premix Line TSW [-] DC 24 D,AL,BL Local Positioner S1MBNS001 DIRECT
Sheet 21 of 30
REV.D
MBN44AA001-S81 Seal Air Ball Cock Fuel Oil Premix Line FOSW [-] DC 24 D,AL,BL Local Positioner S1MBNS001 DIRECT
MBN44AA001-S91 Seal Air Ball Cock Fuel Oil Premix Line FOSW [-] DC 24 D,AL,BL Local Positioner S1MBNS001 DIRECT
MBN44AA001-XG01 Seal Air Ball Cock Fuel Oil Premix Line (Position switch for valve open) Digital Input DC 24 GTCMPS S1MBNS001 MBN44AA001-A01
MBN44AA001-XG02 Seal Air Ball Cock Fuel Oil Premix Line (Position switch for valve closed) Digital Input DC 24 GTCMPS S1MBNS001 MBN44AA001-A01
MBN44AA001-XG03 Seal Air Ball Cock Fuel Oil Premix Line (Remote -Automode-) Digital Input DC 24 GTCMPS S1MBNS001 MBN44AA001-A01
MBN44AA001-XG04 Seal Air Ball Cock Fuel Oil Premix Line (Available) Digital Input DC 24 GTCMPS S1MBNS001 MBN44AA001-A01
MBN44AA001-XG11 Seal Air Ball Cock Fuel Oil Premix Line (Position switch for valve open) Digital Input DC 24 GTCMPS S1MBNS001 MBN44AA001-A01
MBN44AA001-XG12 Seal Air Ball Cock Fuel Oil Premix Line (Position switch for valve closed) Digital Input DC 24 GTCMPS S1MBNS001 MBN44AA001-A01
MBN44AA001-XG51 Seal Air Ball Cock Fuel Oil Premix Line (Position switch for valve not open) Digital Input DC 24 GTCMPS S1MBNS001 MBN44AA001-A01
Seal Air Ball Cock Fuel Oil Premix Line (Position switch for valve not
closed)
MBN44AA001-XG53 Seal Air Ball Cock Fuel Oil Premix Line (Local) Digital Input DC 24 GTCMPS S1MBNS001 MBN44AA001-A01
MBN44AA001-XG54 Seal Air Ball Cock Fuel Oil Premix Line (Collective fault signal) Digital Input DC 24 GTCMPS S1MBNS001 MBN44AA001-A01
MBN44AA001-XG61 Seal Air Ball Cock Fuel Oil Premix Line (Position switch for valve not open) Digital Input DC 24 GTCMPS S1MBNS001 MBN44AA001-A01
Seal Air Ball Cock Fuel Oil Premix Line (Position switch for valve not
closed)
GTCMPS MBN44AA002-S11 Limit Switch for Leakage Oil Solenoid Valve Premix Line PRSW [-] OPEN DC 24 D,AL,BL GTCMPS S1MBNS001 MBY07GF001
MBN44CF501 Fuel Oil Flow for Leakage Motor Ball Valve Premix Line FI [-] S1MBNS001 ----------
MBN44CP001 Fuel Oil Pressure for Leakage Premix Line PSW [0,5÷4bar] 1,5 bar ↑ -0,5 DC 24 D,AL,BL GTCMPS S1MBNS001 MBY39GF001
GTCMPS D MBN45AA001-S21 Limit Switch Solenoid Valve for Drain Premix Line to Leakage Oil Tank POSW [-] CLOSED DC 24 D,BL GTCMPS S1MBNS001 MBY07GF001
GTCMPS D MBN45AA002-S21 Limit Switch Solenoid Valve for Drain Premix Line to Leakage Oil Tank POSW [-] CLOSED DC 24 D,BL GTCMPS S1MBNS001 MBY07GF001
Temperature Upstream Separator between Fuel Oil/Smoking Oil for Fuel

B MBN45CT101 TSE [0-500°C] [0-500=4÷20mA] DC 24 D GTCMPS S1MBNS001 MBY107GF001
Oil Back Purging
B MBN45CT101A Temperature Drain Premix Line to Leakage Oil Tank RTD2 [0-150°C] / PT100 [0-150°C] D GTCMPS SXMBNS001 MBY07GF001
B MBN45CT101B Temperature Drain Premix Line to Leakage Oil Tank RTD2 [0-150°C] / PT100 [0-150°C] D GTCMPS SXMBNS001 MBY07GF001
MBN51CF101 Fuel Oil Flow Return Line FSE [100-2000l/min] 100-2000 = 4-20mA DC 24 D GTCMPS S1MBNS001 MBY07GF001
MBN51CT101A Fuel Oil Temperature Return Line RTD2 [0-150°C] / PT100 [0-150°C] D GTCMPS S1MBNS001 MBY07GF001
MBN51CT101B Fuel Oil Temperature Return Line RTD2 [0-150°C] / PT100 [0-150°C] D GTCMPS S1MBNS001 MBY07GF001
GTCMPS MBN52AA051-S11 Limit Switch Fuel Oil Valve Return Line (ESV) PRSW [-] OPEN DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
GTCMPS MBN52AA051-S21 Limit Switch Fuel Oil Valve Return Line (ESV) PRSW [-] CLOSED DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
Sheet 22 of 30
REV.D
MBN52AA401-S11 Limit Switch Fuel Oil Manual Valve for Drain Return Line POSW [-] OPEN DC 24 D,AL GTCMPS S1MBNS001 MBY07GF001
GTCMPS MBN52AA501-S21 Limit Switch Fuel Oil Shut-off Valve for Drain Return Line PRSW [-] CLOSED DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
GTCMPS MBN52AA501-S22 Limit Switch Fuel Oil Shut-off Valve for Drain Return Line PRSW [-] CLOSED DC 24 D,S,I,BL GTCMPS S1MBNS001 MBY08GF001
MBN52CP101 Fuel Oil Pressure Return Line Upstream ESV PSEI [1.6-160bar] [1.6÷160] = 4÷20mA DC 24 D GTCMPS S1MBNS001 MBY07GF001
MBN53AA151-B01 Position Fuel Oil Valve Return Line (CV) POSE [0-75mm] 0-100% = 4-20mA DC 24 D,S,CTR,BL GTCMPS S1MBNS001 MBY08GF001
MBN53AA151-B02 Position Fuel Oil Valve Return Line (CV) POSE [0-75mm] 0-100% = 4-20mA DC 24 D,S,CTR,BL GTCMPS S1MBNS001 MBY08GF001
B MBN54CP101 Fuel Oil Pressure Return Line Downstream CV PSEI [0.16-16bar] [0.16÷16] = 4÷20mA DC 24 D,AL,BL GTCMPS S1MBNS001 MBY07GF001
MBN60CL001-S01 Fuel Oil Leakage Tank Level (high high alarm) LSW [0-290mm] 75 ↓ from tank top DC 24 I,S,AL,BL GTCMPS S1MBNS001 MBY07GF001
Fuel Oil Leakage Tank Level (low alarm - permissive signal for starting
MBN60CL001-S02 LSW [0-290mm] 215 ↑ from tank top DC 24 I,S,AL,BL GTCMPS S1MBNS001 MBY07GF001
pump )
MBN60CL002-S01 Fuel Oil Leakage Tank Level (high high alarm) LSW [0-290mm] 75 ↓ from tank top DC 24 I,S,AL,BL GTCMPS S1MBNS001 MBY07GF001
[L1= 70mm=100%
MBN60CL101 Fuel Oil Leakage Tank Level (Pump on, Pump off, high high level) LSE
L2= 219mm=0%]
[0%÷100%] 4÷20 mA DC 24 D,I,S,AL,BL GTCMPS S1MBNS001 MBY07GF001
MBN60CL501 Fuel Oil Leakage Tank Level Indication LI [0-400mm] S1MBNS001 ----------
GTCMPS MBN80AA002-S11 Purging Water System, Limit Switch Shut-off Valve for Filling Tank PRSW [-] OPEN DC 24 D,I,S GTCMPS S1MBNS002 MBY11GF001
MBN80CP101 Purging Water System, Pressure Tank PSE [0-0.5bar] [0-0.5] 4÷20 mA DC 24 D GTCMPS S1MBNS002 MBY11GF001
MBN80CP102 Purging Water System, Pressure Tank PSE [0-0.5bar] [0-0.5] 4÷20 mA DC 24 D GTCMPS S1MBNS002 MBY11GF001
GTCMPS MBN82AA052-S11 Purging Water System, Limit Switch Pneumatic Valve Downstream Pump PRSW [-] OPEN DC 24 D,S GTCMPS S1MBNS002 MBY11GF001
GTCMPS MBN82AA052-S12 Purging Water System, Limit Switch Pneumatic Valve Downstream Pump PRSW [-] OPEN DC 24 D,S GTCMPS S1MBNS002 MBY11GF001
GTCMPS MBN82AA052-S21 Purging Water System, Limit Switch Pneumatic Valve Downstream Pump PRSW [-] CLOSED DC 24 D,S GTCMPS S1MBNS002 MBY11GF001
GTCMPS MBN82AA053-S21 Purging Water System, Limit Switch Shut-off Valve for Drain PRSW [-] CLOSED DC 24 D,AL GTCMPS S1MBNS002 MBY11GF001
GTCMPS MBN82AA053-S22 Purging Water System, Limit Switch Shut-off Valve for Drain PRSW [-] CLOSED DC 24 D,AL GTCMPS S1MBNS002 MBY11GF001
MBN82AA151-B01 Purging Water System, Control Valve Position POSE [0-75mm] 0-100% = 20-4mA DC 24 D,AL,CTR GTCMPS S1MBNS002 MBY11GF001
MBN82AA151-B02 Purging Water System, Control Valve Position POSE [0-75mm] 0-100% = 20-4mA DC 24 D,AL,CTR GTCMPS S1MBNS002 MBY11GF001
MBN82CF101 Purging Water System, Flow Downstream Control Valve FSE [0-30m3/hr] [0-30m3/hr] 4÷20 mA DC 24 D GTCMPS S1MBNS002 MBY11GF001
MBN82CP101 Purging Water System, Pressure Downstream Pump PSE [0-100bar] [0-100] 4÷20 mA DC 24 D,AL,CTR GTCMPS S1MBNS002 MBY11GF001
MBN82CP102 Purging Water System, Pressure Downstream Pump PSE [0-100bar] [0-100] 4÷20 mA DC 24 D,AL,CTR GTCMPS S1MBNS002 MBY11GF001
D MBN82CP103 Purging Water System, Pressure Downstream Pump PSE [0-100bar] [0-100] 4÷20 mA DC 24 D,AL,CTR S1MBNS002 MBY11GF001
MBN82CP104 Purging Water System, Pressure Downstream Control Valve DPSE [0-30bar] [0-30] 4÷20 mA DC 24 D,AL,CTR GTCMPS S1MBNS002 MBY11GF001
MBN82CP105 Purging Water System, Pressure Downstream Control Valve DPSE [0-30bar] [0-30] 4÷20 mA DC 24 D,AL,CTR GTCMPS S1MBNS002 MBY11GF001
MBN82CP501 Purging Water System, Pressure Indication Downstream Pump PI [0-100bar] ---- S1MBNS002 ----------
RTD1 130°C (alarm)

MBN82CT101 Purging Water System, Pump Motor Bearing Temperature Driving End PT100 Ohm
[0-160°C] / PT100
155°C (stop)
RTD1 130°C (alarm)

MBN82CT102 Purging Water System, Pump Motor Bearing Temperature Not Driving End PT100 Ohm
[0-160°C] / PT100
155°C (stop)
Sheet 23 of 30
REV.D
Purging Water System, Limit Switch for Pneumatic Valve (FO Diffusion
GTCMPS MBN83AA051-S21 PRSW [-] CLOSED DC 24 D,S GTCMPS S1MBNS002 MBY11GF002
Feed Line)
Feed Line)
Return Line)
Return Line)
Purging Water System, Limit Switch for Pneumatic Valve (FO Feed Ring
Line Upstream Mixer)
Purging Water System, Limit Switch for Pneumatic Valve (FO Feed Ring
Line Upstream Mixer)
Purging Water System, Limit Switch for Pneumatic Valve (FO Premix Feed
Line)
Purging Water System, Limit Switch for Pneumatic Valve (FO Premix Feed
Line)
GTCMPS MBP13AA051-S11 Natural Gas Stop Valve Limit Switch Open PRSW [-] OPEN DC 24 D,S,BL GTCMPS S1MBPS001 MBY09GF001
GTCMPS MBP13AA051-S21 Natural Gas Stop Valve Limit Switch Closed PRSW [-] CLOSED DC 24 D,S,BL GTCMPS S1MBPS001 MBY09GF001
GTCMPS MBP13AA501-S21 Natural Gas Vent Solenoid Valve Limit Switch Closed PRSW [-] CLOSED DC 24 D,S,BL GTCMPS S1MBPS001 MBY09GF001
GTCMPS MBP13AA501-S22 Natural Gas Vent Solenoid Valve Limit Switch Closed PRSW [-] CLOSED DC 24 D,S,BL GTCMPS S1MBPS001 MBY09GF001
MBP13CP101 Natural Gas Upstream Stop Valve Pressure PSEI [0-63bar] [0-40] DC 24 D,AL,BL,CTR,S,I GTCMPS S1MBPS001 MBY09GF001
MBP13CP102 Natural Gas Upstream Stop Valve Pressure PSEI [0-63bar] [0-40] DC 24 D,AL,BL,CTR,S,I GTCMPS S1MBPS001 MBY09GF001
RTD2
MBP13CT101A Natural Gas Upstream Filter Temperature PT100 Ohm
[0-400°C] [0-400°C] D,AL,CTR GTCMPS S1MBPS001 MBY09GF001
RTD2
C MBP13CT101B Natural Gas Upstream Filter Temperature (Available) PT100 Ohm
[0-400°C] [0-400°C] D,AL,CTR S1MBPS001 MBY09GF001
RTD2
MBP13CT102A Natural Gas Upstream Filter Temperature PT100 Ohm
[0-400°C] [0-400°C] D,AL,CTR GTCMPS S1MBPS001 MBY09GF001
RTD2
RTD2
C MBP13CT103A Natural Gas Upstream Filter Temperature (Available) PT100 Ohm
RTD2
MBP14CP101 Natural Gas Downstream Stop Valve Pressure PSEI [0-63bar] [0-40] DC 24 D,AL,BL,CTR,S,I GTCMPS S1MBPS001 MBY09GF001
MBP22AA151-B01 Premix Gas Control Valve Position POSE [0-75mm] 0-100% = 20-4mA DC 24 D,AL,CTR,BL GTCMPS S1MBPS001 MBY09GF001
MBP22AA151-B02 Premix Gas Control Valve Position POSE [0-75mm] 0-100% = 20-4mA DC 24 D,AL,CTR,BL GTCMPS S1MBPS001 MBY09GF001
MBP22CP401 Test Point for Pressure Premix Gas Line P [0-30bar] S1MBPS001 ----------
MBP24AA151-B01 Pilot 2 Gas Control Valve Position POSE [0-75mm] 0-100% = 20-4mA DC 24 D,AL,CTR,BL GTCMPS S1MBPS001 MBY09GF001
MBP24AA151-B02 Pilot 2 Gas Control Valve Position POSE [0-75mm] 0-100% = 20-4mA DC 24 D,AL,CTR,BL GTCMPS S1MBPS001 MBY09GF001
MBP24CP401 Test Point for Pressure Pilot 2 Gas Line P [0-30bar] S1MBPS001 ----------
MBP32AH001-XT01 Heating Fuel Gas Piping - Premix Command On (Feedback) Digital Input DC 24 D,CTR GTCMPS S1MBPS001 MBY31GH001
MBP32AH001-ZV01 Heating Fuel Gas Piping - Premix Command On Digital Output DC 24 D,CTR GTCMPS S1MBPS001 MBY31GH001
MBP32AH001-ZV51 Heating Fuel Gas Piping - Premix Command Off Digital Output DC 24 D,CTR GTCMPS S1MBPS001 MBY31GH001
Sheet 24 of 30
REV.D
B MBP32CP101 Pressure Premix Header PSEI [0.63-63bar] [0-40bar] 4÷20 mA DC 24 D,AL GTCMPS S1MBPS001 MBY39GF001
MBP32CP402 Test Point for Pressure Premix Header P [0-30bar] S1MBPS001 ----------
RTD1
D MBP32CT101 Temperature Pipe Premix Gas Line (Sensor for Controlling) PT100 Ohm
PT 100 OHM ------------------- ----- CTR LOCAL CONTROL BOX S1MBPS001 MBY31GH001:X2
RTD1
D MBP32CT102 Temperature Pipe Premix Gas Line (Sensor for Limiting) PT100 Ohm
MBP34AH001-XT01 Heating Fuel Gas Piping - Pilot 2 Command On (Feedback) Digital Input DC 24 D,CTR GTCMPS S1MBPS001 MBY31GH001
MBP34AH001-ZV01 Heating Fuel Gas Piping - Pilot 2 Command On Digital Output DC 24 D,CTR GTCMPS S1MBPS001 MBY31GH001
MBP34AH001-ZV51 Heating Fuel Gas Piping - Pilot 2 Command Off Digital Output DC 24 D,CTR GTCMPS S1MBPS001 MBY31GH001
MBP34CF101 Flow Gas Pilot 2 FSE [0-1.9] DC 24 D GTCMPS S1MBPS001 DIRECT
B MBP34CP101 Pressure Pilot 2 Header PSEI [0.63-63bar] [0-40bar] 4÷20 mA DC 24 D,AL GTCMPS S1MBPS001 MBY39GF001
Differential Pressure Transmitter for the Calculation of the Pilot 2 Line Gas ENERGY FLOW PC
D MBP34CP110 DPSE [0-500mbar] [0-500mbar] DC 24 S1MBPS001
Flow for MBP34CF101
ENERGY FLOW PC
D MBP34CP111 Pressure Transmitter for the Calculation of the Pilot 2 Line Gas Flow PSE [0-40bar] [0-40bar] DC 24 S1MBPS001
for MBP34CF101
MBP34CP402 Test Point for Pressure Pilot 2 Header P [0-30bar] S1MBPS001 ----------
RTD1
D MBP34CT101 Temperature Pipe Pilot 2 Line (Sensor for Controlling) PT100 Ohm
RTD1
D MBP34CT102 Temperature Pipe Pilot 2 Line (Sensor for Limiting) PT100 Ohm
RTD1 ENERGY FLOW PC

D MBP34CT110 Temperature for the Calculation of the Pilot 2 Line Gas Flow PT100 Ohm
[-50-400°C] [-50-250°C] DC 24 S1MBPS001
for MBP34CF101
GTCMPS MBQ11AA001-S11 Limit Switch for Ignition Gas Valve 1 (Fully Open) PRSW [-] OPEN DC 24 D,I,S GTCMPS S1MBQS001 MBY13GF001
GTCMPS MBQ12AA501-S21 Limit Switch for Ignition Gas Vent Valve (Fully Closed) PRSW [-] CLOSED DC 24 D,I,S GTCMPS S1MBQS001 MBY12GF001
GTCMPS MBQ12AA501-S22 Limit Switch for Ignition Gas Vent Valve (Fully Closed) PRSW [-] CLOSED DC 24 D,I,S GTCMPS S1MBQS001 MBY12GF001
Pressure Indication Upstream Solenoid Valve for Ignition Gas to Fuel Gas
MBQ12CP501 PI [0-25bar] ---- S1MBQS001 ----------
Diffusion Line
MBQ13CP101 Pressure Downstream Solenoid Valve for Ignition Gas to Pilot Line PSE [0-5000mbar] [0-5000mbar] 4÷20 mA DC 24 D,AL GTCMPS S1MBQS001 MBY12GF001
MBR20CP101 Exhaust Gas Differential Pressure DPSE [0-250mbar] DC 24 D,AL,BL GTCMPS S1MBRS001 MBY55GF001
MBR20CP401 Test Point for Pressure Exhaust Gas Diffuser P [-] S1MBRS001 ----------
TC1
MBR20CT101 Exhaust Gas Diffuser Temperature NiCr-Ni type K
0÷800°C 0720°C D,CTR,AL GTCMPS S1MBRS001 MBY55GF001
TC1
TC1
TC1
Sheet 25 of 30
REV.D
TC1
TC1
B MBX01CL001-S01 Hydraulic Oil Tank Very Low Level LSW [0-500mm] > 380 from tank top DC 24 I,BL GTCMPS S1MBXS001 MBY10GF001
B MBX01CL002-S01 Hydraulic Oil Tank Low Level LSW [0-500mm] > 290 from tank top DC 24 I,AL GTCMPS S1MBXS001 MBY10GF001
B MBX01CL002-S02 Hydraulic Oil Tank Very Low Level LSW [0-500mm] > 380 from tank top DC 24 I,BL GTCMPS S1MBXS001 MBY10GF001
Setting:
B MBX01CL101 Hydraulic Oil Tank Level LSE [0-500mm] [0÷500mm] 4÷20 mA DC 24 D,I,AL,BL GTCMPS S1MBXS001 MBY10GF001 L.HYD-02 : 290mm (LL)
L.HYD.04 : 380mm (VLL)
MBX01CL501 Hydraulic Oil Tank Level Indication LI [-] ---- S1MBXS001 ----------
RTD2
MBX01CT101A Hydraulic Oil Tank Temperature PT100 Ohm
[-200-600°C] [20-65°C] D GTCMPS S1MBXS001 MBY10GF001
RTD2
MBX01CT101B Hydraulic Oil Tank Temperature PT100 Ohm
[-200-600°C] [20-65°C] D GTCMPS S1MBXS001 MBY10GF001
MBX01CT501 Hydraulic Oil Tank Temperature Indication TI [0-120°C] ---- S1MBXS001 ----------
MBX03CP001 Hydraulic Oil Differential Pressure for Filter Main Line DPSW 5↑ DC 24 D,AL GTCMPS S1MBXS001 MBY10GF001
MBX03CP002 Hydraulic Oil Differential Pressure for Filter Auxiliary Line DPSW 5↑ DC 24 D,AL GTCMPS S1MBXS001 MBY10GF001
125 ↓
MBX03CP005 Hydraulic Oil Pressure for Supply Line to Actuators Downstream Filter PSW [0-250bar]
145 ↑
DC 24 I,AL,BL GTCMPS S1MBXS001 MBY10GF001
100 ↓
MBX03CP006 Hydraulic Oil Pressure for Supply Line to Actuators Downstream Filter PSW [0-250bar]
125 ↑
DC 24 I,AL,BL GTCMPS S1MBXS001 MBY10GF001
MBX03CP101 Hydraulic Oil Pressure for Supply Line to Actuators Downstream Filter PSE [0-300bar] [0-300] 4÷20mA DC 24 D,I,AL,BL GTCMPS S1MBXS001 MBY10GF001
[max working pressure

MBX03CP401 Test Point for Pressure Hydraulic Oil of Main Delivery Line Upstream Filter P
630bar]
S1MBXS001 ----------
Test Point for Pressure Hydraulic Oil of Main Delivery Line Downstream [max working pressure
MBX03CP402 P S1MBXS001 ----------
Filter 630bar]
Test Point for Pressure Hydraulic Oil of Auxiliary Delivery Line Upstream [max working pressure
MBX03CP403 P S1MBXS001 ----------
Filter 630bar]
Test Point for Pressure Hydraulic Oil of Auxiliary Delivery Line Downstream [max working pressure
MBX03CP404 P S1MBXS001 ----------
Filter 630bar]
Test Point for Pressure Hydraulic Oil of Main Delivery Line Downstream [max working pressure
MBX03CP405 P S1MBXS001 ----------
Pump 630bar]
Test Point for Pressure Hydraulic Oil of Auxiliary Delivery Line Downstream [max working pressure
MBX03CP406 P S1MBXS001 ----------
Pump 630bar]
Test Point for Pressure Hydraulic Oil of Supply Line to Actuators [max working pressure
MBX03CP407 P S1MBXS001 ----------
Downstream Filter 630bar]
MBX03CP501 Hydraulic Oil Pressure Indication of Main Delivery Line Downstream Pump PI [0-250bar] S1MBXS001 ----------
Hydraulic Oil Pressure Indication of Auxiliary Delivery Line Downstream

MBX03CP502 PI [0-250bar] S1MBXS001 ----------
Pump
Hydraulic Oil Pressure Indication for Supply Line to Actuators Downstream
Filter
Analyzer of degree contamination of hydraulic oil (value of the purity of the
B MBX03CQ001-S01 QSW ISO4406 >= 18/15/12 DC 24 D,AL GTCMPS S1MBXS001 MBY10GF001
oil)
Analyzer of degree contamination of hydraulic oil (value of the humidity of
B MBX03CQ001-S02 QSW >=65% RH DC 24 D,AL GTCMPS S1MBXS001 MBY10GF001
the oil)
Analyzer of degree contamination of hydraulic oil (push button for remote
B MBX03GS001 Digital Input DC 24 GTCMPS S1MBXS001 MBY10GF001
request of hydraulic oil analysis)
Test Point for Pressure Hydraulic Oil of Accumulator (Supply Line for Valve [max working pressure
MBX04CP401 P S1MBXS001 ----------
Actuators) 630bar]
Test Point for Pressure Hydraulic Oil of Accumulator (Supply Line for Valve [max working pressure
MBX04CP402 P S1MBXS001 ----------
Actuators) 630bar]
MBX04CP404 Test Point for Pressure Hydraulic Oil Supply Line to IGV P
630bar]
S1MBXS001 ----------
Hydraulic Oil Pressure Indication for Accumulator (Supply Line for Valve
Actuators)
Hydraulic Oil Pressure Indication for Accumulator (Supply Line for Valve
Actuators)
MBX06CP001 Hydraulic Oil Pressure Upstream Air Cooler PSW [0-1bar] 0,7 ↓ DC 24 D,AL GTCMPS S1MBXS001 MBY10GF001
Sheet 26 of 30
REV.D

MBX06CP401 Test Point for Pressure Hydraulic Oil Upstream Air Cooler P
630bar]
S1MBXS001 ----------

MBX06CP402 Test Point for Pressure Hydraulic Oil Delivery Recirculating Pump P
630bar]
S1MBXS001 ----------
MBX06CP501 Hydraulic Oil Pressure Indication Upstream Air Cooler PI [0-6bar] S1MBXS001 ----------

MBX07CP401 Test Point for Pressure Hydraulic Oil of Accumulator (Supply Line for IGV) P
630bar]
S1MBXS001 ----------
MBX07CP501 Hydraulic Oil Pressure Indication for Accumulator (Supply Line for IGV) PI [0-250bar] S1MBXS001 ----------
MBX08CP001 Hydraulic Oil Pressure for Clogged Filter (Contaminations Indication) DPSW 1,5 ↑ DC 24 D,AL GTCMPS S1MBXS001 MBY10GF001

MBX08CP401 Test Point for Pressure Hydraulic Oil Upstream Filter Recirculating Line P
630bar]
S1MBXS001 ----------

MBX09CP401 Test Point for Pressure Hydraulic Oil of Accumulator (Supply Line for CV1) P
630bar]
S1MBXS001 ----------

MBX09CP404 Test Point for Pressure Hydraulic Oil Supply Line to CV1 P
630bar]
S1MBXS001 ----------
MBX09CP501 Hydraulic Oil Pressure Indication for Accumulator (Supply Line for CV1) PI [0-250bar] S1MBXS001 ----------
Contact CLOSED P <= 8,2 bar

MBX21CP001 Safety Pressure Switch Downstream Air Compressor 1 PSW [0-10bar]
Contact OPEN P > 9,5 bar
DC 24 I,AL LOCAL CONTROL BOX S1MBXS002 MBX21GH001
Contact CLOSED P <= 8,2 bar

MBX22CP001 Safety Pressure Switch Downstream Air Compressor 2 PSW [0-10bar]
Contact OPEN P > 9,5 bar
DC 24 I,AL LOCAL CONTROL BOX S1MBXS002 MBX22GH001
MBX24CP001 Pressure for Air Compressor Tank PSW [0-10bar] 5,2 ↓ DC 24 D,AL,BL GTCMPS S1MBXS002 MBY40GH001
MBX24CP004 Pressure for Air Compressor Tank PSW [0-10bar] 7,7 ↑ DC 24 D,AL GTCMPS S1MBXS002 MBY40GH001
Regulator/Sequencer for Operation Air Compressor Master or Air 6,8 ↓ 7,5 ↑ (master)
D MBX24CP101 PSE [0-10bar] DC 24 CTR LOCAL CONTROL BOX S1MBXS002 MBY40GH001
Compressor Slave with Pressure Indication 6,5 ↓ 7,5 ↑ (slave)
MBX24CP501 Pressure Indication for Air Compressor Tank PI [0-16bar] ---- S1MBXS002 ----------
Pressure Hydraulic Oil for Position Check of Solenoid Valve 1 for IGV
MBX30CP001 PSW 100bar ↑ DC 24 AL GTCMPS S1MBXS005 MBY38GF001
Actuator
Pressure Hydraulic Oil for Position Check of Solenoid Valve 2 for IGV
Actuator
MBX30CP003 Hydraulic Oil Differential Pressure for Filter Clogging IGV Actuator DPSW 8bar ↑ DC 24 AL GTCMPS S1MBXS005 MBY38GF001
MBX30CP401 Test Point for Pressure Hydraulic Oil Delivery Line for IGV Actuator P [0-250bar] S1MBXS005 ----------
MBX30CP402 Test Point for Pressure Hydraulic Oil for Lower Part Cylinder IGV P [0-250bar] S1MBXS005 ----------
MBX30CP403 Test Point for Pressure Hydraulic Oil for Upper Part Cylinder IGV P [0-250bar] S1MBXS005 ----------
MBX30CP404 Test Point for Pressure Hydraulic Oil Discharge Line for IGV Actuator P [0-250bar] S1MBXS005 ----------
Pressure Hydraulic Oil for Position Check of Solenoid Valve 1 for CV1
Actuator
Pressure Hydraulic Oil for Position Check of Solenoid Valve 2 for CV1
Actuator
MBX40CP003 Hydraulic Oil Differential Pressure for Filter Clogging CV1 Actuator DPSW 8bar ↑ DC 24 AL GTCMPS S1MBXS005 MBY38GF001
MBX40CP401 Test Point for Pressure Hydraulic Oil Delivery Line for CV1 Actuator P [0-250bar] S1MBXS005 ----------
MBX40CP402 Test Point for Pressure Hydraulic Oil for Lower Part Cylinder CV1 P [0-250bar] S1MBXS005 ----------
MBX40CP403 Test Point for Pressure Hydraulic Oil for Upper Part Cylinder CV1 P [0-250bar] S1MBXS005 ----------
MBX40CP404 Test Point for Pressure Hydraulic Oil Discharge Line for CV1 Actuator P [0-250bar] S1MBXS005 ----------
Hydraulic Oil Differential Pressure for Filter Clogging HP Purging Water

MBX65CP001 DPSW 8bar ↑ DC 24 AL GTCMPS S1MBXS008 MBY11GF001
Control Valve Actuator
Test Point for Pressure Hydraulic Oil Delivery Line for HP Purging Water
MBX65CP401 P [0-250bar] S1MBXS008 ----------
Sheet 27 of 30
REV.D
Test Point for Pressure Hydraulic Oil for Lower Part Cylinder HP Purging
MBX65CP402 P [0-250bar] S1MBXS008 ----------
Water Control Valve
Test Point for Pressure Hydraulic Oil for Upper Part Cylinder HP Purging
MBX65CP403 P [0-250bar] S1MBXS008 ----------
Water Control Valve
Test Point for Pressure Hydraulic Oil Discharge Line for HP Purging Water
MBX65CP404 P [0-250bar] S1MBXS008 ----------
Hydraulic Oil Differential Pressure for Filter Clogging Natural Gas Stop
Valve Actuator
Test Point for Pressure Hydraulic Oil Delivery Line for Natural Gas Stop
MBX70CP401 P [0-250bar] S1MBXS003 ----------
Valve Actuator
Test Point for Pressure Hydraulic Oil for Lower Part Cylinder Natural Gas
MBX70CP402 P [0-250bar] S1MBXS003 ----------
Stop Valve
Test Point for Pressure Hydraulic Oil for Upper Part Cylinder Natural Gas
MBX70CP403 P [0-250bar] S1MBXS003 ----------
Stop Valve
Test Point for Pressure Hydraulic Oil Discharge Line for Natural Gas Stop
MBX70CP404 P [0-250bar] S1MBXS003 ----------
Valve Actuator
Hydraulic Oil Differential Pressure for Filter Clogging Fuel Oil Stop Valve
Actuator (Diffusion Feed Line)
Test Point for Pressure Hydraulic Oil Delivery Line for Fuel Oil Stop Valve
MBX75CP401 P [0-250bar] S1MBXS006 ----------
Actuator (Diffusion Feed Line)
Test Point for Pressure Hydraulic Oil for Lower Part Cylinder Fuel Oil Stop
MBX75CP402 P [0-250bar] S1MBXS006 ----------
Valve (Diffusion Feed Line)
Test Point for Pressure Hydraulic Oil for Upper Part Cylinder Fuel Oil Stop
MBX75CP403 P [0-250bar] S1MBXS006 ----------
Valve (Diffusion Feed Line)
Test Point for Pressure Hydraulic Oil Discharge Line for Fuel Oil Stop
MBX75CP404 P [0-250bar] S1MBXS006 ----------
Valve Actuator (Diffusion Feed Line)
Actuator (Premix Line)
MBX77CP401 P [0-250bar] S1MBXS006 ----------
MBX77CP402 P [0-250bar] S1MBXS006 ----------
Valve (Premix Line)
MBX77CP403 P [0-250bar] S1MBXS006 ----------
Valve (Premix Line)
Test Point for Pressure Hydraulic Oil Discharge Line for Fuel Oil Stop
MBX77CP404 P [0-250bar] S1MBXS006 ----------
Valve Actuator (Premix Line)
Actuator (Diffusion Return Line)
MBX79CP401 P [0-250bar] S1MBXS006 ----------
MBX79CP402 P [0-250bar] S1MBXS006 ----------
Valve (Diffusion Return Line)
MBX79CP403 P [0-250bar] S1MBXS006 ----------
Valve (Diffusion Return Line)
Test Point for Pressure Hydraulic Oil Discharge Line Fuel Oil Stop Valve
MBX79CP404 P [0-250bar] S1MBXS006 ----------
Hydraulic Oil Differential Pressure for Filter Clogging Premix Control Valve
Actuator
Test Point for Pressure Hydraulic Oil Delivery Line for Premix Control Valve
MBX81CP401 P [0-250bar] S1MBXS003 ----------
Actuator
Test Point for Pressure Hydraulic Oil for Lower Part Cylinder Premix
MBX81CP402 P [0-250bar] S1MBXS003 ----------
Control Valve
Test Point for Pressure Hydraulic Oil for Upper Part Cylinder Premix
MBX81CP403 P [0-250bar] S1MBXS003 ----------
Control Valve
Test Point for Pressure Hydraulic Oil Discharge Line for Premix Control
MBX81CP404 P [0-250bar] S1MBXS003 ----------
Valve Actuator
Hydraulic Oil Differential Pressure for Filter Clogging Pilot 2 Gas Control
Valve Actuator
Test Point for Pressure Hydraulic Oil Delivery Line for Pilot 2 Gas Control
MBX84CP401 P [0-250bar] S1MBXS003 ----------
Valve Actuator
Test Point for Pressure Hydraulic Oil for Lower Part Cylinder Pilot 2 Gas
MBX84CP402 P [0-250bar] S1MBXS003 ----------
Control Valve
Test Point for Pressure Hydraulic Oil for Upper Part Cylinder Pilot 2 Gas
MBX84CP403 P [0-250bar] S1MBXS003 ----------
Control Valve
Test Point for Pressure Hydraulic Oil Discharge Line for Pilot 2 Gas Control
MBX84CP404 P [0-250bar] S1MBXS003 ----------
Valve Actuator
Hydraulic Oil Differential Pressure for Filter Clogging Fuel Oil Control Valve
Sheet 28 of 30
REV.D
Test Point for Pressure Hydraulic Oil Delivery Line for Fuel Oil Control
MBX86CP401 P [0-250bar] S1MBXS006 ----------
Valve Actuator (Diffusion Return Line)
Test Point for Pressure Hydraulic Oil for Lower Part Cylinder Fuel Oil
MBX86CP402 P [0-250bar] S1MBXS006 ----------
Control Valve (Diffusion Return Line)
Test Point for Pressure Hydraulic Oil for Upper Part Cylinder Fuel Oil
MBX86CP403 P [0-250bar] S1MBXS006 ----------
Control Valve (Diffusion Return Line)
Test Point for Pressure Hydraulic Oil Discharge Line Fuel Oil Control Valve
MBX86CP404 P [0-250bar] S1MBXS006 ----------
MBX87CP401 P [0-250bar] S1MBXS006 ----------
Valve Actuator (Premix Line)
MBX87CP402 P [0-250bar] S1MBXS006 ----------
Control Valve (Premix Line)
MBX87CP403 P [0-250bar] S1MBXS006 ----------
Control Valve (Premix Line)
MBX87CP404 P [0-250bar] S1MBXS006 ----------
Actuator (Diff. Feed Line)
MBX88CP401 P [0-250bar] S1MBXS006 ----------
Valve Actuator (Diff. Feed Line)
MBX88CP402 P [0-250bar] S1MBXS006 ----------
Control Valve (Diff. Feed Line)
MBX88CP403 P [0-250bar] S1MBXS006 ----------
Control Valve (Diff. Feed Line)
MBX88CP404 P [0-250bar] S1MBXS006 ----------
Actuator (Diff. Feed Line)
Pressure Indication for Actuation Pneumatic Distributing Valve (for on/off
B MBX90CP501 PI [0-10bar] S1MBXS004 ----------
command Blow Off Valve MBA41AA051)
MBY31GH001-XB03 Heating Fuel Gas Piping - Heating Available Digital Input DC 24 D,CTR GTCMPS S1MBPS001 MBY31GH001
MBY31GH001-XT01 Heating Fuel Gas Piping - Heating Fault Circuit Total Digital Input DC 24 D,CTR,AL GTCMPS S1MBPS001 MBY31GH001
B MKD10CY101-B01 Generator Bearing Absolute Vibration Gas Turbine Side VSE 0,01 g to 400 g peak D,AL,BL vibromiter S1MBAS002 MKD10CY101-U01
B MKD10CY101-U01 Generator Bearing Absolute Vibration Gas Turbine Side AMPL [0-25mm/s] DC 24 TSI S1MBAS002 DIRECT
B MKD10CY102-B01 Generator Bearing Absolute Vibration Gas Turbine Side VSE 0,01 g to 400 g peak D,AL,BL vibromiter S1MBAS002 MKD10CY102-U01
B MKD10CY102-U01 Generator Bearing Absolute Vibration Gas Turbine Side AMPL [0-25mm/s] DC 24 TSI S1MBAS002 DIRECT
MKD10CY111-B01 Generator Bearing Relative Vibration Gas Turbine Side VSE [0.4-4.4mm] D,AL,BL vibromiter S1MBAS002 MKD10CY111-U01
MKD10CY111-U01 Generator Bearing Relative Vibration Gas Turbine Side AMPL
MKD10CY112-B01 Generator Bearing Relative Vibration Gas Turbine Side VSE [0.4-4.4mm] D,AL,BL vibromiter S1MBAS002 MKD10CY112-U01
MKD10CY112-U01 Generator Bearing Relative Vibration Gas Turbine Side AMPL
TC3
C MKD11CT001A Generator Bearing Temperature Gas Turbine Side NiCr-Ni type K
[0-150°C] [0-120] D,AL,BL GTCMPS S1MBAS002 MKA10GH001 Generator supply
TC3
C MKD11CT001B Generator Bearing Temperature Gas Turbine Side NiCr-Ni type K
TC3
C MKD11CT001C Generator Bearing Temperature Gas Turbine Side NiCr-Ni type K
B MKD20CY101-B01 Generator Bearing Absolute Vibration Collector Side VSE 0,01 g to 400 g peak D,AL,BL vibromiter S1MBAS002 MKD20CY101-U01
B MKD20CY101-U01 Generator Bearing Absolute Vibration Collector Side AMPL [0-25mm/s] DC 24 TSI S1MBAS002 DIRECT
B MKD20CY102-B01 Generator Bearing Absolute Vibration Collector Side VSE 0,01 g to 400 g peak D,AL,BL vibromiter S1MBAS002 MKD20CY102-U01
Sheet 29 of 30
REV.D
B MKD20CY102-U01 Generator Bearing Absolute Vibration Collector Side AMPL [0-25mm/s] DC 24 TSI S1MBAS002 DIRECT
MKD20CY111-B01 Generator Bearing Relative Vibration Collector Side VSE [0.4-4.4mm] D,AL,BL vibromiter S1MBAS002 MKD20CY111-U01
MKD20CY111-U01 Generator Bearing Relative Vibration Collector Side AMPL
MKD20CY112-B01 Generator Bearing Relative Vibration Collector Side VSE [0.4-4.4mm] D,AL,BL vibromiter S1MBAS002 MKD20CY112-U01
MKD20CY112-U01 Generator Bearing Relative Vibration Collector Side AMPL
TC3
C MKD21CT001A Generator Bearing Temperature Collector Side NiCr-Ni type K
TC3
C MKD21CT001B Generator Bearing Temperature Collector Side NiCr-Ni type K
TC3
C MKD21CT001C Generator Bearing Temperature Collector Side NiCr-Ni type K
Sheet 30 of 30
ELECTRICAL LOAD LIST
Page 1 of 1
ELECTRICAL LOAD LIST TGO1-0510-E00000
24.11.14
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
MAZ AEN 01 MB* EL LIS 001 F
GAS TURBINE AE94.3A

ELECTRICAL LOAD LIST

2
0

F 04/07/2017 REVISED WHERE INDICATED GALANTE ALECCI SANTOLINI CAPOTOS PESCE
PEM/GTE/GFCA PEM/GTE/GFCA PEM/GTE/GPOC ‐ TC PEM/PRE ‐ PE PEM/GTE
E 06/03/2017 REVISED WHERE INDICATED GALANTE TUO SANTOLINI CAPOTOS PESCE

PEM/GTE/GPFO PEM/GTE/GPFO PEM/GTE/GPFO ‐ TC PEM/PRE ‐ PE PEM/GTE
D 29/11/2016 REVISED WHERE INDICATED GALANTE TUO SANTOLINI CAPOTOS PESCE

PEM/GTE/GPFO PEM/GTE/GPFO PEM/GTE/GPFO ‐ TC PEM/PRE ‐ PE PEM/GTE
Doc. No.: 0558 S1MB*U003

For Construction.
Rev.: F
Document Type: ELL
Documentation
(UED) Information
Document Scope: U
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
Revision Record
PAGE B C D E F PAGE B C D E F
1 27
2 28
3 29
4 30
5 31
6 X X X X 32
7 X X X 33
8 X X X 34
9 X X 35
10 36
11 X X X 37
12 38
13 39
14 40
15 41
16 42
17 43
18 44
19 45
20
21
22
23
24
25
26
Doc. No.: 0558 S1MB*U003

Rev.: F
Document Type: ELL
Documentation
(UED) Information
Document Scope: U
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
FIELD DENOMINATION
PSD Power Supply Distribution
PLANT = supply from plant
GTCMPS = supply from control system
DESCRIPTION Equipment description
INTERFACE Type of equipment (according to “INTERFACE” field denomination)
VOLTAGE Voltage supply (1AC alternating current, 3AC 3 phase AC, DC direct current)
POWER Power Supply (nominal / absorbed) [kW]
AMPERAGE Current (under operating condition) [A]
START AMPERAGE Current at start up [A]
COS Power Factor
EFFICIENCY Electric motor performance
SPEED Motor rotation speed [rpm]
TYPE Type of use
DUTY Type of service
CLASS Order of use
P&ID N° Process drawing
JUNCTION BOX N° Terminal Board connected (or DIRECT)
Doc. No.: 0558 S1MB*U003

Rev.: F
Document Type: ELL
Documentation
(UED) Information
Document Scope: U
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
DENOMINATION OF FIELD “INTERFACE”

BRK Magnetic brake
CDC Control Device Coil
CDMO Control Device Motor
EO Electrical Output
HEAT Heater
MO Motor
OUTL Outlet (Electrical Feeder)

RES Resistor
SOV Solenoid Valve
TR Transformer
VAMO Valve Actuating Motor

M Motor Use
R Motor Valve
L Use with Local Starter
Doc. No.: 0558 S1MB*U003

Rev.: F
Document Type: ELL
Documentation
(UED) Information
Document Scope: U
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
DENOMINATION OF FIELD “DUTY”

CS Continuous Service
DS Discontinuous Service
SS Stand-by Service
IS Intermittent Service
DENOMINATION OF FIELD “CLASS”

R for the unit auxiliaries of basic importance
S for station and general service auxiliaries, which slightly affects operation of the unit
U for emergency service auxiliaries (fed by Emergency Diesel or DC system or UPS system)
Doc. No.: 0558 S1MB*U003

Rev.: F
Document Type: ELL
Documentation
(UED) Information
Document Scope: U
Language: E
MAZANDARAN (II) - CCPP GT ELECTRICAL LOAD LIST DOC.N. S1MB*U003
JOB N. 0558 CLIENT DOC. N. MAZ-AEN-01-MB*-EL-LIS-001
REV.F
Start
RN PSD Identification Description Interface Voltage Nominal Power Amperage COS Efficiency Speed Type Duty Class P&ID Junction Box
Amperage
(V) (KW) (A) (A)/In % rpm
PLANT MBA10AT001 AIR DRYER OUTL 3AC400 6,85/ ÷ 11,7 L DS S S1MBAS002 direct
- MBA18AP001-M01 COMPRESSOR WASHING WATER INJECTION PUMP MOTOR MO 3AC400 4 7,35 7.45 In (Un) 0,88 85,8 2873 M DS S S1MBAS003 MBA18GQ001
PLANT MBA18GQ001 PLUG FOR COMPRESSOR WASHING WATER INJECTION PUMP MOTOR EO 3AC400 32 - - - S1MBAS003 direct
GTCMPS MBA22AA001-Y01 VALVE FOR FUEL OIL DRAIN IN FALSE START SV 1AC230 0,073/ ÷ 0,33 - - - S1MBAS004 MBY19GF001
GTCMPS MBA22AA002-Y01 VALVE FOR FUEL OIL DRAIN IN FALSE START SV 1AC230 0,073/ ÷ 0,33 - - - S1MBAS004 MBY19GF001
PLANT MBA51AP001-E01 ROTOR DISPLACEMENT SYSTEM PUMP MOTOR HEATER HEAT 1AC230 0,1/ ÷ - - - S1MBAS005 direct
PLANT MBA51AP001-M01 ROTOR DISPLACEMENT SYSTEM PUMP MOTOR MO 3AC400 2,2/ ÷ 4,6 6.9 In (Un) 0,81 84,3 1455 M DS R S1MBAS005 direct
PLANT MBA51AP002-E01 ROTOR DISPLACEMENT SYSTEM PUMP MOTOR HEATER HEAT 1AC230 0,1/ ÷ - - - S1MBAS005 direct
PLANT MBA51AP002-M01 ROTOR DISPLACEMENT SYSTEM PUMP MOTOR MO 3AC400 2,2/ ÷ 4,6 6.9 In (Un) 0,81 84,3 1455 M SS R S1MBAS005 direct
GTCMPS MBA53AA001-Y01 ROTOR DISPLACEMENT SYSTEM SOLENOID VALVE SV DC 24 0,03/ ÷ - - - S1MBAS005 MBY15GF030
D GTCMPS MBD12GF001 COMPRESSOR MAIN THRUST BEARING LOAD CELL, FEEDER FOR AMPLIFICATION BOX OUTL DC 24 2 - - - S1MBAS002 direct
D GTCMPS MBD12GF002 COMPRESSOR REVERSE THRUST BEARING LOAD CELL, FEEDER FOR AMPLIFICATION BOX OUTL DC 24 2 - - - S1MBAS002 direct
PLANT MBH22AA101-M01 SECOND STAGE TURBINE COOLING AIR CONTROL VALVE MOTOR VAMO 3AC400 0,09/ ÷ 0,6 1,6 0,49 1400 R IS R S1MBHS001 direct
PLANT MBH22AA102-M01 SECOND STAGE TURBINE COOLING AIR CONTROL VALVE MOTOR VAMO 3AC400 0,09/ ÷ 0,6 1,6 0,49 1400 R IS R S1MBHS001 direct
PLANT MBH23AA101-M01 THIRD STAGE TURBINE COOLING AIR CONTROL VALVE MOTOR VAMO 3AC400 0,09/ ÷ 0,6 1,6 0,49 1400 R IS R S1MBHS001 direct
PLANT MBH23AA102-M01 THIRD STAGE TURBINE COOLING AIR CONTROL VALVE MOTOR VAMO 3AC400 0,09/ ÷ 0,6 1,6 0,49 1400 R IS R S1MBHS001 direct
PLANT MBH40AN001-E01 FUEL OIL SEAL AIR COOLING FAN MOTOR HEATER HEAT 1AC230 0.05/ ÷ 0,22 - - - S1MBHS003 direct
PLANT MBH40AN001-M01 FUEL OIL SEAL AIR COOLING FAN MOTOR MO 3AC400 4/ ÷ 8,01 6,95 In (Un) 0,83 90,1 2913 M CS R S1MBHS003 direct
PLANT MBH40AN002-M01 FUEL OIL SEAL AIR COOLING FAN MOTOR MO 3AC400 4/ ÷ 8,01 6,95 In (Un) 0,83 90,1 2913 M CS R S1MBHS003 direct
PLANT MBH40AN003-M01 FUEL OIL SEAL AIR COOLING FAN MOTOR MO 3AC400 4/ ÷ 8,01 6,95 In (Un) 0,83 90,1 2913 M SS R S1MBHS003 direct
C PLANT MBL10AT001 AIR INTAKE - FEEDER FOR AIR DRYER ELECTRICAL PANEL (COMPRESSOR SKID) OUTL 3AC400 2,5 L DS S S1MBLS001 direct
AIR INTAKE - FEEDER FOR INTERNAL & EXTERNAL LIGHTS, EXTERNAL HOIST, POWER
E PLANT MBL10GH001 SOCKETS, HEATING CABLES FOR BLOW-IN DOOR
OUTL 3AC400+N 10 L DS S S1MBLS001 direct
Sheet 6 of 11
REV.F
Start
Amperage
B PLANT MBL10GH001_1 AIR INTAKE - FEEDER FOR HOIST, DUST EXTRACTION FAN 1, DUST EXTRACTION FAN 2 OUTL 3AC400 7 15 94 L DS S S1MBLS001 direct
AIR INTAKE - FEEDER FOR INTERIOR & EXTERIOR LIGHTING, RECEPTACLE & PULSE JET
B PLANT MBL10GH001_2 CONTROL
OUTL 1AC230+N 5 25 43 L DS S S1MBLS001 direct
AIR INTAKE - FEEDER FOR INTERNAL & EXTERNAL LIGHTS, EXTERNAL HOIST, POWER
E PLANT MBL10GH005 SOCKETS, HEATING CABLES FOR BLOW-IN DOOR, INSTRUMENT PANEL HEATER
OUTL 3AC400+N 10 L DS S S1MBLS001 direct
B GTCMPS MBL13AA051A-Y01 AIR INTAKE - SOLENOID VALVE FOR COMMAND OF THE ANTI-ICE STOP VALVE SV DC 24 0.01/ ÷ - - - S1MBLS001 MBL10GH005
E PLANT MBL20GH001 AIR INTAKE - FEEDER FOR DAMPER ACTUATOR OUTL 3AC400 3 L DS R S1MBLS001 direct
C PLANT MBL21GH001 AIR INTAKE - FEEDER AIR COMPRESSOR ELECTRICAL PANEL (COMPRESSOR SKID) OUTL 3AC400 57,6 L DS S S1MBLS001 direct
E PLANT MBL21GH002 AIR INTAKE - FEEDER PULSE JET ELECTRICAL PANEL OUTL 3AC400 40 L DS S S1MBLS001 direct
B PLANT MBL21GH003 AIR INTAKE - FEEDER COOLER PANEL OUTL 3AC400 0,75 L DS S to be defined direct
B PLANT MBL30GH001 AIR INTAKE - FEEDER FOR COMPRESSOR & AIR COOLER OUTL 3AC400 27 37 268 L DS S to be defined direct
- MBM12GT001 IGNITION TRANSFORMER FOR SPARK PLUG (Fed Through MBY04GF001) TR 1AC230 0,2/ ÷ 1,1 1 - DS R S1MBMS001 MBY04GF002
- MBM12GT007 IGNITION TRANSFORMER FOR SPARK PLUG TR 1AC230 0,2/ ÷ 1,1 1 - DS R S1MBMS001 MBY04GF001
Sheet 7 of 11
REV.F
Start
Amperage
PLANT MBN12AP001-E01 FUEL OIL INJECTION PUMP MOTOR HEATER HEAT 1AC230 0.21 - - - S1MBNS001 direct
6 In (Un)
E PLANT MBN12AP001-M01 FUEL OIL INJECTION PUMP MOTOR MO 3AC6600 650 65,9 tolerance 0,90 95,8 2983 M CS R S1MBNS001 direct
included
GTCMPS MBN14AA501-Y01 FUEL OIL DRAIN VALVE - DIFFUSION FEED LINE SV DC 220 0,058/ ÷ - - - S1MBNS001 MBY07GF001
GTCMPS MBN23AA501-Y01 FUEL OIL DRAIN VALVE - PREMIX FEED LINE SV DC 220 0,058/ ÷ - - - S1MBNS001 MBY07GF001
PLANT MBN34AA001-M01 FUEL OIL DIFFUSION - SEAL AIR VALVE VAMO 3AC400 0,16/ ÷ 0,6 1,7 0,67 2800 R DS R S1MBNS001 direct
GTCMPS MBN34AA002-Y01 FUEL OIL DIFFUSION - DRAIN VALVE FROM SEALING AIR PIPING SV DC 220 0,048/ ÷ - - - S1MBNS001 MBY07GF001
PLANT MBN44AA001-M01 FUEL OIL PREMIX - SEAL AIR VALVE VAMO 3AC400 0,16/ ÷ 0,6 1,7 0,67 2800 R DS R S1MBNS001 direct
GTCMPS MBN44AA002-Y01 FUEL OIL PREMIX - DRAIN VALVE FROM SEALING AIR PIPING SV DC 220 0,048/ ÷ - - - S1MBNS001 MBY07GF001
GTCMPS MBN45AA001A-Y01 PILOT SOLENOID VALVE FOR FUEL OIL DRAIN VALVE 1 FROM PREMIX COLLECTOR SV DC 24 0,002/ ÷ - - - S1MBNS001 MBY07GF001
GTCMPS MBN45AA002A-Y01 PILOT SOLENOID VALVE FOR FUEL OIL DRAIN VALVE 2 FROM PREMIX COLLECTOR SV DC 24 0,002/ ÷ - - - S1MBNS001 MBY07GF001
GTCMPS MBN52AA501-Y01 FUEL OIL DRAIN VALVE - DIFFUSION RETURN LINE SV DC 220 0,058/ ÷ - - - S1MBNS001 MBY07GF001
F PLANT MBN60AP001-M01 FUEL OIL LEAKAGE PUMP MOTOR MO 3AC400 1,5/ ÷ 3,40 5,2 In (Un) 0,81 78,3 1400 M DS R S1MBNS001 direct
GTCMPS MBN80AA002-Y01 HIGH PRESSURE PURGING WATER - VALVE FOR FILLING TANK SV DC 24 0,027/ ÷ - - - S1MBNS002 MBY11GF001
HIGH PRESSURE PURGING WATER - ACTUATOR FOR PNEUMATIC VALVE DOWNSTREAM
GTCMPS MBN82AA052A-Y01 PUMP
SV DC 24 0,0025/ ÷ - - - S1MBNS002 MBY11GF001
GTCMPS MBN82AA053-Y01 HIGH PRESSURE PURGING WATER - DRAIN VALVE SKID SV DC 24 0,048/ ÷ - - - S1MBNS002 MBY11GF001
PLANT MBN82AP001-E01 HIGH PRESSURE PURGING WATER PUMP MOTOR HEATER HEAT 1AC230 0,05 - - - S1MBNS002 direct
D PLANT MBN82AP001-M01 HIGH PRESSURE PURGING WATER PUMP MOTOR MO 3AC400 160 265 7,8 In (Un) 0,92 95,6 2982 M DS R S1MBNS002 direct
GTCMPS MBN83AA051A-Y01 HIGH PRESSURE PURGING WATER - VALVE FOR FUEL OIL DIFFUSION FEED LINE SV DC 24 0,0048 - - - S1MBNS002 MBY11GF002
GTCMPS MBN83AA052A-Y01 HIGH PRESSURE PURGING WATER - VALVE FOR FUEL OIL DIFFUSION RETURN LINE SV DC 24 0,0048 - - - S1MBNS002 MBY11GF002
GTCMPS MBN84AA051A-Y01 HIGH PRESSURE PURGING WATER - VALVE FOR FUEL OIL FEED RING LINE SV DC 24 0,0048 - - - S1MBNS002 MBY11GF002
GTCMPS MBN84AA052A-Y01 HIGH PRESSURE PURGING WATER - VALVE FOR FUEL OIL PREMIX FEED LINE SV DC 24 0,0048 - - - S1MBNS002 MBY11GF002
GTCMPS MBP13AA501-Y01 FUEL GAS - VENT VALVE SKID SV DC 220 0,235/0,151 1,07 1,6 - - - S1MBPS001 MBY09GF001
F GTCMPS MBP34CF101 FUEL GAS - FEEDER FOR GAS PILOT 2 FLOWMETER OUTL DC 24 26VA - - - S1MBPS001 direct
GTCMPS MBQ11AA001-Y01 IGNITION GAS - FIRST STOP VALVE SV DC 24 0,065 - - - S1MBQS001 MBY13GF001
GTCMPS MBQ12AA501-Y01 IGNITION GAS - VENT VALVE SKID SV DC 24 0,055 - - - S1MBQS001 MBY12GF001
Sheet 8 of 11
REV.F
Start
Amperage
GTCMPS MBQ13AA001-Y01 IGNITION GAS - STOP VALVE FOR FUEL GAS DIFFUSION LINE SV DC 24 0,065 - - - S1MBQS001 MBY12GF001
E PLANT MBX01AH001 HYDRAULIC OIL TANK HEATER HEAT 3AC400 1,5 2,2 - IS S S1MBXS001 direct
PLANT MBX02AP001-E01 HYDRAULIC OIL MAIN PUMP MOTOR HEATER HEAT 1AC230 0,1/ ÷ - - - S1MBXS001 direct
E PLANT MBX02AP001-M01 HYDRAULIC OIL MAIN PUMP MOTOR MO 3AC400 11/ ÷ 23 5 In (Un) 0,77 90,3 975 M CS R S1MBXS001 direct
PLANT MBX02AP002-E01 HYDRAULIC OIL AUXILIARY PUMP MOTOR HEATER HEAT 1AC230 0,1/ ÷ - - - S1MBXS001 direct
E PLANT MBX02AP002-M01 HYDRAULIC OIL AUXILIARY PUMP MOTOR MO 3AC400 11/ ÷ 23 5 In (Un) 0,77 90,3 975 M SS R S1MBXS001 direct
D GTCMPS MBX03CQ001 FEEDER FOR ANALYZER OF DEGREE CONTAMINATION OF HYDRAULIC OIL OUTL DC 24 < 2.2 Watt 80mA - - - S1MBXS001 MBY10GF001
E PLANT MBX06AH001-M01 HYDRAULIC OIL COOLER 1 MOTOR MO 3AC400 0,55/ ÷ 1,46 3.9 In (Un) 0,81 69,4 1395 M IS S S1MBXS001 direct
E PLANT MBX06AH002-M01 HYDRAULIC OIL COOLER 1 MOTOR MO 3AC400 0,55/ ÷ 1,46 3.9 In (Un) 0,81 69,4 1395 M IS S S1MBXS001 direct
PLANT MBX21AN001 PNEUMATIC COMPRESSOR 1 MOTOR OUTL 3AC400 6,5 16 L CS R S1MBXS002 MBX21GH001
PLANT MBX22AN001 PNEUMATIC COMPRESSOR 2 MOTOR OUTL 3AC400 6,5 16 L SS R S1MBXS002 MBX22GH001
GTCMPS MBX30AA051-Y01 SOLENOID VALVE FOR ACTUATOR OF INLET GUIDE VANES SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS005 MBY38GF001
GTCMPS MBX30AA052-Y01 SOLENOID VALVE FOR ACTUATOR OF INLET GUIDE VANES SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS005 MBY38GF001
GTCMPS MBX30AA101-Y01 SERVOVALVE FOR ACTUATOR OF INLET GUIDE VANES CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS005 MBY38GF001
GTCMPS MBX30AA101-Y11 SERVOVALVE FOR ACTUATOR OF INLET GUIDE VANES CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS005 MBY38GF001
GTCMPS MBX40AA051-Y01 SOLENOID VALVE FOR ACTUATOR OF COMPRESSOR VANE 1 SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS005 MBY38GF001
GTCMPS MBX40AA052-Y01 SOLENOID VALVE FOR ACTUATOR OF COMPRESSOR VANE 1 SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS005 MBY38GF001
GTCMPS MBX40AA101-Y01 SERVOVALVE FOR ACTUATOR OF COMPRESSOR VANE 1 CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS005 MBY38GF001
GTCMPS MBX40AA101-Y11 SERVOVALVE FOR ACTUATOR OF COMPRESSOR VANE 1 CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS005 MBY38GF001
GTCMPS MBX65AA002-Y01 SOLENOID VALVE FOR ACTUATOR OF HIGH PRESSURE PURGING CONTROL VALVE SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS008 MBY11GF001
GTCMPS MBX65AA002-Y02 SOLENOID VALVE FOR ACTUATOR OF HIGH PRESSURE PURGING CONTROL VALVE SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS008 MBY11GF001
GTCMPS MBX65AA101-Y01 SERVOVALVE FOR ACTUATOR OF HIGH PRESSURE PURGING CONTROL VALVE CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS008 MBY11GF001
GTCMPS MBX65AA101-Y11 SERVOVALVE FOR ACTUATOR OF HIGH PRESSURE PURGING CONTROL VALVE CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS008 MBY11GF001
GTCMPS MBX70AA001-Y01 SOLENOID VALVE FOR ACTUATOR OF NATURAL GAS STOP VALVE SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS003 MBY09GF001
GTCMPS MBX75AA001-Y01 SOLENOID VALVE FOR ACTUATOR OF FUEL OIL STOP VALVE (fuel oil diffusion feed line) SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS006 MBY08GF001
Sheet 9 of 11
REV.F
Start
Amperage
GTCMPS MBX77AA001-Y01 SOLENOID VALVE FOR ACTUATOR OF FUEL OIL STOP VALVE (fuel oil premix line) SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS006 MBY08GF001
GTCMPS MBX79AA001-Y01 SOLENOID VALVE FOR ACTUATOR OF FUEL OIL STOP VALVE (fuel oil diffusion return line) SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS006 MBY08GF001
GTCMPS MBX81AA002-Y01 SOLENOID VALVE FOR ACTUATOR OF NATURAL GAS CONTROL VALVE (premix line) SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS003 MBY09GF001
GTCMPS MBX81AA002-Y02 SOLENOID VALVE FOR ACTUATOR OF NATURAL GAS CONTROL VALVE (premix line) SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS003 MBY09GF001
GTCMPS MBX81AA101-Y01 SERVOVALVE FOR ACTUATOR OF NATURAL GAS CONTROL VALVE (premix line) CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS003 MBY09GF001
GTCMPS MBX81AA101-Y11 SERVOVALVE FOR ACTUATOR OF NATURAL GAS CONTROL VALVE (premix line) CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS003 MBY09GF001
GTCMPS MBX84AA002-Y01 SOLENOID VALVE FOR ACTUATOR OF NATURAL GAS CONTROL VALVE (pilot 2 line) SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS003 MBY09GF001
GTCMPS MBX84AA002-Y02 SOLENOID VALVE FOR ACTUATOR OF NATURAL GAS CONTROL VALVE (pilot 2 line) SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS003 MBY09GF001
GTCMPS MBX84AA101-Y01 SERVOVALVE FOR ACTUATOR OF NATURAL GAS CONTROL VALVE (pilot 2 line) CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS003 MBY09GF001
GTCMPS MBX84AA101-Y11 SERVOVALVE FOR ACTUATOR OF NATURAL GAS CONTROL VALVE (pilot 2 line) CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS003 MBY09GF001
GTCMPS MBX86AA101-Y01 SERVOVALVE FOR ACTUATOR OF FUEL OIL CONTROL VALVE (fuel oil diffusion return line) CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS006 MBY08GF001
GTCMPS MBX86AA101-Y11 SERVOVALVE FOR ACTUATOR OF FUEL OIL CONTROL VALVE (fuel oil diffusion return line) CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS006 MBY08GF001
GTCMPS MBX87AA002-Y01 SOLENOID VALVE FOR ACTUATOR OF FUEL OIL CONTROL VALVE (fuel oil premix line) SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS006 MBY08GF001
GTCMPS MBX87AA002-Y02 SOLENOID VALVE FOR ACTUATOR OF FUEL OIL CONTROL VALVE (fuel oil premix line) SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS006 MBY08GF001
GTCMPS MBX87AA101-Y01 SERVOVALVE FOR ACTUATOR OF FUEL OIL CONTROL VALVE (fuel oil premix line) CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS006 MBY08GF001
GTCMPS MBX87AA101-Y11 SERVOVALVE FOR ACTUATOR OF FUEL OIL CONTROL VALVE (fuel oil premix line) CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS006 MBY08GF001
GTCMPS MBX88AA002-Y01 SOLENOID VALVE FOR ACTUATOR OF FUEL OIL CONTROL VALVE (fuel oil diffusion feed line) SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS006 MBY08GF001
GTCMPS MBX88AA002-Y02 SOLENOID VALVE FOR ACTUATOR OF FUEL OIL CONTROL VALVE (fuel oil diffusion feed line) SV DC 24 0,03/ ÷ 1,25 - - - S1MBXS006 MBY08GF001
GTCMPS MBX88AA101-Y01 SERVOVALVE FOR ACTUATOR OF FUEL OIL CONTROL VALVE (fuel oil diffusion feed line) CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS006 MBY08GF001
GTCMPS MBX88AA101-Y11 SERVOVALVE FOR ACTUATOR OF FUEL OIL CONTROL VALVE (fuel oil diffusion feed line) CDC DC 24 0,128W / 80 Ohm ±15mA - - - S1MBXS006 MBY08GF001
SOLENOID VALVE FOR ACTUATION PNEUMATIC DISTRIBUTING VALVE (FOR ON/OFF
GTCMPS MBX90AA002A-Y01 COMMAND BLOW OFF VALVE MBA41AA051)
SV DC 24 0,01 0,4 1 - - - S1MBXS004 MBY39GF001
Sheet 10 of 11
REV.F
Start
Amperage
GTCMPS MBX90AA002B-Y01 COMMAND BLOW OFF VALVE MBA41AA051) SV DC 24 0,01 0,4 1 - - - S1MBXS004 MBY39GF001
SV DC 24 0,01 0,4 1 - - - S1MBXS004 MBY39GF001
GTCMPS MBX91AA002B-Y01 COMMAND BLOW OFF VALVE MBA42AA051)
SV DC 24 0,01 0,4 1 - - - S1MBXS004 MBY39GF001
SV DC 24 0,01 0,4 1 - - - S1MBXS004 MBY39GF001
SV DC 24 0,01 0,4 1 - - - S1MBXS004 MBY39GF001
SV DC 24 0,01 0,4 1 - - - S1MBXS004 MBY39GF001
SV DC 24 0,01 0,4 1 - - - S1MBXS004 MBY39GF001
PLANT MBY04GF001 FEEDER FOR IGNITION TRANSFORMERS OF BURNERS OUTL 3AC400+N 3/ ÷ L DS R S1MBMS001 direct
FEEDER CONTROL CABINET FOR ELECTRICAL TRACING OF FUEL GAS PIPING (PREMIX, PILOT
PLANT MBY31GH001 1 AND PILOT 2 LINES)
OUTL 3AC400 10 17 L DS S S1MBPS001 direct
F PLANT MBY40GH001 FEEDER FOR REGULATOR/SEQUENCER PNEUMATIC COMPRESSOR SKID OUTL 1AC230+N 0,4 2 - - - S1MBXS002 direct
GTCMPS MBY80GF001 FEEDER FOR ICE DETECTOR OUTL DC 24 10mA - - - S1MBLS001 direct
Sheet 11 of 11
EQUIPMENT LIST
Page 1 of 1
EQUIPMENT LIST TGO1-0520-E00000
24.11.14
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
MAZ AEN 01 MB* ME EQL 001 B
GAS TURBINE AE94.3A

COMPONENT LIST

2
0

C
B 23/03/2017 REVISED WHERE INDICATED GALANTE ALECCI SANTOLINI CAPOTOS PESCE

A 04/08/2015 FIRST ISSUE GALANTE GATTI SANTOLINI PINCA DI PASQUALE

IPI/TGS/GPFO IPI/TGS/GPFO IPI/TGS/GPFO ‐ TC IPI/PRE ‐ PE IPI/TGS
Doc. No.: 0558 S1MB*M002

For Construction.
Rev.: B
Document Type: MPC
Documentation
(UED) Information
Document Scope: I
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
Revision Record
1 X 27 X
2 X 28 X
3 X 29
4 X 30
5 X 31
6 X 32
7 X 33
8 X 34
9 X 35
10 X X 36
11 X X 37
12 X 38
13 X X 39
14 X 40
15 X X 41
16 X X 42
17 X X 43
18 X X 44
19 X X 45
20 X
21 X
22 X X
23 X
24 X
25 X
26 X
Doc. No.: 0558 S1MB*M002

Rev.: B
Document Type: MPC
Documentation
(UED) Information
Document Scope: I
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
FIELD DENOMINATION
DESCRIPTION Equipment description
ACTUATION Type of actuation
TYPE Equipment type
P&ID No. Process drawing
DENOMINATION OF FIELD “ACTUATION”

EL Electrical actuation
HYD Hydraulic actuation
MAN Manual actuation
MED Actuation from fluid
PN Pneumatic actuation
Doc. No.: 0558 S1MB*M002

Rev.: B
Document Type: MPC
Documentation
(UED) Information
Document Scope: I
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.

ACT Actuator
BURN Burner
BV Ball Valve
CBM Coupling Bolt for Measurement (Check Valve for Tapping Point)
CC Combustion Chamber
CFR Compensated Flow Regulator
CKF Check Flap
CKV Check Valve
CLVT Clutch
COMP Compressor
COOL Cooler
COPL Control Plate (Actuator Control Unit)
CTCV Combi Transfer Check Valve (Cartridge Valve)
CTRP Centrifugal Pump
CTRV Control Valve
DAMP Damper
DEHUM Dehumidifier
ESV Emergency stop valve
EXP Expansion Joint
FAN Fan
FCV Flow control valve
FILT Filter
HEAT Heater
HYMO Hydraulic Motor
NOZ Nozzle
Doc. No.: 0558 S1MB*M002

Rev.: B
Document Type: MPC
Documentation
(UED) Information
Document Scope: I
Language: E
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE:
Serial
No.
ORF Orifice
ORFA Adjustable Flow Restrictor Orifice
PAC Pressure Accumulator
PCV Pressure Control Valve
PDP Positive Displacement Pump
PRLV Pressure Relief Valve
SDV Servo Directional Valve
SIL Silencer
SOV Shut Off Valve
SOVC Shut Off Valve, Cock Type
SOVP Shut Off Valve, Piston
STPV Stop Valve
STR Strainer
TANK Tank
TCV Temperature Control Valve
THRV Throttle Valve
TR Transformer
TRAP Trap
TRV Change over valve
TRVP Transfer Valve
VENT Ventilator
Doc. No.: 0558 S1MB*M002

Rev.: B
Document Type: MPC
Documentation
(UED) Information
Document Scope: I
Language: E
MAZANDARAN (II) - CCPP GT COMPONENT LIST AEN DOC.N. S1MB*M002
JOB N. 0558 CLIENT DOC. N. MAZ-AEN-01-MB*-ME-EQL-001
REV.B
RN Identification Description Actuation Type P & ID
MBA10AT001KT01 Air Dryer el DEHUM S1MBAS002
MBA11AA301 Instrument Valve for MBA11CP101 man SOV S1MBAS002
MBA11AS001KE01 Adjustment Turbine Blade First Stage (Inlet Guide Vanes IGV) hyd ACT S1MBAS002
MBA11AS002KE01 Adjustment Turbine Blade First Stage (Compressor Vane 1 CV1) hyd ACT S1MBAS002
MBA12AA401 Drain Valve for Measure Line man BV S1MBAS002
MBA18AA251 Intercepting Valve Upstream Compressor Cleaning Jet Nozzles man BV S1MBAS003
MBA18AA252 Intercepting Valve Upstream Compressor Cleaning Spray Nozzles man BV S1MBAS003
MBA18AA401 Drain Valve for Compressor Cleaning Tank man BV S1MBAS003
MBA18AP001KP01 Compressor Cleaning Pump el CTRP S1MBAS003
MBA18AT001 Compressor Cleaning Filter Upstream Pump FILT S1MBAS003
MBA18AT002 Compressor Cleaning Filter Upstream Nozzles FILT S1MBAS003
MBA18BB002 Compressor Cleaning Tank TANK S1MBAS003
MBA18BN001 Compressor Cleaning Jet Nozzles (No. 2) NOZ S1MBAS003
MBA18BN002 Compressor Cleaning Spray Nozzles (No. 20) NOZ S1MBAS003
MBA21AA251 Compressor Stage 0 Drain Valve man SOVC S1MBAS004
MBA21AA254 Extraction Line E1/A1 Stage 5 Drain Valve man SOVC S1MBAS004
MBA22AA001KA01 Fuel Oil Drain Valve el SOVC S1MBAS004
MBA22AA002KA01 Fuel Oil Drain Valve el SOVC S1MBAS004
Sheet 6 of 28
REV.B
MBA22AA251 Compressor Delivery Drain Valve man SOVC S1MBAS004
MBA23AA251 Turbine Stage 2 Drain Valve man SOVC S1MBAS004
MBA24AA251 Compressor Stage 5 Blow-Off Line Drain Valve man SOVC S1MBAS004
MBA24AA252 Compressor Stage 9 Blow-Off Line Drain Valve man SOVC S1MBAS004
MBA24AA253 Compressor Stage 5 Air Cooling Drain Valve man SOVC S1MBAS004
MBA25AA601 Drain Valve (Sampling for Drainage Check) man SOVC S1MBAS004
MBA25BB001 Drain Lines Header TANK S1MBAS004
MBA41AA051KA01 Blow-Off Valve Extraction Line 1.1 Stage 5 Lower Part pn DAMP S1MBAS001
MBA42AA051KA01 Blow-Off Valve Extraction Line 1.2 Stage 5 Upper Part pn DAMP S1MBAS001
MBA43AA051KA01 Blow-Off Valve Extraction Line 2 Stage 9 Lower Part pn DAMP S1MBAS001
MBA44AA051KA01 Blow-Off Valve Extraction Line 3 Stage 13 Upper Part pn DAMP S1MBAS001
MBA51AA191 Supply System RDS Safety Valve for Pump 1 med PRLV S1MBAS005
MBA51AA192 Supply System RDS Safety Valve for Pump 2 med PRLV S1MBAS005
MBA51AA193 Supply System RDS Safety Valve for Bladder Accumulator 1 med PRLV S1MBAS005
MBA51AA194 Supply System RDS Safety Valve for Bladder Accumulator 2 med PRLV S1MBAS005
MBA51AA201 Clamp Check Valve for Over Pressure Filter 1 med CKV S1MBAS005
MBA51AA202 Clamp Check Valve for Over Pressure Filter 2 med CKV S1MBAS005
MBA51AA251 Supply System RDS Isolating Valve for Pump ...AP001 man SOV S1MBAS005
MBA51AA252 Supply System RDS Isolating Valve for Pump ...AP002 man SOV S1MBAS005
MBA51AA253 Supply System RDS Isolating Valve for Filter...AT001 man SOV S1MBAS005
MBA51AA255 Supply System RDS Isolating Valve for Accumulator 1 man SOV S1MBAS005
MBA51AA256 Supply System RDS Isolating Valve for Accumulator 2 man SOV S1MBAS005
MBA51AA281 Supply System RDS Flow Control Valve for Accumulators Line man CTRV S1MBAS005
Sheet 7 of 28
REV.B
MBA51AP001KP01 Supply System RDS Pump 1 el PDP S1MBAS005
MBA51AP002KP01 Supply System RDS Pump 2 el PDP S1MBAS005
MBA51AT001 Supply System RDS Filter Downstream Pump 1 FILT S1MBAS005
MBA51AT002 Supply System RDS Filter Downstream Pump 2 FILT S1MBAS005
MBA51BB001 Supply System RDS Accumulator 1 PAC S1MBAS005
MBA51BB002 Supply System RDS Accumulator 2 PAC S1MBAS005
MBA52AT001 Supply System RDS Filter Upstream Main and Reverse Thrust Valves FILT S1MBAS005
MBA53AA001KA01 Return Line RDS Main Thrust 2-Way Seat Valve el TRVP S1MBAS005
MBA53AA002KA01 Supply Line RDS Main Thrust 2-Way Seat Valve el TRVP S1MBAS005
MBA53AA004KA01 Supply Line RDS Reverse Thrust 2-Way Seat Valve el TRVP S1MBAS005
MBA53AA005KA01 Return Line RDS Reverse Thrust 2-Way Seat Valve el TRVP S1MBAS005
MBA53AA191 Safety Valve for Supply and Return Line RDS med PRLV S1MBAS005
MBA53AA201 Clamp Check Valve for Over Pressure Filter MBA52AT001 med CKV S1MBAS005
MBA53AA281 Control Valve Supply Line RDS Main Thrust man CTRV S1MBAS005
MBA53AA282 Control Valve Supply Line RDS Reverse Thrust man CTRV S1MBAS005
MBA54AA191 Safety Valve for Supply Line RDS Main Thrust med PRLV S1MBAS005
Sheet 8 of 28
REV.B
MBA54AA192 Safety Valve for Supply Line RDS Reverse Thrust med PRLV S1MBAS005
MBA54AA201 Supply Line RDS Main Thrust Clamp Check Valve med CKV S1MBAS005
MBA54AA202 Supply Line RDS Reverse Thrust Clamp Check Valve med CKV S1MBAS005
MBA54AA281 Control Valve Return Line RDS Main Thrust man CTRV S1MBAS005
MBA54AA282 Control Valve Return Line RDS Reverse Thrust man CTRV S1MBAS005
MBH22AA101KA01 Turbine Stage 2 Inlet Air Motor Valve el DAMP S1MBHS001
MBH22AA302 Instrument Valve for MBH22CP102 man SOV S1MBHS001
MBH22AA412 Drain Valve for Measure Line man BV S1MBHS001
MBH40AA201 Check Valve Downstream Seal Air Fan 1 med CKF S1MBHS003
MBH40AA204 Check Valve Downstream Seal Air Cooler med CKV S1MBHS003
MBH40AA281 Control Butterfly Valve man DAMP S1MBHS003
MBH40AH001 Seal Air Cooler COOL S1MBHS003
MBH40AN001KN01 Seal Air Fan 1 el FAN S1MBHS003
Sheet 9 of 28
REV.B
MBH40AT001 Seal Air Filter Upstream Fans STR S1MBHS003
MBH40BP001 Seal Air Cooling Orifice ORF S1MBHS003
MBH40BP002 Seal Air Cooling Orifice ORF S1MBHS003
MBL10AA101 ÷AA150 Air Intake System - Pulse Jet Filter Cleaning Valves Collector A el SOV S1MBLS001
MBL10AA151 Air Intake System - Intercepting Valve for Manifold A of Filter Cleaning System man SOV S1MBLS001
Air Intake System - Intercepting Valve of Filter/Regulator Block for Air from Auxiliary
B MBL10AA160 man SOV S1MBLS001
Compressor
Air Intake System - Self-Regulating Valve of Filter/Regulator Block for Air from
B MBL10AA161 pn CTRV S1MBLS001
Auxiliary Compressor
Air Intake System - Relief Valve Downstream Filter/Regulator Block for Air from
B MBL10AA191 med PRLV S1MBLS001
Auxiliary Compressor
MBL10AA201 ÷AA250 Air Intake System - Pulse Jet Filter Cleaning Valves Collector B el SOV S1MBLS001
MBL10AA251 Air Intake System - Intercepting Valve for Manifold B of Filter Cleaning System man SOV S1MBLS001
MBL10AA301 ÷AA350 Air Intake System - Pulse Jet Filter Cleaning Valves Collector C el SOV S1MBLS001
MBL10AA351 Air Intake System - Intercepting Valve for Manifold C of Filter Cleaning System man SOV S1MBLS001
B MBL10AA355 Air Intake System - Instrument Valve for MBL10CP005 man SOV S1MBLS001
MBL10AA401 ÷AA450 Air Intake System - Pulse Jet Filter Cleaning Valves Collector D el SOV S1MBLS001
MBL10AA451 Air Intake System - Intercepting Valve for Manifold D of Filter Cleaning System man SOV S1MBLS001
MBL10AA501 ÷AA550 Air Intake System - Pulse Jet Filter Cleaning Valves Collector E el SOV S1MBLS001
MBL10AA551 Air Intake System - Intercepting Valve for Manifold E of Filter Cleaning System man SOV S1MBLS001
MBL10AA601 ÷AA650 Air Intake System - Pulse Jet Filter Cleaning Valves Collector F el SOV S1MBLS001
MBL10AA651 Air Intake System - Intercepting Valve for Manifold F of Filter Cleaning System man SOV S1MBLS001
B MBL10AA701 ÷AA750 Air Intake System - Pulse Jet Filter Cleaning Valves Collector G el SOV S1MBLS001
B MBL10AA751 Air Intake System - Intercepting Valve for Manifold G of Filter Cleaning System man SOV S1MBLS001
B MBL10AA801 ÷AA850 Air Intake System - Pulse Jet Filter Cleaning Valves Collector H el SOV S1MBLS001
B MBL10AA851 Air Intake System - Intercepting Valve for Manifold H of Filter Cleaning System man SOV S1MBLS001
MBL10AT001 Air Intake System - Filters …… FILT S1MBLS001
B MBL10AT011 Air Intake System - Filter of Filter/Regulator Block for Air from Auxiliary Compressor…… FILT S1MBLS001
MBL12AA001 Air Intake System - Anti-Implosion Door 1 med CKV S1MBLS001
MBL12AH001 Air Intake System - Anti-Ice Heater for Anti-Implosion Door HEAT S1MBLS001
B MBL12AA002 Air Intake System - Anti-Implosion Door 2 med CKV S1MBLS001
B MBL12AH002 Air Intake System - Anti-Ice Heater for Anti-Implosion Door 2 HEAT S1MBLS001
MBL13AA051 Air Intake System - Anti-Ice Stop Valve pn SOV S1MBLS001
Sheet 10 of 28
REV.B
MBL13AA051A Air Intake System - Solenoid Valve for Anti-Ice Stop Valve el SOV S1MBLS001
MBL13AA151 Air Intake System - Anti-Ice Control Valve pn CTRV S1MBLS001
MBL13AH001 Air Intake System - Anti-Ice Device HEAT S1MBLS001
B MBL13BS001 Air Intake System - Anti-Ice Silencer SIL S1MBLS001
MBL20AA001A/B Air Intake System - Damper el DAMP S1MBLS001
MBL20BR001 Air Intake System - Expansion Joint EXP S1MBLS001
MBL20BS001 Air Intake System - Silencer SIL S1MBLS001
MBL21AP001÷AP002 Air Intake System - Fans for Dust Extraction FAN S1MBLS001
MBM10AA301 Manifold for MBM10CP101 man SOV S1MBMS001
MBM10AA401 Drain Valve for MBM10CP101 Manifold man SOV S1MBMS001
MBM10AA411 Drain Valve for MBM10CP101 Manifold man SOV S1MBMS001
MBM10AV001 Combustion Chamber CC S1MBMS001
MBM12AV001KV01 Burner N.1 BURN S1MBMS001
Sheet 11 of 28
REV.B
MBN11AA201 FO Check Valve for by-pass Feed Line towards Return Line med CKV S1MBNS001
MBN11AA251 FO Change-over Valve for Filter Commutation man TRV S1MBNS001
MBN11AA252 Valve for Filling FO Duplex Filter man SOVC S1MBNS001
MBN11AA253 Isolating Valve for FO Elastomer Bladder 1 man SOV S1MBNS001
MBN11AA254 Isolating Valve for FO Elastomer Bladder 2 man SOV S1MBNS001
MBN11AA301 Instrument Valve for MBN11CP401 man SOV S1MBNS001
MBN11AA401 Drain Valve for FO Filter 1 man BV S1MBNS001
MBN11AA402 Drain Valve for FO Filter 2 man BV S1MBNS001
MBN11AA501 Vent Valve for FO Filter 1 man BV S1MBNS001
MBN11AA502 Vent Valve for FO Filter 2 man BV S1MBNS001
MBN11AA503 FO Isolating Valve for by-pass Feed Line towards Return Line man BV S1MBNS001
MBN11AT001 FO Duplex Filter (Filter Element 1) FILT S1MBNS001
MBN11AT002 FO Duplex Filter (Filter Element 2) FILT S1MBNS001
MBN11BB001 FO Elastomer Bladder 1 PAC S1MBNS001
MBN11BB002 FO Elastomer Bladder 2 PAC S1MBNS001
MBN11BP001 FO Orifice for by-pass Feed Line towards Return Line ORF S1MBNS001
MBN11BP002 Orifice for FO Duplex Filter Vent Line towards Return Line ORF S1MBNS001
MBN12AA051 Automatic Recirculation Valve for Protection FO Injection Pump med PRLV S1MBNS001
MBN12AA191 Pressure Relief Valve Downstream FO Injection Pump towards Return Line med PRLV S1MBNS001
MBN12AA201 Check Valve for by-pass Line of FO Automatic Recirculation Valve med CKV S1MBNS001
MBN12AA255 Shut-off Valve for by-pass Line of FO Automatic Recirculation Valve man BV S1MBNS001
Sheet 12 of 28
REV.B
B MBN12AA401 Drain Valve Upstream FO Injection Pump man BV S1MBNS001
MBN12AA402 Isolating Valve Upstream FO Injection Pump man SOV S1MBNS001
MBN12AA403 Isolating Valve Downstream FO Automatic Recirculation Valve man SOV S1MBNS001
MBN12AP001KP01 Fuel Oil Injection Pump el CTRP S1MBNS001
MBN13AA401 Drain Valve for FO Diffusion Feed Line Upstream ESV man BV S1MBNS001
MBN14AA051KA01 FO Diffusion Feed Line ESV hyd ESV S1MBNS001
MBN14AA151KA01 FO Diffusion Feed Line CV hyd CTRV S1MBNS001
MBN14AA401 Drain Valve for FO Diffusion Feed Line Downstream CV man BV S1MBNS001
MBN14AA501KA01 Solenoid Valve for Drainage FO Diffusion Feed Line (between ESV and CV) el SOV S1MBNS001
MBN14BP001 Calibrated Orifice Upstream Solenoid Valve for Drainage FO Diffusion Feed Line ORFA S1MBNS001
B MBN14BP002 Fuel Oil Calibrated Orifice Upstream Manual Valve for Drain Diffusion Feed Line ORFA S1MBNS001
MBN23AA051KA01 FO Premix Line ESV hyd ESV S1MBNS001
MBN23AA151KA01 FO Premix Line CV hyd CTRV S1MBNS001
MBN23AA401 Drain Valve for FO Premix Line Downstream CV man SOV S1MBNS001
MBN23AA501KA01 Solenoid Valve for Drainage FO Premix Line (between ESV and CV) el SOV S1MBNS001
MBN23BP001 Calibrated Orifice Upstream Solenoid Valve for Drainage FO Premix Line ORFA S1MBNS001
B MBN23BP002 Fuel Oil Calibrated Orifice Upstream Manual Valve for Drain Premix Line ORFA S1MBNS001
Sheet 13 of 28
REV.B
MBN31AT001 FO Filter Diffusion Feed Line (Piping) FILT S1MBNS001
MBN34AA001KA01 Seal Air Ball Cock for Diffusion Feed Line el BV S1MBNS001
MBN34AA002KA01 Leakage Oil Valve for Diffusion Feed Line el SOV S1MBNS001
MBN34BP001 Leakage Oil Orifice to Seal Air Ball Cock for Diffusion Feed Line ORF S1MBNS001
MBN36AA201 Check Valve FO Return Line Burner 1 med CKV S1MBNS001
Sheet 14 of 28
REV.B
MBN36BP001 FO Orifice (Diffusion Feed and Return Line) ORF S1MBNS001
MBN41AT001 FO Filter Premix Line (Piping) FILT S1MBNS001
MBN43AM001 Mixer (HP Purging Water, FO Premix Line) TANK S1MBNS001
MBN44AA001KA01 Seal Air Ball Cock for Premix Line el BV S1MBNS001
MBN44AA002KA01 Leakage Oil Valve for Premix Line el SOV S1MBNS001
MBN44BP001 Leakage Oil Orifice to Seal Air Ball Cock for Premix Line ORF S1MBNS001
MBN45AA001AKA01 Pilot Solenoid Valve for Shut-Off Valve AA001 el SOV S1MBNS001
MBN45AA001KA01 Fuel Oil Shut-Off Valve 1 for Drain Premix Line to Leakage Oil Tank pn SOV S1MBNS001
MBN45AA002AKA01 Pilot Solenoid Valve for Shut-Off Valve AA002 el SOV S1MBNS001
MBN45AA002KA01 Fuel Oil Shut-Off Valve 2 for Drain Premix Line to Leakage Oil Tank pn SOV S1MBNS001
B MBN45AA401 Sampling Valve for Separator Fuel Oil Back Purging man SOV S1MBNS001
B MBN45AT001 Separator for Fuel Oil Back Purging FILT S1MBNS001
Fuel Oil Drain of Premix Line to Leakage Oil Tank (Silencer for Pilot Solenoid Valve
MBN45BS001 SIL S1MBNS001
of Shut-Off Valve)
of Shut-Off Valve)
of Shut-Off Valve)
of Shut-Off Valve)
MBN52AA051KA01 FO Diffusion Return Line ESV hyd ESV S1MBNS001
Sheet 15 of 28
REV.B
MBN52AA401 Drain Valve for FO Diffusion Return Line Upstream ESV man BV S1MBNS001
MBN52AA501KA01 Solenoid Valve for Drainage FO Diffusion Return Line (between ESV and CV) el SOV S1MBNS001
MBN52BP001 Calibrated Orifice Upstream Solenoid Valve for Drainage FO Diffusion Return Line ORFA S1MBNS001
Fuel Oil Calibrated Orifice Upstream Manual Valve for Drain FO Diffusion Return
B MBN52BP002 ORFA S1MBNS001
Line
MBN53AA151KA01 FO Diffusion Return Line CV hyd CTRV S1MBNS001
MBN54AA401 Drain Valve for FO Diffusion Return Line Downstream CV man BV S1MBNS001
MBN60AA191 Pressure Relief Valve for FO Leakage Pump towards Leakage Tank med PRLV S1MBNS001
MBN60AA202 Check Valve Downstream FO Leakage Pump med CKV S1MBNS001
MBN60AA251 Shut-off Valve Downstream FO Leakage Pump man BV S1MBNS001
MBN60AA252 Connection for Emergency Drainage of FO Leakage Tank man SOV S1MBNS001
MBN60AA403 Drain Valve for FO Leakage Tank man SOVC S1MBNS001
MBN60AP001KP01 FO Leakage Pump el CTRP S1MBNS001
MBN60BB001 FO Leakage Tank TANK S1MBNS001
MBN80AA001 HP Purging Water System, Shut-off Valve for Filling Tank man SOVC S1MBNS002
MBN80AA002KA01 HP Purging Water System, Solenoid Valve for Filling Tank el SOV S1MBNS002
MBN80AA401 HP Purging Water System, Drain Valve for Tank man SOVC S1MBNS002
MBN80AT001 HP Purging Water System, Filter for Anti-Intrusion Safety Inside Tank FILT S1MBNS002
MBN80BB001 HP Purging Water System, Tank TANK S1MBNS002
MBN81AA001 HP Purging Water System, Intercepting Valve Upstream Filter man SOV S1MBNS002
MBN81AT001 HP Purging Water System, Filter Downstream Tank FILT S1MBNS002
MBN82AA001 HP Purging Water System, Intercepting Valve Downstream Pump man SOV S1MBNS002
B MBN82AA051 HP Purging Water System, Minimum Flow Regulation Valve med CKV S1MBNS002
MBN82AA052AKA01 HP Purging Water System, Pilot Solenoid Valve for Shut-Off Valve Downstream CVel SOV S1MBNS002
HP Purging Water System, Shut-Off Valve Downstream CV (safety to prevent the

MBN82AA052KA01 pn SOV S1MBNS002
return of fuel oil from washing of burners)
MBN82AA053KA01 HP Purging Water System, Solenoid Valve for Leakage el SOV S1MBNS002
MBN82AA151KA01 HP Purging Water System, Control Valve Downstream Pump hyd CTRV S1MBNS002
B MBN82AA191 HP Purging Water System, Relief Valve for Over Pressure Pump med PRLV S1MBNS002
Sheet 16 of 28
REV.B
MBN82AP001KP01 HP Purging Water System, Pump el CTRP S1MBNS002
HP Purging Water System, Orifice for Flow Limitation Upstream Solenoid Valve for
MBN82BP001 ORFA S1MBNS002
Leakage
B MBN82BP002 HP Purging Water System, Orifice for Flow Limitation Downstream Pump ORF S1MBNS002
HP Purging Water System, Silencer for Pilot Solenoid Valve to Shut-Off Valve
Downstream CV
HP Purging Water System, Silencer for Pilot Solenoid Valve to Shut-Off Valve
Downstream CV
HP Purging Water System, Pilot Solenoid Valve for Shut-Off Valve to Fuel Oil
MBN83AA051AKA01 el SOV S1MBNS002
Diffusion Feed Line
MBN83AA051KA01 HP Purging Water System, Shut-Off Valve for Fuel Oil Diffusion Feed Line pn SOV S1MBNS002
Diffusion Return Line
MBN83AA052KA01 HP Purging Water System, Shut-Off Valve for Fuel Oil Diffusion Return Line pn SOV S1MBNS002
HP Purging Water System, Silencer for Pilot Solenoid Valve to Shut-Off Valve (Fuel
Oil Diffusion Feed Line)
Oil Diffusion Return Line)
Oil Diffusion Feed Line)
Oil Diffusion Return Line)
HP Purging Water System, Pilot Solenoid Valve for Shut-Off Valve to Fuel Oil Feed
Ring Line
MBN84AA051KA01 HP Purging Water System, Shut-Off Valve for Fuel Oil Feed Ring Line pn SOV S1MBNS002
Premix Feed Line
MBN84AA052KA01 HP Purging Water System, Shut-Off Valve for Fuel Oil Premix Feed Line pn SOV S1MBNS002
Oil Feed Ring Line)
Oil Premix Feed Line)
Oil Feed Ring Line)
Oil Premix Feed Line)
MBP11AT001 Natural Gas Filter (Premix Line) STR S1MBPS001
MBP13AA051KA01 Natural Gas Stop Valve hyd ESV S1MBPS001
Sheet 17 of 28
REV.B
MBP13AA301 Instrument Valve for MBP13CP101 man SOV S1MBPS001
MBP13AA501KA01 Natural Gas Vent Valve el SOV S1MBPS001
MBP22AA151KA01 Natural Gas Control Valve (Premix Line) hyd CTRV S1MBPS001
MBP24AA151KA01 Natural Gas Control Valve (Pilot 2 Line) hyd CTRV S1MBPS001
B MBP32AA301 Instrument Valve for MBP32CP101 man SOV S1MBPS001
MBP32AH001 Premix Gas Line Heater HEAT S1MBPS001
B MBP34AA301 Instrument Valve for MBP34CP101 man SOV S1MBPS001
MBP34AH001 Pilot 2 Gas Line Heater HEAT S1MBPS001
MBQ11AA001KA01 Solenoid Valve for Ignition Gas Inlet el SOV S1MBQS001
MBQ11AA251 Shut-off Valve for Ignition Gas Inlet man BV S1MBQS001
MBQ12AA151 Control Valve for Ignition Gas Inlet med PCV S1MBQS001
MBQ12AA301 Instrument Valve for MBQ12CP501 man SOV S1MBQS001
MBQ12AA501KA01 Solenoid Valve for Ignition Gas Vent el SOV S1MBQS001
MBQ13AA001KA01 Solenoid Valve for Ignition Gas to Fuel Gas Pilot Line el SOV S1MBQS001
MBQ13AA201 Check Valve for Ignition Gas to Fuel Gas Pilot Line med CKV S1MBQS001
MBQ13AA301 Instrument Valve for MBQ13CP101 man SOV S1MBQS001
MBR20AA341 Instrument Valve for MBR20CP101 man SOV S1MBRS001
MBR20BR001 Diffuser Expansion Joint EXP S1MBRS001
MBX01AA401 Valve for Emptying Hydraulic Oil Tank man BV S1MBXS001
MBX01AH001 Hydraulic Oil Tank Heater HEAT S1MBXS001
MBX01AT001 Humidifier Filter Hydraulic Oil Tank FILT S1MBXS001
MBX01BB001 Hydraulic Oil Tank TANK S1MBXS001
MBX02AA191 Safety Valve for Hydraulic Oil Pump 1 med PRLV S1MBXS001
MBX02AA192 Safety Valve for Hydraulic Oil Pump 1 (Upstream Filter) med PRLV S1MBXS001
MBX02AA193 Safety Valve for Hydraulic Oil Pump 2 med PRLV S1MBXS001
MBX02AA194 Safety Valve for Hydraulic Oil Pump 2 (Upstream Filter) med PRLV S1MBXS001
MBX02AA201 Check Valve Downstream Hydraulic Oil Recirculating Pump 1 med CKV S1MBXS001
Sheet 18 of 28
REV.B
MBX02AA202 Check Valve Downstream Hydraulic Oil Recirculating Pump 2 med CKV S1MBXS001
MBX02AP001KP01 Hydraulic Oil Pump 1 el PDP S1MBXS001
MBX02AP002KP01 Hydraulic Oil Pump 2 el PDP S1MBXS001
MBX03AA201 Check Valve Downstream Hydraulic Oil High Pressure Filter 1 for Delivery Line med CKV S1MBXS001
MBX03AA202 Check Valve Downstream Hydraulic Oil High Pressure Filter 2 for Delivery Line med CKV S1MBXS001
MBX03AA251 Hydraulic Oil Intercepting Valve for Switching Off Filter 1 man BV S1MBXS001
Pressure compensated flow control valve downstream analyzer of degree

MBX03AA281 man FCV S1MBXS001
contamination of hydraulic oil
MBX03AA301 Instrument Valve for MBX03CP501 man SOV S1MBXS001
MBX03AA315 Drain valve for calibration MBX03CP005 man SOV S1MBXS001
MBX03AA321 Instrument Valve for MBX03CP401 man CBM S1MBXS001
MBX03AA330 Instrument Valve (available) man CBM S1MBXS001
B MBX03AA331 Instrument Valve (available) man CBM S1MBXS001
MBX03AT001 Hydraulic Oil Filter 1 FILT S1MBXS001
MBX03AT002 Hydraulic Oil Filter 2 FILT S1MBXS001
MBX04AA191 Safety Device of Hydraulic Oil Accumulator 1 for Valves Actuation Line med PRLV S1MBXS001
Sheet 19 of 28
REV.B
MBX04AA192 Safety Device of Hydraulic Oil Accumulator 2 for Valves Actuation Line med PRLV S1MBXS001
MBX04AA251 Safety Device of Hydraulic Oil Accumulator 1 for Valves Actuation Line man SOV S1MBXS001
MBX04BB001 Hydraulic Oil Accumulator 1 for Valves Actuation Line PAC S1MBXS001
MBX04BB002 Hydraulic Oil Accumulator 2 for Valves Actuation Line PAC S1MBXS001
MBX06AA001 Hydraulic Oil Changeover Valve for Transition towards Air Coolers or Tank man TRV S1MBXS001
MBX06AA002 Hydraulic Oil Changeover Valve for Transition towards Air Cooler 1 or Air Cooler 2 man TRV S1MBXS001
Check Relief Valve Downstream Hydraulic Oil Recirculating Pump 1 for Return Oil
MBX06AA201 med CKV S1MBXS001
to Tank
Check Relief Valve Downstream Hydraulic Oil Recirculating Pump 2 for Return Oil
to Tank
MBX06AA203 Check Valve Downstream Hydraulic Oil Air Cooler 1 med CKV S1MBXS001
MBX06AA204 Check Valve Downstream Hydraulic Oil Air Cooler 2 med CKV S1MBXS001
MBX06AA331 Differential Check Valve for Hydraulic Oil Air Coolers med CKV S1MBXS001
MBX06AH001KC01 Hydraulic Oil Air Cooler 1 el COOL S1MBXS001
MBX06AH002KC01 Hydraulic Oil Air Cooler 2 el COOL S1MBXS001
MBX06AP001KP01 Hydraulic Oil Pump 1 Cooling/Recirculating Circuit el PDP S1MBXS001
MBX06AP002KP01 Hydraulic Oil Pump 2 Cooling/Recirculating Circuit el PDP S1MBXS001
MBX07AA191 Safety Device of Hydraulic Oil Accumulator for IGV Actuation Line med PRLV S1MBXS001
MBX07AA201 Check Relief Valve Upstream Hydraulic Oil Delivery Line to IGV Actuator med CKV S1MBXS001
MBX07AA251 Safety Device of Hydraulic Oil Accumulator for IGV Actuation Line man SOV S1MBXS001
Sheet 20 of 28
REV.B
MBX07AA401 Safety Device of Hydraulic Oil Accumulator for IGV Actuation Line man SOV S1MBXS001
MBX07BB001 Hydraulic Oil Accumulator for IGV Actuation Line PAC S1MBXS001
MBX08AA001 Hydraulic Oil Intercepting Valve for Filling Tank Line man TRVP S1MBXS001
MBX08AA251 Intercepting Valve for Hydraulic Oil Tank Filling man BV S1MBXS001
MBX08AT001 Filter for Hydraulic Oil Return Line FILT S1MBXS001
MBX09AA191 Safety Device of Hydraulic Oil Accumulator for CV1 Actuation Line med PRLV S1MBXS001
MBX09AA201 Check Relief Valve Upstream Hydraulic Oil Delivery Line to CV1 Actuator med CKV S1MBXS001
MBX09AA251 Safety Device of Hydraulic Oil Accumulator for CV1 Actuation Line man SOV S1MBXS001
MBX09AA401 Safety Device of Hydraulic Oil Accumulator for CV1 Actuation Line man SOV S1MBXS001
MBX09BB001 Hydraulic Oil Accumulator for IGV Actuation Line PAC S1MBXS001
MBX21AA191 Pressure Relief Valve Downstream Pneumatic Compressor 1 med PRLV S1MBXS002
MBX21AA201 Check Valve Downstream Pneumatic Compressor 1 med CKV S1MBXS002
MBX21AA251 Valve for Switching Off Pneumatic Compressor Line 1 man SOVC S1MBXS002
MBX21AA401 Drain Valve for Condense Separator (Downstream Pneumatic Compressor 1) man TRAP S1MBXS002
MBX21AA402 Drain Valve for Compressed Air Filter (Downstream Pneumatic Compressor 1) man TRAP S1MBXS002
MBX21AN001KN01 Pneumatic Compressor 1 el COMP S1MBXS002
MBX21AT001 Condense Separator Downstream Pneumatic Compressor 1 FILT S1MBXS002
MBX21AT002 Compressed Air Filter Downstream Pneumatic Compressor 1 FILT S1MBXS002
MBX21AT003 Air Dryer Downstream Pneumatic Compressor 1 el DEHUM S1MBXS002
MBX22AA191 Pressure Relief Valve Downstream Pneumatic Compressor 2 med PRLV S1MBXS002
MBX22AA201 Check Valve Downstream Pneumatic Compressor 2 med CKV S1MBXS002
MBX22AA251 Valve for Switching Off Pneumatic Compressor Line 2 man SOVC S1MBXS002
MBX22AA401 Drain Valve for Condense Separator (Downstream Pneumatic Compressor 2) man TRAP S1MBXS002
Sheet 21 of 28
REV.B
MBX22AA402 Drain Valve for Compressed Air Filter (Downstream Pneumatic Compressor 2) man TRAP S1MBXS002
MBX22AN001KN01 Pneumatic Compressor 2 el COMP S1MBXS002
MBX22AT001 Condense Separator Downstream Pneumatic Compressor 2 FILT S1MBXS002
MBX22AT002 Compressed Air Filter Downstream Pneumatic Compressor 2 FILT S1MBXS002
MBX22AT003 Air Dryer Downstream Pneumatic Compressor 2 el DEHUM S1MBXS002
MBX23BB001 Drain Header for Compressed Air System TANK S1MBXS002
MBX24AA191 Safety Valve Pneumatic Compressor Tank med PRLV S1MBXS002
B MBX24AA192 Air Pressure Reducer for Emergency Connection Pneumatic Compressor Tank med PCV S1MBXS002
Check Valve for Pneumatic Compressor Tank (Emergency connection for

instrument air use)
MBX24AA202 Check Valve for Delivery Pneumatic Compressor Tank med CKV S1MBXS002
MBX24AA401 Drain Valve for Pneumatic Compressor Tank man SOVC S1MBXS002
MBX24BB001 Pneumatic Compressor Tank PAC S1MBXS002
MBX30AA051KA01 Solenoid Valve for Actuator Control Unit IGV el TRVP S1MBXS005
MBX30AA052KA01 Solenoid Valve for Actuator Control Unit IGV el TRVP S1MBXS005
MBX30AA101KA01 Servovalve for Actuator Control Unit IGV el SDV S1MBXS005
MBX30AA301 Check Valve for Actuator Control Unit IGV med CKV S1MBXS005
MBX30AA331 Differential Check Valve for Actuator Control Unit IGV med CKV S1MBXS005
MBX30AA351KA01 Hydraulic Distributor for Actuator Control Unit IGV hyd TRVP S1MBXS005
MBX30AS001 Actuator Control Unit for IGV hyd COPL S1MBXS005
MBX30AS002 Actuator Piston for IGV hyd ACT S1MBXS005
MBX30AT001 Filter for Actuator Control Unit IGV FILT S1MBXS005
MBX40AA051KA01 Solenoid Valve for Actuator Control Unit CV1 el TRVP S1MBXS005
Sheet 22 of 28
REV.B
MBX40AA052KA01 Solenoid Valve for Actuator Control Unit CV1 el TRVP S1MBXS005
MBX40AA101KA01 Servovalve for Actuator Control Unit CV1 el SDV S1MBXS005
MBX40AA301 Check Valve for Actuator Control Unit CV1 med CKV S1MBXS005
MBX40AA331 Differential Check Valve for Actuator Control Unit CV1 med CKV S1MBXS005
MBX40AA351KA01 Hydraulic Distributor for Actuator Control Unit CV1 hyd TRVP S1MBXS005
MBX40AS001 Actuator Control Unit for CV1 hyd COPL S1MBXS005
MBX40AS002 Actuator Piston for CV1 hyd ACT S1MBXS005
MBX40AT001 Filter for Actuator Control Unit CV1 FILT S1MBXS005
MBX65AA002KA01 Solenoid Valve for Actuator Control Unit HP Purging Water Control Valve el TRVP S1MBXS008
MBX65AA052KA01 Cartridge Valve for Actuator Control Unit HP Purging Water Control Valve med CTCV S1MBXS008
MBX65AA101KA01 Servovalve for Actuator Control Unit HP Purging Water Control Valve el SDV S1MBXS008
Compensated Flow Regulator for Actuator Control Unit HP Purging Water Control
MBX65AA281 med CFR S1MBXS008
Valve
MBX65AS001 Actuator Control Unit for HP Purging Water Control Valve hyd COPL S1MBXS008
MBX65AS002 Actuator Piston for HP Purging Water Control Valve hyd ACT S1MBXS008
MBX65AT001 Filter for Actuator Control Unit HP Purging Water Control Valve FILT S1MBXS008
MBX65BP001 Orifice for Actuator Control Unit HP Purging Water Control Valve man THRV S1MBXS008
MBX70AA001KA01 Solenoid Valve for Actuator Control Unit Natural Gas Stop Valve el TRVP S1MBXS003
MBX70AA031KA01 Solenoid Valve for Actuator Control Unit Natural Gas Stop Valve el TRVP S1MBXS003
MBX70AA051KA01 Cartridge Valve for Actuator Control Unit Natural Gas Stop Valve med CTCV S1MBXS003
Sheet 23 of 28
REV.B
MBX70AS001 Actuator Control Unit for Natural Gas Stop Valve hyd COPL S1MBXS003
MBX70AS002 Actuator Piston for Natural Gas Stop Valve hyd ACT S1MBXS003
MBX70AT001 Filter for Actuator Control Unit Natural Gas Stop Valve FILT S1MBXS003
MBX70BP001 Orifice for Actuator Control Unit Natural Gas Stop Valve man THRV S1MBXS003
MBX75AA001KA01 Solenoid Valve for Actuator Control Unit Fuel Oil Stop Valve (Diff. Feed Line) el TRVP S1MBXS006
MBX75AA031KA01 Solenoid Valve for Actuator Control Unit Fuel Oil Stop Valve (Diff. Feed Line) el TRVP S1MBXS006
MBX75AA051KA01 Cartridge Valve for Actuator Control Unit Fuel Oil Stop Valve (Diff. Feed Line) med CTCV S1MBXS006
MBX75AS001 Actuator Control Unit for Fuel Oil Stop Valve (Diff. Feed Line) hyd COPL S1MBXS006
MBX75AS002 Actuator Piston for Fuel Oil Stop Valve (Diff. Feed Line) hyd ACT S1MBXS006
MBX75AT001 Filter for Actuator Control Unit Fuel Oil Stop Valve (Diff. Feed Line) FILT S1MBXS006
MBX75BP001 Orifice for Actuator Control Unit Fuel Oil Stop Valve (Diff. Feed Line) man THRV S1MBXS006
MBX77AA001KA01 Solenoid Valve for Actuator Control Unit Fuel Oil Stop Valve (Premix Line) el TRVP S1MBXS006
MBX77AA031KA01 Solenoid Valve for Actuator Control Unit Fuel Oil Stop Valve (Premix Line) el TRVP S1MBXS006
MBX77AA051KA01 Cartridge Valve for Actuator Control Unit Fuel Oil Stop Valve (Premix Line) med CTCV S1MBXS006
MBX77AS001 Actuator Control Unit for Fuel Oil Stop Valve (Premix Line) hyd COPL S1MBXS006
MBX77AS002 Actuator Piston for Fuel Oil Stop Valve (Premix Line) hyd ACT S1MBXS006
MBX77AT001 Filter for Actuator Control Unit Fuel Oil Stop Valve (Premix Line) FILT S1MBXS006
MBX77BP001 Orifice for Actuator Control Unit Fuel Oil Stop Valve (Premix Line) man THRV S1MBXS006
Sheet 24 of 28
REV.B
MBX79AA001KA01 Solenoid Valve for Actuator Control Unit Fuel Oil Stop Valve (Diff. Return Line) el TRVP S1MBXS006
MBX79AA031KA01 Solenoid Valve for Actuator Control Unit Fuel Oil Stop Valve (Diff. Return Line) el TRVP S1MBXS006
MBX79AA051KA01 Cartridge Valve for Actuator Control Unit Fuel Oil Stop Valve (Diff. Return Line) med CTCV S1MBXS006
MBX79AS001 Actuator Control Unit for Fuel Oil Stop Valve (Diff. Return Line) hyd COPL S1MBXS006
MBX79AS002 Actuator Piston for Fuel Oil Stop Valve (Diff. Return Line) hyd ACT S1MBXS006
MBX79AT001 Filter for Actuator Control Unit Fuel Oil Stop Valve (Diff. Return Line) FILT S1MBXS006
MBX79BP001 Orifice for Actuator Control Unit Fuel Oil Stop Valve (Diff. Return Line) man THRV S1MBXS006
MBX81AA002KA01 Solenoid Valve for Actuator Control Unit Premix Control Valve el TRVP S1MBXS003
MBX81AA052KA01 Cartridge Valve for Actuator Control Unit Premix Control Valve med CTCV S1MBXS003
MBX81AA101KA01 Servovalve for Actuator Control Unit Premix Control Valve el SDV S1MBXS003
MBX81AA281 Compensated Flow Regulator for Actuator Control Unit Premix Control Valve med CFR S1MBXS003
MBX81AS001 Actuator Control Unit for Premix Control Valve hyd COPL S1MBXS003
MBX81AS002 Actuator Piston for Premix Control Valve hyd ACT S1MBXS003
MBX81AT001 Filter for Actuator Control Unit Premix Control Valve FILT S1MBXS003
MBX81BP001 Orifice for Actuator Control Unit Premix Control Valve man THRV S1MBXS003
MBX84AA002KA01 Solenoid Valve for Actuator Control Unit Pilot 2 Gas Control Valve el TRVP S1MBXS003
MBX84AA052KA01 Cartridge Valve for Actuator Control Unit Pilot 2 Gas Control Valve med CTCV S1MBXS003
MBX84AA101KA01 Servovalve for Actuator Control Unit Pilot 2 Gas Control Valve el SDV S1MBXS003
MBX84AA281 Compensated Flow Regulator for Actuator Control Unit Pilot 2 Gas Control Valve med CFR S1MBXS003
Sheet 25 of 28
REV.B
MBX84AS001 Actuator Control Unit for Pilot 2 Gas Control Valve hyd COPL S1MBXS003
MBX84AS002 Actuator Piston for Pilot 2 Gas Control Valve hyd ACT S1MBXS003
MBX84AT001 Filter for Actuator Control Unit Pilot 2 Gas Control Valve FILT S1MBXS003
MBX84BP001 Orifice for Actuator Control Unit Pilot 2 Gas Control Valve man THRV S1MBXS003
MBX86AA101KA01 Servovalve for Actuator Control Unit Fuel Oil Control Valve (Diff. Return Line) el SDV S1MBXS006
MBX86AS001 Actuator Control Unit for Fuel Oil Control Valve (Diff. Return Line) hyd COPL S1MBXS006
MBX86AS002 Actuator Piston for Fuel Oil Control Valve (Diff. Return Line) hyd ACT S1MBXS006
MBX86AT001 Filter for Actuator Control Unit Fuel Oil Control Valve (Diff. Return Line) FILT S1MBXS006
MBX86BP001 Orifice for Actuator Control Unit Fuel Oil Control Valve (Diff. Return Line) man THRV S1MBXS006
MBX87AA002KA01 Solenoid Valve for Actuator Control Unit Fuel Oil Control Valve (Premix Line) el TRVP S1MBXS006
MBX87AA052KA01 Cartridge Valve for Actuator Control Unit Fuel Oil Control Valve (Premix Line) med CTCV S1MBXS006
MBX87AA101KA01 Servovalve for Actuator Control Unit Fuel Oil Control Valve (Premix Line) el SDV S1MBXS006
Compensated Flow Regulator for Actuator Control Unit Fuel Oil Control Valve
(Premix Line)
MBX87AS001 Actuator Control Unit for Fuel Oil Control Valve (Premix Line) hyd COPL S1MBXS006
MBX87AS002 Actuator Piston for Fuel Oil Control Valve (Premix Line) hyd ACT S1MBXS006
MBX87AT001 Filter for Actuator Control Unit Fuel Oil Control Valve (Premix Line) FILT S1MBXS006
MBX87BP001 Orifice for Actuator Control Unit Fuel Oil Control Valve (Premix Line) man THRV S1MBXS006
MBX88AA002KA01 Solenoid Valve for Actuator Control Unit Fuel Oil Control Valve (Diff. Feed Line) el TRVP S1MBXS006
MBX88AA052KA01 Cartridge Valve for Actuator Control Unit Fuel Oil Control Valve (Diff. Feed Line) med CTCV S1MBXS006
MBX88AA101KA01 Servovalve for Actuator Control Unit Fuel Oil Control Valve (Diff. Feed Line) el SDV S1MBXS006
Sheet 26 of 28
REV.B
Compensated Flow Regulator for Actuator Control Unit Fuel Oil Control Valve (Diff.
Feed Line)
MBX88AS001 Actuator Control Unit for Fuel Oil Control Valve (Diff. Feed Line) hyd COPL S1MBXS006
MBX88AS002 Actuator Piston for Fuel Oil Control Valve (Diff. Feed Line) hyd ACT S1MBXS006
MBX88AT001 Filter for Actuator Control Unit Fuel Oil Control Valve (Diff. Feed Line) FILT S1MBXS006
MBX88BP001 Orifice for Actuator Control Unit Fuel Oil Control Valve (Diff. Feed Line) man THRV S1MBXS006
MBX90AA001KA01 Pneumatic Pilot-Spring Return Valve (Blow-Off Valve Extraction Line 1.1) pn TRV S1MBXS004
MBX90AA002AKA01 Operation Direct Acting Solenoid Valve 1 (Blow-Off Valve Extraction Line 1.1) el TRV S1MBXS004
MBX90AA002BKA01 Operation Direct Acting Solenoid Valve 2 (Blow-Off Valve Extraction Line 1.1) el TRV S1MBXS004
Adjustable Quick Exhaust Valve with External Pilot (Blow-Off Valve Extraction Line
MBX90AA051KA01 med CTCV S1MBXS004
1.1)
MBX90AA191 Air Pressure Reducer for Actuation Line (Blow-Off Valve Extraction Line 1.1) med PRLV S1MBXS004
MBX90AS001 Actuator for Blow-Off Valve (Extraction Line 1.1) pn ACT S1MBXS004
MBX90BP001 Bidirectional Flow Regulator (Blow-Off Valve Extraction Line 1.1) ORFA S1MBXS004
MBX90BS001 Dust Excluder for Actuator (Blow-Off Valve Extraction Line 1.1) SIL S1MBXS004
MBX91AA001KA01 Pneumatic Pilot-Spring Return Valve (Blow-Off Valve Extraction Line 1.2) pn TRV S1MBXS004
MBX91AA002AKA01 Operation Direct Acting Solenoid Valve 1 (Blow-Off Valve Extraction Line 1.2) el TRV S1MBXS004
MBX91AA002BKA01 Operation Direct Acting Solenoid Valve 2 (Blow-Off Valve Extraction Line 1.2) el TRV S1MBXS004
1.2)
MBX91AA191 Air Pressure Reducer for Actuation Line (Blow-Off Valve Extraction Line 1.2) med PRLV S1MBXS004
MBX91AS001 Actuator for Blow-Off Valve (Extraction Line 1.2) pn ACT S1MBXS004
MBX91BP001 Bidirectional Flow Regulator (Blow-Off Valve Extraction Line 1.2) ORFA S1MBXS004
MBX92AA001KA01 Pneumatic Pilot-Spring Return Valve (Blow-Off Valve Extraction Line 2) pn TRV S1MBXS004
MBX92AA002AKA01 Operation Direct Acting Solenoid Valve 1 (Blow-Off Valve Extraction Line 2) el TRV S1MBXS004
MBX92AA002BKA01 Operation Direct Acting Solenoid Valve 2 (Blow-Off Valve Extraction Line 2) el TRV S1MBXS004
2)
Sheet 27 of 28
REV.B
MBX92AA191 Air Pressure Reducer for Actuation Line (Blow-Off Valve Extraction Line 2) med PRLV S1MBXS004
MBX92AS001 Actuator for Blow-Off Valve (Extraction Line 2) pn ACT S1MBXS004
MBX92BP001 Bidirectional Flow Regulator (Blow-Off Valve Extraction Line 2) ORFA S1MBXS004
MBX92BS001 Dust Excluder for Actuator (Blow-Off Valve Extraction Line 2) SIL S1MBXS004
MBX93AA001KA01 Pneumatic Pilot-Spring Return Valve (Blow-Off Valve Extraction Line 3) pn TRV S1MBXS004
MBX93AA002AKA01 Operation Direct Acting Solenoid Valve 1 (Blow-Off Valve Extraction Line 3) el TRV S1MBXS004
MBX93AA002BKA01 Operation Direct Acting Solenoid Valve 2 (Blow-Off Valve Extraction Line 3) el TRV S1MBXS004
3)
MBX93AA191 Air Pressure Reducer for Actuation Line (Blow-Off Valve Extraction Line 3) med PRLV S1MBXS004
MBX93AS001 Actuator for Blow-Off Valve (Extraction Line 3) pn ACT S1MBXS004
MBX93BP001 Bidirectional Flow Regulator (Blow-Off Valve Extraction Line 3) ORFA S1MBXS004
Sheet 28 of 28
SET POINT LIST
Page 1 of 1
SET POINT LIST TGO1-0530-E00000
13.11.2014
Project MC: Owner:

Consultant:
GENERATION CO.
DOCUMENT TITLE: GT SET POINT LIST

Serial
No.
MAZ AEN 01 MB_ PR LIS 002 C
GAS TURBINE
SET POINT LIST
ELECT.SIGN D:Rosellini C:Perpiglia A1:Capotos A2:Pesce A3:- (24/07/2018)

2
0

F. Rosellini F. Perpiglia CAPOTOS (PE) P.PESCE
C 24/07/2018 GENERAL REVISION
PEM/GTE PEM/GTE PEM/GTE PEM/GTE
F. Rosellini F. Perpiglia CAPOTOS (PE) P.PESCE
B 05/04/2018 GENERAL REVISION
For Construction.
R.Massa B. SANTOLINI (TC) CAPOTOS (PE) P.PESCE

A 25/01/2017 FIRST EMISSION
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Revision Record
PAGE A B C D PAGE A B C D
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6 X 32 X
7 X 33 X
8 X
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13 X
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1 REFERENCE DOCUMENTS
All P&ID documents and DSP Documents, have to be considered as reference documents
2 Description
Shown below the Set point list
Note:
 “SET POINT” column represents the list of all GT control parameters/ constants present in
the software and the used acronyms are only for reference in the software;
 “DESCRIPTION” column gives a brief description about what is the parameter, for quick
reference.
 “VALUE” column represent the real value of the parameter used in the software and it’s
eventually tuned during Commissioning ONLY by Ansaldo personnel.
 More information are Ansaldo proprietary
Set Point Adj Denotation DESCRIPTION Value Hyst. Unit Related Set Point rev
CH.RATIO.01 * NG-DENSITY C/H ratio, REFERENCE VALUE 3,19 ---
D.EG.01 * NG-DENSITY NG STANDART DENSITY, FOR CALCULATION OF VALVE-POSITION 0.75 kg/m3
D.HOE.01 * FO-DENSITY FO STANDART DENSITY, FOR CALCULATION OF VALVE-POSITION 840 kg/m3 B
E.LEIST.000 LOAD LOAD RANGE FOR MEASURING AND INDICATION 500 MW B
E.LEIST.001 LOAD LOAD JUMP AFTER SYNCHRONISING 10 MW
E.LEIST.002 LOAD MINIMUM LOAD WHEN GT UNLOADING 2 MW
E.LEIST.008 LOAD INTERLOCK DURING SHUT DOWN 11 0.5 MW
E.LEIST.010 LOAD Fast load change detection 20 MW
E.LEIST.014 LOAD UPPER LIMIT OF LOAD SET POINT 500 MW B
E.LEIST.015 LOAD LOWER LIMIT OF LOAD SET POINT 0 MW
E.LEIST.016 * LOAD MAX Load in ISO condition for PNORM calculation 304 MW B
PARTIAL LOAD REJECTION FOR WATER TRIP, 20% OF BASE LOAD; FOR SINGLE SHAFT REPLACED BY
E.LEIST.022 LOAD 53 MW
J.BRRENNST.04
E.LEIST.023 LOAD LOAD LIMITER 330 MW B
E.LEIST.032 LOAD LOAD REDUCTION AT COMBUSTION CHAMBER ACCELERATION, LIMIT 1 6 MW
E.LEIST.033 LOAD LOAD REDUCTION AT COMBUSTION CHAMBER ACCELERATION, LIMIT 2 15 MW
GENERATOR ON LOAD, LOAD JUMP IS FINISHED; INTERLOCK MANUAL OPERATION BLOW OFF
E.LEIST.035 LOAD 22 -2 MW
FLAPS
E.LEIST.042 * LOAD OPENING GENERATOR BREAKER DURING SHUT DOWN 3.5 0.5 MW
PARTIAL LOAD REJECTION FOR LOAD REJECTION DETECTION, 50% OF BASE LOAD; 60% FOR
E.LEIST.047 LOAD 132 MW
SINGLE SHAFT
E.LEIST.049 * LOAD UPPER LIMIT FREQ INFLUENCE - STATICS 40 MW
E.LEIST.0491 LOAD UPPER LIMIT FREQ INFLUENCE - PRIMARY FREQUENCY 40 MW
E.LEIST.050 * LOAD LOWER LIMIT FREQ INFLUENCE - STATICS -40 MW
E.LEIST.0501 LOAD LOWER LIMIT FREQ INFLUENCE - PRIMARY FREQUENCY -40 MW
E.LEIST.051 LOAD REFERENCE RANGE (±) PRIMARY FREQUENCY INFLUENCE 30 MW
E.LEIST.148 LOAD LOAD REJECTION: LOAD LIMIT FOR RAPID LOAD CHANGE DETECTION 30 MW
E.LEIST.151 LOAD LOAD REJECTION: RESIDUAL LOAD FOR SWITCH OVER IN SPEED CONTROLLER WITH DERIVATE 15 MW
E.LEIST.160 LOAD Load Limit for Steam Turbine Signal Lost (SS) 20 MW B
E.LEIST.233 * LOAD D01 - FG -SS - LVG ISO VALUE for TT.ATK.D160 70 % B
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E.LEIST.240 * LOAD D01 - FO -SS - LVG ISO VALUE for TT.ATK.D167 35 % B
E.LEIST.250 * LOAD DVLEG21 - FG- SS - LVG ISO value for TT.ATK.240 41 % B
E.LEIST.270 * LOAD DVLEG21 - FO- SS - LVG ISO value for TT.ATK.260 41 % B
E.LEIST.286 * LOAD DVLEG UP - FG-SS - LVGISO value for TT.ATK.D336 41 % B
E.LEIST.298 * LOAD DVLEG UP - FO-SS - LVGISO value for TT.ATK.D348 41 % B
E.LEIST.310 * LOAD DVLEG DOWN - FG-SS - LVGISO value for TT.ATK.D360 41 % B
E.LEIST.322 * LOAD DVLEG DOWN - FO-SS - LVGISO value for TT.ATK.D372 41 % B
E.LEIST.900 LOAD POWER LIMIT FOR SOLENOID VALVES ENERGIZED 50 MW
E.LEIST.GL ** LOAD REFERENCE BASE LOAD, NATURAL GAS OPERATION - REFERENCE VALUE 301,7 MW B
E.LEIST.HOE ** LOAD REFERENCE BASE LOAD, FUEL OIL GAS OPERATION - REFERENCE VALUE 248,9 MW B
E.SCHMOEL.10 SIGNAL TEST OF EMERGENCY LUBE OIL PUMP AT START UP >40 A
EK.LEIST.002 LOAD External LOADING 13 MW/min B
EK.LEIST.003 LOAD SLOW LOADING with IGV fully Open 6 MW/min B
EK.LEIST.006 LOAD Max allowed GT gradient with IGV>G.VLE0.023 in case of SS 13 MW/min B
EK.LEIST.008 LOAD NORMAL LOADING 13 MW/min B
EK.LEIST.101 LOAD FLAT GRADIENT, IGV CLOSED 13 MW/min
EK.LEIST.103 LOAD FREQ. INFLUENCE NORMAL GRADIENT IGV REGULATING 6 MW/min
EK.LEIST.108 LOAD LOAD CHANGE RATE FOR LOAD REJECTION DETECTION WITH DERIVATE 13 MW/min
F.EG.20 * FLOW NG-MASS FLOW AT BASE LOAD (ISO) 14,8 kg/s
F.EG.21 * FLOW FG-PILOT-CORRECTION IGNITIONFLOW AT TT.ATK.41 0,06 kg/s TT.ATK.41
F.EG.22 * FLOW FG-PILOT-CORRECTION IGNITIONFLOW AT TT.ATK.42 0,03 kg/s TT.ATK.42
F.EG.23 * FLOW FG-PILOT-CORRECTION IGNITIONFLOW AT TT.ATK.43 0 kg/s TT.ATK.43
F.EG.24 * FLOW FG-PILOT-CORRECTION IGNITIONFLOW AT TT.ATK.44 0 kg/s TT.ATK.44
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F.EG.25 * FLOW FG-PILOT-CORRECTION IGNITIONFLOW AT TT.ATK.45 -0,12 kg/s TT.ATK.45

F.EG.26 * FLOW FG-PILOT-CORRECTION IGNITIONFLOW AT TT.ATK.46 -0,12 kg/s TT.ATK.46
F.EGDB.001 * FLOW IGNITION MASS FLOW AT GT START WITH NG (Pilot1) 0.28 kg/s
F.EGDB.004 * FLOW NG-DIFF MIN FLOW AT CHANGEOVER DURING PREMIX FILLING 1 kg/s
F.EGDB.011 * FLOW ADDITIONAL MASS FLOW AFTER 5S ESV IS OPENED AT GT START WITH NG 0,45 kg/s B
F.EGVB.001 * FLOW NG-PREMIX MIN FLOW AT CHANGEOVER DURING PREMIX COLLECTOR FILLING 0.1 kg/s
F.EGVB.002 * KV-VALUE NG-PREMIX-CV, POSITION CORRECTION CALCULATOR, KV-VALUE AT G.EGVBST.01 0 m³/h G.EGVBST.01 B
F.EGVB.003 * KV-VALUE NG-PREMIX-CV, POSITION CORRECTION CALCULATOR, KV-VALUE AT G.EGVBST.02 4,78864 m³/h G.EGVBST.02 B
F.EGVB.024 KV-VALUE NG-PREMIX-BURNER, KV-VALUE OF ONE SINGLE BURNER 9,51 m³/h B
F.EGVB.025 KV-VALUE NG-PREMIX-BURNER, KV-VALUE OF PIPING 700 m³/h B
F.EGVB.026 FLOW NG PREMIX CONNECTION MASS FLOW AT FUEL CHANGEOVER FO->FG 1,3 Kg/s
F.EGVB.028 * MASS FLOW MINIMUM PREMIX FLOW WITH IGV AT G.VLE0.045 0,45 kg/s G.VLE0.045 B
F.EGVB.036 MASS FLOW LIMIT OF MAX PREMIX MASS FLOW IN CASE OF LOAD REJECTION 2,8 kg/s B
F.EGVB.046 MASS FLOW MAX PREMIX MASS FLOW FOR LOAD REJECTION IN ISLAND MODE na kg/s B
F.EMUSPU.100 * FLOW WATER MASS FLOW FOR PREMIX COOLING, AT CONNECTION 2.9 kg/s
F.EMUSPU.101 * FLOW WATER MASS FLOW FOR PREMIX COOLING, AT COOLING PROCESS 2.9 kg/s
F.EMUSPU.102 * FLOW WATER MASS FLOW FOR PREMIX COOLING - DISCONNECTION 0,5 kg/s
F.EMUSPU.103 * FLOW WATER MASS FLOW FOR PREMIX PURGING, AT CONNECTION 1.5 kg/s
F.EMUSPU.104 * FLOW WATER MASS FLOW FOR PREMIX PURGING, AT PURGING PROCESS 2.5 kg/s
F.EMUSPU.200 * FLOW MINIMUM WATER FLOW FOR MONITORING 6 kg/s
F.FILL.100 * PURGE WATER FLOW Water mass flow for filling (supply line) 4 kg/s -
F.FILL.101 * FLOW WATER MASS FLOW FOR FILLING 4.5 kg/s
F.HOE.011 FLOW RATIO FO FLOW RATIO (INJECTED / SUPPLIED ) FOR FO DIFF SUPPLY LINE PRESSURE LOSS PP.HOE.11 0 --- PP.HOE.11
F.HOE.012 FLOW RATIO FO FLOW RATIO (INJECTED / SUPPLIED ) FOR FO DIFF SUPPLY LINE PRESSURE LOSS PP.HOE.12 0,005 --- PP.HOE.12
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F.HOE.026 FLOW RATIO FO FLOW RATIO (INJECTED / SUPPLIED ) FOR FO DIFF SUPPLY LINE PRESSURE LOSS PP.HOE.26 1 --- PP.HOE.26
F.HOE.031 FLOW RATIO FO FLOW RATIO (INJECTED / SUPPLIED ) FOR FO RETURN LINE PRESSURE LOSS PP.HOE.31 0 PP.HOE.31
F.HOE.032 FLOW RATIO FO FLOW RATIO (INJECTED / SUPPLIED ) FOR FO RETURN LINE PRESSURE LOSS PP.HOE.32 0,005 PP.HOE.32
F.HOE.042 FLOW RATIO FO FLOW RATIO (INJECTED / SUPPLIED ) FOR FO RETURN LINE PRESSURE LOSS PP.HOE.42 0,395 % PP.HOE.42
F.HOE.043 FLOW RATIO FO FLOW RATIO (INJECTED / SUPPLIED ) FOR FO RETURN LINE PRESSURE LOSS PP.HOE.43 0,545 --- PP.HOE.43
F.HOE.046 FLOW RATIO FO FLOW RATIO (INJECTED / SUPPLIED ) FOR FO RETURN LINE PRESSURE LOSS PP.HOE.46 1 --- PP.HOE.46
F.HOE.051 KV-VALUE KV-VALUE OF FO-CV-CHARACTERISTIC AT G.OELST.21 0 m³/h G.OELST.21
F.HOE.052 KV-VALUE KV-VALUE OF FO-CV-CHARACTERISTIC AT G.OELST.22 0,741305 m³/h G.OELST.22
F.HOE.091 * MASS FLOW FO DIFFUSION INJECTION FLOW AT DIFFUSION FEEDLINE FLOW F.HOE.111 0 Kg/s F.HOE.111
F.HOE.092 * MASS FLOW FO DIFFUSION INJECTION FLOW AT DIFFUSION FEEDLINE FLOW F.HOE.112 0,5 Kg/s F.HOE.112
F.HOE.111 * MASS FLOW FO DIFFUSION FEEDLINE FLOW AT DIFFUSION INJECTION FLOW F.HOE.091 16 Kg/s F.HOE.091
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F.HOE.143 * FLOW IGNITION MASS FLOW CORRECTION AT TT.ATK.41 0,06 Kg/s
F.HOE.144 * FLOW IGNITION MASS FLOW CORRECTION AT TT.ATK.42 0,03 Kg/s
F.HOE.145 * FLOW IGNITION MASS FLOW CORRECTION AT TT.ATK.43 0 Kg/s
F.HOE.146 * FLOW IGNITION MASS FLOW CORRECTION AT TT.ATK.44 0 Kg/s
F.HOE.147 * FLOW IGNITION MASS FLOW CORRECTION AT TT.ATK.45 -0,01 Kg/s
F.HOE.148 * FLOW IGNITION MASS FLOW CORRECTION AT TT.ATK.46 -0,03 Kg/s
F.HOE.191 * MASS FLOW FO DIFFUSION INJECTION PURGING WATER FLOW AT DIFFUSION FEEDLINE FLOW F.HOE.211 0 Kg/s F.HOE.211 B
F.HOE.192 * MASS FLOW FO DIFFUSION INJECTION PURGING WATER FLOW AT DIFFUSION FEEDLINE FLOW F.HOE.212 0,5 Kg/s F.HOE.212 B
F.HOE.211 * MASS FLOW FO DIFFUSION FEEDLINE PURGING WATER FLOW AT DIFFUSION INJECTION FLOW F.HOE.191 6 Kg/s F.HOE.191 B
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F.HOEDB.001 * FLOW FO DIFFUSION FLOW AT GT START WITH FO 0,2 Kg/s
F.HOEDB.006 * FLOW FO DIFFUSION INJECTION MASS FLOW AT CONNECTION AT FUEL CHANGE OVER 0,16 Kg/s
F.HOEDB.011 KV-VALUE KV-VALUE OF FO-DIFF-FEEDLINE-VALVE AT G.OELST.41 0 m³/h
F.HOEDB.012 KV-VALUE KV-VALUE OF FO-DIFF-FEEDLINE-VALVE AT G.OELST.42 0,741305 m³/h
F.HOEDB.033 * MASS FLOW FO DIFFUSION INJECTION MASS FLOW AT DISCONNECTION AFTER FUEL CHANGE OVER 0,5 kg/s
F.HOEDB.100 * MASS FLOW FO ADDITIONAL MASS FLOW AT GT START WITH FO 0 Kg/s
F.HOEDB.104 * MASS FLOW FO MIN FLOW DURING FO DIFFUSION MODE 0,5 Kg/s
F.HOEDB.105 * MASS FLOW FO MIN DIFFUSION FLOW DURING FO PREMIX MODE 0,5 Kg/s
F.HOEDB.106 * MASS FLOW FO DIFFUSION MINIMUM MASS FLOW AT G.VLE0.220 2 Kg/s
F.HOEDB.107 * MASS FLOW FO DIFFUSION MINIMUM MASS FLOW AT G.VLE0.221 2,2 Kg/s
F.HOEVB.001 * FUEL OIL MASS FLOW FO MIN PREMIX FLOW AT SWITCH OVER FROM FO DIFFUSION TO FO PREMIX 1,5 kg/s -
F.HOEVB.003 MASS FLOW FO PREMIX MINIMUM FLOW AT DISCONNECTION 2,9 Kg/s
F.HOEVB.011 KV-VALUE KV-VALUE OF FO-PREMIX-VALVE AT G.OELST.61 0 m³/h G.OELST.61
F.HOEVB.012 KV-VALUE KV-VALUE OF FO-PREMIX-VALVE AT G.OELST.62 0,741305 m³/h G.OELST.62
F.LSV.01 FLOW RATIO COMPRESSOR CHARACTERISTIC: COORDINATE FOR MASS FLOW 55 % S.NSTERN
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F.PILOT.001 KV-VALUE KV-VALUE AT G.PILOT.026 0 m³/h G.PILOT.026 B
F.PILOT.002 KV-VALUE KV-VALUE AT G.PILOT.027 0,696671 m³/h G.PILOT.027 B
F.PILOT.026 * MASS FLOW NG PILOT ADDITION AT FUEL CHANGE OVER 0,4 Kg/s B
F.PILOT.027 * MASS FLOW UPPER LIMIT PILOTGAS FLOW, NORMAL FACTOR FOR 100% PILOT GAS MASS FLOW 3,4 kg/s
F.PILOT.028 MASS FLOW LOWER LIMIT PILOTGAS FLOW 0 kg/s B
F.PILOT.039 * MASS FLOW PILOTGASFLOW FOR NG-PREMIX AT G.VLE0.008 1,05 kg/s G.VLE0.008 B
F.PILOT.063 MASS FLOW PILOT GAS MASS FLOW AT CHANGE-OVER FROM FO TO FG WITH IGV G.VLE0.024 0,5 kg/s G.VLE0.024
F.PILOT.070 * MASS FLOW PILOT GAS FLOW (IGV FULLY CLOSED) FOR NG-PREMIX AT TT.ATK.70 1,25 kg/s TT.ATK.070 B
F.PILOT.071 * MASS FLOW PILOT GAS FLOW (IGV FULLY CLOSED) FOR NG-PREMIX AT TT.ATK.71 1,15 kg/s TT.ATK.071
F.PILOT.075 * MASS FLOW PILOT GAS FLOW (IGV FULLY CLOSED) FOR NG-PREMIX AT TT.ATK.75 0 kg/s TT.ATK.075
F.PILOT.086 * MASS FLOW MINIMUM PILOTGASFLOW AT LOAD REJECTION WITH IGV AT G.VLE0.051 2,18 kg/s G.VLE0.051
F.PILOT.130 * MASS FLOW S080U -dPilot gas mass flow uploading with G.VLE0.090 0 kg/s G.VLE0.090 B
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F.PILOT.140 * MASS FLOW S080D- dPilot gas mass flow - download with G.VLE0.101 0 kg/s G.VLE0.101 B
F.PILOT.151 * MASS FLOW FPCRO - dPilot mass flow with Wobbe Index Q.WBI.01 -0,03 kg/s Q.WBI.01 B
F.PILOT.152 * MASS FLOW FPCRO - dPilot mass flow with Wobbe Index Q.WBI.02 -0,011 kg/s Q.WBI.02 B
F.PILOT.153 * MASS FLOW FPCRO - dPilot mass flow with Wobbe Index Q.WBI.03 0 kg/s Q.WBI.03 B
F.PILOT.154 * MASS FLOW FPCRO - dPilot mass flow with Wobbe Index Q.WBI.04 0 kg/s Q.WBI.04 B
F.PILOT.155 * MASS FLOW FPCRO - dPilot mass flow with Wobbe Index Q.WBI.05 0,03 kg/s Q.WBI.05 B
F.PILOT.156 * MASS FLOW FPCRO - dPilot mass flow with Wobbe Index Q.WBI.06 0,038 kg/s Q.WBI.06 B
F.PILOT.157 * MASS FLOW PCI - dPilot mass flow with PCI Q.PCI.01 0 kg/s Q.PCI.01 B
F.PILOT.192 MASS FLOW CORRECTION OF PILOT MASS FLOW AT TEMPERATURE T.VI.26 0,1 kg/s T.VI.26
F.PILOT.195 MASS FLOW CORRECTION OF PILOT MASS FLOW AT TEMPERATURE T.VI.29 0 kg/s T.VI.29
F.PILOT.196 MASS FLOW CORRECTION OF PILOT MASS FLOW AT TEMPERATURE T.VI.30 -0,045 kg/s T.VI.30
F.PILOT.197 MASS FLOW CORRECTION OF PILOT MASS FLOW AT TEMPERATURE T.VI.31 -0,06 kg/s T.VI.31
F.PILOT.259 KV-VALUE PILOTGAS-BURNER, KV-VALUE OF ONE SINGLE BURNER 1,73 m³/h B
F.PILOT.260 KV-VALUE PILOTGAS SYSTEM, KV-VALUE OF PIPING 70 m³/h B
F.PURGE.100 KV-VALUE KV VALUE AT G.PURGE.100 0,0159 m³/h G.PURGE.100 B
F.SPUDB.01 * MASS FLOW PURGE WATER MASS FLOW FOR FO DIFFUSION PURGING 1 Kg/s B
F.SPUDB.02 * MASS FLOW PURGE WATER MASS FLOW AT COMPRESSOR DISCHARGE PRESSURE P.VII.23 1 Kg/s P.VII.23
G.ANTICE.100 CTR VLV POSITION ANTI-ICING CONNECTION POSITION 3 %
G.ANTICE.101 CTR VLV POSITION ANTI-ICING CONNECTION POSITION 7 %
G.ANTICE.201 CTR VLV POSITION MINIMUM POSITION FOR ANTI-ICING CONTROL VALVE 3 %
G.EGVBST.01 CTR VLV POSITION POSITION CORRECTION CALCULATOR, NG-PREMIX-CV POSITION AT F.EGVB.002 2 % F.EGVB.02 B
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G.HOEDB.100 CTR VLV POSITION FO DIFFUSION RETURN LINE FLUSHING POSITION DURING MANUAL OPERATION 20 %
G.HSO.01 POSITION NULL POSITION OF SHAFT, I.E. RDS DEACTIVATED 1,25 0,7 mm B
G.HSO.02 POSITION MAIN POSITION OF SHAFT, I.E. RDS ACTIVATED 2,5 -0,7 mm B
G.OELST.021 CTR VLV POSITION POSITION FO RETURN CONTROL VALVE AT F.HOE.051 0 % F.HOE.051
G.OELST.041 CTR VLV POSITION POSITION FO-DIFF-FEEDLINE-CONTROL VALVE AT F.HOEDB.011 0 % F.HOEDB.011
G.OELST.061 CTR VLV POSITION POSITION FO-PREMIX-CONTROL VALVE AT F.HOEVB.011 0 % F.HOEVB.011
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G.PILOT.026 CTR VLV POSITION POSITION CORRECTION CALCULATOR, NG PG-CV POSITION AT F.PILOT.001 2 % F.PILOT.001 B
G.PURGE.100 CTR VLV POSITION POSITION PURGE WATER CONTROL VALVE AT F.PURGE.100 6,9 % F.PURGE.100
G.VLE0.001 IGV POSITION IGV POSITION FULLY CLOSED (AT BETA-BI ANGLE G.VLE0.15) 0 % G.VLE0.015
G.VLE0.002 IGV POSITION IGV POSITION FULLY OPEN (AT BETA-BI ANGLE G.VLE0.16) 100 % G.VLE0.016
G.VLE0.008 IGV POSITION IGV POSITION FOR NG PREMIX MODE PILOT GAS FLOW F.PILOT.039 0 % F.PILOT.039 B
G.VLE0.015 ** IGV POSITION BETA-BI-ANGLE OF COMPR. IGV MIN-OPERATION-POSITION (0%) - REFERENCE VALUE 53,7 °
G.VLE0.016 ** IGV POSITION BETA-BI-ANGLE OF COMPR. IGV MAX-OPERATION-POSITION (100%) - REFERENCE VALUE 7,7 °
G.VLE0.021 IGV POSITION IGV POSITION>MINIMUM RELEASE FREQ INFLUENCE NORM GRAD 2 %
G.VLE0.022 IGV POSITION IGV OPEN FREQ INFLUENCE SLOW GRAD 95 %
G.VLE0.023 IGV POSITION UPPER LIMIT FOR CHANGE OF MAX. FREQUENCY GRADIENT (IGVS OPEN) 98 -4 %
G.VLE0.024 IGV POSITION IGV POSITION AT FUEL CHANGE-OVER FOR F.PILOT.063 10 % F.PILOT.063
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G.VLE0.038 IGV POSITION IGV POSITION, LOWER LIMIT FOR FUEL CHANGE OVER 10 -1 %
G.VLE0.039 IGV POSITION IGV POSITION, UPPER LIMIT FOR FUEL CHANGE OVER 40 -1 %
G.VLE0.044 IGV POSITION RELEASE FOR THE LIMIT GW4 S.ACC.07 95 % S.ACC.07
G.VLE0.045 IGV POSITION IGV POSITION FOR PG FLOW F.PILOT.86 AND PREMIX MIN FLOW F.EGVB.028 0 % F.EGVB.028
G.VLE0.051 IGV POSITION Load Rejection, IGV POSITION FOR PG FLOW F.PILOT.086 0 % F.PILOT.086
G.VLE0.057 IGV POSITION IGV position reference for CV.VLE0.001 0 % G.VLE1.001 B
G.VLE0.090 * IGV POSITION S080U -Correction point f(IGV) for F.PILOT.130 0 % F.PILOT.130 B
G.VLE0.100 IGV POSITION IGV POSITION TO ACTIVATE COOLING AIR 3 CONTROL 50 %
G.VLE0.101 IGV POSITION IGV POSITION FOR TETC REDUCTION TT.ATK.D131 0 % TT.ATK.D131 B
G.VLE0.200 IGV POSITION IGV POSITION MAXIMUM VALUE FOR CHANGE OVER FROM FO DIFF TO FO PREMIX 10 %
G.VLE0.202 IGV POSITION Minimum IGV position for pre-heating ON 20 B
G.VLE0.220 IGV POSITION IGV POSITION FOR F.HOEDB.106 0 % F.HOEDB.106
G.VLE0.521 IGV POSITION IGV POSITION (for SINGLE SHAFT) FOR GV2 PRESSURE RATIO PP.TLE2.11 % PP.TLE2.11 B
G.VLE1.001 IGV POSITION CV1 position for IGV position G.VLE0.057 0 % G.VLE0.057
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GK.ANTEIL.001 GRADIENT FUEL PERCENTAGE CHANGE GRADIENT DURING CHANGE FROM OIL TO GAS 1,5 %/s
GK.ANTEIL.101 GRADIENT FUEL PERCENTAGE CHANGE GRADIENT DURING CHANGE FROM GAS TO OIL 1,5 %/s
GK.VLE0.103 GRADIENT IGV SPEED ADJUSTMENT, MAX SPEED IN AUTO MODE 15 %/s
H.AMB.01 HUMIDITY HUMIDITY POINT FOR TETC DERATING TABLE (WITH T.VI) 0 % T.VI.200-T.VI.205
H.AMB.05 HUMIDITY HUMIDITY POINT FOR TETC DERATING TABLE (WITH T.VI) 85 % T.VI.200-T.VI.209 B
H.AMB.06 HUMIDITY HUMIDITY POINT FOR TETC DERATING TABLE (WITH T.VI) 100 % T.VI.200-T.VI.210 B
J.BRENNST.20 THERMAL LOAD THERMAL LOAD AT J.HOEANT.01 25 % J.HOEANT.01
CONVERSION FACTOR FUEL MASS FLOW TO THERMAL POWER - REFERENCE VALUE (REVERSE OF %/
J.EG.01 ** FACTOR 5,35 B
J.EG.02) (kg/s)
(kg/s) /
J.EG.02 FACTOR CONVERSION FACTOR THERMAL POWER TO FUEL MASS FLOW 0.187
%
J.EG.04 * THERMAL LOAD LIMITING FUNCTION, STARTUP WITH NG, 1.POINT OF CHARACTERISTIC 1 %
J.EGANT.100 PROPORTION PREMIX PROPORTION AT S.TURB.300 20 % S.TURB.300 B
NG-PREMIX PROPORTION TO BE ADDED AFTER LOAD REJECTION WHEN TETC IS 300°C at
J.EGVB.01 * PROPORTION 1,42 % TT.ATK.087
TT.ATK.087
TT.ATK.088
TT.ATK.089
TT.ATK.090
J.EGVB.05 * PROPORTION 1 % TT.ATK.091
TT.ATK.091
J.EGVB.06 * PROPORTION 1 % TT.ATK.092
TT.ATK.092
(kg/s) /
J.HOE.02 PROPORTION PROPORTIONAL FACTOR FIRE OUTPUT-FO MASS FLOW 0,187
%
J.HOE.03 PROPORTION LIMITING FUNCTION, STARTUP WITH FO, FIRE OUTPUT AT S.TURB.112 1 % S.TURB.112
J.HOEANT.01 * PROPORTION PROPORTION FO-PREMIX OF THERMAL LOAD AT J.BRENNST.20 95 %
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J.HSO.01 LOAD MAX ALLOWED LOAD REDUCTION WITH RDS ON 27 MW
THERM. LOAD
JK.EGDB.01 * 1. GRADIENT THERMAL LOAD AT START UP WITH NG (NG-DIFF-CV) AT S.TURB.53 1.9 %/min
GRADIENT
THERM. LOAD
GRADIENT
THERM. LOAD
JK.EGDB.03 * 1. GRADIENT THERMAL LOAD AT BLACK START WITH NG (NG-DIFF-CV) 2.2 %/min
GRADIENT
THERM. LOAD
JK.EGDB.04 * 2. GRADIENT THERMAL LOAD AT BLACK START WITH NG (NG-DIFF-CV) 5.5 %/min
GRADIENT
THERM. LOAD
JK.EGDB.041 * 3. GRADIENT THERMAL LOAD AT BLACK START UP WITH NG (NG-DIFF-CV) 7.5 %/min
GRADIENT
THERM. LOAD
GRADIENT
THERM. LOAD
GRADIENT
THERM. LOAD
JK.EGDB.06 3. GRADIENT THERMAL LOAD AT BLACK START WITH NG (NG-DIFF-CV) AT S.TURB.541 7,5 %/min
GRADIENT
THERM. LOAD
JK.EGDB.062 4. GRADIENT THERMAL LOAD AT BLACK START WITH NG (NG-DIFF-CV) AT S.TURB.542 7,5 %/min
GRADIENT
THERM. LOAD
JK.HOEDB.01 * 1. GRADIENT THERMAL LOAD AT START UP WITH FO (FO-DIFF-CV) AT S.TURB.55 1.9 %/min
GRADIENT
THERM. LOAD
JK.HOEDB.02 * 2. GRADIENT THERMAL LOAD AT START UP WITH FO (FO-DIFF-CV) AT A.TURB.56 2.2 %/min
GRADIENT
THERM. LOAD
JK.HOEDB.03 * 1. GRADIENT THERMAL LOAD AT START UP WITH FO (FO-DIFF-CV), BLACK START 1.54 %/min
GRADIENT
THERM. LOAD
JK.HOEDB.04 * 2. GRAD. THERMAL LOAD AT START UP WITH FO (FO-DIFF-CV), BLACK START 3.56 %/min
GRADIENT
THERM. LOAD
JK.HOEDB.05 * 3. GRADIENT THERMAL LOAD AT START UP WITH FO (FO-DIFF-CV) AT S.TURB.561 3.56 %/min
GRADIENT
THERM. LOAD
JK.HOEDB.06 * 3. GRADIENT THERMAL LOAD AT START UP WITH FO (FO-DIFF-CV), BLACK START 3,56 %/min
GRADIENT
JK.HSO.01 LOAD GRADIENT MAX ALLOWED LOAD GRADIENT FOR J.HSO.01 WITH RDS ON 27 MW/min B
THERM. LOAD
JK.HSO.02 MAX ALLOWED THERMAL LOAD GRADIENT FOR J.HSO.01 WITH RDS ON 2,55 %min B
GRADIENT
K.ABBL.02 TIME DELAY BLOW OFF AT FO START UP 60 s
K.ACC.01 TIME COMBUSTION CHAMBER ACCELERATION LIMIT 1, DELAY TIME FOR LOAD REDUCTION 4 s
COMBUSTION CHAMBER ACCELERATION LIMIT 2, DELAY TIME FOR LOAD REDUCTION, NG
K.ACC.02 TIME 1 s
OPERATION
COMBUSTION CHAMBER ACCELERATION LIMIT 2, DELAY TIME FOR LOAD REDUCTION, FO
K.ACC.03 TIME 2 s
OPERATION
K.ACC.04 TIME COMBUSTION CHAMBER ACCELERATION LIMIT 3, DELAY TIME FOR GT TRIP 0 s
K.ACC.05 TIME C.C. ACCELERATION DELAY TIME AT SWITCH OVER FG-DB « FG-DB/VB-MB « FG-VB 2 s
K.ACC.06 TIME C.C ACCELERATION DELAY TIME AT SWITCH OVER FO-DB « FO-VB 2 s
K.ACC.07 TIME C.C. ACCELERATION DELAY TIME FOR GW1 AT CONNEC./DISCONNEC. OF WATER IN HD EMULSION 12 s B
K.ACC.08 TIME C.C. ACCELERATION DELAY TIME FOR GW2 AT CONNEC./DISCONNEC. OF WATER IN HD EMULSION 10 s B
COMBUSTION CHAMBER ACCELERATION LIMIT 4, DELAY TIME FOR LOAD REDUCTION, NG
K.ACC.09 TIME 0,5 s
OPERATION
K.AIRFILT.01 * TIME DELAY TIME DELAY BEFORE ACTIVATING GT SHUT DOWN AT P.AIRFILT.03 600 s
K.AIRFILT.02 TIME DELAY TIME DELAY BEFORE ACTIVATING GT RUNBACK AT P.AIRFILT.03 10 s
K.ANTEIL.01 * TIME CHANGEOVER TIME NG-DIFF -> NG-PREMIX 33 %/s
K.ANTEIL.02 * TIME CHANGEOVER TIME NG-PREMIX -> NG-DIFF 33 %/s
K.ANTEIL.09 * TIME CHANGEOVER TIME FO-DIFF -> FO-PREMIX 60 s
K.ANTEIL.10 TIME TIME FOR RAMP FROM FO PREMIX TO FO DIFFUSION 60 s
K.ANTEIL.100 TIME DELAY Time delay for inhibition TRIP during Fuel C/O 5 s
K.ANTEIL.12 TIME TIME FOR FAST SWITCH BACK FROM FO PREMIX TO DIFFUSION AT LOAD REJECTION 0,7 s
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K.ANTEIL.17 TIME DELAY TIME FROM THE OPENING OF THE FO ESV BEFORE THE START OF THE TRANFER RAMP 5 s
K.ANTEIL.21 TIME ADDITIONAL TIME BEFORE FUEL REDISTRIBUTION (FO-->FG) 5 s B
K.ANTEIL.22 TIME WAITING TIME BEFORE NG PREMIX CV CLOSING AT NG DISCONNECTION 5 s
K.ANTEIL.23 TIME FILLING TIME OF FO DIFFUSION PIPES AT FO CONNECTION 10 s B
K.ANTEIL.24 TIME DELAY TIME FOR FO MINIMUM MASS FLOW 10 s
K.ANTICE.201 TIME DELAY TIME DELAY BEFORE GT SHUT DOWN IF ANTI-ICING NOT ON WHEN REQUIRED 1200 s
K.BELEUFT.01 TIME TIME FOR BOILER PURGING 600 s
K.BRACC.104 TIME COMBUSTION CHAMBER ACCELERATION LIMIT 4, DEALY TIME FOR GT TRIP, FO OPERATION 11 s
COMBUSTION CHAMBER ACCELERATION LIMIT 1, DELAY TIME FOR LOAD REDUCTION, FO
K.BRUMM.01 TIME 4 s
OPERATION
K.BRUMM.03 TIME COMBUSTION CHAMBER ACCELERATION LIMIT 1, DELAY TIME FOR GT TRIP, NG OPERATION 15 s
K.BRUMM.04 TIME COMBUSTION CHAMBER ACCELERATION LIMIT 2, DELAY TIME FOR GT TRIP, NG OPERATION 12 s
K.BRUMM.05 TIME COMBUSTION CHAMBER ACCELERATION LIMIT 1, DELAY TIME TO REPEAT LOAD JUMPS 4 s
K.BRUMM.08 TIME COMBUSTION CHAMBER ACCELERATION LIMIT 1, REPEAT TIME FOR LOAD JUMPS 3 s
COMBUSTION CHAMBER ACCELERATION LIMIT 1, DELAY TIME (+K.ACC.01) FOR GT TRIP, FO
K.BRUMM.09 TIME 15 s
OPERATION
K.BRUMM.112 TIME DELAY FOR BAD QUALITY BOTH ACCELERATION SIGNALS (ANALOGIC) 1 s B
EXTENSION OF INTERLOCK OF HUMMING/ACCELERATION MONITORING AFTER FO
K.BRUMM.19 TIME 60 s
DISCONNECTION AT FUEL CHANGE OVER
K.BRUMM.20 TIME DELAY TIME FOR LIMIT 1 AND LIMIT 2 AFTER FUEL CHANGE OVER END 10 s
K.BRUMM.21 TIME C.C. HUMMING GW1, DELAY TIME AT WATER SYSTEM CONNECT/DISCONNECT. IN HD EMULSION 12 s B
K.BRUMM.212 TIME DELAY FOR BAD QUALITY BOTH ACCELERATION SIGNALS (DIGITAL) 2 s
K.CHANGE.100 TIME TIME DELAY FOR OPENING FG-PREMIX CV AT FUEL CHANGE OVER 9 s
K.DRAIN.1 TIME Delay time for FO Premix drain valve trip after valve opening (with flame on) 15 s B
K.EGDB.02 TIME DO PIPE FILLING TIME AT CONNECTION FROM PO 3 s
K.EGDB.03 TIME DO BALANCE TIME AT DO CONNECTION 2 s
K.EGDB.04 TIME DO BALANCE TIME AT DO DISCONNECTION 0 s
K.EGVB.01 TIME PO PIPE FILLING TIME AT CONNECTION IN PO 3 s
K.EGVB.02 TIME FIRST ORDER CONSTANT TIME FOR NG MINIMUM BALANCING 2 s
K.EGVB.03 TIME PO BALANCE TIME AT PO DISCONNECTION 0 s
K.EGVB.300 TIME DELAY TIME BEFORE FUEL TRANSFER 14 s
K.EMUSPU.100 * TIME TIME FOR PREMIX COOLING 40 s B
K.EMUSPU.101 * TIME WAITING TIME BEFORE FINAL TRANSFER TO FO PREMIX 55 s B
K.EMUSPU.102 * TIME PURGING TIME AFTER CHANGE OVER FO PREMIX TO DIFFUSION 20 s
K.EMUSPU.103 * TIME TIME FOR FO PREMIX PURGING 20 s
K.ENTOEL.01 TIME REQUIRED MINIMUM TIME FOR DRAINING BETWEEN TWO SEQUENTIAL GT START UP. 300 s
K.EXH.01 TIME TIME DELAY BEFORE SHUTDOWN FOR HIGH DIFFERENTIAL PRESSURE ON EXHAUST DIFFUSER 60 s
K.FILL.01 TIME RELEASE FOR FO DIFFUSION DIFFERENTIAL PRESSURE MONITORING AT GT START 7 s
K.FILL.02 TIME RELEASE FOR FO DIFFUSION DIFFERENTIAL PRESSURE MONITORING AT FUEL CHANGE OVER 13 s
K.FILL.03 TIME RELEASE FOR FO PREMIX DIFFERENTIAL PRESSURE MONITORING AT SWITCH OVER TO FO PREMIX 7 s
K.FILL.100 TIME RELEASE FOR FO-DO DIFFERENTIAL PRESSURE MONITORING AT GT START 7 s
K.FILL.101 TIME RELEASE FOR FO-DO DIFFERENTIAL PRESSURE MONITORING AT FUEL CHANGE OVER 13 s
K.FILL.102 TIME RELEASE FOR FO-PO DIFFERENTIAL PRESSURE MONITORING AT FO PREMIX SWITCH OVER 7 s
K.FLAMM.01 TIME DELAY FOR ALARM IF FLAME NOT PRESENT 13 s
TIME DELAY BETWEEN FO-DIFF-FEED ESV AND FO-RET ESV CLOSURE IN CASE OF GT TRIP OF SHUT
K.HOE.01 TIME 1 s
DOWN
TIME BEFORE DIFFUSION BALANCING AT FO CONNECTION (FROM THE OPENING OF THE STOP
K.HOEDB.01 * TIME 3,5 s
VALVES, FILLING TIME)
K.HOEDB.03 * TIME FIRST ORDER DELAY TIME CONSTANT FOR FO DIFFUSION MINIMUM FLOW BALANCING 7 s
K.HOEDB.06 * TIME ACTIVE TIME FOR THE FO DIFFUSION MINIMUM FLOW AT PURGING 5 s
K.HOEDB.07 * TIME DELAY TIME FOR FO DIFFUSION PURGING 0,3 s
TIME BEFORE PREMIX BALANCING AT FO PREMIX CONNECTION (FROM THE OPENING OF THE
K.HOEVB.03 * TIME 3,5 s
STOP VALVES, FILLING TIME)
K.HOEVB.04 * TIME FO PREMIX DISCONNECTION MASS FLOW COMPENSATION TIME CONSTANT 0,1 s
K.HOEVB.05 * TIME FIRST ORDER DELAY TIME CONSTANT FOR FO PREMIX MINIMUM FLOW BALANCING 7 s
K.HOEVB.08 * TIME TIME CONSTANT FOR FO PREMIX MINIM FLOW BALANCING AT PIPING PURGING 0,5 s
K.HOEVB.11 * TIME ACTIVE TIME FOR THE FO PREMIX INJECTED FLOW AT PURGING 3,5 s
FIRST ORDER DELAY TIME CONSTANT FOR FO DIFFUSION MINIMUM FLOW BALANCING AT
K.HOEVB.200 * TIME 7 s
E.LEISTP.00
K.HOEVB.201 * TIME FIRST ORDER DELAY TIME CONSTANT FOR FO DIFFUSION MINIMUM FLOW BALANCING AT 5 s
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E.LEISTP.01
K.HOEVB.202 * TIME 2 s
E.LEISTP.02
K.HOEVB.203 * TIME 0,5 s
E.LEISTP.03
K.HSO.01 TIME VENTING AND PURGING TIME RDS SYSTEM BEFORE GT START 30 s
K.HSO.03 * TIME MAX TIME TO FILL THE RDS ACCUMULATOR 30 s
K.HSO.04 TIME GT MINIMUM OPERATING TIME BEFORE IT IS POSSIBLE TO ACTIVATE THE RDS SYSTEM 1 h
K.HSO.05 TIME MAX TIME TO SHIFT THE ROTOR WHEN ACTIVATING THE RDS 18 s
K.HSO.06 TIME TIME INTERVAL AFTER WHICH THE ACTIVATED RDS CHANNEL MUST BE FLUSHED 12 h
K.HSO.07 * TIME MIN TIME TO FILL THE RDS ACCUMULATOR 18 s
K.HSO.08 TIME MIN TIME TO FLUSH THE MAIN LINE (RDS) 20 s
K.HSO.09 * TIME MAX TIME FOR PRESSURE SWITCH TO BE PRESSURIZED AFTER SWITCH-ON RDS PUMPS 5 s
K.HSO.10 * TIME MIN TIME TO MOVE THE ROTOR 2 s
K.HSO.11 * TIME MAX TIME TO SHIFT THE ROTOR WHEN DE-ACTIVATING THE RDS 18 s
K.HSO.12 * TIME MONITORING TIME FOR PRESSURE DROP WHICH MAY OCCUR IN THE RDS SYSTEM 10 h
K.HSO.13 * TIME MIN TIME TO FLUSH THE SECONDARY LINE (RDS) 15 s
K.LAW.03 * TIME DELAY TIME BEFORE FO PREMIX SWITCH OFF AT LOAD REJECTION 0,2 s
K.LAW.05 TIME MAINTENING TIME OF LOAD REJECTION SIGNAL 70 s
K.LAW.100 TIME TIME FOR FO DIFFUSION MINIMUM SELECTION AT LOAD REJECTION (PULSE TIME) 35 s
K.LAW.300 * TIME TIME DELAY FOR DEACTIVATING RDS AFTER LOAD REJECTION 8 s
K.LECKOEL.01 TIME TIME DELAY FOR LEAKAGE OIL PRESSURE MONITORING 30 s B
K.LECKOEL.02 TIME TIME DELAY FOR POSITION MONITORING OF THE LEAKAGE OIL VALVES 3 s
K.LEER.01 * TIME FO PREMIX DRAIN VALVES OPEN AFTER GT TRIP FROM FO PREMIX - 1° PHASE 30 s
K.LEER.07 TIME FO PREMIX DRAIN VALVES OPEN AT LOAD REJECTION FROM FO-PREMIX 10 s B
K.LEER.09 * TIME WAITING TIME BEFORE OPENING OF THE FO PREMIX DRAINS AFTER K.LEER.08 15 s
K.LEER.100 * TIME FO PREMIX DRAIN VALVES OPEN DURING PREMIX PURGING - COLLECTOR PURGING 5 s
K.LEER.101 * TIME FO PREMIX DRAIN VALVES OPEN DURING PREMIX PURGING - PREMIX LINE PURGING 15 s B
K.LEER.102 * TIME FO PREMIX DRAIN VALVES OPEN AFTER PREMIX PURGING 10 s
K.LIFT.100 TIME DELAY TIME TO DEENERGIZE PUMP SOLENOID VALVES 4 s
K.PILOT.15 TIME HOLDING TIME OF INCREASED PILOTA MASS FLOW 100 s
K.PRAL.01 TIME TV P-CONTROLLER ANTICIPATION TIME 1 s
K.PRAL.02 TIME TN P-CONTROLLER CORRECTION TIME 2 s
K.PRAL.04 TIME TN COOLING AIR LIMIT CONTROLLER 6 s
K.PSF.02 * TIME MIN OPERATION TIME OF GT FOR FREQUENCY INFLUENCE (WARM GT) 2 h
MAX TIME, ON WHICH THE GENERATOR SWITCH MAY REMAIN OPEN, WITHOUT LOSING THE
K.PSF.03 TIME 300 s
RELEASE FOR THE FREQUENCY INFLUENCE
K.PSF.102 * TIME TIME DELAY OF END OF GT WARM FOR FREQUENCY INFLUENCE 2 h
K.PUMP.01 TIME DELAY FOR ACTIVATION TRANSMITTER MONITORING FOR SURGE PROTECTION 30 s
K.PURGE.01 * TIME DELAY FOR FO DRAIN VALVES OPENING DURING MANUAL PURGING 35 s B
K.PURGE.02 * TIME OPENING TIME FOR FO DRAIN VALVES DURING BACKPURGING 25 s B
K.PURGE.03 * TIME CLOSING TIME FOR PO RING SHUTOFF VALVE 20 s B
K.PURGE.04 * TIME DELAY BETWEEN PO RING SHUTOFF VALVE AND FO DRAIN VALVE 1 s B
K.PURG.100 TIME TIME DELAY FOR FO-DIFF SEAL VLV OPEN COMMAND 5 s
K.PURG.101 TIME TIME DELAY FOR FO-DIFF SEAL VLV CLOSED COMMAND 5 s
K.PURGPO.01 TIME DELAY TIME BEFORE START OF FO PREMIX MINIMUM FLOW BALANCING AT PIPING PURGING 0,5 s
reset/mi
K.REGLER.01 TIME INTEGRAL CONSTANT LOAD CONTROLLER (KI) 8
n
reset/mi
K.REGLER.101 TIME INTEGRAL CONSTANT SPEED CONTROLLER (KI) 12
n
K.SCHMOEL.01 TIME DELAY FOR THE SIGNAL LUBE OIL FEED LINE TEMPERATURE HIGH 2 s
K.SCHMOEL.02 TIME ALARM IF EMERGENCY LUBE OIL PUMP OPERATES LONGER THAN THIS TIME 30 s
K.SCHMOEL.03 TIME MONITORING TIME FOR PUMP CHECK AND ECO RELAY OFF 5 s
K.SCHMOEL.04 TIME TIME FOR LUBE OIL PRESSURE STABILIZING AFTER PUMP ON COMMAND 10 s
K.SCHMOEL.05 TIME DELAY ACTIVATION OF SIGNALS FROM MBV21CP001 AND MBV26CP101 3 s
K.SCHMOEL.06 TIME Monit.-time for turning-operation for rising of lube- and lift-oil pressure 10 s
K.SCHMOEL.07 TIME DELAY TIME TO MONITORING THE LIFTING OIL SYSTEM 5 s
K.SCHMOEL.08 TIME DELAY FOR S.TURB.02, ENSURES SAFE GT SHAFT STANDSTILL 600 s
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K.SPUDB.01 TIME PURGING TIME FOR FO DIFFUSION BURNERS AFTER FO TRIP 80 s B

K.SPUDB.02 TIME PURGING TIME FOR FO DIFFUSION BURNERS AFTER FO TRIP 18 s B
K.SPUDB.06 TIME TIME OIL-WATER OVERLAPPING 1 s
K.SPUDB.08 TIME TIME BEFORE CLOSING OF FO SUPPLY LINE VALVES 3 s
K.SPUVB.01 TIME PURGING TIME FOR FO PREMIX BURNERS NOZZLES COOLING BEFORE SWITCH TO PREMIX 80 s B
K.SPUVB.02 TIME PURGING TIME FOR FO PREMIX BURNERS NOZZLES AFTER SWITCH BACK TO DIFFUSION 70 s
K.SPUVB.03 TIME DELAY FOR PO BURNERS PURGING AT LOAD REJECTION IN PO 8 s
K.SPUVB.04 TIME PURGING TIME FOR FO PREMIX BURNERS NOZZLES COOLING BEFORE SWITCH TO PREMIX 15 s B
K.SPUVB.08 TIME WAITING TIME BEFORE PREMIX LINES PURGING 100 s
K.TLE.01 TIME OPERATING TIME OF COOLING AIR VALVES 50 s
K.TLE2.01 TIME DELAY TIME, COOLING AIR VALVE STAGE 2 OPEN 10 s
K.TLE2.02 TIME delay time for protection actuation of the shutdown program, PP.TLE2.02 30 s
K.TLE2.03 TIME delay time PP.TLE2.03 300 s
K.TLE3. 01 TIME delay time protection – open, PP.TLE3.02 10 s
K.TLE3.02 TIME delay time for protection actuation of the shutdown program, PP.TLE3.02 30 s
K.TLE3.03 TIME delay time PP.TLE3.03 300 s
K.TURN.01 TIME TIME FOR TURNING-OPERATION AFTER CLOSING OF INTAKE DAMPER 22 h
K.TURN.02 TIME TIME BETWEEN TWO INTERVAL-TURNING-OPERATION-EVENTS 6 h
K.TURN.03 TIME MONIT.-TIME FOR TURNING-OPERATION 24 h
K.TURN.04 TIME FIRST PERIOD OF TURNING TIME, INTAKE DAMPER CLOSING AND COOLER OFF 2 h
K.TURN.06 TIME MONITORING TIME, INTERVAL TO REACH S.TURB.02 120 s
K.TURN.10 TIME CORRECTION TIME FLOW RATE CONTROL VALVE FROM MIN TO MAX. FLOW RATE 60 s
K.TURN.101 TIME TIME FOR TURNING-OPERATION WITH SFC (EMERGENCY COOLING) 24 h
K.VALV.01 TIME DELAY Time delay before CV FAULT - GT TRIP 5 s
K.VALV.02 TIME DELAY Time delay before CV POSITION ERROR 1,5 s
K.VALV.03 TIME DELAY Time delay before CV ALARM 0,25 s
K.VI.01 TIME TIME FOR MEASURING VALUE UPDATING 600 s
K.VLE.100 * TIME DELAY FOR CONTROL INTERRUPTION IN CASE OF BLACK OUT OR FIRE PROTECTION 30 s
K.VLE.105 * TIME DELAY FOR CONTROL DEVIATION 5 s
L.HYD.02 LEVEL Alarm “HYDRAULIC OIL LEVEL < MIN” (or with MBX02CL001-S01) 290 mm B
L.HYD.04 LEVEL “Switching off of both pumps (2v3 MBX01CL001-S01, CL002-S02) 380 mm B
L.LECKOEL.01 LEVEL FUEL OIL DRAINAGE TANK LEVEL FOR PUMP STARTUP 140 mm
L.LECKOEL.02 LEVEL FUEL OIL DRAINAGE TANK LEVEL FOR PUMP STOP 200 mm
L.LECKOEL.03 LEVEL FUEL OIL DRAINAGE TANK LEVEL FOR VERY HIGH LEVEL PROTECTION 100 mm
L.SCHMOEL.01 LEVEL VERY LOW LEVEL IN LUBE OIL TANK (LEVEL << MIN, MIN 2), GT TRIP > 540 mm
L.SCHMOEL.02 LEVEL LOW LEVEL IN LUBE OIL TANK (LEVEL < MIN, MIN 1), ALARM > 490 mm
L.SCHMOEL.03 LEVEL HIGH LEVEL IN LUBEOIL TANK (LEVEL > MAX, MAX 1), ALARM < 290 mm
L.SCHMOEL.04 LEVEL VERY HIGH LEVEL IN LUBE OIL TANK (LEVEL >> MAX, MAX 2), GT TRIP < 240 mm
L.SCHMOEL.05 LEVEL VERY LOW LEVEL IN LUBE OIL TANK, (LEVEL << MIN, MIN 3), PUMPS SWITCH OFF > 790 mm
L.SPUEL.01 LEVEL PURGING WATER LEVEL LOW, START REFILLING 1500 10 mm
L.SPUEL.02 LEVEL PURGING WATER LEVEL TOO LOW, PUMP PROTECTION 200 10 mm
L.SPUEL.03 LEVEL PURGING WATER LEVEL HIGH, STOP REFILLING 1600 -10 mm
L.SPUEL.04 LEVEL PURGING WATER LEVEL TOO HIGH 1650 -10 mm
P.AIRFILT.01 * DIFF.PRESSURE ALARM: HIGH DIFFERENTIAL PRESSURE ON INTAKE FILTER (TOTAL DP) 7 -1 mbar
P.AIRFILT.02 * DIFF.PRESSURE ALARM: VERY HIGH DIFFERENTIAL PRESSURE ON INTAKE FILTER (TOTAL DP) 11 -1 mbar
P.AIRFILT.03 * DIFF.PRESSURE GT SHUT DOWN FOR TOO HIGH DIFFERENTIAL PRESSURE ON INTAKE FILTER (TOTAL DP) 15 -1 mbar
P.ANTICE.01 PRESSURE PRESSURE ANTI-ICE 1,5 bar
P.ANTICE.02 PRESSURE PRESSURE ANTI-ICE 4,5 bar
P.BRUMM.01 HUMMING COMBUSTION CHAMBER HUMMING LIMIT 1, FO OPERATION 25 mbar
COMBUSTION CHAMBER HUMMING, FO OPERATION, GT TRIP IN CASE OF 2V2 TRANSDUCERS
P.BRUMM.07 HUMMING 2 0 mbar
FAULT
P.DFILT.100 DIFF.PRESSURE ALARM: FO DIFFUSION FILTER CLOGGED 1,5 bar
P.DFILT.200 DIFF.PRESSURE GT SHUT DOWN FOR FO DIFFUSION FILTER CLOGGED 2 bar
P.EXH.01 DIFF.PRESSURE ALARM: HIGH DIFFERENTIAL PRESSURE ON EXHAUST DIFFUSER - 1° LIMIT 50 mbar
P.EXH.02 DIFF.PRESSURE SHUTDOWN FOR HIGH DIFFERENTIAL PRESSURE ON EXHAUST DIFFUSER - 2° LIMIT 65 mbar
P.EXH.03 DIFF.PRESSURE TRIP FOR HIGH DIFFERENTIAL PRESSURE ON EXHAUST DIFFUSER - 3° LIMIT 80 mbar
P.FILL.100 PRESSURE FO RETURN PRESSURE SUFFICIENT FOR FO CONNECTION IN FG MODE 22 bar
P.FUEL.01 PRESSURE FO RETURN LINE PRESSURE FOR RETUNR LINE FILLING 22 bar
P.FUELL.01 * PRESSURE WATER PRESSURE IN FO RETURN LINE FOR END FILLING 20 bar
P.GAS.01 * PRESSURE REQUIRED NAT. GAS PRESS. UPSTR. OF FUEL GAS STOP VALVE - REFERENCE VALUE 28 barg
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P.GAS.03 * PRESSURE NG PRESSURE LEVEL FOR AUTOMATIC FUEL CHANGE OVER FUEL GAS TO OIL < 25 barg
P.GAS.06 * PRESSURE FG pressure upstream of FG-ESV low & release fuel change over FO to FG < 26.3 +04 barg
85% of
P.GAS.01 >
P.GAS.07 * PRESSURE NG PRESSURE TOO LOW: NG TRIP IN FG PREMIX barg
max compress.
delivery press
P.GAS.08 NG PRESSURE FG pressure upstream of FG-ESV null 1.5 bar
P.GAS.11 * PRESSURE NG PRESSURE TOO HIGH, ALARM 31 barg B
P.GAS.17 * PRESSURE NG PRESSURE UPSTREAM ESV TOO LOW: GT TRIP < 24.3 +0.8 barg
P.GAS.27 PRESSURE NG MINIMUM PRESSURE FOR CORRECTION CALCULATION 8 bar
P.GENLIFT.100 PRESSURE Low limit value for the transducer MAV60CP101 110 bar
P.HOE.01 PRESSURE FO PRESSURE AFTER INJECTION PUMP > MIN 65 -5 bar
P.HOE.09 PRESSURE RELEASE FOR OPENING FO-ESVS AT GT STANDSTILL 1 +0.5 bar
P.HOE.16 PRESSURE FO PRESSURE BEFORE INJECTION PUMP > MIN 1.2 -0.2 bar
P.HOE.18 PRESSURE ALARM LOW FO PRESSURE 60 +5 bar
P.HOEDB.100 PRESSURE LOW FO DIFFERENTIAL PRESSURE IN FO DIFFUSION MODE, GT TRIP 8 bar
LOW FO DIFFERENTIAL PRESSURE IN FO PREMIX MODE, FAST SWITCH OVER TO FO DIFFUSION
P.HOEVB.100 PRESSURE 5 bar
MODE
P.HSO.02 PRESSURE LIMIT VALUE FOR PRESSURE-FREE RDS SYSTEM 7 -0.5 bar
P.HSO.03 PRESSURE RDS PUMPS OFF > 175 bar
P.HSO.04 PRESSURE RDS PUMPS ON < 160 bar
P.HSO.05 PRESSURE MINIMUM PRESSURE FOR FLUSHING 170 -2 bar
P.HSO.06 PRESSURE PRESSURE OK IN NOT ACTIVATED CHAMBER <5 bar
P.HSO.07 PRESSURE MAX PRESSURE IN NOT ACTIVATED CHAMBER: GT TRIP 10 bar
P.HSO.08 PRESSURE PRESSURE OK IN ACTIVATED CHAMBER > 150 bar
P.HSO.09 PRESSURE PRESSURE LOW IN ACTIVATED CHAMBER, RDS PRESSURE TOO LOW: GT TRIP < 140 bar
P.HSO.10 PRESSURE MAX RDS SYSTEM PRESSURE 190 -5 bar
P.HSO.100 PRESSURE HIGH PRESSURE IN SECONDARY CHANNEL, OPEN SECONDARY CHANNEL RETURN VALVE > 210 bar
P.HSO.101 PRESSURE PRESSURE OK IN SECONDARY CHANNEL, CLOSE SECONDARY CHANNEL RETURN VALVE < 195 bar
P.HSO.102 PRESSURE TOO HIGH PRESSURE IN SECONDARY CHANNEL: GT TRIP 230 bar
P.HSO.11 PRESSURE MAX PRESSURE DURING MAIN CHANNEL PURGING 150 -5 bar
P.HYD.02 PRESSURE SWITCH OFF HYDRAULIC OIL STAND-BY PUMP 145 -20 bar
P.HYD.03 PRESSURE GT start-up: Check for operating pressure 125 bar
P.HYD.04 PRESSURE GT TRIP FOR TOO LOW HYDRAULIC OIL PRESSURE 100 5 bar
P.LIFT.01 PRESSURE LOW LIMIT VALUE FOR THE TRANSDUCER MBV31CP101 130 bar
P.LIFT.100 PRESSURE LOW LIMIT VALUE FOR THE TRANSDUCER MBV35CP101 120 bar
P.PFILT.100 PRESSURE ALARM: FO PREMIX FILTER CLOGGED 1,5 bar
P.PFILT.200 PRESSURE GT TRANSFER TO FO DIFFUSION FOR FO PREMIX FILTER CLOGGED 2 bar
P.PIGL.01 PRESSURE COMPRESSOR PRESSURE RATIO AT BASE LOAD AND ISO-CONDITIONS 19,92 ---
P.PISTERN.11 PRESSURE RATIO COMPRESSOR LIMIT CHARACTERISTICS: MAX. COMPR. PRESSURE RATIO 44 % S.NSTERN.01 B
P.PISTERN.21 PRESSURE RATIO COMPRESSOR LIMIT CHARACTERISTICS: MAX. COMPR. PRESSURE RATIO 42,2 % S.NSTERN.01
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P.PISTERN.52 PRESSURE RATIO COMPRESSOR LIMIT CHARACTERISTICS: MAX. COMPR. PRESSURE RATIO 81 % S.NSTERN.02
P.PISTERN.71 PRESSURE RATIO COMPRESSOR LIMIT CHARACTERISTICS: MAX. COMPR. PRESSURE RATIO -93 % S.NSTERN.01
P.PISTERN.76 PRESSURE RATIO COMPRESSOR LIMIT CHARACTERISTICS: MAX. COMPR. PRESSURE RATIO 151 % S.NSTERN.06
P.PVI.01 * PRESSURE SUBSTITUTE VALUE AT INLET PRESSURE TRANSDUCER FAULT 950 mbar
P.SCHMOEL.01 PRESSURE START OF AUXILIARY LUBE OIL PUMP 1.5 0.2 bar
P.VII.23 PRESSURE COMPRESSOR DISCHARGE PRESSURE FOR F.SPUDB.02 14 bar
P.VII.24 PRESSURE COMPRESSOR DISCHARGE PRESSURE FOR F.SPUDB.03 15,7 bar
P.VII.25 PRESSURE COMPRESSOR DISCHARGE PRESSURE FOR F.SPUDB.04 20 bar
PP.BK.01 RELATIVE DIFF PRESS. VALUE FOR PCCREL ALARM 1,8 0,1 %
MONITORING OF THE PREMIX COOLING: DIFFERENTIAL PRESSURE PURGE WATER - COMPRESSOR
PP.EMUSPU.100 DIFF.PRESSURE >3 bar
IS OK
PP.EMUSPU.101 DIFF.PRESSURE MINIMUM DIFFERENTIAL PRESSURE 3 bar
PP.FUELL.01 PRESSURE MINIMUM WATER PRESSURE 20 bar
NOZZLE bar
PP.HOE.11 STANDARDIZED PRESSURE LOSS ON FO DIFF SUPPLY LINE AT FUEL FLOW RATIO F.HOE.011 25746 F.HOE.011
CHARACTERISTIC s2/kg m3
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
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NOZZLE bar s²/kg

CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar
PP.HOE.31 STANDARDIZED PRESSURE LOSS ON FO RETURN LINE AT FUEL FLOW RATIO F.HOE.031 7069 F.HOE.031
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
NOZZLE bar s²/kg
CHARACTERISTIC m³
PP.HOEDB.100 DIFF.PRESSURE LOW FO DIFFERENTIAL PRESSURE IN FO-DO MODE, GT TRIP 8 bar
MONITORING OF THE FO DIFFUSION PURGING: DIFFERENTIAL PRESSURE COMPRESSOR-FO
PP.HOEDB.101 DIFF.PRESSURE >3 bar
SUPPLY LINE IS OK
PP.HOEVB.100 DIFF.PRESSURE LOW FO DIFFERENTIAL PRESSURE IN FO-PO MODE, FAST SWITCH OVER TO FO-DO MODE 1,5 bar
RELEASE FOR OPENING PURGE SOLENOID VALVE: DIFFERENTIAL PRESSURE PURGE WATER -
PP.SPUEL.100 DIFF.PRESSURE >3 bar
COMPRESSOR IS OK
MONITORING OF THE DIFFUSION PURGING: DIFFERENTIAL PRESSURE PURGE WATER -
PP.SPUEL.101 DIFF.PRESSURE >3 bar
COMPRESSOR IS OK
PP.TLE2.02 PRESSURE RATIO PRESSURE CONTROL RATIO LOW, OPEN COOLING AIR VALVE 2, ALARM 2 -1 %
PP.TLE2.03 PRESSURE RATIO PRESSURE CONTROL RATIO HIGH, COOLING AIR STAGE 2 -3 2 %
PP.TLE2.04 PRESSURE RATIO PRESSURE CONTROL RATIO TOO, COOLING AIR STAGE 2, GT SHUT DOWN 3 -1 %
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Serial
No.
PP.TLE2.11 PRESSURE RATIO GV2 pressure ratio for G.VLE0.121 or E.LEIST.121 0,71 ---
PP.TLE3.02 PRESSURE RATIO warning, pressure ratio low, valve OPEN with option active 2 -1 %
PP.TLE3.03 PRESSURE RATIO warning, pressure ratio high, over cooling -3 2 %
PP.TLE3.04 PRESSURE RATIO alarm, pressure ratio too low, actuation of shutdown program with option active 3 -1 %
MONITORING COMPRESSOR OUTLET PRESSURE: MAX ALLOWED PRESSURE DIFFERENCE FOR
PP.VII.01 PRESSURE 0.5 bar B
TRANSUDECERS
Q.PCI.01 HEAT VALUE LHV for PILOT-CV flow correction F.PILOT.145 0 MJ/Sm3
Q.WBI.01 HEAT VALUE Wobbe Index for PILOT-CV flow correction F.PILOT.151 -0,03 MJ/Sm3 B
Q.WBI.04 HEAT VALUE Wobbe Index for PILOT-CV flow correction F.PILOT.154 0 MJ/Sm3 B
Q.WBI.05 HEAT VALUE Wobbe Index for PILOT-CV flow correction F.PILOT.155 0,005 MJ/Sm3 B
Q.WBI.06 HEAT VALUE Wobbe Index for PILOT-CV flow correction F.PILOT.156 0,01 MJ/Sm3 B
S.ACC.01 COMBUSTION CHAMBER ACCELERATION LIMIT 1, NG OPERATION 2.5 g
S.ACC.02 COMBUSTION CHAMBER ACCELERATION LIMIT 2, NG OPERATION 3 g
S.ACC.03 COMBUSTION CHAMBER ACCELERATION LIMIT 3 8 g
S.ACC.04 COMBUSTION CHAMBER ACCELERATION LIMIT 1, FO OPERATION 2.5 g
S.ACC.05 COMBUSTION CHAMBER ACCELERATION LIMIT 2, FO OPERATION 3 g
S.ACC.06 COMBUSTION CHAMBER ACCELERATION, LIMIT VALUE FOR TRANSDUCER MONITORING 0.1 g
S.ACC.07 COMBUSTION CHAMBER ACCELERATION LIMIT 4 FOR EARLY DETECTION, NG OPERATION 1.8 g
S.ACCFREQ.01 BAND PASS FOR ACCELERATION MONITORING - REFERENCE VALUE 10 ... 1000 Hz
S.BRUMM.00 BAND PASS FOR BURNER STABILITY MONITOR - REFERENCE VALUE 10 ... 1000 Hz
S.BRUMM.01 BAND PASS 2 FOR BURNER STABILITY MONITOR - REFERENCE VALUE 2000 ... 3000 Hz
S.ICE.01 THICKNESS ICE THICKNESS 0,5 mm
S.LAGER.00 BAND PASS FOR VIBRATION PROTECTION - REFERENCE VALUE 20 ... 200 Hz
S.NSTERN.01 SPEED RATIO COMPRESSOR LIMIT CHARACTERISTICS: COORDINATES FOR REDUCED SPEED -0,90 - F.LSV.0# B
S.NSTERN.04 SPEED RATIO COMPRESSOR LIMIT CHARACTERISTICS: COORDINATES FOR REDUCED SPEED -1 - F.LSV.0# B
S.TURB.000 SPEED NOMINAL SPEED 50 Hz
S.TURB.002 SPEED SPEED NEAR STANDSTILL 0.10 +0.01 Hz
S.TURB.003 SPEED START-UP MONITORING 38.6 -0.2 Hz
S.TURB.004 SPEED SPEED NEAR TURNING-SPEED - REFERENCE VALUE 2.50 +0.10 Hz
S.TURB.005 SPEED SEVERAL TASKS AT START, BEGINNING OF TURNING-OPERATION 4.0 -0.1 Hz
S.TURB.007 SPEED CLOSE COMPR. BLOW OFF DAMPER 2 AT GT START UP WITH NG 40.0 -0.2 Hz
S.TURB.009 * SPEED OPENING NG-ESV AT GT START UP WITH NG 6 -0.4 Hz
S.TURB.010 SPEED GT SPEED, 95 % OF NOMINAL SPEED, SEVERAL FUNCTIONS 47,5 +0.2 Hz
S.TURB.012 SPEED SWITCH OFF / ON OF THE LIFTING OIL PUMP 25 -0.5 Hz
S.TURB.013 SPEED CLOSE COMPR. BLOW OFF DAMPERS 1 AND 3 49.0 -0.5 Hz
S.TURB.015 SPEED SEVERAL AT START UP, COMPRRESSOR SURGE PROTECTION ON 42.0 -0.2 Hz
S.TURB.020 * SPEED SEVERAL FUNCTIONS DURING TURNING GEAR OPERATION 1.80 +0.10 Hz
S.TURB.021 * SPEED 25% OF NOM. SPEED, MONITORING OF START-UP-PROCEDURE 12.5 -0.5 Hz
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Serial
No.
S.TURB.030 SPEED GT SPEED,RELEASE FOR COMMAND OPEN TO FO STOP VALVES 6,6 Hz

S.TURB.031 SPEED GT SPEED, IGNTION GAS VALVES COMMAND OPEN AT GT START UP WITH FO 5,5 Hz
S.TURB.032 SPEED RELEASE FOR IGNITION TRANSFORMERS ON ONLY BELOW THIS VALUE 18 -0.5 Hz
S.TURB.037 SPEED SPEED > 30% OF NOM. SPEED AT START UP, START COUNTING OF EOH 15.0 -0.5 Hz
S.TURB.038 SPEED BOILER PURGE SPEED MONITORING, 23% OF NOMINAL SPEED 11,5 -0.5 Hz
S.TURB.051 SPEED SWITH ON OF SPEED CONTROLLER AT GT START UP 47,5 Hz
S.TURB.052 SPEED UPPER LIMIT OF SPEED SET POINT 51,5 Hz
S.TURB.053 * SPEED BEGIN 1.OPENING RATE OF NG-CV AT STARTUP WITH NG 11 Hz
S.TURB.055 * SPEED BEGIN 1.OPENING RATE OF NG-CV AT STARTUP WITH FO 18,3 Hz
S.TURB.056 * SPEED BEGIN 2.OPENING RATE OF NG-CV AT STARTUP WITH FO 30 Hz
S.TURB.0561 * SPEED BEGIN 3.OPENING RATE OF NG-CV AT STARTUP WITH FO 45 Hz
S.TURB.0562 SPEED BEGIN 4.OPENING RATE OF NG-CV AT STARTUP WITH FO N.A. Hz B
S.TURB.057 SPEED Reset to zero for the function (TT.ATK.41..46;F.EG.21..26) 32 Hz
S.TURB.067 SPEED SPEED > 96% OF NOM. SPEED - LOWER LIMIT FOR RELATIVE VIBRATION 48 Hz
S.TURB.068 SPEED SPEED > 103% OF NOM. SPEED - UPPER LIMIT FOR RELATIVE VIBRATION 51.5 Hz
S.TURB.070 SPEED SPEED <94% OF NOM. SPEED 47.0 Hz
S.TURB.071 SPEED SPEED >104% OF NOM. SPEED, SPEED MONITORING (PROTECTION) 52.0 -0.2 Hz
S.TURB.072 SPEED SPEED 108% OF NOM. SPEED, OVERSPEED PROTECTION, TRIP 54.0 -1.62 Hz
S.TURB.082 SPEED SPEED DEADBAND (+/-) PRIMARY FREQUENCY INFLUENCE FOR HIGH SENSITIVE MODE 0,015 Hz
S.TURB.0821 SPEED SPEED DEADBAND (+/-) PRIMARY FREQUENCY INFLUENCE FOR LOW SENSITIVE MODE 0,015 Hz
S.TURB.084 SPEED SETPOINT LIMIT FREQUENCY INFLUENCE UNDERFREQUENCY 49,75 Hz
S.TURB.085 SPEED SETPOINT LIMIT FREQUENCY INFLUENCE OVERFREQUENCY 50,25 Hz
S.TURB.088 SPEED SWITCH OFF IGNITION GAS VLV AT START UP WITH FO 18 -0,5 Hz
LOWEST SPEED FOR SWITCHING ON OF TURNING DEVICE FOR SYNCHRONIZATION WITH GT SHAFT
S.TURB.089 SPEED 0.5 +0.1 Hz
ON COASTING DOWN
S.TURB.096 TURBINE SPEED Minimum GT speed for IGV position track U.VLE.14 42 s-2
S.TURB.098 SPEED BOILER PURGE SPEED, LOWER LIMIT, 23.3% OF NOMINAL SPEED 11,7 Hz
S.TURB.099 SPEED SFC DISCONNECTION AT COMPRESSOR CLEANING MODE 13,3 Hz
S.TURB.106 * SPEED LIMITING FUNCTION, STARTUP WITH NG, 1.POINT OF CHARACTERISTIC 0 Hz
S.TURB.112 * SPEED LIMITING FUNCTION, STARTUP WITH FO, TURBINE SPEED AT J.HOE.03 0 Hz J.HOE.03
S.TURB.122 SPEED UNDERFREQUENCY BLOW OFF A1.1 & A1.2 OPENING 46,5 Hz
S.TURB.125 TURBINE SPEED Minimum GT speed for IGV position track U.VLE.15 26 s-2 B
S.TURB.157 SPEED OPEN PREMIX CV DURING RUN-UP FUNCTION 30 Hz
S.TURB.170 SPEED SPEED < 93% OF NOM. SPEED FOR PROTECTION 46,5 Hz
S.TURB.172 SPEED SPEED 108% OF NOM. SPEED, OVERSPEED PROTECTION, TRIP, EXTERNAL DEVICE 54.4 -1.62 Hz
S.TURB.200 SPEED RELEASE TO OPEN SPRAY NOZZLE 5 Hz
S.TURB.270 SPEED SPEED >70% OF NOM. SPEED FOR SFC PROTECTION 35 Hz
S.TURB.300 SPEED SPEED FOR J.EGANT.100 25 Hz J.EGANT.100
S.TURB.303 SPEED SPEED FOR J.EGANT.103 42 Hz J.EGANT.103 B
S.TURB.304 SPEED SPEED FOR J.EGANT.104 46 Hz J.EGANT.104 B
S.TURB.542 * SPEED BEGIN 4.OPENING RATE OF NG-CV AT STARTUP WITH NG T.B.D. Hz
SE.STATIK.01 * FACTOR DROOP OF SPEED GOVERNOR 5 %
SE.STATIK.104 * FACTOR GAIN OF LOAD GOVERNOR, DIRECT (FF) 0,153999999 %/MW B
SFC.CLEAN.01 TIME MAX TIME FOR SFC ON IN CLEANING MODE 0,5 h
ST.PUMP.01 SPEED RATIO LOWER LIMIT VALUE FOR REDUCED SPEED N* 0.907 ---
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ST.PUMP.02 SPEED RATIO HIGHER LIMIT VALUE FOR REDUCED SPEED N* 1.1 ---
ST.PUMP.04 SPEED RATIO REDUCED SPEED AT REDUCED FLOW U.LSV.07 0,85 --- U.LSV.07 B
ST.PUMP.06 SPEED RATIO REDUCED SPEED AT REDUCED FLOW U.LSV.09 0926 --- U.LSV.09 B
T.ANTICE.01 TEMPERATURE TEMP. ANTI-ICING SET 70 °C B
T.ANTICE.02 TEMPERATURE TEMP. ANTI-ICING SET 110 °C B
T.ANTICE.03 TEMPERATURE TEMP. ANTI-ICING SET --- °C B
Tamb+0.15*R
T.ANTICE.201 TEMPERATURE TEMPERATURE SET POINT FOR ANTI-ICING CONTROL VALVE °C
H-7
T.EMOTOR.01 TEMPERATURE ALARM, HIGH TEMPERATURE IN THE FO INJECTION PUMP-MOTOR WINDING 125 °C
T.GAS.04 TEMPERATURE NG temperature permissive to start the change over FGàFO 50 °C
T.GAS.05 TEMPERATURE REFERENCE TEMPERATURE FOR PILOT GAS POSITION - REFERENCE VALUE 20 20 °C
T.HYD.01 TEMPERATURE HYDRAULIC OIL HEATING: PUMPS ON 30 +1 °C
T.HYD.02 TEMPERATURE HYDRAULIC OIL HEATING: PUMPS OFF 35 -1 °C
T.HYD.03 TEMPERATURE HYDRAULIC OIL COOLING: FAN OFF 45 +2 °C
T.HYD.04 TEMPERATURE HYDRAULIC OIL COOLING: FAN OFF 55 -2 °C
T.HYD.05 TEMPERATURE ALARM HYDRAULIC OIL TEMPERATURE HIGH 70 -5 °C
T.LAGER.M TEMPERATURE ALARM COMPRESSOR BEARING TEMPERATURE HIGH 110 -5 °C
T.LAGER.M01 TEMPERATURE ALARM TURBINE BEARING TEMPERATURE HIGH 110 -5 °C
T.LAGER.MG TEMPERATURE ALARM GENERATOR BEARING TEMPERATURE HIGH 110 -5 °C
T.LAGER.S TEMPERATURE TURBINE / COMPRESSOR BEARING TEMPERAURE TOO HIGH: GT TRIP 120 -5 °C
T.LAGER.SG TEMPERATURE GENERATOR BEARING TEMPERAURE TOO HIGH: GT TRIP 120 -5 °C
T.MOTOR.01 TEMPERATURE ALARM, HIGH TEMPERATURE IN THE FO INJECTION PUMP-MOTOR BEARING 110 °C
FO INJECTION PUMP PROTECTION OFF FOR VERY HIGH TEMPERATURE IN THE FO INJECTION
T.MOTOR.02 TEMPERATURE 120 °C
PUMP-MOTOR BEARING
T.SCHMOEL.01 TEMPERATURE LUBE OIL TANK TEMPERATURE, START-UP RELEASE 10 -3 °C
T.SCHMOEL.02 TEMPERATURE LUBE OIL TANKT EMPERATURE, HEATING ON 15 -3 °C
T.SCHMOEL.03 TEMPERATURE LUBE OIL TANK TEMPERATURE, HEATING OFF 20 -3 °C
T.SCHMOEL.04 TEMPERATURE ALARM: LUBE OIL TEMPERATURE HIGH 58 -3 °C
T.SPERRL.01 TEMPERATURE ALARM: SEAL AIR TEMPERATURE LOW 95 °C (+5) °C
T.SPERRL.02 TEMPERATURE ALARM: SEAL AIR TEMPERATURE HIGH 180 °C (-5) °C
T.SPERRL.03 TEMPERATURE SEAL AIR TEMPERATURE TOO HIGH: GT TRIP 220 °C (-5) °C
T.SPERRL.04 TEMPERATURE TEMPERATURE SET POINT FOR SEAL AIR TEMPERATURE 130 °C °C
TEMP. UPSTR. COMPRESSOR INLET TEMPERATURE RANGE FOR MEAURING AND INDICATION - REFERENCE
T.VI.000 -50 ... +60 °C
COMPRESSOR VALUE
TEMP. UPSTR.
T.VI.009 REFERENCE TEMPERATURE FOR PILOT GAS CONTROL VALVE 15 °C
COMPRESSOR
TEMP. UPSTR.
T.VI.026 Ambient temperature for PILOT-CV flow correction F.PILOT.192 -10 °C F.PILOT.192
COMPRESSOR
TEMP. UPSTR.
T.VI.027 Ambient temperature for PILOT-CV flow correction F.PILOT.193 0 °C F.PILOT.193
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
T.VI.101 COMPRESSOR INLET TEMPERATURE FOR NOX CONSTANT CURVE AT TT.ATK.D101 -30 °C TT.ATK.D101 B
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
T.VI.105 TEMP. UPSTR. COMPRESSOR INLET TEMPERATURE FOR NOX CONSTANT CURVE AT TT.ATK.D105 0 °C TT.ATK.D105 B
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Serial
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COMPRESSOR
TEMP. UPSTR.
T.VI.106 COMPRESSOR INLET TEMPERATURE FOR NOX CONSTANT CURVE AT TT.ATK.D106 5 °C TT.ATK.D106 B
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
T.VI.200 AMBIENT TEMPERATURE FOR TETC DERATING TABLE (WITH H.AMB.) 0 °C B
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
T.VI.288 TVI value at U.KORR.288, LVG ISO correction factor function °C U.KORR.288 B
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
T.VI.294 TVI value at U.KORR.294, PNORM correction factor function -25 °C U.KORR.294 B
COMPRESSOR
TEMP. UPSTR.
T.VI.295 TVI value at U.KORR.295, PNORM correction factor function 0 °C U.KORR.295 B
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
T.VI.300 DVLEG1-Ambient temperature for TT.ATK.D300 -20 °C
COMPRESSOR
TEMP. UPSTR.
T.VI.301 DVLEG1-Ambient temperature for TT.ATK.D301 -10 °C
COMPRESSOR
TEMP. UPSTR.
T.VI.302 DVLEG1-Ambient temperature for TT.ATK.D302 0 °C
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
TEMP. UPSTR.
COMPRESSOR
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Serial
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T.VLE.01 TEMPERATURE LIMIT: TEMPERATURE CONTROL DEVIATION 20 °C

T.VLE.02 TEMPERATURE DEAD BAND TEMPERATURE CONTROL DEVIATION 2 °C
T.VLE.03 TEMPERATURE DEAD BAND INCREASE WHEN COMPRESSOR PRESSURE RATIO CONTROLLER IN OPERATION 4 °C
HIGH TEMPERATURE BEARING MOTOR OF PURGING PUMP, ALARM AND PUMP PROTECTION
T.WMOTOR.01 TEMPERATURE 85 -5 °C
(2V2)
T.WMOTOR.02 TEMPERATURE HIGH TEMPERATURE WINDING MOTOR OF PURGING PUMP 115 -5 °C
T.WMOTOR.03 TEMPERATURE TOO HIGH TEMPERATURE WINDING MOTOR OF PURGING PUMP, PUMP OFF 120 -5 °C
TT.AT.001 * TURB.EXHAUST TEMP. TURBINE TEMPERATURE PROTECTION (MBA26CT101-124): HOT-SPOT ALARM 30 °C
TT.AT.002 * TURB.EXHAUST TEMP. TURBINE TEMPERATURE PROTECTION (MBA26CT101-124): HOT-SPOT, GT TRIP 50 °C
TT.AT.003 * TURB.EXHAUST TEMP. TURBINE TEMP. PROTECTION (MBA26CT101-124): COLD-SPOT ALARM, GT TRIP, SHUT DOWN 50 °C
LIMIT FOR DETECTION OF FAULT THERMOELEMENT (SWITCH OFF FROM TETC AVERAGE
TT.AT.006 * TURB.EXHAUST TEMP. 100 °C
CALCULATION)
TT.AT.100 TURB.EXHAUST TEMP. MONITORING RANGE FOR MBR LOWER VALUE 100 °C
TT.AT.101 TURB.EXHAUST TEMP. MONITORING RANGE FOR MBR HIGHER VALUE 700 °C
TT.AT.102 TURB.EXHAUST TEMP. MONITORING OF MBR, DEVIATION FROM THE AVERAGE 100 °C
K3=0.007" ---
TT.ATG.01 * TURB.EXHAUST TEMP. Hot-Spot Alarm – FO – DO Operation 70 °C B
TT.ATG.02 * TURB.EXHAUST TEMP. Hot-Spot - GT TRIP- FO – DO Operation 80 °C B
TT.ATG.03 * TURB.EXHAUST TEMP. Hot-Spot Alarm - FO PX Operation 30 °C B
TT.ATG.04 * TURB.EXHAUST TEMP. Hot-Spot - GT TRIP- FO PX Operation 50 °C B
TURB.EXHAUST TEMP.
TT.ATK.000 TURBINE EXHAUST TEMPERATURE RANGE FOR MEASURING AND INDICATION - REFERENCE VALUE -50 ... +700 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.001 TETC FOR TRANSFER FROM DIFFUSION TO MIXED MODE (OPTION) 305 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.002 TETC FOR SWITCH OVER FROM FO DIFFUSION TO FO PREMIX 510 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.004 TETC FOR TRANSFER FROM MIXED TO DIFFUSION MODE (OPTION) 295 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.005 TETC FOR SWITCH OVER FROM FO PREMIX TO FO DIFFUSION 490 °C B
CORR.
TURB.EXHAUST TEMP.
TT.ATK.011 * RELEASE FOR HOT-SPOT PROTECTION 300 -10 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.041 * TETC FOR IGNITION ADAPTATION AT F.EG.21 OR F.HOE.143 -41 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.042 * TETC FOR IGNITION ADAPTATION AT F.EG.22 OR F.HOE.144 -20 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.043 * TETC FOR IGNITION ADAPTATION AT F.EG.23 OR F.HOE.145 0 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.044 * TETC FOR IGNITION ADAPTATION AT F.EG.24 OR F.HOE.146 +15 °C
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.060 PO PROPORTION IN DO/PO-MO, TETC FOR J.EGANT.01 300 °C J.EGANT.01
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.070 TETC WITH IGV CLOSED AT F.PILOT.70 300 °C F.PILOT.70
CORR.
TURB.EXHAUST TEMP.
TT.ATK.071 * TETC WITH IGV CLOSED AT F.PILOT.71 450 °C F.PILOT.71
CORR.
TT.ATK.072 * TURB.EXHAUST TEMP. TETC WITH IGV CLOSED AT F.PILOT.72 490 °C F.PILOT.72
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Serial
No.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.086 * TETC SET POINT FOR FUEL CHANGE OVER 550 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.087 TURB.EHAUST TEMP.CORR. at J.EGVB.01 300 °C J.EGVB.01
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.240 * DVLEG21 - SS - FG - TETC correction factor for E.LEIST.250 0 °C E.LEIST.250 B
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.260 * DVLEG21 - SS - FO - TETC correction factor for E.LEIST.270 0 °C E.LEIST.270 B
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.270 TETC for IGV fully closed and pilot2 flow rate F.PILOT.270 300 °C F.PILOT.270
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.300 Condition for change over from PILOT1 to PILOT2 operation 500 °C B
CORR.
TURB.EXHAUST TEMP.
TT.ATK.700 * TETC SET POINT DECREASE AT FOGGING SYSTEM TRIP 3 °C B
CORR.
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Serial
No.
TURB.EXHAUST TEMP.
TT.ATK.701 TETC REDUCTION IN CASE OF COOLING AIR CONTROL VALVES OPEN 3 °C B
CORR.
TURB.EXHAUST TEMP.
TT.ATK.702 TETC REDUCTION IN CASE OF RDS SYSTEM OFF -4 °C B
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D002 SETPOINT FOR IGV CONTROLLER ABOVE BASE LOAD 5 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D003 SETPOINT FOR TETC CONTROLLER DURING FUEL CHANGEOVER 15 °C B
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D006 DIFFERENCE FOR TETC MONITORING 100 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D101 TETC SET POINT DECREASE FOR NOX CONSTANT CURVE AT T.VI.101 16 °C T.VI.101
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D104 TETC SET POINT DECREASE FOR NOX CONSTANT CURVE AT T.VI.104 11,5 °C T.VI.104
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D105 TETC SET POINT DECREASE FOR NOX CONSTANT CURVE AT T.VI.105 9,5 °C T.VI.105
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D130 TETC SET POINT DECREASE WHEN MBR SYSTEM FAULT 2 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D157 D01 -SS - FG -TETC CORRECTION at LVG ISO E.LEIST.230 10 °C E.LEIST.230 B
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D167 D01 -SS - FO -TETC CORRECTION at LVG ISO E.LEIST.240 21 °C E.LEIST.240 B
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D200 * TETC SET POINT DECREASE AT H.AMB.01 / T.VI.200 -4.16 °C B
CORR.
TT.ATK.D201 * TURB.EXHAUST TEMP. TETC SET POINT DECREASE AT H.AMB.01 / T.VI.201 -5.91 °C B
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Serial
No.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP. TETC SET POINT DECREASE AT H.AMB.02 / T.VI.203, H.AMB.03 / T.VI.202 AND 203, H.AMB.04,
TT.ATK.D204 * -13.15 °C B
CORR. H.AMB.05
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D210 * TETC SET POINT DECREASE AT H.AMB / T.VI -4.83 °C B
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D218 * TETC SET POINT DECREASE AT H.AMB / T.VI 0.00 °C B
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D227 * TETC SET POINT DECREASE AT H.AMB.05/ T.VI.203 1.53 °C B
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
Doc. No.: 0558S1MB#S051

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Serial
No.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D250 * TETC SET POINT DECREASE FOR C/H RATIO, PROPORTIONAL COEFFICIENT 40 °C B
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D300 DVLEG1 -TETC set point at TT.VI.300 3 °C B
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D336 * DVLEG UP FG- SS TETC versus LVGISO E.LEIST.286 0 °C E.LEIST.286 B
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D348 * DVLEG UP FO- SS TETC versus LVGISO E.LEIST.298 0 °C E.LEIST.298 B
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D360 * DVLEG DOWN FG- SS TETC versus LVGISO E.LEIST.310 0 °C E.LEIST.310 B
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.D372 * DVLEG DOWN FO- SS TETC versus LVGISO E.LEIST.322 0 °C E.LEIST.322 B
CORR.
TT.ATK.D373 * TURB.EXHAUST TEMP. DVLEG DOWN FO- SS TETC versus LVGISO E.LEIST.323 0 °C E.LEIST.323 B
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Serial
No.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
CORR.
TURB.EXHAUST TEMP.
TT.ATK.EGGL ** TETC AT BASE LOAD TETC CONTROLLER, SIMPLE CYCLE - NATURAL GAS 565 °C B
CORR.
TURB.EXHAUST TEMP.
TT.ATK.EGGLK OTC SET POINT IN FG OPERATION COMBINED CYCLE 568 °C B
CORR.
TURB.EXHAUST TEMP.
TT.ATK.HOEGL ** TETC AT BASE LOAD TETC CONTROLLER, SIMPLE CYCLE - FUEL OIL 523 °C B
CORR.
TURB.EXHAUST TEMP.
TT.ATK.HOEGLK OTC SET POINT IN FO OPERATION COMBINED CYCLE 525 °C B
CORR.
TURB.EXHAUST TEMP.
TT.ATK.M07 * ALARM: TETC HIGH (AVERAGE VALUE) 620 -5 °C
CORR.
TURB.EXHAUST TEMP.
TT.ATK.S07 * TETC TOO HIGH (AVERAGE VALUE): GT TRIP 660 -5 °C
CORR.
TURB.EXHAUST TEMP.
TTK.ATK.001 FLAT TEMPERATURE GRADIENT UP TO BASE LOAD 0,5 °C/s B
CORR.
TURB.EXHAUST TEMP.
TTK.ATK.002 TETC GRADIENT TETC SET POINT CHANGE 0,2 °C/s B
CORR.
TURB.EXHAUST TEMP.
TTK.ATK.100 OTC SET POINT DECREASING GRADIENT AFTER WATER INJECTION TRIP 3 °C/s B
CORR.
TURB.EXHAUST TEMP. OTC SET POINT RESTORING GRADIENT AFTER WATER INJECTION TRIP AND WAITING TIME
TTK.ATK.101 1 °C/s B
CORR. EXPIRED
TURB.EXHAUST TEMP.
TTK.ATK.700 Temperature Gradient for TETC decrease at fogging system trip 2 °C/s B
CORR.
TURB.EXHAUST TEMP.
TTK.ATK.701 Temperature Gradient for TETC decrease at RDS OFF 0,05 °C/s B
CORR.
U.BRENNST.01 LOW VALUE GATE LVG ISO FOR IGV FFWD AT U.VLE.101 40 % U.VLE.101 B
U.BRENNST.11 LOW VALUE GATE LVG ISO FOR IGV FFWD AT U.VLE.111 FOR FO OPERATION 40 % U.VLE.111 B
U.CLE.01 ICV POSITION Air Flow Rate MAP versus IGV/CV1, ULSVC1 - CV1 position 0 % ULSVC1 B
U.EGVB.01 FACTOR number of NG-PREMIX burner - REFERENCE VALUE (n^2) 576 --- B
U.KORR.288 FACTOR LVG ISO correction factor at T.VI.288 % T.VI.288 B
U.KORR.294 FACTOR PNORM correction factor at T.VI.294 1,129504 --- T.VI.294 B
U.KORR.296 FACTOR PNORM correction factor at T.VI.296 1 --- T.VI.296 B
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U.LSV.011 FLOW RATIO Air Flow Rate MAP versus IGV/CV1, ULSVC2 - , U.CLE.02-U.VLE.01 55,53% % ULSVC2 B
U.LSV.057 FLOW RATIO MAX. COMPRESSOR FLOW AT REDUCED SPEED N* ST.PUMP.04 (WITHOUT WATER/STEAM) 60 % ST.PUMP.04 B
U.LSV.058 FLOW RATIO MAX. COMPRESSOR FLOW AT REDUCED SPEED N* ST.PUMP.05 (WITHOUT WATER/STEAM) 99,3 % ST.PUMP.05 B
U.PILOT.01 NUMBER OF BURNER NUMBER OF PILOT GAS BURNERS 24 ---
U.PRAL.01 FACTOR KP PRAL-CONTROLLER FUEL VALVES 1,5 ---
U.PRAL.02 FACTOR KD PRAL-CONTROLLER FUEL VALVES 10 ---
U.PRAL.03 FACTOR KP PRAL- CONTROLLER IGV 1 ---
U.PRAL.05 FACTOR KD PRAL-CONTROLLER IGV 1 %
U.PRAL.06 FACTOR LIMITATION P-CONTROLLER, CONTROL DEVIANCE 5 %
U.PRAL.07 FACTOR AMPLIFICATION OF NEGATIVE PART OF ANTICIPATION 0,1 ---
U.PRAL.08 FACTOR AMPLIFICATION OF POSITIVE PART OF ANTICIPATION 20 ---
U.PRAL.09 FACTOR KP2 P-CONTROLLER FOR FUEL CONTROL VALVES 0,2 ---
U.PRAL.11 FACTOR P-CONTROLLER, DEAD BAND OF ANTICIPATION 1 %
U.PRAL.14 CONSTANT COOLING AIR LIMIT CONTROLLER 3,642100096 --- B
U.PRAL.15 CONSTANT COOLING AIR LIMIT CONTROLLER -3,119899988 --- B
U.PRAL.17 CONSTANT COOLING AIR LIMIT CONTROLLER 4,823699951 --- B
U.PRAL.26 CONSTANT COOLING AIR LIMIT CONTROLLER, OFFSET FOR FUEL CONTROL VALVE 0,3 % B
U.PRAL.27 CONSTANT DEAD BAND, P-CONTROLLER FOR IGV 0,5 %
U.PRAL.28 CONSTANT COOLING AIR LIMIT CONTROLLER FOR FUEL CONTR. VALVE, GAIN FACTOR 1,5 ---
U.PRAL.29 CONSTANT DEAD BAND, COOLING AIR LIMIT CONTROLLER FOR IGV 0,005 ---
U.REGLER.002 PROPORTIONAL GAIN SPEED CONTROLLER PROPORTIONAL COEFFICIENT 0,2 ---
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SPEED CONTROLLER AMPLIFICATION GAIN (RATIO: THERMAL LOAD CHANGE / FREQUENCY

U.REGLER.101 * PROPORTIONAL GAIN 0,255 %/W
CHANGE)
U.REGLER.102 * PROPORTIONAL GAIN LOAD CONTROLLER PROPORTIONAL COEFFICIENT 8 ---
U.REGLER.103 * PROPORTIONAL GAIN Load control integral gain KI in normal operation TBD --- B
U.REGLER.104 * PROPORTIONAL GAIN Load control integral gain KI when GT is in changeover TBD --- B
U.REGLER.105 PROPORTIONAL GAIN IGV CONTROLLER PROPORTIONAL GAIN IN CASE OF LOW DEVIATION FROM SET POINT 0 --- B
U.REGLER.106 PROPORTIONAL GAIN IGV CONTROLLER PROPORTIONAL GAIN IN CASE OF HIGH DEVIATION FROM SET POINT 0,3 --- B
U.REGLER.107 INTEGRAL GAIN IGV CONTROLLER INTEGRAL GAIN IN CASE OF LOW DEVIATION FROM SET POINT 0,3 --- B
U.REGLER.108 INTEGRAL GAIN IGV CONTROLLER INTEGRAL GAIN IN CASE OF HIGH DEVIATION FROM SET POINT 22 --- B
U.REGLER.204 * PROPORTIONAL GAIN IGV FEEDFORWARD -2,27 ---
U.REGLER.205 * PROPORTIONAL GAIN IGV FEEDFORWARD 3,16 ---
U.REGLER.206 * PROPORTIONAL GAIN IGV FEEDFORWARD 75 ---
U.VLE.001 IGV POSITION Air Flow Rate MAP versus IGV/CV1, IGV position 0 % U.LSV.01-051 B
U.VLE.012 IGV POSITION KP IGV POSITION CONTROLLER 0,1 ---
U.VLE.013 * IGV POSITION CONTROL DEVIATION MONITORING IGV POSITION CONTROLLER 20 %
U.VLE.014 IGV POSITION IGV POSITION track when GTspeed> S.TURB.96 0 % -
U.VLE.015 IGV POSITION IGV POSITION track when GTspeed> S.TURB.125 0 % -
U.VLE.101 IGV POSITION IGV POSITION AT U.BRENNST.01 0 % U.BRENNST.01 B
U.VLE.102 IGV POSITION IGV POSITION AT U.BRENNST.02 17.5 % U.BRENNST.02 B
U.VLE.112 IGV POSITION IGV POSITION AT U.BRENNST.12 17,5 % U.BRENNST.12 B
Y.LAGER.01 VIBRATION BEARING ABSOLUTE VIBRATION: LOWER LIMIT FOR MONITORING (REFERENCE VALUE) 0.3 0.2 mm/s
Y.LAGER.02 VIBRATION MAX DEVIATION BEWTWEEN THE 2 CHANNELS FOR MONITORING 1.0 -0.1 mm/s
Y.LAGER.M VIBRATION ALARM : HIGH ABSOLUTE VIBRATION (2V3) - GT 9.3 -0.5 mm/s
Y.LAGER.MA VIBRATION Alarm threshold absolute vibrations – clutch –single shaft configuration only 9.3 -0.5 mm/s B
Y.LAGER.MG VIBRATION ALARM : HIGH ABSOLUTE VIBRATION (2V3) - GENERATOR 11.5 -0.5 mm/s
Y.LAGER.S VIBRATION VERY HIGH ABSOLUTE VIBRATION (2V3) - GT - GT TRIP 14.7 -0.5 mm/s
Y.LAGER.SA VIBRATION Block threshold absolute vibrations – clutch – single shaft configuration only 14.7 -0.5 mm/s B
Y.LAGER.SG VIBRATION VERY HIGH ABSOLUTE VIBRATION (2V3) - GENERATOR - GT TRIP 18 -0.5 mm/s
Y.WELLE.01 VIBRATION BEARING RELATIVE VIBRATION: LOWER LIMIT FOR MONITORING (REFERENCE VALUE) 5 micron
micron
Y.WELLE.M VIBRATION ALARM : HIGH RELATIVE VIBRATION (2V3) - GT 164
p-p
micron
Y.WELLE.MA VIBRATION Alarm relative vibrations – clutch – single shaft configuration only 164 B
p-p
micron
Y.WELLE.MG VIBRATION ALARM : HIGH RELATIVE VIBRATION (2V3) - GENERATOR 165
p-p
This list includes the parametric values to be set in the GT control system and it is released to the Customer FOR INFORMATION ONLY.
The values herewith listed are under Ansaldo responsibility and any modification by the Customer is not allowed.
Notes:
All values marked with * can be optimized only during the commissioning phase. Slight adjustments of these values is therefore possible.
The values marked with ** are for operator reference only, they are NOT used by the control system.
The values marked with *** are used as first attempt during GT commissioning. The proper and final values will be set before the acceptance test.
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PROCESS INTERFACE DATA
See the attached document
Page 1 of 1
PROCESS INTERFACE DATA TGO1-1000-E71000
06.10.14
Project MC: Owner:

Consultant:
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DOCUMENT TITLE: GT PROCESS INTERFACE DATA

Serial
No.
MAZ AEN 01 MB* PR DSH 001 B
GT
PROCESS INTERFACE DATA

2
0 XX/XX/XXXX

C
B.M.Santolini (TC) L.Pizzimenti T. Capotos (PE) P.Pesce
B 22/10/2016 Minor correction
PEM/GTE PEM/GTE PEM/PRE PEM/GTE
B.M.Santolini (TC) R. Gatti F. Pinca (PE) L. Di Pasquale
A 06/08/2015 First Emission
IPI/TGS IPI/TGS IPI/PRE IPI/TGS
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Revision Record
1
2
3 X
4
5
6
7
8
9
10
11
12
13
14
15
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INDEX
1. SCOPE OF THE DOCUMENT 4

2. LIST OF CONNECTION POINTS 5
2.1 P&ID: MAZ-AEN-01-MBA-PR-PID-003 (S1MBAS003) – COMPRESSOR WASHING SYSTEM 5

2.2 P&ID: MAZ-AEN-01-MBA-PR-PID-004 (S1MBAS004) – DRAINAGE SYSTEM 6
2.3 P&ID: MAZ-AEN-01-MBX-PR-PID-001 (S1MBXS001) – HYDRAULIC OIL SYSTEM 7
2.4 P&ID: MAZ-AEN-01-MBA-PR-PID-005 (S1MBAS005) – RDS SYSTEM 8
2.5 P&ID: MAZ-AEN-01-MBX-PR-PID-002 (S1MBXS002) – PNEUMATIC SYSTEM FOR BLOW OFF 8
2.6 P&ID: MAZ-AEN-01-MBR-PR-PID-001 (S1MBRS001) – EXHAUST GAS DIFFUSER 9
2.7 P&ID: MAZ-AEN-01-MBP-PR-PID-001 (S1MBPS001) – FUEL GAS SYSTEM 10
2.8 P&ID: MAZ-AEN-01-MBN-PR-PID-001 (S1MBNS001) – FUEL OIL SYSTEM 11
2.9 P&ID: MAZ-AEN-01-MBQ-PR-PID-001 (S1MBQS001) – IGNITION GAS SYSTEM 13
2.10 P&ID: MAZ-AEN-01-MBH-PR-PID-002 (S1MBHS003) – FUEL OIL SEAL AIR COOLING SYSTEM 14
2.11 P&ID: MAZ-AEN-01-MBL-PR-PID-001 (S1MBLS001) – AIR INTAKE SYSTEM 14
2.12 P&ID: MAZ-AEN-01-MBN-PR-PID-002 (S1MBNS002) – HIGH PRESSURE PURGING WATER SYSTEM 15
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1. SCOPE OF THE DOCUMENT

Scope of this document is to report the information relevant to the fluids at interface
connection between the Gas Turbine scope of supply and the power island. The number of
the connections (flange) are reported in the Gas Turbine P&ID. The given fluid data are not
for design purpose, but refer to operating condition.
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2. LIST OF CONNECTION POINTS
2.1 P&ID: MAZ-AEN-01-MBA-PR-PID-003 (S1MBAS003) – COMPRESSOR

WASHING SYSTEM
Interface 83A
Task Tank discharge (through manual valve)
Fluid Demi water
Amount 700 dm3 (only in case of tank discharge required)
Pressure atmospheric
Temperature ambient
Interface 82
Task Filling of the tank MBA18BB002
Fluid Demi water / Detergent
Amount max. 700 dm3
Temperature ambient
Note: for a complete off line compressor cleaning procedure, required water is: 700 dm3 for
washing (with detergent if required) + 1300 dm3 for rinsing (water or mixture of water and
detergent).
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2.2 P&ID: MAZ-AEN-01-MBA-PR-PID-004 (S1MBAS004) – DRAINAGE SYSTEM
Interface 30A
Task Water drainage after off line compressor cleaning
Fluid Demi water or demi water + detergent
Amount 700 dm3 for washing + 1300 dm3 for rinsing
Temperature ambient
Note: interface 30B is for sampling purpose, fluid characteristic as per 30A
Interface 111A
Task Fuel oil drainage after fuel oil false start up
Fluid Water + Fuel oil mixture
Amount about 4,5 kg (only in case of fuel oil faulty GT start)
Pressure max. 4 bar
Temperature max. 80 °C
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2.3 P&ID: MAZ-AEN-01-MBX-PR-PID-001 (S1MBXS001) – HYDRAULIC OIL

SYSTEM
Interface 73A
Task Filling (through manual valve, after a discharge for maintenance)
Fluid Hydraulic oil
Amount 600 dm3 (only first filling)
Temperature ambient
Interface 61A / 62A

Task Pre-charge of accumulator
Fluid Nitrogen for accumulator in hydraulic oil system
Amount 10 dm3 (only at pre-charge)
Pressure 105 bar
Temperature ambient
Interface 63A / 64A

Fluid Nitrogen for accumulator in hydraulic oil system
Pressure 105 bar
Temperature ambient
Interface 65A
Fluid Hydraulic oil
Amount 600 dm3 (only in case of tank discharge required)
Temperature ambient
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2.4 P&ID: MAZ-AEN-01-MBA-PR-PID-005 (S1MBAS005) – RDS SYSTEM
Interface 640A / 641A

Fluid Nitrogen for accumulator in RDS system
Pressure 145 bar
Temperature ambient
2.5 P&ID: MAZ-AEN-01-MBX-PR-PID-002 (S1MBXS002) – PNEUMATIC SYSTEM

FOR BLOW OFF
Interface 29E
Fluid Instrument Air
Task provision for tank charge with plant instrument air
Amount 270 dm3
Flow rate: min. 15 Nm3/h (*)
Pressure 7 ÷ 8 bar(g)
Temperature ambient
Interface 88A
Fluid Water / condensate
Task drainage discharge
Amount negligible
Temperature ambient
(*) the air supply to the tank is discontinuous, it is required only in case of failure of the
compressors.
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2.6 P&ID: MAZ-AEN-01-MBR-PR-PID-001 (S1MBRS001) – EXHAUST GAS

DIFFUSER
Interface 601
Fluid Water / Condensate
Task drainage of condensate
Amount negligible
Temperature ambient
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2.7 P&ID: MAZ-AEN-01-MBP-PR-PID-001 (S1MBPS001) – FUEL GAS SYSTEM
Interface 14A
Task Natural Gas supply to Fuel Gas System
Fluid Natural Gas (composition according to contract requirements)
Flow rate max 17.1 kg/s (based on design fuel gas LHV )
Pressure 29 bar(g)  3%
Temperature
Nominal 30°C; (in any case +25°C above the dew point of the mixture
must always be ensured)
Maximum 50°C
GT Start up ≥ 10°C
Change rate (dT/dt) ≤ 5°C/s
Interface 15A
Task Fuel gas vent after fuel gas system disconnection
Fluid Natural gas
Volume to be vented 0,09 m3
Amount max. 2 kg (only at vent opening)
Pressure 29 ÷ 0 bar(g) (**)
Temperature refer to flange 14A (same temperature conditions)
(**) since it is a vent to the atmosphere, the downstream pressure shall decrease from 29
bar(g) to atmospheric discharge.
Interface 16A
Task Line inertization for maintenance operation
Fluid Nitrogen
Flow rate (***) (only at NG system inertization for maintenance)
Temperature ambient
(***) depending on the volume to be inertized, according to the maintenance procedure.
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2.8 P&ID: MAZ-AEN-01-MBN-PR-PID-001 (S1MBNS001) – FUEL OIL SYSTEM
Interface 9A
Task Fuel Oil Supply to Fuel Oil System
Fluid Fuel Oil (composition according to contract requirement)
Flow rate max. 150 m3/h  2%
Temperature (*)
Minimum: + 10 °C above Pour Point
Maximum: - 10 °C below Flash Point
Filtration Degree 10 µm
(*) The minimum requirement is in order to ensure the fuel oil to be pumped; if not fulfilled, the
fuel oil cannot be pumped not even in the booster system. The maximum requirement is to
avoid explosion protection measures, but this is not a critical issue for fuel oil n°2 type (light
distillate).
Interface 10A
Task Fuel Oil Return from Fuel Oil System
Fluid Fuel Oil
Flow rate max. 150 m3/h  2%
Pressure
Required Back Pressure max. 1,8 bar(g) (**)
Pressure from Fuel Oil side max 150 bar(g) at fuel oil injection pump start up
max 2 bar(g) when only leakage oil pump is in operation
Temperature: max. 80°C
(**) Attention: the maximum backpressure in the return line shall be ≤ 1,8 bar(g) in any
operating condition, so the downstream system must be designed accordingly.
Otherwise, fuel oil ignition cannot occur.
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Interface 13A
Fluid Air, Water and Fuel Oil mixture
Task Vent the fuel oil drainage tank
Amount: negligible
Interface 386A / 387A

Fluid Nitrogen for accumulator in fuel oil system
Pressure 3 bar
Temperature ambient
Interface 45A
Fluid Fuel oil mixture and water
Amount 1,6 m3 (only in case of tank discharge required)
Temperature ambient
Interface 12B
Task Drain for maintenance (through manual valve)
Fluid Fuel oil mixture and water
Amount 0,3 m3 (only in case of return line discharge required)
Temperature ambient
Interface 373A
Task Vent the back-purge system (during premix oil operation)
Fluid Air, Water and Fuel Oil mixture
Amount negligible
Temperature ambient
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2.9 P&ID: MAZ-AEN-01-MBQ-PR-PID-001 (S1MBQS001) – IGNITION GAS

SYSTEM
Interface 20A
Fluid Propane (preferred), butane or propane / butane mixture
Task Vent the ignition gas system at GT start with fuel oil
Volume to be vented 0,2 m3
Amount max. 1,3 kg (only at vent opening)
Interface 244A
Fluid Propane (preferred), butane or propane / butane mixture
Task Supply Ignition Gas for fuel oil ignition (at GT start with fuel oil)
Flow Rate 0,2 kg/s (max. continuously for 180 sec) (*)
Temperature min. 40 °C (**); max. 80 °C
(*) Total amount for single ignition is about 35 kg
(**) The minimum temperature is referred to propane. In case of other mixtures, the minimum
temperature must be higher to ensure the proper inlet pressure required at flange 244A.
The use of propane is suggested in order to reduce the heating of the ignition gas. The
minimum temperature in case of propane-butane mixture depends on the type of mixture.
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2.10 P&ID: MAZ-AEN-01-MBH-PR-PID-002 (S1MBHS003) – FUEL OIL SEAL AIR

COOLING SYSTEM
Interface 325A
Fluid Air
Task Inlet of primary medium to heat exchanger
Flow Rate 4.8 m3/s
Pressure ambient
Temperature max 52 °C
Interface 325B
Fluid Air
Task Outlet of primary medium to heat exchanger
Flow Rate 4.8 m3/s
Pressure ambient
Temperature 150 °C
2.11 P&ID: MAZ-AEN-01-MBL-PR-PID-001 (S1MBLS001) – AIR INTAKE SYSTEM
Interface 31A
Task Drainage of water for Compressor washing
Fluid Demi water/ Water with detergent
Flow rate max. 2 kg/s
Temperature ambient
Note: 31A is a connection for drains, placed at ground level collecting Demi water /detergent for
compressor cleaning (reason of 2kg/s).
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2.12 P&ID: MAZ-AEN-01-MBN-PR-PID-002 (S1MBNS002) – HIGH PRESSURE

PURGING WATER SYSTEM
Interface 59A
Task Filling the purging water tank
Fluid Demi water
Amount 2 m3
Flow rate 0,3 kg/s
Pressure 1 ÷2 bar
Interface 192A
Task Manual drainage of the purging water tank
Fluid Demi water
Amount 2 m3 (only in case of tank discharge required)
Pressure ambient
Temperature max. 60°C
Interface 217A
Task Vent the purging water tank
Fluid Water and Air mixture
Flow Rate negligible
Interface 420B
Task Drain the purging water line
Fluid Water
Amount 5 dm3
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DESCRIPTION
Technical Data
RATING PLATE DATA
Ansaldo Energia S.p.A.
Gas Turbine Model

AE94.3A
Order / Job – N.: 0558
Nominal Power: 310 MW
Speed Frequency : 50 Hz
MADE IN ITALY
Ansaldo Energia S.p.A.
Serial – No: G057AA

Year of Construction: 2016
Pagina 1 di 1
RATING PLATE DATA TGO2-0020-E71558
21.03.17
DESIGN DATA
TYPE: AE94.3A Unit BASE LOAD

Fuel -- FUEL GAS FUEL OIL
Low Heating Value kJ/kg 47878 42600
Gross power output at generator terminals MW 301.7 248.9
Gross efficiency at generator terminals % 39.42 38.56
Exhaust mass flow kg/s 734 733
Exhaust temperature °C 579 512
Opening degree IGV % 100 100
Reference ambient conditions:
- Grid frequency Hz 50
- Temperature °C 16.5
- Pressure mbar 1007.7
- Relative humidity % 78
- Power factor - 0.85
Pagina 1 di 1
DESIGN DATA TGO2-0100-E71558
21.03.17
DETERMINATION OF TEMPERATURES LIMITS IN THE EXHAUST DUCT
Description
To protect the gas turbine against overheating which may occur during normal operation, the
reaction times of the thermocouples must be as short as possible.
For this reason, the exhaust gas temperatures TET are measured immediately downstream of the
turbine by 24 thermocouples (MBA26CT101,….124) distributed around the circumference of the
turbine diffuser.
Each thermocouple has three channels A,B and C. The first channel (A) readings are used to
calculate the corrected exhaust gas temperature used for control purpose. For proper location of
these thermocouples see section TGO2-2700.
The second and third channels readings (B and C) are used for protection in event of overheating.
All temperature measurements are displayed at control desk
The exhaust gas temperature (TET) is corrected with the value of the compressor inlet
temperature (CIT) (measured at MBA11CT101, …102, …103) in order to give the so called TETC
(corrected turbine exhaust temperature) which is always representative of the heat condition of
the gas turbine.
In order to operate the gas turbine almost at the same turbine inlet temperature (TIT) also when
changing the ambient conditions and since it is not possible to measure directly the TIT, an
indirect way of control the TIT is to use the following parameter TETC (corrected exhaust gas
temperature)
The corrected turbine outlet temperature is calculated by the following:
TETC = TET- (K1 + K3 x CIT) x CIT - (1 .n/n 0 ) x K2
Page 1 of 3
DETERMINATION OF TEMPERATURES LIMITS IN THE EXHAUST DUCT TGO2-0114-E72000
24.11.14
Where:
TET = actual exhaust gas temperature, measured as average by the six A thermocouples.
CIT = compressor inlet temperature
n= actual speed
n0 = rated speed
K1 = 0.37 (e.g.)
K2 = 200 (e.g.)
K3 = 0.007 (e.g.)
Value of K1, K2, K3 to be found in the Set Point List (TGO1-0530)
NOTE:
Since the NOx levels increase in a significant manner below 15°C of ambient temperature and due to
the relative humidity, in order to maintain the NOx level at contractual limits in all ambient
conditions, a NOx derating curve as function of ambient temperature and relative humidity is also
applied.
In order to take into account also the gas composition on the NOx influence, a derating curve based
on the fuel C/H (*) and LHV (**) is used. The curve comes active in case of strong variation in the
fuel gas supply in terms of composition.
(*) C/H is the ratio between the carbon mass and the hydrogen mass in the supplied natural gas
(**) LHV = Low Heating Value of the supplied natural gas.
See the relevant Set Point List (TGO2-2020) to see which correction is applied to the specific project.
TETC setting
An initial and preliminary value for the TETC control is implemented during the commissioning phase,
the final value is set during the performance test.
Page 2 of 3
24.11.14
Note:
For more uniform and representative measure of the temperature in the boiler, at gas turbine
diffuser end 6 thermocouples (MBR20CT101…106) are located. They are not used in the control logic
of the gas turbine control but used during the performance test in order to calculate the TIT in
accurate manner.
Note: after HGPI or Major Inspection or burner replacement or other intervention should be
necessary, the TETC set can be changed
The new setting of TETC can be carried out only by Ansaldo Energia personnel, Gas Turbine
Engineering Department (TGS) or Gas Turbine Service Department (GSE)
See in addition section:

Exhaust gas Temperature Control TGO3-0100
Exhaust gas Temperature Protection TGO3-0110
Temperature Limits at the Turbine Outlet.
After the final setting of the TETC at the base load, the temperature values for each thermocouple
are registered. For each thermocouple, specific limits for alarm and trip are set and used for the
protection logic of the gas turbine. The logic is explained in detail in section TGO3-0100.
In addition to what above, the gas turbine is protected by the following general criterion based on
the TETC:
 When TETC > TT.ATK.M07  alarm

 When TETC > TT.ATK.S07  GT trip
Where as a rule the following setting is used:

TT.ATK.M07=TETC (base load) +50°C
TT.ATK.S07= TETC (base load) +90°C
For the proper values order related see the Set Point List in section TGO1-0530.
Anyway, before the above mentioned protection, in general the gas turbine has already been tripped
by other more specific protections which intervene earlier.
Page 3 of 3
24.11.14
SETTING OF START UP PARAMETERS
Description
Refer also to
Set Point List TGO1-0530
Blow off system description TGO2-4411
The values here stated in this description are only guideline values.
Introduction
Setting of the following parameters is to ensure that the acceleration time of about 4 minutes will be
achieved with the lowest possible thermal stresses on the turbine. The proper parameters are set
during the commissioning phase and they cannot be modified by the operator .
During startup, the following parameters should be recorded as a function of time:

• Speed n
• Premix Control valve lift
• Pilot2 gas Control valve lift
• Corrected turbine exhaust temperature TETC
• Compressor discharge pressure PVII
• Fuel gas pressure (during fuel gas operation)
• Acceleration levels
 Fuel oil supply pressure (during fuel oil operation)
• Fuel oil return pressure (during fuel oil operation)
• Fuel oil Diffusion Feed Control valve lift
• Fuel oil Return Control valve lift
Humming levels are useful as well although not directly linked to the GT protection
On graphics, indicate also the scale and any offset of the parameters recorded.
Page 1 of 3
SETTING OF START UP PARAMETERS TGO2-0116-E70005
24.11.14
Startup Procedure with Fuel Gas
Ignition occurs at speed S.TURB.09. The pilot gas control valve (PILOT2-CV) is set in order to allow the
start up mass flow F.EGDB.01.
At speed S.TURB.157 the premix control valve (FG-PREMIX-CV) is opened to the start up mass flow
F.EGVB.01.
Here the pilot gas control valve (PILOT2-CV) lift is adjusted as a function of time according to 4
gradients speed dependant:
• 1st gradient JK.EGDB.01 is applied after speed S.TURB.53
• 2nd gradient JK.EGDB.02 is applied after speed S.TURB.54
• 3rd gradient JK.EGDB.05 is applied after speed S.TURB.541
• 4th gradient JK.EGDB.052 is applied after speed S.TURB.542
Note: in case of black start up (e.g. by diesel) the applied gradients can be different, see Set Point List
order related.
Startup frequency converter switched off at approx. 70% on nominal speed
After the reaching of the speed S.TURB.70, the blow off valves receive the closed command as it
follows::
Blow off valve Command

N > S.TURB.07 A2 Closed
N > S.TURB.13 A1.2 Closed
N > S.TURB.13 + 5 s delay A1.1 Closed
N > S.TURB.13 + 20 s delay A3 Closed
When the last blow off is closed and after a certain delay (ex. 30s) the pilot control valve (PILOT2-CV)
is adjusted according to its mass flow set point depending on the GT operating condition conditions
(TETC, IGV) and on the ambient conditions (TVI, PCI), while the GT controller acts on the premix
control valve. This configuration is maintained for all the GT operation involving fuel gas mode.
Protective Function
Additionally, a speed-dependent protective function is implemented.
This protective function (limiting function) serves to limit the start-up function over a MINIMUM
selection when the required thermal output is larger than permissible at certain speed (e.g. in the
case of a start-up converter being too weak or set too low). The limiting function is set in form of 6
points table (J.EG.04 to J.EG.09, see Set Point List).
Page 2 of 3
24.11.14
As a rule, assuming no disturbances occur, the gas turbine runs up to full speed by normal startup
without intervention of the speed-dependent protective function.
Startup Procedure with Fuel Oil
Ignition occurs at speed S.TURB.31 by opening the ignition gas valves. The fuel oil stop valves are
opened at speed S.TURB.30. The fuel oil start up mass flow is F.HOEDB.01.
In order to take into account different start up conditions (e.g. cold, warm, hot), the fuel oil mass
flow for the ignition is corrected according to a proper function of the exhaust temperature before
start up (see parameters TT.ATK.41…46 in the set point list).
Here the fuel oil return control valve lift is adjusted as a function of time according to 4 gradients
speed dependant:
• 1st gradient JK.HOEDB.01 is applied after speed S.TURB.55
• 2nd gradient JK.HOEDB.02 is applied after speed S.TURB.56
• 3rd gradient JK.HOEDB.05 is applied after speed S.TURB.561
• 4th gradient JK.HOEDB.051 is applied after speed S.TURB.562
Note: in case of black start up (e.g. by diesel) the applied gradients can be different, see Set Point List
order related.
Startup frequency converter switched off at approx. 70% on nominal speed
After the reaching of the speed S.TURB.70, the blow off valves receive the closed command as it
follows:
Blow off valve Command

N > S.TURB.70 + K.ABBL.02 A1.1 Close
N > S.TURB.70 + K.ABBL.02 + 10 s A1.2 Close
N > S.TURB.70 + K.ABBL.02 + 20 s A2 Close
N > S.TURB.70 + K.ABBL.02 + 30 s A3 Close
The GT is synchronized in fuel oil diffusion mode.
Protective Function
Additionally, a speed-dependent protective function is implemented.

This protective function (limiting function) serves to limit the start-up function over a MINIMUM
selection when the required thermal output is larger than permissible at certain speed (e.g. in the
case of a start-up converter being too weak or set too low). The limiting function is set in form of 6
points table (J.HOE.04 to J.HOE.09, see Set Point List).
As a rule, assuming no disturbances occur, the gas turbine runs up to full speed by normal startup
without intervention of the speed-dependent protective function.
Page 3 of 3
24.11.14
AUTOMATIC LOADING AND UNLOADING
During normal GT operation, the following loading / unloading gradients are applied:
 EK.LEIST.08 (Normal gradient): from GT minimum load after synchro up to IGV fully open
condition
 EK.LEIST.03 (Slow gradient): from IGV fully open condition up to base load operation
The figure 1 shows a general behaviour of the Turbine exhaust gas temperature, IGV position and Air
flow rate as function of GT power output during loading / unloading processes.
Note: First Compressor Vanes (CV1) are moved according with IGV movement.
Figure 1: Loading / unloading : Exhaust gas temperature, IGV position and Air flow rate as
function of GT Power Output
Page 1 of 1
AUTOMATIC LOADING AND UNLOADING TGO2-0120-E71000
27.02.18
POWER OUTPUT AS FUNCTION OF AMBIENT TEMPERATURE
The following curves are for reference only, the contractual curves are reported in
the performance test report.
 Power Output at generator terminals (range +15°C + 55°C)
R.H. relative humidity
Page 1 of 2
POWER OUTPUT VS AMBIENT TEMPERATURE TGO2-0124-E71000
10.12.14
Power Output at generator terminals (range -20°C + 15°C)
R.H. relative humidity
Page 2 of 2
POWER OUTPUT VS AMBIENT TEMPERATURE TGO2-0124-E71000
10.12.14
DIMENSIONS AND WEIGHT
This section shows dimensions and weights of main components of the gas turbine
The gas turbine consists of one piece named “flange to flange” showed in figure 1 (casing, rotor,
blades and vanes, bearings) and the other components in the following listed.
Not mentined here other inor components such as:

 connecting piping,
 end flanges,
 electric measuring instruments (thermocouples, pressure transducers, etc.) which are
installed at the power plant,
 tools,
 insulation,
 transportation devices,
 spare parts (filters, etc.),
 operating media (lube oil, hydraulic oil, etc.).
Figure 1: Gas Turbine “flange to flange”
Page 1 of 3
DIMENSIONS AND WEIGHT TGO2-0130-E71001
21.11.14
N. Description Weight 1) Dimensions 1)
L x B x H (L x )
kg mm
1 Gas turbine, flange to flange 316550 10800 x 5050 x4900
Sub items (not to be considered for shipment since included in item 1)

1.1 Compressor bearing pedestal -upper 8932/14367 1812 x 4100
part/lower part
1.2 Compressor stationary blading 1 –(with 3120 x 3800 x 1800
stationary blade ring) – and associated
adjusting device
Upper part 24000
Lower part 24000
1.3 Compressor stationary blading 2 (with
stationary blade ring)
Upper part 6000 1200 x 2700 x 1350
Lower part 6000 1200 x 2700 x 1350
1.4 Combustion chamber – Outer casing
Upper part 3200 1250 x 4100
Lower part 3200 1250 x 4100
1.5 Turbine – Blade carrier
Upper part 14100 1750 x 4050 x 1900
Lower part 14900 1750 x 4050 x 1900
1.6 Casing 2: upper part/lower part 8974/9147 1350 x 5040 x 2320
1.7 Casing 3: upper part/lower part 22598/23402 3168 x 5040 x 2320
1.8 Burners (24 pieces) 2000 (total) 1000 x 400
1.9 Rotor (complete) 114150 9900 x 4300
Sub items of item 1.9 (included in rotor complete)
1.9.1 Turbine – Bearing housing 17700 1800 x 4300
1.9.2 Shaft cover 11900 1700 x 3100
1.9.3 Rotor 84550 9750 x 3250
1. Tolerance for weights 100kg and 50 mm for dimensions
Page 2 of 3
21.11.14
N. Description Weight 1) Dimensions 1)
L x B x H (L x )
kg mm
2 Intermediate shaft 7870 4473 x F1100
3 Compressor supports (2 pieces, 1 for 22200 (total) 1590 x 2096 x 3438 (2x)
side)
4 Centering support 2750 650 x 1050 x 3200
5 Diffuser 3300 2000 x 4300 x 4800
6 Blow off line (4x) 4000 (total) 6500 x 400 (4x)
7 Cooling air line (5x) 2100 (total) 4500 x 250 (5x)
1. Tolerance for weights 100kg and 50 mm for dimensions
For auxiliary systems refer to the Outside Vendor Part Manual.
Page 3 of 3
21.11.14
REQUIREMENTS FOR GAS TURBINE WORKING FLUIDS
This section refer to both liquid and gaseous fuel. For gas turbine operating in fuel gas mode only,
the liquid fuel section is not applicable.
Proper Use of the Gas Turbine

As a supplement to the description of proper operation given in section TGO1-0045, the following
includes a more detailed explanation of approved fuels.
Only those fuels which are stipulated in the supply contract shall be permissible for operation of gas
turbines. Operation with fuels other than those contractually stipulated is not permitted. The
definitive evaluation of gaseous and liquid fuels will be made by Ansaldo Energia.
This Section gives limits for contaminants in the GT working fluids air, fuel and water as well as the
procedures to be used for determining these concentrations; if the working fluids contain
contaminants for which no limits are prescribed, this must be clarified with the Ansaldo on a case to
case basis. Gas turbine operation without filtration or without adequate filtration (e.g. damaged
filter) shall not be permitted. Handling of fuels shall be subject to all regulations stipulated in the
operating documentation and technical documentation.
Risk of injury!
Improper use of the gas turbine can adversely affect the (operational) safety of the GT
and result in personal injury and equipment damage.
General
In the open gas turbine cycle, large amounts of the working fluids air, fuel and water are processed
by the turbine (in contrast to the steam cycle, in which the same working fluid is circulated through a
closed loop).
Ideally, these working fluids are “pure”, i.e. they contain no contaminants which are harmful to the
gas turbine or the exhaust gas path.
This ideal situation does not hold in practice, and contaminants can enter the gas turbine in the
following ways:
Via contamination of the:
• intake air
• fuel
• water injected for NOx reduction or operation with evaporative / fogging (where applicable)
• washing water for compressor cleaning or burner washing
Contamination of these working fluids can have various effects; these are listed under “Effects of
Contaminants and Measures”.
Operation of gas turbines for the duration of the normal maintenance interval is only possible if
Page 1 of 20
REQUIREMENTS FOR GAS TURBINE WORKING FLUIDS TGO2-0160-E71001
12.10.17
prescribed limits (see “Limits for Chemical Contaminants...) for contaminants are adhered to and
monitored as specified. Furthermore, specified physical parameters of the working media must also
be adhered to during gas turbine operation. Pollutants can ingress into the fuel and intake air in the
following ways:
Table 1 : Origin of GT pollutants
Fuel Air
Na - Originating in rock formation from which crude oil mas - Aerosols at coastal locations
obtained - Washing of filters to remove
- Seawater used a ballast in tankers which have no cargo dust containing salts
transfer to GT fuels if tanks and piping are not flushing prior
to pumping GT fuel
- In dust contained in gaseous fuels
K - Minor costituent of seawater (K/Na  1:28) - Dust of mineral origin (clay,

- Dominant in plant matter (coal-based fuels) feldspar)
Pb - Tetraethyl and tetramethal lead as a fuel additive. - Automotive exhaust gases
In GT fuels stored in refinery tanks/pipings which were not
flushed prior to pumping of fuel, not water soluble!
V - Originating in rock formation from which crude oil was

obtained, present as water-insoluble vanadium porphyrin
complex
- Enriched in residual oil
In GT fuels stored in refinery tanks/piping which were not
flushed prior to pumping of fuels
Definitions:
ASH Designation of incombustible constituents left on complete combustion of organic

substances
SEDIMENT Designation for loose solid mineral matter arising from physical, chemical or, to a lesser extent,
biogenic weathering of previously existing rock. For this application: inorganic contaminants (sand)
entrained in liquid fuels (crude oil, residual oil, etc.) in pumping, transportation or storage.
DUST Designation for dispersed solid matter in gases, arising from mechanical processes or entertainment.
For this application, the term dust is used to indicate all solid particles of a grain size less than 200
m.
Page 2 of 20
12.10.17
Table 2: Effects of contaminants and measures
Constituent or Parameter Effect (s) Measures / Remarks

Vanadium Hot corrosion - Adjustment of the operating
hours meter if limit is slightly
exceeded.
Lead Hot corrosion - Strict adherence to limits
Alkali metals (Na, K) Hot corrosion (Alkali sulfate corrosion) - Fuel washing
- Filtering of intake air (prevent
dissolution of salts retained in
filter during rainy weather!)
- Demineralization of water
Calcium (Ca) Formation of hard deposits on blades - Fuel washing
which cannot be removed by washing with
water, if these deposits flake off,
downstream items can be damaged by
erosion.
Chlorine (Cl) + Fluorine (F) Formation of HCl or Cl2 and HF. - Fuel washing (gases)
- Accelerated corrosion mechanisms - Fuel cleaning (oils) (centrifuging
with austenitic materials (acid or electrostatic separation)
corrosion)
- Hot corrosion
Sulfur (S) Nearly complete conversion to SOx. - Observe applicable SOx emissions
- Compounds such as Na2SO4, K2SO4, limits
Na3Fe(SO4)3 are also corrosive, as
their melting points lie within the GT
temperature range (alkali sulfate
corrosion)
Hydrogen Sulfide (H2S) Acid anhydride soluble in water - Fuel preheating
condensation (piping corrosion – fuel - Increased risk of autoignition
preheating) - Refer to sulfur
Hydrogen (H2) > 1 Vol. % Increased flame velocity - Possible explosion protection
Acetylene (C2H2) > 0.1 Vol. % measures must be clarified in
individual case
Liquid fuel gas constituents Burner cooking, flashback, sudden input of - Heating to temperatures of at
(higher molecular large amounts of energy least 10K above dew point of the
weight - Overheating corresponding CnHm
hydrocarbons)
Water Clogging of filter, erosion - Fuel cleaning (centrifuging or
electrostatic separation)
Dust, sediments Clogging of filter, erosion, formation of - Cleaning of fuel and intake air
deposits, hot corrosion, acid corrosion (filtering, electrostatic
separation)
Page 3 of 20
12.10.17
If the levels of fuel contaminants are no higher than a following limits, the gas turbine can be
operated at a permissible output without restriction or shortening of a specified inspection intervals.
As a matter of principle, the total ingress of all contaminants with the process media air, fuel and H2O
is the determining factor for damage to the gas turbine and its component parts!
The working fluid inside the admissible limits are indicated with f=1 and no penalization to the
equivalent operating hours applies (see also section TGO3-0126)
Compressor Intake Air
Contaminants
The compressor intake air filters are designed to adhere to the requirements of the Table 3 according
to the site condition. Countermeasures shall be taken in case of exceeding limits below reported.
Table 3 – Limits for compressor intake air (f=1)

Contaminants Test Unit Compressor intake air
downstream of filters (empirical
values)
Dust total ASTM D 3605 ppm (weight)  0.08
d < 2 m  0.06
2 < d < 10 m  0.02
d > 10 m  0.0002
d > 25m 0
Vanadium (V) DIN 51790 ppm (weight)  0.001
ASTM D 3605
Lead (Pb) DIN 51790 ppm (weight)  0.002
ASTM D 3605
Sum of Sodium (Na) + Potassium (K) DIN 51790 ppm (weight)  0.001
ASTM D 3605
Calcium (Ca) ASTM D 3605 ppm (weight)  0.02
Caution!
Danger of equipment damage: due to the sensitivity of the cooling air system to clogging by dust
particles, the gas turbine must never be operated with a defective intake air filter or none at all.
Cleaning intervals for the intake filters must absolutely be complied with
Page 4 of 20
12.10.17
Corrosive air contaminants such as salts which can enter the turbine through the intake of seawater
droplets or salt-containing dust particles must be separated out to the greatest extent possible. This
must be ensured with suitable filter equipment (droplet separator if necessary) and timely cleaning
of filters. The following danger prevails in particular at sites with salt-laden air and extended dry
periods: if the intake filter is not cleaned often enough, salt-laden dust which accumulates on the
filter elements is dissolved when humidity reaches high levels. This causes a very high concentration
of salts in the intake air entering the gas turbine and the resultant corrosion damage.
Moisture
Components in the compressor, combustion chamber and turbine (with the exception of the turbine
blading and the hot gas path casing) are subject to corrosion damage in moist air.
During operation, impermissibly high humidity can only occur in the area of the initial compressor
stages because the air is heated so rapidly in compression. Coating of the first five rows of stationary
blading and the first six rows of moving blading with a film containing aluminum pigment is sufficient
to prevent impermissible pitting damage.
During outages the entire gas turbine must be protected against impermissibly high humidity (>50 %
rel.) in the flow areas. Provisions must be made for closing off the intake duct (e.g. damper or similar
device) after a time delay (sufficient for cooldown of the rotor). The dehumidifier must be operated
simultaneously to remove moisture from the air. Even in unfavorable climates, these measures
sufficiently reduce the relative humidity of the air enclosed in the gas turbine to suppress corrosion.
Low Intake Temperatures

Icing
At air temperatures below freezing and high humidity, ice can form in the intake area where the air is
cooled by acceleration. Although most Ansaldo gas turbines which operate under such conditions are
not provided with deicing equipment, no cases of damage have yet been observed which were
determined to be caused by ice formation on the blading or duct walls, however when the external
conditions require, it is suggested the use on anti-icing.
Extremely Low Intake Temperatures
If the gas turbine cools during an outage to the extent that all rotor parts reach temperatures below
0C, the rotor disks and tie bolt are in danger of brittle fracture. This can be prevented by closing off
the intake duct and heating the enclosed air to ensure that this cannot occur.
Unrestricted operation, including water injection, is possible at intake temperatures down to -100C.
At ambient temperatures between -10° and -30°C, unrestricted GT operation is only permissible
without water injection.
In these cases and in the case of ambient temperatures below -30 C, contact Ansaldo Energia, Gas
Turbine Engineering Department (GTE).
Page 5 of 20
12.10.17
Fuel gas requirements
Refer to the fuel gas composition as per contract specification.

The contaminants limits, showed in table 4, shall be fulfilled. Functional requirements are shown in
Table 5
Table 4: Limits for Chemical Contaminants (Fuel weighting factor f=1)

Contaminants Test Unit Prescribed value at flange 14 A
Dust: VDI2066 ppm(w)
total ASTM D2709/6304  20
d < 2 µm  18.5
2 < d < 10 µm  1.5
d > 10 µm 0
Vanadium (V) ppm(w)  0.5 (1)
Lead (Pb) (2) ppm(w) 1
Zinc (Zn) ppm(w) ≤2
Calcium (Ca) (3) DIN 51790 ppm(w) ≤ 10
Mercury (Hg) ASTM D 3605 ppm(w) 0 (1)
Sodium (Na) + ppm(w) ≤ 0.3 (1)
Potassium (K)
Chlorine (Cl) ASTM D895 ppm(w) ≤ 0.1
Fluorine (F) (4)
Total Sulfur (S) ASTM D 4468 ppm(w) ≤ 20 (5)
ASTM D 1072
Hydrogen Sulfide (H2S) ASTM D 4084 ppm(v) ≤ 10 (5)
ASTM D 4810
Mercaptane ASTM D 1988 ppm(w) ≤ 10
Notes to table 4
(1) No violations of the prescribed limits are permissible.
(2) In presence of other contaminants (Na, K, V) Pb accelerates the oxidation process. Pb damages
also the catalysts used for NOx reduction (SCR), therefore more stringent limits can be applied
in case of requirements of external equipment (e.g. SCR).
(3) Calcium after combustion can lead to hard deposits in combustion chamber and on the turbine
blades which cannot be removed by washing. These deposits degrade the performance and
can abrade turbine coatings.
(4) Chlorine and Fluorine accelerate hot corrosion of turbine parts in presence with sodium and/or
sulphur. In addition Chlorine can also contribute to boiler and exhaust stack corrosion.
(5) Elementar sulphur is not applicable to fuel gas. Sulphur content refers to sulphur compounds,
such as mercaptans, H2S, carbonyls COS and odorizing agents (THT). With a total S content > 20
ppm(w) provision for fuel pre-heating up to at least 60°C must be applied. In this case the
maximum H2S content can be up to 200 ppm(w) provided that some other
countermeasures/limitations are taken, please consult Ansaldo Energia in this case.
Page 6 of 20
12.10.17
Warning: if gas compressors are used, they must be absolutely lube-oil-free.
Warning: Comprehensive evaluation of all available fuels is only possible if a separate analysis
is performed for each fuel in accordance with the subsection “Checklist for fuels”.
Table 5: natural gas composition required for standard burners
Gas Constituents (*) Test Prescribed value at flange 14 A
CH4 (methane) ≥ 80% vol
C2H6 (ethane) ≤ 15% vol
(1)
CnHm (n>2) ≤ 10 % vol
CnHm (n≥2) ≤ 20 % vo
N2+Ar+CO2 ≤ 20 % vol
(2)
H2 (hydrogen) ≤ 1 % vol
C2H2 (acetylene) ASTM D1945 / (2)
≤ 0.1 % vol
O2 ISO6974 / ≤ 0.1% vol
H2O ISO6975 Proper temperature to be selected to avoid condensation
S Elementary Sulphur not allowed, see Table 1
CO Normally not present in natural gas, to be evaluated case by case
Fuel Bound N NOx formation cannot be controlled by water/steam
Other To be evaluated case by case
(3)
Liquid hydrocarbons, oil 0
compounds, condensate
(5)
Low heating Value (LHV) ASTM D 3588 Design range: 40000 ÷ 50035 kJ/kg (100% methane)
(4)
ISO 6976 Tolerance:  5 % of design value
Change rate:  1 % LHV / s
(6) 3 (7)
Wobbe Index ASTM D 3588 Design value: 42 ÷ 51 MJ/Nm
ISO 6976 Tolerance:  5 % of design value
Notes:
(1) Above this limit there is the risk of combustion instability due to increased flame velocity.
To be evaluated case by case.
(2) This value must absolutely be respect.
(3) If gas compressors are used, they shall be absolutely lube oil free.
(4) A "design value" must be selected between the minimum lower heating value (LHV) of
40000 kJ/kg and the maximum heating value of 50035 kJ/kg (depending on the fuel gas
analysis, the given tolerance shall apply to this value). Case by case evaluation shall be done
when LHV lies outside the permissible range.
(5) In case of fuel preheating, the allowed range is restricted to 45000 ÷ 50035 kJ/kg.
(6) The Wobbe index (LWI) is defined as the ratio between the Lower Heating Value in MJ/Nm 3
(LHV) and the square root of the relative density of natural gas (𝜌𝑓𝑢𝑒𝑙) to air (𝜌𝑎𝑖𝑟) at
standard temperature and pressure [0 °C, 1.013 bar].
Page 7 of 20
12.10.17
𝐿𝐻𝑉𝑣
𝐿𝑊𝐼 = = 𝐿𝐻𝑉𝑚 × √𝜌𝑓𝑢𝑒𝑙 × √𝜌𝑎𝑖𝑟
𝜌𝑓𝑢𝑒𝑙
√
𝜌𝑎𝑖𝑟
(7) In case of fuel gas preheating, the allowed range is restricted from 45 ÷ 51 MJ/Nm3. Larger
deviations in Wobbe index require evaluation case by case.
Referring to P&ID Fuel Gas System, the following interface data are given:
Inlet flange of the gas turbine natural gas skid (flange 14 A): see below Table 6.
Table 6 Functional requirements at fuel gas GT skid inlet

Parameter Condition Prescribed value at flange 14 A
Mass flow (m)
Design value 20 kg/s (1) (reference value)
Pressure (P)
Operating value 29 bar(g) (3)(4)
Tolerance range 0 ÷ 15% of the max.  5 % of design value
fuel flow
Range 15 ÷ 100% of the max.  3 % of design value
fuel flow
Change rate dP / dt  0.5 bar/s
Temperature (T) (2)
Nominal 30°C; in any case +25°C above the
dew point of the mixture must
always be ensured.
Maximum 50°C (3)
At GT start up ≥ 10 °C
Change rate dT / dt  5°C / s
(1) The proper mass flow value is specified case by case according to the ambient and site
condition and the fuel gas composition given for the specific offer / order. Refer to the GT
performance table.
(2) It is imperative to maintain +25°C of margin against the dew point of the mixture (as per ASME
B133.7) in order to avoid condensation of possible hydrocarbons. Anyway the fuel gas shall not
contain any condensate or liquid constituents. In case this requirement is fulfilled, in any case
the operating temperature shall be 30°C. The use of proper heater shall be used but care must
be taken in order not to exceed the maximum admissible temperature. Heater shall be used in
combination with liquid separators, if necessary.
(3) In case of fuel gas preheating (only when foreseen and included in the specific project), the
maximum temperature of the fuel gas is 110°C and the operating pressure is 31 bar(g).
Page 8 of 20
12.10.17
Anyway, there must be foreseen the possibility to supply fuel gas at normal temperature when
necessary. In case of fuel gas preheating Ansaldo Energia shall be consulted for further details.
(4) In case of range of fuel with LHV between 40.000 -44900 kJ/kg, the operating pressure is 31
bar(g).
Note: the fuel gas skid is equipped with connection for line inertization, if required for
maintenance operation, (flange 16 A). At this connection, only nitrogen can be used, at
pressure 3 ÷ 5 bar(g).
Page 9 of 20
12.10.17
Liquid Fuel Requirements
(Fuel oil conforming to ISO 4261; DIN 51603; ASTM D 396, 975, 2880)
The liquid fuels covered here include oils conforming to ISO 4261, DIN 51603 Part 1, ASTM D 396
(Fuel Oils), ASTM D 975 (Diesel Fuel Oils) and ASTM D 2880 (Gas Turbine Fuel Oils); the limits given in
the following table are binding for the use of the respective liquid fuel.
The limits given below must be observed for safe, reliable and fault-free gas turbine operation.
The limits are based on test procedures which are specified in the aforementioned standards. The
specified test procedures are used for verification of new analysis methods and are thus not binding
in the sense that analysis methods are not limited to these standards; in other words the use of other
analytic methods is permissible, provided the detection thresholds stipulated in the standards are
achieved.
The major inspection intervals for Ansaldo gas turbines are based on the use of fuels which meet
contractually-specified quality requirements.
Caution!
Danger of equipment damage: the use of crude and heavy fuel oils as fuel is subject to the
approval of Ansaldo Energia Gas Turbine Department (PEM/GTE).
The limits of table 7 shall be fulfilled. Functional requirements are shown in Table 8
Page 10 of 20
12.10.17
Table 7: Limits for Chemical Contaminants (Fuel weighting factor f=1)
Contaminants Test standard Unit
Prescribed value at flange 9A
Sediments and total D6217/DIN ppm(wt)  20
particulates (1) d < 10 µm EN12662  18.0
(for light 10  d  25 µm DIN51575  2.0
distillate) d > 25 µm 0
Ash (2) D482 / ISO6245 ppm(wt)  100
DIN51575 /
DIN EN 2645
Vanadium (V) ppm(wt)  0.5 (3)
Lead (Pb) (4) ppm(wt) 1
DIN 51790
Zinc (Zn) ASTM D 3605 ppm(wt)  2.0
Total of ppm(wt)  0.3 (5)
Sodium (Na) + Potassium (K)

Calcium (Ca) (6) ppm(wt)  10
Mercury (Hg) and wax ppm(wt) 0(3)
Chlorine (Cl) ISO15597/D4929 ppm(wt) 6
Fluorine (F) (7)
Nitrogen (N) ASTM D 4629 % (wt) ≤ 0.015 (8)
(FBN = Fuel Bound Nitrogen)
Sulfur (S) D3246/D5453/ % (wt) ≤ 0.2 (9)
ISO6326
Acid number (10) D664 mg/g KOH ≤ 0.1
Note to table 7
(1) These limits ensure that the gas turbine can be operated without the risk of erosion or
clogging. If filters are used which have a finer mesh size than that specified, sediments and
organic components could cause filter fouling after a relatively short period of operation.
On the contrary, if filters are not adequate there is a danger of increased erosion in the fuel
oil nozzles and on the turbine blades causing the following effects:
- Poor atomisation
- Uneven temperature distribution
- Premature replacement of fuel oil nozzles and/or blades.
Large particles could affect the turbine cooling path and reduce the cooling effectiveness.
Small particles collect in the blades and vanes airfoils and restrict the flow path thus
reducing the margin against surge.
(2) Ash is the non combustible part of the fuel oil and it can contain mineral solids or organic
compounds. The mineral particles have the same effect of sediments (see point 1) and
contribute to the wear of the system. Metallic compounds can form corrosive deposits.
Organic compounds do normally not create erosion or clogging problems however, in
presence of water, can react and form sludges which can give blockage problem on the
lines and burners.
Page 11 of 20
12.10.17
(3) No violation of the prescribed limits is permissible.
(4) In presence of other contaminants (Na, K, V) Pb accelerates the oxidation process. Pb
damages also the catalysts used for NOx reduction (SCR), therefore more stringent limits
can be applied in case of requirements of external equipment (e.g. SCR).
(5) Operation with Na+K about the limit but < 1 ppm(wt) is still possible but with penalization
of 1.5 on the Equivalent Operating Hours (eoh) counting.
(6) Calcium after combustion can lead to hard deposits in combustion chamber and on the
turbine blades which cannot be removed by washing. These deposits degrade the
performance and can abrade turbine coatings.
(7) Chlorine and Fluorine accelerate hot corrosion of turbine parts in presence with sodium
and/or sulphur. In addition Chlorine can also contribute to boiler and exhaust stack
corrosion.
(8) Fuel Bound Nitrogen (FBN) is not stable as elemental N and it causes NOx formation that
cannot be controlled by water/steam injection.
(9) Combustion product is SO2 but also SO3 in with O2 excess. When combined with trace
metals, SO3 generates sulphate compounds with low melting point which can cause
corrosion to turbine hot parts. Corrosion prevention is based on limiting the trace metals
rather than the sulphur. Therefore if the fuel is metal free the limit of sulphur can be
increased. However the SO2/ SO3 can condensate in form of acids in the turbine exhaust
thus damaging the boiler or SCR (where present). For exceeding the limit of 0.2% evaluation
case by case shall be done.
(10) Normally liquid fuels do not show acid presence. However for liquid fuels deriving from
cracking or blending process can contain H2S or Mercaptane, these components in presence
of water accelerate corrosion.
Page 12 of 20
12.10.17
Table 8: Functional requirements at fuel oil GT skid inlet
Properties Unit Limits Remarks

Flash point °C As specified in If explosion protection measures are
applicable codes and required, electrical equipment shall
standards be designed in accordance with
4)
ElexV and DIN 57165 / VDE 0165
2 5)
Kinematic viscosity cSt (mm /s)  1.2
 12
6)
Operating temperature °C   PP +10
  FL -5
7)
Pressure upstream of injection pump bar p  3.0
Water content, bound wt %  0.1
Lower heating value (LHV) kJ / Kg  42000
3
Density (at 15 °C) kg/m max. 870
Notes to table 8
1) Flash point:
Flash point shall be determined and compared with the limits of the national regulations
applicable at the location where the gas turbine is installed. Applicable explosion protection
guidelines shall be complied with.
If fuels must be heated to or above their flash point, additional explosion protection measures
are absolutely imperative. This shall also apply if it is not possible to determine the flash point.
ElexV = Ordinance pertaining to electrical equipment in surroundings where there is an
explosion hazard
DIN 57165/VDE 0165 = Installation of electrical equipment in areas with explosion hazard
2) Kinematic viscosity
If the maximum permissible viscosity is exceeded, fuel oil atomisation is impaired.
Effects:
- Poor combustion
- Increased pollutant emission
3) Operating temperature
Page 13 of 20
12.10.17
The minimum operating temperature for light distillates is determined by the maximum
viscosity and the paraffin crystallisation temperature (PP = pour point). It may be necessary
to preheat the fuel oil to meet these viscosity requirements imposed to ensure proper flow
and atomisation, but fuel oil shall never be heated to above its flash point (FL) to obviate the
need for explosion protection measures.
If the temperature drops below the minimum operating temperature, paraffin may precipitate
out and/or the viscosity may exceed the maximum limit.
Effects:
- Filter clogging
- Shutdown of fuel oil injection pumps due to insufficient pressure in intake line
If the pour point is reached, the fuel oil can no longer be pumped.
Effects:
- Damage and outage of fuel oil pumps.
As a matter of principle, the maximum operating temperature should be 5 K below the flash
point. Otherwise, additional explosion protection measures must be taken.
4) Pressure
The fuel oil pressure upstream of the injection pump must be between 3 and 7 bar(g).
The value of the backpressure for the fuel oil return line (outside fuel oil skid) shall always
be < 1.8 bar(g).
Page 14 of 20
12.10.17
Requirements for NOx, Flushing, and Washing Water
Water can be used for compressor cleaning, for NOx reduction and fuel oil burner washing (where
fuel oil operation applicable). Water shall fulfill the requirement of the below table 9 and it shall be
demi water. Tap water is not admissible.
Table 9: Permissible water contaminants
Water quality
Contaminants Test Demineralised water Drinking water
Conductivity S/cm < 0.5 -----
DIN 51797
Sodium and Potassium (Na+K) ppm(wt) < 0.05 < 100
ASTM D 3605
Calcium (Ca) ASTN D 3605 ppm(wt) <1 No data
Chlorine and Fluorine ASTM D895 ppm(wt) < 0.1 ----
Silicic acid (SiO2) ppm(wt) < 0.05 ppm(wt) ----
pH ASTM D 1293 5-8
Filtration degree µm <5
Page 15 of 20
12.10.17
Special Fuels
The term special fuels is used to denote all fuels which do not meet the requirements described
above. In general, special fuels require modification of the gas turbine mechanical design.
Caution!
Danger of equipment damage: operation of your GT with special fuels is subject to approval of
Ansaldo Energia Gas Turbine Engineering Department (GTE).
Units and Conversions

Gas turbine data are usually given on a mass basis (…/kg). However, the gas industry customarily
provides data on a volume basis (../ m3 ). It is therefore necessary to convert the data of the fuel gas
analysis. The following data are used for this conversion.
The designation m3 is used to denote standard cubic meter (mn3, mstp3) i.e. a cubic meter at standard
temperature (Tn) and pressure (pn), where:
Standard pressure:
pn = 1.01325 bar (rounded off to 1.013 bar)
Standard temperature:
Tn = 273.15 K = 0°C (rounded off to 273 K)
Heating value (kJ/kq) (conversion):
heating value (k.J/m3n) / density (kg/rn3).
Gas density (conversion of rel. density):
rel. density x 1.293 kg/m3 = gas density (kg/m3).
In the gas industry, “relative density” is frequently stated instead of density. Relative density is the
ratio of the gas density to that of air. Relative density is therefore dimensionless.
The density of air at standard pressure and temperature is 1.293 kg/rn3.
American Units
Gas data are often given in American units rather an in metric units. These data must then be
converted. Requisite conversion factors are listed below:
Conversion of BTU (British Thermal Units) to kJ:
Page 16 of 20
12.10.17
BTU x 1.05505=kJ
Conversion of lbs (pounds) to kg:
lbs x 0.45359 = kg
Conversion of CF (cubic feet) to m3:
CF x 0.02832 = m3
Conversion of psi to bar: psi x 0.06895 = bar
Standard conditions are also used for American units, however, these conditions are, however, based
on different reference values:
 Standard pressure:
pn = 1.01325 bar (rounded off to 1.013 bar).
 Standard temperature:
Tn= 288.15 K = 15°C (rounded off to 288 K)
The difference is approx. 5.5% (288/273 = 1.055).

This difference must also be allowed for.
The use of American standard conditions is usually indicated by the prefix “S” (standard).
• Conversion of heating value:
BTU/SCF x 1.055 x 1.055 / 0.02832= ...kJ/m3
• Conversion of density:
lbs/SCF x 0.453 x 1.055 / 0.02832= ...kg/m3
Page 17 of 20
12.10.17
Checklist for Fuels
The following checklist must be completed to enable Ansaldo Energia to perform an unequivocal
evaluation of the customer-specific fuel analysis and thus ensure safe, reliable gas turbine operation.
Checklist for Gaseous Fuels

Gas costituents Unit Value
(other ISO unit are permitted)
CH4 Mass %
C2H2 Mass %
C2H6 Mass %
C3H6 Mass %
C4H8 Mass %
n C4H10 Mass %
iso C4H10 Mass %
n C5H12 Mass %
iso C5H12 Mass %
C6 Mass %
C7 (+) Mass %
H2 Mass %
CO Mass %
CO2 Mass %
H2O Mass %
N2 Mass %
O2 Mass %
Ar Mass %
Other Mass %
Properties
Lower heating value (LHV) MJ/kg
3
Density at 15°C kg/m
Temperature °C
Dew point of water °C
Contaminants (all listed in table 4)
Page 18 of 20
12.10.17
Dust Mass %
Alkali metals (Na + K) ppm(wt)
Other metals (V,..) ppm(wt)
NH3 ppm(wt)
H2S ppm(wt)
Other specific characteristics
Checklist for Liquid Fuels
Constituents Unit Value

(other ISO unit are permitted)
C Mass %
O Mass %
S Mass %
N Mass %
H Mass %
Page 19 of 20
12.10.17
Properties
Lower heating value (LHV) MJ/kg
Density at 15°C 3
kg/m
at ..°C
Cinematic viscosity 20°C
cSt
40°C
Flash point °C
lound point °C
Boiler curve °C
10%
20%
30%
40%
50%
60%
70%
80%
90%
Vapour pressure ……bar at ……°C

……bar at ……°C
……bar at ……°C
Contaminants (all listed in table 6)

Sediment Mass %
Water content Mass %
Paraffins Mass %
Coke residues Mass %
Ash ppm(wt)
Na+K ppm(wt)
Mercaptans ppm(wt)
Other specific characteristics
Page 20 of 20
12.10.17
TURBINE OIL SPECIFICATIONS
Introduction
This specification describes the requirements for turbine oils used for lube and lifting oil of gas
turbine-generators.
Only turbine oil approved by the gas turbine manufacturer shall be used.
References documents
DIN 51 562-1, DIN 51 381, DIN 51 558-1, DIN 51 777-1, ISO 6247, DIN 51 589-1, DIN 51 599, DIN 51
757, DIN ISO 2592, ISO 3016, ISO 5884, ISO 4406, DIN ISO 2049, DIN EN ISO 2160, DIN 51 585, DIN 51
587, DIN 51 354, ASTM D 445, ASTM D 3427, ASTM D 974, ASTM D 1744, ASTM D 892, ASTM D 1401,
ASTM D 1298, ASTM D 92, ASTM D 97, ASTM D 1500, ASTM A 130, ASTM D 665, ASTM D 943, ASTM
D 5182
Type of Turbine Oil
For the purpose of this specification, turbine oil is defined as a mineral oil or synthetic oil with
additives which enhance corrosion protection and oxidation stability.
As a rule, turbine oil is a paraffin-base mineral oil comprising a mixture of saturated hydrocarbons.
Because of the numerous chemical constituents involved, it is not possible to state a defined
composition. The physical properties of the oil are the selection criteria for choosing a turbine oil.
The additives must not have any adverse effect on the materials used in the oil system. The additives
must not contain any organometallic compound (e.g. organic zinc compounds).
Page 1 of 7
TURBINE OIL SPECIFICATIONS TGO2-0171-E00000
02.04.16
• Gas Turbine AE64.3A:
Use oil type ISO VG 32 with FZG - Test ≥ 8, due to the Gear Box
• Gas Turbine AE94.3A & AE94.2:

Use oil type ISO VG 46
Requirements (for “new” oil) – see also table 1
q Thermal stability:
The turbine oil must be capable of withstanding temperatures in turbo set components
(e.g. bearings, coupling, gearboxes) of max 120°C and oil tank temperatures of max.
80°C without physical or chemical degradation of the oil properties.
q Compatibility:
The fluid must be capable of mixing with residue (max 4% vol) of another similarly based
product (mineral or synthetic) with no negative impact on the properties of the oil.
q Physiological properties:
By nature, turbine oil must be non-hazardous to the health of the person working with
it, if the necessary hygienic precautions are taken.
Page 2 of 7
02.04.16
Table 1: Requirements for new oil
Properties Unit Value DIN-ISO / ASTM Test method

Kinematic viscosity at 40 °C
ISO VG 32 mm2/s 28.8 - 35-2 51 562-1 / D 445
ISO VG 46 mm2/s 41.4 - 50.6
Air release capability at 50°C min ≤4 51 381 / D 3427
Neutralization number
A oil without EP/AW- additives mg KOH/g ≤ 0.20 51 558-1 / D 974
B oil wit EP/AW additives mg KOH/g ≤ 0.30
Water content mg/kg ≤ 100 51 777-1 / D 1744
Foam properties at 25 °C ISO 6247 / D 892
Tendency (volume) ml ≤ 400
Stability (dissipation time) s ≤ 450
Water separability s ≤ 300 51 589-1
Demulsibility min 40/40/0 (≤ 20) 51 599 / D 1401
Density at 15 °C Kg/m3 ≤ 900 51 757 / D 1298
Flash point
ISO VG 32 °C > 160 2592 / D 92
ISO VG 46 °C > 185
Pour point °C ≤ -6 ISO 3016 / D 97
Colour - ≤2 2049/D 1500
Corrosive effect on copper - ≤ 2 -100 A 3 2160 /D 130
Corrosion protection for steel - 0 -8 (DIN) 515 85 / D 665
pass (ASTM)
Ageing characteristics: increase of mg KOH/g ≤ 2.0 51 587 / D 943
neutralization number after 2500 h h ≥ 2500

Cleanliness level * - ≤ 17/14 Test: ISO 5884
Result : ISO 4406
* Since the cleanliness level depends on the design of the system, the lube oil inside the lube oil reservoir must
be ≤ 17/15/12 (see “Filling”). Each Supplier must be compliant (near) with the value wrote in this table.
Additional requirements on turbine oils for use in gearboxes (AE64.3A only)

FZG- Test A/8,3/90
Failure load stage - ≥8 51 254 / D 5182
Note
A periodic check of the oil conditions helps to value the correct functioning of the system and to
consider an possible early action. Recommended intervals for oil checks: Every three months.
Page 3 of 7
02.04.16
Filling:
q Filling of the system shall be done by the supplier at his own risk and expense.
q Filling must be done through a filter unit having a maximum mesh size of 6/7 micron. The
Cleanliness to reach must be ≤ 17/15/12 (see page 3)
q Filling must be finished within max 24 hours. Additional services must be agreed between
purchaser and supplier.
q Before filling of the reservoir, 2 litres sample is to be taken ( in case of more batches will
mixer 1 litre sample from those batches ) and sent to Ansaldo. In case there is the gear box
the sample quantity must be 3 liters.
Supply:
The supplier, before the each delivery, will communicate to Ansaldo (or the client) the test’s results
of each batch of oil utilized for the supply. For each batch the test results of the following parameters
have to be submitted:
ü Viscosity
ü Air release
ü Neutralization number
ü Water content
ü Foaming
ü Water separability
ü Demulsibility
The oil supply will be made in clean drums, each drum must be show univocal identification of the
product and of the batch number.
IMPORTANT:
The approval does not release the supplier from his responsibility for the quality of the product.
ANSALDO ENERGIA must be informed without fail in case of any alteration in the product or
manufacturing process. In this case a new approval will be necessary.
Page 4 of 7
02.04.16
APPROVED TURBINE OILS
Attention:
q The selection should be made under consideration of the viscosity class determined for
the Gas Turbine.
q Gas Turbine with Gearbox need special turbine oils suitable for gearbox lubrication.
Nationality ISO VG Possible use

Supplier Product Name
Supplier class with Gear Box
ITALY Eni Eni OTE GT 32 32 X

Eni OTE GT 46 46 X
Mobil DTE 932 GT (only for GAS

USA ExxonMobil 32 X
Turbines)
ExxonMobil Mobil DTE 746 46
ExxonMobil Mobil DTE 832 32 X
ExxonMobil Mobil DTE 846 46 X
Mobil SHC 824 (very high pour
ExxonMobil 32 X
point)
Mobil SHC 825 (very high pour
ExxonMobil 46 X
point)
NETHERLANDS shell Turbo S4 GX32 32 X

shell Turbo S4 GX46 46 X
shell Turbo Oil T 46 46
FRANCE Total Preslia 32 32 X

Total Preslia 46 46 X
Total Preslia GT 32 32 X
Total Preslia GT 46 46 X
Page 5 of 7
02.04.16
ESPANA Cepsa HD Turbinas * 46 46

Cepsa Turbinas EP (32) 32 X
Cepsa Turbinas EP (46) 46 X
USA Chevron/Caltex/Texaco GST 2300 32 32 X

Chevron/Caltex/Texaco GST 2300 46 46 X
Chevron/Caltex/Texaco GST OIL 46 46
Chevron/Caltex/Texaco GST EP 32 32 X
Chevron/Caltex/Texaco GST EP 46 46 X
INDIA Indian Oil Corp. (IOC) Servoprime 32XL 32 X

Indian Oil Corp. (IOC) Servoprime 46 XL 46 X
Indian Oil Corp. (IOC) Servoprime 32G 32 X
Indian Oil Corp. (IOC) Servoprime 46G 46 X
KUWAIT Kuwait Petroleum Q8 van Gogh 46 46

Kuwait Petroleum Q8 van Gogh EP 32 32 X
Kuwait Petroleum Q8 van Gogh EP 46 46 X
Kuwait Petroleum Q8 Volta 46 46
Kuwait Petroleum Q8 Volta EP 32 32 X
Kuwait Petroleum Q8 Volta EP 46 46 X
RUSSIA Lukoil LUKOIL Tornado M 32 32 X

Lukoil LUKOIL Tornado M 46 46 X
Lukoil Tornado T 32 32 X
Lukoil Tornado T 46 46 X
Page 6 of 7
02.04.16
CANADA Petro-Canada Lubricants Turboflo XL 46 46

Petro-Canada Lubricants Turboflo EP 32 32 X
Petro-Canada Lubricants Turboflo EP 46 46 X
Petro-Canada Lubricants Turboflo LV 46 46
USA Phillips 66. Diamond Class™ AW Turbine Oil 32 32 X

Phillips 66. Ultra Clean Turbine Oil 46 46
CHINA Sinopec Corp. L-TSE/LF32 32 X

Sinopec Corp. L-TSE/LF46 46 X
Sinopec Corp. L-TSA/LF46 46
Page 7 of 7
02.04.16
HYDRAULIC OIL SPECIFICATIONS
Introduction
This specification regards the hydraulic oils used for all the hydraulic actuators of the gas turbine.
Quality, cleanliness and operating viscosity of the hydraulic oil are decisive factors for the operational
reliability, economy and service life of the hydraulic system. The specification for hydraulic oil is
always determined by the component with the most stringent requirements (servo positioning valve
in servo-hydraulically actuated drives). Only those hydraulic oils meeting the following general
requirements may be used.
Type of Hydraulic Oil

DIN 51524-2-HLP 46
lSO-L-HM 46 acc. ISO 3498
Chemical Composition
For the purposes of this specification, hydraulic oil is defined as a liquid pressure medium on the
basis of mineral oil, having additives which enhance oxidation, corrosion and wear protection, and
exhibiting good resistance to emulsification, i.e. indispersibility.
The additives must not have any adverse effect on the materials used in the hydraulic system. The
additives must not contain any organometallic compounds (e.g. organic zinc compounds). Hydraulic
oils which reactive aggressively with lead or bearing materials containing lead may not be used, even
if they comply with Specification HLP according to DIN 51524 Part 2.
Contact Ansaldo Energia in case of doubt on the oil to be used.
Thermal Stability
The hydraulic oil must be capable of withstanding temperatures of up to +70° C in the hydraulic oil
tank with no negative impact on the properties of the oil.
Miscibility
Sludge and deposits may be formed if hydraulic oils from different manufacturers or different types
of hydraulic oils from the same manufacturer are mixed. Under certain circumstances, these could
result in faults and damage to the hydraulic system.
The mixing of hydraulic oils is therefore prohibited.
An exception is made in the case of compatibility of the hydraulic oil with residual amounts (max. 2
vol. %) of another hydraulic oil with the same mineral basis.
Page 1 of 2
HYDRAULIC OIL SPECIFICATIONS TGO2-0172-E00003
08.10.15
Physiological Properties
By nature, the hydraulic oil must not be hazardous to the health of the persons working with it if the
necessary hygienic precautions are taken.
Tab. 1: Physical and Chemical Properties OF DIN 51 524 - HLP 46 Hydraulic oil in the as-delivered
condition
Test procedure
Property Numeric value Unit
DIN / ASTM ASTM
2
Kinematic viscosity at 40°C 41.4 - 50.6 mm /s DIN 51 562-1 ASTM D 445
Air release at 50°C  10 min DIN 51 381 ASTM D 3427
Water content  100 mg / kWh DIN 51 777-1 ASTM D 1744
Foaming characteristics at 25°  150/0 ml --- ASTM D 892
(Sequence 1)
Demulsibility  40 min DIN 51 599 ASTM D 1401
3
Density at 15°C  900 kg/m DIN 51 757 ASTM D 1298
Flash point > 185 °C DIN ISO 2592 ASTM D 92
Pour point  -15 °C ISO 3016 ASTM D 97
Cleanliness level, (1) ≤17/15/12 --- ISO 4406 ---
Copper strip corrosion  2-100 A3 --- DIN EN ISO 2160 ASTM D 130
Rust-preventing characteristics  0-A --- DIN 51 585 ASTM D 665
Oxidation stability: increase in  2.0 Mg KOH/g DIN 51 587 ASTM D 943
neutralisation number after
1000h
(1) Because various systems are commonly used to classify the cleanliness of hydraulic oils,
additives common contamination classes are indicated below with the classification on which
they are based.
Minimum requirements: Class 6 per NAS 1638

Class 3 per SAE
Class 17/15/12 per CETOP RP 70H
Page 2 of 2
HYDRAULIC OIL SPECIFICATIONS TGO2-0172-E00003
08.10.15
Turbine / compressor
GAS TURBINE DESCRIPTION
 General
The AE94.3A gas turbine is a heavy duty gas turbine designed for 50 Hz operation with single shaft, cold end
drive and annular combustor.
The mono shaft configuration allows to drive directly the air compressor and the separated electrical
generator from the gas turbine.
Ambient air enters the compressor through the air intake system, equipped with filters suitable for the
operation at site conditions and the intake duct. The compressed air is then directed in the annular
combustion chamber. Here, the combustion of the fuel takes place across 24 burners that produce an
increase of the gas temperature.
Hot gas of combustion flows through the turbine, where its enthalpy is converted into mechanical power.
The exhaust gas is discharge through an axial diffuser at atmospheric pressure.

Downstream the diffuser , the hot gas can be discharged to the atmosphere through a vertical stack or
either used to generate steam in an external boiler. The steam could be used for district heating purposes,
for industrial processes or to operate a separate steam turbine (not part of this description).
The electrical generator is coupled to the compressor side of the gas turbine rotor through an intermediate
shaft.
 Machine body
The AE94.3A gas turbine consist of a single shaft design, composed by fifteen (15) stages axial compressor
and four (4) stages of a axial turbine having a common rotor.
All the turbine stator and rotor blades are air-cooled, with the exception of the last rotor stage ones.
Cooling air is provided at different pressure and temperature levels by compressor extractions, either to
provide the best possible cooling effect and the optimal unit thermal performance.
Extensive film cooling is used to improve the cooling efficiency without any requirement for an external
cooling air system.
The cooling air, after flowing across blades and vanes, discharges into the hot gas stream.
The first 2 rows of the compressor vanes are stagger adjustable. To prevent compressor surge when the
speed is below the allowed speed range, the gas turbine is equipped with blow off valves for air extraction
from selected compressor stages.
The rotor is made by a front shaft section, fifteen (15) compressor blade disks, three (3) Central Unbladed
Disks (CUD), four (4) turbine blade disks and a rear shaft section, all held together by a single central tie bolt
with a clamping nut at the turbine end.
Page 1 of 5
GAS TURBINE DESCRIPTION TGO2-0300-E71000
19.09.14
Each disk of the rotor has radial Hirth teeth on both sides; the Hirth serrations provide radial alignment
between the rotor sections, ensuring torque transmission and allowing free relative radial expansion and
contraction.
The result of this constructions is a self-supporting drums with low weight and high stiffness; therefore it
can be supported by only two bearings, one at the front shaft section and one at the rear shaft section. The
bearing at the compressor end is a combined journal and thrust bearing designed to accommodate the
axial thrust of the rotor.
The cooling air across the rotor, flows through two cooling circuits, separated by an internal drum. This
cooling air flow circuit ensures that the rotor drum, including the turbine section, is completely enveloped
in cold air and prevents any additional thermal stresses which might result in rotor distortion during load
changes and starts.
The two bearings are located outside the pressurised region of the gas turbine, providing the basis for
constant good alignment and excellent running qualities.
The AE94.3A gas turbine design is based by single shell principle from the inlet section to the compressor
9th stage, and featured by the two shell design principle .
The major advantage of the two-shell design principle is that the mechanical and thermal loads on the
casings are clearly separated.
The pressure containing outer casing consists of the front bearing housing, the compressor first stator
blade carrier, a centre section and the rear bearing housing and withstood all mechanical loads due to
internal pressure since the thermal loads are low.
The inner casing is made by the second stator vane carrier, the combustion chamber and the turbine stator
vane carrier, all supported by the centre section of the outer casing so as to allow free thermal expansion.
The inner casing is opposed to the thermal loads since the mechanical loads are low.
The gas turbine is also provided with two stator vane carries for the compressor and one stator vane carries
for the turbine.
The combined journal and thrust bearing is equipped with provision for moving the rotor during GT
operation in order to reduce the clearance (radial gap) from the turbine blades and the vane carrier. This
allows gas turbine performance improvement.
The exhaust gases are discharged from the turbine by means of an axial exhaust casing which combines the
advantages of simple geometry and low exhaust losses. Flow straightening profiles in the turbine’s exhaust
section are supplied to reduce exhaust losses. The exhaust casing is bolted to the outer casing around its
circumference.
Additionally, for facilitates the connection of an optimum-geometry exhaust gas diffuser to a stack or to a
heat recovery boiler without significant changes in direction, the generator is driven from the compressor
(cold) end.
A turning gear system, which acts on the compressor shaft by an hydraulic motor, is provided for the
turning operations after the gas turbine has been shut down.
The gas turbine is supported on the foundation by compressor- supports, turbine supports and one
centring guide.
The compressor supports are used as the fixed point of the machine. The turbine supports are designed as
flexible support rods which accommodate thermal expansion and contraction of the machine in the
Page 2 of 5
19.09.14
horizontal plane without significant reaction forces, while being sufficiently rigid in the vertical plane to
provide fixture in the turbine region.
The centring guide, located in the bottom half of the turbine casing, centres the unit in the axial direction.
 Combustion chamber and burners
The AE94.3A gas turbine is equipped with an annular combustion chamber and 24 Dry Low NOX burners.
The combustion zone is wrapped around the gas turbine first stage inlet section.
The combustion chamber casing is formed by low alloy steel cast shells which are completely enveloped by
the compressor discharge air. They are thus not exposed to the local variations in temperature of the
surface in contact with the hot gas. The surface exposed to the hot gas is protected by heat shields made of
ceramic tiles. They are flexibly attached to the colder casing of the combustion chamber and this permits
deformation in response to temperature gradients. This free expansion results in minimal thermal stresses
which can be readily accommodated by the heat shields. The air used to cool the metallic fixations of the
tiles exits through the gaps between the heat shields and thus serves as sealing air to prevent hot gas
ingress.
Page 3 of 5
19.09.14
Longitudinal Section
1 2 3 4 5 6 7 8 9
1. Front bearing pedestal with compressor bearing

2. Compressor stationary blade carrier 1
3. Outer casing 2
4. Burner assembly
5. Annular combustion chamber
6. Central Unbladed Disk
7. Outer casing 3
8. Turbine
9. Turbine exhaust casing
Page 4 of 5
19.09.14
 Installation
The overall gas turbine is a compact unit which is completely assembled (flange to flange) and
delivered from AEN factory to site. Therefore there is no need to adjust any clearances during field
assembly.
The other auxiliary systems are delivered as packaged skid as well, completed mounted and pre-
assembled before shipment. Only interconnecting piping between the gas turbine flange to flange
and the relevant auxiliaries skids have to be mounted during assembly activities on site.
Page 5 of 5
19.09.14
ROTOR (AND BLADES)
 Rotor
The rotor carries the 15-stage compressor and the 4-stage turbine blading.
The rotor comprises the front shaft (1), fifteen compressor wheel disks (2), three Torque Disk (3), four
turbine wheel disks (4), the rear shaft (5) the central tie rod (6) the tie rod nut (7).
The hollow shafts and disks are held together by the tie rod and the tie rod nut. The tie rod is supported in
the disks at several locations along its length by truncated conical springs.
Hirth facial serrations near the periphery of the disk and shaft faces center items relative to adjacent items.
These Hirth facial serrations also transmit torque within the rotor.
The rotor is mounted on bearings at both ends.
The rotor is provided with 7 balancing planes; 3 of these planes (E) are available for placement of balancing
weights in the event that rebalancing is necessary.
2 E 3 4 E
1 5
Page 1 of 4
ROTOR TGO2-0310-E70000
19.09.14
 Compressor Blades (CB)
4
3
1 2
Each moving blade is manufactured from a single piece of stainless steel.

The profile of the airfoil (1) is optimized with respect to flow and strength.
The blade has a dovetail root (4) whose size is proportional to the profile length.
These blades are inserted into corresponding slots in the rotor disks (3) during assembly.
Locking strips (2) are inserted in the front section of the rotor to prevent the moving blades from shifting in
the rotor disks.
Blades in the front stages of the compressor are provided with a surface coating to protect against
corrosion. Differences in the color of compressor airfoil coatings may occur as a result of fabrication
methods, however do not restrict the quality of the component.
All compressor moving blades can be removed and inserted without dismantling the rotor.
Page 2 of 4
19.09.14
 Turbine Blades (TB) 1
The turbine moving blades convert the kinetic energy of the hot gas flow into mechanical energy.
Moving blades comprise the airfoil (1), platform (2) and blade root (3). Airfoil width decreases from root to
tip. Airfoils are twisted to allow for the varying circumferential velocities from root to tip.
The platform forms the inner boundary of the hot gas path and protects the blade root and wheel disk
periphery from excess thermal input.
Blade roots in the 1st and 2nd stage have fir tree roots with two pairs of teeth each, those in the 3rd and
4th rows have three pairs of teeth each. Blades are inserted into slots in the rotor wheel disks. Locking
strips prevent axial shifting of the blades. Seal strips upstream of the front face at the root/wheel disk
interface and seal wires between the platforms of neighboring blades prevent the ingress of hot gas into
the root area.
Moving blades are manufactured from superalloys Nickel or Cobalt base material with high-temperature
resistance property due to the severe stress that have to face at high temperatures and speed. The surfaces
of these materials exposed to the flow of hot gas must, however, be provided with a protective coating to
prevent oxidation and corrosion. Differences in the color of turbine airfoil coatings may occur as a result of
fabrication methods, however do not restrict the quality of the component.
Nevertheless such protective coatings, the first three rows of turbine moving blades are cooled. Cooling air
is fed to these blades via turbine discs through blade root (4).
Page 3 of 4
19.09.14
A combination of convection, impingement and film cooling is used for cooling the stage 1 moving blades.
Separate cooling air channels are provided for the leading edge, central and trailing edge regions.
Three rows of film cooling bores are provided along the leading edge. These holes are supplied with a flow
of impingement cooling air along the front rib inside the airfoil. A coating is applied to all airfoil surfaces to
protect against oxidation and corrosion, the suction and pressure sides also have a thermal barrier coating
on top of this.
Film cooling is also employed at the leading edges of stage 2 moving blades. These blades, too, are
provided with a thermal barrier coating.
Stage 3 moving blades are cooled by a flow of cooling air through three channels which are arranged along
the longitudinal axis. Also these blades are provided with a thermal barrier coating.
Stage 4 moving blades are not cooled, but they are hollow in the outer two thirds of the airfoil length to
increase stiffness. These blades are provided with an overlay coating to protect against oxidation and
corrosion.
Blade airfoils in stages 1 - 3 are also provided with internal surface protection to increase their resistance to
oxidation and hot corrosion.
All turbine moving blades can be removed and inserted without having to remove and dismantle the rotor.
Page 4 of 4
19.09.14
STATOR AND VANES
§ General
Stator incudes compressor vanes and turbine vanes assembly and compressor and turbine vanes.
The compressor and turbine vane assembly secures the vane rings, which carry the vanes, in position
and transmits the reaction forces due to the flow and pressure to the outer casing.
Compressor vane assembly

The compressor vane assembly is divided into two vane carriers.
Vane carrier I (2) is rigidly mounted between the compressor bearing housing (1) and the center casing
section (4), forming a part of the outer casing
Stationary blade carrier II is suspended in the center casing section so as to accommodate thermal
expansion. The blade carrier supports the vane outer ring (3). The annular spaces indicated with A are
extraction points for compressed air which needs to be extracted for blow off (during startup and
shutdown) or for cooling purposes. The compressor vane rings are inserted into circumferential grooves in
the stationary blade carriers.
4
1 2 3 A
A
A
1 Compressor bearing housing

Figure 1: Compressor Vane Assembly 2 Vane carrier I
3 Vane outer ring
4 Center casing
7 Stationary blade carrier II
A Extraction space
Radial clearances between blades can be measured without disassembling the compressor and turbine via
covered bores in the stationary blade carriers.
Page 1 of 7
STATOR AND VANES TGO2-0330-E71000
19.09.14
Compressor outlet diffuser
At the compressor discharge, a compressor outlet diffuser (1) reduces the flow velocity in order to convert
the kinetic energy of the compressed air into static pressure. Outlet guide vanes (2) immediately upstream
of the compressor diffuser prevent excessive turbulence as the air exits the compressor blading (3).
Deflector elements (4) guides properly the air flow. Refer to figure 2.
1
3 2
1 Compressor outlet diffuser

2 Compressor outer guide vane
3 Compressor blades
4 Deflector
Figure 2: Compressor Outlet Diffuser
Page 2 of 7
19.09.14
Compressor vanes
The stator blades are named ‘vanes’ to clearly identify them with respect to the moving blades.
Each vane is manufactured from a single piece of material.
The vanes, together with the outer ring (refer to figure 1, position 3 ) and the split inner ring, comprise the
vane ring.
The inner rings connect the vanes to the hub and are fitted with seal strips for shaft glands.
The variable inlet guide vanes and the compressor vane stage 1 have pivot pins (1) at both ends (see figure
3) and are supported in an outer ring (3) and an inner ring (4).
See in addition section TGO2-0340 - Variable inlet guide vanes
All other vanes have dovetail blade roots and are radially and circumferentially fixed in corresponding slots
in the outer rings.
Vanes in the front stages of the compressor are provided with a surface coating to protect against
corrosion. Differences in the color of compressor airfoil coatings may occur as a result of fabrication
methods, however do not restrict the quality of the component.
1 Pivot pin
2 Airfoil
2 3 Outer ring
4 Inner ring
1
4
Figure 3: Variable Compressor vanes (inlet guide vanes and vane of 1 stage)
Turbine vane assembly

Refer to figure 4. The turbine stationary blade assembly comprises the vane carrier (5), the vanes (1, 2, 3,
4), the guide rings (6, 7) and seal rings (8, 9, 10, 11). The stationary blade carrier is suspended in the casing
(12) so as to accommodate thermal expansion.
Page 3 of 7
19.09.14
Circumferential slots in the stationary blade carriers hold the outer shrouds of the stationary blades.
Gaps between adjacent blades are closed with seal elements. Inner shrouds of turbine vanes (1,2, 3, 4) hold
segmented seal rings in position (8, 9, 10, 11).
Cooling air flows through the hollow spaces between the stationary blade carrier and the outer shrouds of
individual vanes; a portion of this air flow is fed as seal air to the seal rings for stages 2 and 3.
12
6 4
3
1 Vane of turbine stage 1
1 2 Vane of turbine stage 2
8 3 Vane of turbine stage 3
4 Vane of turbine stage 4
2 11 5 Vane carrier
6 Guide ring stage 1
9 10 7 Guide ring stage 4
8 Seal ring stage 1
9 Seal ring stage 2
10 Seal ring stage 3
Figure 4: Turbine Vane Assembly 11 Seal ring stage 4
12 Casing
Page 4 of 7
19.09.14
Turbine vanes
The stator blades are named ‘vanes’ also for the turbine section, to clearly identify them with respect to the
moving blades. The turbine vanes convert the pressure energy of the hot gas flow into kinetic energy and
ensure optimal flow to the next row of turbine blades.
The turbine vanes comprise an outer shroud (1), airfoil (3) and inner shroud (2).The outer shroud secures
the vane in the stationary blade carrier and forms the outer boundary of the hot gas path. Due to
temperature differences between the various items, sufficiently large expansion gaps are required between
the vanes in both the axial and circumferential directions. To minimize the amount of cooling air escaping
through these gaps, the circumferential gaps are sealed by inserting seal strips (4). Refer to figure 5 but the
same is applicable also for the following other figures.
The airfoils of all four turbine stages are hollow-cast and air-cooled to ensure that the maximum
permissible metal temperatures specified for the materials used are not exceeded. The four rows of vanes
are cooled in a variety of ways with air under a variety of conditions.
See in addition section TGO2-0801 - Cooling air system
The turbine vanes are named according to the stage, i.e. TV1 means turbine vanes of stage 1.
The TV1 is cooled in the front portion of the airfoil, in the outer shroud and inner shroud by a combination
of convection and impingement cooling via metal insert with holes. The shape and the angle of the holes
are made in order to ensure the formation of a film cooling in certain areas on the surface of the blade. The
rear portion of the airfoil (named trailing edge) is cooled by convection cooling air flow.
The cooling flow is represented in blue.
Figure 5: Turbine Vane 1 (TV1) (front view and view from above)
Page 5 of 7
19.09.14
For the TV2, only the front portion of the outer shroud and the leading edge of the airfoil are impingement
and film cooled. The remainder of the airfoil is convection cooled via a multi-channel system of internal
passageways.
Cooling air flow is shown in blue in figure 6.
Figure 6: Turbine Vane 2 (TV2) (front view and view from above)
The TV3 airfoils are cooled by a convection flow via a multi-channeled system of passageways. A portion of
this cooling air is deflected towards the trailing edge.
Cooling air for TV4 also enters the interior of the airfoil and cools the cane as a single flow passage.
The cooling flow is depicted in blue in figure 7 for TV3 and TV4.
Figure 7: Turbine Vane 3 (TV3) and Turbine Vane 4 (TV4)
Page 6 of 7
19.09.14
The vanes are cast from high-temperature alloys due to the severe stresses sustained at the high metal
temperatures. A protective coating is applied to the airfoils as necessary to increase their resistance to hot
corrosion. The first rows are additionally provided with a ceramic thermal barrier coating. Differences in
the color of turbine airfoil coatings may occur as a result of fabrication methods, however do not restrict
the quality of the component.
Page 7 of 7
19.09.14
VARIABLE GUIDE VANES
The compressor inlet guide vanes and the first stage of compressor vanes are variable adjusting.
By moving the inlet guide vanes (IGV) from closed to open position it is possible to partialize the
compressor air flow, in this way it is possible to maintain a certain fuel to air ratio in the higher load range
in order to improve and optimize the combustion and in order to keep constant the exhaust gas
temperature for improving the efficiency of the combined cycle.
Also the first stage of compressor vanes (CV1) are made adjustable, this is order to optimize the flow angles
to the next compressor stage for improving the efficiency of the compressor itself.
IGV
Refer to figure 1.
The IGV are connected via a levers to an adjusting ring (2), which is supported on the vane carrier I (1).
To rotate the adjusting ring (2) in the circumferential direction, a hydraulic actuator (4) is mounted on the
compressor support (6) and connected to the adjusting ring via a pushrod (5).
Figure 1: IGV actuation system
1 Vane carrier I
2 Adjusting ring
3 Bearing
4 Actuator (hydraulic)
5 Pushrod
CV1
Refer to figure 2 (the scheme is totally analogue to figure 1).
VARIABLE GUIDE VANES Page 1 of 2 TGO2-0340-E71000

19.09.14
The CV1 are connected via a levers to an adjusting ring (2), which is supported on the vane carrier I (1).
To rotate the adjusting ring (2) in the circumferential direction, a hydraulic actuator (4) is mounted on the
compressor support (6) and connected to the adjusting ring via a pushrod (5).
Figure 2: CV1 actuation system
VARIABLE GUIDE VANES Page 2 of 2 TGO2-0340-E71000

19.09.14
OUTER CASING
 General
The external part of the gas turbine comprises the compressor stationary blade carrier (which is the low
pressure section of the compressor and it can be considered also as casing 1), the outer casing 2 and the
outer casing 3. The outer casings form the pressure containing shell of the gas turbine.
Outer casing 2
The outer Casing 2 is between the compressor vane carrier 1 and outer casing 3. It contains the compressor
vane carrier 2 and burners. Refer to figure 1.
The outer Casing 2 is a welded casing formed by the casing joint flanges (9), the cylindrical (13) and conical
half-shells (6) and the connecting flanges to compressor vane carrier 1 (12) and to outer casing 3 (1).
Paws (10) are welded on at the left- and right-hand casing joint flange; hydraulic jacks press against these
paws to lift off the upper section during major inspections. Load attachment lugs (15) welded onto the
casing are used for transporting the casing during manufacture and major inspections.
Flanges for air extraction (cooling and blow off) are also foreseen.
The conical shell is equipped with segmented internal shields (2) which compensate thermal expansion.
Baffles (3) are provided on selected shield segments to ensure an uniform, low-turbulence flow of air from
the compressor discharge to the burners.
Space for burners (5) are located concentrically in the front conical casing section.
The compressor vane carrier 2 is fixed axially in a slot (11). Its position relative to the rotor can be checked
through the clearance gap measurement bores (8).
A sealing strip inserted in the circumferential slot (14) forms a barrier between the annular cooling air
extraction point and the compressor discharge.
The four endoscopic inspection ports (7) in the conical section of the casing facilitate inspection of the
combustion chamber inlet part.
Page 1 of 4
OUTER CASING TGO2-0500-E70000
19.09.14
Figure 1: View of outer casing 2
1 Connecting flange to outer casing 3 9 Casing joint flange
2 Internal shields 10 Paws for hydraulic jack
3 Baffel 11 Slot for compressor vanes carrier 2
4 Lateral guide 12 Connecting flange for compressor vanes carrier 1
5 Burner flange 13 Cylindrical shell
6 Conical shell 14 Circumferential slot
7 Endoscope port 15 Load attachment lugs
8 Clearance gap measurement bores
Page 2 of 4
19.09.14
Outer casing 3
The outer Casing 3 is located downstream of outer casing 2 and encloses the burner ring combustor and
the turbine. It is split horizontally at the centerline and it is flanged to the turbine bearing casing. Refer to
figure 2.
The outer Casing 3 is a welded casing formed by the casing joint flanges (21), the cylindrical half-shells (19),
the connecting flanges to outer casing 2 (22) and to the turbine bearing casing (6).
Cooling air at the temperatures and pressures required by the individual stages is supplied to this casing via
the flanges (1) on the cylindrical shell.
Drain fittings (14) are located at the lowest point of the semi-cylindrical lower section in the individual
cooling air extraction annular caves.
An additional drain nozzle is located in the lower manhole cover (15).
Lateral support points (5) are provided for hydraulic jacks required to lift off the upper casing section during
major inspections.
Load attachment lugs (3) welded onto the casing flange which is bolted to outer casing 2 and attachment
eyes (7) at the rear flange are used for transporting the casing during manufacture and major inspections.
The attachment eyes are also used to tie down the gas turbine for transport on a cargo ship.
Using the two trunnions (10) of the turbine and the corresponding trunnions on the compressor, the entire
gas turbine can be transported by crane.
Horizontal casing flange bolts (20) are hydraulically pretensioned.
Flange for anti-icing connection (4) is provided as standard feature, while the anti-icing system is an option
order related (in case of anti-icing foreseen for this specific project, see section TGO2-8002).
Planar surfaces (12) at the right- and left-hand casing joint faces of the lower section are used to center the
two turbine supports; these items are designed to securely bear the weight of the gas turbine without
impairing thermal casing expansion in either the transverse or longitudinal direction.
A center guide is also provided because it is at the same time absolutely imperative that lateral motion of
the gas turbine, e.g. induced by an earthquake, is prevented. To perform this function, a center guide key
(8) is provided.
The support and hold-down paws (17) located near the casing joint face ensure that the outer shell of the
burner ring combustor remains in its correct vertical position, without impairing motion caused by thermal
expansion.
The position of the turbine stationary blade carrier is fixed by a means similar to that used with the outer
shell of the burner ring combustor. Both the associated support paws (16) and hold-downs (18) are,
however, substantially heavier, because these points must transmit the entire reaction forces of the
turbine into the casing.
The inner wall is lined with insulation (9) to prevent excessive heating of this casing region by thermal
radiation.
During initial assembly and major inspections it must be possible to center the lower section of the turbine
stationary blade carrier without the use of the support mechanism located in outer casing 3. This is
accomplished using the two radially moveable axial shims of the turbine stationary blade carrier which are
inserted in the support points (13) of the lower casing section.
The flame detectors for flame monitoring are mounted in nozzles (2), refer to section TG2-4380 for details
on flame detectors.
Page 3 of 4
19.09.14
19 1 Cooling air flange
2 Nozzles for flame
detectors
3 Lifting eyes
4 Flange for optional
anti-icing system
5 Paws for hydraulic
jack
6 Connecting flange
20 for turbine bearing
casing
7 Load attachment
lugs
8 Center guide key
9 Insulation
10 Trunnion
11 Turbine height
adjustment
12 Centering point for
turbine support
13 Assembly support
for turbine vane
carrier
14 Drain nozzle
15 Manhole cover
16 Turbine support
17 Fixing points for
22 burner ring
combustor
21 18 Turbine holddown
19 Shell
20 Casing joint flame
21 Casing joint flange
22 Flange to outer
casing 2
Figure 2: View of outer casing 3
Page 4 of 4
19.09.14
EXHAUST GAS DIFFUSERS
 General
The turbine discharge ends with a short exhaust diffuser, named gas turbine diffuser, which is still part of
the gas turbine flange to flange and which is assembled on site.
Downstream of the short diffuser there is the expansion joint and then the exhaust gas flows are conveyed
to the discharge (to a stack or a boiler) via a second exhaust gas diffuser.
Refer to figure 1 .
In the diffusers the static pressure increases as the exhaust gas flow velocity decreases.
 Gas turbine diffuser

This diffuser, by conical shape, is bolted to the gas turbine casing and, on its outlet end, it is welded to the
downstream exhaust system. This diffuser is connected to the blow off lines, to discharge the air from
compressor during start up and shut down of the gas turbine.
In addition it accommodates also the 24 thermocouples, in a circumferential arrangement, used to detect
the exhaust gas temperature (TET).
The diffuser is also equipped with a manhole for inspection purpose.
 Exhaust gas diffuser

The second diffuser is used to convey the exhaust flow to the discharge (boiler or stack).
For this component, see the relevant section in the Outside Vendor Part Manual.
Page 1 of 2
EXHAUST GAS DIFFUSERS TGO2-0520-E70001
01.06.16
Figure 1
Page 2 of 2
EXHAUST GAS DIFFUSERS TGO2-0520-E70001
01.06.16
BEARING HOUSING (COMPRESSOR AND TURBINE)
 General
The function of the bearing casing is to support the rotor (turbine and compressor side).
 Compressor bearing housing

Refer to figure 1.
The bearing housing (8) comprises outer and inner shell which form the compressor intake duct and are
connected by struts .
The interior accommodates bearing and seal ring. The combined journal and thrust bearing (5) with radial
struts (6) is located in the strut plane. The shaft is sealed by a bearing seal ring (2) at the front end and an
oil box (7) at the rear.
Items showed in figure 1:
1. Intermediate shaft
2. Seal ring
3. Coupling
4. Cover
5. Combined journal and thrust bearing
6. Radial struts
7. Oil box
8. Bearing housing
Page 1 of 5
BEARING HOUSING TGO2-0530-E70000
19.09.14
6 8
4
1
2 7
Figure 1: Compressor Bearing Housing
Page 2 of 5
19.09.14
 Turbine bearing housing
Refer to figure 2 and figure 3.

The bearing casing comprises an inner cylinder (1) which is connected by the five radial struts (2) to the
downstream outer casing (3).
The tilting-pad journal bearing (4) is bolted to the bearing shell support sleeve.
Oil is supplied to the bearing an oil chamber (5) connected to the oil supply pipe (6). Oil is drained through
the pipe (7) screwed into the casing. The cover plate, the bearing shell support sleeve and the bearing
casing are protected with a layer of thermal insulation (8).
Items showed in figures 2 and 3:
1 Inner cylinder
2 Radial struts
3 Outer casing
4 Tilting pad
5 Oil chamber
6 Oil supply pipe
7 Drain pipe
8 Insulation
Page 3 of 5
19.09.14
3
5
1
8
Figure 2: Turbine Bearing Housing
Page 4 of 5
19.09.14
6
Fig 3: Turbine Bearing Housing
Page 5 of 5
19.09.14
COMPRESSOR BEARING
 General
The compressor bearing is a combined journal and thrust bearing which has the task to supports the rotor
at the compressor side and to support the axial thrust. In addition it is designed to accommodate a facility
to displace the rotor axially.
Refer in addition to section TGO2-0530.
The combined journal and thrust bearing (2) is a split plain bearing. Two bearing shells (3) lined with babbitt
metal are inserted into the journal bearing bore. Their inside surfaces are shaped such that load-bearing oil
wedges form between the bearing shells and the shaft during operation. Lube oil is supplied through bores
into the babbitt metal. Lifting oil is injected at high pressure (5) to reduce friction at low speed (start up and
shut down). A thermocouple is installed in the lower journal bearing shell monitors the babbitt metal
temperature at that location which is subjected to the greatest thermal loading.
1 Thrust bearing pads

2 Bearing shell support sleeve
3 Bearing shell
4 Bolts
5 Lifting oil supply
Figure 1: Compressor bearing
Page 1 of 2
COMPRESSOR BEARING TGO2-0540-E70000
10.12.14
The thrust bearing is designed as a tilting-pad bearing in the higher stresses region and as a rigid bearing at
the less stressed region (rear). Oil is supplied via bores in the bearing shell support sleeve and via injection
nozzles. The specific geometry of this bearing ensures automatic adjustment and proper formation of the
oil film. Thermoelements are installed in upper and lower thrust bearing shells to monitor babbitt metal
temperature.
The bearing is also equipped with several pistons actuated by lube oil in order to shift the rotor during
operation (Rotor Displacement System) in direction opposite to flow, for functional details see section
TGO2-6001.
Figure 2: Compressor bearing with RDS system
Page 2 of 2
COMPRESSOR BEARING TGO2-0540-E70000
10.12.14
TURBINE BEARING
 General
The shaft at the turbine end in supported by a journal bearing.
The journal bearing is a tilting-pad journal bearing. Individual tilting-pad segments are lined with
babbitt metal and offer optimum operating behavior thanks to their spherical seats.
Lube oil is supplied to the injection nozzles via a ring duct. Jacking oil is injected at high pressure
through the bottom two tilting-pad segments to ensure that complete lubrication is maintained at
low speeds. This reduces wear on the babbitt contact surface and facilitates shaft rotation. Oil is
then connected at the two sides of the bearing and drained off.
Thermocouples monitor babbitt metal temperature at those locations subjected to the greatest
thermal loading.
This bearing can be removed axially in the downstream direction.
For further details and figures refer to section TGO2-0530.
Page 1 of 1
TURBINE BEARING TGO2-0560-E70000
19.09.14
INTERMEDIATE SHAFT
 General
The intermediate shaft connects the gas turbine to the generator.
 Description
The intermediate shaft (see figure 1) is coupled by bolts to the mating flanges of the gas turbine, at the
compressor side, and of the generator.
On the intermediate shaft a gear ring is mounted to drive the pinion of a hydraulic motor of the turning
gear (see section TO2-0620). Cranes are also provided to allow speed measurements.
Figure 1: Intermediate shaft
Coupling flange to generator Coupling flange to gas turbine
cranes for turbine speed measurement gear ring
Page 1 of 2
INTERMEDIATE SHAFT TGO2-0600-E70001
24.10.18
Only in case of multi-shaft configuration, in order to avoid injury to personnel due to the shaft rotation
when the gas turbine is running, on the intermediate shaft between the gas turbine and generator
enclosure there is a cover protection.
When the cover protection is open an interlock logic is activated to inhibit the machine start up, this to
avoid to have the shaft running while the cover is open.
See figure 2 for an example of possible configuration of the cover protection on the intermediate shaft.
Figure 2: example of a cover protection on the intermediate shaft

Page 2 of 2
INTERMEDIATE SHAFT TGO2-0600-E70001
24.10.18
MANUAL TURNING GEAR
 General
Provision for rotating manually the shaft for slow turning is given, in case it is necessary to manually rotate
the shaft (e.g. due to a fault in the automatic turning procedures or if required by commissioning or
maintenance activities). For this purpose a strap wrench is included in the gas turbine operating tools.
WARNING !
Manual turning operation using the strap wrench is NOT RECOMMENDED
It is necessary to MANUALLY rotate the shaft ONLY when, in case of TRIP or Shutdown, the following
conditions are all verified :
1. FAULT of BHS turning sequence

2. SFC emergency turning sequence fault or not started ( when applicable)
3. When GT has reached standstill condition (speed null (rpm0))
See also section :

General operating instruction TGO3-0033
SFC Emergency turning TGO3-0034 when applicable
GT starting – Lube oil sequence TGO3-0047
BHS turning Sequence TGO3-0049
 Description
Before any manual intervention, it must be ensured that the shaft is at complete standstill (0 rpm).
The strap (2) is wrapped around a readily accessible region of the shaft (1) and inserted through the handle
of the strap wrench (3) (See figure 1).
Page 1 of 3
MANUAL TURNING GEAR TGO2-0610-E70001
14.07.16
CAUTION !
Risk of injury!
In order to avoid injury to personnel due to the shaft rotation, before any manual
intervention, verify that SFC is electrically interlocked (only when SFC Emergency turning is
applicable)
There is a risk of pinching one's fingers when threading the strap through the strap
wrench handle.
Never attempt to mount the strap wrench when the shaft is rotating!
The jacking oil system must be switched on (by manual command) before starting rotating the shaft.
After positioning the strap wrench near the top of the shaft and pulling the strap taut, the shaft line can be
rotated by pulling down on the handle of the strap wrench (cf. Fig. 4). The extension (4) of the strap wrench
handle can be pulled out to increase leverage.
The shaft can be kept in rotation by repeatedly "ratcheting" the strap wrench and pulling down on the
handle.
Figure 1
1 Shafting
1 Shafting 2 Strap
2 Strap 3 Strap wrench
3 Strap wrench 4 Handle extension
Attaching the Strap Wrench Turning the Line of Shafting with Strap Wrench
Page 2 of 3
14.07.16
Figure 2
Page 3 of 3
14.07.16
HYDRAULIC TURNING GEAR
 General
The hydraulic turning gear is used to turn the rotor after the gas turbine has been shut down. This ensures
uniform cooling of the rotor and it prevents distortion.
 Description
Refer to figure 1. On the intermediate shaft (see section TGO2-0600), a gear rim is mounted. On the gear
rim a drive pinion (7) acts to turn the rotor.
To turn the rotor, the drive pinion (7) mounted on a pivot arm (8) is shifted inward to engage the gear rim.
The pinion (6) connects the drive pinion (7) with the hydraulic motor (1).
When moving the pivot arm (8), the circumferential speed of the drive pinion (7) and the gear rim on the
intermediate shaft must be equal.
The speed of the hydraulic motor, taking account of the transmission ratios must be brought to the speed
of engagement.
 Hydraulic Motor
The hydraulic motor (1) converts oil pressure (given by the lube oil system, see section TGO2-1501) into
torque. The greater the oil pressure acting on the hydraulic motor, the greater this torque will be. The
speed of the hydraulic motor is roughly proportional to the oil flow rate. This speed is measured by speed
sensors (3).
 Engaging mechanism
The drive pinion (7) is mounted on a pivot arm (8).
To shift the drive pinion (7) inward, oil pressure is acting on the engaging cylinder (2).
The motion of the engaging cylinder causes the pivot arm and the attached drive pinion (7) to move
towards the gear rim of the intermediate shaft causing the engaging of the drive pinion (7) with the gear
rim of the intermediate shaft. The proximity switches (4) detect the status (engaged / Not engaged) of the
pinion.
When the turning gear is not in operation, the engaging cylinder is not pressurized and the pivot arm (8) is
held in the disengaged position by the spring (5).
Page 1 of 2
HYDRAULIC TURNING GEAR TGO2-0620-E70001
19.09.14
Figureff
Figure 1 : Hydraulic motor
3 1
4
5
6
7
GEAR RING
1. Motor
2. Engaging cylinder
3. Speed sensors
4. Proximity sensors
5. Spring
6. Pinion
7. Drive pinion
8. Pivot arm
Page 2 of 2
HYDRAULIC TURNING GEAR TGO2-0620-E70001
19.09.14
Combustion chamber
COMBUSTION CHAMBER
 General
In the combustion chamber the combustion between air from the compressor and fuel takes place with
thermal energy release. The hot gases as combustion products expand in the turbine section thus
producing mechanical work.
Air from the compressor is partly used for cooling the blades and vanes and the combustion chamber while
the most part enters the burners.
Burners are described in section TGO2-0760.
 Description
The annular chamber has a ring shape with a decreasing section towards the turbine inlet. Refer to figure
1.
It consists of two casings: the inner shell (9) and the outer shell (5). The inner shell is firmly bolted to the
shaft guard and it constitutes the inner contour of the ring combustor. The air flow from the compressor
outlet diffuser (1) enters the burner assemblies (2). The end of the outer shell (5) engages with the turbine
stationary blade carrier such that the inner shell and the outer shell can move independently of one
another.
The external part of the combustion chamber accommodates the 24 burners (2), uniformly spaced.
The combustion chamber components inside the outer casing are enveloped and cooled by a flow of
compressed air from the compressor outlet.
The inner surface of the combustion chamber is lined with ceramic tiles (3) and heat shields (8) in the
terminal parts.
Ceramic tiles (3) are fixed to the ring combustor by metallic tile holders. Also these tile holders are cooled
with air from the compressor outlet. Each row of tiles ends in heat shields. Thanks to the lining on the hot
gas side of the combustion chamber and the flow of seal air, the casing is not subjected to the high
temperatures of combustion.
Two manholes (6) allow access into the combustion chamber in order to perform maintenance activities on
the burners and in the inner part of the combustor or inspection of the hot gas path items and turbine inlet.
All items, which get into contact with the hot gas, can be dismantled through the two manholes.
The flame sensor for flame monitoring are located in two openings in the outer shell.
Page 1 of 3
COMBUSTION CHAMBER TGO2-0700-E70001
19.09.14
Figure 1 Section of the combustion chamber
3 4 5 6 7 8
2
9
1. Compressor outlet diffuser
2. Burner assembly
3. Ceramic tile
4. Outer casing
5. Outer shell
6. Manhole
7. Heat shields
8. Hot gas outlet
9. Inner shell
Figure 2 Internal view of the combustion chamber
Page 2 of 3
19.09.14
Burners tiles 1° vanes
Page 3 of 3
19.09.14
BURNER ASSEMBLY FOR LIQUID AND GASEOUS FUELS
To keep low NOX emissions, premix burners are used both for fuel gas and for fuel oil mode. As
general concept of the premix combustion, if the fuel and air to be combusted are homogeneously
mixed prior to entry into the reaction region there are no zones of stoichiometric mixture and
therefore no zone of high peak temperatures, which are mainly responsible for NOx formation.
The burner used for premix combustion is named “hybrid burner”.
Construction and Functional Principle of the Hybrid Burner

The hybrid burner is shown schematically in Fig.1. The burner has two swirlers for the air flow. The
combustion air is swirled as it is passed into the combustion zone, with the larger fraction of
combustion air passing through the diagonal swirler (outer swirler, n°6) and the smaller fraction
passing through the axial swirler (inner swirler, n°7). Both swirlers gives to the air the same rotational
direction. The burner has three distinct nozzle systems for fuel gas operation: the premix and two
pilot burner nozzles. There are two distinct nozzle systems for fuel oil operation: the central diffusion
burner nozzle and the premix burner nozzles located in the duct of the diagonal swirler.
The Pilot burner (n°1) for fuel gas operation could be used only during fuel ignition at GT start up.
The diffusion burner for fuel oil operation is used for startup and part load operation at low loads.
The fuel oil supplied to the diffusion burner (n°9) is partly injected and partly going back via the
return line (n°8).
In fuel gas premix mode, the gas is added to the combustion air via nozzles (n°11) in the diagonal
swirlers (n° 6) and mixes with the air as it flows toward the combustion zone. A small pilot flame,
supplied by a separate channel (n° 3), burns during premix mode to enhance premix flame stability.
In fuel oil premix mode, the fuel oil is sprayed through the injection nozzles into the combustion air
in a very tight pattern; each of the injection nozzles is located at the inner cone of the diagonal
swirler between two adjacent vanes at a point downstream of the diagonal swirler itself. The air flow
breaks down the individual jets into droplets which are evaporated by the high air temperature and
mix with the air prior to reaching the flame front. A small pilot diffusion flame burns continuously to
enhance premix flame stability. The pilot fuel is injected into the combustion zone via the central oil
lance (fuel oil diffusion burner, n°12). In the event of a load rejection, the supply of premix oil to the
burner is interrupted so that the premix flames extinguish, and the supply of fuel for the diffusion
flame is increased to the level required to ensure stable flame conditions.
Again referring to figure 1, each pilot annulus is equipped with a spark plug (5).
Spark plug ignites the gas at the gas outlet opening. An ignition voltage (approx. 10,000 V) generates
the spark between the two spark electrodes. The spark is present throughout the ignition process.
Optimal sparking requires strictly maintaining the specified gap between the two spark electrodes.
The gap is set by bending the spark electrodes.
Page 1 of 3
BURNER ASSEMBLY FOR LIQUID AND GASEOUS FUELS TGO1-0760-E70006
10.12.14
Figure 1: AE94.3A Dual Fuel Burner assembly
1 Pilot gas inlet (option)
2 Premix gas inlet
3 Pilot 2 gas channel
4 Spark plug
5 Premix Fuel Oil nozzles
6 Diagonal swirler
7 Axial swirler
8 Fuel oil return line
9 Fuel oil diffusion supply
10 Fuel oil premix channel
11 Premix gas nozzles
12 Fuel oil diffusion nozzles
Page 2 of 3
10.12.14
9
8 3
12
1
Figure 2: AE94.3A Dual Fuel Burner Section /pilot and Pilot 2 view
2 11
10
Figure 3: AE94.3A Dual Fuel Burner Section /PREMIX Fuel Gas and PREMIX Fuel Oil view
Page 3 of 3
10.12.14
Cooling air system
P&ID TURBINE COOLING AND SEAL AIR SYSTEM
See the attached drawing
In addition see
Set Point list TGO1-0530

Instrument list TGO1-0500
Electrical load list TGO1-0510
Equipment list TGO1-0520
Page 1 of 1
P&ID TURBINE COOLING AND SEAL AIR SYSTEM TGO2-0800-E00000
06.10.07
For Construction.
TURBINE COOLING AND SEAL AIR SYSTEM, DESCRIPTION
Function
Turbine blades and vanes are cooled with air to prevent turbine material temperatures from
exceeding maximum permissible limits.
Air at higher pressure seals gaps and hollow spaces, present in the gas turbine for reasons relating to
mechanical design, preventing hot gases from entering these spaces.
Air is extracted from the compressor and supplied to the turbine blades, vanes, rotor and casing as
seal and cooling air. Because the cooling air in most cases also serves as a seal, the remainder of this
text does not differentiate between cooling air and seal air.
Remark: turbine stationary vanes are named TV (Turbine Vanes) with number showing the stage,
turbine rotor blades are named TB (Turbine Blades) with number showing the stage.
Functional Principle
Since the cooling air must be supplied at various pressure levels for the respective rows of turbine
stage, it is extracted from a proper compressor stage, where the pressure is adequate.
One fraction of the cooling air flows goes to the stationary vane carriers to the turbine vanes via
external extraction lines (see P&ID “Turbine cooling system”).
Any water which may have been accumulated there during compressor washing is drained off via
drain lines (see “P&ID drainage system” and system description TGO2-4966 “Drain System”).
Another fraction of cooling air flows is led to the turbine blades via internal passages to the rotor and
it cannot be shown on P&ID.
Cooling of Turbine Stage 4

To cool the vanes of turbine stage 4 (TV4), air is extracted downstream of compressor stage 5 at an
extraction point designated E1.
Rotor blades of turbine stage 4 (TB4) are not cooled, because heat removal is achieved by the seal air
leaving TV4.

To cool the TV3, air is extracted at two extraction points designated E2 downstream of compressor
stage 9. The extraction points are offset from one another on the compressor casing.
To cool the TB3, air is extracted downstream of compressor stage 9 and flows to the blades through
channels in the rotor. Design aspects of the channels relevant to fluid dynamics determine the
pressure of the cooling air.
Page 1 of 4
TURBINE COOLING AND SEAL AIR SYSTEM, DESCRIPTION TGO2-0801-E70002
01.12.14
To cool the TV2, air is extracted at two extraction points designated E3 downstream of compressor
stage 13. The extraction points are offset from one another on the compressor casing.
To cool the TB2, air is extracted downstream of compressor stage 13 and flows to the blades through
channels in the rotor. Design aspects of the channels relevant to fluid dynamics determine the
pressure of the cooling air.

A portion of the compressor discharge air flow is used as cooling air for turbine stage 1.
The TV1 is cooled by a portion of the compressor discharge via a cooling air guide pipes running
radially around the rotor.
The TB1 is cooled directly from the air coming from the compressor outlet and flowing to the blades
through channels in the rotor. Design aspects of the channels relevant to fluid dynamics determine
the pressure of the cooling air.
Control of Cooling Air for the Stationary Vanes

The cooling air system is designed for the most unfavorable conditions, ensuring sufficient cooling for
blades and vanes all times. The worst condition occurs with the inlet guide vanes in their minimum
position at low ambient temperature. Under these conditions, the pressure at the extraction points is
at its lowest relative to the compressor discharge pressure and thus the flow of cooling air is at its
minimum. Since it is designed for the most critical point, in other more favorable conditions the
cooling air can be reduced and the saved air can be used for combustion, thus increasing the gas
turbine power and efficiency. The adjusting of the cooling air is done only for turbine stage 2 and 3,
while for turbine stage 1 and 4 the cooling air flow is kept at its maximum flow.
Control of Cooling Air to TV2 and TV3

The cooling air flow to the TV2 and to the TV3 is determined by the differential pressure between the
cooling air supply pressure upstream of the vanes and the opposing pressure in the hot gas path. The
cooling air pressure upstream of the stationary vane carriers and the compressor discharge pressure
are measures for these pressures.
To adjust the cooling air flow the control valves MBH22AA101 and MBH22AA102 are located in each
external pipe to TV2 and control valves MBH23AA101 and MBH23AA102 are located in each external
pipe to TV3.
The pressure upstream each stationary vane carrier is measured redundantly by pressure
transducers MBH22CP102 and MBH22CP103 and MBH22CP104 for TV2 and MBH23CP102 and
MBH23CP103 and MBH23CP104 for TV3. Shutoff valves MBH22AA412, MBH22AA413, MBH22AA414
MBH23AA412, MBH23AA413, MBH23AA414 are located at the lowest points of the instrumentation
lines. Condensation in the instrumentation lines can be drained through these valves when the GT is
at standstill.
Page 2 of 4
01.12.14
Compressor discharge pressure is measured redundantly using pressure transducers MBA12CP101
MBA12CP102 and MBA12CP103. These measuring points are described in system description TG02-
2601, “Gas Turbine Instrumentation”.
Control action (i.e. valves positioning) is based on the ratio “cooling air pressure upstream of the
stationary vane carrier”/“compressor discharge pressure”. This parameter is defined as PP.TLE2.01
for TV2 and PP.TLE3.01 for TV3.
The cooling air valves are mechanically protected against complete closure: when fully closed they
ensure anyway a passage for a minimum required cooling air flow.
Should the cooling air pressure drop below the limit value PP.TLE2.02 for TV2 or PP.TLE3.02 for TV3 ,
an alarm “low pressure ratio to TV2” or “low pressure ratio to TV3“ is issued.
In case the cooling air pressure drop below the limit value PP.TLE2.04 for TV2 or PP.TLE3.04 for TV3,
a GT shut down is issued (this protection is maintained in the GT control system but this condition is
not foreseen to occur).
Pressure Measurement, Axial Displacement Compensation Piston

The E1 extraction point is connected to the axial displacement compensation piston via the
extraction line, the turbine casing and the 5 radial struts of the turbine bearing casing. This piston
partly compensates for the axial thrust of the rotor and thus relieves the compressor thrust bearing.
The pressure exerted against the piston can be read off of measuring point MBH24CP501 (pressure
gage).
Shutoff valve MBH24AA401 is located at the lowest point of the instrumentation line. Condensation
in the instrumentation line can be drained through this valve when the GT is at standstill.
Page 3 of 4
01.12.14
OPTION:
WARNING
The activation of this option is possible only when decided and performed by Ansaldo Energia
Gas Turbine Department specialist.
Under special conditions, to be evaluated by Ansaldo Energia during the commissioning or

performance test execution, taking into account site conditions and contractual constrain, it is
possible to set a variable set point for PP.TLE2.01 and/or PP.TLE3.01 as function of IGV.
This option has the purpose to optimize the minimum environmental load or operation at low partial
load if required.
The variable set point for PP.TLE2.01 or PP.TLE3.01 is reported directly in the Set Point List, version
“As Built”.
Page 4 of 4
01.12.14
Hydraulic system
P&ID HYDRAULIC OIL SYSTEM
In addition see

Page 1 of 1
P&ID HYDRAULIC OIL SYSTEM TGO2-2002-E00000
13.11.14
For Construction.
For Construction.
For Construction.
HYDRAULIC OIL SYSTEM DESCRIPTION
The high-pressure hydraulic oil system has the following task:

 to position the control valves of the fuel system;
 to open the emergency stop valves;
 to position the Inlet Guide Vane and First Compressor Vane1 (CV1) actuators .
The unit supplies the hydraulic oil at the required conditions, i.e. operating pressure, in sufficient
quantity, at the optimum temperature and in an adequately pure condition.
The actuators are mounted directly on the valves ensuring a compact design. The actuators are
connected to the hydraulic oil supply station via one oil supply line and one oil return line of
structural steel.
The IGV/CV1 actuator and valve actuators are described in dedicated sections.
Configuration of the Hydraulic Oil Supply Unit

The hydraulic oil supply unit comprises all components essential to the supply of hydraulic oil, such
as pumps, filters and accumulators. All components are mounted on the hydraulic oil tank, yielding a
compact, transportable unit.
The tank is divided in two parts. The first part of the tank contain the cleaned oil, and the second part
of the tank contain the oil deriving by the return line of the actuator. The two parts of the hydraulic
tank are divided by a wall.
The hydraulic oil tank is made entirely of stainless steel in order to avoid corrosion. The tank is
equipped with an hygroscopic filter MBX01AT001 with the task to prevent the presence of umidity
inside the hydraulic oil.
The major components of the hydraulic oil supply unit are:
 hydraulic oil tank MBX01BB001,
 pumps MBX02AP001 and MBX02AP002,
 hydraulic oil pressure accumulators: MBX04BB001, MBX04BB002, MBX07BB001 and
MBX09BB001 (only in case of supply of hydraulic actuator for the first Compressor Stage) ;
 supply line filters MBX03AT001 and MBX03AT002,
 the combined cooling and cleaning loop (secondary loop) with two oil-air cooler
MBX06AH001/MBX06AH002, and return line filter MBX08AT001 which provides primary
filtration of the hydraulic oil.
 One hydraulic oil heater MBX01AH001
1
When provided by the project
Page 1 of 7
HYDRAULIC OIL SYSTEM DESCRIPTION TGO2-2003-E70001
20.01.17
The supply station also includes indicating and monitoring devices housed in a rack which is also
mounted on the hydraulic oil tank.
All the electrical instrumentation can be removed during the hydraulic oil system operation.
The two submersible pumps MBX02AP001 and MBX02AP002 are directly connected to secondary
loop pumps MBX06AP001 and MBX06AP002, respectively, and inserted into the hydraulic oil tank
from above. The suction sides of the two pumps are connected to the part of the tank used for the
cleaned oil.
Pump MBX02AP001 is designated as the operating pump, pump MBX02AP002 as the standby pump.
These are axial piston pumps of identical design which function on the swash plate principle. The
pumps are equipped with a pressure-dependent control system which continuously adapts the
amount of oil supplied to the amount consumed by the hydraulic system. Pump delivery is varied by
altering the angle of disc inclination in the pump dependent upon the hydraulic oil pressure in the
hydraulic system. The optimum adaptation of oil supply to oil consumption thus achieved practically
eliminates the need to remove excess oil from the system. In this way it’s also optimized the
electrical power comsumption of electrical motor coupled to the pump.
Pump discharge pressure is about 160 bar.
Page 2 of 7
20.01.17
The pumps are equipped with adjustable, internal safety valves MBX02AA191 and MBX02AA193.
These valves protect the pumps from excessive pressure. Adjustable pressure limiting valves
MBX02AA192 and MBX02AA194 are also installed in the discharge pipes downstream of the pumps.
If the downstream oil pressure exceeds a specific limit, these valves divert a portion of the oil being
pumped back to the tank, thus preventing impermissibly high pressures within the hydraulic system.
The oil pressure within the supply lines directly downstream of axial piston pumps MBX02AP001 and
MBX02AP002 is indicated by pressure gauges MBX03CP501 and MBX03CP502, respectively.
The discharge pipe of each pump is equipped with supply line filter MBX03AT001 and MBX03AT002,
respectively, both of which include a fouling monitor.
Differential pressure switches MBX03CP001 and MBX03CP002 monitor fouling and are equipped
with visual displays for local reading. Should the setpoint of at least one of the two differential
pressure switches be exceeded for more than 10 minutes, the alarm "Hydraulic oil filter fouled" is
annunciated. The supply line filters can be individually isolated by valves MBX03AA251 and
MBX03AA252 and MBX03AA253 and MBX03AA254. While the filters are being changed, the standby
pump temporarily assumes the task of supplying hydraulic oil. Since the supply line filters are
intended to function simply as a protective device, they are subjected to little fouling during service.
The discharge lines of the two pumps merge downstream of the supply line filters. Reverse flow
through the pumps while shut down is prevented by check valves MBX03AA201 and MBX03AA202.
Four hydraulic oil accumulators are mounted in two different hydraulic accumulator blocks with the
task to supply oil at the hydraulic valve actuators during the transitory.
The first hydraulic accumulator block includes the followings component:
- Hydraulic oil accumulators MBX04BB001, MBX04BB002;
- local pressure taps: MBX04CP401,MBX04CP402;
- pressure indicators MBX04CP501, MBX04CP502;
- shutoff valve block comprising: shutoff valve MBX04AA251 and MBX04AA252, drain valves
MBX04AA401 and MBX04AA402, safety valve MBX04AA191 or MBX04AA192, respectively.
The second accumulator block includes the followings component:
- Hydraulic oil accumulators MBX07BB001,
- local pressure tap MBX07CP401;
- pressure indicator MBX07CP501;
- shutoff valve block comprising: shutoff valve MBX07AA251,drain valve, safety valve
MBX07AA191.
- They are mounted in an hydraulic accumulator block with the task to supply oil to the Inlet
Guide Vane Actuator
Page 3 of 7
20.01.17
The third accumulator block is present only in case of actuation of the First Compressor Stage (CV1)
and includes the followings component:
- Hydraulic oil accumulators MBX09BB001 (only in case of supply of hydraulic actuator for CV1)
- local pressure tap MBX09CP401;
- pressure indicator MBX09CP501;
- shutoff valve block comprising: shutoff valve MBX09AA251,drain valves MBX09AA401, safety
valve MBX09AA191.
- They are mounted in an hydraulic accumulator block with the task to supply oil to the First
Compressor Stage Actuator
System pressure monitors MBX03CP005, MBX03CP006 and pressure transducer MBX03CP101 are
connected to the discharge pipe downstream of the filters. The tasks performed by these devices are
described below under "Pressure Monitoring" paragraph.
The hydraulic oil supply line runs from this point to the various hydraulic actuators, which are
described in separate sections. Each actuator is connected to the hydraulic oil supply station by one
oil supply line, and one oil return line.
The actuator return lines merge upstream of the hydraulic oil supply station and the return oil is then
fed back into the tank directly.
Secondary Loop
This loop maintains an optimal hydraulic oil temperature and keeps it free of debris by constantly
circulating the oil through oil-air cooler MBX06AH001/MBX06AH002 and filter MBX08AT001.
The secondary circuit has the task of keeping a good oil quality, i.e. maintain an optimum
temperature range by means of the coolers MBX06AH001/002 and eliminating contamination via the
filter MBX08AT001. The secondary oil circuit, independently of the working cycles of the high
pressure hydraulic unit, operates continuously. By means of the secondary circulation pumps
MBX06AP001/002 (mechanically connected to the main circuit pumps), the oil is first conveyed
through the air coolers MBX06AH001/002. According to the temperature in the oil tank, the main
ventilator is switched on or off, whereas the other is kept in cold standby (also see "Oil Temperature
Monitoring"). The oil flow from the secondary loop is then merged with the return oil line
downstream of the cooler and fed to filter MBX08AT001.
The oil return line filter fouling is monitored by backpressure switch MBX08CP001. If the pressure
switch setpoint MBX08CP001 is exceeded for longer than 10 minutes, the alarm "Hydraulic oil filter
fouled" is annunciated. This filter is additionally protected against mechanical damage by a check
valve connected in parallel. This valve opens if a certain pressure is exceeded upstream of the filter.
The secondary loop pumps are equipped with safety valves MBX02AA201, MBX02AA202,
MBX06AA201 and MBX06AA202 .
The secondary loop flow of oil can be shut off with the aid of shutoff valve MBX06AA001. Oil then
flows directly back into the tank Secondary flow shutoff is necessary, for example, when it is
Page 4 of 7
20.01.17
necessary to carry out brief maintenance activities on the cooler or in case it is necessary to replace
the filter element MBX08AT001.
After changing the filter, the manual valve MBX06AA001 shall be positioned again in the normal
position.
Secondary loop pressure is indicated on pressure gauge MBX06CP501 and monitored by pressure
switch MBX06CP001. If, in the event of a postulated failure of the circulation pump or cooler, for
example, the secondary loop pressure should drop below a specified limit for more than five
seconds, the alarm "Hydraulic secondary loop faulted" is annunciated.
Oil Temperature Monitoring

The hydraulic oil temperature monitoring system is always ready for operation, both during outages
and GT operation.
The temperature of the hydraulic oil in the tank is measured by resistance thermometer
MBX01CT101. The output signal of the resistance thermometer is monitored for violation of various
limits.
Oil is heated as necessary during outages by operation of the pumps. If the temperature drops below
limit T.HYD.01 the oil is circulated by starting up both hydraulic oil pumps. If the temperature
exceeds limit T.HYD.02, both hydraulic oil pumps are switched off. Oil temperature control is only
active if the oil level protection system in the receiver has not responded.
If the oil temperature exceeds setpoint T.HYD.04, the fan at the oil-air cooler in the secondary loop is
switched on. When the oil temperature drops below limit T.HYD.03 the fan is switched off. Should
the oil temperature exceed T.HYD.05, e.g. 70 °C, the alarm "Hydraulic oil temperature high" is
annunciated.
Oil heater MBX01AH001 is switched on at T.HYD.06 and switched off at T.HYD.07.
The temperature of the hydraulic oil in the tank can be read at the local indicator MBX01CT501.
Warning:
When the alarm “hydraulic oil temperature high” is issued, the function of the fan and the
clogging of the secondary filter must be checked.
Page 5 of 7
20.01.17
Oil Level Monitoring
Oil level monitoring equipment is always ready for operation, both during outages and GT operation.
The level of hydraulic oil in the tank can be monitored by sight glass MBX01CL501 ,by level monitors
MBX01CL001, MBX01CL002 and by level transducer MBX01CL101.Limits L.HYD.02 and L.HYD.04 are
derived from the pressure transducer signal.
Level monitor MBX01CL002 has two switches –S01 and –S02, one used for alarm and the other one
for tripping the hydraulic oil pumps. MBX01CL001 has only the switch corresponding to the
intervening point MBX01CL001-S01.
If the oil level in the tank drops below setpoint MBX01CL002-S01 or L.HYD.02 , the alarm "Hydraulic
oil level low" is annunciated.
If the oil level in the tank drops below at least two of the two limit switches MBX01CL001-S01,
MBX01CL002-S02 or L.HYD.04 (2-of-3 logic), both main pumps (if running) and thus also the
secondary loop pumps are shut down and the alarm "Hydraulic oil level too low" is annunciated. With
the pumps shut down, hydraulic pressure slowly decreases and results in GT trip when it drops below
the minimum pressure (see paragraph "Pressure Monitoring").
Pressure Monitoring
The header downstream the supply line filters, accommodates not only local pressure indicator
MBX03CP503, but also pressure switches MBX03CP005, MBX03CP006 and pressure transducer
MBX03CP101. These monitor the pressure in the hydraulic oil system. Limits P.HYD.02 and P.HYD.04
are derived from the pressure transducer signal.
The operating pump is switched on when GT starts. If system pressure is lower than operating
pressure P.HYD.02, the reserve pump is also switched on to accelerate the increase in system
pressure and filling of the pressure accumulator. System pressure monitoring with pressure switch
MBX03CP005 and pressure transducer MBX03CP101 is enabled concurrent with startup of the
hydraulic pumps. When the upper settings of pressure switches MBX03CP005 and MBX03CP006 or
limit P.HYD.02 are exceeded (2-of-3 logic), operating pressure has been reached and the standby
pump is shut down, if running.
The hydraulic system is now ready for operation. The operating pump is capable of maintaining a
system pressure of approx. 160 bar under all normal operating conditions without the aid of the
standby pump.
If the hydraulic oil pressure drops below the setpoint of pressure switch MBX03CP005 or P.HYD.02
during GT operation, a startup command is sent to standby oil pump. This occurs regardless of
whether the operating pump is running at this time. The standby pump remains in operation
regardless of the pressure established or whether the operating pump is running. The operating or
standby pump can be shut down manually once the cause of the fault has been determined. Manual
shutdown of one of the two pumps is not enabled until operating pressure has been exceeded (e.g.
> 145 bar).
Page 6 of 7
20.01.17
The alarm "Standby hydraulic pump on" is annunciated during operation of standby oil pump
MBX02AP002.
Changeover from the operating pump to the standby pump can be performed as necessary by first
starting up the standby pump. The operating pump can be shut down when both pumps are running
and system pressure is greater than the operating pressure (e.g. > 145 bar). Changeover back to the
operating pump is analogous.
Fuel safety shutoff valves, these include the emergency stop valve and control valves in both the
natural gas and fuel oil systems (those foreseen), are only given the enable to open once the
operating pressure (e.g. > 145 bar) has been exceeded.
If pressure drops below the settings of the two pressure switches MBX03CP005 and MBX03CP006
and limit P.HYD.04, e.g. 100 bar (minimum pressure, 2-of-3 logic of MBX03CP005, MBX03CP006 and
P.HYD.04), the gas turbine trips.
Warning:
In case of main pump fault, the stand-by pump is switched on. Should the main pump be put
again in operation, when the operating pressure is reached, it can be switched off by manual
command. After the repair of the main pump the stand-by pump can be switched off manually.
Hydraulic Oil Accumulators

The hydraulic oil accumulators are redundant bladder accumulators filled with nitrogen to a prefilled
pressure.
The accumulators task is to prevent fluctuations on the pressure circuit to avoid trip due to minimum
pressure. Fluctuations can occur during pump changeover from operating pump to standby pump
Page 7 of 7
20.01.17
P&ID HYDRAULIC OIL FOR FUEL VALVES
AND HP PURGING CONTROL VALVE
In addition see

Page 1 of 1
P&ID HYDRAULIC OIL for FUEL VALVES and HP PURGING CONTROL VALVE
TGO2-2004-E00000
21.02.14
For Construction.
For Construction.
For Construction.
For Construction.
HYDRAULIC OIL SYSTEM FOR FUEL VALVES
Overview
The fuel valves (stop and control) and the control valve for the High Pressure (HP) Purging are equipped
with hydraulic actuators, which are connected to the hydraulic oil station supply. Refer to figure 1.
The hydraulic actuator ensures fast closing of the valves and fast positioning of the control valves
(according to the requirements of the Fuel Controller).
There are 3 types of actuators:
Type 1: actuator for fuel stop valve (gas and gasoil)

Type 2: actuator for fuel control valve (gas and gasoil supply line and HP purging)
Type 3: actuator for fuel control valve (only gasoil return line)
Since all the actuators of the same type are identical, only one description with a reference KKS code is
taken for each type of actuators, so there is no need to mention the fuel or the fuel system
configuration.
The numbers and the KKS of the actuators to be processed must be found in the applicable PIDs order
related.
Additional reference:
P&ID of the relevant actuators
Hydraulic oil station supply TGO2-2003
Fuel gas system TGO2-3001
Fuel oil system TGO2-3005
HP Purging system TGO2-3007
Valve Actuators – General

The principle structure and materials of the valve actuators are identical.
The actuator is mounted on the valve stem flange. It essentially comprises a hydraulic cylinder and a
Belleville spring stack which closes the valve and is integrated into the actuator unit. The piston area is
identical in the two cylinder plenums and pressure is applied from one side only. The valve can only be
opened when the actuator is supplied with hydraulic fluid under pressure. The Belleville spring stack in
the actuator applies the pressure necessary to close the valve.
Page 1 of 10
HYDRAULIC OIL SYSTEM FOR FUEL VALVES TGO2-2005-E72005
13.11.14
Actuator – control
unit
Actuator – cylinder
with Belleville
spring
Valve
Figure 1: Group Valve + Actuator
Each control devices (MBXyyAS001) is connected to the hydraulic supply station by one supply and one
return line.
Each control device is protected by a dedicated 10 µm pressure filter (MBXyyAT001). A limit switch
(MBXyyCP001) is installed to control the fouling of every filter. If the differential pressure value through
the filter exceeds the fixed value, the alarm ‘ Actuator MBXyyAT001 hydraulic oil filter dirty ‘ appears.
Control devices are implemented in the actuator housings in line with the respective task requirements
and are explained in the following.
Page 2 of 10
13.11.14
Stop valve actuators – Type 1
The table 1 shows the relation between each valve, actuator, actuator control module and equipment
inside each module.
Actuator control Equipment inside the module

Valve Actuator
module
MBP13AA051 MBX70AS002 MBX70AS001 MBX70AA001 :Solenoid tipe pilot valve with double
Fuel Gas coil 1,2 to cartridge
Emergency Stop MBX70AA031 : opening solenoid valve, coil 1,2
Valve MBX70AA051 : cartridge valve
FG-ESV MBX70AT001 : filter on supply line
MBX70BP001 : orifice on supply line
MBX70BP002 : orifice on discharge line
MBX70BP003: orifice on supply line
MBX70CP001 : differential pressure switch on filter
MBN23AA051 MBX77AS002 MBX77AS001 MBX77….all components as mentioned above
Fuel Oil ESV
Premix line
FO-PX-ESV
Fuel Oil ESV
Diffusion line
FO-DO-ESV
Fuel Oil ESV
Diffusion return
line
FO-DOR-ESV
Table 1: KKS Designations for stop valve actuators
Page 3 of 10
13.11.14
Filter on supply line
Limit switches (4
of 6 are here
Solenoid-type shown, the other 2
opening valve are on the back side
of the view)
Cartridge valve
Solenoid-type pilot
valve
with Belleville
spring
Figure 2 : Stop valve actuator
Refer to P&ID and to figure 2.
The actuator of the fuel gas stop valve (MBXyyAS001) comprises the solenoid-type opening valve
MBXyyAA031, the 2-way cartridge valve MBXyyAA051, the solenoid-type pilot valve MBXyyAA001.
To open the valve, the solenoid-type pilot valve MBXyyAA001 and the solenoid-type opening valve
MBX70AA031 are energized, the latter with a slight delay.
By energizing the solenoid-type pilot valve MBXyyAA001 the upper plenum of the spring-loaded piston
in the cartridge valve (MBXyyAA051) is pressurized, thus closing the cartridge valve and preventing the
oil flow in the lower part of the cylinder from draining into the return line.
Then the activation of the solenoid-type opening valve MBXyyAA031 supplies oil to the lower part of the
cylinder. The oil in the upper part of the cylinder is discharged in the return line and the valve is opened.
Closure of the natural gas emergency stop valve MBP/NyyAA051 in the event of trip is triggered by
deactivating solenoid-type pilot valve MBXyyAA001 (deactivation to close principle), the lower plenum is
depressurized. Pilot 2 oil to the cartridge flows back to the return line. Hydraulic oil flows via the opened
Page 4 of 10
13.11.14
cartridge valve into the upper part of the cylinder and the Belleville spring stack MBXyyAS002 in the
hydraulic cylinder push the cylinder to close (now the lower part of the cylinder is depressurized).
The cartridge valve is capable of draining large oil flows at low pressure drop, thus ensuring that the
emergency stop valve actuator achieves short closure times. The Belleville spring stack reliably closes
the emergency stop valve.
When the trip signal is received, the solenoid-type pilot valve MBXyyAA001 and the solenoid-type
opening valve MBXyyAA031 are simultaneously deactivated. This interrupts the connection to the
pressure line. Reliable rapid closure of the valve is, however, ensured by deactivation of the solenoid-
type pilot valve alone.
The OPEN and CLOSED positions of the emergency stop valves MBP/NyyAA051 are each monitored by
three inductive position limit switches located in the actuator unit (MBP/NyyAA051-S11, -S12, S13 -S21,
-S22, S23).
Page 5 of 10
13.11.14
Control valves actuators (with stop function) – Type 2
The table 2 shows the relation between each valve, actuator, actuator control module and equipment
inside each module.

Valve Actuator
module
MBP22AA151 MBX81AS002 MBX81AS001 MBX81AA002 : pilot valve to cartridge
FG-PX-CV MBX81AA052 : cartridge valve
MBX81AA101 : servovalve
MBX81AA281 : orifice on servovalve
MBX81T001 : filter on supply line
MBX81CP001 : differential pressure switch on filter
MBP23AA151 MBX82AS002 MBX82AS001
MBX82….. all components as the précédent
FG-PG-CV
MBP24AA151 MBX84AS002 MBX84AS001
FG-PG2-CV
MBN23AA151 MBX87AS002 MBX87AS001
FO-PO-CV
FO-DO-CV
HP-PURGING-CV
Table 2: KKS Designations for control valve actuators
Page 6 of 10
13.11.14
Position transmitter
Servovalve (LVDT)
Solenoid-type pilot Cartridge valve

valve
with Belleville
spring
Figure 3 : Control valve actuator
All the control valves have the same opening/closing structure of the stop valve.
The fast closing function is performed in the same way by energizing / deenergizing the solenoid-type
pilot valve (MBXyyAA001) which actuates the cartridge valve (MBXyyAA052).
The proper position of the control valve is controlled by the two-stage servo valve (MBXyyAA101).
The valve actuator, together with the control device, is an integral component of the control circuit. The
position controller sends a positioning signal in the form of a load-independent current to servo valve
Page 7 of 10
13.11.14
MBXyyAA101, which changes the hydraulic oil flow, proportionally to the signal current, but with a
much greater amplification. A positive current at the controller output opens the natural gas control
valve and a negative current closes it. The greater the current, the faster the natural gas control valve
opens or closes.
The hydraulic settings of the servo valve are such that in the event of a loss of electric power supply (e.g.
broken wire) the natural gas control valve always assumes its CLOSED position.
To open the valve, hydraulic oil is supplied to the lower plenum. Upward piston travel compresses the
closing spring and displaces the hydraulic fluid from the upper plenum into the return line.
To close the valve, a connection is opened between the lower plenum and the upper plenum and/or the
return.
Closure of the control valve in the event of trip is triggered by deactivating solenoid-type pilot 2 valve
MBXyyAA002 and depressurizing the lower plenum, causing the Belleville spring stack to rapidly close
the emergency stop valve. The Belleville spring stack reliably closes the control valve.
Two inductive position sensors (MBP/NyyAA151-B01/B02) with integrated electronics and plug
connection are mounted on the piston rod of each actuators.
Note
No manual service for the control valve is admitted.
Broken wire for both coils of the solenoid valves as well as failure of the valve
position regulator determines hydraulic trimming such that the control valves and
the stop valves are moved to the fail safe position.
Page 8 of 10
13.11.14
Actuator for fuel oil return control valve - Type 3
This actuator is applicable only to the fuel oil return control valve (the stop function for this valve is
not foreseen):

Valve Actuator
module
MBN53AA151 MBX86AS002 MBX86AS001 MBX86AA101 : servovalve
MBX86T001 : filter on supply line
MBX86CP001 : differential pressure switch on
filter
Position transmitter
Servovalve (LVDT)
with Belleville
spring
Figure 3 : Return control valve actuator

Page 9 of 10
13.11.14
The fast closing function is not foreseen for this valve since the total closure of this valve means
maximum amount of fuel oil injected in the combustion system.
The proper position of the control valve is controlled by the two-stage servovalve MBX86AA101.
The valve actuator, together with the control device, is an integral component of the control circuit.
The position controller sends a positioning signal in the form of a load-independent current to servo
valve MBX86AA101, which changes the hydraulic oil flow, proportionally to the signal current, but
with a much greater amplification. A negative current at the controller output opens the fuel oil
control valve and a positive current closes it. The greater the current, the faster the fuel oil control
valve opens or closes.
The hydraulic settings of the servo valve are such that in the event of a loss of electric power supply
(e.g. broken wire) the natural gas control valve always assumes its CLOSED position.
To open the valve, hydraulic oil is supplied to the lower plenum. Upward piston travel compresses
the closing spring and displaces the hydraulic fluid from the upper plenum into the return line. To
close the valve, a connection is opened between the lower plenum and the upper plenum and/or the
return.
The oil supplied in the feed line is filtered by fine filter (MBX81AT001) which is equipped with a
differential pressure switch (MBX81CP001).
Note
No manual service for the return control valve is admitted.
Broken wire for both coils of the solenoid valves as well as failure of the
valve position regulator determines hydraulic trimming such that the control
valves and the stop valves are moved to the fail safe position.
Page 10 of 10
13.11.14
P&ID HYDRAULIC IGV / CV1
In addition see

Page 1 of 1
P&ID HYDRAULIC OIL FOR IGV/CV1 TGO2-2010-E71000
13.11.14
For Construction.
For Construction.
HYDRAULIC OIL SYSTEM FOR IGV/CV1, DESCRIPTION
The following description concerns the actuator of the Hydraulic Inlet Guide (IGV) and first
Compressor Vane (CV1) systems.
Since the two actuators are identical, only one description with a reference KKS code is taken.
The hydraulic actuator MBX30AS001consists in a double effect piston. The hydraulic oil is supplied or
discharged from one site by means of a servovalve (MBX30AA101).
The piston is balanced, that is to say that it maintains its position when no current is given to the
servovalve.
The oil to the servovalve is filtered by fine filter MBX30AT001. If the delta P value across the filter
exceed the prefixed value, the alarm “Actuator MBX30AT001 hydraulic oil filter fouled” is
annunciated.
The actuator is equipped with a fail Safe servovalve MBX30AA351 with two solenoid valves
MBX30AA051 and MBX30AA052 to close the IGV in case of GT trip and also in case of failure of the
IGV positioner. Two pressure switches MBX30CP001 and MBX30CP002 detects the position of the
two solenoid valves listed above.
The IGV actuator is equipped with two linear position transmitters (MBA11AS001-B01/B02) and a
limit switch (MBA11AS001-S11) to detect the maximum operating position.
This limit switch is settled during the performance test.
Additionally, on the IGV/CV1 ring, two physical limit switches are given: MBA11CG001/
MBA11CG011, corresponding to maximum opening position and MBA11CG002/ MBA11CG012
corresponding to the minimum opening position. They represent the maximum allowable
mechanical movement of the IGV/CV1.
Page 1 of 2
HYDRAULIC OIL SYSTEM FOR IGV/CV1 DESCRIPTION TGO2-2011-E71005
14.10.16
Mobile Vane Actuator Actuator module Elements in the module
MBX30AA101 : Servo valve coil 1 &2
MBX30AA351 : Fail safe servo valve
MBX30AA051 : Solenoid valve
MBX30CP001 : pressure transducer on
solenoid valve AA051
IGV
MBX30AS002 MBX30AS001 MBX30AA052 : Solenoid valve
MBA11AS001
MBX30CP002 : pressure transducer on
solenoid valve AA052
MBX30AT001 : filter on supply line
MBX30CP003: Differential pressure filter
transducer
CV1
MBX40AS002 MBX40AS001 MBX40….all components as the précédent
MBA11AS002
Fig .1 Section of hydraulic actuator for IGV
Page 2 of 2
HYDRAULIC OIL SYSTEM FOR IGV/CV1 DESCRIPTION TGO2-2011-E71005
14.10.16
Measuring and supervisory
equipment
P&ID GAS TURBINE INSTRUMENTATION
In addition see

Page 1 of 1
P&ID GAS TURBINE INSTRUMENTATION TGO2-2600-E00000
13.11.2014
For Construction.
GAS TURBINE INSTRUMENTATION
This description is relevant to the gas turbine instrumentation .

Speed Measurement
The speed monitoring device consists of two 3-channel-type redundant systems. Speed transmitters
MBA10CS101/102/103 (logic 2 out of 3) has the purpose of control; MBA10CS104/105/106 (logic 2
out of 3) act directly on the overspeed protection trip .
GT trip is issued in case of 108% of overspeed reached (set point S.TURB.72).
The speed data are used for control, for speed-dependent switching operations, for under /
overfrequency protection (see Figure 1) and for indication.
SPEED
<S.TURB.70 <S.TURB.10 normal >S.TURB.68 >S.TURB.71 >S.TURB.72

< 47 Hz < 47.5 Hz speed >51.5 Hz > 52 Hz >54 Hz
(47,5÷
51,5)Hz
In case of In case of In case of

GENERATOR NOT ON
GT TRIP Load Rejection Load Rejection Load Rejection

NORMAL OPERATING RANGE
GT TRIP
active 5s >30s GT TRIP >30s GT TRIP >30s GT TRIP
(FSNL)
GRID
after grid Overspeed

disconnection No No No
ALLOWABLE
protection
Load Rejection Load Rejection Load Rejection
> 14s GT TRIP > 20s GT TRIP > 20s GT TRIP
Grid > 20s grid > 20s grid >0s grid

GENERATOR
GT TRIP
disconnection disconnection, disconnection, disconnection,
operation)
ON GRID
(Power
Overspeed
If still on grid for If still on grid for If still on grid for If still on grid for
protection
10s, GT TRIP 10s, GT TRIP 10s 10s,
GT TRIP GT TRIP
Page 1 of 6
GAS TURBINE INSTRUMENTATION TGO2-2601-E71002
04.04.18
Phase-Processor-Module (key phasor) MBA10CY101 /102
The K-phasors determinate the shaft circumferential position by evaluating the signals from the
amplifier of the corresponding sensors and supply the voltage.
Two key phasors MBA10CY101/102 are arranged and shifted by 72°. The rotating versus of the shaft
is indicated by the blu arrow.
As a rule the GT start occurs with the GT on the turning gear however GT start is possible also with
rotor at standstill. There is a remote possibility that, in this case, the shaft is started against its
rotanionary versus and in this cased the start up must be prevented. So at any command start given
to SFC it is monitored the time elapsing between signal from K-phasor MBA10CY101 (1) and
MBA10CY102 (2).
MBA10CY101 MBA10CY102
As a rule it must be : 1 < 2.

On the contrary, if 2 < 1, command OFF is given to the SFC and start up is stopped.
Absolute Vibration Measurement

The casing vibrations are monitored by transmitters MBD11CY101/102 (turbine), MBD12CY101/102
(compressor), MKD10CY101/102 and MKD20CY101/102(generator). The vibration values are
displayed and recorded.
A processor module calculates the effective vibration velocity from the signal; the effective vibration
velocity is then used by the I&C system as the output signal current. If at least in one measuring point
the first limit value Y.LAGER.M is exceeded an alarm is issued; in case the second limit value
Y.LAGER.S is exceeded the GT trip is issued.
For the generator the limit values are Y.LAGER.MG for alarm and Y.LAGER.SG for trip.
The main thrust load cells (MBD12CY115…118 and MBD12CY125…128) are for monitoring purpose
only.
Page 2 of 6
04.04.18
Relative Vibration Measurement
In addition to the absolute vibration monitoring, on each bearing are mounted two sensors which
measure the shaft vibration relative to the casing: MBD11CY111/112 for turbine bearing,
MBD12CY111/112 for compressor bearing, MKD10CY111/112 and MKD20CY111/112 for generator
bearings. These couple of signals are used to generate a first limit value for alarm and a second limit
value for trip.
If at least in one bearing the first limit value Y.WELLE.M is exceeded an alarm is issued; in case the
second limit value Y.WELLE.S is exceeded a GT shut down is initiated.
For the generator the limit values are Y.WELLE.MG for alarm and Y.WELLE.SG for shut down.
The above actions are only performed if the GT speed is in the allowable speed for continuous
operation.
Vibration Protection
Since for each bearing, two values for absolute vibration and one for relative vibration are provided,
the alarm for high vibration is issued when exceeding the above alarm limit value in a 2 out of 3 logic.
In the same way, the GT trip is issued in a 2 out of 3 logic when the trip limit values are exceeded.
Page 3 of 6
04.04.18
Bearing Measurement
The compressor end of the GT shaft is equipped with a journal and thrust bearings for both
directions. At the turbine end, the rotor is equipped with a journal bearing.
An insufficient supply of lube oil, overloading, excessive oil temperatures or foreign matter can all
damage these bearings. Bearing metal temperature is used to permit timely recognition of the threat
of damage. Bearing damage is indicated by elevated bearing temperature.
The metal temperature of the journal bearings are measured by triple thermocouples
MBD11CT101/102 (A/B/C) (turbine), MBD12CT101 (A/B/C) (compressor), MKD11CT101A/B/C and
MKD21CT101A/B/C (generator). The compressor thrust bearing is equipped by 8 double
thermocouples MBD12CT102,103,112,113 on the main side and MBD12CT104/105/114/115 on the
secondary side. The temperatures are displayed. For each bearing, if the temperature exceeds the
first limit value (2 out of 3 logic made by the triple thermoelement), an alarm is issued; when
exceeding a second limit value the GT trip is initiated.
The limit values for alarm are:
 T.LAGER.M for the compressor
 T.LAGER.M01 for the turbine
 T.LAGER.MG for the generator.
The limit values for trip are:
 T.LAGER.S for compressor and turbine
 T.LAGER.SG for the generator.
NOTE: For the thrust bearing the 2 v 3 logic is carried out with 4 channels of the thermocouples of
the same side and the 4th element is not used but considered as a reserve.
Moreover load on the main and secondary compressor thrust bearings is monitored by thrust load
cells MBD12CY125..128 and MBD12CY115…118
Compressor Inlet Air Temperature

Resistance thermometers MBA11CT101/102/103/104 measure the air temperature upstream
compressor which is used for calculating the corrected exhaust gas temperature (TETC) required for
temperature control and for turbine temperature protection (see section TGO2-0114).
Page 4 of 6
04.04.18
Compressor Inlet Pressure
Pressure transducers MBA11CP101/102 measure the pressure in the compressor intake duct. The
pressure measurement combined with the compressor inlet air temperature can be used to
determine the compressor mass flow (for display purpose only). In addition it is used to calculate the
compressor pressure ratio. Moreover the differential pressure MBA11CP103 monitors total pressure
drop between ambient air and compressor inlet.
Compressor Surge Detection

The pressure drop between the intake duct and the compressor inlet (immediately upstream of the
variable inlet guide vane row) is measured by 3 differential pressure switches MBA11CP001/002/003
(logic 2 out of 3).
Instabilities in the compressor are quickly detected by the changing in the differential pressure.
When the differential pressure falls below the switching point of the switches (2 out of 3 logic), a GT
trip is initiated.
The compressor surge detection is activated when the turbine speed rises above speed S.TURB.15, in
order to avoid faulty intervention during the start up phase.
In case of surge detection, please refer to section TGO4-1600.
Compressor Discharge Pressure and Temperature

Pressure transducers MBA12CP101/102/103 are used to measure the pressure discharge pressure.
This is used for display purpose and, combined with the signal from MBA11CP101, to calculate the
compressor pressure ratio which is used in the “Compressor pressure ratio controller” (see section
TGO3-0055).
The thermocouples MBA12CT101/102/103 measure the compressor discharge temperature for
display and data acquisition.
Drain valve MBA12AA401 can be opened briefly after turbine shut-down to drain the pressure
sensing line. Valve must be closed after draining.
Page 5 of 6
04.04.18
Adjustment of the Compressor Inlet Guide Vanes
The flow of air through the gas turbine is controlled by adjusting the angle of the compressor inlet
guide vanes MBA11AS001 (stationary blade row 0) and of the first compressor stage vanes
MBA11AS002. When the IGV and CV1 are fully "opened", the air flow through the gas turbine
increases, when they are "closed" it decreases.
On the IGV/CV1 ring, two physical limit switches are given: MBA11CG001/MBA11CG011,
corresponding to maximum opening position and MBA11CG002/MBA11CG012 corresponding to the
minimum opening position. They represent the maximum allowable mechanical movement of the
IGV/CV1. The IGV and CV1 are described in section TGO2-0340, actuator is described in section
TGO2-2011.
Turbine Outlet Temperature
Exhaust temperature is measured immediately downstream of the turbine using 24 triple-element
thermocouples (MBA26CT101A/B/C to MBA26CT124A/B/C) distributed around the circumference of
the exhaust diffuser.
All “B” and “C” channels from the 24 thermocouples are used for control and protection purpose,
while “A” channel are spare.
See section “Exhaust gas temperature control” TGO3-0100 and “Exhaust gas temperature
protection” TGO3-0110.
Intermediate shaft interlock (only in case of multi-shaft configuration)

In order to avoid injury to personnel due to the shaft rotation when the gas turbine is running, on the
intermediate shaft between the gas turbine and generator enclosure there is a cover protection with
three Closed limit-switch MBA10CG001/002/003.
When the cover protection is open a interlock logic is activated to inhibit the machine start up, this to
avoid to have the shaft running while the cover is open.
Shaft position monitoring

Two linear measuring transducers MBA10CG101 / 102 are mounted on the compressor bearing cover
to measure the axial position of the rotor shaft and the shifting caused by the RDS system (for more
information see TGO2-6001).
Page 6 of 6
04.04.18
P&ID COMBUSTION CHAMBER INSTRUMENTATION
In addition see

Page 1 of 1
P&ID COMBUSTION CHAMBER INSTRUMENTATION TGO2-2602-E00000
13.11.14
For Construction.
COMBUSTION CHAMBER INSTRUMENTATION
This description concerns the combustion chamber instrumentation .
Pressure Drop (∆P) across the Combustion Chamber

The differential pressure across the combustion chamber (∆pCC ) is measured by differential pressure
transducer MBM10CP101. This is an indication of the air mass flow thought the combustion chamber
and the burners.
In case of wear phenomena or unbalancing in the cooling air flow, a lower air mass flow enters the
combustion chamber, and ∆pCC decreases.
Since the absolute value of the ∆pCC is not significant since the air flow through the combustion
chamber depends on compressor air flow, the ∆pCC value shall be compared to the actual compressor
delivery pressure pCII (absolute pressure) by pressure transducer MBA12CP101. This measuring point
is shown in “Gas Turbine Instrumentation” (TGO2 - 2601, in the sketch “GT diagram”).
Signals from these instruments are used to calculate the relative combustion chamber pressure drop
(in percent):
∆pCC rel = (∆pCC /pCII) * 100%
In case ∆pCC rel < PP.BK.01 for more than 5 sec and turbine speed is > di S.TURB.70, the alarm
“RELATIVE COMBUSTION CHAMBER PRESSURE DROP <MIN” is annunciated.
The ∆pCC is displayed for monitoring purpose.
The ∆pCC rel value is monitored during the combustion parameter setting by expert personnel on gas
turbine by Ansaldo Energia during the commissioning phase and/or re-commissioning after major
inspection.
Flame Monitoring
Fuel must never be fed into the gas turbine combustion chamber for an impermissibly long period
without combustion taking place. The purpose of flame monitoring is to determine whether the main
fuel is in fact burning in the combustion chamber, i.e., whether a flame is present.
Flame detectors are mounted on the combustion chamber for this purpose, their signals are
processed in the respective evaluation units (generation of limits). These limits are used by the
downcircuit interlock logic for actuating the fuel shutoff valves.
Flame monitoring employs two flame detectors MBM13CR101/102 located somewhat offset from
one another on the circumference of the combustion chamber. See section TGO2-4380 for flame
detectors description.
In case flame intensity is higher than a fixed threshold, the signal FLAME ON is generated.
In case flame intensity is lower than a fixed threshold, the signal FLAME OFF is generated.
Page 1 of 3
COMBUSTION CHAMBER INSTRUMENTATION TGO2-2603-E70003
19.10.16
Since it is the flame intensity that closes the contact, in case one flame detector detects “flame on”,
the flame is surely present. Therefore fort the gas turbine safety only one flame detector could be
sufficient. The second one is used only to increase the gas turbine reliability.
Operational Functions
If one flame detectors signals ‘Flame OFF’, an alarm is issued; If both flame detectors signal ‘Flame
OFF’, a turbine trip is initiated.
Ignition transformers
Flames are electrically ignited. Each burner is equipped by two ignition electrodes ending at the end
of the pilot gas burners. The ignition transformers (from MBM12GT001 to MBM12GT024) give the
necessary voltage to ignite the spark plugs of each burners. The voltage causes an electric arc
between the two electrodes.
Monitoring of the Combustion Chamber, Acceleration and Humming

Combustion instability is manifested in gas turbines by increased combustion chamber pressure
fluctuation amplitudes, also known as humming, and combustion chamber accelerations.
Humming and high acceleration levels must be promptly detected and suppressed to prevent
damage to the gas turbine. This is achieved by:
• Power output reduction

• Triggering of trip.
Humming is detected by measuring the amplitudes of combustion chamber pressure fluctuations
using the two dynamic pressure sensors MBM11CP101 and MBM11CP102.
Acceleration is detected using piezoelectric sensors MBM10CY101/102/103 mounted on the
combustion chamber.
Page 2 of 3
19.10.16
- Humming monitoring :
Humming is detected by measuring the pressure amplitude in the combustion chamber by means of
the two pressure dynamic transducers MBM11CP101 and MBM11CP102.
Humming values are only displayed for monitoring purpose and not used by the protection logics of
the gas turbine.
In addition, other three dynamic pressure transducers are installed at burners 7, 10 and 15
(MBM12CP107/110/115 are shown on the table in the sketch “Combustion chamber”).
Humming levels give additional information to the commissioning people during the tuning phase of
the combustion process and they can be correctly evaluated only by skilled personnel of Ansaldo
Energia.
- Acceleration monitoring:
The values of combustion chamber accelerations are continuously monitored to avoid damages on
the combustion chamber ceramic tiles by means of piezoelectric sensors MBM10CY101/102/103
arranged on the outer shell of the combustion chamber.
The following actions are carried out:
A) Violation of limit S.ACC.01 for a time longer than K.ACC.01 causes a load reduction of
E.LEIST.32. The load reduction is repeated every K.BRUMM.05 time until the acceleration
level returns below S.ACC.01, if the accelerations exceed the above value for a time longer
than K.BRUMM.03 (ex. 15s) a GT trip is carried out.
B) Violation of a second limit value S.ACC.02 after the time K.ACC.02 causes a load reduction of
E.LEIST.33, if the accelerations don’t fall under the above value within the time K.BRUMM.04
a GT trip is issued.
C) In any case, violation of an higher limit value S.ACC.03 (e.g. 8.0 g) causes immediately a GT
trip.
D) In addition a fourth acceleration threshold is implemented at the value S.ACC.07 with the
aim of a fast combustion chamber acceleration detection. This protection is active only when
IGV position is above 95% and in case is the above threshold is exceeded for a time longer
than K.ACC.09 a load reduction of E.LEIST.32 is issued.
The above monitoring criteria are not active during GT run up, the release is issued when the speed
S.TURB.70 is exceeded
Countermeasures to be taken in case of acceleration phenomena are described in section TGO4-

1700.
Page 3 of 3
19.10.16
SPEED MEASUREMENT
The speed of the gas turbine is monitored by six speed sensors required for:
§ speed measurement and recording
§ overspeed protection
§ gas turbine control
§ under / over frequency protection.
In addition, according to the configuration, three additions probes dedicated to the external
overspeed device can be provided, see section TGO2-2601.
Refer to figure 1. The intermediate shaft (1) is machined with grooves (2) where the speed sensors
(3) are located.
The speed measuring equipment is fitted in the area of the compressor bearing. The speed sensors
MBA10CS101 to MBA10CS106 are supported by the lower half of the bearing seal ring (not shown in
the figure). The speed sensors are supplied with the required auxiliary voltage by a junction box.
Plug connectors ensure that the speed sensors can be easily replaced when necessary.
When the intermediate shaft rotates, the magnetic field due to the machined surface changes and it
is detected by the speed sensors which issue pulse signals. Turbine speed is calculated on the basis of
the time intervals between the pulses and the number of pulses.
In addition see:
Gas Turbine Instrumentation TGO2-2601

Measuring Instruments Compressor Bearing TGO2-2750
Page 1 of 2
SPEED MEASUREMENT TGO2-2660-E00000
14.11.2014
2
1. Intermediate shaft 1
2. Grooves
3. Speed sensors
Figure 1: schematic view on the speed sensor positioning
Page 2 of 2
SPEED MEASUREMENT TGO2-2660-E00000
14.11.2014
TEMPERATURE MEASURING POINTS AT GAS TURBINE
In addition refer to section TGO2-2602.
§ Temperature measuring point at compressor inlet

See in figure 1 the location of the temperature measurement at compressor inlet (MBA11CT101
…104). In the figure, limit switches for IGV position are also reported (MBA11CG001/002).
Figure 1: view from the compressor inlet
Page 1 of 3
TEMPERATURE MEASURING POINT AT GAS TURBINE TGO2-2700-E72000
14.11.14
§ Temperature measuring point at compressor outlet
See in figure 2 the location of the temperature measurement at compressor outlet (MBA12CT101
…103).
Figure 2: view from the compressor outlet
Page 2 of 3
14.11.14
§ Temperature measuring point at turbine outlet
See in figure 3 the location of the 24 thermocouples at turbine outlet (MBA26CT101 …124).
1 = MBA26CT101
……..
24 = MBA26CT124
Figure 3 : view from turbine outlet
Page 3 of 3
14.11.14
Measuring Instrument, Compressor Bearing
In addition refer to sections TGO1-0500 and TGO2-2601.
§ Compressor bearing temperature

See in figure 1 the location of the temperature measurement for compressor bearings:
MBD12CT101 for bearing metal temperature measurement, MBD12CT102 … 105 and
MBD12CT112…115 for thrust bearing temperature monitoring.
Figure 1: temperature measurement points at compressor bearing
Page 1 of 2
COMPRESSOR BEARING MEASURING INSTRUMENT TGO2-2750-E72000
22.02.17
§ Speed sensors and vibration measurements
In figure 1 the main thrust load cells (MBD12CY115…118 and MBD12CY125…128).

Figure 2 shows the location of the speed sensors (MBA10CS101 …106) and the probe for
relative vibration (shaft vibration) measurement (MBD12CY111/112).
Absolute vibration sensors are located as shown on figure 3 for casing vibration monitoring
(MBD12CY101/102).
Figure 2: location of speed and relative

vibration sensors
Figure 3: location of absolute vibration sensors
Page 2 of 2
COMPRESSOR BEARING MEASURING INSTRUMENT TGO2-2750-E72000
22.02.17
Measuring Instrument, Turbine Bearing
In addition refer to section TGO2-2602.
§ Turbine bearing temperature
See in figure 1 the location of the temperature measurement for temperature bearings:
MBD11CT101/102 for bearing metal temperature measurement.
Figure 1: temperature measurement points at turbine bearing
Page 1 of 3
TURBINE BEARING MEASURING INSTRUMENT TGO2-2800-E72000
14.11.14
§ Turbine vibration monitoring
Figure 2 shows the location of the probe for relative vibration (shaft vibration) measurement
(MBD11CY111/112) and figure 5 shows a picture of the same on the assembled machine.
Absolute vibration sensors are located as shown on figure 3 for casing vibration monitoring
(MBD11CY101/102).
Figurer 4 shows the route of all the turbine bearing instrument outside the measuring region.
Figure 2: location of speed and

relative vibration sensors
Figure 4: route for instrument of

turbine bearing measurement
Figure 3: location of absolute vibration sensors
Page 2 of 3
14.11.14
Figure 4: probe for relative vibration, turbine bearing
Page 3 of 3
14.11.14
Fuel Supply System
P&ID FUEL GAS SYSTEM
In addition see

Page 1 of 1
P&ID FUEL GAS SYSTEM TGO2-3000-E00000
14.11.14
FUEL GAS SYSTEM
Function
The fuel gas system controls the fuel gas mass flow into the GT combustion chamber and also blocks
the flow of gas to the gas turbine under certain conditions. The flow of fuel gas to the gas turbine is
cut off by rapid and tight-closing shutoff valves .
The function of the most important components of the fuel gas system are described in the sections
below.
Fuel Gas Supply

A fuel gas supply system must be provided upstream of the fuel gas system to ensure that fuel gas is
available in the quantity required by prevailing conditions. Dry, clean fuel gas must be supplied to the
fuel gas system to prevent corrosion, erosion, and the formation of deposits on the system
components. The pressure of the fuel gas at the fuel gas system inlet must be relatively constant
regardless of the rate at which it is supplied. Fuel gas pressure is dependent on the composition of
the fuel gas and is listed as P.GAS.01 in the "Set point List” section TGO1-0530.
The requisite fine filtering and pressure control system are not part of this system and are therefore
not described here in greater detail.
Strainer MBP11AT001 is provided to prevent the ingress of any coarse foreign matter which may be
located In the piping between the fine filter unit and the strainer into the natural gas emergency stop
valve. In the event of a fault, foreign solids could prevent the emergency stop valve from closing
properly.
Downstream the strainer, the line is equipped with a flange 16A for inertisation purpose before a
system maintenance or a long standstill period.
Fuel gas lock and vent system functional principle

Due to safety rules, a FUEL GAS LOCK is required in the fuel gas system in order to ensure safe
isolation, during system standstill, between fuel supply system and combustion chamber.
The GAS LOCK must consist of a gas-proof double isolation with fail safe closing.
The double isolation function is carried out by a first valve (Emergency Stop Valve) FG.ESV
MBP13AA051 and a second one (control valves with stop and control function (PILOT 2 control valve
MBP24AA151 and premix control valve MBP22AA151).
Between the first and the second isolation valves, a depressurizing device ( pressure relief Vent Valve
MBP13AA501) is implemented; it is OPEN when the isolations are closed and viceversa. This
equalizes any pressure difference in the piping system between the isolating devices.
In the event of a leakage in the first shutoff valve, pressure cannot build up upstream of the fuel gas
control valves because the gas leakage is routed via the venting line to a location which is not critical
and then released to the atmosphere. This prevents undesired flows of fuel gas from entering the
combustion chamber, and also prevents combustion gases or compressor discharge air from
penetrating into the fuel gas supply system.
Page 1 of 7
NATURAL GAS SYSTEM, DESCRIPTION TGO2-3001-E70006
18.11.16
The FUEL GAS LOCK must be integrated into the natural gas system so that in closed state, neither
any gas can pass from the natural gas supply to the firing equipment nor any medium (hot
combustion air or exhaust gas from the combustion chamber) can pass from the firing equipment to
the natural gas supply.
Fuel Gas Pressure Relief Valve

The fuel gas pressure relief vent valve MBP13AA501 is part of the vented gas seal and permits
depressurization of the associated piping sections between the first and second shutoff valves in the
event of an outage of the fuel gas system.
This valve is solenoid (single coil) which is open in currentless state. The vent valve is equipped with 2
limit switches for detecting the close position.
NOTE: The release to open the vent valve is given when the FG-ESV, the premix- and pilot gas control valves
have the CLOSED feedback signals.
NOTE: A faulty position on FG vent valve after the GT start up (i.e. open) has no effect on the GT
operation. The fuel gas which is lost through the opened vent valves is led to roof and it causes only
an increased pressure difference across the stop valves. The fuel gas mass flow lost through the
opened vent valve is negligible and it does not affect gas turbine operation. It causes mainly a fault in
the position nominal value.
Fuel Gas Emergency Stop Valve (First Shutoff Valve)

Fuel gas emergency stop valve MPB13AA051 (FG ESV) is a rapid-closing, fail-safe and leak-tight
shutoff valve.
Its function is to enable or disenable the flow of fuel gas to the burners on startup and shutdown of
the gas turbine, as well as during startup or shutdown of the fuel gas system. It is also closed in the
event of faults which require the immediate cut off of the supply of fuel gas to the gas turbine. The
FG ESV is opened hydraulically and closed very rapidly by a spring force (in less than 1 second). The
hydraulic actuator mechanism is described in "Hydraulic Oil System for Fuel Gas Actuator".
Fuel Gas Control valves (Second Shutoff Valve)

Fuel gas system is equipped with two control valves, precisely, the fuel gas premix control valve
MBP22AA151 and the pilot 2 control valve MBP24AA151. These valves constitutes the second
shutoff of the fuel gas lock and vent system. All these valves are fail-safe, which means that the
valves close automatically in the event of the loss of opening energy. As with the emergency stop
valve, this is realized by means of a spring which is compressed when the valve is opened. When the
opening force is no longer applied, the compressed spring is released and closes the valve.
NOTE: Additionally, for any further use may be needed, a spare line with a pilot control valve
MBP23AA151 could be provided; it is optional, depending on the project. It could be used as an
additional fuel gas line only during certain conditions as well as in case of transient phases which
require more stabilization e.g. start up.
The position of the fuel gas control valves is hydraulically actuated, the functioning of these devices is
explained in the section ‘hydraulic oil for actuators’.
Page 2 of 7
18.11.16
Gas Lines to the Fuel Gas Burners
Downstream of the fuel gas emergency stop valve, the fuel gas supply line is split into the premix and
pilot 2 gas branches (pilot is spare, reserve for further needs). The control valves are located on the
fuel gas package just downstream of this split. Downstream of the fuel gas package, each of the two
separate gas lines empties into a corresponding ring line. Branch lines lead from these ring lines to
the individual burners.
When a gas line in not operated, it is slowly filled with compressor discharge air. To prevent the
formation of condensation, that section of each of the three fuel gas lines between the fuel gas
package and the GT ring line is equipped at its lowest point with an electric trace heater. The trace
heater (MBP32/34AH001 and MBP33AH001 in case of pilot line presence) is in operation whenever
there is no gas flowing through the corresponding gas tine. This prevents the accumulation of
condensation in the three fuel gas lines.
Fuel Gas Pressure Monitoring

The amount of fuel gas burned in the combustion chamber of the GT is a function of the supply
pressure of the gas, the lift of the fuel gas control valves and the combustion chamber pressure. Fuel
gas pressure is measured upstream of the FG ESV by pressure transducers MBP13CP101 and
MBP13CP102, and downstream of the FG ESV by pressure transducer MBP14CP101.
To ensure reliable operation of the, fuel gas pressure is checked for violation of prescribed
maximum and minimum limits. In the following are described the actions carried out .
• The contractual value of the pressure is indicated by the parameter P.GAS.01 reported in
the Set point list
• An alarm for low fuel gas pressure is emitted if the limit P.GAS.06 is exceeded in logic 2V3
(the set point on the pressure transducer MBP14CP101 is reduced of 0.5 bar)
• A trip of the machine is issued if in logic 2V3 the set points P.GAS.17 on the
MBP13CP101/102 transducers and P.GAS.07 on the MBP14CP101 transducers are
violated
• An alarm for high fuel gas pressure is emitted if the limit P.GAS.11 is exceeded.
NOTE: No action has to be carried out in case of an increasing of the fuel gas pressure, in fact in this
case is possible to exert a control action closing the control valves, furthermore the gas turbine is
protected from an excess of fuel by other circuits (in example exhaust gas temperature protection)
Page 3 of 7
18.11.16
OPERATION
The sequence in which items of the fuel gas system equipment are operated or actuated during
startup, operation and shutdown is described below.
Steady-State Operation Modes
Standstill
The vented gas seal is closed during standstills, therefore the FG ESV MBP13AA051, the fuel pilot 2
control valve MBP24AA151, the fuel gas premix control valve MBP22AA151 are closed and the
pressure relief valve MBP13AA501 is opened.
Fuel Operation- General

The gas turbine start up with fuel gas occurs by means of the pilot2 gas burners. In the last phase of
the run up the premix burners is activated.
The load range from the nominal speed up to the base load is covered by the premix mode in which
both the premix and pilot 2 gas burners are in function and the fuel is modulated respectively by the
MBP22/24AA151 control valves.
The pilot flames are necessary to stabilize the premix main flames by means of a less premixed
flame.
Startup
The following switching operations are performed in the fuel gas system after the gas turbine has
received a start command, all systems which are not part of this description have been prepared for
startup of the gas turbine and all prerequisites for enabling the system have been fulfilled:
The vent valve MBP13AA501 is closed.
The static frequency converter (SFC) is switched on, causing the GT to be continually accelerated The
pilot 2 control valve is positioned for the fuel gas mass flow F.EGDB.01 (start position for fuel pilot
gas control valve). This establishes the proper flow of fuel gas for subsequent ignition.
When the gas turbine has been accelerated up to ignition speed S TURB.09, the FG ESV opens and
the ignition transformers are supplied with high voltage. Fuel gas flowing to the pilot 2 burners, is
ignited by spark electrodes downstream of the burners.
Page 4 of 7
18.11.16
The ignition transformers are shut down 20 seconds after the "Open" command has been issued to
the fuel gas ESV. If the flame detectors do not detect a flame approximately 12 seconds after the FG-
ESV has been opened, the start is aborted by closing the FG ESV.
After a successful start, the pilot 2 control valve begins to open in accordance with linear timing
function "gradient" JK.EGDB.01 when speed value S.TURB.53 is exceeded. When the reaches the
value S.TURB.54 the gradient of fuel gas increasing, is increased to the value JK.EGDB.02. During this
phase the torque of the gas turbine is increasing but is not enough itself to accelerate the machine,
therefore the start up converter is still switched on.
When the speed S.TURB.157 is reached, also the premix gas is added by opening the premix valve
according to the set point F.EGVB.01; the pilot gas valve is closed to compensate this amount of fuel.
When the speed S.TURB.541 is reached a third gradient is selected (JK.EGDB.05) for the pilot gas flow
in order to increase the fuel flow to the combustion chamber for further acceleration.
Once the turbine generator has been accelerated to a speed of S.TURB.03 i.e. the turbine has
reached its critical startup speed, the SFC is switched off.
Shortly before reaching rated speed S.TURB.00 (50 Hz), the speed controller assumes control of the
fuel pilot gas control valve from the run up function.
When the last blow off is closed and after a certain delay the change over to premix mode is
released: as a consequence, the premix control valve is regulated according to the GT controller
(speed controller, load controller ecc. in the logic of the low value gate) while the pilot 2 control
valve is regulated according to its mass flow set point depending on the GT operating condition
conditions (TETC, IGV) and on the ambient conditions (TVI, PCI).
Now the machine is in premix mode ready to be synchronized; the premix mode is maintained for all
the operation conditions.
Load operation
During the load operation the gas turbine is controlled by the load or the TETC controller, whose
action is exerted on the premix gas control valve, instead the pilot flow set point is regulated by the
TETC and the position of the IGV; an appropriate amount of pilot gas is supplied to stabilize the
premix flames.
Shutdown
The shut down is defined as the operation of load reduction down to the opening of the generator
breaker, which takes place at a very low load then the fuel gas emergency valve and the control
valves are closed while the vent valve is opened, then the speed is reduced and the turning gear
system is activated when the turning speed is reached.
Page 5 of 7
18.11.16
Fault Management
The following describes how faults which may occur during operation can be managed and the
switching operations which take place in the fuel gas system during such faults.
Load Rejection
If the gas turbine is disconnected from the grid during power operation by opening the generator
breaker, the mechanical power consumed by the generator suddenly becomes zero. The power of
the turbine then accelerates the turbine-generator. One characteristic of load rejection is that the GT
controller switches from load control to speed control. The overspeed resulting from the sudden
reduction in power transfer must be corrected as soon as possible. In such cases control intervention
must be sufficiently prompt to prevent triggering of overspeed trip so that the gas turbine can be
quickly resynchronized with the grid.
After the opening of the breaker the premix control valve is closed to the minimum position, function
of IGV position which allows the passage of premix mass flow to have a stable flame; contemporarily
the pilot 2 gas control valve is opened to sustain the flames, the set point of pilot gas flow during the
load rejection is function of the position of the IGV.
After a certain time the total amount of gas supplied to the burners is lower than the necessary to
maintain the gas turbine at nominal speed, as result the speed decreases, when nominal speed is
newly attained the speed controller may control the speed by opening the premix control valve.
At this point the machine is again ready for the synchronization
Initiation of Trip
A gas turbine trip is commanded in case that the operational conditions lead to a dangerous point for
the machine (example over temperature, surge etc) . In this case the fuel gas emergency stop valve
and all the control valves receive a CLOSE command and the vent valve is then opened.
Now the fuel gas system is locked and the vent is opened.
Fuel Changeover
Fuel changeover is made between natural gas premix mode and dry fuel oil diffusion mode and vice
versa. The permissible window range is defined by IGV position which must be > G.VLE0.38 and <
G.VLE0.39 (e.g. IGV position higher than 10% and lower than 70%). If the gas turbine is not running
in the permissible load window, load must be increased or decreased manually or by unit
coordination control before fuel changeover is made.
From Gas to Oil
During fuel gas operation, if ‘Fuel Oil Operation” is selected at the local control console or in the
control room or in case of decreasing fuel gas pressure below the limit value P.GAS.03 for more than
K.GAS.01 time, the fuel change over is initiated.
Page 6 of 7
18.11.16
The connection of fuel oil in fuel gas operation is described in the Fuel Oil system description, see
section TGO2-3005.
During the fuel change over process the load set point is blocked.
After the fuel oil connection, when the GT is temporary operating in dual fuel mode, the fuel
controller moves the fuel proportion from 100% gas to 100% oil.
When the fuel gas premix control valve has reached the position corresponding to the disconnecting
mass flow F.EGVB.26, the fuel gas system is disconnected by closing all the stop valves in the fuel gas
system. Also all the fuel gas control valves are closed as well. The vent valves are opened.
When the GT is in fuel oil operation, the load set point is released.
From Oil to Gas

To make the changeover from operation on fuel oil to natural gas, the gas turbine must first be
operated in fuel oil diffusion mode. Once the gas turbine is running in diffusion mode on fuel oil in
the requisite output window, the machine can be automatically changed over to natural gas premix
mode.
During fuel oil operation, if ‘Fuel Gas Operation” is selected at the local control console or in the
control room, the gas turbine is first switched to dual-fuel mode and then the fuel oil system is
disconnected.
Fuel change over is initiated only if the fuel gas pressure is above P.GAS.03.
The fuel gas system is activated: the vent valves are closed, the fuel gas premix control valve is set to
the position corresponding to the connection mass flow F.EGVB.26. The pilot 2 control valve is
positioned as well and the fuel gas stop valves are then opened.
Once the fuel gas stop valves are opened, the GT is temporary operating in dual fuel mode, the fuel
controller moves the fuel proportion from 100% oil to 100% gas.
When the fuel oil system reaches the minimum quantity for disconnection F.HOEDB.33, the fuel oil
system is excluded (see section TGO2-3005) and from now on the GT is running in fuel gas premix
mode.
The load set point is now released.
Page 7 of 7
18.11.16
P&ID FUEL OIL SYSTEM
In addition see

Page 1 of 1
P&ID FUEL OIL SYSTEM TGO2-3004-E00000
14.11.2014
FUEL OIL SYSTEM
Function
The fuel oil system supplies the burners with fuel oil and controls the volume of fuel injected into the
combustion chamber. On shutdown, it ensures that the flow of fuel oil is quickly and reliably shut off.
Supply of fuel oil to the system must meet various requirements, i.e. the fuel oil must have a certain
pressure, temperature, and mass flow rate and be of a precisely defined quality. Refer to section
TGO2-0160.
The forwarding system and any treatment system required for the specific project are not part of the
gas turbine scope and, if present, they are described elsewhere.
The fuel oil system branches downstream of the injection pump to form 2 subsystems, one for each
of the two operating modes diffusion and premix (DO and PO). The diffusion system comprises a
supply line and return line since, for technical reasons, only a portion of the oil supplied to the DO
burners is actually injected into the combustion chambers. The premix system has only a supply line,
i.e. all of the oil entering the PO burners is also injected into the combustion chambers.
Startup and shutdown of the GT on oil is always performed in diffusion mode. The premix system is
inactive during operation in diffusion mode. Diffusion mode is possible from the start up to about
70% of GT power output.
In the upper output range, pollutant emissions and thermal stresses on materials are significantly
lower in premix mode than in diffusion mode. At low output in premix mode, there is a marked
increase in CO emissions (unfavorable fuel-air ratio) and the flames become unstable. Premix mode
is therefore only permissible in the upper output range (above appr. 41% of rated power). In premix
mode, the diffusion burners are used to produce small pilot flames that are required to stabilize the
premix flames. This means that both subsystems are active in premix mode.
A large portion of this equipment, including the fuel oil filters, injection pump, as well as the
emergency stop valves and control valves, are compactly arranged on the fuel oil package.
The fuel oil system is designed as leak-tight as possible. Whenever possible and appropriate, the
main components of the fuel oil system are described in the following in the order in which the fuel
oil passes through them.
Note: for all set points here mentioned and generated by transducers, refer to the Set Point List in
section TGO1-0530.
Page 1 of 14
FUEL OIL SYSTEM TGO2-3005-E70002
23.02.18
Components in the Supply Line
Venting
A venting line is connected at the highest point of the fuel oil line upstream of the duplex filters
(MBN11AT001 and MBN11AT002). Any air which may have collected during standstill to form large
bubbles is fed into the auxiliary return line via orifice MBN11BP001. An additional venting device is
located in the upper portion of the filter. Any air present as small bubbles in the flowing fuel oil and
which can pass into the filter (through which the oil slowly flows) is discharged by way of this vent
and likewise fed into the auxiliary return line via orifice MBN11BP002. Shutoff valves MBN11AA501
and MBN11AA502 in the filter vent lines are always open during operation of the GT. Sight glass
MBN11CF501 is installed in the vent line downstream of the two orifices.
Filter
The fuel oil filter (MBN11AT001 and MBN11AT002) removes all matter from the fuel oil that could
damage downstream components such as the injection pump, fuel oil nozzles and turbine blading.
Since these filters have a very fine mesh, normally a filtering system is included in the forwarding
system (which is not part of this description) to avoid frequent changeover of the fuel oil filter for
cleaning.
This filter is a duplex filter. If the pressure drop due to fouling exceeds a certain level, an alarm is
annunciated on local display MBN11CP501 of differential pressure switch MBN11CP001, after which
changeover to the other filter element must be made manually. It is absolutely imperative to ensure
that this filter has already been filled with fuel oil using valve MBN11AA252. After draining a
sufficient volume of oil via the respective valve, MBN11AA401 or MBN11AA402, the fouled filter
cartridge can be removed from the filter housing and cleaned. Then the filter housing itself must be
cleaned prior to reinsertion of the clean filter cartridge.
Bladder Accumulator for Damping Pressure Surges
Opening the emergency stop valves, starting up and shutting down the injection pump but in
particular rapid closing of the emergency stop valves induces sudden flow velocity changes in the fuel
oil lines that can cause pressure surges of considerable amplitude. Bladder accumulators
MBN11BB001 and MBN11BB002 dampen these pressure peaks.
Page 2 of 14
23.02.18
Injection Pump
The injection pump MBN12AP001 boost fuel oil pressure to the level required for atomization in the
burners. These pump is centrifugal type.
The pump has upstream / downstream manual isolating valves (MBN12AA402 / 403) to be used for
isolating the pump for maintenance activity.
If at least two of the pressure switches MBN12CP101, MBN12CP102, MBN12CP103 signal that
pressure upstream of the pump is too low, pump startup is prevented or, if in operation, it is
switched off, to prevent cavitation due to low intake pressure. In addition the pressure upstream of
the pump can be read on pressure gauge MBN12CP501; pressure gauge MBN12CP502 indicates the
pressure downstream of the pump.
Bearing temperature of the pump is monitored by MBN12CT101 / 102 as well as the temperature of
the electric motor by MBN12CT105 to …110. All instruments are dual-element and in case both
elements of any one of these temperature measuring points register excessive temperature, the
pump is shut down.
Measurement of Pump Discharge Pressure
Pump discharge pressure is determined using pressure transducers MBN13CP101, MBN13CP102, and
MBN13CP103. This pressure is required for various open- and closed-loop control functions.
Minimum-flow Orifice and Shutoff Ball Valve in the Bypass Line
When the injection pump MBN12AP001 is running and ESVs MBN14AA051 and MBN23AA051 have
closed, the valve MBN12AA051 in the bypass line is opened by spring force to direct the flow into the
auxiliary return line.
Safety valve
Safety valve MBN12AA191 prevents pressure downstream of the injection pump from reaching
impermissible levels due to several faults (i.e. high density fuel oil is used, or if pump speed becomes
excessive).
Page 3 of 14
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Diffusion System Components
Diffusion Supply Line Emergency Stop Valve
Fuel oil diffusion supply line emergency stop valve MBN14AA051 is used to enable or disenable the
flow of fuel oil to the diffusion burners during startup and shutdown, and during changeover from
fuel oil to natural gas operation and vice versa. It is also closed in the event of faults requiring
immediate turbine shutdown (GT trip).
Diffusion Supply Line Control Valve
Diffusion supply line control valve MBN14AA151 has two functions. As a control valve, it regulates
the amount of oil supplied to the diffusion burners. This valve also has an emergency stop function,
i.e. when trip is triggered it is closed very rapidly and reliably by spring force, as is the diffusion
supply line emergency stop valve.
Downstream diffusion control valve, the diffusion supply line is equipped with the thermocouple
MBN17TC101 and the flowmeter MBN17CF101 with monitoring purpose.
Permanent-element Fuel Oil Filter (DO)
Despite filtering of the FO, isolated instances of contamination may occur, particularly after lengthy
outages of the FO system. To protect the FO burners against impermissible soiling, permanent-
element, fine- mesh filter MBN31AT001 is installed upstream of the fuel oil diffusion ring line.
GT shutdown is initiated if the differential pressure at filter MBN31AT001 exceeds the setting of
pressure transducers MBN31CP101/102/103 (2vs3 logic).
Fuel Oil Lines to the Combustion Chamber (DO)
Fuel oil from the DO supply line is distributed to the 24 burners via a ring line mounted directly on
the combustion chamber.
In addition to the diffusion burner supply line, the seal air line fitted seal air ball valve MBN34AA001
is also connected to the ring line. The seal air ball valve opens after the diffusion system is shut down
and purging is completed. During operation on natural gas, air from the gas turbine compressor
outlet is fed into the ring line so that air flows through the FO diffusion burners, preventing hot
combustion gasses from the combustion chamber from entering the FO diffusion system. To prevent
coking due to any fuel oil residue that may remain entrapped in the fuel oil burner, the fuel oil
burner is flushed by seal air taken from the compressor outlet via the sealing air ball valve
MBN34AA001. This sealing air also passes through orifice MBN36BP001 into the return ring line to
help also the check valves (BMN36AA201 to …224) which are mounted on the fuel oil burner on
return line side to remain closed during natural gas operation. This prevents the circulation of hot gas
between the burners which would normally occur due to slight differences in pressure in the
combustion chamber.
Page 4 of 14
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The diameter of the MBN36BP001 orifice is so small that only insignificant cross flows of oil pass
through during operation on fuel oil.
In case of defective seals in the sealing air ball valve, to prevent oil from flowing from the ring line
into the seal air line and from there to the compressor outlet (risk of ignition!) during operation on
fuel oil, a leakage oil line is provided to drain the space between the ball and valve body. Solenoid
valve MBN34AA002 is open during fuel oil operation, allowing any leakage oil to flow through orifice
MBN34BP001 into leakage oil tank MBN60BB001. If the amount of leakage oil is so great that
pressure upstream of this orifice, detected by pressure switches MBN34CP001 /002 /003 in 2 v 3
logic, exceeds a proper set limit, the fuel oil system shall be immediately disconnected (trip).
The oil returning from the diffusion burners flows through the branch lines into the return ring line.
The return line to the fuel oil package has a connection to the purge water system, refer to section
TGO2-3007.
Return Line Emergency Stop Valve (DO)
Return line emergency stop valve MBN52AA051 performs the same function in the fuel oil return line
as the diffusion emergency stop valve MBN14AA051 in the supply line. If an “OPEN” command is
issued to the diffusion supply line ESV, the return line ESV must open within a short time, otherwise
the entire flow through the diffusion supply line would be injected into the combustion chamber and
this is not permissible. Fuel oil system trip is triggered if the return line ESV does not open within a
short time.
Diffusion Return Line Control Valve (DO)
The task of diffusion fuel oil control valve MBN53AA151 is to regulate the return line flow. This in
turn determines the volume of fuel injected, which is the difference between the supply line flow
and the return line flow. Whenever the return line emergency stop valve is closed, the control valve
also closes.
Upstream return control valve, the return line is equipped with the thermocouple MBN51TC101 and
the flowmeter MBN51CF101 with monitoring purpose.
Measurement and control of Return Line pressure
During FO-DO operation the return line pressure, downstream MBN53AA151, is also monitored by
the pressure transmitters MBN54CP101/102/103. Since the amount of diffusion mass flow injected
through diffusion burners is dependent on fuel oil return line pressure, in case of sudden increase in
return line pressure a FO injection overflow can occur with the risk of overpressure inside
combustion chamber. For such reason during fuel oil operation if the fuel oil return line pressure
rises above P.HOE.10 (e.g. 10bar) a GT trip in 2V3 logic is issued with a 0.5s delay.
Page 5 of 14
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In order to filter the pressure fluctuations after FO-DO-ESVs opening, the pressure monitoring logics
above described on diffusion lines are activated only after the delay time K.HOE.03 from ESVs open
command.
NOTE: for the bad quality of one pressure transducer it must be always assumed that the sensor
protection threshold has been triggered. Therefore in case of 2V3 bad quality sensors the GT trip is
issued.
Premix System Components

Premix Emergency Stop Valve
Similar to the diffusion supply line ESV, the task of premix emergency stop valve MBN23AA051 is to
enable or disenable the supply of fuel oil to the premix burners. Furthermore, it is closed in the event
of faults requiring immediate shutdown of the gas turbine.
Premix Supply Line Control Valve
Like the diffusion supply line control valve, premix control valve MBN23AA151 has two functions. As
a control valve, it regulates the amount of fuel oil supplied to the premix burners. In addition, it also
has a trip function, i.e. spring force is used to very rapidly and reliably close this valve concurrent
with the premix emergency stop valve when trip is triggered.
Downstream premix control valve, the premix supply line is equipped with the thermocouple
MBN25TC101 and the flowmeter MBN25CF101 with monitoring purpose.
Note: all the stop and control valves for both diffusion, return and premix circuits are hydraulically
actuated and described in section TGO2-2005.
Permanent-element Fuel Oil Filter (PM)
Despite filtering of the FO, isolated instances of contamination may occur, particularly after lengthy
outages of the FO system. To protect the FO burners against impermissible soiling, permanent-
element, fine-mesh filter MBN41AT001 is installed upstream of the fuel oil premix burner ring line.
If the differential pressure at filter MBN41AT001 exceeds the setting of pressure transducers
MBN41CP101/102/103 (2vs3 logic), changeover is made from FO-PO to FO-DO. In addition, further
load reduction down to 70% occurs.
Fuel Oil Line to the Combustion Chamber (PO)
The premix supply line is equipped with seal air ball valve MBN44AA001, orifice MBN44BP001,
pressure switches MBN44CP001 / 002 / 003 and solenoid valve MBN44AA002 with identical
components, configuration and function as described for the fuel oil diffusion supply line to the
Page 6 of 14
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combustion chamber. The mixer MBN43AM001 has the task to create a water oil emulsion during
the purging phase of the premix burner (see section TGO2-3007).
Back purge system (PO)
The automatic backpurge system is used only in fuel oil operation with the purpose of cleaning the
fuel oil premix nozzles. During the connection /disconnection of fuel oil premix burners, there’s the
possibility for some fuel oil traces to crack into the nozzles due to the high operating temperature
inside the combustin chamber. In such case the nozzles can get clogged and therefore the corrected
fuel oil premix operation is no longer stable.In order to prevent such phenomenon and to keep the
premx nozzles clean, the backpurge system is activated.
The backpurge system is characterized by an external skid with two pneumatic valves
MBN45AA001/002. The pneumatic valves are connected on one side to the lower part of fuel oil
premix manifold and on the other side with the fuel oil dranage tank MBN60BB001. A thermocouple
MBN45CT101 is installed on the pipe between the premix manifold and the drainage tank only with
monitoring purposes.
During the backpurge sequence (activated automatically during the diffusion –premix changeover or
manually during diffusion operation), the purging water skid is activated and a certain amount of
purge water is firstly injected inside the premix burners, in order to flush and cool down premix
nozzles . After a few seconds, the purging water system is disconnected and both the pneumatic
valves MBN45AA001/002 are opened, creating a “reverse” flow across premix burners, from
combustion chamber towards the drainage tank MBN60BB001. Such backflow (which normally lasts
few seconds) allows any cracked fuel oil inside the nozzles to be mechanically removed, keeping
premix nozzles clean and allowing a correct and stable premix operation.
Warning:
in case of suspicious of premix burner clogging (e.g. due to increasing differential pressure at filter
MBN41AT001(measured by MBN41CP101/102/103)) , an emergency changeover in diffusion mode
may occur after an emergency clos command on MBN53AA051 and then, when the gas turbine is in
diffusion mode, the HP purging sequence is activated in the “premix burners purging”.
Burner Pressure Monitoring
Proper burner function requires sufficient pressure at the burner inlet (diffusion, premix supply lines)
to atomize the fuel oil. Otherwise, un-combusted oil could enter the combustion chamber (explosion
hazard!) or hot combustion chamber gases could flow in the reverse direction into the burners and
the fuel oil system. It is for this reason that the differential pressure between the FO supply line and
the combustion chamber is monitored. For reasons of simplicity, the compressor outlet pressure,
which is only slightly higher, is used instead of the combustion chamber pressure; this parameter is
measured by pressure transducers MBA12CP101 and MBA12CP102.
Page 7 of 14
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Pressure transducers MBN14CP101/102/103 in the diffusion supply line and pressure transducers
MBN23CP101/102/103 in the premix supply line are provided for measuring fuel oil pressure at the
burners. Differential pressure is calculated by the control system using these instrument readings.
If pressure drops below a certain differential pressure values in the premix line, the premix mode is
interrupted, the switch back to diffusion occurs and a maximum of 70% of GT load is possible.
If pressure drops below a certain differential pressure values in the diffusion line, the fuel oil system
shall be disconnected. Of course in case of GT running in fuel oil operation (i.e. not during a fuel
change over phase), this action will lead to a GT trip.
Pressure Relief of Diffusion and Premix Systems (Vented Oil Seal)
When the GT is at standstill, there is a danger that a slight amount of leakage oil may enter the
combustion chamber via the ESVs due to pressure prevailing in the supply line or to the tank back
pressure in the return line. An impermissibly large amount of oil could accumulate in the GT during a
very lengthy outage. To prevent this, the piping between the premix supply line valves
(MBN23AA051, MBN23AA151), the diffusion supply line valves (MBN14AA051, MBN14AA151), and
the diffusion return line valves (MBN52AA051 and MBN53AA151) is depressurized by opening
solenoid valves MBN14AA501, MBN23AA501 and MBN52AA501. This diverts any oil leakages that
occur into the leakage oil tank. Very small diameter orifices installed in the relief lines (MBN23BP001,
MBN14BP001, MBN52BP001) ensure than only an insignificant amount of oil can enter the leakage
oil tank if a solenoid valve spuriously opens during FO operation.
Leakage Oil Tank
Leakage oil from the shutoff ball valves of the diffusion and premix seal air line, the premix ring drain
line, the vented oil seal venting lines and from various drain lines and from the back purge system is
collected in the leakage oil tank MBN60BB001. This tank is provided with a venting line that opens to
the atmosphere (flange 13A).
Leakage oil pump MBN60AP001 forwards oil leakages into the auxiliary return line. It is automatically
started up and shut down according to level. For level measurement, level switches MBN60CL001 /
002 and level transducer MBL60CL101 are used.
Page 8 of 14
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Miscellaneous
In addition to several optional measuring points, the following local pressure indicators are provided
for maintenance and checking purposes: differential pressure across the fuel oil filter (MBN11CP501),
pressure upstream of the injections pump (MBN12CP501), pressure downstream of the injection
pumps (respectively MBN12CP502..503), and pressure in the diffusion return line (MBN52CP101).
Valves are provided at various locations for draining piping and certain components of the fuel oil
system. These drain valves must remain closed whenever the gas turbine is running.
Control valves
Stop valves
Motor
Pump
3 way valve
filter
Premix line
Figure 1: typical view of the fuel oil system Return line Diffusion line
Page 9 of 14
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OPERATION
Startup, FO Operation, Shutdown
The sequence in which items of fuel oil system equipment are operated or actuated during startup,
operation and shutdown is described below. All of these processes are fully automatic.
In the following all the operations are described considering the main injection pump running, in case
of fault of the main pump the sequences take place symmetrically with the stand by pump, provided
that this has been selected.
GT Startup with fuel oil

The forwarding system is started up with the gas turbine at standstill (or in turning gear mode). The
DO supply line and return line control valves are actuated to their startup lift settings. The startup
equipment (generator and startup frequency converter) begins to accelerate the gas turbine. If at
least two of the pressure transducers MBN12CP101, MBN12CP102, and MBN12CP103 upstream of
the selected injection pump signal sufficient pressure, the injection pump is started when the gas
turbine reaches a proper speed. Since the emergency stop valves are still closed, the fuel oil
delivered by the injection pump flows through the minimum-flow valve into the auxiliary return line.
Fuel oil pressure downstream of the pump increases.
When the gas turbine has reached the speed S.TURB.31, ignition gas is fed into the natural gas
burners and ignited by the ignition transformers, the ignition flames are therefore generated.
Thereafter the diffusion supply and return line emergency stop valves are simultaneously opened so
that fuel oil flows through the diffusion burners and is ignited by the ignition flames. The flame
monitoring starts counting, flame must be detected within 9 seconds after the opening of the FO
stop valves Once speed S.TURB.88 is exceeded, the ignition gas flow is shut off; the fuel oil diffusion
flames burn stably on their own. At a turbine speed of S.TURB.55, the volume of fuel oil injected is
increased with a linear time function (JK.HOEDB.01). At turbine speeds above S.TURB.56, the slope of
this time function becomes greater and the volume of fuel oil injected increases more rapidly
(applied gradient JK.HOEDB.02). A third gradient (JK.HOEDB.05) is applied by exceeding the turbine
speed S.TURB.561. When rated speed is reached the speed controller assumes control of the DO
control valve actuators. The turbine-generator is then synchronized with the grid and the fuel control
is routed to load controller.
Page 10 of 14
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Diffusion Mode
After synchronizing, the lift of the DO return line CV and thereby the fuel oil injected are regulated by
the load controller. Initially the gas turbine is operated in diffusion mode.
The diffusion supply line control valve is used to regulate the amount of fuel oil supplied in
accordance with a stored characteristic as a function of the injection flow, in order to reach a good
nozzle operation. By so doing, the mass flow in the diffusion supply line is kept within a range
favorable for the pumps and burners. The diffusion return line control valve regulates the amount of
fuel oil actually injected.
The changeover to premix mode can be made once the exhaust temperature exceeds the value
TT.ATK.02.
Changeover from FO DIFFUSION to PREMIX MODE

Before activating the premix system, the backpurge is activated for a short time K.PURG.200.
Once the conditions for changeover to premix mode operation have been satisfied, the PO seal air
ball valve MBN44AA001 is closed and the PO control valve is actuated to a position in accordance
with the minimum premix ignition flow.
The premix burners must first be cooled with water to prevent the inflowing fuel oil from coking (see
purging water system, section TGO2-3007). To do this, the ring line is first filled with water. In the
process, a small amount of water enters the combustion chamber via the lower burners. As soon as
the ring line is completely filled with water, the supply of purge water is shut off and the ESV opened.
The flow of oil initially forces the water through the premix burner nozzles, which cools them. After a
brief transition period, all nozzles are supplied with oil and stable premix flames form.
The control valves for fuel supply to the premix and diffusion burners are then actuated such that the
total volume of oil injected remains constant, the premix fraction increases and the diffusion fraction
decreases. Changeover is completed when the diffusion burners only receive the flow of fuel that is
necessary for formation of the pilot flames.
FO Premix Mode
In premix mode, the amount of fuel required for the desired output is controlled using the premix
control valve whereas the diffusion system supplies the amount of fuel required for the pilot flames
(as function of the total fuel demand).
Page 11 of 14
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Changeover from FO PREMIX to DIFFUSION MODE
Fuel oil premix flames are stable only over a certain fuel/air ratio, therefore when the turbine
exhaust temperature drops below the value TT.ATK.05 the change back to diffusion mode is initiated
the diffusion fraction is increased and the premix fraction decreased, maintaining constant the gas
turbine output. Premix system trip is triggered shortly before the point at which stable premix flames
are no longer possible. In order to remove any oil residue into the piping demineralized water is used
to displace the oil; due to the water pressure the remaining oil atomizes and any oil film on the
burners is avoided, this ensures that no coking process may take place. After the purging operation
has been completed, the ring line remains filled with purge water to the height of the outlet of the
lowest burner. Premix drain valves MBN45AA001 and MBN45AA002 are therefore opened briefly
during the purging operation. This also purges the premix drain line with water, ensuring that during
subsequent diffusion mode operation no oil can reenter the premix burners from this line which
would cause clogging of the premix nozzles in the lowest burners.
Upon completion of purging, the premix seal air ball valve opens, i.e. cooled air from the compressor
outlet is supplied to the premix burners. The gas turbine is now running in diffusion mode.
Shutdown
First the output of the GT is reduced, in case of premix operation, when the proper exhaust
temperature is reached the switch back to diffusion is performed, the generator is disconnected from
the grid at a very low positive output. Fuel oil system trip is then triggered, i.e. the DO emergency
stop and control valves in the supply and return lines close and the injection pump is shut down.
The diffusion burners and their ring lines are then purged with water. With the return line ESV and
return line CV, the water forces the remaining oil out of the supply lines into the return line.
The GT coasts down without combustion until it reaches turning speed. The fuel oil system is ready
for the next startup.
Page 12 of 14
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GT trip in fuel oil mode
In case of fault which requires to immediately shut down the GT during operation, all control and
stop valves in the fuel oil system are closed and the injection pump is shut down. During the
subsequent purging operation, large amounts of oil still in the lines must be prevented from entering
the combustion chamber. This oil could feed uncontrolled ignition on the hot walls or enter the
exhaust system as uncombusted oil mist. Consequently, first the diffusion system alone is purged as
described under “Shutdown”. In doing so, most of the oil is forced into the return line. At the same
time, solenoid valves MBN45AA001 and MBN45AA002 are opened, and the remaining (low)
combustion chamber pressure forces the remaining oil from the premix ring line and the premix
burners into the leakage oil tank. The solenoid valves close after a proper delay.
Once purging of the diffusion system has been completed, the premix system is then purged.
Fuel Changeover
Fuel changeover is made between natural gas premix mode and dry fuel oil diffusion mode and vice
versa. The permissible window range is defined by IGV position which must be > G.VLE0.38 and <
G.VLE0.39 (e.g. IGV position higher than 10% and lower than 70%). If the gas turbine is not running
in the permissible load window, load must be increased or decreased manually or by unit
coordination control before fuel changeover is made.
From Gas to Oil
During fuel gas operation, if ‘Fuel Oil Operation” is selected at the local control console or in the
control room or in case of decreasing fuel gas pressure below the limit value P.GAS.03 for more than
K.GAS.01 time, the gas turbine the fuel change over is initiated.
The fuel oil system is connected by activating the FO forwarding system and then, when the pressure
upstream of the fuel oil injection pump is sufficient, the injection pump receives a command start. In
the meantime, since the annular collector can be empty, in order to avoid back flow of hot gases
when the fuel oil valves are opened, the annular collector are filled with water by activating the
purging system (see Purging Water system description, section TGO2-3007).
Then the fuel oil control valves are set in order to inject the fuel oil connecting mass flow
F.HOEDB.33.
Then the FO diffusion supply and return stop valves are opened and the fuel oil flow is injected in the
combustion chamber where it is ignited by the fuel gas flame.
Page 13 of 14
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After the fuel oil connection, when the GT is temporary operating in dual fuel mode, the fuel
controller moves the fuel proportion from 100% gas to 100% oil.
When the fuel gas premix control valve has reached the position corresponding to the disconnecting
mass flow F.EGVB.26, the fuel gas system is disconnected. The disconnection of fuel gas system is
described in the Fuel Gas system description, see section TGO2-3001.
Now the GT is in fuel oil operation diffusion mode, the load set point is released.
From Oil to Gas
To make the changeover from operation on fuel oil to natural gas, the gas turbine must first be
operated in fuel oil diffusion mode. Once the gas turbine is running in fuel oil diffusion mode in the
allowed output window, the machine can be automatically changed over to natural gas premix
mode.
During fuel oil operation, if ‘Fuel Gas Operation” is selected at the local control console or in the
control room, the gas turbine is first switched to dual-fuel mode and then the fuel oil system is
disconnected.
Fuel change over is initiated only if the fuel gas pressure is above P.GAS.03.
The fuel gas system is activated and connected as described in the Fuel Gas system description, see
section TGO2-3001.
Once the NG ESV is opened, the GT is temporary operating in dual fuel mode, the fuel controller
moves the fuel proportion from 100% oil to 100% gas.
When the fuel oil system reaches the minimum quantity for disconnection F.HOEDB.33, the fuel oil
system is excluded by closing the FO diffusion supply and return stop valves, the injection pump is
stopped. Then the fuel oil diffusion system must be washed in order to remove the fuel oil deposits
from burners and annular collector, therefore the fuel oil diffusion purging is started (see Purging
Water system description, section TGO2-3007).
When the fuel oil system has been disconnected and purged, the GT is running in fuel gas premix
mode. The load set point is now released.
Page 14 of 14
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P&ID PURGING SYSTEM
In addition see

Page 1 of 1
P&ID PURGING SYSTEM TGO2-3006-E00000
14.11.14
For Construction.
For Construction.
PURGING WATER SYSTEM
Function
On Gas Turbine equipped for fuel oil operation, it is necessary to foresee a purging water system in
order to purge the fuel oil burners / lines on several occasions.
In particular, purging is required in the following phases:
 PREMIX COOLING -Before the connection of the FO premix burners. At this step the premix
burners must be cooled to avoid coking of fuel oil, in fact the nozzles are surrounded by hot air
extracted from the compressor.
 PREMIX PURGING - After the disconnection of the FO premix burners: the premix burners must
be purged to displace the oil remaining in the burners and in the ring line to avoid that the oil
enters the combustion chamber without being properly atomized which may result in burners
nozzles clogging.
 DIFFUSION PURGING - After a trip of the FO diffusion system for the same reasons as stated
above.
 DIFFUSION FILLING - Before a change over from natural gas to fuel oil the return line must be
filled with water to avoid the penetration of hot gases in the first phases of the change over.
Furthermore before the FO injection also the feed line ring is filled.
A de-ionized water supply must be available from the plant.
The overall system consists of an high pressure (HP) skid and valves.
Components
The HP purging skid is characterized by the following equipment:
 Purging water tank MBN80BB001.

 Filling solenoid valve MBN80AA002, equipped with an OPEN position limit switch
(MBN80AA002-S11).
 Two pressure transmitters MBN80CP101/102, used to monitor the purging water tank level.
 A safety lock open manual valve MBN81AA001 and a second manual valve MBN82AA001,
respectively upstream and downstream the HP purging water pump, just for pump
maintenance operations.
 A filter MBN81AT001 located upstream the HP purging pump as protection for the pump
itself
 HP purging water pump MBN82AP001
 Two thermos-resistances MBN82CT101/102 installed on the motor bearings of HP purging
water pump
 Three pressure transmitters MBN82CP101/102/103 and a local pressure gauge MBN82CP501
used to monitor the pressure downstream HP purging water pump
Page 1 of 8
PURGING WATER SYSTEM TGO2-3007-E72000
18.01.18
 HP purging control valve MBN82AA151 (hydraulically actuated) regulating the proper
amount of water to inject during the several phases of purging process
 A drain valve MBN82AA053 equipped with two CLOSED position limit switches
(MBN82AA053-S21-S22) located between the HP water control valve and the common shut
off valve to allow discharge of water or water / oil mixture to the fuel oil drainage.
 HP purging shutoff valve MBN82AA052, equipped with two OPEN position (MBN82AA052-
S11-S12) and one CLOSED position (MBN82AA052-S21) limit switches.
 Two differential pressure transducers MBN82CP104/105 used to monitor the delta pressure
between the HP purging delivery pressure and GT compressor discharge pressure.
 A purging water flow meter MBN82CF101, used to monitor the purging water flow during
purging process.
Outside the HP purging skid limits, four separate lines are provided in order to supply water to
diffusion and premix lines during the purging process.
Each line is equipped with a shut off valve as below described:
 MBN83AA051 in diffusion FEED line (respectively actuated by MBN83AA051A)

 MBN83AA052 in diffusion RETURN line (respectively actuated by MBN83AA052A)
 MBN84AA051 in premix RING line (respectively actuated by MBN84AA051A)
 MBN84AA052 in premix FEED line (respectively actuated by MBN84AA052A)
All the shutoff valves are equipped with two CLOSED position limit switches (S21-S22) and are
pneumatically actuated by the related control solenoid valves. The valves are opened when the
solenoid valve are energized (allowing compressed air to enter and win the spring resistance) and
are closed when the solenoid valves are de-energized (the compressed air is vented and the spring
restore the closed position).
Moreover there is a mixer MBN43AM001 positioned in the premix ring line to create an emulsion
between the injected HP purging water and fuel oil during the premix cooling or purging, in order to
perform such changeovers in a bump less way
Flushing water tank
The volume of flushing water tank MBN80BB001 is sufficient to carry out all the flushing, filling and
cooling (if required) procedures during an entire fuel oil operating cycle without refilling the tank.
The filling mass flow is regulated by the filling solenoid valve MBN80AA002.
The tank filling is done opening the filling solenoid valve MBN80AA002 according to the purging
water level and is opened if the level is "low" (L.SPUEL.01) and closed if the level is "high"
(L.SPUEL.03).
Page 2 of 8
18.01.18
HP Water pump
The HP water pump MBN82AP001 is protected against dry operation by the level "too low"
(L.SPUEL.02). A malfunction of the filling is transmitted if the level "too high" is reached (L.SPUEL.04).
The level limit values are derived from the flushing water tank pressure (MBN80CP101/102). The
level (expressed in mm) is derived multiplying the pressure level (expressed in mbar) with the value
10.2.
From the tank, the water passes via the flushing water filter MBN81AT001 to the High Pressure water
pump (MBN82AP001). The filter is equipped with a local differential pressure indicator
MBN82CP501.
Bearing temperatures of the pump motor are measured by single-element temperature instruments
(MBN82CT101/102). In case of high temperature in motor bearing an alarm is issued, in case of very
high temperature or fault to both instruments, the pump is shut down and therefore premix purging
is interrupted. The motor winding temperature is controlled directly by 3 PTC thermistors.
The water pump is disconnect in case of low pressure at the suction side by means the tank pressure
transducer MBN80CP101/102.
HP Water Control Valve
Downstream the pump, the HP water control valve MBN82AA151 ensures that a proper water flow is
delivered to the different burners as required by the different purging modes.
The pressure transmitters MBN82CP101/102/103 are used to calculate the water mass flow to the
control valve MBN82AA151. The flushing procedure is monitored by differential pressure
transmitters MBN82CP104/105 (measuring the differential pressure between water supply line and
compressor delivery).
The valve is hydraulically actuated, (for more information see the proper document).
HP purging shut-off valve
The HP purging system is isolated through the shutoff valve MBN82AA052 located on HP purging skid
and through the shutoff valves MBN83A051/052 and MBN84AA051/052 located on the HP purging
lines to the burners (diffusion and premix).
All the shutoff valves are commanded in OPEN/CLOSE position by the HP purging sequence.
In case of opening of one of the shutoff valves MBN83A051/052 and MBN84AA051/052 AND of the
shutoff valve MBN82AA052 when not required, there is the risk of contamination of purge water
with oil and therefore a GT TRIP is issued in such case.
NOTE: The OPEN and CLOSED position for the shutoff valves MBN83AA051/052 and
MBN84AA051/052 must be in logic 2oo2, using both the CLOSED limit switches.
The OPEN and CLOSED position of the shutoff valve MBN82AA052 must be in 2oo3 logic, using the
two OPEN and the one CLOSED limit switches
Page 3 of 8
18.01.18
OPERATION
Pressure control
The pressure downstream of the pump is monitored by transmitters MBN82CP101/102/103
(upstream of the control valve) with a logic 2oo3.
Downstream the common shut off valve, two differential pressure transmitters MBN82CP104/105 control that
the water pressure is higher than the compressor discharge.
In case of fault of one pressure transmitter an alarm is issued. In case of fault of both the transducers
if the GT is operated at fuel gas an alarm is emitted and the change over to fuel oil is inhibited; if the
GT is running at fuel oil an alarm is emitted, in case of switch to fuel gas a trip will be released by the
purging monitoring.
WARNING
It is necessary that the purging skid is always available because the missing of one of the cooling
process can lead to burner clogging / cocking .
Premix burners cooling before FO premix operation

Before the injection of FO through the premix nozzles it is necessary to cool the nozzles to avoid
coking, for this purpose emulsion water is sent to the premix ring and then to the burners.
When the cooling procedure is activated (required by the FO sequence), the following actions are
achieved:
 the water pump (MBN82AP001) is started,
 the water control valve MBN82AA151 (CV) is set to emulsion water premix mass flow
F.EMUSPU.100
 the FO premix seal air ball valve MBN44AA001 and HP purging drain valve MBN82AA053 are
CLOSED
 provided that the water pressure at MBN82CP104/105 is > P.EMUSPU.100, the emulsion
premix water shut off valve MBN84AA051 and shut off valve MBN82AA052 are opened. In
case the pressure is not reached within 3s from the starting of the pump, the change over is
aborted.
 In case the pressure is not reached within 3s from the starting of the pump the change over
is aborted.
 Then the fuel oil can be added and a water / oil emulsion is realized, this constitutes an
advantage in terms of the first oil coming in contact with the burner nozzles, which are still
cooled by the water.
 When the switch over to premix is terminated, the water system is disconnected (pump off
and all valves closed) and the premix cooling is ended.
Page 4 of 8
18.01.18
The premix cooling is interrupted in case of fault to the sequence, an alarm is issued and the fuel oil
premix mode is not achieved, e.g. the GT returns in fuel oil diffusion mode.
Premix burners purging after switch over from FO premix to FO diffusion
The premix burners purging after switch over from FO premix to FO diffusion, takes place according
with the following sequence:
 the water pump MBN82AP001 is switched ON,
 the control valve MBN82AA151 is positioned according to the set point for premix purging
connection F.EMUSPU.103,
 when the pressure at the pump discharge is > P.EMUSPU.100, the emulsion premix water
shut off valve MBN84AA051 and shut off valve MBN82AA052 are opened while HP purging
drain valve MBN82AA053 is CLOSED
 After 3 seconds from the opening, the emulsion water set point is changed to the purging
value F.EMUSPU.104.
 When the fuel oil premix flow reaches the F.HOEVB.104, the emulsion premix valve
MBN84AA051 receives a closed command and the FO premix drains MBN45AA001/002
receive a pulsed open command for the time K.LEER.100; the purging is continued for the
time K.EMUSPU.102 and at the end the emulsion premix shutoff off valve MBN84AA051 is
closed.
 Now also the line between the purging water line connection and the mixer (see fig 1) must
be purged, so the premix purging lines shut off valve MBN84AA052 is opened for the time
K.EMUSPU.103, the FO premix drains MBN45AA001/002 are pulsed open for the time
K.LEER.101
 At the end HP purging Shutoff valve MBN82AA052, control valve MBN82AA151 and
MBN84AA052 close and the pump is switched off.
Page 5 of 8
18.01.18
Water from premix line
from fuel oil MBN84AA051/052
Mixer
MBN43AM001
Water from emulsion

premix line
MBN84AA053/054
Figure 1: arrangement of purging and emulsion for premix cooling / purging
WARNING
In case of GT trip for failure of premix purging, before the next start up a manual
purging of the premix line / burner is necessary (manual start).
FO diffusion purging
The FO diffusion purging is carried out at any end of the FO operation (i.e. GT trip from fuel oil mode,
at fuel oil disconnection after fuel change over from oil to gas), according to the following sequence:
 The water pump MBN82AP001 is switched ON,
 MBN82AA053 CLOSE and the MBN34AA001 close (see P&ID Fuel Oil System)
 the FO return stop valve is then opened and the FO return line control valve is set to the
purging position H.SPUDB.01 for the time K.SPUDB.01-7s, (then the return line control valve
is closed to clean the nozzles forcing all the water to enter the diffusion burners), the water
control valve MBN82AA151 is set to the mass flow F.SPUDB.100 and the water is sent to the
diffusion branch by opening the diffusion shut off valve MBN83AA051 and shut off valve
Page 6 of 8
18.01.18
MBN82AA052 for the time K.SPUDB.01. After the purging process the FO diffusion seal air
ball valve is opened. At the end of the purging, the purging system is shut off (pump OFF and
all valves closed).
In case the purging procedure is not successful an alarm is issued.
WARNING
In case of failure of diffusion purging, before the next start up a manual purging of
the diffusion lines / burner is necessary (manual start).
FO diffusion filling at fuel change over from gas to oil
Before connecting the fuel oil in fuel gas mode (when change over from gas to oil is required), it is
necessary to fill the FO return line with water to avoid back flow of hot gases.
Filling the FO return line
At first the water pump MBN82AP001 is switched ON, the water CV is set to the filling mass flow
F.FILL.100 then provided that the minimum water pressure is reached, the FO return line purging
shut off valve MBN83AA052 and shut off valve MBN82AA052 are opened. The filling procedure lasts
at least 15 s and it ends when the pressure in the FO return line is > P.FUELL.01. At the end the shut
off valve MBN83AA052 is closed.
Filling the FO supply line

After the return line has been filled, also the supply line must be filled. The water pump is on, the
water CV is now set to the filling mass flow F.FILL.101 and then the FO supply line purging shut off
valve MBN83AA051 (and shut off valve MBN82AA052) is opened, then the FO diffusion seal air ball
valve receive a close command delayed by the time K.PURGE.101 (from the starting of the purging).
After the time K.PURGE.101 the supply line filling is considered completed and the purging system
(valves and pump) is switched off.
In case the filling procedure cannot be successfully performed an is issued and the change over
procedure interrupted.
Page 7 of 8
18.01.18
The operator shall be familiar with the following summary table:
Operating mode When Branch activated Start mode

PREMIX COOLING Before switch over FO emulsion premix line Auto only
diffusion to FO Premix MBN84AA051
and premix line
MBN84AA052
PREMIX PURGING After switch over FO emulsion premix line Auto & Manual
premix to FO diffusion MBN84AA051
In case of GT trip from and
FO premix mode premix line
In case of FO-premix MBN84AA052
trip (e.g. load
rejection)
DIFFUSION PURGING After FO operation: diffusion supply line Auto & Manual
- In case of GT trip MBN83AA051
from FO mode
- After fuel change
over from oil to gas
DIFFUSION FILLING Before fuel change diffusion supply line Auto only
over from gas to oil MBN83AA051
and diffusion return line
MBN83AA052
See in addition:
Fuel oil system TGO2-3005
Fuel Actuators TGO2-2005
GT starting – Purging water Sequence TGO3-0049
Page 8 of 8
18.01.18
P&ID IGNITION GAS SYSTEM
In addition see

Page 1 of 1
P&ID IGNITION GAS SYSTEM TGO2-3410-E00000
14.11.14
For Construction.
IGNITION GAS SYSTEM
Two different fuels can be used to run the gas turbine (GT).
When the GT is started up with natural gas, there is no need to activate the ignition gas system since
there is no need to ignite the fuel gas flowing via the pilot gas burner (see fuel gas system
description, section TGO2-3001), i.e. the fuel gas is directly ignited.
On the contrary, in case of GT started up with fuel oil, the fuel oil needs to be ignited by a small
ignition gas flame. The ignition gas system has the purpose to supply the ignition gas in proper flow
to form ignition flames. Once a certain speed has been reached, conditions in the combustion
chamber are such that the fuel oil flames burn stably and the supply of ignition gas can be shut off.
Note: the ignition burners depend on the burner configuration, refer to section TGO2-0780.
Configuration
Ignition gas (usually propane or mixture propane-butane) is supplied from tank MBQ10BB001. This
tank, its filling and shutoff valves and the associated safety and control devices are not part of the
gas turbine description, refer to Plant documentation.
The ignition gas is present in the tank in both liquid and gaseous form.
The two ignition gas valves MBQ11AA001 and MBQ13AA001 automatically shut off the ignition gas
flow. These solenoid valves are of an identical design and each is equipped with two inductive limit
switches for the OPEN position. The ignition gas valves are closed by spring force when deenergized.
Together with ignition gas vent valve MBQ12AA501, they constitute a vented gas seal.
Ignition gas valve MBQ11AA001 functions as the initial shutoff element of the vented gas seal, and, is
mounted with manually-actuated shutoff valve MBQ11AA251 on a separate equipment package
located near the ignition gas tank. For maintenance purposes the ignition gas supply can be manually
shut off using this shutoff valve.
The ignition gas package located nearby the gas turbine comprises pressure control valve
MBQ12AA151, ignition gas relief valve MBQ12AA501 and the second ignition gas valve
MBQ13AA001. Pressure control valve MBQ12AA151 reduces ignition gas pressure to the level
required for ignition. It ensures that the flow of ignition gas is independent of tank pressure.
The relief valve is opened by spring force when deenergized and is equipped with two inductive
switches which detect the "closed" position. Gauge MBQ12CP501 is located downstream of the
pressure control valve and is used to visual check the prevailing pressure. The ignition gas pressure is
monitored during the ignition phase by pressure transducer MBQ13CP101 for displaying purposes
only.
Check valve MBQ13AA201 protects the ignition gas system against the ingress of natural gas or
compressor discharge air.
Flames are ignited electrically by spark plug located in convenient point of the fuel gas burner.
Page 1 of 2
IGNITION GAS SYSTEM TGO2-3411-E72000
21.10.16
Function
The ignition sequence takes place completely automatically during startup of the gas turbine. Shortly
before reaching ignition speed S.TURB.31, e.g. 11 % of rated speed, the pressure relief valve is
closed. When the vent valve has reached the closed position, the ignition gas valves are opened and
the ignition gas flows to the diffusion burners of the fuel gas system. The startup operation
continues.
At the same time the ignition gas valves are opened, voltage is supplied to the ignition transformers.
An electric arc forms between the two electrodes of the igniter and the ignition gas is lit.
Now the fuel oil injected into the combustion chamber is ignited by the ignition flames. When speed
S.TURB.88 is reached, e.g. 46% of rated speed, the ignition gas valves are closed and power to the
ignition transformers is switched off, as the FO flames now burn stably. When both ignition gas
valves are closed, the vent valve is opened and the ignition gas in the pipe section between the two
ignition gas valves can be vented to the atmosphere.
In case the fuel oil emergency stop valves receive a "close" command before speed S.TURB.88 is
reached, the GT start procedure has failed.
The ignition gas valves are closed and the ignition transformers deenergized.
If one of the two solenoid ignition gas valves MBQ11AA001 or MBQ13AA001 does not open or if the
vent valve MBQ12AA501 is not closed during startup, the opening of the FO diffusion mode
Emergency Stop Valve is not enabled. The start up is interrupted.
Page 2 of 2
IGNITION GAS SYSTEM TGO2-3411-E72000
21.10.16
Safety and protective
system
FLAME MONITORING ARRANGEMENT
Function
The flame detectors measure the radiant energy given off by the flames inside the combustion
chamber. Since the flame detectors are only designed for operation at atmospheric pressure,
however, and a positive pressure exists inside the combustion chamber, openings are needed in the
combustion chamber which allow the radiant energy to pass through but seal tightly against the
pressure prevailing inside the combustion chamber.
Construction and Functional Principle

Two flame detectors (1) MBM13CR101/102 are mounted in the combustion chamber, each in a
flanged pipe (8) welded into the combustion chamber shell. Two quartz lenses (7), arranged in
tandem, are set in plates (5) and gaskets (6) and bolted to the flanges (9) by means of an end plate
(4). The flame detector (1) is bolted with thermal insulators (10) to thermal insulation plate (2) which,
in turn, is bolted to endplate (4) with spacers (3).
This arrangement ensures that the flame detector, which contains electronic components, among
other things, does not become too hot.
The space between the two plates (5) is open to the atmosphere via a small radial slot so that the
space between the two quartz glass lenses (7) is not pressurized. If the seal of the inner quartz glass
lens is not absolutely tight, warm air enters the space between the two quartz glass lenses and
escapes to the atmosphere from there radially at (X). Even in this case, the flame detector is not
exposed to hot air.
In order to test the proper function of the flame detector, the radiant energy to the flame detector
can be interrupted by holding a piece of sheet metal or cardboard between endplate (4) and thermal
insulation plate (2).
The flame detectors can be removed and reinstalled during operation. First disconnect the cable
from the flame detector, then loosen the threaded connection between the flame detector and the
thermal insulation plate.
In order to prevent turbine trip, both flame detectors on one combustion chamber should not be
removed at the same time.
Page 1 of 2
FLAME MONITORING ARRANGEMENT TGO2-4380-E72000
14.11.14
1. Flame detector
2. Thermal insulate plate
3. Spacer
4. Endplate
5. Plate
6. Gasket
7. Quartz glass lens
8. Flanged pipe
9. Flange
10. Thermal insulator
Page 2 of 2
FLAME MONITORING ARRANGEMENT TGO2-4380-E72000
14.11.14
P&ID BLOW OFF SYSTEM
In addition see

Page 1 of 1
P&ID BLOW OFF SYSTEM TGO2-4410-E00000
14.11.2014
For Construction.
BLOW OFF SYSTEM
Function
The axial compressor of the gas turbine is designed to run at the rated speed of the turbine
generator. When speed is lower than rated speed, the front stages of the compressor would be so
highly loaded aerodynamically that air flows would be separated at the compressor blading surface
due to excessive deceleration. As a result, the overloaded compressor stages are no longer capable
of generating the necessary increase in pressure, the compressor surges and the air flow becomes
unstable. The breakdown of flow results in periodic reverse flow, which is characterized outwardly by
pronounced, periodic fluctuations in the pressure at the final compressor stage together with severe
vibration of the turbine generator and pulsating noise synchronous with the pressure fluctuations.
This subjects the compressor blades to high alternating bending stresses and high temperatures.
When this surge-critical speed range is reached, air has to be bled from certain stages of the
compressor, reliably preventing compressor surging.
Functional Principle
For the purpose of bleeding compressor air, two blow off lines are provided on the compressor
casing from the extraction points at stages 5 (two extraction points),one at stage 9 and one at stage
13. The blow off lines open into the exhaust gas duct downstream of the gas turbine. As a result, the
exhaust silencer simultaneously functions as a silencer for the blow off air.
Because the blow off lines located at the bottom act as siphons due to their position, drain lines are
connected at the lowest points of these lines. Any water which may have been accumulated here
during compressor cleaning can be drained off via these lines.
As described above, the blow off will be OPEN during the GT start-up and shutdown and CLOSE
during GT normal operation as described in the following chapters.
Each blow off line is provided with a butterfly valve actuated by pneumatic actuators. The actuators
are fed by compressed air from the pneumatic system.
KKS Blow Off valve (butterfly type) Compr. stage Associated actuator
MBA41AA051 1.1 5 MBX90
MBA42AA051 1.2 5 MBX91
MBA43AA051 2 9 MBX92
MBA44AA051 3 13 MBX93
Page 1 of 3
BLOW OFF SYSTEM, DESCRIPTION TGO2-4411-E72000
07.10.16
The actuator is controlled by 2 solenoid valves, a pneumatic valve and a cartridge. In addition the
actuator is equipped with a spring that safety opens the blow off valve when the opening is required.
The solenoid valves enable or disenable the air passage towards the pneumatic valve which controls
the actuator. For availability reason, one solenoid is able to move the pneumatic valve. The air
passage via the pneumatic valve keeps the cartridge closed thus avoiding the air discharge. With
both solenoid de-energized the cartridge valve open and it discharges the air from the actuator
piston and the spring forces the blow off to open. In addition, the pneumatic valve is no more
supplied with compressed air.
Associated
Control solenoids Pneumatic valve Cartridge
actuator
MBX90 MBX90AA002A / B MBX90AA001 MBX90AA051

The compressed air is supplied by a dedicated pneumatic station, see description “Pneumatic station
supply” section TGO2-7001
Open-loop Control
The blow off system is controlled automatically. Actuation of the individual valves is described in the
following sections.
GT Start up with Natural Gas

At the beginning of the GT startup, all four blow off valves must be in the open position. During the
start up, they are closed as a function of speed. They are closed as soon as possible to maximize the
amount of air which can flow through the burners and the amount of fuel which can be added. This
reduces the starting time of the gas turbine.
When speed S.TURB.07 (approx. 80 % of rated speed) is exceeded, blow off valve 2 is closed. When
speed S.TURB.13 (approx. 98 % rated speed) is exceeded, the blow off valve 1.2 is closed . After a 5
seconds delay, blow off valve 1.1 closes as well. After a 20 seconds delay also the blow off valve 3 is
closed.
Page 2 of 3
07.10.16
GT Start up with Fuel Oil
At the beginning of the GT startup, all four blow off valves must be in the open position. During the
start up, they are closed as a function of speed. They are closed as soon as possible to maximize the
amount of air which can flow through the burners and the amount of fuel which can be added, but
later enough in order not to disturb the oil flame.
When speed S.TURB.70 (approx. 94% of rated speed) is exceeded, after the K.ABBL.02 time delay the
blow off valve 1.1 is closed. After 10 seconds delay the blow off valve 1.2 is closed. After additional
10 seconds delay the blow off valve 2 is closed. After additional 10 seconds delay also the blow off
valve 3 is closed.
GT trip and GT shutdown

In case of GT trip, all the blow off valves are opened at the same time with the trip command. During
GT shutdown, all the blow off valves are opened simultaneously as soon as the fuel supply is
interrupted by closure of the emergency shutoff valves.
Power Operation
During power operation the blow off valves must remain CLOSED.
Extraordinary Operating Conditions

In the event of an abnormal and not entirely preventable decline in speed during startup the blow off
valves are re-opened as a function of the speed limits.
In case one or more blow off valves are still opened at rated speed for more than 100 seconds, the
GT is shut down. A corresponding fault alarm is issued.
Manual command
No manual command can be given to the blow off valves as a safety requirements during the GT start
up and during power operation no manual command is necessary.
Page 3 of 3
07.10.16
Other Auxiliares
P&ID COMPRESSOR CLEANING SYSTEM
In addition see

Page 1 of 1
P&ID COMPRESSOR CLEANING SYSTEM TGO2-4961-E00000
14.11.2014
For Construction.
MANUAL COMPRESSOR CLEANING SYSTEM
Compressor cleaning serves to remove blade deposits that have caused a loss in power output and
efficiency. The intervals for cleaning and the procedure are described in section TGO4-4961 and
TGO4-4962.
Function
The compressor washing system supplies the mixture water / detergent and / or water for the
compressor clearing procedure at the required pressure (about 10 bar).
The system consist of the following components:
• Water tank with a capacity of approximately 750 litres (MBA18BB002). The tank is filled with
water and / or a mixture of water and detergent (flange 82). The tank can be drained by opening
the manual valve MBA18AA401 and the liquid discharged by the flange 83A. The tank is
equipped with local level indicator MBA18CL501.
• Multi-stage centrifugal pump (MBA18AP001), driven by AC motor, draws the cleaning solution
from the lowest point of the tank via a pipe. The pump is protected by a strainer MBA18AT001.
A motor ON/OFF switch is provided on local control panel including a motor-protection circuit
breaker. A cable with plug serves for connection to the power supply.
In the air intake, two type of nozzles are located in order to inject the water for compressor cleaning:
- 2 jet nozzles (MBA18BN001)
- 20 spray nozzles (MBA18BN002)
• Water is supplied to the jet nozzles by means of manual ball valve MBA18AA251 and to the
spray nozzles by means of manual ball valve MBA18AA252. Upstream of the valves a strainer
MBA18AT002 is located.
The details of the equipment is given in the Outside Vendor Parts.

The compressor cleaning procedure is described in section TGO4-4962.
Page 1 of 1
COMPRESSOR CLEANING SYSTEM, DESCRIPTION TGO2-4962-E00001
14.11.2014
P&ID DRAINAGE SYSTEM
In addition see

Page 1 of 1
P&ID DRAINAGE SYSTEM TGO2-4965-E00000
14.11.14
DRAINAGE SYSTEM
Cleaning solution, sprayed into the compressor during the cleaning operation, is collected in several
locations of the gas turbine. This liquid is removed via the drainage system before the gas turbine is
restarted.
Danger!
Risk of scalding! The cleaning and subsequent draining of the compressor are
manual operations, i.e. valves must be actuated by hand. It is imperative that
all the valves opened during the draining process be closed once draining has
been completed. If this is not ensured, hot air which can injure persons or
damage equipment will escape from the drainage piping. In addition,
crosscurrent flow may occur between the individual gas turbine drain
connections.
Configuration
Cleaning fluid is drained off at the following gas turbine locations:
No. / name Drain valve Gas Turbine Location
1 MBA21AA251 Compressor stage 0
4 MBA22AA251 Compressor outlet
5 MBA23AA251 Turbine stage 2
8 MBA21AA254 Extraction ring E1/A1 stage 5
BL MBA24AA251 Compressor stage 5 blowoff line
BM MBA24AA252 Compressor stage 9 blowoff line
BN MBA24AA253 Compressor stage 5 cooling air line
BO MBA24AA254 Compressor stage 9 cooling air line
BP MBA24AA255 Compressor stage 13 cooling air line
BJ MBA24AA256 Compressor stage 13 cooling air line
These locations are connected by pipes to header MBA25BB001. The shutoff valves in these lines
must be opened manually to drain cleaning solution and closed after completion of the draining
process. Cleaning solution must be routed from header MBA25BB001 via connection 30A and a hose
line to a disposal tank, which is to be supplied locally. The header only has a small volume and
therefore cannot function as a collecting vessel. For this reason it must be ensured that the cleaning
Page 1 of 3
DRAINAGE SYSTEM, DESCRIPTION TGO2-4966-E70001
23.03.17
fluid can freely flow from the header into a disposal tank at all times. A venting nozzle prevents the
buildup of pressure in the collecting tank.
When cleaning the compressor, some of the cleaning fluid flows to the lowest point of the
compressor intake structure which is not depicted in the PID diagram. This lowest point, is
connected to the disposal tank via a duct which has no shutoff valve. Instead the duct contains a
hydraulic seal which must be filled with water before the gas turbine is started up. During operation
this hydraulic seal prevents air in the disposal tank from flowing into the compressor because of the
subatmospheric pressure prevailing upstream of the compressor.
A thermoelement MBA25CT101 is positioned in the drainage collector with SIL protection purpose; in
case of high temperature, an Alarm is issued.
Fuel Oil Drainage System

When the gas turbine is started on liquid fuel (fuel oil), the latter is injected into the combustion
chamber during the ignition phase. In the event that the flames do not ignite immediately on startup
with fuel oil –or if they initially light and then extinguish– fuel oil may precipitate on the combustion
chamber walls. This unburned fuel oil must be drained off before the gas turbine is restarted. The
drain collection point and piping (drain valve MBA22AA251) is the same used to drain the water after
the compressor cleaning procedure.
Three-way solenoid valve MBA22AA001 is used to route fluid from this drain to the fuel oil discharge
system instead of to the water drain system (as in case of water after compressor cleaning). A second
shut off solenoid valve MBA22AA002 safely isolates the combustion chamber from the oil disposal
system, whose connection is represented at flange 111A. This disposal system is not part of the gas
turbine description.
In “fuel oil drainage setting”, the three-way solenoid valve MBA22AA001 has the setting “A–B open;
C closed” (that represents the three-way solenoid valve MBA22AA001 OPEN position i.e. energized
valve) and solenoid valve MBA22AA002 is OPEN.; while in “water drainage setting”, the three-way
solenoid valve MBA22AA001 has the setting “A–C open; B closed” (that represents the three-way
solenoid valve MBA22AA001 CLOSE position i.e. NOT energized valve) and solenoid valve
MBA22AA002 is CLOSED.
During standstills or turning gear operation the solenoid valves MBA22AA001 / 002 remain in fuel oil
drainage settings to allow any unburned oil that collects to drain off; this configuration is kept below
speed S.TURB.05 (for example 5% rated speed).
During startup with fuel gas, solenoid valve MBA22AA002 is closed at step 2 of GT Main Sequence
and the drainage system goes to water drainage setting.
During a startup with fuel oil, the drainage system goes to fuel oil drainage setting because it cannot
be ascertained in advance whether the start will be successful or aborted. These solenoid valve
Page 2 of 3
23.03.17
settings ensure that any fuel oil which may collect does not enter the water drainage system and no
hot air can escape from the fuel oil drainage system. When the “FLAME ON” signal is generated, the
3-way valve is actuated to its water drain setting “A–C open; B closed” when flames are detected in
the combustion chamber.
A distinction is made between two types of failed start:
 Fuel oil is injected without formation of flames. If this type of failed start occurs, the absence of a
signal from the flame monitor keeps the 3-way valve in its fuel oil drainage setting.
 Fuel oil is injected, flames initially form, however they subsequently extinguish. This type of
failed start is always followed by GT trip. When flames extinguish, the 3-way valve receives the
signal “Flame out” from the flame monitor and is returned to the fuel oil drainage setting.
These solenoid valves are equipped with limit switches.

During GT operation at least one valve must be closed in order to avoid the hot gas flow from
combustion chamber to fuel oil drainage. In case both valves are opened to the oil discharge position
for GT speed > S.TURB.21 a GT Trip is initiated and the consequent alarm: “Fuel oil drainage valves
not closed” is issued.
Each time the gas turbine is shut down, including after failed starts, both solenoid valves are
energized, i.e. actuated to their oil drainage settings, when speed drops below S.TURB.21. After a
failed start, oil flows via connection 111A into disposal system (not included in this description).
At speeds below S.TURB.21 it is ensured that pressure does not become excessive when draining oil
from the combustion chamber and thus that oil and air cannot flow into the leakage oil tank at an
impermissibly high velocity. To ensure that all unburned oil collecting after a failed start has
sufficient time to drain out of the combustion chamber, it is not possible to restart the gas turbine
until monitoring period K.ENTOEL.01 has elapsed.
At speeds below S.TURB.05 the solenoid valves can be actuated manually. This function allows to
drain the wastewater after the compressor cleaning. In this case, the solenoid valves MBA22AA001
and MBA22AA002 must be positioned by manual command to their drain settings.
Page 3 of 3
23.03.17
P&ID FUEL OIL SEAL AIR COOLING SYSTEM
In addition see

Page 1 of 1
P&ID FUEL OIL SEAL AIR COOLING SYSTEM TGO2-5000-E00000
06.10.14
For Construction.
FUEL OIL SEAL AIR COOLING SYSTEM
The fuel oil burner is foreseen to be cooled by cooling air taken from the GT compressor when it is
not operated with fuel oil. This is necessary both to cool the burner and to avoid hot gas back flow
which can lead to a hot gas recirculation among the burners.
The purpose of the seal air cooling system is to ensure that the sealing air to the burner maintains a
certain temperature level (T.SPERRL.04) 1.
Then, the cooled air reaches the fuel oil burners via the seal air ball valves, refer to section TGO2-
3005.
This system consists of an air-air heat exchanger. The ambient air is used to cool the compressor
discharge air by means of several fans. In order to achieve a sufficient level of redundancy 3 x 50%
fans are used.
The ambient air is filtered by MBH40AT001 and then it passes through the air-air heat exchanger
MBH40AH001 by the 3 x 50% fan system (MBH40AN001 / 002 / 003) and then it is discharged to the
atmosphere.
The non-return valves MBH40AA201 / 202 / 203 avoid air recirculation between the fans.
The temperature of the cooled seal air is measured by the three double-resistance thermometers
MBH40CT101/102/103 that are located on the pipe downstream of the cooler.
Any condensation which forms due to temperature decrease upstream or downstream of the cooler
is led to a drain line which is permanently open.
The orifices MBH40BP001 (upstream of cooler) and MBH40BP002 (downstream of the cooler) are
installed in the drain lines to ensure that only a small amount of air from the seal air line escapes via
these drain lines during operation. This additionally ensures that no cross flow of air can occur
between the drain lines.
Check valve MBH40AA204 prevents reverse flow of fuel oil vapours (caused by the stack effect)
during GT outages or turning gear operation which could otherwise flow in the reverse direction
through the drain line into the seal air system and be drawn into the GT.
1
The manual valve MBH40AA281, in the seal air cooler BYPASS line, is fixed in a proper position during
commissioning operations by Ansaldo Personel to guarantee the required seal air temperature T.SPERRL.04
Page 1 of 3
FUEL OIL SEAL AIR COOLING SYSTEM, DESCRIPTION TGO2-5001-E70000
16.11.16
Operating conditions
The below table summarizes the status of the seal air system:
Table 1 : Fan activation
GT operation Fan Seal air needed by:

system
status
FO-DIFFUSION ON FO-premix burners
FO-PREMIX OFF None
Fuel change over (FO-FG) ON FO-premix burners
FG operation ON FO-diffusion and FO-
premix burners
The fans must remain in operation during the fuel change over.
At first, when the fan system is activated, only fan 1 is in operation.

When the air temperature is > T.SPERRL.04, then the fan 2 is put in operation.
In order to change the operating status of the working fans and to assure a certain changeability
between the different fans, every 24 hours it must automatically switch on also the third fan
according to the following table:
Table 2 : periodical switch over between fans
Operation: 0 – 24 h 24 – 48 h + 48 – 72 h +
K K
Fan 1 ON OFF ON
Fan 2 ON ON OFF
Fan 3 OFF ON ON
The above cycle is repeated after 72 h operation.
When the GT is tripped or shut down the above time is reset and the time counter starts from the
beginning with the 0-24 h column.
For each fan, in case of command ON and the feedback status “fan ON” is not available, then the fan
shall be considered faulty and the corresponding alarm issued. The control is then switched to the
next fan.
Page 2 of 3
16.11.16
The average of MBH40CT101A / 102A/ 103A is used for fan control and protection:
Control
§ In case the average is 30°C below the set point value T.SPERRL.04, the second fan is switched
OFF and operation will continue with one fan only.
§ In case the average is 30°C over the set point value T.SPERRL.04, all 3 fans are switched ON.
Protection
§ In case the cooled air temperature, at each measuring point, is below the value T.SPERRL.01
(in a 2 v 3 logic), an alarm is issued: seal air temperature LOW.
§ In case the air temperature, at each measuring point, exceeds the value T.SPERRL.02 (in a 2 v
3 logic), an alarm is issued: seal air temperature HIGH.
§ In case the air temperature, at each measuring point, exceeds the value T.SPERRL.03 (in a 2 v
3 logic), an alarm is issued: a GT trip is issued after 5 seconds delay.
Tapping point for pressure (MBH40CP401 / 402) and temperature (MBH40CT404) are available in
case of need.
Page 3 of 3
16.11.16
P&ID ROTOR DISPLACEMENT SYSTEM
(RDS)
In addition see

Page 1 of 1
P&ID ROTOR DISPLACEMENT SYSTEM TGO2-6000-E00000
14.11.14
For Construction.
For Construction.
ROTOR DISPLACEMENT SYSTEM (RDS) SYSTEM
A gain in efficiency and an increase in power output can be obtained from Gas Turbines when the
rotor is shifted against the direction of flow. Through this action the gaps between turbine blades
and the casing become narrower, and the gaps in the compressor are increased accordingly but the
sum of the two effects produces an increased GT efficiency and power output.
The design of thrust bearing permits axial displacement when a hydraulic system supplies fluid to
corresponding cylinders and axial stops limit rotor displacement in the primary and in the secondary
displacement direction, see figure 1.
The shifting may be performed only when the GT is sufficiently heated (time K.HSO.04 after reaching
rated speed).
Main
channel
Secondary channel
Figure 1. RDS system: main and secondary channel
For a reliable function of the RDS system an operating pressure between 160-180 bar is required. Therefore a
separate hydraulic supply unit is used. The fluid is lube oil taken from the delivery side of the lube oil supply
feed line. The shifting may not be effected too quickly (>1,5s) in order that the mechanical loading on the
bearing structure may not grow too rapidly. Specifically defined shifting time can be established only if the
system has been vented. For this reason the system must always be completely filled with hydraulic fluids (lube
oil) - each channel of the axial bearing is fitted with a feed and a return .
To maintain at a low value the flow rate of the hydraulic fluid (lube oil) and also the load on the pump, as well
as to avoid a too early clogging of the filter, the return is locked so that in the RDS system no continuous oil
circulation takes place.
In order that a change of the hydraulic fluid (Lube oil) may be possible, and a too high heating be avoided ,
during the GT operation it shall be provided that a regular change of the hydraulic fluid (flushing) may take
place. Only one change is designed for the activated channel in order to restrain a possibly occurring frictional
Page 1 of 11
RDS SYSTEM, DESCRIPTION TGO2-6001-E70003
27.04.17
action on the RDS piston seal. Moreover, flushing also serves to remove possible air trapped and as a functional
test for the accumulator and the instrumentation.
Pumps and pressures

Two pumps (MBA51AP001 / MBA51AP002) are used to boost the lube oil pressure at 160 ÷ 180 bar.
During start up of the RDS system both pumps are switched ON, during RDS operation only one
pump is used.
The running pump shall be selected by a manual pre-selection module.
Upstream each pump there is a manual isolating valve (MBA51AA251 / MBA51AA252) for revision
purposes.
Each valve is equipped with a OPEN limit switch. The pumps may be switched on only if the related
manual valve is in open position.
Downstream of each pump there is a pressure switch (MBA51CP001 / 002) to check whether the
pumps start running regularly and build up adequate pressure.
Filtering
Each RDS Pump MBA51AP001/002 has an oil filter downstream MBA51AT001/002 equipped with a
differential pressure switch MBA51CP003/004 to monitor the contamination state. In case of
intervention of the differential pressure switch, an alarm is issued: RDS filter clogged.
Accumulators
The two accumulators MBA51BB001/BB002 have the following functions:
 They stabilize pressure in the system during operating phase;

 On fire protection trip, the emergency lubrication pump is kept in operation; in this case it is
still possible to shift the rotor axially with the aid of the pressure accumulator;
 Accumulators are used also, during the flushing phases, to ensure the required pressure in
the circuits.
Page 2 of 11
27.04.17
Oil supply to main and secondary channel
To admit pressure to the main and secondary channel or to remove a load from it, solenoid valves
are provided in the feed and backflow lines of the main (MBA53AA001/002/003) and the secondary
(MBA53AA004/005) channel. Every solenoid valve is fitted with a linear limit switch for the closed or
open valve position.
The solenoid valve MBA53AA002 is situated in the feed line – main channel.
When it is opened, the main channel chamber is equipped with oil and then piston is moved. The
solenoid valve MBA53AA003 is also situated in the main channel feed, in parallel with MBA53AA002.
It is opened when the main line is to be vented or flushed but it can’t be used for shifting the shaft,
since no volume flow control valve is connected downstream.
The solenoid valve MBA53AA006 is situated in the main channel feed downstream of the solenoid
valves MBA53AA002 and…003. It represents a redundancy to both the solenoid valves and it
prevents the RDS from being activated, in the event of fault of both of the previous valves.
The solenoid valve MBA53AA004 is situated in the secondary channel feed. It is open when the
secondary channel flushes or shall be stopped.
The solenoid valve MBA53AA001 is installed in the back flow from the main channel to the
lubrication oil tank.
The solenoid valve MBA53AA005 is situated in the secondary channel return line. To vent, flush and
run-in the secondary line it is open, and it is closed to stop the secondary channel.
To limit the process speed and to ensure that allowed shaft displacement times are achieved, the
following flow control orifices are installed: MBA53AA281/282 downstream of the solenoid valves in
the supply line to the respective RDS piston chamber and MBA54AA281/282 upstream of the
solenoid valves in the return lines.
All solenoid valves and flow control orifices are located in a single overall control block mounted on
the supply station.
Pressure limiting valves MBA54AA191/192 are provided to guard against impermissible pressure
increases in the piston chambers; if they react then oil is routed out directly to the lube oil tank.
In addition, a third line directly connected to the lube oil system is provided. The line is required to
supply a minimum amount of oil to the RDS channels at interval turning when RDS pumps are
switched off. The line is equipped with an oil filter downstream MBA52AT001 with a differential
pressure switch MBA51CP001 to monitor the existing contamination state.
To prevent reverse flow from RDS channels, a check valve MBA53AA201 is placed downstream the
filter.
The MBA53AA005 is used for venting, purging moving the shaft to the reverse position.
Pressure monitoring
The RDS pressure in the common line upstream the solenoid valves is monitored by pressure
transducers MBA51CP101 / 102 and MBA51CP103 as spare.
When the RDS system is operating, the pressure in the main chamber and in the secondary chamber
is monitored respectively by pressure transducers MBA53CP101 / 102 (main) and MBA53CP103 / 104
(secondary); MBA53CP105(main) and MBA53CP106 (secondary) as spare.
Page 3 of 11
27.04.17
Shaft position monitoring
Two linear measuring transducers MBA10CG101 / 102 are mounted on the compressor bearing cover
to measure the axial position of the rotor shaft and the shifting caused by the RDS system.
Page 4 of 11
27.04.17
Pressure monitoring
RDS system pressure
The pressure switches MBA51CP001 and MBA51CP002 monitor that the running pump is working
and the downstream pressure is rising. If this is not the case, automatic switch on to the stand-by
pump occurs.
During GT operation, the pressure in the RDS system is monitored by pressure transducers
MBA51CP101, MBA51CP102 (MBA51CP103 is spare). The normal operation pressure level ranges
between P.HSO.04 and P.HSO.10.
The operator can pre-select the operating pump. When:
- RDS pressure is < P.HSO.04: the pre-selected pump is automatically switched ON
- RDS pressure is > P.HSO.03: the running pump is automatically switched OFF.
In case of pressure below P.HSO.04 an alarm is issued.
If the system pressure falls below P.HSO.09 the GT Shut down occurs since below a certain system
pressure it is not ensured that the rotor is in a correct position.
Pressure in the main and secondary chambers

Pressure transducers MBA53CP101 / 102 and MBA53CP103 / 104 monitor the pressure in the return
line of the main and secondary channel. In stationary condition these pressure values correspond to
the chamber pressures of the main and the secondary channel.
The following events may occur:
 High pressure in the not-loaded chamber: bearing stress condition
When a channel is not activated, the pressure must be low. A pressure increase can indicate a
bearing stress and a damage.
In case of pressure > P.HSO.07 all feed valves in the main and secondary channels are closed and the
return valves opened. If 10s after opening the return valves, no pressure reduction still takes place,
then a GT trip is issued and corresponding alarms issued.
Page 5 of 11
27.04.17
 High pressure in the loaded secondary chamber
In case of special conditions during GT start up (cold bearing and cold lube oil), it is possible that
pressure in the secondary chamber increases due to thermal expansion of the lube oil. The following
actions must be taken:
If the pressure is > P.HSO.100 for more than 10 s, the secondary return valve must be opened and
the alarm issued. The valve is closed again when the pressure is < P.HSO.101.
In case the pressure is > P.HSO.102 for more than 10 s, a GT Trip shall be issued for too high pressure
in secondary chamber.
 Low pressure in the loaded chamber
When a channel is activated, the pressure must be higher than P.HSO.09 otherwise a defined axial
position of the rotor is no more guaranteed.
In case of pressure < P.HSO.09, an alarm is issued.
GT trip occurs in case of fault of two pressure transducers in return main line or in return secondary
line.
When low pressure is in the main channel (RDS ON), the RDS system shall be manually deselected
by the operator
When low pressure is in the secondary channel (RDS OFF), the RDS system shall be manually
selected by the operator
Warning:
In case the RDS selection is not possible or not desired, the GT shall be operated as much as possible
in a stable way (i.e. avoid sudden load change)
Page 6 of 11
27.04.17
Position monitoring
The axial position of the shaft is monitored through the linear transducers MBA10CG101 / 102.
When the RDS is activated (main channel pressurized), the shaft shall reach the proper position
G.HSO.02 within the time K.HSO.05 otherwise a deactivation of the RDS system occurs.
Note: in case the position is attained too quickly (<K.HSO.10) an alarm is issued but automatic
deselection of RDS does not occur.
When the RDS is de-activated (secondary channel pressurized), the shaft shall reach the proper
position G.HSO.01 within the time K.HSO.11 otherwise the RDS pre-selection is reset and an alarm is
issued.
Note: in case the null position is attained too quickly (<K.HSO.10) an alarm is issued and the RDS pre-
selection is reset.
Warning:
In case of too quick movement of the shaft (to G.HSO.01 or G.HSO.02 position), a bearing damage
can occur.
Should the shaft during the operation with deactivated RDS move away from position G.HSO.01 (i.e.
actual position > G.HSO.01), an alarm is issued.
Before this event, however the low pressure in the secondary return line should have responded.
In case the position is > G.HSO.01 before time K.HSO.04 has elapsed from GT startup, a GT Trip
occurs.
Should the shaft during the operation with activated RDS move away from position G.HSO.02 (i.e.
actual position < G.HSO.02), an alarm is issued. Before this event, however the low pressure in the
main return line should have responded.
GT Trip is also issued in case of fault to both (2 v 2) position transducers.
Page 7 of 11
27.04.17
GT OPERATION
GT Start Up
A release for GT start is the “RDS system READY for GT Startup”.
This means that all the following conditions are to be fulfilled:
 RDS Pump1 OR Pump2 available for start
 MAIN CH RET vlv, MAIN CH FEED vlv1/vlv2, SEC CH FEED vlv, SEC CH RET vlv
NON in ALARM
Before any GT start up, the main and secondary channels are purged in order to remove any air via
the return line to the lube oil tank.
GT Load operation
The rotor can be shifted to narrow the gap (to position G.HSO.02) by activating the RDS. Activation of
the RDS is possible only 1 hour after the synchronization (time K.HSO.04). Loading / unloading
according to the allowed gradients can be performed with the operating RDS system.
Page 8 of 11
27.04.17
Load rejection and GT fast unloading
In case of load rejection the RDS system is deactivated with delay K.LAW.300 after the detection of
the load rejection.
A fast unloading is equivalent to a load rejection. It is considered fast unloading when:
- The load gradient is > JK.HSO.01 (load change of about 0,1%/s)
AND
- The load reduction is > J.HSO.01 (load difference of about -6%).
In the above cases, the RDS is automatically deactivated.
In case the rotor is not in the NULL position G.HSO.01 after delay K.HSO.11, a GT trip is released.
When the RDS has been deactivated due to a load rejection, it is necessary to wait that K.HSO.04
(e.g. 1 h) has elapsed before a new activation of the RDS.
GT Shut Down
The RDS system can be maintained ON during shut down. It is automatically disconnected after the
fuel stop valve(s) closure when the proper speed for disconnection is reached.
GT Turning gear operation and standstill

During turning gear operation for cooling, the RDS system is under pressure and the secondary
chamber is pressurized.
In case of fault to the RDS system, the turning gear operation is performed also with the
depressurized RDS system. However in this condition a GT start is NOT ALLOWED since the shaft shall
be in the NULL position before attempting a GT start up.
In case of interval turning and GT standstill the RDS system is not pressurized.
Page 9 of 11
27.04.17
Maintenance on the RDS system
Warning:
In case it is required to totally exclude the RDS system with the GT at standstill or in turning gear
mode in order to perform maintenance job, it is necessary to switch off manually all pumps, to
deactivate all manual sequences and to interlock pumps (otherwise they will start again due to
the low pressure protection logic).
To perform maintenance job, all system shall be TOTALLY DEPRESSURIZED.
The following actions are required (necessary fundamental condition: GT speed < S.TURB.05):
1. Switch off the RDS pump (if just in operation) and disconnect the pumps at the switchboard by
smooth action (in order to avoid undesired automatic start).
2. Switch off the RDS-SEQUENCE
3. Open Secondary channel return valve (MBA53AA005)
When the pressure in the RDS system has decayed it is possible to perform work on the RDS system.
When the lube oil has been removed from the RDS system, after work completion, the RDS system
must be refilled with oil according to next paragraph.
After that, during cool down turning, the RDS system is pressurized.
When the RDS system is filled with lube oil, the RDS-Sequence shall be switched on for automatic
operation. This action activates automatically the shut down branch of the RDS sequence. Since
during the depressurization of the system the RDS pressure has dropped below P.HSO.02, the main
and secondary channels are at first vented and purged. Then the solenoid valves are positioned by
the RDS sequence in order to bring the shaft in the NULL position and the secondary channel is
pressurized.
NOTE: The valves MBA53AA001, MBA53AA002, MBA53AA003, MBA53AA004, MBA53AA005 should

be cleaned and the electrical connections inspected every Minor Inspection or every time the
pressurization time is longer than normal.
Page 10 of 11
27.04.17
Additional warnings
The accumulator pre-charge is monitored by the control system via the filling time of the
accumulators. The accumulator pre-charge shall be controlled at regular intervals.
The closure of not used optional tapping points must be checked at regularly maintenance activity
in order to avoid potential leak.
Before activating again the RDS system when the RDS system has been deactivated due to a fault,
it is necessary that the fault event has been removed.
Warning:
In case of alarm whose origin may indicate a potential bearing damage or piston damage, the GT
can be restarted only after approval of the Ansaldo Energia, Gas Turbine Service Department
(GSE).
Page 11 of 11
27.04.17
P&ID PNEUMATIC STATION SYSTEM
In addition see

Page 1 of 1
P&ID PNEUMATIC STATION SYSTEM TGO2-7000-E72000
14.11.2014
For Construction.
PNEUMATIC STATION SYSTEM
The pneumatic station supplies the compressed air used as the working medium for the pneumatic
actuators (blow off valves, (HP Purging system and Fuel Oil Back Purging System in case of dual fuel)).
A LPC (Local Panel Control) is responsible for switching ON / OFF the compressors and to check the
system, while a general supervision of the system is in charge of the GT Control System.
Note:
In the following the system is described only concerning its operation in relation with the gas turbine
requirements. Details of single components are given in the Outside Vendor Parts (Sub Supplier
documentation).
Construction and Function

The pneumatic station essentially comprises two redundant subsystems, both of them supplying air
to fill a pneumatic air tank MBX24BB001. Both compressor subsystems have identical design. The
system is completely redundant, i.e. the capacity of each compressor subsystem is sufficient to
ensure a reliable supply of compressed air to the GT.
The air is compressed using the compressor (MBX21AN001 or MBX22AN001). A first coalescent filter
is located downstream of each compressor (MBX21/22AT001). The liquid condensed out of the air is
drained into drains collecting tank MBX23BB001 via drains traps MBX21/22AA401.
The air is then dried by means of an air dryer (MBX21/22AT003). Any other liquid form, is condensed
into drains collecting tank MBX23BB001 via drains traps.
The final filtration is via high efficiency compressed air filters (MBX21/22AT002). The liquid
condensed out of the air is drained into drains collecting tank MBX23BB001 via drains traps
(MBX21/22AA402).
Condensate accumulating in the condensate tank MBX23BB001 is then passed into a vacuum
disposal tank.
Any compressor is equipped with a pressure switch for internal control (see paragraph “Internal loop
control”) and a safety relief valve (MBX21/22AA191) in order to discharge any overpressure.
The compressed air streams delivered by the two compressor subsystems are sent to the air tank
MBX24BB001 via shutoff valves MBX21/22AA251.
The compressor subsystems can be shutoff independently of one another using the two shutoff
valves. This makes it possible to carry out maintenance job on the pneumatic station while the GT is
in operation.
The system is equipped also with a local differential pressure indicator and a drain discharger.
Compressed air accumulator MBX24BB001 is used to store the cleaned and dried control air. Local
pressure gauge MBX24CP501 displays the pressure in the accumulator.
There also four pressure switches for monitoring and alarm purpose (MBX24CP001/004):
Page 1 of 2
PNEUMATIC STATION SYSTEM, DESCRIPTION TGO2-7001-E72002
19.11.14
Ø In case of high pressure at MBX24CP004 (e.g. > 8.5 bar) a corresponding alarm is issued.
Ø In case of low pressure at MBX24CP003 (e.g. < 6 bar) a corresponding alarm is issued.
Ø In case the pressure falls below the set point of MBX24CP001/002 (e.g. 5.5 bar) in a 2 out logic
with MBX24CP003 (2 v 3 logic), a GT trip is issued.
The set point causing a GT trip is set in such a way that, even with this low pressure (5.5 bar) the air
pressure is sufficient to move the blow off valves to the safety position (open).
Internal loop control

The open-loop control for the pneumatic station represents a black box for the GT control system.
The GT control system receives from the local internal logic of the compressors skid the following
signals:
§ Compressor ON/OFF
§ Compressor FAULT
and those signals are displayed in the control and monitoring system. Once the pneumatic station
has been started, no switching operations are required for its operation.
Compressor fault signal represents a cumulative fault signal generated in fail safe manner (e.g. it
includes also the loss of supply and should be generated with circuits normally energized that give
alarms by de-energizing the output circuit) .
After a loss of power supply during the pneumatic station in operation (i.e. compressors on or ready
to start according to the system pressure) each compressor is capable to start again when the power
supply is restored without any manual intervention of the operator.
Warning:
In case of loss of power supply the compressors are switched off. But they go automatically to
service (i.e. running in case they were running before the power supply interruption) when power
supply is again available.
Pressure switch MBX21CP001 switches ON compressor MBX21AN001 when pressure decreases

below 6.7 bar and it switches it OFF when pressure is > 7.5 bar.
Pressure switch MBX22CP001 switches ON compressor MBX22AN001 when pressure decreases
below 6.7 bar and it switches it OFF when pressure is > 7.5 bar.
With the slightly different setting of the pressure switches MBX21/22CP001 it is ensured that only
one compressor is functioning when small leakage are detected in the system and that both
compressors are operating when the compressed air need is greater.
In this way it is ensured a complete and independent redundancy of the compressors.
See in addition the manual of the pneumatic station Manufacturer and follow all the
safety instruction.
Page 2 of 2
PNEUMATIC STATION SYSTEM, DESCRIPTION TGO2-7001-E72002
19.11.14
P&ID PNEUMATIC ACTUATORS FOR BLOW OFF SYSTEM
In addition see

Blow off system description TGO2-4411
Page 1 of 1
P&ID PNEUMATIC ACTUATORS FOR BLOW OFF SYSTEM TGO2-7002-E72000
16.06.2016
For Construction.
P&ID AIR INTAKE SYSTEM
In addition see

Page 1 of 1
P&ID AIR INTAKE SYSTEM TGO2-8000-E00000
17.11.14
For Construction.
AIR INTAKE SYSTEM
The air intake system has the purpose of conveying the combustion air to the compressor inlet in
order to ensure:
- the required filtering degree in the relevant environmental conditions;
- the observance of the contract sound emissions by the gas turbine;
- the right distribution and regularity of the air flow rate at the compressor inlet and its regular
fluid dynamic operation.
The air inlet system supplies filtered intake air with a specific purity grade to the compressor. The air
intake system consists of the following main components:
- Weather Hoods protects the filtering cartridges against damages caused by foreign objects,
excessive rain water or direct exposure to the sun
- Droplet catcher has the purpose to prevent the filter to be clogged by any coarse dust or/and
liquid airborne particles
- Self cleaning filtering section with pulse jet (*)
- Anti-ice system
- Insect Screen
- Anti-Implosion doors
- Transition with Blow in Door
- Inlet Silencer
- Bend
- Expansion joint
- Vertical duct with plenum
- Shut off damper
- Stairs and service footbridges
- Support structures
- Electrical hoist for filtering element lifting
Air enters the filter, then the inlet silencer, the bend, the vertical duct and the plenum till the
compressor inlet. Air is compressed and then it enters the combustion chambers to take part to the
combustion process and to the following expansion in the turbine.
An air dryer is integrated in the air inlet system, it has the task of reducing the air humidity
downstream intake air isolating valve (damper) during a long GT shut down in order to preserve the
turbine from humidity
(*) FOR MORE INFORMATION ON THE TYPE OF FILTERING SECTION REFER TO AIR INTAKE SYSTEM
MANUFACTURER O&M MANUAL (Outside Vendor Parts)
Page 1 of 4
AIR INTAKE SYSTEM, DESCRIPTION TGO2-8001-E71558
12.04.17
Function
Independently on the type of the filtering system the following measures are taken across the
filtering system.
Pressure upstream of the filtering section is measured by MBL10CP101.
The total differential pressure on the filtering system is monitored by the pressure transducers
MBL11CP101, and by the differential pressure switches MBL11CP001/002 that have protection
purposes. It is available another differential pressure transducer MBL11CP102, for alarm only.
A pressure switch MBL10CP005 is located upstream the pulsejet skid to monitor compressed air
pressure; in case of LOW pressure (> 4 bar), an Alarm is issued.
The following thresholds are used:
a. When exceeding the first limit value P.AIRFILT.01 an alarm is issued. A manual intervention by
operator is required, i.e. by checking the reason for abnormal increase in the pressure drop on
filters (fault in the pulse system or filter elements deterioration).
b. When exceeding the second limit value P.AIRFILT.02 another alarm is issued.
Warning:
The operator shall intervene on the filtering system when exceeding the limit value
P.AIRFILT.02. Filter replacement and/or fault acknowledgment of the system is necessary.
c. a GT protection shut down must be activated in case of intervention of the differential pressure
switches (e.g. MBL11CP001 /002 > max) and exceeded the third limit value P.AIRFILT.03 of the
transmitter in logic 2 out of 3. The GT shut down is activated after time delay K.AIRFILT.01.
d. a runback command is generated if the same 2 out of 3 logic is activated for more than
K.AIRFILT.02
Note: The differential pressure alarms and intervention are not related to the IGV
actual position.
Page 2 of 4
12.04.17
Warning:
One the GT shut down program has been activated by the air intake system protection
(point c), a memory is set ON: before the next GT start-up the operator must reset that
memory from the keyboard.
The signal of MBL10CP101 is displayed for monitoring purpose only.
Filtering section with pulse jet system

The single stage self-cleaning filtration system is provided by conical and cylindrical high efficiency
filter elements, grouped in modules.
Filters are automatically cleaned by the pulse jet system during the turbine operation when the
pressure drop is up to ~450÷550 Pa, Δp is verified by MBL10CP102.
The relative humidity, the temperature and the pressure of the inlet air are measured by the
respective transducers MBL10CM101, MBL10CT101 and MBL10CP101.
The filters are cleaned in counter-flux by a compressed air jet. Each filter is reached by a nozzle of the
air network positioned behind the hole that leaves the air to enter into the cleaned zone. Each
module has an air accumulator connected to air feeding pipe avoiding that pressure varies too much
during valve opening.
A set of valves is foreseen for each accumulator (MBL10AA101…1##, MBL10AA201…2##,

MBL10AA301…3##, etc.). The cleaning sequence, that takes less than one hour, starts when the
pressure drop evaluated across the filters is higher than a selected value (about 550 Pa), after
cleaning the pressure drop is usually less than 450 Pa. It is possible to isolate each accumulator by a
valve.
The cleaning sequence starts from the higher levels of the filter house, to the lower ones. The dust is
collected on the bottom of the filter chamber and extracted by fans (MBL21AP001÷ MBL21AP…).
Other components
Downstream of the filtering section, the filtered air pass through the intake duct to the silencer
(MBL20BS001) which has a set of sound absorbent vertical splitters.
After silencer, a flexible connection between the elbow and the straight duct is provided.
The straight duct between the connection joint and the intake diffuser is constructed to incorporate
the intake damper (MBL20AA001).
The compressor intake damper (MBL20AA001) has the purpose of isolating the compressor and
avoiding humidity to increase in the compressor section. It is equipped with limit switches for the
Page 3 of 4
12.04.17
open position (MBL20CG002A/004A/002B/004B) and for the closed position
(MBL20CG001A/003A/001B/003B).
The intake damper is a double blade design with electrical drive assembly. Each blade is equipped
with 4 limit switches. Refer to the applicable PID order related.
A faulty position NOT OPEN of the intake damper during GT operation causes a GT trip.
The damper is closed 2 hours after the GT shut down and it is opened with the GT start-up command.
GT start-up is prevented in case of not open signal from the intake damper.
The intake system includes also implosion doors (whose numbers depend on the GT model, the air
intake system type and air intake system manufacturer). Each implosion door is equipped with 3
limit switches for the open position.
The closed status of implosion doors is a release for the GT start up.
In case of OPEN position detection of at least one implosion door (logic 2 v 3 with the open limit
switches) a GT TRIP is automatically issued.
Note: the implosion door opening is in principle avoided due to the differential
pressure monitoring on the overall filtering system. In fact the limit switch of
the implosion door is set in order to allow the intervention of the shut down,
due to high differential pressure, before the opening of the implosion door.
Page 4 of 4
12.04.17
ANTI-ICING SYSTEM
The anti-icing system has the task to avoid ice formation on the filtering section and on the first stage
of the compressor.
Connection for anti-icing system is provided upstream of the filtering section.
Function
The anti-icing system is constituted of a circuit of compressed air taken at the delivery side of GT
compressor from flange 36 and delivered on the intake system downstream of the weather louver.
Hot air (up to a max. of 400 – 500°C) has the function of increasing the inlet air temperature of about
5°C when there is the possibility of ice formation.
Anti-icing system is activated by opening the stop valve MBL13AA051 when the outside temperature
is in the range from –5°C to +5°C and, at the same time, humidity is higher than 80%.
To detect ambient humidity signals from MBL10CM101/102 are used and to detect ambient
temperature signals from MBL10CT101/102 are used.
The control valve MBL13AA151 is positioned in order to obtain a temperature increase of 5°C in
temperature measured upstream of the compressor. By the 5 °C increase in temperature, ice
formation is avoided in any point of the air circuit taking into account the air depressurization and
vortex formation inside the ducts.
The control valve is positioned depending on outside temperature and on the mixture temperature
in order to establish the correct air amount flowing from compressor.
Anti icing pipes are thermally insulated where accessible to avoid personnel injuries due to high
temperature.
If after a fixed delay time (K.ANTICE.201, e.g. 10 min) after the anti-ice receives the command ON,
the activation has not yet take place, then GT shutdown is carried out and relevant alarm issued

Air intake system TGO2-8001
Page 1 of 1
ANTI-ICING SYSTEM, DESCRIPTION TGO2-8002-E00000
13.10.16
P&ID EXHAUST GAS SYSTEM
In addition see

Page 1 of 1
P&ID EXHAUST GAS SYSTEM TGO2-9000-E00000
17.11.14
For Construction.
EXHAUST GAS SYSTEM
The exhaust gas system has the scope to convey the hot gases to the HRSG (Heat Recovery Steam
Generator) or to stack according to plant configuration.
Function
The differential pressure transmitters (e.g. MBR20CP101/102/103) are used in logic 2 out of 3
in order to:
- issue an alarm in case of exceeding first limit value P.EXH.01
- issue a GT protection shut down in case of exceeding second limit value P.EXH.02.
issue a GT trip in case of exceeding a third limit value P.EXH.03. Reason: in case of
sudden collapse of exhaust system, a GT trip is the only possible solution for
protecting the GT against damage.
Warning:
In case a fast increase in the exhaust pressure drop, the operator is suggested to perform a load
reduction or a GT shut down, according to the pressure increasing gradient, since something
anomalous is likely to occur in the exhaust system. Such faults (e.g. boiler or stack rupture) are
quite rare but even this possibility shall be kept in mind.
Moreover tapping points MBR20CP401/402/403/404 are provided.

Downstream the turbine, normally a set of 6 thermocouples is located between the diffuser and the
HRSG.
The thermocouples MBR20CT101 to CT106 (or up to CT110, according to the plant configuration) are
used for monitoring purpose.
In case of simple cycle, those thermocouples are normally not provided, refer to the applicable PID
order related to state the presence and the number of the thermocouples.
Downstream there is a drain valve MBR20AA401 to remove condensation
Page 1 of 1
EXHAUST GAS SYSTEM, DESCRIPTION TGO2-9001-E00000
05.07.17
OPERATION
DUTIES OF THE OPERATING PERSONNEL
Warning:
The GT Manufacturer is not responsible for disturbances and the consequences of these
disturbances which are due to operating the unit beyond the contractual limits or the limits set and
agreed during acceptance test measurements.
The manufacturer shall assume that operating personnel are familiar with the functional principles of
the turbine and all related auxiliary systems which influence normal operation.
Operating personnel should also be familiar with the information contained in this gas turbine
operating manual, the P&IDs, piping arrangement, the location and purpose of the supervisory and
protective equipment.
During gas turbine operation, operating personnel shall check the measurements displayed on
screens and indicated by recorders at regular intervals to ensure their plausibility.
At least once a shift, operating personnel should inspect the gas turbine and its auxiliary systems to
check for leakage, abnormal noise and correct instrument readings.
If operating personnel observe abrupt changes in operating conditions which are not related to
changes of power output or the mode of operation, the technical supervisor should be informed
immediately so that the cause can be pinpointed.
If operating personnel feel that the safety of the gas turbine or plant components are at risk, they
should not delay in initiating the shutdown program or turbine trip.
To prevent operating disturbances and faulty indications, all measuring instruments and supervisory
equipment shall be carefully maintained and calibrated at regular intervals. The manufacturer
recommends that the power plant operator keeps an accurate and complete record of the gas
turbine plant operating history. These data sheets can help to carry out comparison and statistics on
gas turbine availability and the outage analysis of gas turbine components.
Extraordinary occurrences and observations made during gas turbine operation and work performed
during plant outage must be recorded and should be transmitted to the manufacturer as necessary.
Page 1 of 1
DUTIES OF THE OPERATING PERSONNEL TGO3-0030-E00003
17.11.2014
GENERAL START UP CONDITIONS
The checks and inspections listed in this chapter shall be performed with the gas turbine plant is to
be restarted after an extended shutdown period (e.g. major inspection, major repair or
preservation).
If there is only a short interruption in operation, e.g. shutdown over the weekend, extended turning
gear operation, minor repair or shutdown for maintenance work, these start up preparations are not
necessary.
Lube oil system MBV

• Inspection of the cleanness of the lube oil return strainer in the lube oil tank.
Note: it is necessary to open the manhole cover on the tank to perform this inspection.
• In the event of lube oil replacement, the quality and the quantity of the oil shall be checked.
• Visual inspection of the piping flanges and unions to ensure they are correctly installed and leak-
tight.
• Test run of the lube oil pumps. Inspection for abnormal vibration, noise and power consumption.
The pressure in the lube oil tank shall be 20 – 40 mm Hg with one vapour extractor switched on
(this test can be performed using a simple U-tube pressure gauge).
• Check to ensure that the shut off valves upstream of the pressure sensing instruments are open.
The shut off valves to the inspection connections must be closed (as a rule applied to valves
upstream of pressure switches and pressure transducers).
• Secure test connections with caps.
Air intake system MBL

• If filter elements were replaced, these shall be checked to ensure correct seating and securing.
• Check implosion doors in the filter compartment to ensure freedom of movement and leak
tightness. Access doors must be leak-tight and should be locked.
• Damaged paint and the formation of uniform corrosion on the clean side of the filter
compartment, in the metal intake duct and in the area upstream of the compressor is not
permissible under any circumstances. The entire air intake area shall be carefully cleaned prior
to start-up.
• Inspection of the compressor damper to ensure correct functioning.
Page 1 of 4
GENERAL START UP CONDITIONS TGO3-0031-E72001
20.11.14
Hydraulic oil system MBX
• Check accumulators for correct precharge pressure.
• Check cleanness of filters.
• Test run of the hydraulic oil pumps. Inspection for abnormal vibration, noise and power
consumption.
• Check to ensure that the shut off valves upstream of the pressure sensing instruments are open.
Blow off system MBA

• Check the air compressors (switch them on separately and check the relief pressure)
• Check accumulation of air in the blow off tank.
• Check opening and closing function of the pneumatically controlled blow off valves and record
the time response.
• Check the limit position signal
Supervisory and protective equipment

• Check readings of the thermocouples, resistance thermometer and temperature sensor. At
standstill, the readings should be on the order of the ambient temperature.
• Inspection of the displayed corrected exhaust gas temperature (TETC) and the exhaust gas
temperature (TET).
• Check the vibration measuring equipment (check the transducer to ensure correct mounting and
electrical connections, check to ensure correct functioning of the indicating and recording
instruments ).
• Visual check of all measuring and indicating equipment (check for state of operational readiness).
Page 2 of 4
20.11.14
Fuel gas system MBP
• Since a pressure test of the entire fuel gas system up to the burners can only be performed at
great effort, the manufacturer recommends a leak test using the gas turbine compressor.
The inspection sequence described below checks for leaks not only in the fuel gas system but also in
the other internal piping systems (where present) and casing flanges, e.g.
a) fuel oil lines up to the stop valves;
b) ignition gas lines up to the check valves;
c) pulse and instrumentation lines (combustion chamber differential pressure, blow off system,
fuel oil leakage line)
The following steps shall be carried out:
- prepare the GT for washing mode,
- remove the flange insulation caps which are to be checked for leakage integrity,
- select washing mode and start up the GT (by SFC);
- After the above mentioned operation have been done, the air from compressor enters
into the fuel gas and fuel oil system in the reverse direction under slight pressure. Any
leak can be located using leakage detection spray or soapy water.
- the washing program is shut off.
• Check to ensure that the fuel gas strainer is clean and intact.
• Check to ensure that the shut off valves upstream of the pressure measuring instruments are
open.
• Check to ensure that the fuel gas lock function is active (the vents must be opened and the stop
and control valves must be closed, the ball valves must be closed too).
• Operation value check of the fuel gas pressure upstream of the fuel gas stop valve.
Ignition gas system MBQ

Perform leakage test of the ignition gas system up to the connection of ignition gas solenoid valve n.
2.
Attention: a leakage test should preferably be performed at an air pressure ¾ of 5 bar. When using
combustible gases, compliance shall be with the general safety regulation.
• Check to ensure leakage integrity of flange connections, valves, measurements connections, ecc.
with a soap solution or a sniffer probe.
• Check to determine whether ignition gas is available at proper pressure.
• Check the ignition gas pressure upstream of ignition gas valve n.2.
Page 3 of 4
20.11.14
• Check proper ignition current at all ignition burners.
Procedure:
- shut off ignition gas system
- simulate ignition speed in control system or bring GT at washing speed
- open ignition gas valve n.2 (ignition is switched on simultaneously)
- pull off ignition caps one after each other and hold directly at the spark plug
- clearly audible and visible sparks must be recognized over to the spark plug.
Fuel oil system MBN

• Perform visual check paying particular attention on flange connections, closed drains and
leaktightness.
• Check fuel filter for cleanness and damage.
• Check the fuel oil injection pump. Inspection for abnormal vibration, noise and power
consumption.
• Test run of the available fuel oil supply pressure upstream of the fuel oil injection pump.
• Check correct venting of fuel oil by observation through sight glass in the venting line.
• Check the draining pipes and solenoids on the combustion chamber for leaktightness.
• Test run of the leakage oil pump, check the level in the leakage oil tank.
Water Systems for Fuel oil (purging MBN and water injection MBU if present)
• Perform visual check paying particular attention on flange connections, closed drains and
leaktightness.
• Check filter for cleanness and damage.
• Check the water pump. Inspection for abnormal vibration, noise and power consumption.
• Check correct intervention of the safety / relief valves in the system.
Page 4 of 4
20.11.14
FUNCTIONAL TEST PRIOR TO START UP
This section contains details on important function tests performed on the gas turbine which must be
carried out after an extended shutdown.
The term extended shutdown shall apply to operating condition, e.g. after a maintenance shut down,
after a major repair or after turbine preservation.
These function tests are not prescribed after a brief shutdown period (e.g. week end shut down,
after extended turning gear operation, minor repair or routine maintenance work) but are within the
scope of decisions to be made by the operator.
To ensure optimal preparation for operation, however, independent of the shut down designation, it
is recommended that a minimum scope of standard function checks are performed, in particular any
weak point identified during operation.
Scope of the function tests

The scope is to actuate manually the equipment that can be manually moved by the GT I&C,
provided that all release conditions are met.
Lube Oil
Switch ON the main oil pump and check the raising lube oil pressure
Switch off the main oil pump and switch ON the auxiliary oil pump and check the raising lube oil
pressure.
Switch off the auxiliary oil pump and switch ON the emergency oil pump. Switch off the pump at the
end of the test.
Switch ON the main lifting oil pump and check the raising lifting oil pressure. Switch off the main
lifting pump
Switch on the auxiliary lifting pump (if present) and check the raising lifting oil pressure. Switch it off
at the end of the test.
Give command OPEN / CLOSE to the turning gear valve and check the response of the position limit
switch.
Intake damper
Give command OPEN to compressor intake damper and check the response of the position limit
switches
Close again compressor intake damper.
Page 1 of 2
FUNCTIONAL TEST PRIOR TO START UP TGO3-0032-E72001
20.11.14
Blow off system
Warning: be sure the blow off tank is filled with compressed air before attempting a start up.
Check the air compressors before the GT start in order to be sure they are able to feed compressed
air at the right pressure.
IGV/CV1 system
Check IGV (and CV1 if expected by the project) are free to move by manual command (set manual
mode). After the check IGV/(CV1) must be put in closed position and reset the auto mode.
Hydraulic Oil
Switch ON one pump and check the raising oil pressure
Switch off the previous pump and switch ON the other one and check the raising oil pressure.
Fuel gas system

Warning: be sure the fuel gas supply is interrupted.
Give command OPEN to the FG stop valve (the stop valve will automatically close after a time delay)
and check the response of the position limit switches. Note: to move the stop valve one hydraulic oil
pump must be put in service. Switch off the hydraulic oil pump at the end of the test.
Fuel oil system

Warning: be sure the fuel oil forwarding system is switched OFF.
Give command OPEN to the FO stop valves (any stop valve will automatically close after a time delay)
and check the response of the position limit switches. Note: to move the stop valve one hydraulic oil
pump must be put in service. Switch off the hydraulic oil pump at the end of the test.
It is suggested to prepare a checklist including all the function tests in advance.
Page 2 of 2
FUNCTIONAL TEST PRIOR TO START UP TGO3-0032-E72001
20.11.14
COOLING PROCEDURE - GENERAL OPERATING INSTRUCTION
The following general operating instructions are provided as a tool for the control console operator
to enable him to recognize any problems occurring in good time and implement the correct
measures at the right time. Furthermore they facilitate enhancement of safety and a certain degree
of problem consciousness.
GAS TURBINE COOLING
After any GT shut down or TRIP, to avoid distortion of casing and rotor (bending), the rotor must be
kept in slow rotation by the turning gear in order to ensure uniform and low flow rate ventilation
through the blading.
This procedure called cooling turning operation (activated by the BHS turning sequence), has to be
maintained for a convenient time (24 hours). After this period of time, turning gear stops and GT
reaches normal STANDSTILL ( speed 0rpm); this correct cooling guarantee no distortion for the GT
shaft.
After long periods of standstill, the shaft is additionally turned briefly at regular intervals (every 6
hours) in order to check freedom of turning. This operation is called interval turning.
See, for more information, Section TGO3-0049
NOTE: in case of normal cooling turning operation, GT can be re-started anytime without damage
also before reach the stand still condition.
In case of fault of cooling turning operation (BHS sequence fault), different scenarios are possible:
1. If the fault can be corrected before the rotor comes to a stop, turning gear operation must
be started immediately. The rotor must be brought to normal turning gear operation and the
requirements for turning gear operation must be fulfilled
2. If the turning gear itself is found to be the cause of the fault, the rotor can be rotated by
means of the procedure “Emergency turning with SFC”. This procedure can be manually
selected by the operator during shutdown in the range of speed 1.4Hz-0.3Hz (see section
TGO3-0034).
NOTE In this case the SFC emergency cooling operation keeps 24hour. No GT restart is
possible during this period
In this case it is absolutely imperative to make sure of the following conditions:
• No damage has occurred (otherwise the damage could be worsened by turning the rotor
with SFC)
• The lube and lifting oil system is operational.
Page 1 of 3
COOLING PROCEDURE TGO3-0033-E70003
07.01.16
3. If also the SFC emergency turning fault or cannot be engaged, GT stop with non correct
procedure. Only in this condition, operator can MANUALLY rotate the shaft according to the
procedure described above (see also TGO2-0610) to avoid damage to the rotor.
NOTE: In this case, if there aren’t damages to the shaft glands and blading, GT doesn’t have
the release to RE-START before turning gear system is already engaded.
NOTE: in the event of a suspect of fault on the rotor, the rotor must be allowed to coast to a
complete stop.
The suspect of a damage can regard:
Ø rotor to stator contact (elevated vibration, abnormal running noise, reduced rotor coast-
down time)
Ø bearing damage (increased bearing metal temperature, high vibration).
In any case, fault removal activities shall be carried out before re-starting the GT.
MANUAL TURNING PROCEDURE

In case the turning mode cannot be started before the rotor comes to a stop or in case the turning
gear has a fault during the GT shut down (in this case take note on the instant when the rotor has
stopped in order to know how much cooling time has elapsed), the rotor is likely to be distorted (not
permanently)
In this case, the emergency cooling by SFC is not permitted under any circumstances as this could
cause severe damage to the shaft glands and blading.
The operator shall then take the following actions:
• As soon as possible, start up the lube and lifting oil pumps.
• Attempt to turn the rotor with the manual barring gear and continue until the turning gear system
is available otherwise for the 24 hours cooling time. If this is not possible, let the shaft be cooled
for other 24 hours (as a rule, it will then be possible to turn the shaft).
• After the 24 hours, try to turn the shaft manually by means of the barring gear, in case it is
possible to turn the shaft, switch on immediately the automatic turning gear provided it is
available Before the start up of the turning gear system make sure that the wrench has been
removed.
• Turning gear operation must now be continued without interruption for at least one hour and
after the evaluation of the vibrations runout trend (vibrations asymptotic trend) to eliminate the
shaft distortion which has already occurred and to prevent excessive start up vibration.
• After this procedure, the gas turbine can be started as usual.
Page 2 of 3
07.01.16
Loss of 3AC power supply
In the event of loss of the three phase power supply during operation, a GT trip occurs, it is
disconnected from the grid and it coasts down to a stop with the emergency oil pump running.
In such circumstance the control console operator is not permitted to switch off the emergency oil
pump as it is imperative to maintain the bearing cooling as long as possible. If the emergency oil
pump is shut down shortly after the shaft has coasted to a stop, the turbine bearing will overheat
due to the thermal input transmitted from the exhaust casing.
Every effort must be made to restore the three phase power as quickly as possible in order to resume
turning gear operation.
In case it was not possible and the rotor stops before the restoring of the 3AC power supply, the
following measures shall be taken:
• Prevent the batteries (emergency oil pump) from discharging completely.
• Immediately after restoring three phase power, check the lube and lifting oil and turning
equipment for proper operational status.
At this point two scenarios are possible:
1. It is possible to recover the turning gear mode à see section “Gas Turbine cooling 1.& 2”
2. The rotor remains at standstill (i.e. due to prolonged loss of 3AC power supply) à see
section “MANUAL TURNING Procedure”
Page 3 of 3
07.01.16
SFC EMERGENCY TURNING
In case of turning gear system fault during the GT Shutdown Sequence, the cooling turning operation
can be performed by activating the SFC with the “ SFC emergency turning” procedure.
Warning
The “SFC emergency turning” procedure can be selected manually by the operator, only during GT
Shutdown in the range of speed between S.TURB.20 (1,4Hz) and S.TURB.89 (0,3Hz).
Only one attempt to start SFC Emergency Turning, can be done.
In order to avoid injury to personnel due to the shaft rotation, the SFC Emergency Turning procedure
can’t be started (due to interlocking in control system) in case of one of the following conditions :
• GT standstill
• when an operator manually increases shaft speed above 0,3Hz.
• In case of black out
Moreover, on the intermediate shaft between the gas turbine and generator enclosure there is a
cover protection with three Closed limit-switch MBA10CG001/002/003. When the cover protection is
open an interlock logic is activated to inhibit the machine start up, this to avoid to have the shaft
running causing a possible injury to people.
See also section :

General operating instruction TGO3-0033
BHS turning Sequence TGO3-0049
Manual Turning TGO2-0610
Page 1 of 1
SFC EMERGENCY TURNING TGO3-0034-E70001
08.01.16
GT STARTING – MASTER SEQUENCE
The purpose of this section is to give a general guide on operation involving the master sequence.
All starting conditions are supposed to be respected.
Such conditions are:
 General preparation
 Working tests before starting
 General working indications
Indications
Before first GT start up takes place, the personnel should become familiar with the operative
program sequences and the process associated sequences included.
In the same way, the shutdown procedures indicated in case of starting failure must be well known,
so that the correct decisions can be made on the basis of the failure reasons.
Before starting, the personnel should know the actions occurring in the different steps of each
sequence indicated in the operation program, together with the associated procedures. In particular
the personnel should become familiar with:
- Sequences
- Starting releases
- Gas turbine protection system
- Alarms
- Setting
Sequence’s structure
As a general structure, the gas turbine operation is supervised at any time by step programs called
sequences. In particular, there is a master sequence, for the high level controls, which coordinates
other sequences, see figure 1.
The sequences are independent and the master one is destined to the control of all the other ones
and their mutual interconnection.
Page 1 of 11
GT STARTING – MASTER SEQUENCE TGO3-0045-E70004
23.03.17
MAIN SEQUENCE
LUBE OIL FUEL OIL FUEL GAS RDS

SEQUENCE SEQUENCE SEQUENCE SEQUENCE
Figure 1: Master Sequence coordinates other

BHS PURGING Sequences
TURNING
General structure of sequence and Master sequence MYB01EC001

Each sequence consists of a series of steps.
In each step, some commands are given to particular equipment and the commands are visualized on
the right side of the chain. In particular, the master sequence can control the operation of other
sequences.
Feedback signals which must be achieved before proceeding to next step are indicated on the left
side.
Each step has a waiting time (WT). When it is expressly indicated, the sequence remains on that step
for at least the waiting time, also if all feedback signals are already available.
When the monitoring time is indicated (MT), all the step feedback signals must be received within
the monitoring time. If this doesn’t happen, something wrong is occurring. Depending on the
operating mode, initiation of shut down program or alarm is issued. For instance, if the monitoring
time is not respected during the GT start up phase the start up is interrupted. If the monitoring time
is not respected during the standstill steps an alarm only is emitted.
The master sequence starts the operation steps as long as all the release conditions for GT operation
are respected.
The releases relevant the gas turbine are shown below, further releases coming from different areas
in the plant are not included in the present description.
Page 2 of 11
23.03.17
See also section:
Fuel Gas Sequence TGO3-0046
Lube Oil Sequence TGO3-0047
Fuel Oil Sequence TGO3-0048
BHS Turning TGO3-0049
RDS Sequence TGO3-0050
Start Up branch
The start-up procedure shall include the following processes:
- preparation of the generator and SFC
- start of the boiler purging
- start of the fuel selection and the relevant sequence
- setting of the sequences related to the selected fuel
- IGV/CV1 controller activation
- lube oil system start-up
- hydraulic oil system start-up
- air dryer switching off and opening of the air intake damper
- blow off valves opening
- closing the GT drain (*)
- activation of the RDS system
- generator excitation and synchronization
NOTES: Conditions marked with (*) are applicable only for gas turbines with fuel oil operation.
The start of the operating program and therefore the GT start up can only be possible when the
following start up releases are present (depending on the plant configuration, some conditions can
be not applicable and other ones can be necessary):
RELEASE CONDITIONS:
The start of the operating program and therefore the GT start up can only be possible when the
following start up releases are present (depending on the plant configuration, some conditions can
be not applicable and other ones can be necessary):
- GT Common permissive
o GT/Generator enclosure ventilation available
o Start permissive from Turning System
o Lube oil system available
o Generator Cool Air >> MIN
o Cooling Air system available
o Damper and Blow off system available
o Pneumatic Air pressure OK (N.A.for AE94.2)
o Seal air fans not fault (*)
Page 3 of 11
23.03.17
o At least one IGV/(CV1(***)) cartridge available
o Inspection doors closed
o Anti-implosion doors closed
o RDS system ready for GT start up (**),
o GT drain valves ok (*)
o Cooling oil system ready
o FO purge NOT requested (*)
o Fuel Controller common release
o Auto shutdown completed and reset
o Fire fighting permissive
o Hydraulic oil systems available
o In case of single shaft
- Clutch brake not inserted
- Steam Turbine lifted
o FO LOCKED (drain valves (MBN14/23/52AA501) OPEN, Emergency STOP Valves and
control valves CLOSED, no open request for control valves)
o FG LOCKED (vent valve OPEN, Emergency STOP Valve and control valves CLOSED)
o MBM12GT001 OK
o FO premix drains closed (MBN45AA…) (*) (N.A. for AE94.2)
- SFC start releases

o BOP or HRSG start release
o SFC normal start selected
o Generator Breaker available
- GT electrical permissive
- No FAULT permissive
o Speed sensor OK
o no main ALARM (i.e. at least one TCI TC (A) ok, gives release to start)
o no TRIP cause from SIL, present (i.e. if one Turbine exhaust TC (B/C) is in fault, NO
release to start)
o Seal Air fan sensor no fault
- FUEL RELEASE
o FG selected –
 FG system available for startup
 FG start inhibition from SIL (NOT)
o FO selected
 Ignition gas available
 FO system available for startup
 FO start inhibition from SIL (NOT)
Page 4 of 11
23.03.17
- Water injection/emulsion system is off (*) (+)
(+) only in case the water emulsion/injection system is foreseen
- - (*) conditions applicable only for gas turbines with fuel oil operation.
(**) condition applicable only for AE94.2/AE94.3 with RDS
(***) condition applicable only for AE94.3A EVO1
GT STARTUP
Step Action Feedback WT MT Note
[s] [s]
open intake damper Intake damper is open - 30 SFC possible operating
stop air dryer SFC ONE operating mode mode selected:
reset the SFC turning selected
GT Step 1  SFC /FG
command Speed < S.TURB.09
 SFC /FO
start Generator and Generator and GT
 Purging
GT enclosure fans enclosure ventilation ON
 SFC Clean
- 25
 Start Lube Oil - Lube Oil Sequence
Sequence running /MEMORY ON
 Start Hydraulic oil - GT drains CLOSED

pumps
- IGV/CV1 in closed
GT Step 2  IGV/CV1(***) position OR SFC Clean
control ON Selection
 Close GT Drain
valves 1&2(*)
 RDS Sequence
Shutdown ON (**)
- 10
 All blow off valves - Synchronizing system
open OFF
GT Step 3 - Control voltage ON
- At least one hydraulic

oil pump running
Page 5 of 11
23.03.17
GT STARTUP
[s] [s]
Select the minimum - 60
load (E.LEIST.01) - All blow off valves
Start up function opened
active
GT Step 4
Enable IGV/CV1 - Lube Oil Sequence step
control if SFC wash 10 active
selected
- RDS ready for runup
SFC ON SFC Start selected - - In case of SFC selected
in ‘washing mode’, the
Purging in progress
Main Sequence ends at
GTCMPS Braun speed not this step.
GT Step 5 high deviation When the Normal start
mode or the purging
mode are active, the
next step is enabled.
 Boiler purge completed In case of SFC selected
from SIL in ‘purging mode’, the
Main Sequence ends at
 SFC Start selected
this step.
When the Normal start
mode is active, the next
step is enabled
WT = K.BELUEFT.01
(active only in case of
Boiler Purging mode
selected) *
GT Step 6 No Command
WT = 0 (active in case
of normal start
selected)
MT =
At the end of the
purging sequence, the
SFC selector is
automatically switched
on ‘normal start’.
*not applicable for
single cycle
GT Step 7 No Command GT speed NOT > - 45
Page 6 of 11
23.03.17
GT STARTUP
[s] [s]
S.TURB.09
Start FG sequence step 7 - 120 The fuel emergency
Fuel Gas Sequence or Or stop valve(s) is opened
GT Step 8 and the flame is ON.
FO sequence(*) FO sequence step9
No commands - GT speed >S.TURB.03 - 240

GT Step 9
- SFC OFF
GT Step 10 No commands GT speed >S.TURB.13 - 40
IGV CONTROL ON - - -
GT Step 11
No commands
Excitation ON Excitation - 4
GT Step 12
is ON
GT Step 13 No commands No commands - -
Synchronization ON Generator - The GT is ready to be
Monitoring time STOP on grid synchronized in
automatic or
semiautomatic mode (if
selected).
GT Step 14
MT= N.A. (the
feedbacks must be
absolutely received
before proceeding to
the next step).
GT Step 15 No commands No feedbacks - -
The Gas Turbine is in This step enables the
service load reduction (when
GT Step 16 required) and the re-
synchronization (in
case of load rejection).
Table 1: GT MAIN SEQUENCE – START UP BRANCH
Page 7 of 11
23.03.17
Shut Down branch
The shut down branch is activated by the “shut down” command issued by the operator or it is
automatically initiated by the safety system (GT protection shut down or trip).
The shutdown branch shall include the following processes:
 GT unloading
 start-up converter switch-off (in case of faulty start)
 switch off the boiler purging (for shutdown activation during the boiler purging)
 generator disconnection from the grid
 fuel disconnection
 IGV/CV1 controller off
 hydraulic system disconnection
 starting of the turning operation (start of the lube oil/turning program)
 fuel oil relief valve opening
GT SHUTDOWN
[s] [s]
No commands GT active - 3000 the GT load decreases by
power<E.LEIST.08 the normal gradient)
GT Step 51 OR
Generator NOT on
GRID
Emergency oil pump - -
GT Step 52
ON
ZERO REACTIVE POWER GT active - 25
COMMAND power<E.LEIST.42
GT Step 53 OR
Generator NOT on
GRID
Generator NOT on - 5
 Generator CB open grid
GT Step 54  Load rejection logic
interlock with a TIME
DELAY=K.LAW.05
No feedback - -
 Generator CB open
GT Step 55 (the command of the
previous step is
repeated)
Page 8 of 11
23.03.17
GT SHUTDOWN
[s] [s]
 IGV/CV1 control OFF
 Anti-icing OFF
 SFC turn RESET
 Excitation OFF
Fuel Gas Sequence shut - 35
down program (release to  Excitation OFF
start)
Fuel Oil Sequence shut  Synchronization
down program (Release to not running
start)(*)
Emergency oil pump OFF  SFC OFF
SFC AUTO OFF
Protection shutdown logic  FG sequence
GT Step 56
1 (GT startup aborted) step 52 or FO
Sequence step
55
OR
 GT SHUTDOWN
M.T. excd
delayed
Shut down branch
GT drain valve 2 open (*) interlocked in case of trip
GT speed <
GT Step 57 Protection shutdown logic - - signal (since the fuel
S.TURB.09
1 (GT startup aborted) emergency stop valve(s)
is closed just now)
GT Step 58 No Commands No feedback
No Commands GT speed < 300
GT Step 59
S.TURB.05
GT Step 60 No Commands No feedback
Lube Oil shut down 650
Hydraulic oil pumps OFF sequence in progress
GT Step 61 Lube Oil Sequence shut Turning gear
down program sequence step 8 or
step 14
Page 9 of 11
23.03.17
GT SHUTDOWN
[s] [s]
OR
SFC turning & speed
> S.TURB.20)
End of the GT Main This step enables the
Sequence. next start up program
GT Step 62
End of all monitoring activation.
times.
Table 2: GT MAIN SEQUENCE – SHUT DOWN BRANCH
Faults leading to the shut down program activation

The following faults or protection criteria activate the shut down branch of the GT Main Sequence
(single criterion can be dependent on the plant configuration):
 monitoring time exceeding in the start up program

 GT TRIP sensor FAULT- (one Turbine exhaust TC (B+C) fault)
 fault in the Fuel Oil or in the Fuel Gas sequence
 COLD SPOT protection shutdown (3 adjacent Burners extinguished)
 Cooling air system fault
 SFC fault in Startup or black start fault (i.e. voltage supply fault)
 SFC NOT OFF TRIP
 SFC speed set BAD
 too long start up times (measured between S.TURB.21 and S.TURB.70)
 Air intake filters - differential pressure MBL14CP101> P.AIRFILT.03 (14mbar) and High Total
Pressure MBL14CP001/002 (2oo3 signal) with the delay K.AIRFLT.01=600s
 FAULT of anti-ice system (when present)
 RDS feed line pressure too low (MBA51CP101/102)<P.HSO.09 (140bar)
 Both LO vent-fans off
 IGV/CV1 not in minimum position for start up
 pressure difference in FO diffusion supply line too high (*)
 External criteria (depending on plant configuration, to be set order related).
(*) conditions applicable only for gas turbines with fuel oil operation.
Notes:
 in case of monitoring time exceeding in the GT Main sequence start up branch, during
steps from 1 to 10, the GT Main sequence shut down branch is automatically activated.
An alarm must be issued always in case of monitoring time exceeded (e.g. during all
steps).
Page 10 of 11
23.03.17
 In case of monitoring time exceeding in the steps of the shut down program, an alarm is
issued and the next step is performed as well, when the feed-back criterion arrives.
Page 11 of 11
23.03.17
GT STARTING – FUEL GAS SEQUENCE
The purpose of this section is to give a general guide on operation involving the fuel gas operation.
The Master Sequence is supposed to be known.
The following abbreviations will be used:
FG = fuel gas , FO = fuel oil, PG = pilot gas, CV = control valve , ESV = emergency stop valve
Note: two type of pilot gas can be foreseen, named Pilot and Pilot 2, see burner arrangement,
section TGO2-0760
Also the fuel gas sequencer consists of a series of steps.
Each step can control the different uses, they are then visualized on the chain right side.
Each step has a waiting time (WT) and a monitoring time (MT).
When the monitoring time is indicated (MT), all the step feedback must be received within the
monitoring time. If this doesn’t happen, the standstill program is activated. If the monitoring time is
not respected, and alarm is emitted during the standstill steps.
The NG sequence is activated when the GT start up is required (by the master sequence).
See also section:

Fuel gas system description TGO2-3001
Master Sequence TGO3-0045
For GT start up, the GT Main sequence activates the Fuel Gas Sequence .
START UP branch
Fuel gas start up is initiated by activating the startup program.

The FG startup may only be performed if all requisites applicable to other GT systems have been met.
In case of monitoring time exceeding during the startup procedure, the GT start is prevented and the
shutdown process is automatically activated.
The GT is in standstill or in turning gear operation mode.
In the following tables, actions, feedback, WT , MT and note of each single sequence step are
reported.
Page 1 of 5
GT STARTING –FUEL GAS SEQUENCE TGO3-0046-E70001
17.11.14
FG STARTUP
Step Action Feedback WT [s] MT [s] Note
IF ⋅ 1 10 The start up
1. FO DIFF ESV is CLOSED branch can be
AND activated by step
2. GTspeed NOT> 8 of GT MAIN
S.TURB.09 Sequence
THEN
GO to step 02 à GT start
selected
IF
FG Step 1 FO-DIFF-FEED ESV is
OPENED
AND
T speed > S.TURB.70

THEN
GO to step 20 à FG
addition in FO operation
MBP13AA501 ⋅ MBP13AA501 1 10 In case of

CLOSED external Shut off
CLOSE command
Valve (not
⋅ Skid gas enclosure included in the
FG Step 2 ON GT scope of
supply), the
command must
be issued in this
step
⋅ MBP22AA151 OPEN FG pilot2 CV Not 1 50 the fuel gas
request CLOSE pilot2 control
valve opens to a
FG Step 3 ⋅ MBP24AA151 OPEN position
request corresponding to
the start up mass
flow F.EGDB.01
No Command Speed>S.TURB.09 1 120 Waiting for
FG Step 4 reaching ignition
speed S.TURB.09.
⋅ MBP13AA051 OPEN ⋅ MBP13AA051 OPEN 1 20
FG Step 5 Command ⋅ FLAME ON
⋅ Ignition transformer ON
Page 2 of 5
17.11.14
FG STARTUP
Step Action Feedback WT [s] MT [s] Note
No Command Speed>S.TURB.21 1 150 the GT speed
increases due to
both the SFC and
FG Step 6
to the increased
fuel gas mass
flow
No Command Speed>S.TURB.70 1 600 The premix gas is
connected at
F.EGVB.01 mass
flow. The FG-
PG2-CV is
FG Step 7 closed to
compensate
the PREMIX-CV
opening . The
GT is in Premix
operation
End of start-up sequence Stop -
FG Step 8
Timing
Table 1: FG startup Sequence
Fuel Gas addiction (fuel changeover from oil to gas):
The fuel gas connection in fuel oil operation occurs when the operator has manually selected
“FG operation, the GT is operating in FO DIFFUSION mode and the IGV position is within the
proper range for fuel change over ( IGV position > G.VLE0.38 + 10% AND < G.VLE.39).
Note:
if the gas turbine is running in the fuel oil premix mode and a fuel changeover is selected, at first the
change over from premix to diffusion has to be carry out because fuel changeover with the fuel oil
premix burners is not permitted.
Fuel Gas Connection -CHANGEOVER FO-FG SEQUENCE

Step Action Feedback WT MT [s] Note
[s]
FG ⋅ No Command ⋅ IGV > G.VLE0.38 and IGV < 2 400
Step20 G.VLE0.39)
FG ⋅ No Command FO-PREMIX ESV 2 600
Step21 (MBN23AA051) has to be
closed for more than 10
minutes
Page 3 of 5
17.11.14
FG The solenoid valves in the MBP13AA501 closed 2 100
actuators of the FG premix and MBP24AA151 not closed
Step22
pilot 2 gas control valves are P gas > P.GAS.06
energized.
In case of external shut off valve
(not included in the GT scope of
supply), the command open must
be issued in this step.
FG MBP13AA051 OPEN Command MBP13AA051 OPEN 2 60
Step23
FG After a defined WT from the Open MBP22AA151 open >0% K.EGV 40 the Fuel Gas
command to the FG-ESV, B.300 Sequence Step
Step24
MBP22AA151 position to END of FG Connection -> (14 s) 24 attainment
guarantee the connection premix GO to step 08 + represents a
mass flow F.EGVB.24 and activates GK.AN release for the
the Fuel Gas proportioner TEIL.01 FO purging
sequence
AUTOSTART
When the FO is
disconnected,
the GT runs only
in FG mode and
the FG Sequence
returns to step
08 (end of NG
addition)
Page 4 of 5
17.11.14
SHUT DOWN branch:
In case of standstill program (for protection or selected by the operator), or in case of GT trip, the
master sequence activates the gas system disconnection. Fuel gas system shutdown is issued at step
56 of the GT master sequence by the closure of the fuel gas emergency stop valve. The following
commands are issued:
FG SHUTDOWN SEQUENCE
Step Action Feedback WT MT [s] Note
[s]
FG ⋅ MBP13AA051 ⋅ MBP13AA051CLOSE 1 100 The vent valve
Step51 CLOSE Command ⋅ MBP22AA151 CLOSE MPB13AA501
is open by the
⋅ MBP22AA151 ⋅ MBP24AA151 CLOSE
fuel gas stop
CLOSE Command ⋅ MBP13AA501OPEN logic
⋅ MBP24AA151
CLOSE Command
FG End of FG Shutdown 1 50 Feedback is
Step52 Sequence given to the
step 56 of the
GT Main
Sequence.
Table 2: FG shutdown Sequence
Page 5 of 5
17.11.14
GT STARTING – LUBE OIL AND TURNING SEQUENCE
The purpose of this section is to give a general guide on operation involving the lube oil sequence
including turning operation.
The following abbreviations are used:
MOP = Main Oil Pump, AOP = Auxiliary Oil Pump, EOP = Emergency Oil Pump, LOP= Lifting Oil Pump
Also the lube oil and turning sequencer consists of a series of steps.
On the left side, the return signals are indicated, which the step expects before going on.
Each step has a waiting time (WT). ). When it is expressly indicated, the sequencer remains on that
step for at least the waiting time, also if all feedbacks are available.
When the monitoring time is indicated (MT), all the step feedbacks must be received within the
monitoring time. If this doesn’t happen, an alarm signal is emitted . The sequencer stops and remain
on the present step until it receives the necessary consents.
The lube oil and turning sequencer is activated by the master sequencer when the GT has to be
started up, stopped, or kept in the turning status. It is disconnected only when the GT is at complete
standstill. In these periods, only the logic for lube oil heating is active.
See also section:

SFC Emergency Turning TGO3-0034
BHS Turning Sequence TGO3-0049
Page 1 of 6
GT STARTING –LUBE OIL AND TURNING SEQUENCE TGO3-0047-E70001
13.07.16
Lube Oil Sequence - Start Up Branch:
The start up branch is activated by step 2 of GT MAIN Sequence.

Release conditions are :
- Lube oil level OK (i.e. > min 2 L.SCHMOEL.01)
- Lube oil temperature OK (i.e. > min T.SCHMOEL.01)
- No alarm on the lube oil pumps
- No fire protection alarm present
LUBE OIL STARTUP SEQUENCE

Step COMMAND FEEDBACK WT MT Note
1 STOP LO heating LO heating OFF 1s 10s
MOP is ON
AND
2 START MOP 5s 8s
LO pressure >
P.SCHMOEL.01
To verify the EOP correct running,
EOP test ACTIVATED: the EOP has to be activated. The
pressure switch MBV26CP003
• OPEN • LO EMERGENCYPMP ON
switch on the EOP motor, in case
3 MBV26AA510 • ECO RELAY ON 5s 6s
of low lube oil pressure; this
• SWITCH ON ECO condition can be forced closing
relay (ON status) the MBV26AA510 valve for a few
second
AOP AND MOP are ON I.e. the sequence can proceeds
or if either the MOP or the AOP is
LO pressure > running.
P.SCHMOEL.01
4 START AOP and 1s 30s
EOP test is OK :
• EOP is ON
• absorbed current =
E.SCHMOEL.10 ± 20%
• SHUT DOWN In case of start up from turning
TURNING VALVES CLOSED
TURNING GEAR
5 MBV35AA001 or 002 1s 60s gear operation, it must be
SEQUENCE ensured that the turning mode
(pivot arm disengaged)
• OFF CMD to SFC is interrupted
• LO pressure >
P.SCHMOEL.01
6 NO • at least 1 lube oil tank 1s 60s
blower ON
(MBV50AN001/002)
Page 2 of 6
13.07.16
LUBE OIL STARTUP SEQUENCE
e.g. in case of low lube oil
• STOP AOP and EOP LO pressure > pressure detected they are
• Release for P.SCHMOEL.01 switched ON, by the protection
7 1s 60s
protection criteria AND logic, and the sequence
ON to AOP and EOP EOP is OFF proceeds with the running AOP
pump
• LOP ON
8 • START LOP • Lifting pressure > 1s 60s
P.LIFT.01
Repeated release for
9 NO NO 1s 30s
protection ON to AOP and EOP.
Signal “Lube oil Repeated release for
sequence, start protection ON to AOP and EOP
10 completed” is given to NO 1s 30s
GT MAIN Sequence -
STEP 4
Lube Oil Sequence - Shut Down Program:
The shut down branch is activated by step 51 of GT Master.

It is executed on when GT speed is < S.TURB.05.
A selector SFC emergency turning ON/OFF is available. In case the SFC emergency turning is
preselected (ON), SFC emergency turning will be automatically activated in case of fault of the
turning gear system.
Page 3 of 6
13.07.16
LUBE OIL SHUTDOWN SEQUENCE
51 START Turning Gear • Turning Sequence at 1s 20 min In case the MT is exceeded and
pump STEP 8 or STEP 14 (i.e. the emergency turning by SFC
START Turning in case of normal has been previously selected:
Sequence and the WT turning) if the speed is within 1.4 Hz
K.TURN.104 (3 hours) OR (S.TURB.20) and 0.3 Hz
as well. • SFC ON (in case of (S.TURB.89) , the command
emergency turning) START is given to the SFC to
Note: This condition perform the GT turning cooling.
allows the re-
alignment of the shut If MT exceeding in this step,
down sequence in the following alarm is issued:
case of manual “Emergency turning by SFC
operation. activated” and the relevant
actions for SFC turning are
initiated (see section TGO3-0034)
52 NO • IF SFC Emergency K.TURN.04 7500s This step starts monitoring the
turning ON --> STEP turning/cooling time of 2 hours
57 (K.TURN.04), indicated by the
OTHERWISE waiting time. Step is skipped
• WT by GT speed < 0,11 Hz and
OR speed signal not faulty (for re-
• GT speed < S.TURB.02 alignment). If Emergency
(0.11 Hz) - NO FAULT turning by SFC is activated
jumps to Step 57.
53 • CLOSE Damper Flap • Damper Intake 1s 11000s Step is skipped by GT speed <
MBL20AA001 CLOSED 0,11 Hz and speed signal not
• START air dryer AND faulty (for re-alignment).
MBA10AT001 • Air drier ON
• STOP Cooling AND
system • Cooling system OFF
• ECO relay OFF OR
• GT speed < S.TURB.02
(0.11 Hz) - NO FAULT
54 SPARE
55 SPARE
56 SPARE
57 NO WT K.TURN.01 22h Step is skipped by GT speed <
OR GT speed < 0,11 Hz and speed signal not
S.TURB.02 (0.11 Hz) - faulty (for re-alignment).
Page 4 of 6
13.07.16
NO FAULT
58 • STOP Turning GT speed < 1.8 Hz (An 1s K.TURN.05

• STOP Turning alarm is given in case of
Sequence MT exceeding)
• STOP SFC (in case
the ON command
was active due to
the emergency
turning).
59 NO GT speed < S.TURB.02 1s 15 min.
(0.11 Hz) - NO FAULT
60 NO • ECO relay is OFF K.SCHMOE K.SCHMOE
• GT speed < L.08 L.08 + 1
S.TURB.02 (0.11 Hz) - min.
NO FAULT
61 Now the GT is at ALL PUMPS OFF 2s 10s (Note: the flames have been
standstill switched-off 3 hours before)
STOP all pumps (MOP,
AOP, EOP, LOP and
Turning Pump) if the
Flame signal is not
active
62 LO heating ON WT K.TURN.02 50s The rotor stays at standstill for
6 hours (waiting time of
K.TURN.02).
63 The interval turning is NO 60s 70s
started.
STOP LO heating
START MOP
Release for protection
ON to AOP and EOP
64 NO NO 2s 10s the monitoring time exceeding
will cause the interruption of
the interval turning and the
shut down of the turning
sequence
Page 5 of 6
13.07.16
65 • START LOP • Lube oil tank level OK 2s K.SCHMOE Note: MT exceeding will cause
• START Turning • Lifting Pressure > L.06 the interruption of the interval
Pump (Multi Shaft) P.LIFT.01 turning and the shut down of
the turning sequence.
66 START Turning GT speed < S.TURB.02 120s K.TURN.06

Sequence (0.11 Hz) - NO FAULT (120s)
67 STOP Turning GT speed < S.TURB.02 1s 300s
Sequence (0.11 Hz) - NO FAULT
68 END of LUBE OIL
SEQUENCE
Page 6 of 6
13.07.16
GT STARTING – FUEL OIL SEQUENCE
The purpose of this section is to give a general guide on operation involving the fuel oil operation.
NG = fuel gas , FO = fuel oil , CV = control valve , ESV = emergency stop valve
Also the fuel oil sequencer consists of a series of steps.
The FO sequence is activated when the GT start up with fuel oil is required (by the master sequence)
OR when the fuel change over from gas to oil (by operator selection) is started. In the first case, the
FO sequence will start the GT start up steps, in the latter the FO connection in NG operation.
See also section:

Fuel oil system description TGO2-3005
Purging Sequence TGO3-0051
Page 1 of 11
GT STARTING –FUEL OIL SEQUENCE TGO-0048-E72001
20.11.2014
Start Up branch
Fuel oil start up is initiated by selecting FO and activating the startup program. In addition the
start up branch is activated in case of fuel change over from gas to oil.
Furthermore, the FO startup may only be performed if all requisites applicable to other GT
systems have been met.
In case of monitoring time exceeding during the startup procedure, the GT start is prevented
and the shutdown process is automatically activated.
In the following, the proper steps of the FO start up are indicated:
The GT is in standstill or in turning gear operation mode. All fuel system are switched off.
Step 01: No command and no feedback.

Note
The first step discriminates the GT start up with fuel oil or the fuel oil connection in fuel gas
operation ( at fuel change over from gas to oil). In case the GT speed is higher than S.TURB.70
and the fuel gas emergency stop valve is opened, it means that the GT is already in operation
and, if the FO has been selected and the GT is in the proper range for fuel change over, the fuel
oil connection in fuel gas operation occurs, the sequence skips to step 23 (fuel oil addition).
Otherwise, for GT start up with fuel oil, next step is 02.
Step 02: The FO-DIFFUSION-seal air ball valve MBN34AA001 (see sketch “FO System”) receives
a CLOSE command (step 02). The FO-PREMIX-drain valves MBN45AA401/402 are first opened
to check their functioning and then immediately closed. The GT drain valves MBA22A001/002
(see sketch “Drainage System”) are already closed. The FO forwarding system receives a
command on.
If all the feedbacks are received the sequence may be continued. One of the feedbacks is the
achievement of a minimum pressure before the FO injection pumps (pressure >P.HOE.16).
Step 03: The fuel oil injection pump is commanded ON, as feedback the pressure after the
pump must be higher than P.HOE.01.
A command to the pilot solenoid valves in the actuators of the FO diffusion feed control valve
and FO diffusion return control valve is given.
Page 2 of 11
20.11.2014
Step 04: The ignition vent valve MBQ13AA501 is closed.
As feedback it is expected the closed signal of the ignition vent valve and the speed>S.TURB.31
within the monitoring time of 40s.
Step 05: At this step, the ignition gas valves 1 and 2 are opened. At the same time, voltage is
sent to the ignition transformers. When the ignition takes place, the GT drain valve 1
MBA22AA001 is moved to the FO-drain position (A-B, C closed), so that in case of a faulty start-
up, no unburned FO would flow into the water drain system. The sequence may proceed when
the signal ‘OPEN’ of both the ignition gas valves is present.
Step 06: Once speed S.TURB.30 has been reached and the pressure produced by the injection
pump is higher than P.HOE.01 (65 bar), before opening the FO stop valves it is necessary to
check that the FO-DIFFUSIONVL-CV and that the FO-DIFFUSIONRL-CV have reached the start-
up position. The above conditions are a release criteria for step 07.
Step 07: At step 07 the command open is given to the FO-DIFFUSIONVL-ESV MBN14AA051. As
a consequence, the open command becomes effective for the FO-DIFFUSIONRL-ESV also and
the stop valves in the feed and return lines are opened. The sequence waits for the signal open
of the fuel oil stop valves.
Note
20 seconds after the command OPEN is given to FO-DIFFUSIONVL-ESV, the flame detector
signal is released. In case of “flame ON” signal, the GT-drain valve 1 is moved once again to the
drain water position (A-B, C closed), since the FO start up has been successful.
Step 08: The sequence waits for the signal GT speed > S.TURB.21
If within 25 seconds after the command OPEN to the FO-DIFFUSIONVL-ESV, the “flame ON”
signal is not present, the start-up is faulty and the trip is released. In case of false start up, the
next start is possible only when the speed has dropped below S.TURB.09.
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Step 09: The sequence is at step 9 until speed S.TURB.10 is reached
Step 10: No command and no feedback.
Step 11: The GT is in stable diffusion operation and may be operated is this step time
unlimited. The sequence may proceed when the release criteria for the switch to FO premix
operation are met. A waiting time of 30s is implemented (waiting time before the release of
premix operation, the GT must have been at least 30s in diffusion mode).
Fuel oil diffusion mode operation

The GT is in fuel oil diffusion mode (FO-DIFFUSION) and is ready to be synchronized.
The power output depends on the supplied FO flow which is determined by the FO-
DIFFUSIONRL-CV position. The default burner mode selection is “premix” operation, so that
when the release conditions are met, the automatic switch over from diffusion to premix
occurs.
Switch over from FO-DIFFUSION to FO-PREMIX

The changeover from FO-DIFFUSION to FO-PREMIX occurs only when a certain fuel/air ratio is
reached, and as criterion a minimum TETC must be attained. Switch over from diffusion to
premix automatically occurs when TETC is higher than TT.ATK.02 and all the other releases are
met, provided that premix operation is selected.
The switch over must occur at the minimum possible compressor delivery temperature. When
compressor temperature increases, there is the risk that the oil ignites in the outlet of the
premix capillary tubes surrounded by hot compressor air flow, causing a flash-back. As a
criterion for low compressor delivery temperature, an interlock to the change over is
implemented if IGV position is higher than G.VLE0.200 . The switch over from FO-DIFFUSION to
FO-PREMIX is implemented in the FO sequence from step 12 to step 17.
In the following, the actions which take place during the DO to PO switch over are described.
The relevant FO sequence steps are also indicated.
The load set point is blocked during all switch over (from step 12 to step 16 ).
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Step 11: FO-diffusion operation (step 11)
The GT is in stable FO-DIFFUSION operation mode.

Switch over release conditions
Before carrying out the switch over procedure, the following criteria must be fulfilled:
§ FO must be selected
§ FO premix operation selected
§ TETC is higher than TT.ATK.02
§ FO-PREMIX-ESV MBN23AA051 is closed
§ The generator is connected to the grid
§ The FG-PG/PO-ESV are closed
§ FO PO leakage solenoid MBN44AA002 is closed
§ Signal FO Premix purge/cool fault is not present
§ IGV position is lower than G.VLE0.200
The signal of premix purge fault is generated if, in the previous attempt to switch to FO premix
a fault is recognized (see relevant task), this signal may be manually reset.
Step 12: The Purging Sequence is activated in mode: “PREMIX COOLING”.
Step13: The premix seal air ball valve MBN44AA001 receive a command close (step 13), in
order to interrupt the sealing air flowing in the fuel oil burner.
Step 14:
In this phase it is expected to receive a feedback from the Purging Sequence. The FO premix
control valve is commanded to the change over position.
Step 15: The FO premix emergency stop valve is commanded open, it is expected to receive
the feedback open within 5s. When the valve is recognised open the sequence goes on to the
next step.
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Step 16: During this step the change over to premix is performed. The sequencer waits for the
end of the change over process. The monitoring time is K.ANTEIL.09+10s.
Step17:At this step the GT is in FO-PREMIX MODE and it may be operated time unlimited,
provided that the conditions for FO premix are met.
In case of fault in one of the steps from 13 to 17 the sequence skips to step 18.
Fuel oil premix mode operation

The FO-premix flames must be supported by pilot flames. The FO-DIFFUSION-system uses the
diffusion fuel oil to provide pilot flame for the premix flames. The pilot fuel amount must be
enough to provide stable pilot flames, and at the same time the premix valve must work
opened enough to achieve a good pressure on the premix nozzles. Also the NOx emissions
depends on the pilot flame.
Switch over from FO-PREMIX to FO-DIFFUSION

In FO premix operation, the GT is running in FO sequence step 17.
The reverse switch over from PREMIX to DIFFUSION can occur due to normal or emergency
conditions.
The normal conditions which induce the automatic switch over premix to diffusion are:
§ FO diffusion selected and IGV position<G.VLE0.39

§ OTC<limit for premix operation, TT.ATK.05
§ FO premix filter clogged (MBN12CP101/102/103>P.PFILT.200 in logic 2v3), which induces
a load decrease down to the reaching of the allowed position of IGV for the change over.
The signal of FO premix filter clogged furthermore deselects the premix pre-selection.
The emergency conditions which induce the automatic switch over premix to diffusion are:
§ Load rejection
§ Switch over diffusion to premix faulty from steps 13 to 16
In the following, the actions which take place during the premix to diffusion switch
over are described. The relevant FO sequence steps are indicated.
The load set point is blocked during all switch over (from step 18 to step 22 ).
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Step 18: By normal switch over, the FO sequence skips from step 17 to step 19. Step 18 is used
in case of a command close given to the FO-PREMIX-ESV due to load rejection or faults which
require immediate closing of the stop valve, i.e. in case of fault during diffusion to premix
switchover. This step commands the closing of the FO premix emergency stop valve and selects
a fast switch over to diffusion.
Step 19: Not used.
Step 20: The premix percentage is moved from 100% to 0% and as a consequence the FO-
PREMIX-CV starts closing towards the minimum position while the diffusion flow injected in the
combustion chamber increases. This occurs within time K.ANTEIL.10 in case of normal switch
over.
When the change over is terminated the premix line purging takes place. The Purging Sequence
is activated in mode: “PREMIX PURGING”.
Step 21: At this step the feedback signal from the Purging Sequence must be received
confirming that the premix burners purging have been carried out properly.
Step 22: The purging process is over and the FO-seal air ball valve MBN44AA001 is opened again
.The switch over is completed and the FO sequence returns to step 11, diffusion operation. The
fuel change over and the load set point are released. In case of missing of the signal indicating
the opening of the premix seal air valve a GT trip is commanded.
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Fuel oil connection (at change over from gas to oil)
The fuel oil connection in fuel gas operation can occur for two reasons:
§ when the GT is operating in FG mode, the operator manually selects “FO operation” and
all the necessary releases are present (normal fuel changeover);
§ when the GT is operating in FG mode and a pressure decrease in the FG system below
threshold P.GAS.03 is detected (emergency fuel changeover, automatic selection of fuel
oil).
Conditions for fuel change over from gas to oil:
The fuel change over can only occur between fuel gas in PREMIX mode and fuel oil in
DIFFUSION mode. This condition is automatically fulfilled since when connected to the grid the
FG system is operating in premix mode and the FO connection occurs always in diffusion
mode.
The fuel change over occurs in a particular load range which must be proved to be “humming
free”.
Main actions during fuel change over from gas to oil

The GT is running in FG premix mode. After the fuel changeover selection (manual, made by
the operator or automatic, selected by the low FG pressure) the GT controller starts changing
load according to the admissible gradient up to reach the allowable load range for fuel change
over (between G.VLE0.38 and G.VLE0.39), furthermore the TETC set point is shifted to
TT.ATK.86 (by the gradient TTK.ATK.02). When these conditions are met (Fuel C/O range OK)
the load set point is blocked and the FO connection starts.
During fuel change over, with reference to the FO sequence steps (from 23 to 28), the
following actions occur:
Step 23:FG-Premix operation

The FO sequence is activated by the FO selection. The load is changed while the FO forwarding
system receive a command ON and the pilot solenoid valves in the FO diffusion control valves
actuators are energized (step 23). As a result, the FO-DIFFUSION-CV moves to the connection
position.
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Step 24: preparing the FO system.
In order to avoid back flow of hot gases from the combustion chamber into the FO pipes
immediately after the FO valves opening, it is necessary to fill in the return pipe and the
annular manifold with purging water. Therefore the Purging Sequence is activated in mode
“FILLING”. Both the return and the diffusion supply lines are filled with water.
The FO forwarding system is switched ON and as result the pressure before the injection pump
reaches the minimum value (P.HOE.16)
Step25: The fuel oil injection pump is switched ON and the fuel oil pressure increases.
Step 26: Once the filling is completed (Signal from the Purging Sequence), the FO-
DIFFUSIONVL-CV is moved to the position for fuel changeover while the FO-DIFFUSIONRL-CV is
already in the connection position.
At this step the following commands are to be emitted (up to end of fuel change over):
• Pilot increase to change over set point
• Hot/cold spot limit increase
• Humming/acceleration first limit values interlocked
• IGV feed forward action stop.
Step 27: The command OPEN is given to the FO-DIFFUSIONVL-ESV, the same command is given
at the same time to the FO-DIFFUSIONRL-ESV (already open) and the fuel oil starts flowing to
the fuel oil burners. The GT is in temporary mixed operation (FG/FO).
Step 28: When both fuels are operating, a load redistribution between 100% FG to 100% FO
takes place within the proper time. When the FG system is disconnected (see description “FG
operation”), the GT continues to operate only in fuel oil.
At the end of this process the FO sequence shifts to step 11, fuel oil diffusion operation.
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Shut Down branch
In case of standstill program (for protection or selected by the operator), or in the case of GT trip,
the master sequence activates the oil system disconnection and the relevant standstill steps (51).
In addition the following steps are also activated by the fuel controller when disconnecting the
fuel oil system after the fuel change over from oil to gas. In this case the GT will continue
operation in fuel gas mode
Fuel oil system shutdown is actuated at Step 51 of the sequence where the following commands
are issued.
Emergency stop (trip)

Under disturbances which require immediate interruption of GT operation, or by manual trip
activation, the GT emergency stop is released to switch off the FO-system. After fuel change
over from oil to gas, when the FO-DIFFUSIONRL-CV has reached the disconnecting position, the
FO system is disconnected. In addition see description “FG operation”. The protection shut
down sequence is induced by the monitoring time exceeded at certain steps.
NOTE:
In case of diffusion filter clogged (differential pressure MBN13CP101/102/103>P.DFILT.200 in
logic 2v3) a shut down is commanded, not by the fuel oil sequence but by the GT main
sequence. The fuel oil sequence is shut down when the FO ESV’s close.
After the trip release, the following actions occur:

FO-load operation
The GT is in stationary load operation with fuel oil or is just being started, when the start-up
procedure is in a step in which the FO-DIFFUSIONVL-ESV is already open.
Step 51: All FO stop valves receive a close command, all FO control valves receive an OFF
command, the injection pump is switched off, the FO isolating valve is closed .
Step 52: The Purging Sequence is activated in mode “DIFF. PURGING”. The FO-DIFFUSIONRL-CV
is set to the purging position.
Step 53: At the end of the diffusion purging (signal from the Purging Sequence) the FO-
DIFFUSIONRL-CV is closed while the FO-DIFFUSION seal air valve is opened. Now the Purging
Sequence is activated in mode: “PREMIX PURGING”.
Note: it is not possible to reset manually or interrupt the FO Purging during step 52 and 53.
Page 10 of 11
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Step 54: Opening of GT drain valve 1 and 2
At the end of the premix purging (signal from the Purging Sequence) the FO-PREMIX seal air
valve is opened. When speed is below S.TURB.21, the GT drain valves 1 and 2 are opened. They
are kept opened during the remaining part of the shutdown. In this way it is possible to drain
any residual oil from the combustion chamber.
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BHS TURNING SEQUENCE
The lifting oil system supplies high-pressure oil to the gas turbine and generator bearings when the
shaft is moving at low speed in order to avoid friction. In fact at low speed, the lube oil alone cannot
create a sufficient hydrodynamic lubrication film. By means of lifting oil, which is injected to the
bearing recesses below the bearing journals in the rotor shaft, the shaft is lifted and it floats by
hydrostatic way on the oil film.
In order to move the turning device (hydraulic motor and valves for actuation), the Turning Pump is
used.
After any shut down of the gas turbine, it must be kept in slow rotation (e.g. turning gear speed) for a
convenient time (24 hours) to ensure uniform and low flow rate ventilation through the blading. This
procedure, which avoids distortion of casing and rotor (bending), is called cooling turning operation
and it is activated by the BHS turning sequence.
If no faults occur, applying this procedure and maintaining the cooling turning operation for 24 h, the
shaft shall be free to move and GT could be considered in standstill.
After long periods of standstill, the shaft is additionally turned briefly at regular intervals (every 6
hours) in order to check freedom of turning. This operation is called interval turning.
The turning speed is selected to have a sufficient air flow rate for casing uniform cooling but blade
striking must be avoided. Turbine blades are for design reasons set loose in the wheel disks. During
rotation at low speed the blade roots move in the wheel disk grooves and so the blades rattle . High
speed causes the blades to be pressed in their seats by the centrifugal force.
See also section:

General operating instruction TGO3-0033.
SFC emergency turning TGO3-0034 (only when applicable)
The main steps of BHS turning sequence are indicated below:
Abbreviation:
LOP = Lifting Oil Pump
ALOP = Auxiliary Lifting Oil Pump (OPTION)
Page 1 of 4
BHS TURNING SEQUENCE TGO3-0049-E70002
14.07.16
START UP program:
The start up branch is activated by step 51 or step 66 of Lube Oil Sequence.

Release conditions are :
- Lifting oil pressure > min
- Lifting oil pump (LOP or ALOP1) ON
- Speed sensors (GT and turning gear motor) not faulty
- Turning gear valves available
BHS TURNING STARTUP SEQUENCE

1 § Turning gear valves turning gear swivelling 10S
MBV35AA001 / 002 / arm must be NOT
003 close ENGAGED
§ Flow rate control valve
MBV35AA101 closed.
2 The Sequence proceeds to step
3 in case GT speed is >
S.TURB.89 (GT in coast down),
to step 9 in case GT speed is <
S.TURB.89 (GT at standstill) or
in case of bad quality (BQ) of
the speed sensor (GT or
hydraulic motor).
3 § Flow rate control valve § turning gear speed > 50s Active in case GT speed is >
MBV35AA101 set to S.TURB.20. S.TURB.89 (GT in coast down
speed increase.
§ Turning gear valve
MBV35AA003 open
4 Flow rate control valve § speed difference 40s
MBV35AA101 set to between the turning
speed decrease (to gear and the GT shaft >
engage the GT shaft) minimum value (set to
0).
§ Turning Gear engaged
5 No command. speed difference between 20

the turning gear and the
GT shaft > minimum
value (set to 0) and <
maximum value (set to
1
ALOP is an OPTION depending on the project
Page 2 of 4
14.07.16
BHS TURNING STARTUP SEQUENCE
0.02 Hz).
6 Open stop solenoid swivel arm is engaged 10

valves MBV35AA001 /
002 (in order to engage
the swivel arm).
7 Flow rate control valve GT speed shall be not 10 in case of monitoring time
MBV35AA101 is set to lower than S.TURB.20 min exceeding the SFC emergency
speed increase turning is activated
(see TGO3-0034)
8 Lube Oil Sequence: - - - The turning sequence starting
Release for step 51 from GT coast down is ended
9 NO command NO feedback start turning from GT standstill

Active for GT speed <
S.TURB.89
10 Flow rate control valve NO feedback 60s
MBV35AA101 is set to
speed decrease
11 Open stop solenoid swivel arm is NOT 10s
valves MBV35AA001 / disengaged
002 (in order to engage
the swivel arm)
12 § Flow rate control valve swivel arm is engaged 10s
speed increase.
§ Turning gear valve
MBV35AA003 OPEN.
13 § Flow rate control valve GT speed shall be not lower 10min
MBV35AA101 is set to than S.TURB.20
speed increase
14 Lube Oil Sequence: No feedback The interval turning is ended
Release for step 51
Page 3 of 4
14.07.16
SHUT DOWN program:
The shut down branch is activated by step 5 or step 58 or step 67 of Lube Oil Sequence or by the
monitoring time exceeded of step 66 of the Lube Oil Sequence or by the fire protection activated.
In addition the shut down branch is activated also in case of monitoring time exceeded of the BHS
Turning Sequence start up branch, where a monitoring time is stated.
BHS TURNING SHUTDOWN SEQUENCE

51 § Turning gear valves swivelling arm NOT 20s in case of MT exceeding, the
MBV35AA001 / 002 / engaged sequence skips to newt step
003 close
§ Flow rate control valve
MBV35AA101 closed.
52 Flow rate control valve No feedback. 60s
speed decrease
53 Turning Gear pump OFF No feedback 50s
End of sequence
Page 4 of 4
14.07.16
RDS SEQUENCE
The purpose of this section is to give a general guide on operation involving the RDS sequence.
All starting conditions are supposed to be respected.
A gain in efficiency and an increase in power output can be obtained from Gas turbines when the
rotors are shifted in a direction opposite to the direction of flow. Through this action the gaps
between turbine blades and the casing become narrower, and the gaps in the compressor are
increased accordingly.
o RDS Rotor Displacement System
o MAIN Main channel
o SEC Secondary channel
o CH Channel
o RET Return line
o FEED Feed line
See also section:

RDS System TGO2-6001
RDS activation:
For RDS activation, the RDS shall be preselected.

The operator shall pre-select the running RDS pump.
Note: considering AE94.3A, manual activation / deactivation of RDS can be actuated only in case of
IGV position < G.VLE0.300 (90%).
Pressure-free condition:
- RDS system pressure < P.HSO.02
- Main and Second channel unloaded, pressure < P.HSO.06
RDS is off
Page 1 of 15
RDS SEQUENCE TGO3-0050-E00000
29.06.16
Trouble-free condition:
- P.HSO.04 < RDS system pressure < P.HSO.10
- Main channel unloaded, pressure < P.HSO.06
- Second channel loaded, pressure < P.HSO.08
- Shaft in null position
RDS is in deactivated condition
RDS FLOW CHART
K.HSO.04
Step 01 - 06 - RDS STANDARD OPERATION MODE
K.HSO.06
Step 07-14 INTERVAL FLUSHING OF THE MAIN CHANNEL
RDS in auto-mode
(press-free condition) Step 51-58 (FIRST RUN), INITIAL FLUSHING OF THE MAIN AND
THE SEC CHANNEL BEFORE STARTUP
trouble-free condition
Step 59-63 DEACTIVATION OF RDS
K.HSO.06
Step 64-69 INTERVAL FLUSHING OF THE SECONDARY CHANNEL
Page 2 of 15
29.06.16
Sequences
The values here given are only for reference, proper setting are in the Set Point List order related.
In next pictures the following convention is used to show the status of the valves:
Closed Open
Start Up Branch
Step 01-06 (RDS goes to standard operation mode)
Release for RDS activation: Rotor in NULL position and RDS system in TROUBLE FREE operation.
Then valves are driven to the following position:
Fig .1: Standard operating mode
Page 3 of 15
29.06.16
Standard operation mode: rotor in main position (G.HSO.02) and pressure in MAIN channel >
P.HSO.08 (150 bar)
RDS leaves stationary operation (goes to step 07) mode if all of the following are met:
- request of main channel flushing (main channel press > P.HSO.08 for more than
K.HSO.06)
- RDS system pressure > P.HSO.04
- WT (2h) elapsed
Step 1:
The MAIN CH RET valve MBA53AA001 is closed
WT= MT+3s
MT = 2s
Step 2:
Command close is given to the SEC CH FEED valve MBA53AA004
WT= MT+3s
MT = 2s
Step 3:
The SEC CH RET valve MBA53AA005 receives command open
WT= MT+3s
MT = 5s
Step 4:
The MAIN CH FEED valves MBA53AA002/MBA53AA006 are opened. The MAIN set memory
is enabled for monitoring the time K.HSO.06 (e.g. 12 h)
(The MAIN CH FEED MBA53AA006 may be opened only if the MBA53AA003 is NOT OPEN, in
order to prevent that the shaft may be shifted too quickly).
WT= MT+3s
MT = 2s
Step 5 (RDS in standard operation mode):

No command.
This step is required to wait the shaft to move to main position.
As feedback to proceed, MAIN CH RET pressure must be >P.HSO.08 and shaft must have
reached the G.HSO.02 position, or WT is exceeded
WT= MT+3s
MT = K.HSO.05
Page 4 of 15
29.06.16
Step 6:
The gas turbine is now in a stationary RDS operation mode. The sequence stays in
this step until the purging of the main channel is required, i.e after 12 h
The sequence proceeds if the following conditions are all met: RDS system press >P.HSO.04,
MAIN flush memory set ON and WT has elapsed.
WT= 720min
MT = //
Step 07-14 (flushing of the main channel)
Valves are driven to the following position:
Fig .2: Main channel flushing
Sequence goes to next step (main in operation flushing accomplished) if one of the following is met:
- RDS pump in operation

- RDS system pressure < P.HSO.04 (160 bar)
- Main channel pressure < P.HSO.11 (150 bar)
- WT elapsed (32s)
Page 5 of 15
29.06.16
Then valves driven again to standard operation mode
Fig .3: Standard operating mode
RDS in standard operation mode again

The sequence goes again to step 6 (to repeat flushing procedure after K.HSO.06)
Step 7 (start main channel purging):

The preselected pump receives command on.
WT= MT+2s
MT = K.HSO.03
Step 8:
The MAIN CH FEED valves MBA53AA003 is opened
WT= MT+2s
MT = 2s
Step 9 :
The MAIN CH RET valves MBA53AA001 is opened
WT= MT+2s
MT = 2s
Step 10:
Command again to MAIN CH RET valves MBA53AA001. In this step flushing procedure is
carried out.
If at least one RDS pump is in operation, RDS pressure < P.HSO.04, MAIN CH RET pressure <
P.HSO.11 or WT has elapsed, the flushing procedure is to be considered completed.
WT= MT+2s
MT = K.HSO.08+10s
Page 6 of 15
29.06.16
Step 11:
The MAIN CH RET valve MBA53AA001 is closed.
WT= MT+2s
MT = 2s
Step 12:
The MAIN CH FEED valve MBA53AA003 is closed.
WT= MT+2s
MT = 2s
Step 13:
No command
WT=MT+2s
MT=2s
Step 14:
Main flush memory set ON, monitoring time K.HSO.06 reset.
After WT has elapsed, the sequence is driven to step 6 again.
WT=1s
MT =//
Shut-down Sequence
Page 7 of 15
29.06.16
Step 51-58 First run, (Flushing of the main and the sec channel before startup)
If the following conditions are met:

- GT speed < S.TURB.05 (4 Hz)
Then RDS system is considered as at a FIRST RUN, then LOP activated (to give a slight shifting to the
shaft) and valves are driven in such a position to perform the flushing of the main channel at RDS
first run.
Fig .4: Main channel flushing at FIRST RUN
Page 8 of 15
29.06.16
Then valves are driven in such a position to perform the flushing of the sec channel at RDS first run
Fig .5: Secondary channel flushing at FIRST RUN
Sequence goes to next step (first run secondary CH flushing accomplished) if one of the following is
met:
- Main channel pressure > P.HSO.09 (140 bar) and all main valves opened at least for
K.HSO.01 (30s)
- WT elapsed (34s)
Step 51:
No command
The sequence goes to step 52 if GT speed is < S.TURB.05 with pressure-free RDS system
because flushing steps are requested.
If this is not the case, the flushing steps are skipped and the sequence goes to step 59 (i.e
flushing not requested and not performed).
WT= //
MT = //
Step 52 (start flushing the main channel):

It opens the Main Channel Return MBA53AA001, opens the Sec Channel Return
MBA53AA005, closes the Sec Channel feed MBA53AA004, closes the Main Channel feed
MBA53AA002, MBA53AA003 and MBA53AA006, and Commands the Main Lift Oil Pump
ON.
(It resets the system in order to restore the initial conditions).
WT= 30 s
MT = //
Page 9 of 15
29.06.16
Step 53:
The MAIN CH RET (MBA53AA001) , MAIN CH FEED (MBA53AA002/006), SEC CH RET
(MBA53AA005) valves are opened; while SEC CH FEED (MBA53AA004) and MAIN CH FEED
(MBA53AA003) are closed.
WT=MT+2s
MT=2s
Step 54:
Command ON is given to both RDS pumps.
WT=MT+2s
MT=2s
Step 55:
No command
WT=
MT=40s
Step 56:
No command.
The sequence proceeds if the “main channel flushing not required” is active or WT has
elapsed.
WT=K.HSO.01
MT=MT+2s
Step 57 (start flushing secondary channel)

The MAIN CH FEED valves MBA53AA002/006 are closed and the SEC CH FEED MBA53AA004
is opened.
The sequence proceeds if the valves are all in the requested positions or WT has elapsed
MT=2s
WT=MT+2s
Step 58:
No command.
The sequence proceeds if the “secondary channel flushing not required” is active or WT has
elapsed
MT=K.HSO.01+2s
WT=MT+2s
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29.06.16
Step 59-63 (DEACTIVATION OF RDS)
Valves position:
Fig .6: RDS in deactivated condition
Page 11 of 15
29.06.16
Step 64-69 (Flushing of the secondary channel)
If
- RDS syst press > P.HSO.04 (140 bar)
- Secondary channel activated for more than K.HSO.06
Then secondary channel operating flushing is performed
Valves are then driven to the following position
Fig .7: Flushing of the secondary channel
Page 12 of 15
29.06.16
Secondary channel flushing is accomplished if one of the following is met:

- At least on RDS pump in operation
- Secondary channel pressure < P.HSO.09 (140 bar, min press in activ channel)
- WT elapsed
Valves are driven again to de-activated condition
Fig .8: RDS in deactivated condition
Sequence goes back to step 64 to perform interval turning of the secondary channel after K.HSO.06.
Step 59 (start deactivation of RDS system):

At this Step the sequence will arrive from Step 51 if GT speed is NOT < S.TURB.05,
with RDS system pressurized.
The MAIN CH FEED MBA53AA002/003 and MBA53AA006 valves are closed
MT=2s
WT=MT+3s
Step 60:
The SEC CH RET valve MBA53AA005 is closed
MT=2s
WT=MT+3s
Page 13 of 15
29.06.16
Step 61:
The MAIN CH RET valve MBA53AA001 is opened
MT=2s
WT=MT+3s
Step 62:
The SEC CH FEED valve MBA53AA004 is opened and the MAIN memory is set (start
monitoring time K.HSO.06 – 12 h)
MT=2s
WT=MT+3s
Step 63:
No command
To proceed all these conditions must be fulfilled: pressure MAIN CH RET < P.HSO.06,
pressure SEC CH RET > P.HSO.08, rotor in null position (G.HSO.01). The sequence goes to
next step if the previous conditions are present or WT has elapsed.
MT=K.HSO.11
WT=MT+3s
Step 64:
RDS system is now in deactivated condition.
(The sequence will remain in this position till a sec refreshing oil action is active, that is after
720 min –12 h).
The shutdown memory monitoring time is stopped.
The sequence proceeds if the following conditions are met: RDS pressure > P.HSO.04 and
SEC flushing memory is set ON or WT has elapsed.
WT= 120min
MT = //
Step 65:
The preselected RDS pump is switched on
If the system pressure has dropped below the values P.HSO.05, the accumulator shall be
filled before the flushing procedure.
As feedback to proceed: both pumps must be OFF and RDS pressure is > P.HSO.05.
If this is not the case the sequence goes back to previous step 64.
MT=K.HSO.03
WT=MT+3s
Page 14 of 15
29.06.16
Step 66 (flushing secondary channel):
The SEC CH RET valve MBA53AA005 is opened
MT=2s
WT=MT+2s
Step 67:
Command open repeated for the SEC CH RET valve MBA53AA005.
MT=K.HSO.13+10s
WT=MT+2s
Step 68:
The SEC CH RET valve MBA53AA005 is closed
As feedback to proceed the SEC CH RET valve must be closed and the SEC flush memory is
NOT ON. Furthermore, the sequence skips to next step if WT has elapsed.
MT=2s
WT=MT+2s
Step 69:
Interval flushing is now ended. The monitoring time K.HSO.06 is reset.
After elapsing WT, the sequence goes back to step 64
MT=//
WT=1s
Page 15 of 15
29.06.16
GT STARTING – PURGING SEQUENCE
The purpose of this section is to give a general guide on operation involving the purging operation
always connected to fuel oil operation.
The Master Sequence and the Fuel Oil Sequence are supposed to be known.
NG = fuel gas , FO = fuel oil , CV = control valve , ESV = emergency stop valve RET = return
DO = diffusion operation; PO = premix operation
Also the fuel oil sequencer consists of a series of steps.
The Purging sequence has no shut down branch, a reset memory is used to bring the sequence at
standstill.
See also section:

Purging water system description TGO2-3007
Fuel Oil Sequence TGO3-0048
Page 1 of 15
GT STARTING –PURGING SEQUENCE TGO3-0051-E72000
20.11.2014
Purging Sequence
The purging sequence is automatically initiated in the following cases:

Ø PREMIX COOLING: FO Sequence step 14 (at beginning of the switch over from DO to PO in
order to cool the premix burners before the fuel oil ingress)
Ø PREMIX PURGE: FO Sequence step 19 (after premix mode, when switch back in diffusion
mode in order to purge premix line and burners)
Ø At FO TRIP: when closing both ESV (DO & PO) or closing of FO PO ESV only (for instance in
case of load rejection from premix mode). The diffusion line is purged as well.
Ø FO FILLING: FO Sequence step 24 (during the fuel change over from gas to oil in order to
fill the fuel oil diffusion line)
Ø FUEL CHANGE OVER FROM OIL TO GAS: NG Sequence step 24 (in order to purge the fuel
oil diffusion system and burners after fuel oil operation)
Ø FO DIFFUSION MANUAL PURGE: manual command start to the diffusion line (active only
with GT at standstill)
Ø FO PREMIX MANUAL PURGE: manual command start to the premix line (active only with
GT at standstill)
The general structure of the purging sequence is shown in figure 1.
Step 00 – Standstill Stage

After each branch, a reset to step 00 is performed. The reset consists of the following commands:
§ WATER CONTROL VALVE CLOSE
§ PURGING PUMP OFF
§ WATER CONTROL VALVE FLOW SET POINT RESET
§ WATER SHUTOFF VALVES CLOSE
§ WATER DRAIN VLV MBN82AA052 CLOSE
Step 01
Command
§ PURGE WATER PUMP ON
Feedback
§ PRESS DWNSTR WATER PMP MBN82CP101/102 > P.SPUEL.100
WT = 2 s
MT = 10 s
Page 2 of 15
20.11.2014
Step 02
This step is used to discriminate which type of purging is to be initiated (see figure 1).
WT = 1 s
MT = 5 s
Page 3 of 15
20.11.2014
Figure 1 :
Structure of the Purging Sequence
Page 4 of 15
20.11.2014
PREMIX COOLING ( CHANGE OVER FROM FO DO TO FO PO)
Step 03
Command
§ WATER CV AT FLOW F.EMUSPU.100
§ DRAIN VLV MBN82AA052 CLOSE
Feedback
§ PRESS DWNSTR WATER PMP MBN82CP101/102 > P.SPUEL.100
WT = 4 s
MT =15 s
Step 04
Command
§ PO RING WATER VALVES OPEN
Feedback
§ MBN84AA053/054 OPEN OR
MBN82CF101>F.EMUSPU.200 AND MBN84AA053/054 NOT CLOSE
§ MBN82CP103/104 > PP.EMUSPU.100
WT = 20 s (K.EMUSPU.100)
MT = 25 s
Step 05
Command
Feedback
WT = 2 s
MT = 40 s
Page 5 of 15
20.11.2014
Step 06
Command
§ FEEDBACK TO FO STARTUP SEQUENCE – STEP 14
Feedback
§ FEEDBACK FROM FO STARTUP SEQUENCE – FEEDBACK STEP 16
WT = 2 s
MT = 90 s
Step 07
No command and no feedback (spare step)
WT = 2 s
MT = 5 s
Step 05
Command
No feedback (go to next step for MT exceeding)
WT = 2 s
MT = 60 s
Reset, go to step 00
Page 6 of 15
20.11.2014
PURGE FO TO FG ( PURGING C/O FROM FO TO FG )
Step 11
Command
§ FO DO MIN FLOW SET TO F.SPUDB.02-04
§ OPEN WATER CV AT FLOW F.SPUDB.101
Feedback
§ MBN82AA151 POS. > 2%
§ PRESS DWNSTR WATER PMP MBN82CP101/102 > 50 bar
§ MBN14AA051 CLOSED
WT = 2 s
MT = 120 s
Step 12
Command
§ FO DO WATER SHUTOFF VLVS OPEN
§ FO RET ESV OPEN
§ FO RET CV AT PURGE FLOW F.SPUDB.02-04
Feedback
§ MBN52AA051 OPENED
§ MBN14CP101/102 – MBA11CP102/103 > PP.HOEDB.101
WT = 15 s
MT = 20 s
Step 13
Command
§ FO DO SEAL AIR VLV OPEN
§ FO RET CV AT PURGE FLOW F.SPUDB.06-08
Feedback
§ MBN14CP101/102 – MBA11CP102/103 > PP.HOEDB.101
§ MBN34AA001 OPENED
WT = 10 s
MT = 20 s
Page 7 of 15
20.11.2014
PURGE FG TO FO (FILLING DO LINE BEFORE C/O FROM FG)
Step 20
Command
§ WATER CV ENERGIZE
§ OPEN WATER CV AT FLOW F.FILL.100
Feedback
§ MBN82AA151 POS. > 2%
WT = 2 s
MT = 5 s
Step 21
Command
§ FO RET WATER SHUTOFF VLVS OPEN
Feedback
§ MBN52CP101 > P.FUELL.01
WT = 15 s
MT = 20 s
Step 22
Command
§ FO RET WATER SHUTOFF VLVS CLOSE
Feedback
§ MBN83AA053/054 CLOSED
§ MBN82AA151 POS. > 2%
§ DP DWNSTR WATER CV – C.C. MBN82CP103/104 > PP.SPUEL.101 ( 3 bar )
WT = 2 s
MT = 3 s
Page 8 of 15
20.11.2014
Step 23
Command
Feedback
§ DP DWNSTR WATER CV – C.C. MBN82CP103/104 > PP.SPUEL.101 ( 3 bar )
§ MBN52CP101 > P.FUELL.01
WT = K.PURGE.101( 10 s)
MT = 15 s
Step 24
Command
§ FO DO WATER SHUTOFF VLVS CLOSE
§ FO DO SEAL AIR VLV CLOSE
Feedback
WT = 2 s
MT = 15 s
PREMIX PURGE (SWITCH OVER FROM FOPO TO FO DO)
Step 29
Command
§ OPEN WATER CV AT FLOW F.EMUSPU.103
Feedback
§ MBN82AA151 POS. > 2%
WT = 1 s
MT = 5 s
Page 9 of 15
20.11.2014
Step 30
Command
§ PO RING WATER VALVES OPEN
Feedback
WT = 3 s
MT = 5 s
Step 31
Command
Feedback
WT = 3 s
MT = 40 s
Step 32
Command
Feedback
WT = 2 s
MT = 100 s
Page 10 of 15
20.11.2014
Step 33
Command
Feedback
MT = 20 s
Step 34
Command
§ OPEN WATER CV AT FLOW F.EMUSPU.1XX
§ PO RING WATER VALVES CLOSE
§ PO PURGE WATER VALVES OPEN
§ FO PREMIX DRAIN VLAVES OPEN
Feedback
§ MBN84AA053/054 CLOSE
MT = 10 s
Step 35
Command
§ PO PURGE WATER VALVES CLOSE
§ PURGE WATER PUMP OFF
§ WATER CONTROL VALVE FLOW SET POINT RESET
Feedback
§ MBN44AA001 OPEN DELAYED 60 s
WT = 2 s
MT = 80 s
Page 11 of 15
20.11.2014
Step 36
Command
§ FO PREMIX DRAIN VALVES OPEN
Feedback
WT = 5 s
MT = 10 s
PURGING AFTER FO TRIP / MANUAL PURGING
Step 44
Command
§ WATER CV ENERGIZE
§ OPEN WATER CV AT FLOW F.SPUDB.100
§ FO DO SEAL AIR VLV CLOSE
Feedback
§ MBN82AA151 POS. > 2%
WT = 1 s
MT = 20 s
Step 45
Command
§ OPEN FO RB CV AT FLOW F.SPUDB.100
§ FO RET ESV OPEN
Feedback
WT = K.SPUDB.01 (20 s)
MT = 30 s
Page 12 of 15
20.11.2014
Step 46
Command
§ FO DO WATER SHUTOFF VLVS CLOSE
§ FO DO SEAL AIR VLV OPEN (command active in case of manual purging)
Feedback
§ MBN34AA001 OPEN
§ MBN14AA051 CLOSE DELAYED (K.SPUVB.08 = 100 s)
WT = 2 s
MT = K.SPUVB.08 + 5 s (105 s)
In case of trip from FO premix, sequence proceeds at step 47

In case of trip from FO diffusion, sequence is ended and reset to step 00
Step 47
Command
§ FO PO SEAL AIR VLV CLOSE (command active in case of manual purging)
Feedabck
§ FO SHUTDOWN SEQ STEP 53 OR SPEED < S.TURB.05
WT = 1 s
MT = 20 s
Step 48
Command
Feedback
§ MBN82AA151 POS. > 5%
§ MBN82AP001 ON
WT = K.SPUVB.01 (20 s)
MT = 25 s
Page 13 of 15
20.11.2014
Step 49
Command
§ PO PURGE WATER VALVES CLOSED
Feedback
WT = 2 s
MT = 5 s
Step 50
Command
§ PREMIX DRAIN VLVS OPEN
Feedback
§ MBN45AA001 OPEN AND MBN45AA002 OPEN
WT = K.LEER.08 – 10s (90 s)
MT = 95 s
Step 51
No command and no feedback (spare step)
WT = 1 s
MT = 5 s
Step 52
Command
Feedback
WT = 20 s (K.SPUVB.101)
MT = 25 s
Step 53
Command
§ PO PURGE WATER VALVES CLOSE
Feedback
WT = 20 s
MT = 25 s
Page 14 of 15
20.11.2014
Step 54
Command
§ PREMIX DRAIN VLVS OPEN
Feedback
§ MBN45AA001 OPEN AND MBN45AA002 OPEN
WT = K.LEER.100 (5 s)
MT = 10 s
Step 55
Command
§ PREMIX DRAIN VLVS CLOSED
§ FO PURGING SEQUENCE RESET
Feedback
§ MBN45AA001 OPEN OR MBN45AA002 CLOSED
WT = 2 s
MT = 25 s
Page 15 of 15
20.11.2014
CONTROL SYSTEM OPERATION
Gas Turbine Control System Configuration

The gas turbine is controlled by means of an electronic digital control system which is integrated into
the redundantly configured automation system .
The GT control system uses the following individual controllers:
Ø Speed controller
Ø Load controller
Ø Exhaust gas temperature controller
Ø Load limiter
Ø Compressor ratio limit controller(β)
Output signals from these controllers are passed through a minimum (MIN) gate which determines
any control action to be initiated by the master controller. The active controller is indicated optically
on the control room console.
Operation with Speed Controller

During GT start up, the run-up start up function accelerates the rotor up to abut nominal speed
(open loop control, see section TGO2-0116).
The speed controller cuts in and overrides the startup control loop above a specified speed range
(e.g. 97% of nominal speed).
The speed controller governs the turbine during final run up to rated or synchronization speed. This
control function is performed automatically. The operator has the possibility to adjust the nominal
speed set point value around nominal speed (47.6 – 51.4 Hz)
The speed controller is primarily used during no-load operation before the GT is synchronized to the
grid.
Page 1 of 3
CONTROL SYSTEM OPERATION TGO3-0055-E00000
17.11.2014
Operation with Load Controller
The load controller is automatically activated when the generator circuit breaker has been closed
after synchronization.
The load controller increases or reduces load in line with the selected target value. This is set by
means of the load set-point adjuster control and is displayed on the load set-point panel.
The operator shall specify the load target value before activating the subgroup control operating
program.
Load variations are possible according to the allowed load gradients
(see section TGO2-0120).
The load controller takes over the GT control in the power range from synchronization to base load
(base load excluded).
The load controller is switched off when the GT is disconnected from the grid (e.g. load rejection).
In order to take into account the frequency contribute, the load controller is subdue to a frequency
influence. In case of frequency variation, this has effect on the load controller set point too. The
frequency influence has no effect in case of 50 Hz operation.
Operation with Exhaust Gas Temperature (TETC) Controller

This controller limits the TETC turbine outlet temperature when the base load temperature has been
reached. Further load increases are thus avoided when the base load temperature is reached.
The GT is under turbine outlet control (TETC control) only when it is at base load. See in addition
section TGO3-0100.
The temperature controller is deactivated at any load reduction, i.e. when the exhaust gas
temperature decreases below the base load value.
Operation with Load Limiter

This controller limits the turbine maximum permissible mechanical load. Conditions can occur at low
intake temperature and power augmentation operation (if foreseen) which could increase the gas
turbine mass flow and active power without reaching the maximum inlet temperature. Control
action by this controller excludes the load controller and interrupts loading, preventing any further
load increases.
The maximum permitted load E.LEIST.23 is specified by the GT Manufacturer and is permanently
implemented in the control system (see Set Point List, section TGO1-0530).
Page 2 of 3
17.11.2014
Operation with Compressor Ratio Limit Controller
The compression ratio limiting device (short: β-controller) has the task of preventing inadmissible
operating conditions on the compressor.
In order to take a safety distance between the operating point and the instability limit of the
compressor, i.e. the surge limit, a limiting curve is be implemented. If this limiting curve is reached,
the following countermeasures are taken:
1. When approaching the limiting curve slowly
The IGV are opened further, the fuel mass flow is reduced accordingly.
NOTE: In case the frequency goes below a certain value, if GT is approaching the surge limiting curve,
the IGV opening can be dangerous cause it shortens the distance from the limiting curve. In this case
IGV can be opened up to a maximum allowable IGV position.
2. When approaching the limiting curve rapidly
the fuel mass flow is quickly reduced in order to decrease the compressor delivery side pressure so
that the operating point remains below the compressor instability limit.
During normal gas turbine operation, the operating point should always be below the limiting curve
and the β-controller is not active.
See also section:

Exhaust gas temperature controller TGO3-0100
Page 3 of 3
17.11.2014
UNUSUAL OPERATING CONDITIONS
This section gives details of disturbances which can occur during gas turbine operation.
These brief instructions are intended to enable the operating personnel to react appropriately to
disturbances and thus on the one hand keep gas turbine outages to a minimum by taking the correct
action and prevent damage to the turbine generator on the other.
Procedure in the Event of Serious Disturbances

If a fault occurs which is of such a serious nature that the services of the GT manufacturer must be
requested, attention must be paid to certain significant details to enable assessment of the
disturbance or the damage.
After occurrence of the fault, the plant should immediately be placed in an operationally safe
condition. During the fact-finding inspection and investigation into the cause of the fault, operating
records such as strip charts, operating logs, records from the alarm printer and observations by
operating personnel should always be referred to.
Damaged equipment should be left untouched as far as possible, as agreed upon with the
manufacturer, so that the original condition is still available for the fact-finding inspection.
It is advisable in all cases to contact the GT Manufacturer to determine immediate remedial action,
so that targeted repairs or other measures can be initiated.
The following instructions are given:

1. Gas turbine trip
2. Fire Protection
3. Loss in AC power supply
4. Shaft distortion in case of turning gear procedure fault
5. Operation with open blow off valves
6. Closing the intake damper
Page 1 of 5
UNUSUAL OPERATING CONDITIONS TGO3-0060-E70001
17.11.14
1. Gas turbine trip
1.1 Manual Trip

The operator has always the possibility to push the relevant button for activating the GT trip. It is
also available a manual button for activating the fire protection trip.
In case of disturbance regarding the GT safety or the personnel security, the operator must
immediately press the GT trip button and, if necessary, the fire protection trip activation.
Warning:
the operator shall be aware of the risk of activating the fire protection GT trip button. In
this case the lube oil pumps will be stopped by the fire protection activation. The fire
protection activation must be manually released only in case of absolute necessity.
1.2 Actions to be taken after a GT Trip

 Identify the reason which caused the GT trip and store all the recorded data.
 Be sure the GT is in turning gear operation.
 In case of manual trip, check the reason which induced to push the GT manual button.
 Check the GT history before and after the accident.
 Identify and remove the trip causes.
Warning:
the GT must NOT be started again until the trip causes have been identified and removed.
Page 2 of 5
17.11.14
2. Fire Protection
Push the manual button for fire protection activation in case of fire in the building where the gas
turbine is located.
Push the manual button for fire protection activation in case of fast decreasing in the lube oil tank.
 In case of fire detection activated, the main- and auxiliary lube oil pump are switched off and
the emergency lube oil pump is switched on by automatic control.
 Also the lifting oil pump is switched off by a protective command.
 The BHS turning sequence is interlocked and the GT turning cannot be performed.
In case of fire protection, there is the possibility to switch OFF manually also the emergency oil
pump. In this case serious damage to the gas turbine occur.
The operator must evaluate the possible damage and what decision is to be taken.
In case of real fire, check that all the lifting oil pumps are OFF
Switch off also the emergency oil pump in case of any damage to the personnel.
Check which fire protection system has been activated and in what area of the plant.
Inform the fire brigades.
Follow specific instructions regarding the safety procedures.
Reset the fire protection when the safety conditions have been reached.
Page 3 of 5
17.11.14
3. Loss in AC power supply
In case of loss of the AC power supply, the GT is tripped and it coasts down with the emergency oil
pump running.
In this case it is not permitted to switch off the emergency lube oil pump.
On the contrary, it must be kept in operation as long as it is possible in order to cool the bearings.
Since the DC batteries have a limited capacity, it is necessary to restore the AC supply in order to
avoid shaft distortion. See point 4.
4. Shaft distortion in case of turning gear procedure fault
In case it is not possible to carry out the turning gear procedure (for instance, due to point 3.), the
shaft will be deformed. The distortion will not be a permanent one, however:
 It is not possible to immediately start up the GT by SFC, it would cause serious damage to
the blades.
 It is not possible to use the procedure cooling by SFC turning.
The following instructions must be followed:

 Activate the lube oil sequence as soon as possible
 Switch ON the lifting oil pump and try to turn manually the shaft using the barring gear
device. In case the shaft does not move, keep at standstill the shaft for 24 hours. After this
periods, generally, the shaft will move with no problem (because the distortion is recovered).
 As soon as it is possible to rotate the shaft by the manual barring device, activate the
sequence of the BHS turning.
 Keep the GT in turning mode with no interruption for at least 6 hours.
 After what above it is possible to restart the GT as usual.
Warning: risk of people injury or equipment damage

Be sure to disconnect the BHS Turning sequence before using the barring gear (manual turning).
Page 4 of 5
17.11.14
5. Operation with open blow off valves
The operation with open blow off valves is only permitted during the start up and the coast down.
When the nominal speed is reached, the blow off valves must be kept closed.
The GT operation at load with one or more open blow off valves is not allowed since the
compressor blades can be damaged (vibrations) and therefore this operating condition is not
permitted.
It is absolutely necessary that the blow off valves are correctly operated.
In case the blow off valves are opened due to a human error and it is not possible to close it
immediately, the GT must be immediately shut down by GT trip.
It is not possible to start the GT again if the trouble occurred at the blow off valves has not been
rectified.
6. Closing the intake damper
During the GT operation the intake damper must be kept opened. GT trip occurs in case of closure of
the intake damper. The open position of the intake damper is a release criteria for the GT start up.
After the shut down, the intake damper is automatically closed after 2 hours of turning operation.
From necessity, it is possible to reduce this time to 1 hour.
It is not allowed to close the intake damper before 1 hour of turning operation since the air flow
for the turning cooling operation will not be sufficient.
The same criteria is applied in case of closing device (if any) to the exhaust system.
Page 5 of 5
17.11.14
RDS SYSTEM ADJUSTING
The following actions must be taken in case of prolonged standstill of the gas turbine or after a major
inspection, or any time the RDS system has been isolated for maintenance or repairing job.
Adjustment of the linear measuring system

The measuring transducers are so installed that the complete shift way of the shaft lies about in the
middle of the recording measuring range. The shaft is brought into the MAIN position, where the
measuring recorders indicate maximum shift way, namely the initial and end values are to be
adjusted accordingly.
Moreover, during a parameterization it should be taken into account that by shifting the shaft in the
direction of MAIN position, the distance to the measuring recorder becomes shorter, i.e. the electric
signal given by the recorder is required but in a reverse behaviour, namely with a departure of the
MAIN in the direction of the RDS activated position, the value measured for the shift way must
become bigger.
Pressure reduction in RDS system during cooling down turning
After shutting down the GT, the RDS system is depressurized by switching off the lubrication oil
system after a 24-hour cooling down turning.
To be enabled to do work at the RDS system already during the cooling down turning, the RDS
system can be manually depressurized by carrying out the following actions.
A fundamental condition is that GT speed is < S.TURB.05.
§ Switch off RDS pumps
§ Switch off RDS-SEQUENCE
§ Open secondary channel return solenoid valve (MBA53AA005)
The pressure in the RDS system has now decayed and the work can be brought to completion.
When the lubrication oil has been drained from the RDS system, maintenance work on RDS system
can be done. After that, fill again RDS System with lube oil (see paragraph: “First fill-up of RDS
system”.
When the RDS system is filled with lube oil, the RDS-Sequence is switched on for automatic
operation, what makes the standstill branch automatically activated. Since during the load decrease
the system pressure dropped below P.HSO.02, .it is first carried out the flushing and venting of the
main and the secondary channels. After it, the solenoid valves are set through RDS-Sequence, so
that the shaft can be shifted to the secondary channel position, whereas the secondary channel
pistons are invested with pressure.
Page 1 of 2
RDS SYSTEM ADJUSTING TGO3-0070-E00000
17.11.14
WARNING:
When a trouble caused the RDS to be switched-off, a new switch-on by hand is allowable after
trouble shooting is completed.
Upon signals whose origin may be a seizure of pistons, or when there is a danger for damages
to the bearings, a new start of the GT is allowed only after consulting the Ansaldo Energia Gas
Turbine Engineering Department.
The closure of not usable optional test points must be checked during commissioning and a
regularly maintenance activity conducted to avoid potential leakage points.
WARNING:
It is suggested to keep in AUTO operation the RDS system once it has been activated (i.e.
automatic disconnection will occur during shut down when reaching the proper speed setting).
See in addition:
RDS System, description TGO2-6001
Page 2 of 2
RDS SYSTEM ADJUSTING TGO3-0070-E00000
17.11.14
EXHAUST GAS TEMPERATURE CONTROL
The purpose of the exhaust temperature control is to operate the gas turbine with an optimized
inlet temperature at almost any base load conditions. In fact at base load it is important to operate
the gas turbine at the proper inlet temperature: if the inlet temperature is too high this could lead to
damages and thermal stress on hot components, if it is too low this means bad gas turbine
performance and underemployment .
Since it is not possible to measure in a reliable way the inlet temperature (due to the very high
values), the exhaust gas temperature is used. The inlet temperature is related to the exhaust
temperature by a correlation involving compressor inlet temperature and rotation speed.
By means of this correlation, it is possible to operate the gas turbine at constant exhaust gas
temperature and at the same time at almost constant turbine inlet temperature.
Calculation of the Correct Turbine Exhaust Temperature (TETC)
The TETC is calculated using the following measures:
- Exhaust gas temperature (TET): it is measured directly downstream the turbine by means of 24
triple thermocouples (MBA26CT101124) which are located along the circumference of the
exhaust gas diffuser. To have a better representation of the average temperature, the average of
the 24 thermocouples may be corrected by a second average calculated by means of 6
thermocouples located at the end of the exhaust gas diffuser duct. The average value of turbine
exhaust temperature is attained by the average value of the 24 thermocouples in case of fast load
variations and by the average value of the 6 thermocouples in case of base load operation and
slow load variations. For the GT control, the channel B and C of each thermocouple are used.
- Compressor inlet temperature (TCI): it is measured at compressor inlet by means of 4
thermoresistances (from MBA11CT101 to …..104). The average of the temperature measured is
calculated from channel A of all 4 thermoresistances.
- Ratio between the real rotation speed N (measured by MBA10CS101/2/3) and the nominal speed
N0. N/N0 is significant only in the case of GT operation in over/under frequency.
Starting from the above variables, therefore, TETC is the result of:
TETC = TET – (K1+K3 x TCI) x TCI – (1 – n/n0) x K2
Page 1 of 2
EXHAUST GAS TEMPERATURE CONTROL TGO3-0100-E70001
12.10.17
K1 = non dimensional constant, influenced by compressor intake temperature (e.g.0,37)
K2 = speed correction constant [°C] (e.g.200)
K3 = constant [1/°C]. for special climatic conditions (e.g. 0,007)
The TETC value is the controlled variable at base load.
The set point of the TETC is established according to the gas turbine configuration and according to
the selected fuel.
For different configuration (e.g. simple and combined cycle) and for different fuels (e.g. gas and oil)
the set points are different.
For instance it applies:
TT.ATK.GLGAS = set point for TETC controller in fuel gas operation, simple cycle
TT.ATK.GLKGAS = set point for TETC controller in fuel gas operation, combined cycle
TT.ATK.GLOIL = set point for TETC controller in fuel oil operation, simple cycle
TT.ATK.GLKOIL = set point for TETC controller in fuel oil operation, combined cycle
according to the applicable configuration.
The above temperature set points are further corrected according to the following correction curves:
-NOx derating curve: it is a function by which the TETC set point is reduced as a function of the
ambient temperature and relative humidity in order to avoid NOx emissions to increase above
certain values if the ambient temperature goes below 15°C.
-DIGV curve: at partial loads (IGV controller active), in order to regulate the GT at a lower
temperature than the base load one in order to avoid combustion instability phenomena, a DIGV
curve as a function of ambient temperature is implemented, reducing then the TETC set point when
the GT is operated at partial load.
- Fuel composition (C/H ratio) curve: according to the type of fuel, the temperature set can be
changed in order to maintain the emissions. For this purpose the ratio between C and H is calculated
and the temperature set point is corrected as function of this ratio (deviation from the contractual
fuel is corrected).
Final values are properly established and set only after all commissioning operations and according
the results of the guaranteed performance tests.
See also section:

Setting of temperature limits at turbine outlet TGO2-0114
Page 2 of 2
EXHAUST GAS TEMPERATURE CONTROL TGO3-0100-E70001
12.10.17
EXHAUST GAS TEMPERATURE PROTECTION
The gas turbine protection logics from too high exhaust gas temperature follow the same principle
than indicated for the turbine exhaust gas temperature (TETC) control . Refer to section TGO3-0100.
Each thermocouple is corrected with the compressor inlet temperature and the speed factor
according to the formula:
TETC = TET – (K1+K3 x TCI) x TCI – (1 – n/n0) x K2
For the exhaust temperature protection purposes, the channel B and C of the 24 thermocouples, at
the GT outlet are used. The reference value TETAV is calculated by the average of the 24 B/C
channels. In addition, also the each 4th B element is used at 3 of 6 measuring points (OR logic). The
quality of the signal is constantly monitored, the channel is considered faulty if its value deviates
more than the quantity TT.AT.06 (ex 100° C) from the average of the remaining channels or if an
electrical fault is detected. In this case for the calculation of the average the faulty signal is removed,
instead for the monitoring of the temperature distribution its value is replaced by the other channel
of the same measuring point; in case both the B/C channels of the same thermocouples are faulty a
GT shut down is issued.
There are two main protections for the exhaust gas temperature:
-HOT SPOT protection
The hot spot protection is based on the monitoring of temperature profile in the turbine outlet. The
monitoring “too much fuel at single burner” is activated at TETC > TT.ATK.11 and speed > S.TURB.70.
The following thresholds are used:
 TET > TETAV + TT.AT.01 + dynamic offset for alarm  alarm

 TET > TETAV + TT.AT.02 + dynamic offset for trip  GT TRIP
In case of FO –DO operation:
 TET > TETAV + TT.ATG.01 + dynamic offset for alarm  alarm

 TET > TETAV + TT.ATG.02 + dynamic offset for trip  GT TRIP
In case of FO -PO operation:
 TET > TETAV + TT.ATG.03 + dynamic offset for alarm  alarm

 TET > TETAV + TT.ATG.04 + dynamic offset for trip  GT TRIP
-COLD SPOT PROTECTION
The detection of a loosing flame occurs by the monitoring of the symmetry of the temperature
Page 1 of 4
EXHAUST GAS TEMPERATURE PROTECTION TGO3-0110-E72003
12.10.17
profile. The detection of a burner off occurs by comparing the average TETAV with a decrease
TT.AT.03 + dynamic offset with a criterion shown in the table. The cold spot protection is activated at
the following conditions:
- at speed > S.TURB.70 in fuel gas operation

- at power > E.LEIST.35 in fuel oil operation.
In both cases TETAV= average of the B/C exhaust temperatures.

The general protection criteria for the exhaust gas temperature are summarized in the table 1.
The proper values are indicated in the Set Points List (TGO1-0530).
See also section:

Setting of temperature limits at turbine outlet TGO2-0114
Exhaust gas temperature control TGO2-0100
Page 2 of 4
12.10.17
Table 1: General criteria for exhaust gas temperature protection
No. Criterion Recognition Action
Total Fuel Amount TETC > TT.ATK.M07, average on 24 B+C channels TETC high
1
high Alarm,
Total Fuel Amount If TC 101/105/109/111/115/121 , 3oo6>TT.ATK.M07 TETC high
2
high Alarm,
Total Fuel Amount TETC > TT.ATK.S07, average on 24 B+C channels TETC too high
3
too high GT TRIP
Total Fuel Amount If TC 101/105/109/111/115/121 , 3oo6>TT.ATK.S07 TETC too high
4
too high GT TRIP
Single Burner TETC > TT.ATK.11 and n > S.TURB.70, as well as TET > Hot-Spot Alarm
excess fuel TETAV + TT.AT.01, *1)
5
FG operation Each B and C element, i.e. 2v2 elements at 1v24
measuring points *2)
Single Burner TETC > TT:ATK.11 and n > S.TURB.70 as well as TET > Hot-Spot
excess fuel TETAV + TT.AT.02, *1) GT TRIP
6
FG operation Each B and C element, i.e. 2v2 elements at 1v24
measuring points, *2)
excess fuel TETAV + TT.ATG.01, *1)
7
FO-DO operation Each B and C element, i.e. 2v2 elements at 1v24
excess fuel TETAV + TT.ATG.02, *1) GT TRIP
8
FO-DO operation Each B and C element, i.e. 2v2 elements at 1v24
excess fuel TETAV + TT.ATG.03, *1)
9
FO-PO operation Each B and C element, i.e. 2v2 elements at 1v24
excess fuel TETAV + TT.ATG.04, *1) GT TRIP
10
FO-PO operation Each B and C element, i.e. 2v2 elements at 1v24
Single Burner P>E.LEIST.35 and Cold-Spot Alarm
Extinguished TET < TETAV - TT.AT.03, *1),
11
each B and C element, i.e. 2V2 elements at 2
neighbouring measuring points of 24, 2*)
Page 3 of 4
12.10.17
No. Criterion Recognition Action
3adjacent Burners P > E.LEIST.35 and TET < TETAV - TT.AT.03, *1), Cold-Spot
12 extinguished each B and C element, i.e. 2V2 elements at 3 GT Shutdown
neighbouring measuring points of 24, 2*) Program
4adjacent Burners P > E.LEIST.35 and TET < TETAV - TT.AT.03, *1), GT TRIP due to
Extinguished or each B and C element, COLD SPOT
13 double 3adjacent at  4 neighbouring measuring elements B&C
Burners or
extinguished 3+3 neighbouring measuring elements B&C
4 compressor inlet All channel A measures are in bad quality or too GT TRIP
14 temperature much deviated from the average value
measure faulty
Page 4 of 4
12.10.17
EVALUATION OF TEMPERATURES DISTRIBUTION AT TURBINE OUTLET
The exhaust gas temperature distribution is used according to section TGO3-0110 in order to
evaluate specific problems that can occur at several burners (see hot spot protection, cold spot
protection).
At gas turbine outlet 24 triple thermocouples (MBA) are installed to measure rapid changes of the
temperature in the hot zone. For control purpose (calculation of the temperature) the average of
the 24 ‘a’ channels is used; the b and c channels are used for protection purposes.
In addition 6 single element thermocouples (MBR) are installed in exhaust duct, the signals of
these thermocouples supply a more reliable value of the average temperature since the hot gases
are mixed.
The exhaust gas temperature distribution is monitored by the gas turbine control system, in
order to find anomalies in the combustion chamber. In fact a not uniform temperature
distribution may lead to thermal stresses on the hot gas path or increase the NOx emissions
(because of a localized temperature increase) .
The temperature distribution evaluation is based on the deviance of a single thermocouple from
the average temperature, in case an high deviation is reached an alarm is issued.
The temperature distribution is displayed on the operator control panel; it is recommendable to
periodically check the distribution . During normal operation (i.e. excluding start up or change
over) it is expected to reach a maximum deviation of 50°K between the maximum and minimum
value of the thermocouples (not from the average). In case of higher deviations it is
recommended to investigate about the cause of this increase.
In case an alarm of hot/cold spot or if a difference higher than 50°K between two thermocouples
is recognized the following actions are recommended:
1. Check all the three channels of the same thermocouple and evaluate their deviation
2. Check the thermocouples near the hot/cold point; if only one thermocouple deviates it is
more probable a fault in the thermocouple. In this case substitute the thermocouple at
next gas turbine shut down
NOTE: After a load rejection, the fast load variation leads normally to a non uniform temperature
distribution and a cold spot zone may be present. During this phase the thresholds for protection
are slightly increased and then brought again to the normal values at the end of the load rejection
(when the load profile is stabilized).
Page 1 of 2
EVALUATION OF TEMPERATURES DISTRIBUTION AT TURBINE OUTLET TGO3-0119-E70001
17.11.14
In case the hot/cold spot alarm is not related to a fault in one or more thermocouples, a trouble in
the combustion system has to be expected, in this case:
1. For fuel gas operation: check the proper position of the pilot gas control valve
2. For fuel oil operation (where applicable): in case of operation with denox water, check
the proper position of the denox water control valve (where applicable)
3. After a gas turbine shut down look for burner(s) clogging: note that the spot regions are
shifted as function of the gas turbine load, in particular according to IGV position. In
case of a hot/cold zone the thermocouple(s) associated with the burner(s) rotate with
the load. As general rule at full speed no load a shift of 10 is expected (e.g. a spot on
thermocouple 13 may be due to a fault on burner ±1), at base load a shift of 2 is
expected.
If one ore more burners result clogged, at first the cause should be investigated.
As general countermeasure a premix burner back flow (gas or oil) could be useful to clean the
burners.
Note: all back flow operations must be carried out by qualified personnel, since it is necessary
to adjust the control system. Please always contact in advance Ansaldo Energia service
department.
In case of a single burner found clogged the substitution of this is more advantageous than a
general back flow.
Page 2 of 2
EVALUATION OF TEMPERATURES DISTRIBUTION AT TURBINE OUTLET TGO3-0119-E70001
17.11.14
EQUIVALENT OPERATING HOURS
During the operation of gas turbines, high temperatures cause stress in components carrying hot gas
(for example combustion chamber lining and turbine blades), which are determining for the life of
these components.
An evaluation of the service life (in hours) of the components carrying hot gas is done by means of
the calculation of the Equivalent Operating Hours (EOH). The GT revision and inspection planning is
based on the EOH. See section TGO5-0022 as reference.
This calculation is principally based on the actual GT operating duration, the numbers of starts up,
the analysis of fast temperature changes, the injection of water in the burner, etc.
Equivalent Operating Hours calculation (EOH)
The Equivalent Operating Hours are calculated as it follows:
EOH  a1  n1  a2  n2  a3  n3   ti   f j  w j  b j  t j
where:
a1: constant factor for start-up (a1 = 10 h / start)

n1: number of starts(see note 1)
constant factor for black start or emergency start (a2 = 10 h / black start or emergency
a2 :
start) in addition to the constant of a standard start-up
n2: number (summation) of black starts and emergency starts
a3: constant factor fast loading (a3 = 10 h / fast loading) – OPTION
n3: number (summation) of fast loading – OPTION
calculated equivalent operating hours for the quick temperature change in turbine inlet
ti:
temperature (see note)
factors for calculation of equivalent operating hours, depending on the operating mode
fj, wj, bj:
(see note )
tj: recording time interval for the operating mode (see note)
The accumulated EOH are stored automatically by the GT control system.
Page 1 of 4
EQUIVALENT OPERATING HOURS TGO3-0126-E72000
19.01.17
Notes:
1. n1
For the calculation of the EOH, a start up is recognized when :

fuel emergency stop valve is OPENED
and
speed exceeding S.TURB.37 (see Set Point List, section TGO1-0530)
2. ti
To evaluate the number of fast temperature changes a monitoring interval is set in order not
to correct the slow temperature changes occurring during normal loading / unloading. The
EOH due the fast temperature changes is shown in figure 1 and 2. Transient phases starting
from open or closed IGV are weighted in a different manner since the thermal energy due to
the inlet mass flow is different.
The quick temperature changes normally can happen in event of trip or load rejection.
ti mainly depends on the following parameters:
 amount of temperature change
 the rate of temperature change
 the thermal convection conditions (these depend on the compressor IGV position)
With reference to the temperature change rate, conditions such as load rejection and trip (i.e.
quick temperature changes) are set as basic conditions and the calculation algorithm is
adjusted on it.
3. “f” constant fuel evaluation factor for the fuel used in the time interval tj.
fj=1 for natural gas and light oil whose characteristics are in accordance with the “Fuel
specification” TGO2-0160.
4. wj is a variable evaluation factor for operation with water injection (if water injection is not
provided for a defined GT, the factor wj is to be set to “1”)
5. bj is an evaluation factor for the turbine inlet temperature or outlet temperature.

Where:
bj = 1 for the operation in the whole load range up to base load (base load GL included)
bj = 4 for the (temporary) operation above base load (peak load) even with water
injection active (this factor is used by the set point U.EOH.02), where applicable.
6. ti is the watching time interval (usually 10s)

Basically tj can be selected at discretion; however, tj should be sufficiently small, to be
able to come out approximately from stationary conditions (as regards time variable
factors).
Page 2 of 4
19.01.17
Equivalent operating hours for trip and load rejection
1000
Variable-pitch IGVs open
100
Equivalent operating hours
Variable-
pitch IGVs
10
1
200 300 400 500 600 °C
Fig.1 initial corrected exhaust temperature
Page 3 of 4
19.01.17
Equivalent operating hours for fast turbine temperature changes
1000
Variable-pitch IGVs:
Equivalent opoerating hours
100
Open
Halfway
10
Closed
1
0 100 200 300 400 °C
Fig.2 Fast change of turbine temperature 
Page 4 of 4
19.01.17
SAFETY PROCEDURE DURING VERY LONG STANDSTILL
General Instruction
In case the GT plant and its auxiliary systems are shut down intentionally for very long periods, the
following additional protective measures must be obligatory observed.
It is assumed that, during the prolonged standstill, the plant is not ready for operation and that no
relevant maintenance activities are ongoing.
The following protective measures are not aimed to be exhaustive. Further measures shall be
identified and put in place by the operating personnel also on the basis of his own specific
experience.
START UP PROGRAM
- All Sequences: Switch off / shut down program completed
(Select shut down / manual ) STOP / manual
(the relevant led is lighted)
Intake system MBL

- Compressor intake damper TO BE CLOSED
- Inspection doors TO BE CLOSED
Fuel oil system MBN

- Electric motor supply TO BE SWITCHED OFF
- Fuel oil pump(s) TO BE SWITCHED OFF
- Leakage oil pump TO BE SWITCHED OFF
- Fuel oil supply TO BE ISOLATED
- Control valves TO BE CLOSED
- Stop valves TO BE CLOSED
- Drain valves TO BE OPENED / DE-ENERGIZED
Fuel gas system MBP

- Fuel gas supply TO BE ISOLATED
- Control valves TO BE CLOSED
- Stop valves TO BE CLOSED
- Vent valves TO BE OPENED (de-energized)
Page 1 of 5
SAFETY PROCEDURE DURING VERY LONG STANDSTILL TGO3-0200-E70001
17.09.14
Water systems MBN / MBU (*)
- Water pump(s) TO BE SWITCHED OFF
- Water supply TO BE ISOLATED
- Control / stop valves TO BE CLOSED
- Drain valves TO BE OPENED
(*) in case of water system foreseen (purging water for fuel oil premix or water system for NOx
control depending on the fuel oil configuration), the water tank must be drained and the water
must be discharged. Measures against corrosion must be adopted following the Supplier’s
instruction.
Lube and lifting oil system MBV

- Main lube oil pump TO BE SWITCHED OFF
- Auxiliary lube oil pump TO BE SWITCHED OFF
- Emergency lube oil pump TO BE SWITCHED OFF
- Lifting oil pump TO BE SWITCHED OFF
- Emergency lifting oil pump TO BE SWITCHED OFF
- Blowers TO BE SWITCHED OFF
- Solenoid valves to turning gear TO BE DE-ENERGIZED
- RDS pump TO BE SWITCHED OFF
- RDS solenoid valves TO BE DE-ENERGIZED
Hydraulic oil system MBX

- Hydraulic oil pump 1 TO BE SWITCHED OFF
- Hydraulic oil pump 2 TO BE SWITCHED OFF
- Nitrogen from accumulators TO BE DISCHARGED
- Oil system from actuators TO BE DISCHARGED
Cooling water system PAB

- Cooling water supply system TO BE ISOLATED
- Oil cooler – water side TO BE DISCHARGED
- Oil cooler – oil side TO BE DISCHARGED
Note
The operator shall adopt all necessary measures to avoid an increase in corrosion in such components
subdue to the cooling water.
Page 2 of 5
17.09.14
Drainage system MBA 18
- Drain collector TO BE DISCHARGED
- All draining valves TO BE CLOSED
- Solenoid valves TO BE OPENED (de-energized)
Static Starter SFC

- SFC TO BE INTERLOCKED / avoid the possibility
of a system start up
Generator
- Avoid switch ON possibility regarding the generator
components. TO BE INTERLOCKED
Air dryer
- Compressor I turbine (air dryer) TO BE SWITCHED ON
- Generator TO BE SWITCHED ON
Blow off compressors TO BE SWITCHED OFF (power supply off)
Note
During all the standstill period the air dryer must be maintained switched ON.
In order to avoid an increase in humidity, the GT plant and its components must be kept away from
water sources (e.g. tank).
In order to check the humidity level of the gas turbine, it is necessary to perform the control of the
air relative humidity at regular intervals. The average relative humidity shall not exceed 50%.
Procedure for very long standstill periods
1. All equipment and device must be properly switched OFF
After the GT has been shut down, the turning gear procedure must be carried out as described in
section TGO3-0047.
When the turboset is completely cooled down (e.g. turning gear procedure completed), it is possible
to switch off al the equipment (pumps, blowers, etc.) in the lube oil tank.
Follow the prescriptions reported in the paragraph: “General Instruction”.
The lube oil tank must be kept inside the lube oil tank.
For its preservation follow the prescriptions issued by the Supplier in order to reduce the oxidation
and the ageing. In case, add some proper additives if this is the Supplier’s advice.
The fuel oil must be discharged from the fuel oil system and from the pipe leading to the combustion
chambers. Use proper drainage valves.
Page 3 of 5
17.09.14
All the water tanks (e.g. in the purging water skid if foreseen, in the water injection skid if foreseen)
must be discharged. Use proper drainage valves. Follow the Supplier’s instruction in order to avoid
corrosion.
The compressor intake damper must be closed in order to avoid the air circulation inside the gas
turbine.
Via the manhole located nearby the intake camper, check the effective leak tight of the compressor
intake damper and make some intervention in order to censure a complete leak tightness.
The air dryer must be kept switched on in order to avoid moisture inside the machine.
The control system must be switched off. Follow the instruction of the Supplier to perform a safe
switch off.
Close all manual valves for:

- inlet/outlet water from / to oil / water coolers
- fuel gas supply
- fuel oil supply
- drainage
If the intake filters are made by cellulose fibers, they have an expire date. Follow the Supplier’s
instruction. If the filters are in good conditions, it is suggested to dismounted them from the intake
system and to preserve them in a clean and dry room.
Open the implosion doors and fix them in OPEN position in order to avoid blockage of the gaskets
(follow the instructions of the air intake Supplier).
2. Plant preservation
During all the standstill period the air humidity inside the gas turbine must be checked and the air
dryer kept ON.
In case it is not possible to maintain the air dryer switched on due to the loss in the 220 V power
supply, it is suggested to introduce a proper quantity of SILICAGEL or equivalent into the intake duct
via the manhole. The SILICAGEL packs must be changed at regular intervals by checking their
effectiveness by means of humidity control (optimum value < 30%).
The packs shall be metallic free in order to avoid any risk for the machine in case they are forgotten
inside the duct at the next start up.
The fuel oil forwarding system shall be switched off as well. Follow the Supplier’s instruction for safe
preservation of the unit.
Page 4 of 5
17.09.14
All the water systems must be switched off. The water must not be left circulating in the unit. All
water passages must be isolated in order to avoid corrosion.
GT Start up after long standstill periods.
Follow all instructions reported in section TGO3-0031 / 0032.
Besides:
- Restore all the power supply (hydraulic oil, electric connections, blow off compressors etc.)
- Carefully check the cleanness of the intake duct and that no obstruction is present.
- Check the integrity of the intake filters. In case, replace them.
- Remove the blockage of the implosion doors and replace the damaged gaskets.
- Open and check the drainage valves, move them in the proper position foreseen for operation
- Restore the fuel supply systems.
Page 5 of 5
17.09.14
ACTIVATION OF THE FUEL OIL SYSTEM DURING PROLONGED FUEL GAS
OPERATION
High GT availability and reliability require regular inspection of representative components. In
particular the following procedure must be observed in order to increase the reliability of the fuel oil
system starting and the associated water systems (i.e. HP purging) required for safe fuel oil
operation.
In addition to this procedure, the activities reported in section TGO4-0032 must be carried out at
regular intervals as indicated.
Safety
Ensure compliance with all safety and hazard notices presented in this manual and in the vendor
documentation.
Note
Since several manual operations are required on the skids are required, all the process of activation
of the components has to be executed in manual mode.
Test Interval: Every month
After long periods of outage it is advisable to check the proper functionality of the fuel oil system
in order to maintain the components in good efficiency.
1. Fuel oil systems check with GT in operation:
• Make sure that both the ESV’s (MBN14AA051 and MBN23AA051) on diffusion and
premix lines are closed and remain closed during the following operations.
• Open the proper injection pump suction isolation valves (MBN12AA402 or
MBN12AA405) and keep the discharge valve closed (MBN12AA402).
• Activate the fuel oil forwarding system and recirculate fuel oil for a time equivalent at
least of two downstream pipeline volumes.
• Check that differential pressure across the fuel oil filters, downstream fuel oil forwarding
pumps and upstream fuel oil injection pump (MBN11CP001), is normal. In case of high
differential pressure across filters, proceed with filters cleaning (section W3.4-0032) and
restart the test procedure. Repeat the recirculating procedure till the fuel oil differential
pressure across the filters is normal and stable for at least 1 hour of fuel oil recirculation.
• Check that the pressure upstream the injection pump is stable > min
(MBN12CP101…103).
Warning: the injection pump is damaged if it is started with no suction pressure.
Page 1 of 4
ACTIVATION OF THE FUEL OIL SYSTEM IN CASE OF
PROLONGED FUEL GAS OPERATION TGO3-0210-E70002
11.10.14
Test Interval: Every two (2) months
2. Fuel oil injection pump(s) check:
The following actions must be executed only when the gas turbine is shut down and the turning gear
is on operation at least since 6 hours.
• Make sure that both the ESV’s (MBN14AA051 and MBN23AA051) on diffusion and
premix lines are closed and remain closed during the following operations.
• Open the proper injection pumps isolation valves (MBN12AA402..403 or
MBN12AA405..406).
• Activate the fuel oil forwarding system and, provided that pressure upstream the
injection pump is stable > min (MBN12CP101…103) and the fuel oil differential pressure
downstream fuel oil forwarding pumps and upstream fuel oil injection pump
(MBN11CP001) is normal, then switch ON manually the selected injection pump.
• Warning: In case of high differential pressure across filters, proceed with filters cleaning
(as reported in section TGO4-0032) and restart the recirculating procedure (see
paragraph 1), before starting the injection pump.
• Check that the fuel oil injection pump is running and that the pressure downstream the
pump is increased (by the pressure transmitter MBN13CP101..102..103)
• Check that no leakage on the pump and on the valve is present
• Check that injection pump’s bearing and winding temperatures are normal during the
operation.
• After 30 minutes of operation, stop the fuel oil injection pump and isolate it by closing
the isolating valve(s)
• Stop the running fuel oil injection pump and isolate it by closing the isolating valves and
stop the fuel oil forwarding system.
• Repeat the same operations with the stand by pump (if present)
3. Check the fuel oil stop valves:
After long periods of outage it is preferable to open and close the stop and control valves in
order to maintain these components in good efficiency.
• Make sure that the fuel oil injection pump(s) cannot be activated during the test
• Make sure that the forwarding system is not on operation
• Close the isolating valves MBN12AA402/403
• Open the fuel oil diffusion supply line stop valve MBN14AA051
• Close the fuel oil diffusion supply line stop valve MBN14AA051
• Open the fuel oil diffusion supply line control valve MBN14AA151
Page 2 of 4
11.10.14
• Close the fuel oil diffusion supply line control valve MBN14AA151
• Open the fuel oil premix supply line stop valve MBN23AA051
• Close the fuel oil premix supply line stop valve MBN23AA051
• Open the fuel oil premix supply line control valve MBN23AA151
• Close the fuel oil premix supply line control valve MBN23AA151
• Open the fuel oil diffusion return line stop valve MBN52AA051
• Close the fuel oil diffusion return line stop valve MBN52AA051
• Open the fuel oil diffusion return line control valve MBN52AA151
• Close the fuel oil diffusion return line control valve MBN52AA151
• Set the isolating valves MBN12AA402/403 in the proper position
Note: automatic command close are issued for any stop valve after 12 s the valve has been opened
by a manual command for test purpose.
4. Check the HP purging water pump
The following actions must be executed only when the gas turbine is shut down and the
turning gear is on operation:
• Before starting the pump be sure that the level of water in the purging water tank is
normal
• Before starting the pump be sure that no shut off valve may open during the test
• Start the purging water pump. The water is automatically recirculated into the tank
(MBN80BB001) by the safety valves.
• Check the water pressure increase by the pressure transmitter MBN81CP101
• Stop the purging water pump
5. Check the purging water solenoid valves and control valve
The following actions must be executed only when the gas turbine is shut down and the
turning gear is on operation:
• Before opening the valves be sure that the pump may not be accidentally started up
• Open the purging water shut off valves (MBN83/84AA05x) by energizing the respective
solenoid valve
• Check one valve each time, i.e. open one valve, check the position by the limit switch
then close the valve before opening the following one.
• By means of the hydraulic station supply, open the water control valve MBN82AA151 to
check free movement. Then close it again.
Page 3 of 4
11.10.14
Test Interval: Every year (once a year)
6. Perform a complete start up of the gas turbine with fuel oil
NOTE: Before starting up the gas turbine with fuel oil for test, be sure that no trouble is
present on the purging water system (i.e. the purging water system is available), since it is
necessary, after the start up the purging of the diffusion lines and burners.
This action may be carried out only once a year, selecting the main or the stand by pump and
opening the proper valves. After the selection of fuel oil the gas turbine may be started.
• Check that no leakage is present on the valves and on the burners

• Check that differential pressure across the fuel oil filters, downstream fuel oil forwarding
pumps, upstream fuel oil injection pump (MBN11CP001) and across the Y-filter on fuel
oil diffusion line (MBN31CP101/102/103), is normal. In case of high differential pressure
across filters, shutdown the GT and proceed with filters cleaning (as reported in section
TGO4-0032) and recirculating procedure (see paragraph 1). Restart the GT when filters
are clean and no high differential pressure across filters is detected.
• When full speed no load is reached and all the leakages check is carried out the gas
turbine may be shut down.
• Make sure that the FO diffusion lines purging takes place immediately after the shut
down sequence is initiated.
In case of fault to one or more test above described, refer to the relevant fault rectification
instruction, sections TGO3-3000, TGO3-3050
Page 4 of 4
11.10.14
OPERATION AT VERY LOW AMBIENT TEMPERATURE
Low ambient temperatures may require operating restrictions in gas turbine operation. A distinction
is made between gas turbine start up or prolonged operation at low ambient temperatures. In this
latter case, not the entire gas turbine but only a small portion (compressor inlet) is affected by low
temperatures.
Start up of a cold gas turbine after an outage
Start up of the gas turbine is forbidden if the rotor disks and tie bolt have been cooled down below
+5°C after an extended outage, as this would involve the risk of brittle fracture of the rotor. Under
such conditions, the rotor temperature must be increased > +5°C, for instance by blowing warm air.
This is considered in case of gas turbine outdoor installation.
Prior to gas turbine start up, the bearings shall be heated above +5°C by circulating lube oil.
The functionality of certain auxiliary systems is restricted for temperature below +5°C.
Therefore
In case of indoor installation, the temperature shall also be maintained > +5°C.
Gas turbine operation
During operation of the gas turbine, the auxiliary systems and the connecting piping must remain at
temperature > +5°C.
Extended operation in with inlet cooling systems (if present) by fogging or wet compression mode is
not allowed for ambient temperature < +10°C.
Compressor cleaning is not allowed for ambient temperature < +5°C.
In the ambient temperature range –5°C  + 5°C with relative humidity > 80% ice can form on the
compressor inlet and on the filters. Under those ambient conditions, operation with anti-icing to
avoid ice formation is required.
Page 1 of 2
OPERATION AT VERY LOW AMBIENT TEMPERATURE TGO3-0220-E72001
20.09.17
Unless special low-temperature grease is used on the IGV/CV11 pitch adjustment device, check on
next occasion the grease for prolonged operation below –20°C.
As far as compressor surge is concerned, the gas turbine can be operated with no performance
restriction down to –20°C of ambient temperature. Below this temperature the load limiter will
intervene sooner and there is the possibility that the Gas Turbine will be derated due to the
intervention of the compressor pressure ratio controller which will limit the maximum achievable
power output in order to avoid compressor surge.
It is recommended not to operate the gas turbine at ambient temperatures < -30 °C.
In this case, Ansaldo Energia Gas Turbine Department (TGS) shall be consulted.
It is recommended however to consult Ansaldo Energia Gas Turbine Department (TGS)

in case of prolonged operation at < -20°C
Special conditions
In case the gas turbine is installed in a geographical area where low ambient temperatures are
frequent, INDOOR installation is mandatory for gas turbine and its relevant equipment. The
temperature of the building shall also be maintained > +5°C.
1
where applicable
Page 2 of 2
OPERATION AT VERY LOW AMBIENT TEMPERATURE TGO3-0220-E72001
20.09.17
Fault tracing
FAULT TRACING, GENERAL REMARKS
This section gives details of disturbances which can occur during gas turbine operation.
These brief instructions are intended to enable the operating personnel to react appropriately to
disturbances and thus on the one hand keep gas turbine outages to a minimum by taking the correct
action and prevent damage to the turbine generator on the other.
Notes on Procedure
In the following sections, the disturbances are listed according to the KKS system.
Fault rectification documentation includes a table of the fault alarms (with signal KKS identifiers)
output on the alarm printer together with brief descriptions of the associated causes of each fault
and possible measures for rectification. The information given on possible causes and their
correction is by no means complete. In addition to the brief instructions, information on the causes
of faults given by other product manufacturers (see Outside Vendor Part) should also be considered.
Procedure in the Event of Serious Disturbances

If a fault occurs which is of such a serious nature that the services of the GT manufacturer must be
requested, attention must be paid to certain significant details to enable assessment of the
disturbance or the damage.
After occurrence of the fault, the plant should immediately be placed in an operationally safe
condition. During the fact-finding inspection and investigation into the cause of the fault, operating
records such as strip charts, operating logs, records from the alarm printer and observations by
operating personnel should always be referred to.
Damaged equipment should be left untouched as far as possible, as agreed upon with the
manufacturer, so that the original condition is still available for the fact-finding inspection.
It is advisable in all cases to contact the manufacturer to determine immediate remedial action, so
that targeted repairs or other measures can be initiated.
Page 1 of 1
FAULT TRACING, GENERAL REMARKS TGO3-0300-E00002
10.11.14
INSTRUCTION FOR FILLING A PROBLEM REPORT
In case of serious fault during gas turbine operation requiring investigation by the GT Manufacturer,
it is recommended to collect all the necessary information concerning the fault event and send it to
Ansaldo Energia, gas Turbine Service Department (GSE).
To collect the information, fill a so-called “Problem Report” reporting at least the following:
1.1 NUMBER / NAME OF THE PLANT
1.2 GT TYPE
1.3 DATE : day/month/year:
1.4 TIME, well identifying in which interval the anomalous event has occurred
1.5 GT OPERATING MODE before the event: i.e specifying :
- FUEL
- POWER OUTPUT MW
- COMBUSTION TYPE (DIFFUSION/PREMIX)
- STATIONARY OR DYNAMIC OPERATION (i.e. stable load operation or GT start, load
rejection, turning gear mode, frequency support, etc.)
- ANY WATER ADDITION: i.e. water injection (where applicable), inlet cooling (where
applicable), compressor cleaning , etc.
1.6 AMBIENT CONDITIONS AND GRID FREQUENCY.
1.7 ALARM and CAUSES which induced a GT Trip.
For instance, in case of faulty start up, indicate the step of sequence and the GT speed during
which the start was aborted.
In case of GT trip, state the alarms and the parameters determining the GT trip.
1.8 COMPLETE KKS of the equipment which caused the GT trip, its status (e.g. Open – closed in
case of valves) and the instrument reading, if any
In addition:
§ Give brief and essential explanations of faults.
§ Print and attach a graphic trend of the parameters or/and equipment involved in the
disturbance, recorded at least 10 minutes before the faulty event
§ Observe and report any anomaly in auxiliary system before the faulty events, even if not
directly related to the fault.
Page 1 of 1
INSTRUCTION FOR FILLING A PROBLEM REPORT TGO3-1708-E00003
11.11.14
VIBRATIONS
Of the possible variables vibration displacement, vibration velocity and vibration acceleration, the
internationally applicable guidelines stipulate vibration displacement as the relevant variable for
determining absolute bearing vibration and vibration path as the relevant variable for determining
relative shaft vibration. These three variables are rigidly interrelated, and in the case of sinusoidal
vibrations, each can be converted to either of the other two.
v=s ω
a=s ω2 = v ω where: ω=2 π f
With non sinusoidal vibrations, such conversion is only permissible for a single component which has
been filtered out, and not for the sum value. When citing bearing casing or shaft vibration data, it
must absolutely be ensured that the correct units are used. In general, vibration can be expressed as
an effective value, as a peak value (single amplitude) or as a peak-to-peak value (double amplitude).
in the USA, for example, vibration amplitude is usually expressed as a peak-to-peak value.
Before stating any vibration data, always convert to those units stipulated in the ISO standards, that
is, express bearing casing vibration in [mm/s eff] and shaft vibration in [µmpp] (peak-to-peak).
Instrumentation
Accelerometers have a long, proven record for measuring absolute vibration. The spring-mass system
of these transducers is selected such that the pickup operates below its own natural frequency. The
piezoelectric effect of quartz crystals is used to convert mechanical motion into an electric signal.
Here the charge shift is proportional to acceleration. Compared to velocity pickups, this technique
offers significant advantages through its higher cutoff frequency, long service life and ruggedness,
even at high operating temperatures. Furthermore, accelerometers are insensitive to magnetic fields.
Because very high-frequency vibration can, under unfavorable circumstances (e.g. blade resonance
which can be transmitted as structure-borne noise), interfere with measurement, each
accelerometer is mounted on a mechanical filter. These filters allow vibration in the frequency range
from 20 to 500 Hz of the accelerometer’s primary measuring direction to pass unfiltered while
simultaneously blocking transverse vibration which causes interference. In addition, the vibration
signal is filtered electronically with high-pass and low-pass filters prior to further processing by the
l&C system.
Non-contact eddy current sensors are employed for measuring shaft vibration. This measurement
technique is based on the principle that the magnetic field generated by a coil through which eddy
current flows induces eddy currents in electrically conducting materials. These eddy currents, in turn,
draw power from the coil via its magnetic field. The result of this is a reduction in the voltage
amplitude. This effect is then converted to a signal proportional to the measured variable. In the case
Page 1 of 15
VIBRATIONS TGO3-1780-E00002
11.11.14
of relative shaft vibration, shaft motion relative to the bearing shell is measured. Since the oil film is
not infinitely rigid, the rotor may deviate from its ideal path during rotation. Two sensors offset by 90
are required for determining this kinetic shaft path.
Change in Vibration Behaviour

Despite all mechanical design, fabrication and installation measures, vibration may occur due to
factors which, as they usually compound each other, are sometimes difficult to quantify. If increased
vibration occurs, investigations must be performed together with the manufacturer to pinpoint their
cause and define targeted measures to eliminate them. It is not practicable to give a complete
overview of causes and the resultant remedial measures. The intent of this document is to simply
point out characteristics and causes of possible vibration phenomena which may occur.
The majority of turbine-generator vibrations are caused by unbalance. These are primarily forced
vibrations at the frequency of shaft rotational speed. In addition, vibrations also occur at integral
multiples of the rotational frequency. Sub harmonic or high-frequency vibrations are rarely
registered.
Rotational-frequency Vibration
Causes of increased rotational frequency vibration may include the following mechanisms, among
others:
− Serious unbalance caused by factors relating to operation which cannot be considered when
balancing individual shafts (for example temperature or load dependent faults). Vibrational
disturbances may also have their origin in the coupling of several shafts where centering errors or
axial run out of the coupling flanges occur.
− Thermal factors can usually be identified by continuous transitions of vibration parameters on
load or temperature change. Differences in the heat transfer coefficient at the shaft surface may
cause shaft bowing and thus changes in the quality of shaft balancing. Vibration usually increases
with load or temperature. After a sufficient time has elapsed, temperatures are equalized,
thereby offsetting this effect. If the heating process is decelerated, this type of disturbance is
correspondingly less pronounced. Even slight temperature differences may be sufficient to cause
substantial changes in vibration behavior. This fact is of particular significance for the gas turbine
rotor, as this item is unavoidably subjected to very rapid temperature increases.
− Thermally-induced vibrational disturbances with a so-called “linking effect” also occur, however
less frequently. At low output running behavior is initially good, vibration increases with
increasing output but does not return to its initial level when output is decreased. In such cases
thermal effects are compounded by mechanical factors.
− If the shaft rubs against the gland seal strips or inner casing, localized temperature increases
cause slight shaft bowing and also induce thermal unbalance. Clearances may also be bridged at
the bearing casing oil wiper rings which may cause formation of oil coke.
Page 2 of 15
11.11.14
Sub harmonic Vibration
A loose connection in the load path anchoring rotating machinery to the foundation is one possible
cause of this rarely-occurring disturbance. Such vibrational components can only be detected by
frequency analysis.
Balancing
Unbalance is not directly measurable. It can only be recognized by its effect on vibration. When
rebalancing, additional balancing weights are either added to the rotor or weights previously
installed are removed to largely compensate for existing unbalance. Balancing merely establishes an
equilibrium between the original unbalance and the newly-placed balancing weights.
This fact has a definitely practical significance, particularly in the case of subsequent rebalancing
measures performed in the power plant. Rebalancing rarely improves the balance condition of a
single shaft, instead it merely improves the running behavior of the entire line of shafting. In practical
terms, if a rotor is replaced after rebalancing in a major inspection or is completely rebalanced during
repair in the factory, it may be necessary to perform further rebalancing after connecting the entire
line of shafting in the power plant as field rebalancing measures performed previously are no longer
suitable for the new situation.
One frequently-made error is performing only one vibration measurement shortly after reaching
operating speed and then shutting down the turbine-generator for the purpose of placing balancing
weights. Measured data of this kind are not representative for the actual balancing condition. A
steady-state condition must be achieved, this frequently takes many hours. Quality balancing can
only be achieved if reliably reproducible data are available. For the above-mentioned reasons, we
urgently recommend that only appropriately qualified personnel is assigned to perform rebalancing
work.
If it is necessary to question the reproducibility of a given turbine-generator vibration behavior, then
it is more expedient to repeat measurements than to begin rebalancing. Should this not become
evident until after commencement of rebalancing, one should consider restoring the initial condition
(i.e. remove all weights added in the course of rebalancing) and determine whether the balance
condition is reproducible.
A limited number of balancing planes are available for rebalancing in the power plant. This fact often
has the result that only partial improvement of balance condition can be achieved, i.e. a portion of
the vibrations can be reduced but at the cost of degraded vibration performance at other measuring
points or under other operating conditions. If one is to accurately recognize this contradictory
situation during rebalancing, it is necessary to register vibrations at all measuring points and under
all operating conditions as comprehensively as possible. This is the only way to find an optimal
compromise between technical and economic considerations.
As a rule, a minimum of five days should be scheduled for performing rebalancing work. This time
frame is based on placement of balancing weights and the requisite steady-state test runs. If the time
requirements of previous rebalancing work are known, it may be reasonably possible to schedule less
time for rebalancing.
Page 3 of 15
11.11.14
Incorrect conclusions regarding evaluation of the system’s sensitivity to unbalance are often drawn
on the basis of rebalancing results. if a system only slightly responds to test unbalance masses this by
no means indicates that substantial unbalance is involved, it is also possible that the test unbalance
mass in this case also lies in the selected balancing plane and is thus ineffective due to nodal
proximity. Conversely, the following conclusion is possible: if minor unbalance triggers substantial
change in vibration behavior, this is clearly indicative of increased vibration sensitivity to test
unbalance masses.
Even the effects of thermally-induced unbalance can be mitigated by rebalancing. This is, however,
only possible if the load-dependent change in vibration behavior remains within certain limits. If the
load-dependent change is greater than twice the permissible vibration, it is very unlikely that
rebalancing can achieve acceptable results.
In some cases it is possible to agree on a reasonable compromise with the operator prior to
completion of rebalancing. In the case of a turbine-generator intended almost exclusively for full-
load operation, one will strive for an optimum balance condition under these conditions, perhaps at
the expense of increased vibration during loading and unloading and even when passing through
critical speed ranges.
Conversion of Limits
Before stating any vibration data, always convert to those units stipulated in the ISO standards, that
is, express bearing casing vibration in mm/seff or mm/srms and shaft vibration in µpp (peak-to-peak).
The following equations apply for conversion (sinusoidal vibration):
1 (mm/s)pk = 0.707mm/seff
1 (inch/s)rms = 25.4 mm/seff
1 (inch/s)pk = 18 mm/seff
Vibration amplitude:
1
1 milpp = inchpp= 25.4 µmpp
1000
Examples:
Vibration velocity:
Vpk = 13.15 mm/s => veff 13.15 • 0.707 mm/s eff = 9.3 mm/seff
Vpk = 025 inch/s =>Veff 0.25 25.4 “0.707 mm/s eff = 4.5 mm/seff
vrms= 0.58 inch/s => V eff = 25 4 • 0.58 mrn/seff =14.7 mm/seff
Vibration amplitude:
Page 4 of 15
11.11.14
Spp = 2.5 mils =>Spp = 2 5 • 25.4 µm = 63.5 µmpp
Evaluation Criteria
ISO standards of the series ISO 10816 “Mechanical vibration - evaluation of machine vibration by
measurements on non-rotating parts” and series ISO 7919 “Mechanical vibration of non-
reciprocating machines - measurements on rotating shafts and evaluation” were revised during the
last decade and for the first time now provide information on the interpretation of evaluation results
and for setting limit values for vibration monitoring. Information relevant to gas turbines can be
found in Part 4 of both standards, as well as the general introduction comprising Part I of both
standards. Instead of indicating vibration range limits, both series designate the ranges themselves as
zones lettered A, B, C and D. Assessments have been defined for each of these zones and are applied
consistently in all parts of the series. The zones are defined as follows:
• Zone A: The vibration of newly commissioned machines would normally fall within this zone.
• Zone B: Machines with vibration within this zone are normally considered acceptable for
unrestricted long-term operation.
• Zone C: Machines with vibration within this one are normally considered unsatisfactory for long-
term continuous operation. Generally, the machine may be operated for a limited period in this
condition until a suitable opportunity arises for remedial action.
• Zone D: Vibration values within this zone are normally considered to be of sufficient severity to
cause damage to the machine.
These evaluations enable the operator to diagnose the vibration condition of a machine and provide
clear instructions regarding any necessary measures.
Evaluation zone limits for vibration velocity veff for measurements on non-rotating parts per ISO
10816-4
Zone limit A/B Veff = 4.5 mm/seff
Zone limit B/C veff = 9.3 mm/seff (alarm)
Zone limit C/D veff = 14.7 mm/seff (trip)
The values apply for casing vibration in the vertical direction under steady-state operating conditions
and at operating speed.
A second evaluation criterion is the change in vibration magnitude from a previously established
reference value. If a rapid or instantaneous increase in vibration is observed, appropriate
investigation should be initiated in cooperation with the manufacturer, even if the overall level is
below the alarm value of veff = 9.3 mm/seff. If a change in vibration magnitude is accompanied by
loud noises from the GT, the turbine-generator must be shut down immediately, even if the accuracy
of the display is in doubt. Such noises are indicative of mechanical damage (blade damage or massive
rubbing damage).
Page 5 of 15
11.11.14
Fault Causes and Rectification
Despite all mechanical design, fabrication and installation measures, vibration may occur as
described above due to factors which, as they usually compound each other, are sometimes difficult
to quantify. If increased vibration occurs, investigations must be performed together with the
manufacturer to pinpoint their cause and define targeted measures to eliminate them. It is not
practicable to give a complete overview of causes and the resultant remedial measures. The table-
(pp. 6-10)-merely points out characteristics, and causes of as well as countermeasures for several
possible vibration phenomena which may occur.
Troubleshooting Questionnaire on: Vibration Problems

The following questionnaire (pp. 11-15) should be filled out as completely as possible if vibration
problems occur at your power plant. The information you provide enables us to make a preliminary
assessment of the problem and possibly derive measures for rectifying the problems. Please send the
completed questionnaire to Ansaldo Energia, address indicated in section TGO1-0200.
Instructions for analyzing changes in vibration behavior
• Others symptoms Cause Measures/Fault Rectification
1. Rapid or instantaneous increase in

vibration
§ loud noises, change in GT parameters Possible damage, e.g. blade • Shut down turbine-generator immediately, even if
(output, TETC NOX) observed damage, rubbing damage the, accuracy of the display is in doubt Observe
(bridging of axial clearances) whether the increase in vibration also occurs during
coastdown. Measure coastdown time. Inspect GT.
§ Significantly elevated bearing metal
Bearing damage • Check affected bearings and surrounding area.
temperatures
Page 6 of 15
11.11.14
• Others symptoms Cause Measures/Fault Rectification
2. increased vibration due to

pronounced rotational frequency
components
§ Temporary increase in Transient vibration These are faults with thermal origins observed during
Transient vibration vibration
changes in load and temperature and are generally of only
under transient operating
conditions brief duration. This vibration behavior is a known phenome-
non typical for gas turbines. Increased vibration during
loading or load changes is often caused by thermally-induced
unbalance. This results from a rotationally asymmetric
temperature distribution within the rotor due to very slightly
uneven heating. The magnitude of thermally-induced
unbalance is a function of various parameters and may
change more or less significantly over time. The effects of
thermally-induced unbalance can usually be mitigated by
rebalancing. lf the heating process is slowed, the
phenomenon is less pronounced.
Rubbing If the shaft briefly rubs against the gland seal strips or inner
casing, localized temperature increases cause slight shaft
bowing and thus induce thermal unbalance. Rubbing-induced
faults are identified using special measurement techniques,
often in combination with polar vector diagrams. These
rubbing effects can be eliminated by balancing and / or
reducing the load change rate.
Restrained expansion Restrained expansion (due to distortion or jamming) can lead

to more or less significant changes in the transmission
behavior (stiffness/damping characteristics) of the GT system
and thus to increased vibration.
Check th. casing and exhaust gas path for anything which may
restrain expansion. Eliminate the causes of restrained
expansion.
Page 7 of 15
11.11.14
• Other s symptoms Cause Measures/Fault Rectification
§ Increased vibration over the Thermally induced faults Thermal factors can usually be identified by continuous
entire load range under (general) transitions of vibration parameters on load or
steady-state operating
conditions; elevated temperature change. As a rule, vibration increases with
vibration relative to load or temperature. The specific load conditions
previous values while
corresponding to vibrational conditions are usually
passing through natural
frequencies reproducible. The effects of thermally-induced
unbalance can usually be mitigated by rebalancing
Rotor distortion due to Turn the turbine-generator shaft as specified.

improper turning gear
operation.
Forces acting on the rotors Provisional rectification by rebalancing the turbine-
with eccentric coupling generator; correct Irregularities at next opportunity.
Replacement of rotor Rebalance the line of shafting.

components during a major
inspection; change in
distribution of unbalance
along the rotor
Blade failure Check blading (consult manufacturer).
Bearings A change in bearing geometry results in changes to

system characteristics (stiffness, damping effect of the
oil film). Check bearing geometry after consulting the
manufacturer.
Page 8 of 15
11.11.14
3. Increased vibration due to

pronounced low-frequency
components
Vibration occurs as a function of lube Unstable rotor balance due to Oil whip/oil whirl leads to instability. Frequency analysis
oil temperature; frequency is
self-induced vibration identifies these vibrations. This phenomenon has so far
approximately 0.46 - 0.48x rotational
frequency not been observed in ANSALDO gas turbines, however.
Change oil inlet temperature; it may be necessary to
increase damping the plain bearings. Notify the
manufacturer. This phenomenon has so far not
occurred with ANSALDO gas turbines.
Subharmonic vibration components Slack in the load path between A non-linear spring characteristic results if the
the foundation and the connection between the foundation and the bearing
bearing casings casing is not solidly bolted. Such vibrations can often be
identified on control room multi-channel strip charts or
by frequency analysis. Check the load path between the
foundation and the bearing casing.
4. Increased vibration due to higher

harmonic frequency components
• Vibration occurs at 2x rotational Mechanical or magnetic As a rule, turbine-generators with two-pole generators
frequency excitation by the generator also sustain vibration at a frequency equal to 2x
rotational frequency. Detection of such vibrations
requires measurement at selected frequencies.Consult
the engineering department responsible for generator
construction in the event of elevated values.
Alignment The cause of increased components at 2x rotational

frequency may also be the result of changes in shaft
alignment.
Check alignment.
Page 9 of 15
11.11.14
5. High-frequency vibration Faulty measurement chain Under unfavorable conditions (special frequency
components constellations, modulation of low-frequency
components), high-frequency vibration may interfere
with/invalidate the actual measurements. Check the
entire instrumentation chain, including the mounts for
the mechanical filters and accelerometers. Perform
control measurements.
6. Increased vibration during startup Excessive/elevated amplitudes Pass through these speed ranges as quickly as possible;
or shutdown while passing through natural rebalance after consulting the manufacturer in the
frequencies of the system event of more significant disturbances.
Page 10 of 15
11.11.14
Vibration Troubleshooting Questionnaire
Gas turbine plant (project name)……………………………………………………….

Type (GT and generator) ……………………………………………………….
Date……………………………………………………….
Operating hours……………………………………………………….
Number of starts……………………………………………………….
Equivalent operating hours……………………………………………………….
1. Description of the problem:

Please describe the problem as completely as possible and send us copies of all documents (correspondence, vibration
records, etc.), compiled to date on this problem.
……………………………………………………………………………………………………………………………….
2. Turbine-generator operating mode: Number of start/stop cycles per unit time (per day/week/month)
……………………………………………………………………………………………………………………………….
3. Is the turbine-generator also equipped for bearing pedestal vibration monitoring using a shaft vibration monitoring
system?
q Yes
q No
4. With what type of vibration does the problem occur?

q Bearing pedestal vibration
q Shaft vibration
q Both
5. At which measuring point does the problem occur?

(Please indicate measuring direction, e.g. vertical, etc.)
Turbine bearing (turbine end)………………………………
Compressor bearing (compressor end) …………………..
Generator bearing (turbine end) …………………………...
Generator bearing (exciter end) …………………………..
Page 11 of 15
11.11.14
6. Under which operating condition does the problem occur?
q During startup
q After synchronization
q When loading the GT
q During steady-state power operation
7. Under which startup conditions does the problem occur?

q during cold start (TETC <70 C)
q during hot start (TETC > 70 C)
q Independent of startup conditions
8. How long has the problem persisted? Was the change sudden or progressive? (Over what period of time?)
…………………………………………………………………………………………………………………………………
9. Was/is each start preceded by turning gear operation as specified in the Product Manual?
q Yes
q No
10. What type of disturbance occurs?

q Vibration peak following synchronization
q Excessively high steady-state vibration
q Instantaneous changes in steady-state vibration
q Severe vibration during startup (indicate speeds)
q Other phenomenon (explain)
11. if severe steady-state vibration occurs:

How many hours after startup is steady-state operation achieved (at constant load)? ………………………………
Please indicate load (MW) and reactive power (Mvar). ………………………………
12. Are the steady-state vibrations a function of load?

q Yes (attach copies of the vibration plot and load/reactive power)
q No
13. Is the problem reproducible, i.e. does it always occur in the same manner?
q Yes
q No (explain) ………………………………………………………………
Page 12 of 15
11.11.14
14. Is the turbine-generator operated with under and/or overfrequency?
q Yes (explain) ………………………………………………………………
q No
15. In the case of bearing pedestal vibration, the vibration velocity (derived from vibration acceleration) is recorded.
To what mode is the instrumentation chain set? ………………………………
Effective value (rms) in [minis] (specified setting) ………………………………
Peak value in [inm/s] ………………………………
Peak to peak value in [mm/s]………………………………
16. In the case of shaft vibrations, vibration amplitude is measured. To what mod. is the instrumentation chain set?
Peak to peak value in [urn/s] ………………………………
Other setting (explain) ………………………………
17. How do the vibration plots made during operation look? Please send a copy (separate copies for cold and warm
start if applicable), indicating the following data: machine number, time scale, date, scale increment, color coding. Always
indicate load and reactive power.
18. Is the machine equipped with a diagnostic computer?

q Yes (computer information, diagrams, etc.)
q No
19. Were readings checked for plausibility (e.g. using hand-held instruments), to determine whether standard
instrumentation was faulted?
q Yes (explain, results - always include dimension with measurements!) ………………………………
q No
20. Were instrumentation chains switched (e.g. compressor and turbine bearing or machine A and B) to check for
instrumentation hardware faults?
q Yes (explain) ………………………………
q No
21. Are replacement instruments for the vibration monitoring instrumentation chain available at the power plant?
q Yes (explain) ………………………………
q No
Page 13 of 15
11.11.14
22. Are the vibration pickups firmly seated?
q Yes
q No
23. Describe the subjective assessment of rotor vibration behavior made by placing a hand on the machine.
q Machine runs smoothly
q Machine does not run smoothly (explain) ………………………………
24. In the case of vibration peaks (excluding thermally-induced transient unbalance peaks occurring immediately after
synchronization): is it possible to record vibration peaks using a logger with a sufficiently fast response time?
q Yes
q No
25. Is machine expansion restrained at any point (e.g. in the center guide)?
q Yes (explain) ………………………………
q No
26. Does severe vibration occur at peripheral equipment (e.g. high-amplitude piping vibration)?
q Yes (explain) ………………………………
q No
27. When and by whom was the machine last balanced?

Date………………………………
Balanced by………………………………
28. Would it be possible to perform a vector measurement (=plotting the time history of vibrations as amplitude over
phase angle) at the power plant without the assistance of ANSALDO specialists?
q Yes (indicate device, pickups, phase relation) ………………………………
q No
29. Would it be possible to perform a frequency analysis at the power plant without the assistance of ANSALDO
specialists?
q Yes (indicate device, pickup) ………………………………
q No
30. What assembly, dismantling or reassembly work which could be related to machine vibration behavior was recently
Page 14 of 15
11.11.14
performed?
q Measures (explain) ………………………………
q Date………………………………
q Performed by whom? ………………………………
31. If (partial) blading replacement was performed recently: was a blade installation plan from the Berlin manufacturing
plant available?
q Yes (provided by whom?) ………………………………
q No
32. If the rotor has been recently disassembled: Were all components restored to their original relative positions during
rotor reassembly?
q Yes
q No (explain) ………………………………
33. If the rotor has been recently disassembled: Were any irregularities observed during disassembly?
q Yes (explain) ………………………………
q No
Provide information on a separate sheet.
Page 15 of 15
11.11.14
MEASURING EQUIPMENT - FAULT RECTIFICATION
The following fault rectifications regard the instrumentation in general:
Fault Possible Causes Fault Rectification

No signal acquisition by Shutoff valve upstream of Open shutoff valve.
pressure gauges, pressure pressure sensor dosed
switches, pressure transducers,
etc.
Line to pressure gauge
Check pressure gauge line and rectify
clogged or leaking
fault.
Pressure sensor has

Repair instrument and recalibrate or
mechanical or electrical
replace.
defect
No signal acquisition by Thermometer damaged by Replace thermometer.
temperature sensors impact or vibration
Protect thermometer against impact
(thermocouples, resistance
and vibration.
thermometers, thermal well
lube oil line thermometers)
Change in switching point of Setting has changed Reset
pressure and temperature
switches
Pressure gauge isolation valves, Devices leaking or have Rectify leaks.
pressure regulators and mechanical defects
Rectify mechanical faults; replace
pressure control valves
devices if necessary.
inoperative
Solenoid valve does not Mechanical or electrical valve Replace valve or the defective
respond to control commands parts defective (broken coil, part/rectify jam
loose cable connection,
piston jammed)
Limit switch does not function Limit switch defective or Replace or readjust limit switch.
properly mount loose
Page 1 of 1
MEASURING EQUIPMENT – FAULT RECTIFICATION TGO3-2500-E00002
11.11.14
SUPERVISORY AND PROTECTIVE EQUIPMENT - FAULT RECTIFICATION
The following alarms concern the system Gas Turbine Instrumentation:
Alarm Effect on GT operation Fault removal
GT SPEED MONITORING FAULT, NON NONE Check speed monitoring

COINCIDENCE
Check speed monitoring (in case of ≥

GT OVERSPEED ACTIVATED GT TRIP faults on speed sensors)
Check fuel control valve and / or mass
flow setting at load rejection
UNDER / OVER FREQUENCY (*) GT DISCONNECTION FROM None

GRID / NO LOAD
OPERATION
UNDER / OVER FREQUENCY GT TRIP None

(*)
TRIP
UNDER / OVER FREQUENCY The operator shall shut Check speed controller
30 MINUTES VIOLATED, down the GT and carry
out a blade inspection
INSPECTION REQUIRED
(*)
see table in section TGO2-2601
Warning:
When the sum of the operating times out of the allowable range [S.TURB.10 ÷ S.TURB.68]
reaches 30 minutes, the operating personnel must shut down the gas turbine and make a blade
inspection. The GT shut down does not occur automatically.
Page 1 of 3
SUPERVISORY AND PROTECTIVE EQUIPMENT –
FAULT RECTIFICATION TGO3-2600-E72000
11.11.14
BEARING TEMPERATURE HIGH None Check the sensor, the card, the lube
oil system (*)
BEARING TEMPERATURE TOO HIGH GT TRIP Check the sensor, the card, the lube
oil system, the bearing (*)
BEARING TEMPERATURE CHANNEL None Check the sensor, the card (*)
FAULT
BEARING TEMPERATURE GT SHUT DOWN / Check the sensor, the card, the wiring
3 V 3 CHANNEL FAULT NO START RELEASE (*)
HIGH ABSOLUTE VIBRATIONS NONE Check sensors and acquisition cards,

stop GT on first occasion for
mechanical check (**)
HIGH RELATIVE VIBRATIONS NONE Check sensors and acquisition cards,

stop GT on first occasion for
mechanical check (**)
ABSOLUTE VIBRATIONS MEASURE NONE / NO START RELEASE Check sensors and acquisition cards
FAULT (***)
ABSOLUTE VIBRATIONS NON NONE Check sensors and acquisition cards

COINCENDENCE (***)
RELATIVE VIBRATIONS MEASURE NONE / NO START RELEASE Check sensors and acquisition cards
FAULT (***)
VERY HIGH ABSOLUTE VIBRATIONS GT TRIP Check the shaft alignment, check for
(2v3) reason for high vibrations (***)
VERY HIGH RELATIVE VIBRATIONS GT TRIP Check the shaft alignment, check for
(2v3) reason for high vibrations (***)
(*) See in addition section TGO3-7040;

(**) See in addition section TGO3-1780
(***) Reattach or replace transmitter; check insulation of transmitter mount. Check cable connections.
Visually inspect exposed cables; replace as necessary. To localize the fault, swap installed
transmitters. Check cables for sensitivity to extraneous voltages. Apply test voltage indicated in
the device specification sheets to first the instrument and then the transmitter and compare
readings. Recalibrate as necessary.
Page 2 of 3
11.11.14
SURGE PROTECTION FAULT, NON NONE Check signal generation, recalibrate

COINCIDENCE as necessary. Locate obstruction,
disconnect line from instrument and
remove obstruction, e.g. using
compressed air.
SURGE PROTECTION ACTIVATED Check the instrument and the control

GT TRIP chain
Ascertain the surge cause
See Table 1 of section TGO3-0110 : General criteria for exhaust gas temperature protection
In case of alarm or GT trip for over temperature: Check fuel system and fuel
controller circuit, check for thermal unbalance
In case of hot spot protection: Check fuel system and fuel controller circuit, check
for thermal unbalance
In case of cold spot protection: Check fuel system and fuel controller circuit, check
for thermal unbalance, check sensor and circuit.

Gas turbine instrumentation TGO2-2601
Vibrations TGO3-1780
TETC protection TGO3-0110
Gas Turbine Bearing, fault rectification TGO3-7040
Page 3 of 3
11.11.14
FUEL OIL SYSTEM - FAULT RECTIFICATION
The following alarms concern the Fuel Oil System MBN:
Alarm Effect on GT Fault removal

operation
Differential pressure high on FO inlet None Clean FO filter
filter (MBN11CP001)
FO supply pressure low upstream of Pump protection OFF, Check pressure elements, check
pump fuel oil operation booster system (see note 1)
MBN12CP101 / 102 / 103 (2 oo 3) < stopped
P.HOE.16 (start up interruption
in fuel oil start, GT
trip from fuel oil
operation, fuel
change over to FO not
concluded)
FO supply pressure low downstream None Check for possible pipeline leakages
of pump Check the check-valve
MBN13CP101 / 102 / 103 (2 oo 3) <
P.HOE.100
FO supply pressure too low GT TRIP Check for possible leakages
downstream of pump Check the check-valve
Check the pump
MBN13CP101 / 102 / 103 (2 oo 3) <
P.HOE.18
FO-PREMIX supply pressure too low GT TRIP Check the FO-ESV is open
MBN23CP101/102/103 (2 oo 3) Check for possible pipeline leakages
(see note 6)
FO-DO supply pressure too low GT TRIP Check the FO-ESV is open
MBN14CP101/102/103 (2 oo 3) Check for possible pipeline leakages
(see note 6)
Double fault (2oo3) to FO pressure GT TRIP Check FO system, see section
measurement on one measurement TGO3-2500
point.
High level in leakage oil tank None Check leakage oil tank (see note 5)
MBN60CL002 > MAX
Page 1 of 5
FUEL OIL SYSTEM, FAULT RECTIFICATION TGO3-3000-E72001
20.11.2014
operation
FO-PREMIX-FEED ESV non None Check limit switch
coincidence monitoring
FO-DIFF-FEED ESV non coincidence None Check limit switch
monitoring
FO-DIFF-RET ESV non coincidence None Check limit switch
monitoring
FO-DIFF-FEED ESV : fault CLOSED None Check limit switch, valve and relevant
signal formation in the control system
(see note 3)
FO-PREMIX-FEED ESV : fault None Check limit switch, valve and relevant
CLOSED signal formation in the control system
(see note 3)
FO-DIFF-RET ESV : fault CLOSED None Check limit switch, valve and relevant
signal formation in the control system
(see note 3)
FO-RET ESV : fault OPEN FO system trip (i.e. GT Check limit switch, valve and relevant
Trip in case of FO signal formation in the control system
operation, GT (see note 3)
remains in FG mode
in case of fuel change
over occurring)
See also section

Measuring equipment TGO3-2500
Hydraulic oil system, fault rectification TGO3-9110
Hydraulic oil system for fuel oil valves actuators, fault rectification TGO3-9120
Page 2 of 5
20.11.2014
NOTE Possible Causes Corrective measures
1. Fuel oil pressure upstream § Fuel oil filter fouled § Change to reserve filter
of injection pump low § Clean filter. If cleaning intervals are
shorter than normal establish causes
of excessive fouling
§ Fuel oil forwarding pumps § Examine forwarding pumps for

failed proper mechanical and electrical
condition, if required, overhaul
pumps
§ Check power supply
2. Emergency stop valve(s) § Contact bounce § Check setting of limit switch

open and close immediately § Fault in hydraulic oil supply § Rectify fault according to section
afterwards system TGO3-9110
3. Trouble with fuel oil stop § Sluggishness due to fouling of § Restore free movement
valve(s) or control valve(s) stuffing box or stem distortion
§ Limit switch defective § Replace limit switch
§ Fault in fuel oil stop valve § See section TGO3-9110
actuator
§ Fault in fuel oil control valve See section TGO3-9110
actuator § See section TGO3-9110
§ Fault in hydraulic oil supply § Check position transmitter
§ Fuel oil control valve position
transmitter faulted
Page 3 of 5
20.11.2014
5. Fuel oil level in leakage oil § Fuel oil leakage pump defective § Check fuel oil leakage pump for
tank too high proper mechanical and electrical
condition, if required, overhaul pump
§ Loss of power supply for oil § Check power supply
leakage pump
§ Shut off valve downstream § Open shut off valve
leakage pump closed
§ Fuel oil level switch defective § Replace level switch
§ Pump’s suction line clogged § Clean suction line
§ Drain valve(s) during operation § Close drain valve(s)
not closed
§ Too much oil drained during § Fuel oil leakage, identify and remove
operation leakage
Hazard of fire: in the event of fire, push
the fire protection button. Locate the
leakage and repair it.
6. Fuel Oil pressure upstream § FO-feed line stop valve does § Check control logic, see note 3
of burner low not open or does not open
completely
§ Substantial leakage in the § Identify and remove leakage

pipeline Hazard of fire: in the event of fire,
push the fire protection button.
Locate the leakage and repair it.
Page 4 of 5
20.11.2014
Additional Faults
FAULT Possible Causes Corrective measures

Fuel oil injection pump fails to § Loss of power supply § Check power supply
start or fails immediately after § Suction valves (isolating valve) § Open suction valves
starting closed
§ Fuel oil pressure upstream of § See note 1
injection pump too low
§ Fuel oil injection pump § Examine fuel oil injection pump for
defective proper mechanical and electrical
condition, if required, overhaul pump
GT power output is not § Oil leakage § Check fuel oil supply lines and filters
achieved § Oil burner clogged or defective § Check burners
or
Individual flames are out
Increased fuel oil consumption § Fuel oil line leak § Locate and remove leaks
Lack in fuel oil § Fuel oil re-circulating valve fault § Check valve, replace if necessary
§ Drain valve(s) not closed § Close drain valves
§ Fuel oil injection pump § Check pump for proper mechanical
defective and electrical condition, overhaul
pump if necessary
§ Safety valves downstream of § Adjust, overhaul the safety valve if
fuel -oil injection pumps necessary
defective
§ Fuel oil emergency stop valve § See note 2,3
defective
Page 5 of 5
20.11.2014
PURGING WATER SYSTEM - FAULT RECTIFICATION
The following alarms concern the Purging Water System MBN1:

operation
Purging water level too high None, purging water Check level, check filling solenoid
(MBN80CP101 > L.SPUEL.04) tank overflow
Purging water level too low None, purging water Check level, check filling solenoid, look
(MBN80CP101 < L.SPUEL.02) pump cannot be for leakage
switched ON, in case
purging is required,
see note (*)
Purging water flow low Water system trip, Check water supply, check instrument
(MBN82CF101<MIN) PURGING NOT
PERFORMED (*)
Water pressure upstream of pump Water system trip, Check instrument, check the pump,
low PURGING NOT check for leakages
PERFORMED (*)
Water pressure downstream of Water system trip, Check instrument, defective pump look
pump low PURGING NOT for and rectify fault, see pump’s
PERFORMED (*) manufacturer’s instruction, check for
leakages
Water control valves, position Water system trip, Check control valve and actuator,
regulator fault PURGING NOT position regulator check
(MBN82AA151) PERFORMED
(*) In case purging is not performed:

GT TRIP after FO premix operation;
no release to FO premix in case of FO diffusion
no change over to fuel oil mode in fuel gas mode.
1
System used in case of operation with Fuel Oil
Page 1 of 2
PURGING WATER SYSTEM, FAULT RECTIFICATION TGO3-3050-E72001
15.07.2014
operation
Purging valves 1 v 2 OPEN None Check proper solenoid valve 51A / 52A,
(MBN83AA051 or …AA052) – FO check limit switch
DIFF FEED LINE
Purging valves 1 v 2 OPEN GT TRIP Check solenoid valve 51A or 52A, check
(MBN83AA051 or …AA052) – FO limit switch, check control logic.
RET LINE
Purging valves 1 v 2 OPEN None Check proper solenoid valve 53A or
(MBN83AA053 or …AA054) – FO 54A, check limit switch
RET LINE
Purging valves 1 v 2 OPEN GT TRIP Check solenoid valve 53A / 54A, check
RET LINE
PREMIX PURG LINE
PREMIX PURG LINE
PREMIX LINE
PREMIX LINE
See also section

Page 2 of 2
PURGING WATER SYSTEM, FAULT RECTIFICATION TGO3-3050-E72001
15.07.2014
FUEL GAS SYSTEM - FAULT RECTIFICATION
The following alarms concern the Fuel Gas System MBP:

operation
FG--ESV non coincidence None Check limit switches (see note 1)
monitoring
FG--ESV fault to OPEN Fuel gas connection Check limit switches and valve’s
not possible actuator (see note 2)
FG--ESV fault to CLOSE Fuel gas further Check limit switches and valve’s
connection not actuator (see note 2)
possible
FG-PG-CV (*)position monitoring FAULT ALARM Check LVDT signal
FAULT(LVDT signal 1oo2)
FG-PG-CV (*)position monitoring GT trip Check valve position and LVDT signal,
FAULT (e.g. LVDT signals (2oo2) or check position request loop
too high deviation) (see note 3)
FG-PREMIX-CV position monitoring FAULT ALARM Check LVDT signal
FAULT(LVDT signal 1oo2)
FG-PREMIX-CV position monitoring GT trip Check valve position and LVDT signal,
FAULT (e.g. LVDT signal or too high check position request loop
deviation) (see note 3)
FG supply pressure high (P.GAS.11) None Check FG system (see note 4)
> MAX
FG pressure low (P.GAS.06) < MIN None Check FG system (see note 5)
FG pressure low (P.GAS.03) < MIN Automatic fuel Check FG system (see note 5)
change over to FO
(where applicable)
FG pressure too low GT trip Check FG system (see note 5)
(P.GAS.07)<MIN
Double fault to FG pressure GT trip Check FG system, see section
measurement on the same line. TGO3-2500
(*) PILOT or PILOT 2 line, depending on the project.
Page 1 of 3
FUEL GAS SYSTEM, FAULT RECTIFICATION TGO3-3100-E72006
09.12.14
1. Emergency stop valves § Contact bounce § Check setting of limit switch
opens and closes immediately § Fault in hydraulic oil supply § Rectify fault according to section
afterwards system TGO3-9110
2. Trouble with fuel gas stop § Sluggishness due to fouling of § Restore free movement
valves or fuel gas control stuffing box or stem distortion
valves § Limit switch defective § Replace limit switch
§ Fault in fuel gas stop valve § See section TGO3-9110
actuator
§ Fault in fuel gas control valve § See section TGO3-9110
actuator
§ Fault in hydraulic oil supply § See section TGO3-9110
§ Fuel gas control valve position § Check position transmitter
transmitter faulted
§ Fuel gas pressure too high § Adjust fuel gas pressure
3. Control valves fail to open § Actuator faulted § Check actuator
or opens too slowly § Sluggishness due to fouling of § Check pilot control valve
stuffing box or stem distortion
§ Limit switch defective § Replace limit switch
4. High or fluctuating fuel gas § Fault in fuel gas supply (for § Rectify fault in fuel gas supply
pressure example in reducing station)
5. Low fuel gas pressure § Fault in fuel gas supply § Rectify fault in fuel gas supply
§ High pressure drop across fuel § Clean fuel gas filter
gas filter
§ Fuel gas vent valve upstream of § Close fuel gas vent valve. Clarify why
emergency stop valve open the valve is open. Check/repair fuel
gas vent valve
Page 2 of 3
09.12.14
Additional Faults
FAULT Possible Causes Corrective measures

GT power output is not § Fuel gas vent valve(s) leaking or § Close fuel gas vent valve(s)
achieved not closed
§ FG premix control valve faulted § Check the signal of the pressure
transmitter. See note 2
Increased fuel gas § Fuel gas line leak § Locate and remove leaks
consumption § Fuel gas vent valves leak or are § Fuel gas vent valves close
open § Overhaul fuel gas vent valve
§ leak upstream / downstream § Locate and remove leaks
of emergency stop valve
Individual flames are out § Fuel gas supply lines to burners § Locate obstruction and remove
clogged or burners defective § Clean filters and check burners
See also section

Hydraulic oil system, fault rectification TGO3-9110
Hydraulic oil system for fuel gas valves actuators, fault rectification TGO3-9130
Page 3 of 3
09.12.14
IGNITION GAS SYSTEM - FAULT RECTIFICATION
The following alarms concern the Ignition gas system MBQ1:
Effect on GT
Alarm operation Fault removal
MBQ11AA001 NONE FIND CAUSE OF THE ANTIVALENCE,

IGNITION GAS VALVE 1 CHANGE SENSOR IF NECESSARY
LIMIT SWITCH OPEN

IGNITION GAS VALVE 2 CHANGE SENSOR IF NECESSARY
LIMIT SWITCH OPEN

IGNITION GAS VENT VALVE CHANGE SENSOR IF NECESSARY
LIMIT SWITCH CLOSED
MBQ11AA001 NONE CHECK VALVE

IGNITION GAS VALVE 1
FAULT

IGNITION GAS VALVE 2
FAULT

IGNITION GAS VENT VALVE
FAULT
1
Page 1 of 2
IGNITION GAS SYSTEM, FAULT RECTIFICATION TGO3-3400-E72000
20.11.2014
Additional fault causes:
Fault Possible Causes Fault Rectification

1. No ignition spark Spark plug connector loose Firmly seat spark plug connector
Power supply interrupted Check wiring and connections
No voltage from ignition transformers Check transformers.
Arcing at insulators Install electrode with proper
Igniter improperly aligned with center insulators.
of burner Align the igniter.
Electrode gap too wide Set to specified electrode gap
2. No ignition gas Ignition gas line isolated or clogged Open or restore free motion to
shutoff valves in ignition gas
system; blow out line with
compressed air.
Ignition gas line leaking Seal ignition gas line.
Ignition gas solenoid valve 1or 2 Check/replace ignition gas solenoid
faulted valve
Ignition gas shutoff valve closed or Open/check ignition gas shutoff
faulted valve
3. Ignition gas pressure Ignition gas flow path obstructed Check passage of gas through the
entire flow path, including valves
too low
Valves not completely open Check valves, open/ drain
Ignition gas valve 1 leaking Check/overhaul ignition gas valve
Page 2 of 2
IGNITION GAS SYSTEM, FAULT RECTIFICATION TGO3-3400-E72000
20.11.2014
BLOW OFF SYSTEM - FAULT RECTIFICATION
The following alarms concern the Blow Off system:
Blow off valve 1.1

GT START INTERRUPTED / CHECK: LIMIT SWITCH,
MBA41AA051 NOT OPEN
GT TRIP DURING START SOLENOID VALVES, PNEUMATIC
Blow off valve 1.2 UP DISTRIBUTOR,
MBA42AA051 NOT OPEN PNEUMATIC ACTUATORS,
Blow off valve 2. COMPRESSED AIR SUPPLY,

MBA43AA051 NOT OPEN THE BLOW OFF VALVES.
Blow off valve 3

MBA44AA051 NOT OPEN
LIMIT SWITCHES NON NONE CHECK LIMIT SWITCHES,

COINCIDENCE (> 6 s)
Blow off valve 1.1 MBA41AA051
GT SHUT DOWN CHECK: LIMIT SWITCH,
OR
Blow off valve 1.2 MBA42AA051 SOLENOID VALVES, PNEUMATIC
NOT CLOSED DISTRIBUTOR,
OR PNEUMATIC ACTUATORS,
Blow off valve 2.
MBA43AA051 NOT CLOSED
OR
Blow off valve 3 MBA44AA051
NOT CLOSED
Page 1 of 3
BLOW OFF SYSTEM, FAULT RECTIFICATION TGO3-4400-E70001
17.11.14
Additional fault causes:
Fault Cause Fault Rectification
1. Blow-off valves fail to § No activating signal supplied to § Rectify speed signal

operate solenoid valve transmitter
§ Rectify fault in signal
transmission or processing
§ Solenoid valve defective system
§ Repair or replace solenoid
valve
§ Pneumatic distributor defective § Repair or replace pneumatic
distributor
§ Low pressure from pneumatic § Restore the required pressure
system value of the pneumatic system
2. Blow-off valves operate, but § Limit switch adjustment § Correct limit switch
no check-back signal for limit changed adjustment
position § Limit switch defective § Replace limit switches
§ Fault in signal transmission or § Rectify electrical fault
processing system
3. Actuator opens/closes § Loose connection between valve § Rectify connection
correctly but blow-off valve shaft and actuator (piston) rod
stops in intermediate position
4. Blow-off valves stop in § Sluggishness § Overhaul I lubricate valves(s)
intermediate position § Valve bearing defective or § Increase bearing clearance
insufficient bearing clearance according to inspection
instructions
§ Replace bearing
§ Insufficient axial clearance “a” § Restore required clearance “a”
Page 2 of 3
17.11.14
between valve bearing bolt and according to inspection
cover instructions
§ Sluggishness due to fouling of § Restore free movement
stuffing boxes (at shaft or piston
rod) or shaft/piston rod
distortion
§ Low pressure from pneumatic § Restore the required pressure
system value of the pneumatic system
5. Gas turbine fails to reach § Valve leaky § Readjust seal
full output § Defective seal § Replace seal
§ Actuator and valve not coupled § Couple parts in proper position
in synchronous position as indicated
§ Loose connection between valve § Rectify connection
shaft and actuator (piston) rod
Page 3 of 3
17.11.14
DRAINAGE SYSTEM - FAULT RECTIFICATION
The following alarms concern the GT Drainage system MBA1:
Alarm Effect on GT Intervention Fault removal

operation options for the
operator
GT drain valve1 position fault NONE Change the limit Check valve / limit switch
MBA22AA001 switch
GT drain valve 2 position fault NONE Change the limit Check valve / limit switch
MBA22AA002 switch
GT drain valves 1 and 2 faulty GT TRIP None Check valve / limit switch
opened (2 v 2)
1
Page 1 of 1
DRAINAGE SYSTEM, FAULT RECTIFICATION TGO3-4966-E72000
20.11.2014
MEASUREMENTS AT COMBUSTION CHAMBER - FAULT RECTIFICATION
The following alarms concern the system Combustion Chamber Monitoring:
Check the flame detector, quartz

NONE lenses can be fouled, clean the lenses
FLAME DETECTOR FAULT (1 element)
according to Supplier’s instruction
(see Outside Vendor Parts)
FLAME OFF ( 2 v 2) GT TRIP Check fuel system
RELATIVE DIFFERENTIAL PRESSURE NONE Check the instrument and the control
LOSS INSIDE COMBUSTION CHAMBER chain, check the combustion chamber
< MIN on next occasion
ACCELERATION MONITORING FAULT Protection Logic Control

Check the instrument
(1 element) from 2v3 to 1v2
ACCELERATION MONITORING FAULT GT TRIP

Check the instrument
(2v3)
GT TRIP
ACCELERATION MONITORING FAULT
or in case of GT startup Check the instrument
(3 v 3)
NO release to start
Check the instrument and the control

LOAD REDUCTION chain, check that each channel give
ACCELERATION > S.ACC.01 (2v3) the same signal, check the fuel gas
delayed by K.ACC.01 temperature, check fuel gas
temperature for abnormal values or
distribution
ACCELERATION > S.ACC.01 (2v3) GT TRIP Contact Ansaldo Energia Service

delayed by K.ACC.01 + K.BRUMM.03 Department
Page 1 of 3
MEASUREMENTS AT COMBUSTION CHAMBER – FAULT RECTIFICATION
TGO3-5000-E70001
20.11.14

LOAD REDUCTION chain, check that both channel give
the same signal, check the fuel gas
ACCELERATION > S.ACC.02 (2v3)
temperature, check fuel gas
delayed by K.ACC.02 temperature for abnormal values or
distribution

delayed by K.ACC.02 + K.BRUMM.04 Department
LOAD REDUCTION Check the instrument and the control

chain, check that both channel give
ACCELERATION > S.ACC.07 (2v3) the same signal, check the fuel gas
delayed by K.ACC.09 temperature, check fuel gas
temperature for abnormal values or
distribution

no delay Department

FO OPERATION LOAD REDUCTION chain, check that both channel give
ACCELERATION > S.ACC.04 (2 v 3) temperature, check fuel gas
distribution
FO OPERATION GT TRIP
Contact Ansaldo Energia Service
ACCELERATION > S.ACC.04 (2 v 3) Department
delayed by K.ACC.01 + K.BRUMM.09

ACCELERATION > S.ACC.05 (2 v 3) temperature, check fuel gas
distribution
Page 2 of 3
TGO3-5000-E70001
20.11.14
Contact Ansaldo Energia Service
ACCELERATION > S.ACC.05 (2 v 3) Department
delayed by K.BRACC.104

HUMMING LEVEL > P.BRUMM.01 (1 v temperature, check fuel gas
2) delayed by K.BRUMM.01 temperature for abnormal values or
distribution
FO OPERATION NONE
HUMMING MONITORING FAULT (1 Check the instrument
element)
HUMMING MONITORING FAULT (2 v Check the instrument
2)
NOTE : acceleration sensor fault management:

- In case of fault to one measuring transducer, the protection logics are carried out in logic 1V2
with the two remaining transducers and an alarm for the fault sensor is issued.
- In case of fault of all the three measuring transducers a GT TRIP is issued and the GT start up
release is denied. An alarm indicated the fault on the transducers is emitted.
Page 3 of 3
TGO3-5000-E70001
20.11.14
COOLING AIR SYSTEM - FAULT RECTIFICATION
The following alarms concern the system Cooling air system:
COLING AIR PRESSURE STAGE 1 / 2 / 3 NONE Check the sensor

or compressor outlet pressure
1 SENSOR FAULT
COLING AIR PRESSURE STAGE 2: NONE - Valve Check the sensor

2 SENSORS FAULT MBH22AA101/102
protection OPEN
COLING AIR PRESSURE STAGE 3: NONE - Valve Check the sensor

2 SENSORS FAULT MBH23AA101/102
protection OPEN
COMPRESSOR OUTLET PRESSURE : GT TRIP Check the sensor

2 SENSORS FAULT
COOLING AIR STAGE 2 / 3: NONE Check the sensor

HIGH DEVIATION BETWEEN PRESSURE
SENSORS
COOLING AIR VALVES: NONE – Valve protection Check limit switch

LIMIT SWITCHES NON COINCIDENCE OPEN
COOLING AIR VALVES: NONE – Valve protection Check transducer

TRANSDUCER FAULT OPEN
COOLING AIR VALVES: NONE Check valve movement for

TORQUE SWITCH RESPOND overloading
RELATIVE DIFF PRESSURE NONE Check sensor and isolating valve

STAGE 1 LOW
COOLING AIR PRESSURE NONE – Valve protection Check pressure signals,

STAGE 2 LOW OPEN check valve position
COOLING AIR PRESSURE NONE – Valve protection Check pressure signals,

STAGE 3 LOW OPEN check valve position
Page 1 of 2
COOLING AIR SYSTEM – FAULT RECTIFICATION TGO3-6000-E72000
17.11.2014
COOLING AIR PRESSURE STAGE 2 SHUT DOWN PROGRAM Check pressure signals,
VERY LOW check valve position
COOLING AIR PRESSURE STAGE 3 SHUT DOWN PROGRAM Check pressure signals,
VERY LOW check valve position
COOLING AIR PRESSURE STAGE 2 NONE Check pressure signals,

HIGH check valve position
COOLING AIR PRESSURE STAGE 3 NONE Check pressure signals,

HIGH check valve position
Page 2 of 2
COOLING AIR SYSTEM – FAULT RECTIFICATION TGO3-6000-E72000
17.11.2014
GAS TURBINE BEARINGS - FAULT RECTIFICATION
Change In Normal
Alarm Possible Causes Corrective Measures
Condition
BEARING Availability of the Measuring circuit Pinpoint fault
TEMPERATURE measuring circuit is faulted, broken wire Replace measuring
CHANNEL FAULT restricted One or two point during the next
(turbine, compressor, thermocouples of the scheduled outage
generator or gear-box measuring point could because the GT must
where required) be defective be shut down using the
“Shutdown Program” if
all of the
thermocouples of one
measuring point are
faulted.
TURBINE BEARING 1. Slow change in § Change in lube oil § Check lube oil supply
TEMPERATURE HIGH bearing temperature supply, change in (oil cooler, oil filter)
and / or over operating time line cross section § Check grounding
COMPRESSOR BEARING § Fouling by foreign brushes and bearing
TEMPERATURE HIGH matter, change in surfaces during next
bearing contact scheduled outage
surface, wear caused
by shaft current
2. Turbine running § Change in shafting § Check alignment and

smoothness changed alignment. correct at next
opportunity if
necessary
Page 1 of 4
GAS TURBINE BEARINGS – FAULT RECTIFICATION TGO3-7040-E00000
17.11.2014
Change In Normal
Condition
TURBINE BEARING 3. One or several § Displacement of § No special measures
TEMPERATURE HIGH journal bearing rotor in journal required NOW he
and / or temperatures varies bearing as a function maximum
COMPRESSOR BEARING with output (Bearing of output permissible bearing
TEMPERATURE HIGH metal temperatures metal temperatures
should always be are not reached
identical under
comparable output
conditions)
4. All bearing metal § Oil cooler fault § Rectify fault on lube

temperatures oil cooler
change, oil
temperature
downstream of oil
cooler changes
5. Increased bearing § Lube oil pressure too § Clean oil filter, check
metal temperatures, low, oil filter fouled. oil pump at next
decreased lube oil outage
pressure
Page 2 of 4
17.11.2014
Change In Normal
Condition
BEARING Rapid temperature § Bearing damage § Check bearings
TEMPERATURE TOO increase to the set
HIGH alarm threshold at
(GT TRIP) one or several bearing
locations (similar
temperature increase
not observed to date).
GENERATOR BEARING Slow temperature § Increased thrust § Check blading and

TEMPERATURE HIGH increase caused by fouled or bearing surfaces
and / or damaged blading during next
TURBINE BEARING scheduled outage
TEMPERATURE HIGH
§ Wear caused by § Check grounding
foreign matter shaft brushes and bearing
current surfaces during next
scheduled outage
§ Lube oil temperature § Pinpoint cause of

increase lube oil temperature
increase.
Page 3 of 4
17.11.2014
Change In Normal
Condition
GENERATOR BEARING Gross differences in § Angular § Check bearing for
TEMPERATURE HIGH bearing metal misalignment of the offset, alignment and
and / or temperature occur at bearing cage Offset shim wear during the
TURBINE BEARING the various measuring between the upper next scheduled
TEMPERATURE HIGH points of the thrust and lower portion of outage
bearing the bearing body,
worn thrust shims,
deformation of
spring shims caused
by non uniform force
distribution
GENERATOR BEARING Rapid temperature § Thrust bearing § Measure axial

TEMPERATURE TOO increase to the set damage caused by displacement and
HIGH alarm threshold at excessive thrust, non inspect thrust
(GT TRIP) one or several thrust uniform force bearing. Check
and / or bearing locations distribution, foreign blading for fouling
TURBINE BEARING (similar temperature matter (fouling) or and damage. Check
TEMPERATURE TOO increase not observed wear caused by shaft grounding brushes.
HIGH to date) current
Page 4 of 4
17.11.2014
EXHAUST GAS SYSTEM - FAULT RECTIFICATION
The following alarms concern the system MBR:
Alarm Effect on GT Intervention Fault removal

operation options for the
operator
EXHAUST SYSTEM: NONE Anomaly in the

exhaust system WARNING: CHECK EXAUST
DIFFERENTIAL PRESSURE HIGH
SYSTEM AT NEXT GT STOP
(P.EXH.01)
EXHAUST SYSTEM: GT SHUT Anomaly in the
DOWN exhaust system WARNING: CHECK
DIFFERENTIAL PRESSURE HIGH
IMMEDIATELY EXAUST SYSTEM
(P.EXH.02)
EXHAUST SYSTEM: GT TRIP Collapse in the WARNING: EXAUST SYSTEM
DIFFERENTIAL PRESSURE TOO exhaust system TO BE IMMEDIATELY
HIGH (P.EXH.03) INSPECTED
Page 1 of 1
EXHAUST GAS SYSTEM, FAULT RECTIFICATION TGO3-8100-E00000
17.11.14
PNEUMATIC STATION SYSTEM - FAULT RECTIFICATION
The following alarms concern the system MBX:
Alarm Effect on GT Intervention options for Fault removal

operation the operator
COMPRESSOR 1 FAULT NONE YES, intervene on the

Open Subdistributor and
pneumatic station,
search for the fault
check that the other
compressor is working
COMPRESSOR 2 FAULT NONE YES, intervene on the

Open Subdistributor and
pneumatic station,
check that the other search for the fault
compressor is working
PNEUMATIC SYSTEM PRESSURE NONE YES, intervene on the

pneumatic station, be Check the Pneumatic station
LOW
sure the pressure is according to the
Manufacturer instruction,
restored
check subdistributor, check
pressure switches, check for
leakage from traps and drains
PNEUMATIC SYSTEM PRESSURE NONE YES, intervene on the

Check the Pneumatic station
HIGH pneumatic station
according to the
Manufacturer instruction,
check subdistributor, check
pressure switches,
PNEUMATIC SYSTEM PRESSURE GT TRIP NO

Check of the Pneumatic
VERY LOW
station by the Manufacturer,
(2 v 3) check subdistributor, check
pressure switches and lines,
check for leakage.
Warning: Condenser discharge equipment shall be checked regularly.
Page 1 of 1
PNEUMATIC STATION SYSTEM, FAULT RECTIFICATION TGO3-9000-E72000
17.11.14
HYDRAULIC OIL SYSTEM - FAULT RECTIFICATION
The following alarms concern the system Hydraulic Oil Supply:
Alarm Effect on GT Possibility of Fault removal

operation intervention by the
operator
HYD OIL LEVEL < MIN None None Fill the hydraulic oil tank
MBX01CL001-S01 (see note 3)
HYD OIL LEVEL < MIN MIN PUMP OFF None Fill the hydraulic oil tank
(see note 4)
HYD OIL LEVEL SENSOR FAULT NONE None Check the sensor
HYD OIL TEMPERATURE HIGH NONE Check the cooler Check the fan and the secondary
MBX01CT101 circuit (see note 5)
HYD OIL STAND BY PUMP ON NONE None Check the main pump and the
pressure relief valve (see note 7)
HYD OIL PRESSURE < MIN NONE None Check pump, check sensor
MBX03CP005 (see note 6)
MIN MBX03CP006 (see note 6)
MBX03CP101 (see note 6)
Page 1 of 7
HYDRAULIC OIL SYSTEM – FAULT RECTIFICATION TGO3-9110-E00000
19.11.14
Alarm Effect on GT Possibility of Fault removal
operation intervention by the
operator
HYD OIL PRESS. DIFF. ACROSS NONE Pump switch over Clean filter (see note 1)
FILTER > MAX
MBX03CP001 or
MBX03CP002
HYD OIL PRESS. DIFF. ACROSS NONE Check the return Clean filter (see note 2)
FILTER > MAX filter
MBX08CP001
HYD. OIL SECOND. CIRCUIT NONE Check cooler Check secondary circuit and fan
FAULT (see note 8)
HYD. OIL PRESSURE < MIN GT TRIP None Check the pump, tank level and
MIN sensor (see note 6)
(2 v 3 MBX03CP005, …06,
…101)
Page 2 of 7
19.11.14
NOTE Change with Possible causes Corrective measures
respect to normal
conditions
1. MBX03CP001 Excessive § Differential § Check whether the alarm has
MBX03CP002 differential pressure switch been caused by the feed line
Hydraulic oil filter pressure faulty filter or by the return line filter
contaminated using the local displays.
§ Check differential pressure
switch
§ Oil highly § Feed line filter: switch over
contaminated, the stand-by oil pump, vent
filter damages spare filter and put it into
service by opening the valves.
Switch off operating pump,
close valves on the operating
filter. Clean the filter,
replacing the filter cartridges if
necessary. Plan to exchange
the oil during next scheduled
standstill if necessary. When
the faulty has been cleared,
switch back to the standard
supply using the operating
pump.
Page 3 of 7
19.11.14
respect to normal
conditions
2. MBX08CP001 return § Oil highly § Clean the filter. The filter can
filter contaminated contaminated, be cleaned/changed also with
filter damages the hydraulic oil unit running:
shift the manual valve
MBX06AA251 to the discharge
position. The return oil flows
now directly into the tank and
the return filter is isolated (by-
pass operation is possible for a
limited period of time).
Replace cartridges if
necessary. After the activity,
remember to shift again the
MBX06AA251 to the operating
position (return oil from
actuator shall pass the return
filter in normal operation).
§ Plan to exchange the oil during
next schedules standstill if
necessary.
3. MBX01CL001 Hydraulic oil level § Level switch faulty § Check level reading the
Hydraulic oil level slowly falling inspection glass, check level
low switches
§ Normal oil loss § Fill up the system using oil of

the same type
§ Drain valve or pipe § Clear the leakage

connection leaky
4. Hydraulic oil level § Level switch faulty § Check level reading the
MBX01CL101,001,002 rapidly falling. inspection glass, check level
Hydraulic oil level The pumps in the switches
very low hydraulic system
are disconnected, § Considerable leak § Hazard of fire: in the event of
a GT trip occurs in the hydraulic fire, push the fire protection
system button. Locate the leakage
and repair it.
Page 4 of 7
19.11.14
respect to normal
conditions
5. MBX01CT101 Hydraulic oil § Thermometer § Verify temperature by reading
Hydraulic oil temperature high faulty the local display, check
temperature high resistance thermometer Check
differential pressure switch
§ Fan on cooler for § Check electrical circuit and

the secondary oil driving motor
circuit not switched
on or faulty
§ Cooler in the § Isolate secondary circuit and

secondary oil clean cooler. The cooler can
circuit clogged be isolated also with the
hydraulic unit running by
shifting the manual valve
MBX06AA252 to the discharge
position. This way, oil from
secondary pump can by-pass
cooler and it is discharged
directly into the tank. This
operating mode is possible for
a limited period of time. When
the cooler is cleaned /
repaired, remember to shift
again the manual valve
MBX06AA252 to the operating
position (no bypass)
Page 5 of 7
19.11.14
respect to normal
conditions
6. MBX03CP101,005, Hydraulic oil § Pressure switch or § Check pressure switches or
006 pressure too low, pressure pressure transducer
Hydraulic oil GT trip occurs transducer faulty
pressure too low
§ Operating pump or § Check driving motor and
stand-by pump pumps
faulty
§ Oil leakage in the § Isolate and stop oil leakage

hydraulic feed line
system
§ Safety valves on § Check or readjust safety valves

the pumps
incorrectly
adjusted or stuck
§ Pressure limitation § Check or readjust pressure

valves incorrectly limitation valves
adjusted or stuck
7. Stand by pump is ON Hydraulic oil § Pressure switch § Check pressure switch
pressure low faulty
§ Operating pump § Check driving motor and pump

faulty
§ Pressure relief § Check or readjust relief valves

valve incorrectly
adjusted or stuck
§ Oil leakage in the § Hazard of fire in the event of

hydraulic feed line considerable leakage. In the
system event of fire, push the fire
protection button. Locate oil
leakage leak and repair it. If
necessary, shutdown the GT
Page 6 of 7
19.11.14
respect to normal
conditions
8. Hydraulic Oil Pressure in the § Pressure switch § Check pressure switch
secondary circuit secondary oil faulty
fault circuit low
MBX06CP001 § Secondary oil § Check ump
pump faulty
§ Oil leakage in the § Hazard of fire in the event of

secondary oil considerable leakage. In the
circuit, cooler or event of fire, push the fire
piping protection button. Locate oil
leakage leak and repair it. If
necessary, shutdown the GT
Page 7 of 7
19.11.14
HYDRAULIC OIL FOR FUEL OIL VALVES ACTUATORS - FAULT RECTIFICATION
The following alarms concern the system Hydraulic Oil for Fuel Oil Valves Actuators:
ALARM EFFECT ON GT OPERATION FAULT REMOVAL
DIFFUSION FEED or RETURN or

PREMIX CONTROL VALVE NOT
CLOSED Valve defective, check valve and
None
actuator
(pos > 0% when command closed
is present)
DIFFUSION FEED or RETURN Sluggish or defective, control

CONTROL DEVIATION > MAX FO-trip valve will be closed, check valve
(8%) and actuator
PREMIX VALVE, Sluggish or defective, control

CONTROL DEVIATION > MAX FO-PREMIX TRIP valve will be closed, check valve
(8%) and actuator
DIFFUSION FEED or RETURN

None in case of double LVDT
CONTR. VALVE POSITION FAULT Check position transducer
FO TRIP (in case of single LVDT)
(transducer -B01 or B02)

CONTR. VALVE POSITION double Check position
FAULT FO TRIP
transducers
(transducer -B01 and B02)

CONTR. VALVE Check output signals/ hardware
FO TRIP
device
POSITION REGULATOR FAULT
PREMIX CONTR. VALVE POSITION None in case of double LVDT

FAULT FO-PREMIX TRIP Check position transducer
(transducer -B01 or B02) (in case of single LVDT)
Page 1 of 3
HYDRAULIC OIL FOR FUEL OIL VALVES ACTUATORS – FAULT RECTIFICATION
TGO3-9120-E72000
20.11.14
PREMIX CONTR. VALVE POSITION

Check position
double FAULT FO-PREMIX TRIP
transducers
(transducer -B01 and B02)
PREMIX CONTR. VALVE Check output signals/ hardware

FO-PREMIX TRIP
POSITION REGULATOR FAULT device

CONTR. VALVE Check output signals/ hardware
FO-TRIP
device
VOLTAGE SUPPLY FAULT
PREMIX CONTR. VALVE Check output signals/ hardware

FO-PREMIX TRIP
VOLTAGE SUPPLY FAULT device

CONTR. VALVE FO-trip check valve and actuator
POSITION < MIN
PREMIX CONTR. VALVE

FO-PREMIX TRIP check valve and actuator
POSITION < MIN

CONTR. VALVE Position sensor fault, check
FO-trip
sensor and signal - line
MEASURING RANGE EXCEEDED
PREMIX CONTR. VALVE Position sensor fault, check

FO-PREMIX TRIP
MEASURING RANGE EXCEEDED sensor and signal - line
HP PURGING CONTROL VALVE

NOT CLOSED Valve defective, check valve and
NONE
(pos > 0% when command closed actuator
is present)
Page 2 of 3
TGO3-9120-E72000
20.11.14
- During premix or diffusion

purging: GT TRIP
HP PURGING CONTROL VALVE
NOT OPEN - During premix cooling: switch
Valve defective, check valve and
back in diffusion mode
(valve does not open when actuator
purging required) - During diffusion filling: no fuel
change over to fuel oil, GT stays
in NG mode
HP PURGING CONTROL . VALVE Check output signals/ hardware

NONE
POSITION MODULE FAULT device
HP PURGING CONTROL VALVE Check output signals/ hardware

NONE
VOLTAGE SUPPLY FAULT device
Page 3 of 3
TGO3-9120-E72000
20.11.14
HYDRAULIC OIL FOR FUEL GAS VALVES ACTUATORS - FAULT
RECTIFICATION
The following alarms concern the system Hydraulic Oil for Fuel Gas Valves Actuators:
EFFECT ON GT OPERATION
ALARM FAULT REMOVAL
PREMIX CONTROL VALVE OR GT TRIP Valve defective, check valve

PILOT CONTROL VALVE (*)NOT and actuator
CLOSED
(pos > 0% when command closed
is present)
PREMIX CONTROL VALVE GT TRIP Sluggish or defective,

CONTROL DEVIATION > MAX control valve will be closed,
(8%) check valve and actuator
PILOT CONTROL VALVE (*) GT TRIP Sluggish or defective,

CONTROL DEVIATION > MAX control valve will be closed,
(8%) check valve and actuator
PREMIX CONTROL VALVE GT TRIP Check output signals/

position regulator FAULT hardware device
PILOT GAS CONTROL VALVE GT TRIP Check output signals/

position regulator FAULT (*) hardware device
(*) PILOT or PILOT2 control valve depending on the specific project and depending on which one is in
operation.
Page 1 of 1
HYDRAULIC OIL FOR FUEL GAS VALVES ACTUATORS–
17.11.14
HYDRAULIC OIL FOR IGV/CV1 ACTUATOR - FAULT RECTIFICATION
The following alarms concern the system Hydraulic Oil for IGV actuator and, when it is provided for
the project, CV11 actuator:
Single fault alarm Effect on GT operation Fault removal
IGV or CV1 POSITION FAULT None in case of double LVDT Check IGV or CV1 position transducer
(transducer -B01 or B02) GT TRIP(in case of single
LVDT)
IGV or CV1 POSITION double GT TRIP Check IGV or CV1 position transducer
FAULT (transducer -B01 and
B02)
IGV or CV1 valve position GT TRIP Check output signals/ hardware

regulator FAULT device
IGV or CV1 CONTROL GT TRIP Check actuator, check hydraulic oil

DEVIATION > MAX (delayed system
by K.VLE.105)
IGV or CV1 NOT CLOSED IN NONE Check Fail Safe valve, check actuator
10s DURING GT TRIP GT trip is already on going
1
When expected by the project configuration
Page 1 of 1
HYDRAULIC OIL FOR IGV/CV1 ACTUATOR – FAULT RECTIFICATION TGO3-9150-E70001
17.11.14
LUBE OIL SYSTEM - FAULT RECTIFICATION
Safety Notices
The safety notices in this section are intended to supplement, not replace, the general safety
notices.
Danger!
Danger of Injury: The rotor must be at standstill before performing repairs.
Allow only appropriately trained personnel to perform repairs on the gas turbine.
Fire hazard!
Press the fire protection button Immediately to trip the GT In the event of rapidly
dropping oil level In lube oil tank. Press fire protection button immediately (GT
trips).
Caution!
Risk of bearing damage: turbine generator must never be operated with
nonfunctional oil pumps.
Caution!
Risk of bearing damage: the emergency lube oil pump must remain in operation
even In the event of motor overload.
Page 1 of 15
LUBE OIL SYSTEM – FAULT RECTIFICATION TGO3-9400-E00000
17.11.14
The following alarms concern the Lube Oil System:
Single fault alarm Effect on GT Intervention options Fault removal

operation for the operator
LUBE OIL FILTER CLOGGED None Switch filter over Open MBV25AA252 valve for
venting, then switch to auxiliary
filter with MBV25AA251 (see
note 1)
MAIN LUBE OIL PUMP FAULTY None None Check MBV21CP001, MBV26CP101
and main lube oil pump (see note 2)
AUXILIARY LUBE OIL PUMP None None Check MBV21CP001, MBV26CP101

FAULTY and auxiliary lube oil pump (see
note 3)
Page 2 of 15
17.11.14
EMERGENCY LUBE OIL PUMP None None Check power supply. Do not
FAULT disconnect emergency lube oil
pump (see note 4)
ECO RELAY EMERGENCY LUBE None None Check ECO relay functioning (see
OIL PUMP FAULTY note 5)
EMERGENCY LUBE OIL PUMP None Switch pump off if Check all lube oil pressure switches,
RUNNING necessary lube oil tank level and low-voltage
power supply (see note 6)
EMERGENCY LUBE OIL PUMP None None Check temperature switch on

OVERLOAD emergency lube oil pump. Do not
disconnect emergency lube oil
pump (see note 7)
EMERGENCY LUBE OIL PUMP GT TRIP Pump off by manual None, condition is cleared only
FIRE PROTECTIVE OFF intervention when fire protection signal is no
longer present (see note 8)
OIL VAPOUR BLOWER FAULTY None None Check oil vapour blower. If both
blower fails, GT shut down can be
necessary (see note 9)
LUBE OIL TANK LEVEL LOW None Refill lube oil Check lube oil tank and level
switches (see note 10)
LUBE OIL TANK LEVEL HIGH None None Check lube oil tank and level
switches (see note 11)
LUBE OIL TANK TEMPERATURE None Switch lube oil Switch lube oil heating on and check
LOW heating on temperature sensors. Separate
alarm for each temperature sensor
(see note 12)
Page 3 of 15
17.11.14
LUBE OIL FEED LINE None Switch lube oil Switch lube oil heating off, check
TEMPERATURE HIGH heating off (during temperature sensors and switch
standstill) lube oil cooler on if necessary.
Connection delay K.SCHMOEL.01
(see note 13)
LUBE OIL SYSTEM PRESSURE None None Check MBV21CP001, MBV26CP002
SENSOR FAULTY and MBV26CP101
TEMPERATURE LUBE OIL TANK No start Switch lube oil heating on and check
FOR GT START NOT >MIN release temperature sensor
LUBE OIL TANK LEVEL VERY GT TRIP None Check lube oil tank level
LOW (see note 10)
LUBE OIL TANK LEVEL VERY GT TRIP None Check lube oil tank level and water
HIGH cooler (see note 11)
LUBE OIL PRESSURE VERY LOW GT TRIP None Check pressure switches and pumps
LUBE OIL PUMPS VOLTAGE GT TRIP None Restart voltage at 380 Bus Bars
LOSS
Page 4 of 15
17.11.14
Change with
NOTE respect to normal Possible causes Corrective measures
conditions
1. Lube oil filter fouled Excessive § Oil badly fouled § Open venting valve, change
differential over to standby filter and
pressure during clean main filter
normal operation
§ High dust content § Maintain dust-free ambient
of ambient atmosphere
atmosphere
§ Dust penetrates § Increase pressure in bearing

the bearing casings casings
via the seal rings
§ Dust penetrates § Improve sealing of lube oil

openings in the tank
lube oil tank
§ Filter damaged § Replace filter elements
Excessive § Oil circuit not § Drain and filter oil, clean lube
differential properly cleaned oil tank and refill with filtered
pressure after and flushed oil
major inspection following major § Repeat flushing
inspection
Page 5 of 15
17.11.14
Change with
conditions
2. Main Lube Oil Pump Main Lube Oil § Power failure § Check power supply
Fault Pump does not
start § Overcurrent relay § Check/adjust overcurrent
set too low relay
§ Pressure switch § Check pressure switch setting

and / or pressure § Replace pressure switch,
transducer faulted check pressure transducer
§ Motor overloaded § Determine cause of overload
§ Motor defective § Check/repair motor
§ Pump damage § Check pump for proper

mechanical and electrical
function; repair if necessary
Electrical fault § Interior fault, short § Check motor / switch gear

circuit in motor, at
the motor
terminals, in the
switchgear
Page 6 of 15
17.11.14
respect to normal
conditions
3. Auxiliary Lube Oil Auxiliary Lube Oil § Power failure § Check power supply
Pump Fault Pump does not
start § Overcurrent relay § Check/adjust overcurrent
set too low relay



the motor
terminals, in the
switchgear
Warning
Main and auxiliary lube oil pumps fail during operation or during shutdownà the emergency oil pump
starts automatically and the GT is automatically tripped. Repair main and auxiliary lube oil pumps.
Page 7 of 15
17.11.14
Change with
conditions
4. Emergency Lube Oil Emergency Lube § Power failure, dead § Check power supply
Pump Fault Oil Pump does batteries
not start
§ Thermal protection § Check/adjust thermal
switch set too low protection switch
or defective.



the motor
terminals, in the
switchgear
5. Emergency Pump, ECO relay is § Contacts, coil § Perform functional test of ECO
ECO relais Fault activated during defective relay
every GT start
6. Emergency Oil Pump Emergency oil § Lube oil pressure § Check all lube oil pressure
running pump switches on switch defective, switches, oil level in lube oil
during operation oil level in lube oil tank and level switch.
or during startup tank too low or
although the level switch
main or auxiliary defective.
lube oil pump is
in operation
7. Emergency Oil Pump Emergency oil § Pump or motor § Check pump for proper
overloaded pump overloaded damaged, pump or mechanical and electrical
motor sluggish (e.g. function; repair if necessary
bearing damage,
rotating parts
rubbing.)
Page 8 of 15
17.11.14
Note 8: Fire protection activated
In case of fire detection activated, the main- and auxiliary lube oil pump are switched off and
the emergency lube oil pump is switched on by automatic control.
The connection of the emergency lube oil pump is ensured either via a PROTECTIVE ON
command by the decreasing lube oil pressure, or directly by means of the MBV26CP003
pressure switch (ECO relay remains still in ON position for 5 sec.), or by the fire protection
signal (active no longer than for 5 sec.) The automatic interruption mode keeps the
emergency lube oil pump switched on. The short time of 5 sec. is necessary and admissible
since the emergency lube oil pump needs a sufficient time to be switched on and because
the service personnel may need time to decide whether the manual disconnection of the
emergency pump is really necessary (with probable machine damage).
The operator has the possibility to disconnect the emergency lube oil pump manually with
priority over the automatic commands.
In fact the operator must have the possibility to decide whether to risk damage to the
bearings if the pump is disconnected or to risk damage by the fire to the personnel.
In order to avoid that the MBV26CP003 pressure switch connects again the emergency lube
oil pump, the ECO relay is disconnected 5 sec. after the fire protection has been activated.
In case of general control system fault, the emergency lube oil pump is switched on via the
additional 220V control circuitry due to the decreasing lube oil pressure at MBV26CP003 and
it is kept in operation. Manual disconnection via the driving unit control function is not
possible. The only alternative to stop the pump, provided that it is required, is the direct
intervention on the switch gear by the operator.
Page 9 of 15
17.11.14
Change with
conditions
9. Oil Blower fault No negative § Motor defective § Check motor, repair blower
pressure in the
bearing casings, oil § Power failure § Check power supply
drain lines and
lube oil tank § Overcurrent relay § Check/activate overcurrent
set too low protection
§ Extractor fouled § Replace blower
Warning
Extended operation without negative pressure results in oil leaking from the bearing casings.
Page 10 of 15
17.11.14
Change with
conditions
10. Lube Oil Level Level in lube oil § Level switch § Check level switches /
low / very low tank slowly defective transducer
dropping § Normal loss of oil § Refill using same type of oil
§ Excessive negative § Measure and correct negative
pressure in the pressure, check blowers
bearing casings, oil
drain lines and lube
oil tanks too high.
§ Drain valves leaking § Tighten valve bolts
§ Seal discharge line with plugs
§ After graining oil from line,
rework drain valve
§ Oil loss at bearing § Localize and eliminate leak
casings § Check for smoke originating
from turbine and compressor
bearing casings
§ Replace / repair compressor
and/or turbine shaft glands
§ Leaks in oil cooler § Switch to stand-by cooler,
tubing repair leaking cooler
§ Return line or § Check and clear return lines or
return ducts ducts, check screen, clean and
obstructed, screen examine residues
in lube oil tank
fouled
10. Lube Oil Level Level in lube oil § Large leak in lube § Fire hazard! Press fire
low / very low tank rapidly oil system protection button
dropping immediately (GT trips). Locate
leak and take corrective action
Alarm occurs § More oil in § Important: add only enough

during turning circulation than oil to deactivate the alarm.
gear operation during normal Add oil
operation
Page 11 of 15
17.11.14
Change with
conditions
11. Lube Oil Level § Large leak due to § Check water pressure in lube
high / very high lube oil cooler oil cooler, repair leak / restore
proper pressure values. Switch
off the water pump to lube oil
cooler
12. Lube Oil With GT shutdown, § Lube oil heating § Start lube oil heating system
Temperature low temperature in system not active and check the raise in
lube oil tank temperature
<T.SCHMOEL.01
13. Lube Oil Lube oil § Lube oil heating § Disconnect oil heating system,
Temperature high temperature in system active check temperature measure
supply line
>T.SCHMOEL.04 § Cooling water § Check cooling water pump
system and motor; repair if necessary.
contaminated Check cooling water
temperature. Check flow of
cooling water, search for leaks
§ Temperature § Switch thermostatic valve to

control valve fault “Emergency manual mode”.
Repair temperature control
valve during next GT outage.
§ Lube oil cooler § Clean lube oil cooler, check

fault motor, power supply,
switchgear
§ Lube oil cooler not
completely vented § Vent lube oil cooler
§ Lube oil cooler

bypass flow too § Check orifice setting
high
§ Check supply of coolant to
§ Supply of coolant lube oil cooler
medium to lube oil
cooler fault
Page 12 of 15
17.11.14
Additional Fault Causes:
Change In Normal
Possible Causes Corrective Measures
Condition
Oil badly fouled. High dust content of ambient Maintain dust - free ambient atmosphere
Oil fouled during atmosphere
normal operation Dust penetrates the bearing Increase pressure in bearing casings
casings via the seal rings
Dust penetrates openings in Improve sealing of lube oil tank
the lube oil tank.
Oil badly fouled Oil circuit not properly cleaned Repeat flushing
following a major and flushed following major
inspection inspection
Differential Filter clogged Replace filter elements, clean filter more often
pressure too high
Drain and filter oil, clean lube oil tank and refill
Oil badly fouled
with filtered oil
Oil very milky Excess negative pressure in Decrease suction
(emulsified) bearing casings
Check negative pressure (vacuum) and reset
Excess oil vapor extraction
pressure, if necessary
Declining air release Test air release of oil sample
Lube oil cooler is defective if Drain water from lube oil tank. Switch to
water pressure greater than standby lube oil cooler. Replace lube bundle in
lube oil pressure. lube oil cooler
Oil contains too Turning gear shutoff valve not Close turning gear shutoff valve, check oil level
much air (foams completely closed. in bearing casing
excessively) Turning gear running in oil
Circulating oil flow too high Reduce flow of oil to bearings
Oil level low (oil flows too Add oil, see above
quickly through lube oil tank)
Oil vapor extraction defective Start oil vapor extractor or rectify fault
or not switched on
Draw oil sample and test oil for air release and
Air release of oil inadequate
foaming (see corrective measures below)
Page 13 of 15
17.11.14
Change In Normal
Condition
Oil properties Air release Consult oil supplier. In case of severe changes
change (oil test) in air release, the oil must be changed after
flushing the oil circuit with fresh oil.
Foaming Consult oil supplier.
Additives can improve foaming behavior of oil.
Excessive dosing with foam inhibitors can
degrade air release.
Auxiliary or Pressure switch faulted. Check setting of pressure switch.
emergency oil
pump
automatically Replace pressure switch.
started despite
normal lube oil
pressure. Test valves open.
Close test valves.
Main, auxiliary or Pump shaft out of balance. Check and rebalance pump shaft.
emergency lube oil Pump bearings damaged. Fact-finding inspection of bearings (repair or
pump runs noisily replace).
Motor bearing damage. Check motor, replace motor bearings.
Oil contains too much air See above.

(cavitation).
Pump internals damaged. Check pump for proper mechanical and
electrical function; repair if necessary.
Auxiliary or Check valve jammed or leaking Remove check valve, restore freedom of
emergency oil pump (oil pressure develops between motion or overhaul seat.
turns in reverse the pump and the check valve).
direction.
Main, auxiliary or Impeller damaged. Replace impeller.
emergency oil pump Check valves jammed. Replace check valves.
delivers no oil. Oil level too low. Add oil.
Page 14 of 15
17.11.14
Change In Normal
Condition
Delivery rate or Pump rotating in reverse Reverse phases at motor terminals.
delivery pressure of direction.
main auxiliary or Oil contains too much air. See above.
emergency oil pump Oil temperature too low. Check temperature control valve.
is too low. (inadequate air release).
Pump damage. Check pump for proper mechanical and
electrical function.
Excessive consumption due to Check oil lines and valves.
leaks.
Lube oil pressure Excessive consumption due to Check oil lines and valves.
upstream of oil leaks.
cooler too low or
unstable during Oil contains too much air. See above.
normal operation.
Main or auxiliary lube oil pump See above.
runs noisily.
Main or auxiliary pump is See above.
rotating in reverse direction
(pump not started).
Delivery pressure of main or See above.
auxiliary lube oil pump too low.
Page 15 of 15
17.11.14
ROTOR DISPLACEMENT SYSTEM (RDS) SYSTEM - FAULT RECTIFICATION
Safety Notices
The safety notices in this section are intended to supplement, not replace, the general safety
notices.
Danger!
Danger of Injury: The rotor must be at standstill before performing repairs.
Allow only appropriately trained personnel to perform repairs on the gas turbine.
Fire hazard!
Press the fire protection button Immediately to trip the GT In the event of rapidly
dropping oil level In lube oil tank. Press fire protection button immediately (GT
trips).
Caution!
Risk of bearing damage: turbine generator must never be operated with
nonfunctional oil pumps.
Caution!
Risk of bearing damage: the emergency lube oil pump must remain in operation
even In the event of motor overload.
Page 1 of 5
RDS SYSTEM – FAULT RECTIFICATION TGO3-9600-E00000
19.11.14
The following alarms concern the RDS System:
Effect on GT
Single fault alarm Fault removal
operation
RDS DIFF-PRESS OIL FILTER HIGH Check oil filter, clean as necessary. If filter
None
clean, check pressure switch
RDS system 1 pressure transducer fault Check transducer
None
(MBA51CP101, 102, 103)
RDS system 2 pressure transducers fault Check transducer, rectify fault
GT shut down
(MBA51CP101 , 102, 103)
MAIN / SEC system Check transducer
1 pressure transducer fault None
(MBA53CP101,102,105 or 103,104,106)
MAIN / SEC system Check transducer, rectify fault
2 pressure transducers fault GT trip
(MBA53CP101, 102,105 or 103,104,106)
RDS / MAIN /SEC pressure transducers – non Check transducer, check signal
equivalence monitoring (between
None
MBA51CP101,102,103 or MBA53CP101,102,
105 or MBA53CP103,104,106)
RDS PUMP 1 or 2 fault Check pressure switch, check pump
None, stand-
(pressure at MBA51CP001 or MBA51CP002 by pump on
< MIN)
RDS-PUMP 1 or 2 isolating vlv CLOSED None, pump Open isolating valve
(MBA51AA251 / 252 closed) cannot be
switched ON
RDS Pressure switch fault Check / restore pressure switch
(MBA51CP001 or MBA51CP002 > MAX when None
pump is OFF)
RDS pressure too low No sufficient pressure available for GT
(MBA51CP101/102/103 < P.HSO.09) operation.
GT shut down
(logic 2oo3) Check RDS system for leakages, test pumps
and pressure measuring transducer
Page 2 of 5
19.11.14
Effect on GT
operation
ACCUMULATOR FILLED TOO QUICKLY Check accumulator for faulty bladder. Test
(P.HSO.03 attained within time K.HSO.07) None pressure transducer
RDS PRESSURE FALLS, LEAKAGE (P.HSO.04 GT can be further operated; check RDS
None
within K.HSO.12) system for tightness.
PRESSURE TOO HIGH (>P.HSO.07) IN NOT Check RDS system for tightness
GT Trip
ACTIVATED CHANNEL (with time delay 10 s)
HIGH PRESSURE (>P.HSO.100) IN SEC Check safety valves and pressure

CHANNEL None transducer
TOO HIGH PRESSURE (>P.HSO.102) IN SEC Check safety valves and pressure
GT Trip
CHANNEL (with time delay 10 s) transducer, check SEC return valve for not
opening
NO PRESSURE IN ACTIVATED MAIN None, RDS is Check pressure transducers, check for
CHAMBER (< P.HSO.09) deactivated leakage, check MAIN return valve
NO PRESSURE IN ACTIVATED SEC CHAMBER None Check pressure transducers, check for
(< P.HSO.09) RDS can be leakage, check SEC return valve
activated
(provided time
K.HSO.04 has
elapsed)
Shaft monitoring position 1 sensor fault Check transducer and signal conditioning
None
(MBA10CG101 or 102)
Shaft monitoring position 2 sensors fault GT trip (only Check transducers, rectify fault
(MBA10CG101 and 102) from cold
condition)
Shaft position – non equivalence monitoring Check transducer, check signal
None
(between MBA10CG101 and 102)
SHAFT NOT IN NULL POSITION (time < Check linear recorder inclusive of signal
K.HSO.04) GT Trip conditioning
Page 3 of 5
19.11.14
Effect on GT
operation
SHAFT ABANDONED MAIN POSITION Check transducers and RDS system
None
RDS SYSTEM - MAIN POSITION NOT None RDS deactivated. Check transducers and
REACHED RDS system
RDS
preselection
reset
RDS SYSTEM - NULL POSITION NOT None (if time > RDS remains activated. Check transducers
REACHED K.HSO.04) and RDS system
RDS
preselection
reset
RDS SYSTEM - MAIN POSITION REACHED None Check RDS system pressure and setting of
TOO QUICKLY Possible flow control valves, check for any damages
damages to at the bearing
the bearings
RDS SYSTEM - NULL POSITION REACHED None Check RDS system pressure and setting of
TOO QUICKLY Possible flow control valves, check for any damages
damages to at the bearing
the bearings
See in addition
Adjusting of the RDS system section TGO3-0070
Page 4 of 5
19.11.14
Change with
conditions
1. RDS filter 1 / 2 Excessive § Oil badly fouled § Check lube oil filter, change
fouled differential RDS filters with GT at
pressure during standstill. Change to the stand
normal operation by pump.
§ High dust content § Maintain dust-free ambient

of ambient atmosphere
atmosphere
§ Filter damaged § Replace filter elements

Excessive
differential § Oil circuit not § Drain and filter oil, clean lube
pressure after properly cleaned oil tank and refill with filtered
major inspection and flushed oil
following major § Repeat flushing also of the
inspection RDS system
2. RDS Pump 1 / 2 Fault RDS Pump does § Power failure § Check power supply
not start
§ Over current relay § Check/adjust over current
set too low relay

§ Interior fault, short § Check motor / switch gear

Electrical fault the motor
terminals, in the
switchgear
In case of fire protection activated the RDS system is disconnected and the RDS pumps switched OFF.
Page 5 of 5
19.11.14
SEAL FAN SYSTEM - FAULT RECTIFICATION
The following alarms concern the SEAL FAN SYSTEM MBH 1 :

operation
Fan 1 faulty None Check the fan, check the voltage supply
Seal air temperature, high None Check temperature sensor, check connection
discrepancy
Seal air, temperature sensor 1 None Check temperature sensor, check connection
faulty
faulty
faulty
Seal air temperature < None Check the number of operating fan.
T.SPERRL.01
Seal air temperature > None Check the number of operating fan / check the fans
T.SPERRL.02 / check the cooler
Seal air temperature > GT trip Check the number of operating fan / check the fans
T.SPERRL.03 / check the cooler
See also section

1
Page 1 of 1
SEAL FAN SYSTEM, FAULT RECTIFICATION TGO3-9700-E70000
09.11.14
MAINTENANCE
INSPECTION AND MAINTENANCE INTERVALS
High GT availability and reliability require regular inspection of representative components.

The plant equipment and scope of inspection listed here is by no means complete and must be
continually modified by each operator on the basis of his operating experience.
Safety
Ensure compliance with all safety and hazard notices presented in this manual and in the vendor
documentation.
Inspection Intervals and Sequence

Inspections are scheduled on the basis of equivalent operating hours. However, a ordinary day-by-
day maintenance can be carried out also during other GT shut down periods or when occasion
occurs. The here indicated time intervals (in Operating Hours) are considered for reference on
activities to be carried out.
The inspection intervals are based on the following operating hours:
• every 100 operating hours or weekly
• every 4000 operating hours or every 6 months
• every 8000 operating hours or every 12 months
• after outages lasting longer than 5 months.
If the GT is in continuous power operation, it is appropriate to postpone the 4000 operating hour
inspections until the next weekly outage. The inspections must be organized in such a way that the
impact on operation of the GT is minimized
Many of the Inspections should be performed during operation to permit evaluation of the system
under operating conditions.
Inspections performed with the GT at standstill must be performed during scheduled outages (e.g. on
weekends) using a detailed inspection program (e.g. checklists).
In addition to this inspection and maintenance task, the following instruction / procedures must be
followed:
- Intervals for cleaning filters and strainers TGO4-0049
- lubricating chart TGO4-0052
- compressor cleaning, sections TGO4-4961 / 4962
- general gas turbine cleaning including auxiliary systems (depending on site conditions)
Page 1 of 9
INSPECTION AND MAINTENANCE INTERVALS TGO4-0032-E71001
19.11.14
Note:
inspections under section TGO5 must be carried out by Ansaldo Energia personnel or under
its supervision.
Evaluation of Results
Early detection of gradually progressing deficiencies and impending changes is made possible by the
use of the evaluation chart and documentation of previous inspections.
Preventive measures and timely rectification of deficiencies can greatly reduce downtime, prevent
costly repairs and increase the operating availability of the GT.
The entry in the column KKS System refers only to system level components and equipment.
Refer to the plant-specific Instrument, Equipment and electrical load lists.
Abbreviations In the Column ,,Op. Co.” (Operating Conditions)

The Column “Op. Co. (Operating Conditions) gives the operating conditions for the mentioned
inspections/tests. The following abbreviations are used:
O Operation
S Standstill/outage
NOTE:
This section applies to any gas turbine AE94.3A in general. Systems which are not part of the order
related configuration must be ignored (es. fuel oil system where not applicable, etc.).
Page 2 of 9
19.11.14
Inspection Interval: Every week
KKS Op. Instructions / Information

Component / Equipment Inspections and Checks
System Co.
ALL • All pipes, valves, tanks • Visual check for leak all O / - Visual check for liquid
valves, flanges, tanks S leakage
- Use a different gas
detection system than
used by the gas alarm
• Pressure gauge • Visual check for leak equipment
O/
S - Replace if damaged or if
• Cable • Mechanical damage indication is not correct
O / - Check that cables and

S conduits are integer
MBV – • MBV10CL501 - Level of • Visual inspection through O - Oil level measurement

Lube and lube oil tank sight glass on the lube oil tank as
lifting oil • Measurement of oil level per
system • Comparison of new and - Record TGTR-0060.
previous measurements - Oil quality see TGO2-
(if tank has not been 0171
topped up since last - See TGO4-1510.
measurement). Top up if
necessary.
MBV – • MBV25CP001 - lube oil • Sudden color change O/ During a shut down, with
Lube and filter S the turning gear in
lifting oil operation:
system - Check local display
- Foresee a filter cleaning
during next outage
- The sudden color
change can be
determined by
1. increase in dirtiness:
dirtiness is gragged
2. decrease in dirtiness:
the filter element has
broken.
Page 3 of 9
19.11.14
Inspection Interval: Every week
KKS Op. Instructions /

System Co. Information
MBV – • Lifting oil pressure ≈ 160 bar - 200 bar S During a shut down, with
Lube and the turning gear in
lifting oil operation:
system - Check local display
- Check if the pump
delivers always the
same pressure at the
same conditions. In
case of change of 10
bar in pressure, check
for leakage and check
the pump.
MBX • MBX01CL501 - Level of ≈ max. O / S - Check local display.
Hydraulic hydraulic oil tank Compare level with
system previous levels
(provided oil not
added in the
meantime)
MBX • MBX03CP501 - hydraulic ≈ 160 bar O / S - Pump MBX02AP001 is

Hydraulic oil pressure downstream running. It is
system of pump 1 preferable to keep this
pump in operation.
Page 4 of 9
19.11.14
KKS Op. Instructions /
System Co. Information
MBX • MBX03CP502 - ≈ 160 bar O / S - Pump MBX02AP002 is
Hydraulic hydraulic oil pressure running when
system downstream of pump 2 MBX02AP001 has
been stopped.
- During GT start up
hydraulic oil is
required to move the
valves actuators. Both
hydraulic oil pumps
are switched ON in
this phase.
MBX • MBX24CP501 – ≈ 7 bar O / S - Check local display

Pneumatic Pneumatic pressure
system
MBX • MBX21AN001, ≈ 7 max O / S - Check oil through sight
Pneumatic MBX22AN001 – glass
system Pneumatic compressors - Add oil, if necessary; in
case of fast level
changing, check that
no leakage occurs.
Inspection Interval: Every 4000 operating hours in addition to inspections performed every
week
KKS Op. Instructions / Information

System Co.
MBM • MBM13CR101 / • Check lens and quartz S - Check quartz disk if the
Combustio MBM13CR102 flame disks is necessary (see flame detector, clean
n chamber monitor section TGO4-5009) off deposits is necessary
- Check lens, clean from
dust is necessary.
Page 5 of 9
19.11.14
Inspection Interval: Every 8000 operating hours in addition to inspections performed every 4000
operating hours
KKS Op.
Component / Equipment Inspections and Checks Instructions / Information
System Co.
MBA – • MBA11AS001 – IGV • Check for physical S - Visual check for leakage
Turbine and actuator and MBA11AS002 damage and leakage
compressor – CV1 actuator • Check position indicator, - Visual check for damage
check mechanical parts or position changes
• MBA11CG501 – IGV (where accessible) when the actuator
position indicator and moves
MBA11CG502 – CV1
position indicator
MBD – • Generator / turbine • Check S - Visual check of the
Bearings absolute and relative instrumentation
vibration monitoring - Check the circuit using a
Vibrometer calibrator
(see Outside Vendor
Parts)
MBM – • MBM10CY101 • Check S - Visual check of the
Combustion MBM10CY102 instrumentation
chamber MBM10CY103– - Check the circuit using a
acceleration monitoring Vibrometer calibrator
(see Outside Vendor
Parts)
MBM – • MBM11CP101/102– • Check S - Visual check of the
Combustion humming monitoring instrumentation
chamber • MBM12CP107/110/115 - Check the circuit using a
Humming monitoring Vibrometer calibrator
(see Outside Vendor
Parts)
Page 6 of 9
19.11.14
KKS Op.
System Co.
MBV – Lube Fire protection activation • Check the lube oil pumps S Perform the test with the
and lifting • Lube oil pump disconnection is case of GT at 0 speed (no turning
oil system disconnection fire and the auto start of operation mode)
the emergency oil pump The test is successful if:
- the lube oil pumps are
correctly disconnected
and the emergency
pump starts
- also manual
disconnection of
emergency oil pump is
possible (only in this
case of fire protection
activated).
Inspection Interval: Every 8000 operating hours in addition to inspections performed every 4000
operating hours
KKS Op.
System Co.
MBX – MBX04BB001, MBX04BB002 • Check the discharge S At 0 speed or in turning
Hydraulic MBX07BB001, MBX09BB001 - pressure gear mode.
oil system bladder accumulators - Use a nitrogen bottle
with pressure reducing
valve.
- Warning: check with the
Supplier the point for
gas regulation, from the
hydraulic oil side 90 bar
(or 105 bar – depending
by hydraulic power unit)
at 50°C (use the
conversion table of the
accumulator Supplier)
MYB Control System • Manual GT emergency S The test is successful if:
• Emergency stop stop using emergency - the alarm indicates that
pushbutton stop button on remote or the GT trip is occurred
control panel or control - no other equivalent
room panel alarm due to the
manual operation is
displayed
Page 7 of 9
19.11.14
Inspection Interval: After outage of more than 5 months in addition to inspections performed
every 4000 and 8000 operating hours
KKS Op.
System Co.
MBA Turbine and Compressor • Closing of blow-off valves S
• Blow-off valves according to speed (by The pneumatic system
simulated speed input) must be operating
• Opening of the blow-off
valves by simulated
emergency stop
• Check of the appropriate
valve position with
associated status
discrepancy alarm
• Turbine exhaust temperature • Measurement check via S Comparative

indication indicating and recording measurement of actual
instruments measurement with
ambient temperature.
• IGV/CV1 adjustment device • Check of minimum and S Actuate manually (control

maximum position with console)
position indicator
MBD / Bearings • Limit check with alarm S With the lube oil supply
MKD • Bearing metal temperature and trip switched on, observe the
protection bearing metal
temperature (rate of rise)
• Vibration protection • Limit check with alarm S Actuation by simulated

and trip signals
MBN Fuel Oil System • Check of system S Actuation by simulated
• Fuel oil system shutdown shutdown on actuation of trip. Check performance of
turbine protection system switching and positioning
• Check correct purging commands directly at
sequence equipment units.
• Check control valve lift in
open and closed direction
with position comparison
with indication at control
desk
Page 8 of 9
19.11.14
MBP Fuel Gas System S
• Fuel gas system shutdown • Check functional - Trip by simulated
switching of vented gas actuation
seal during protection trip
• Check control valve lift in

open and closed direction
with position comparison
with indication at control
desk
Page 9 of 9
19.11.14
INTERVALS FOR CLEANING FILTERS AND STRAINERS
NOTE:
related configuration must be ignored (e.g. fuel oil system where not applicable, water EMU
system where not applicable, etc.).
This section is not a detailed procedure for cleaning the filters. Refer to the Outside Vendor Parts for
any component. This section has the purpose to furnish general information for a global
understanding of the involved operations.
All information referring to the safety rules must be observed.
Warning!
Danger to be hurt: Depressurize the system before carrying out any manual work on
filters which lay on high pressure system.
Page 1 of 3
INTERVALS FOR CLEANING FILTERS AND STRAINERS TGO4-0049-E70000
19.11.14
KKS Name Maintenance Interval Remarks
MBA10AT001 Dehumidifier Check filter cleanliness; After 20 uses of the The air dryer
Filter clean/replace filter if dehumidifier or at must be OFF.
necessary 4000/8000 EOH. See Vendor Parts
MBA18AT002 Compressor Clean filter. After about 5 cleaning The system must
cleaning filter operations be NOT
operating
MBA51AT001 RDS filters Clean filter. After response of the Clean the filters
MBA51CP003 Warning! fouling indicator. when the system
MBA51AT002 Risk of injury: wait until is not operating.
MBA51CP004 pressure in system has See Vendor Parts
MBA52AT001 decayed!
MBA52CP001
MBN11AT001 Fuel oil filter Switch over to stand-by When responding See Vendor Parts
MBN11AT002 (*) filter on indication of differential pressure
MBN11CP001 differential pressure switch switch
MBP11AT001 Natural gas Clean the inlet part of the Inspect the system for The strainer
MBP11AT002(* strainer strainer and the casing clogging every 2 years. clogging is not
*) expected (< 0.5
mm)
MBV25AT001 Lube oil filter Check fouling indicator. If After response of the Check the local
MBV25AT002 necessary switch over to fouling indicator. indication before
MBV25CP001 reserve filter. Clean filter any planned shut
and the inner part of the down, clean in
casing. case of clogging.
See Vendor Parts
MBV30AT001 Lifting oil Switch over to stand-by After response of the Check the local
MBV30AT002 filter filter on indication of fouling indicator. indication before
MBV30CP001 differential pressure switch any planned shut
Warning! down, clean in
Risk of injury: wait until case of clogging.
pressure in system has See Vendor Parts
decayed!
MBV35AT001 Tuning Oil Switch over to stand-by After response of the Check the local
MBV35AT002 Filter filter on indication of fouling indicator. indication before
MBV35CP001 differential pressure switch any planned shut
Warning! down, clean in
Risk of injury: wait until case of clogging.
pressure in system has See Vendor Parts
decayed!
MBV50AT001 Oil vapor Clean the grid insert Every 8000 EOH No visual ∆P
extractor indication
Page 2 of 3
19.11.14
KKS Name Maintenance Interval Remarks
MBU24AT001 Water EMU Switch over to stand-by When responding See Vendor Parts
MBU24AT002 filter(*) filter on indication of differential pressure
MBU24CP001 differential pressure switch switch
MBX03AT001 Hydraulic oil Warning! After response of the Switch on the
MBX03AT002 filter Risk of injury: switch off the fouling indicator. stand by pump.
MBX03CP001 running pump (and activate It is suggested to
MBX03CP002 the stand by one), isolate clean the filter
the circuit and wait until on next planned
pressure in system has outage.
decayed. See Vendor Parts
Clean filter housing and
replace filter element.
MBX08AT001 Hydraulic oil Switch over to bypass. After response of the See Vendor Parts
MBX08CP001 return line Clean filter housing and fouling indicator.
filter replace filter element. Replace filter element
once a year
MBXxxAT001 Hydraulic Warning! At first standstill after Clogging of these
filter in valves Risk of injury: wait until indication by the filters is not
actuators (gas pressure in system has fouling indicator. expected.
/ oil / water) decayed! See Vendor Parts
control valves Clean filter housing and
/ stop valves replace filter element.
Filters Pneumatic Clean filter, when necessary Every 500 hours of The interval
upstream system filters operation of the refers to the
Pneumatic compressor (see the operating hours
compressors operating hours in the of the pneumatic
MBX21AN001 local control cabinet) compressor
MBX22AN001 See Vendor Parts
MBX21AT002 Direct Clean the grid. Any year or when See section
MBX22AT002 Expansion necessary TGO4-5016
Compressed Replace the drainage trap before start up
Air Dryer and the filtering element- Every 1-2 years or
when necessary.
MBX21AT001 Condense Replace the filter After GT shut down See Vendor Parts
MBX22AT001 separators when the indicator
responds
(*)in case of Dual Fuel Gas Turbine
(**) in case of two parallel fuel gas stop valves (heater on the premix line)
Page 3 of 3
19.11.14
LUBRICATION CHART
NOTE:
related configuration must be ignored (es. fuel oil system where not applicable, water EMU system
where not applicable, etc.).
No. of
Relubrication with
KKS Item lube Q Interval Remarks
(*)
point
MBA18AP001KP01 Compressor 1 ISO VG46: If Replace
cleaning ESSO Tbearing>50°C bearing (**)
water pump AGIP every 6
MOBIL months
If
Tbearing<50°C
every
12 months
MBA18AP001M01 Three-phase 2 Lithium E. P. Soap Replace
motor grease, stiffness bearing (**)
NLGI 2
MBA51AP001KP01 RDS pumps 2 Litium soap grease 24,000 EOH Remove, clean,
MBA51AP002KP01 or equivalent or 2 years inspect the
pump bearings.
Replace if
necessary.
MBA51AP001-M01 Three-phase 2 Shell: Alvania R3 20,000 h Replacement of
MBA51AP002-M01 motor (max 3 bearing (**)
years)
MBH22AA101-M01 Cooling air 1 Shell: Alvania 1029 0.6 kg 6 – 8 years
MBH22AA102-M01 valves, motor / 0.67
MBH23AA101-M01 - gear dm3
MBH23AA102-M01
MBH22AA101-M01 Cooling air Shell: Alvania 1029 0.35 6 – 8 years
MBH22AA102-M01 valves, motor kg /
MBH23AA101-M01 - screw 0.39
MBH23AA102-M01 dm3
MBN12AP001KP01 Fuel oil 1 Beacon 3 (ESSO) or 25 g 1600 hours
injection equivalent multi
pump purpose grease
Page 1 of 3
LUBRICATION CHART TGO4-0052-E71000
19.11.14
No. of
Relubrication with
(*)
point
MBN12AP001-M01 Fuel oil 2 DIN 51825/KL3K 1 ½ years
injection Lithium soap base (max.)
pump, motor 10000 hours
MBN60AP001-M01 Fuel oil 2 DIN 51825/KL3K 10 g 2 ½ years
leakage Shell Alvania R3 (max.)
pump, motor 20000 hours
MBN82AP001-M01 Purging water 2 DIN 51825/KL3K 10 g 2 ½ years
pump, motor Shell Alvania R3 (max.)
20000 hours
MBU Water EMU 1 Beacon 3 (esso) or 25 g 1600 hours
pump equivalent multi
purpose grease
MBU Water EMU 2 DIN 51825/KL3K 1 ½ years
pump, motor Lithium soap base (max.)
10000 hours
MBV10BB001 Lube oil tank 1 See section TGO2- 1 year Check oil,
0171 replace if
necessary. See
TGO4-1510 for
refilling
procedure
MBV21AP001-M01 Three-phase 2 MOBILUX EP3 30g 7000h Replacement of
MBV21AP002-M01 motor bearing (**)
MBV21AP003-M01 DC motor 2 20000h Replacement of

bearing (**)
MBV30AP001KP01 Lifting oil 2 Litium soap grease 24,000 EOH After 2 years
pump or equivalent or 2 years operation for 8
hours a day.
Remove, clean,
inspect the
pump bearings.
Replace if
necessary.
MBV30AP001-M01 Lifting oil 2 MOBILUX EP3 20g 12000h Replacement of
Pump Three- bearing (**)
phase motor
MBV35AP001-M01 Three-phase MOBILUX EP3 36g 11000h Replacement of
motor bearing (**)
Page 2 of 3
19.11.14
No. of
Relubrication with
(*)
point
MBX01BB001 Hydraulic oil 1 See section TGO2- 300 l Replace oil Check oil,
tank 0172 at least replace if
once a year necessary. See
or as TGO4-1006 for
indicated by refilling
the Supplier procedure
MBX02AP001-M01 Three-phase 2 ESSO: Unirex N3 20,000 h Replacement of
MBX02AP002-M01 motor (max 3 bearings
MBX06AH001-M01 years)
MBX21AN001KN01 Pneumatic 1 All Season SelectTM 500 For the first
MBX21AN002KN01 compressor is recommended compressor time after 50
operating operating
hour (every hours of the
year) compressor,
then every 500
operating
hours of the
compressor or
once a year
(the operating
hours are
displayed on
the local
control
cabinet). See
section TGO4-
5016 before re-
start
MBX21AN001-M01 Three-phase 10,000
MBX21AN002-M01 motor compressor
operating
hours (max.
3 years)
*) Avoid mixing lubricants! For more details, initial lubricant and alternative lubricants see
respective vendor documentation (See outside vendor parts)
**) The bearing is permanently lubricated. Due to ageing, at the end of the indicated period the
bearing replacement is recommended.
Page 3 of 3
19.11.14
ENDOSCOPIC INSPECTION DOORS
Fig. 1: Endoscopic inspection doors of gas turbine

2 Through holes for gap measuring (not used on machine on site, only for workshop)
3b Through nozzles of the extraction line (upper section)
4 Through balancing device (lower section)
6 Through manhole in the casing (upper and lower sections) and in the annular chamber (after tile
removing)
7 Through manhole in the casing (upper and lower sections) on cooling air hole to vane 3.
Page 1 of 2
ENDOSCOPIC INSPECTION DOORS TGO4-1000-E70001
17.11.14
Fig. 2: Endoscopic inspection doors of gas turbine (longitudinal section)
1 Through manhole in the intake channel
2 Not used
3 See 3b in Fig.1
4 Through balancing device (lower section)
5 Through endoscopic ports (4 point on circumference)
6 Through manhole in the casing (upper and lower sections) and in the annular chamber (after
tile removing)
7 Through manhole in the casing (upper and lower sections) on cooling air hole to vane 3
8 Through annular space of turbine vane carrier I by extraction and drain line (lower section)
9 Through annular space of turbine vane carrier II by extraction and drain line (lower section)
10 Through annular space of turbine vane carrier III by extraction and drain line (lower section)
11 Through closing plug in the lower section
12 Through door between the structure and the lining
13 Through manhole in the exhaust diffuser.
NOTE: inspection points commonly used are 1, 3, 4, 5, 6, 7, 13. The other points are available but
used only in case of very specific necessity, established by Ansaldo Energia.
Page 2 of 2
ENDOSCOPIC INSPECTION DOORS TGO4-1000-E70001
17.11.14
ROTOR DISASSEMBLING DEVICE
Warning:
This device is not part of the gas turbine scope of supply.
It is Ansaldo Energia propriety.
In general the gas turbine rotor does not need to be disassembled, even during major maintenance
jobs involving refurbishment / replacement of blades and vanes. For this reason the rotor unstacking
is not necessary during major inspection.
This section has the only purpose to give indication about space and load requirements due to a
possible unstacking operation.
The rotor unstacking is an exceptional operation whose necessity is established only by the gas
turbine Manufacturer in case that severe damage occurred on blades, vanes disks (e.g. due to foreign
object entrance).
The different devices here below described are not included in the gas turbine scope of supply.
Ansaldo Energia will make them available in case the rotor unstacking has been declared necessary
and only for the duration of the intervention.
The devices are the following:
§ Lifting device: used to lift the rotor
§ Blockage and tensioning device: used to block and tension the tie rod
§ Blade and disk moving device: used to move blades and disks during the unstacking.
The required crane capacity and characteristics for rotor lifting and unstacking are indicated in the
next figures.
Page 1 of 5
ROTOR DISASSEMBLING DEVICE TGO4-1001-E70001
16.12.15
1. ROTOR UNSTACKING : UPENDING THE ROTOR
Required crane capacity for

upending the rotor : 95000 kg
Required minimum crane hook height for upending : H (height) = 12800 mm
A ≈ 8230 mm
LV ≈ 752 mm
LT ≈ 1044 mm
Page 2 of 5
16.12.15
2A. ROTOR UNSTACKING : DISMANTLING THE ROTOR WITH STANDARD DEVICE
REQUIRED CRANE CAPACITY: 16000 kg
LOAD CAPACITY: 6500 kg
Compressor blade disk
MINIMUM HOOK HEIGHT = 21,8 m
Page 3 of 5
16.12.15
2B. ROTOR UNSTACKING : DISMANTLING THE ROTOR WITH SPECIAL ADAPTER
REQUIRED CRANE CAPACITY: 16000 kg
LOAD CAPACITY: 6500 kg
Compressor blade disk
MINIMUM HOOK HEIGHT = 14 m
Page 4 of 5
16.12.15
MINIMUM REQUIREMENTS FOR SPECIAL ADAPTER:
ØDI = 500 mm
M = M36
ØDT = 800 mm
Page 5 of 5
16.12.15
STANDARD TOOLS AND TOOLS FOR INITIAL ASSEMBLY AND INSPECTION
This list of tools contains the necessary tools and equipment for the field assembly of the gas
turbine generator set.
Refer to the Assembly Manual (TGA1- 201 AND -201bis sections).
They are divided into two families:
ü Base tools (C54)
ü Tools for initial assembly and inspection (C55)
Base tools (C54):
Code Description
014B2 Tensioner for coupling / decoupling intermediate shaft- generator
01407 Tools and wrenches container (including measuring device for blade clearance)
Tools for initial assembly and inspection (C55)
Code Description
01402 Hydraulic and dynamometric wrenches and relevant accessories
01411 Special wrenches for threated plug (on semi-casing for tapping points)
01412 Tool for checking the junction between turbine shaft and intermediate shaft
01413 Special wrenches for balancing weights
01421 Assembly fixture for compressor front bearing cover
01423 Support device for intermediate shaft
01425 Equipment for turbine bearing (for transport)
01426 Equipment for flushing lube oil piping
01427 Platform for exhaust gas diffuser maintenance
01442 Support for combustion chamber maintenance
01471 Hydraulic lifting device for rotor lifting (compressor side)
01481 Hydraulic tools for 01471
Page 1 of 1
STANDARD TOOLS AND TGO4-1002-E70000
TOOLS FOR INITIAL ASSEMBLY AND INSPECTION 17.11.14
NORD-LOCK PERMANENTLY TIGHT WASHERS
NORD-LOCK permanently tight lock washers offer enhanced protection against loosening and
unscrewing of bolted connections subjected to lateral loads or vibrations, or which themselves
vibrate.
The geometry of these washers is such that bolt tension actually increases briefly if the bolt or nut is
rotated in the loosening direction.
Description
The NORD-LOCK system comprises a pair of identical washers with radial ridges on their outer
surfaces and asymmetric “saw tooth” cams on their inner surfaces.
Fig. 1: NORD-LOCK lock washers (radial ridges exaggerated).
The angle of inclination of the cams is greater than the lead angle of the screw thread.
NORD-LOCK washers are always installed in pairs so that the cams face Inward.
Fig. 2: InstallatIon of NORD-LOCK lock washers
Page 1 of 3
NORD-LOCK PERMANENTLY TIGHT WASHERS TGO4-1004-E00002
19.11.14
NORD-LOCK washers can be used with both normal and high-strength screws. If the bolted
connection comprises a screw and a nut, two pairs of washers must be used.
When tightened, the lock washers are clamped against the screw head or the nut. The radial ridges
increase the surface pressure. One washer of the pair is positively interlocked with the screw head or
the nut; the second washer of the pair is positively interlocked with the work-piece.
Fig. 3: Tightened bolted connection with NORD-LOCK lock washers
If unfavorable conditions cause the bolted connection to turn, the screw head or the nut moves in
conjunction with the washer to which it is positively interlocked and thus turns slightly relative to
the other washer of the pair.
In addition to the rotary motion, an axial motion is produced as the opposing cams force the lock
washers apart axially thus increasing the axial force on the bolted connection (wedge effect).
Fig. 4: Wedge effect with NORD-LOCK permanently tight lock washers
In other words: the harder a screw connection “tries” to work loose, the better the NORD-LOCK
washers prevent the connection from loosening.
Page 2 of 3
19.11.14
Caution!
Risk of equipment damage: NORD-LOCK washers must be replaced with new ones after use,
otherwise the bolted connections can loosen.
Used NORD-LOCK washers must be accounted for and disposed of Immediately to prevent their
reuse.
Always use these washers in pairs. Because of the way they function, single NORD-LOCK washers
do not provide sufficient locking action.
Always use the right size washers for the bolted connection.
The bolted connection and NORD-LOCK washers must be centered on the part. Ensure that the
“teeth” mesh (cf. Fig. 3). Installing the washers with “teeth” already offset (as shown in Fig. 4)
decreases the force required to loosen the bolted connection, thus reducing the effectiveness of
these washers.
Bolted connections with NORD-LOCK washers require roughly 20% more tightening torque than is
necessary without NORD-LOCK washers. The greater tightening torque is required to overcome the
friction of the radial ridges and fully utilize the self-locking effect.
Normal torque is sufficient to loosen the bolted connections as the residual prestress is only approx.
10% greater.
Page 3 of 3
19.11.14
CLEANING AGENTS FOR COMPRESSOR CLEANING
Compressor Cleaning with cleaning agents is more effective than cleaning with demineralized water.
The cleaning agents listed in Table 1 have been tested and approved by the Gas Turbine
Manufacturer for use with gas turbines.
The table makes no claims to the effectiveness of the cleaning agents rather leaves this evaluation up
to the operator.
Caution!
Risk of equipment damage: The use of cleaning agents not approved by Ansaldo for compressor
washing can damage the gas turbine.
Attention:
When ordering cleaning agents, always request the corresponding material safety data sheet and
disposal instructions from the manufacturer.
Page 1 of 3
CLEANING AGENTS FOR COMPRESSOR CLEANING TGO4-1005-E00004
19.11.14
Table 1: Approved cleaning agents for compressor washing
Approved for:
Approved for:
Manufacturer Type Off-line cleaning
On-line cleaning
Airworthy Ltd. ZOK 27 X X
Elsted, Midhurst, West Sussex
Great Britain
Applied Chemicals Applied Penetone 19 X X
Applied House
Wilson Lane
Coventry (UK)
B&B Chemical Company Inc. B&B 3100 X
Miami, FL, USA
Brent GmbH Ardrox 6322 X
Postfach 30017 Ardrox 6345 X
D-41191 Monchengladbach Ardrox 6366 X
Ardrox 6367 X X
Castrol International Techniclean GT X X
Whitchurch Hill
Prangbourne
Great Britain
Chem Klenz Systems Protoklenz X X
Selkirk Scotland (UK) Turboklenz X X
Chemtron Chemie-Handel Chem Turbo Ol X X
GmbH Chem Turbo Ol W X X
Industriestrebe 69
D-28876 Oyten
Conntect Inc. Conntect 5000 X X
332 Federal Road Conntect 7000 X X
Brookfield (USA)
FP Turbomachinery Turbo K X X
Consultants GmbH
Wiesenstr. 57
D-79312 Emmendingen,
Germany
GE Betz S.r.L. CLEANBLADE GTC1000 X X
Strada Consortile 7
03013 Ferentino (FR)
Italy
Page 2 of 3
19.11.14
Approved for:
Approved for:
Manufacturer Type Off-line cleaning
On-line cleaning
Ivar Rivenaes A/S R-MC 21 X X
Damsgardsvelen 35 Power Guard X X
N-5037 Solhelmsviken, Bargen Power Back X X
Rochem Technical Service Fyrewash F1 X X
50A Fulham Road Fyrewash F2 X X
London SW3 6HH Fyrewash F3 X X
Turbotect Ltd. T-927 X X
CH-5401 Baden T-950 X X
Switzerland T 2020 X
T-ARF-301(anti freeze) X
Siemens AG, KWU 0111 SIWASH W X X
Huttenstrasse 12-16 SIWASH S X X
D-10553 Berlin
Page 3 of 3
19.11.14
OIL FILLING AND MAINTENANCE – HYDRAULIC OIL SYSTEM
The required volume of oil for all hydraulically-actuated valves is supplied from the hydraulic oil tank.
Maintenance includes monitoring of level and oil properties.
At least once a year, it is necessary to replace oil.
In addition, the hydraulic oil filters must be cleaned and their filter cartridges replaced; the
respective intervals are stipulated in TGO4-0049.
Note:
Please also refer to the extensive literature on oil maintenance prepared by oil suppliers, engineering
associations and standards committees.
Oil Level
Check the level of oil in the hydraulic oil tank at least once each week by reading off the level
indicator (MBX01CL501). When doing this, the hydraulic station should be in operation.
Add oil, if necessary (refer to the following)
If the tank level deviates from its permissible range, the level monitor issues a signal to the control
room.
Oil Level Fluctuations
The oil level shall not fall below the designated minimum oil level during normal plant operation
(refer to the following).
If the oil level in the hydraulic oil tank drops:
Immediately pinpoint and eliminate the cause(s) of such losses.
Possible causes include oil system leaks through which oil escapes to the outside; these are usually
recognizable by the accumulation of dripping oil.
Caution!
Fire hazard: Immediately clean up any external leakages to eliminate the fire hazard which they
constitute. Oil leaks can also be detected on the basis of increased oil consumption. If the oil level in
the hydraulic oil tank rises:
Immediately check for irregularities (e.g. ingress of water into the oil system) and eliminate cause(s).
Page 1 of 2
OIL FILLING AND MAINTENANCE – HYDRAULIC OIL SYSTEM TGO4-1006-E00002
19.11.14
Adding Oil
Only add oil when the GT and hydraulic oil system are shut down, always use the same brand and
grade of oil (if different types of oil are mixed, oil properties can change unpredictably). Oil
specifications listed in TGO2-0172 are to be observed in doing this. Add fresh oil through filler
connection MBX01AA251; never add oil to above the maximum tank level! This permits the ingress
of extraneous particles into the hydraulic oil system.
Caution!
Risk of equipment damage: Any and all leakage must be properly disposed of and shall never be
returned to the oil system.
Draining Water from the Hydraulic Oil Tank

Because of its higher specific gravity, water collects at the bottom of the hydraulic oil tank and it can
be drained off from this location (a type of oil is used which inhibits formation of water-oil
emulsions). If necessary, water can be drained off from the oil tank using drain valve MBX01AA401.
Oil Analyses
Oil samples must be taken at the following occasions and analyzed (Ansaldo recommends that the oil
release and frothing behavior also be investigated):
• when oil is first added to the tank, after completion of commissioning activities
• at the intervals prescribed by the oil supplier (or at least once every two years)
• when irregularities occur which are in some way related to oil properties.
One sample each must be taken when the tank is filled for the first time and on completion of
commissioning activities and then made available to Ansaldo. This is the only way to ensure that the
oil properties after extended operation can be reliably compared with those of the oil In the new
condition.
Page 2 of 2
OIL FILLING AND MAINTENANCE – HYDRAULIC OIL SYSTEM TGO4-1006-E00002
19.11.14
OIL FILLING AND MAINTENANCE – LUBE OIL SYSTEM
The lube oil tank stores the requisite amount of oil for supplying lube oil to all gas turbine plant
bearings as well as the jacking oil system and turning gear. This oil also performs cooling functions in
addition to lubrication of bearings.
Maintenance includes monitoring of level and oil properties. Oil specifications listed in TGO2-0171
are to be observed in doing this. Failure to perform maintenance with due care can have extremely
serious consequences.
This instruction includes information on the amount of oil, monitoring activities and oil properties.
Note:
Please also refer to the extensive literature on oil maintenance prepared by oil suppliers, engineering
associations and standards committees.
Amount of Oil Added

The amount of oil to be added listed in Test Record TGTR-0060 is not equal to the nominal volume of
the lube oil tank, because allowance must be made for filling the lube and jacking oil system.
Oil is drained when the oil is changed and for cleaning the oil system. The volume of oil filled into the
tank must be known so that appropriate tank capacity is available when draining the system.
Oil Level
Check the level of oil in the lube oil tank at least once each week by reading off the level indicator
(sight glass) and record.
Add oil, if necessary (refer to the following)
Not admissible deviations from the correct tank level are annunciated optically and acoustically by
the level monitor.
Oil level data in Test Record TGTR-0060 refer to the oil level indicator. These data indicate the
distance from the surface of the oil to the top of the lube oil tank.
Oil level in the lube oil tank varies with operating status due to changes in the amount of oil
circulating in the lube and jacking oil system.
Page 1 of 5
OIL FILLING AND MAINTENANCE – LUBE OIL SYSTEM TGO4-1510-E00002
19.11.14
Operating Oil Level = Normal Oil Level
During operation at rated speed the oil level in the tank should assume the normal oil level (TGTR-
0060 Oil Level with Oil Supply System Active). The oil level should not deviate more than ±25 mm
from the normal oil level.
Oil Level with the Oil Supply System Shut Down
After the oil pumps are shut down, some of the oil which was in circulation during pump operation
flows back to the lube oil tank, causing the tank level to rise about the operating oil level = normal oil
level.
Oil Level Fluctuations
The oil level shall not fall below the designated minimum oil level during normal plant operation. If
the oil level in the lube oil tank decreases more rapidly than usual:
Immediately pinpoint and eliminate the cause(s) of such losses.
Possible causes of oil loss may include:
• Oil system leaks through which oil escapes to the outside, usually recognizable by dripping oil.
• Oil losses through leaks in or at coolers, detectable by oil contamination in the cooling water.
Caution!
Fire hazard: immediately clean up any external leakages to eliminate the fire hazard which they
constitute increased oil consumption may indicate the existence of oil leaks.
Any oil added must therefore be meticulously recorded and plotted as specific oil consumption
(volume of oil / operating time). If the oil level in the lube oil tank rises or the specific volume of oil
added decreases:
Immediately check for Irregularities (e.g. ingress of water into the oil system) and eliminate cause(s).
Page 2 of 5
19.11.14
Adding Oil
Only add oil when the GT and lube oil system are shut down, always use the same brand and grade of
oil (if different types of oil are mixed, oil properties can change unpredictably).
Prior to adding oil, take a 1-liter sample (in the case of turbine-generators equipped with a gearbox,
3-liter sample) of the fresh oil and have this sample analyzed. If oil to be added is from two batches,
mix the sample 1:1.
Add oil via a filter system with a maximum pore size of 40 pm connected to the filler connection on
the oil strainer cover, in doing so, ensure that no extraneous matter is entrained into the system
because the basket strainer located below the filler nozzle only retains coarse particles. The filling
operation must be completed within a maximum of 24 h.
Caution!
Risk of equipment damage: Regardless of its source, it is only permissible to return leakage oil to the
oil system after treatment and subsequent investigation.
Draining Water from the Lube Oil Tank

Because of its higher specific gravity, water collects at the bottom of the lube oil tank and it can be
drained off from this location. The ingress of water can be recognized by turbidity (emulsification),
and unchanged or increasing tank oil level.
Under such circumstances an oil sample is taken the during a turbine outage and all oil pumps have
been shut down. This sample is then investigated for water content.
If water is present, pinpoint location of ingress and rectify.
Remove water from the lube oil system using one of the following methods:
Drain water off via drain MBV10AA401.
Extract water from oil using an external separator (not included in the standard scope of supply).
When this has been completed, take a new oil sample and have it analyzed for water content.
Page 3 of 5
19.11.14
Cleaning the Oil System
The oil system, and in particular the lube oil tank, must be thoroughly cleaned during major
Inspections. It must be ensured that only those cleaning agents are used, the residues of which have
no negative impact on oil properties. Above all substances containing chlorine and sulfur must be
avoided. Cleaning aids such as rags or materials which release substantial amounts of lint are not
permissible for cleaning because such lint cause impermissible fouling of the lube and jacking oil
system.
Intervals for cleaning filters are shown in TGO4-0049. Observe manufacturer’s instructions when
cleaning filters/replacing filter cartridges (see Outside Vendor Parts).
Oil Supplier, Oil Type and Oil Properties

The oil supplier, oil type and viscosity of the current oil tank filling are stated in the Test Record
(TGTR-0060). It goes without saying that any oil which meets or exceeds the requirements specified
in TGO2-0171 can be used when an oil change is made. When such changes are to be made it is,
however, necessary to consult the Ansaldo engineering department regarding compatibility of any
unavoidable residues in the system and the new type/brand of oil.
Caution!
Risk of equipment damage: Turbine oil must have the properties specified in Section TGO2-0171. The
turbine oil supplier must guarantee that the oil in question has the properties specified therein.
Only order oil in cleaned containers which clearly bear full product and batch designations. It must
also be agreed that the oil supplier make the test results pertaining to those properties specified in
Section TGO2-0171 available in due time prior to delivery of oil.
Test results must be compared with the requirements specified In Section TGO2-0171. If these oil
quality requirements are not met, another supplier, grade or batch must be used.
Archive test results.
Page 4 of 5
19.11.14
Oil Analyses
Oil samples must be taken on the following occasions and analyzed in terms of the requirements
specified in Section TGO2-0171:
• when oil is first added to the tank, after completion of commissioning activities
• at the intervals prescribed by the oil supplier (or at least once every two years)
• when irregularities occur which are in some way related to oil properties
• when oil is added to top up the tank
One sample each must be taken when the tank is filled for the first time and on completion of
commissioning activities and then made available to Ansaldo. This is the only way to ensure that the
oil properties after extended operation can be reliably compared with those of the oil in the new
condition.
Page 5 of 5
19.11.14
MEASURES FOLLOWING COMPRESSOR SURGE
The GT control system ensures that the GT is always operated inside its permissible limits in every
phase of operation. This applies also with respect to the compressor surge, i.e. the control system
acts to maintain a certain safety margin between the operative pressure and the surge pressure.
However, there are certain unpredictable fault situations which could lead to compressor surge.
Surge happens when the compressor leaves its stability range, in this case fast mass flow fluctuation
occurs leading to strong pressure and vibration oscillations, causing severe mechanical loading on
the compressor vanes and blades and on other GT components.
Each occurrence of surging must therefore be followed by inspection measures to verify the integrity
and functionality of the GT before continuing operation.
The following checks and measures must be performed:

1. The cause of surging must be determined, preferably with the support of AEN specialists.
Repairs of the components impaired by surge may be required.
2. Inspect the air intake system and structure.
3. Visual inspection by means of endoscope of the compressor blades and vanes via inspection
point 1 (see section TGO4-1000) and turbine discharge via inspection point 13. Particular
attention shall be directed to:
- check damage to blades and vanes caused by foreign objects
- lack and discoloration of the coatings at the blade tips on coated compressor stage.
- confirm that the accessible rows of blades are intact.
4. Visual inspection and function test of the IGV and CV1. In particular check the bearings (they
must be free of rotating), the adjustment and cinematic device are intact and fully functional.
5. Visual inspection of the combustion chamber via inspection points 6 / 7 (see section TGO4-
1000) to ensure that tiles are not damaged and there is no signs of incoming damage. If the
combustion chamber lining has been damaged, the visible turbine stages must be visually
inspected for damage or impact marks.
6. Check the burners and burner inserts.
7. Visual inspection of control actuators, valve and on board piping. Ensure that blow-off valves
are properly positioned (OPEN, as per position required at GT standstill).
Page 1 of 2
MEASURES FOLLOWING COMPRESSOR SURGE TGO4-1600-E72001
19.11.14
Warning!
Risk of equipment damage.
The GT can be re-stared only when no damage is present or all damages are checked and
rectified. Do not perform fuel change over (where applicable) before test on each fuel has
been carried out.
8. During load operation following next start up, the following check shall be carried out:
a) Check the proper positioning of fuel valves, fuel supply, blow off valves
b) All accessible fuel lines shall be checked for any leakage
c) Check the following GT parameters and check if their values are normal
- lube oil pressure
- turbine exhaust temperature
- compressor discharge pressure
- combustion chamber differential pressure
- power output
9. In case of dual fuel gas turbine, check the fuel change over in both direction (gas to oil and oil
to gas).
An inspection report showing the results of all inspections and test performed must be sent to
Ansaldo Energia, Service Department, immediately.
Warning:
In case of damage on one or several components, before re-starting the gas turbine, corrective
measures shall be taken according to Ansaldo Energia procedures
Page 2 of 2
MEASURES FOLLOWING COMPRESSOR SURGE TGO4-1600-E72001
19.11.14
MEASURES FOLLOWING HUMMING / ACCELERATION PHENOMENA
The “humming phenomenon” occurs when there are pressure fluctuations in the combustion
chamber; this can happen under certain operating conditions, for instance due to a fluctuation in the
fuel gas supply pressure. The pressure fluctuation can produce flame instability and forced
accelerations which have impact on the combustion chamber. In case the accelerations exceed
determined limit values for a certain time it is necessary to inspect the combustion chamber in order
to quickly detect a small damage in its initial phase (and thus avoiding higher damages). For these
reasons, all the protective actions are carried out on the basis of the acceleration limit values and not
to the humming limit values.
GT trip; acceleration ≥ 8 g (heavy event) involves a combustion chamber inspection

When a GT trip occurs for overcoming the S.ACC.03 threshold (e.g. 8 g) an inspection of the
combustor tiles must be performed before re-staring the gas turbine. See next paragraph.
Inspection of combustor tiles
Danger!
Danger of burns: the GT must be sufficiently cooled down before beginning the burner
ring combustion tiles inspection. During the inspection the turning gear operation is
forbidden.
Warning!
Risk of equipment damage: only persons who have been trained to inspect burner ring
combustor tiles shall be assigned to this work. Otherwise damage to the burner ring
combustor tiles could go undetected and result in severe turbine damage.
§ The lining of the hot gas path should be covered with rubber mats before
climbing into the combustion chamber. The combustion chamber lining could
otherwise be damaged.
§ Wear always protective shoes before entering the combustion chamber.
§ Only use approved markers (e.g. “Edding 800”) to mark the heat shields.
Machining is not permissible for this purpose as it could impair the thermal
protection function.
§ Inspection and evaluation of the ceramic tiles must be done by trained personnel using
proper templates with acceptance criteria and test records.
Page 1 of 1
MEASURES FOLLOWING HUMMING / ACCELERATION PHENOMENA TGO4-1700-E70001
19.11.14
CLEANING OF FILTERING EQUIPMENT
To keep the lube and jacking oil systems free of solid impurities, oil is fed through filtering equipment
integrated into each system. These filters are located in the main oil line of each system, thus
ensuring that the entire volume of oil passes through the filtering equipment. The nominal filter
mesh size of the filtering equipment is 25 pm. This ensures that the lube oil is free of foreign particles
when regular cleaning intervals are maintained. Depending on the system, the degree of fouling of
the filter is indicated by either a differential pressure gauge or a visual indicator.
Cleaning Intervals and Criteria

The frequency for cleaning of the filters depends on the degree of fouling of the system involved and
is influenced to a great extent by various external factors. Here, it is essential that slight negative
pressure is maintained (max. 1 to 2 mbar) in the lube oil system. If this level is exceeded, there is an
increased threat of ingress of particulates from the ambient air around turbine-generator into the oil
circuit through the shaft seals.
The differential pressure across the filter equipment, i.e. variations in the pressure difference
between filter inlet and filter outlet, forms the criterion for indicating the necessity of cleaning of the
filters.
Differential pressure in the lube oil duplex filter is indicated optically by a contact gauge and, when
the specified limit is reached (p > 0.6 bar), electrically by an alarm being issued. The degree of fouling
is indicated by the red zone on the indicator dial.
The degree of fouling of the filter located in the jacking oil system is also indicated by a differential
pressure gauge which optically indicates degree of saturation.
Lube oil supply duplex filter

Cleaning of a fouled duplex filter can be performed during gas turbine operation. Changeover from
one filter to the other during turbine operation requires that the filter which is to ‘be put into use be
ready for operation, I.e. the filter has been vented and filled with oil.
Jacking oil system filter

When annunciated by the fouling level indicator, the filter insert shall be replaced and the filter
housing cleaned.
This filter can be manually switched over to the reserve filter. However it is recommended to clean /
change the filter when the lifting oil pump is NOT operating (warning: high pressure oil), i.e. when
the shaft is not in turning gear mode.
Page 1 of 3
CLEANING OF FILTERING EQUIPMENT TGO4-4550-E70001
20.11.14
Basket strainers in the oil tank
Two parallel oil strainers are located in the oil return chamber of the oil tank. The return oil flow, and
all oil added to the system, flows through these strainers.
Any solids in the oil system are removed by this filtering equipment (basket strainers; mesh size =28
µm).
The oil strainer cover can be opened to gain access to the strainers after removing the bolts in the
cover on the oil tank platform. To clean, lift the basket strainers out through the opening and, after
cleaning, use compressed air to remove any remaining foreign material before reinstalling.
RDS system filters

When annunciated by the fouling level indicator, the filter insert shall be replaced and the filter
housing cleaned.
This filters in the RDS system can be cleaned only when the system is not in operation and the GT is
at standstill. In fact it is recommended to clean / change the filters when the lube oil system is NOT in
operation, i.e. when the shaft is not in turning gear mode.
Fuel oil supply duplex filter

Cleaning of a fouled duplex filter can be performed also during gas turbine operation with fuel oil.
Changeover from one filter to the other during turbine operation requires that the filter which is to
‘be put into use be ready for operation, i.e. the filter has been vented and filled with oil.
Fuel oil diffusion line filter

The filter must be cleaned on next occasion when the pressure transducers respond. Cleaning of a
fouled filter can be performed only when the fuel oil system is not operating and the GT is at
standstill or in turning gear mode.
Risk of injury!
Warning: during fuel gas operation, hot air from compressor (seal air) can back flow to
the dismounted filter.
Clean filter only at GT standstill or in turning gear mode
Page 2 of 3
20.11.14
Fuel oil premix line filter
The filter must be cleaned on next occasion when the pressure transducers respond. Cleaning of a
fouled filter can be performed only when the fuel oil system is not operating and the GT is at
standstill or in turning gear mode.
Risk of injury!
Warning: during fuel gas operation, hot air from compressor (seal air) can back flow to
the dismounted filter.
Clean filter only at GT standstill or in turning gear mode
Examination of Solids Removed

Solids collected in the filtering equipment frequently provide valuable information on prevailing
conditions of bearings, pumps and in control equipment systems. Major consequential damage can
be prevented by implementing prophylactic measures derived from meticulous evaluation of this
information. Residues shall therefore be examined carefully for presence of metal, corrosion, scaling
and slag.
Page 3 of 3
20.11.14
DETERMINATION OF TIME FOR COMPRESSOR CLEANING
Despite the filter system installed in the intake structure, the ambient air reaches the compressor
with particles having a diverse spectrum. This includes, for example, dust particles, soot, pollen or
salts (at coastal locations) as well as a wide range of chemical compounds which vary from one gas
turbine plant location to another. These particles are deposited on the compressor blading, primarily
in the front stages. These deposits cause a decrease in mass flow MCI and in compressor efficiency
which is function of the fouling degree.
On-line and Off-line Washing

A distinction is drawn between on-line and off-line compressor washing. On-line washing is
performed during GT power operation, off-line washing utilizes outages, i.e. periods when the GT is
not being used for power generation.
On-line washing is primarily intended to prevent the buildup of deposits. Off-line washing is capable
of removing heavier deposits. Compressor washing procedure must be performed as described in
Section TGO4-4962.
Site Conditions
The term normal site conditions is used to denote power plant locations which do not have
particulate burdens above and beyond those described above in the subsection Fundamentals and
which are not characterized by extreme ambient factors, such as site locations on the seacoast (high
salt content), in the desert (sandstorms) or with high humidity. Site conditions are also considered
off-normal if intake air contains other contaminants (e.g. industrial plant flue gas and/or exhaust).
Scheduling of Washing
It is not possible to clearly defined when the compressor cleaning is necessary, however it is highly
recommended to perform off-line compressor cleaning as soon as it’s possible, that is to say before
any restart after GT shutdown of medium duration (e.g. week end stop).
As a matter of principle, since compressor dirtiness causes loss in GT efficiency, where frequent off
line compressor washings are not possible, perform several on-line cleaning according to the
following, in order to prevent dirty particles from adhering to the blades:
ü on-line washing with demi-water for two consecutive days
ü on the third day wash with cleaning solution, then rinse with demi-water
In case fouling cannot be removed this way, perform daily compressor washing with cleaning
solution.
Page 1 of 2
DETERMINATION OF TIME FOR COMPRESSOR CLEANING TGO4-4961-E00000
19.11.14
Warning
It is recommended to perform off line washing once a week.
In case it is not possible due to the load profile of the gas turbine, the off line should be performed at
least once a month. In this case, frequent on line washing shall be carried out ( 1 / 2 per week)
according to the environmental conditions.
It is therefore expedient to define procedures based on experience gathered at the plant in question.
in the event of changing environmental or operating conditions, cleaning practice must be
reconsidered. It Is possible, for example during the power plant construction phase or periods of high
wind, that dust and salt burdens are higher, pollen is by nature only a seasonal problem.
Notes
As experience has shown that blade deposits cannot be completely removed by washing, the blade
surfaces tend to be gradually roughened by erosion and the radial clearances change with increasing
operating hours (aging), compressor washing can no longer restore performance to the original
output level. If residual fouling is still severe, it cause could involve a change in the type of deposits
or their consistency (e.g. oily). In such cases it is recommended to have an expert inspect the
compressor blading and change the type of cleaning fluid used, if necessary. Regular checks must be
performed to ensure that the pressure drop across the intake filter remains within permissible limits.
Contact the GT service if required.
See also section:

Compressor Cleaning Procedure TGO4-4962
Page 2 of 2
DETERMINATION OF TIME FOR COMPRESSOR CLEANING TGO4-4961-E00000
19.11.14
MANUAL COMPRESSOR CLEANING PROCEDURE
The compressor washing system removes deposits from blades which adversely affect output and
efficiency.
Refer to Section TGO4-4961 to determine when to perform compressor washing.
Two different type of compressor washing are foreseen:
ü OFF line, after the GT shut down, by means of SFC and reaching a certain washing speed,
ü ON line, at GT nominal speed and during load operation.
On-line washing is primarily intended to prevent the accumulation of deposits. Off-line washing is
also capable of removing heavier deposits.
No cleaning procedures different from what here indicated are allowed. Any modification on the
here stated washing procedure must first be approved by Ansaldo Energia.
Detergents / cleaning agents

The cleaning agents / detergents approved by the GT’s Manufacturer are shown in section TGO4-
1005. The table makes no claims to the effectiveness of the cleaning agents rather leaves this
evaluation up to the operator.
Caution!
Risk of equipment damage: the use of not approved detergents for the compressor washing can
damage the gas turbine.
When ordering the detergent, always require the safety technical data sheet and the safety
instruction for use and disposal of the detergent.
Caution!
Risk of equipment damage: when using detergents, always refer to the instruction of the Supplier
(quantity, dilution degree, safety instruction, etc.). Take care that the solution is homogeneous.
Page 1 of 6
COMPRESSOR CLEANING PROCEDURE TGO4-4962-E00000
29.09.15
OFF LINE WASHING
The procedure occurs in 4 steps:
• Preparation
• Soaking
• Rinsing
• Drying
Caution!
Risk of equipment damage: The GT may only be washed if it can be ensured that the temperature of
the compressor intake air will remain above 4° C throughout the entire washing process, Including
drying (icing hazard).
As a general rule, the use of antifreeze is prohibited since the adhesive effect of these agents can
result in increased fouling. However in case of very cold climate, the use of a specific anti-freeze
agent is permitted, consult Ansaldo Energia for further information (See TGO4-1005).
For GT with IGV hydraulically actuated (e.g. AE94.3A), the hydraulic oil system has to put it in service.
Preparations
• The GT must be cold enough (at least 6 h in turning gear)
• The SFC must not be in alarm conditions
• Connect MANUALLY the water pump and flexible hose to the compressor cleaning plant
termination
• Fill MANUALLY the tank (MBA18BB002) with cleaning fluid (demineralized water and
detergent). Refer to the instructions from the cleaning agent manufacturer for dilution ratios.
• Open MANUALLY the drain valves
• Connect MANUALLY the drain pipe stubs to the plant dirty water system and open the isolating
device
• Check the fuel supply and ignition systems are deactivated and isolated
• Check the blow off valves are open (as consequence of GT shut-down)
• Open the stack isolating flap (if any)
• Open the generator intake damper
• Open the generator cooling air flap
Page 2 of 6
29.09.15
Soaking
• Operate gas turbine on turning gear.
• Switch the IGV to manual mode and bring them to OPEN position (at least 95%)
• Open MANUALLY valve MBA18AA251 upstream the jet nozzles (MBA18BN001).
• Connect water pump MBA18AP001 to electric power supply.
• Start water pump. The jet nozzles inject the cleaning solution on the first two rows of the
rotating blades.
• When approx. 25% of the cleaning solution has been used, switch off. the pump and close
MBA18AA251 upstream the jet nozzles.
• prepare SFC for washing operation
• deactivate turning gear equipment
• Start the SFC in compressor cleaning mode on the control desk.
• at about 5Hz open isolating valve MBA18AA252 upstream of full cone spray nozzles
MBA18BN002
• activate the pump:
• the cleaning fluid is injected in the air flow by means of the full cone spray nozzle and in this
way is directed through the suction surface into the compressor
• The IGV can be moved between the permissible positions from the controlling place to obtain,
if necessary, a better cleaning grade.
• The gas turbine is brought to the washing speed by means of the static frequency converter,
when the 26.7 % of rated speed is reached the SFC is switched off, the cleaning solution
continues to be injected also when speed decreases
• When the tank is empty, switch off the water pump and close MBA18AA252 upstream of spray
nozzles.
Page 3 of 6
29.09.15
900
See Note 1
800
700
600
Speed [rpm]
TURNING
500 GEAR
inject
400
25% of
solution by
300
jet-nozzles
spray nozzles open
200
100 SFC ON
TURNING
0 GEAR
-2 0 2 4 6 8 10
Time [min]
NOTE 1: it is possible, depending on the water tank capacity, that not all the cleaning solution has
been consumed at reaching the 26.7% speed. In this case, the SFC can be set in order to prolong for
short time the washing procedure. Speed is not maintained at constant value but oscillation is
implemented in order to avoid the blades eigenfrequency.
In case of washing with detergent, remember to rinse with demi water only. At least two time
rinsing is suggested.
Rinsing
• For rinsing, demineralised water is used.
• REPEATE THE ABOVE PROCEDURE but now the tank must be filled with demi water only.
• Once water stops flowing from the nozzle on the drain header close all drain valves
(otherwise hot vapors could escape during operation and cause scalding injuries and/or
damage the compressor and turbine).
Page 4 of 6
29.09.15
Caution!
Risk of scalding: Close all drain valves after completion of draining. Otherwise hot vapors could
escape during operation and cause scalding injuries and/or damage the compressor and turbine.
Caution!
Corrosion risk: never shut down the GT immediately after compressor washing, as residual
moisture can cause corrosion of GT parts.
Drying
• Release the fuel supply and the ignition system again
• Switch the IGV control to AUTO mode
• SFC: select network start
• the GT must be started by the "Operation Program"
• Reach full speed no load (up to nominal speed)
• If possible, synchronize and reach 30% of GT load (otherwise maintain idle conditions for
several minutes in order to dry the equipment)
• Proceed with normal gas turbine operation as required, i.e. increase load, or shut down the
unit and proceed with turning gear operation.
Page 5 of 6
29.09.15
ON LINE CLEANING
If the gas turbine cannot be shut down for cleaning the compressor, the compressor cleaning can be
performed at rated speed and on-load.
Compressor cleaning is suggested between 80 and 95% of base load, with IGV fully open. It is
strongly recommended to avoid higher GT loads.
Note: Compressor cleaning at operating speed is less effective than the cleaning procedure at
washing speed. It could be necessary to repeat the procedure several times.
Caution!
Risk of equipment damage: Only the spray nozzles may be used. Use of the jet nozzles is
prohibited. The drain valves must remain closed.
The GT may only be washed if It can be ensured that the temperature of the compressor Intake air
will remain above 4 °C throughout the entire washing process, including drying (icing hazard).
In case of temperature > -2°C it is possible to activate the anti-icing system and wash the compressor.
It must be ensured that the anti-icing is kept ON during all the washing procedure.
Execution
• Connect pipe or hose of water pump MBA18AP001 to the compressor device termination
• Fill tank of water pump set with demineralised water or a mixture of water and detergent
• Open manual valve MBA18AA252 upstream spray nozzles.
• Start water pump MBA18AP001.
• When the tank is empty, switch off the water pump and close manual valve MBA18AA252
upstream spray nozzles.
Note
Washing with detergent is more effective than washing with demi water only.
In case of washing with detergent, remember to rinse with demi water only. At least two time
rinsing is suggested.
See also section

Compressor cleaning System TGO2-4961
Drainage System TGO2-4966
Cleaning Agents for Compressor Washing TGO4-1005
Determining the intervals for Compressor cleaning TGO4-4961
Page 6 of 6
29.09.15
FLAME MONITORING SYSTEM
The combustion chamber is equipped with two flame detectors to monitor the flame zone, whose
function is described in section TGO2-2603.
Since the flame detectors are each other independent, several tests can be performed on one only
and then on the other one separately. Therefore individual functions can be tested during operation
of the GT.
Cleaning the quartz glass on the flame detector support and cleaning the lenses of the flame
detectors is performed with GT at standstill (disassembling the light receiver from its support). For
proper cleaning of the lenses refer to specific instruction of the Supplier (see Outside Vendor Parts)
Test Purpose
This test checks the functionality of the flame detectors and the analog board in the control cabinet.
The tests must be performed during operation of the GT, preferably at zero load or low
load. Avoid high load during the test since the GT trip is activated if both flame
monitors are tested simultaneously.
As general rule, avoid test which leads to GT trip during operation.
The test consists in checking the following alarms in the control desk:
- “Flame monitor faulted”
- GT trip caused by ‘Flame OUT” signal
- Check flame intensity 0 – 100% on video display.
Page 1 of 3
FLAME MONITORING SYSTEM TGO4-5009-E72001
15.12.14
Procedure
The flame monitoring system is tested by blocking the flame light path to the flame detector.
This can be done by holding a sheet of metal or non igniting material between the sight glass end
plate on the combustion chamber sight pipe and the receiver of the flame detector /red line point A
in the below figure). This blocks the flame light path and no flame signal is received by the
monitoring system.
The details of this figure are given in section TGO2-4380.
Perform the following steps:

• Cover one flame detector as above indicated and check the alarm “Flame monitor faulted’. The
GT shall remain in operation due to the flame ON signal maintained by the other flame detector.
• Uncover the flame detector.
• Cover the other flame detector as above. Check the alarm “Flame monitor faulted’. The GT shall
remain in operation due to the flame ON signal maintained by the other flame detector.
• Uncover the flame detector.
Page 2 of 3
15.12.14
Test causing a GT trip
Warning:
this test causes the GT trip. In principle, test leading to GT trip shall be avoided if not strictly
necessary.
• Uncover both flame detectors of the combustion chamber. Check the signal “Flame OUT’. The
GT is automatically tripped!
• Uncover both flame detectors.
Page 3 of 3
15.12.14
PNEUMATIC SYSTEM MAINTENANCE
The following measures and check must be performed after the inspection / maintenance activities
before re-starting the gas turbine.
In addition to the check listed below, the pneumatic system must be checked also according to the
Supplier’s instructions (see Vendor Parts).
Pumps and motors

Ensure that:
• Shut off valves for the supply lines (MBX21/22AA251) are “open”
• Instrument valves (from MBX24AA301 to …304) are “open”
• The power switch of the two compressors are “ON”. The main switches are outside the control
panel.
Pressure switches
• Check the set point (on the Instrument List) of every pressure switch.
• Check the intervention of one compressor based on its pressure switch (MBX21AN001 starts /
stops on lower / upper level of MBX21CP001)
• Check the intervention of the other compressor based on its pressure switch (MBX22AN001 starts
/ stops on lower / upper level of MBX22CP001)
At regular intervals (see the Manufacturer’s instruction on the Vendor Parts) replace the safety
valves of the compressor MBX21 / 22AA191 and MBX24AA191 in tank.
It is suggested at regular intervals (for instance once a year), to change the set point value of
pressure switches MBX21 / 22CP001 in order to interchange the functionality of the two compressor,
i.e.:
In case MBX21CP001 is set at lower level at 6.7 bar and MBX22CP001 lower level at 6.8 bar,
interchange the two levels: i.e. set MBX21CP001 at 6.8 bar and MBX22CP001 at 6.7 bar in order to
change the priority to start of the compressors.
Page 1 of 2
PNEUMATIC SYSTEM MAINTENANCE TGO4-5016-E72001
19.11.14
Test of the pressure switches MBX24CP001 / 002 / 003 / 004
• Open instrument valves MBX24AA301 / 302 / 303/ 304
• Switch on one compressor in order to increase the pressure in the pressure tank. When the
pressure is reached the compressor is automatically switched off.
• Close the instrument valves to the pressure switches to be tested.
• Open the drain valve MBX24AA401 in order to discharge the pressure tank down to the lower
pressure set point.
• Then close the drain valve MBX24AA401.
• Open the instrument valves to the pressure switches to be tested.
• Test all the pressure switches with the same procedure.
Page 2 of 2
PNEUMATIC SYSTEM MAINTENANCE TGO4-5016-E72001
19.11.14
FUEL OIL SKID DRAINAGE PROCEDURE
Introduction
During fuel oil system maintenance, all the fuel oil skid piping must be drained out in order to keep
the piping fuel oil free during the activity. All the instructions stated below must be executed
carefully with GT in standstill.
Fuel oil system drainage procedure
In order to carry out the fuel oil skid drainage correctly, refer to the following instructions:
1) Make sure the FO forwarding pumps, injection pump and purging water pump are in safety
position (breaker opened) before going on with the fuel oil skid drainage. Keep the leakage
pump available and ready (breaker closed) in order to drain the fuel oil out automatically in
case the drainage tank reaches the high level .
2) Close the isolation valves MBN12AA402/403 located upstream and downstream the
injection pump and therefore open the drain valve MBN12AA401.
3) Connect the flexible pipes between the valves MBN23AA401 (FO premix), MBN14AA401 (FO
diffusion supply), MBN52AA401 (FO diffusion return) and the drainage tank. Therefore open
the valves and drain the fuel oil out.
4) Open the drain valves MBN13AA401, MBN54AA401 and MBN55AA401 to drain the piping
upstream the fuel oil control valves.
5) Open the drain valves MBN11AA401/402 in order to drain the duplex filter
MBN11AT001/002.
Fuel oil system restoring procedure after drainage
Once the fuel oil skid has been drained, before restarting the fuel oil system refer to the following
restoring instructions:
1) Close all the drain valves MBN23AA401 (FO premix), MBN14AA401 (FO diffusion supply) and
MBN52AA401 (FO diffusion return), and remove manually the flexible pipes between the
valves and the drainage tank.
Pagina 1 di 2
FO SKID DRAINAGE PROCEDURE TGO4-6000-E72000
24.03.14
2) Restore all drain valves MBN11AA401/402 ,MBN13AA401, MBN54AA401 and MBN55AA401

in closed position.
3) Restore isolation valves MBN12AA402/403 in open position and the drain valve
MBN12AA401 in closed position.
4) Re-check once again step 1) ,2) and 3) have been correctly carried out before going to step
5).
5) Remove the safety block on the forwarding pumps, injection pump and purging water pump
(breaker closed).
Refer to P&IDs “FUEL OIL SYSTEM” .
Pagina 2 di 2
FO SKID DRAINAGE PROCEDURE TGO4-6000-E72000
24.03.14
INSPECTION
MAINTENANCE
WARNING:
THIS WHOLE SECTION IS INTENDED AS REFERENCE ONLY
Proper actions, such as replacement and/or refurbishment of components,

repair jobs, time schedule must be agreed according to the proper
maintenance contract and may change from what above indicated.
Reference to the Service Contract or Service Agreement shall be made.
Service Contract or Service Agreement has priority over this section.
It is assumed that the operator has followed all the prescription reported in this Operating
and Maintenance Manual and that the activity of “day by day”/ ordinary maintenance has
been carried out as soon as it was necessary.
It is also assumed that the gas turbine has been operated with fuels and medium working
fluids compliant with the specification of section TGO2-0160, TGO2-0171, TGO2-0172.
In the following reference to the Equivalent Operating Hours as per section TGO3-0126 will
be made.
Page 1 of 15
MAINTENANCE TGO5-0022-E70001
21.07.16
§ GENERAL
Gas turbine is subjected to wear during use as it occurs for any other machine.
In addition the working fluids through the gas turbine (e.g. fuel, water, air with the associated
contaminants, dust and pollution) can cause corrosion / erosion.
Furthermore the high temperatures inside the gas turbine cause thermal stresses, material
fatigue and oxidation on components exposed to hot gas.
The purpose of maintenance is to recognise wear and keep it under control by repairing or
replacing the wear parts as needed. With proper maintenance, the gas turbine is able to be
operated with high availability and high service life.
This section deals with the scheduled maintenance measures to be carried out while the gas
turbine is in standstill for a prolonged period in order to carry out the inspection, i.e. Minor
Inspection, Hot Gas Path and Major Inspection.
Ansaldo Energia has developed customized maintenance plans, in order to optimise efficiency and
availability along the whole life of the gas turbine. The maintenance plans are based on Ansaldo
Energia expertise in the fields of design, operation and maintenance of gas turbines and also take
into account all critical points evidenced during operational life of the machines.
Since the evaluation and interpretation of the findings is very important in order to obtain the
proper corrective measures during maintenance, skilled knowledge and experience is required for
maintenance activities, therefore fact finders and inspectors of Ansaldo Energia are highly
recommended.
Page 2 of 15
21.07.16
§ EQUIVALENT OPERATING HOURS (EOH)
The wear sustained by the gas turbine during operation depends on a series of factors which are
summarized by the concept of the Equivalent Operating Hours.
Refer to section TGO3-0126 for the EOH calculation.
This formula tries to summarize the wear effects which can be divided in two categories:
1. Wear effects due to time
2. Cyclic wear
1. Wear effect due to time basically includes:

• internal creep damage to the material as a result of mechanical loadings at high metal
temperatures during base load
• creep deformation of hot gas path items
• erosion due to fine dust particles entering with the working fluids
• oxidation at high metal temperatures
• additional mechanical loadings at high metal temperature and the destabilization of oxide
coatings as a result of water injection (when applicable)
• vibrations, which result in friction wear.
2. Cyclic wear effect results from rapid transient phase such as start up, shut down, trip, load
rejection and in generally everything can cause a fast temperature change in the exposed
component, therefore we refer to:
• low cycle fatigue (LCF)
• friction wear caused by sliding.
The formula of section TGO3-0126 tries to give a weighted factor for the wear caused both by point
1. and 2. For this reason also the transient phases such as start up, shut down, trip, etc. are taken
into account as they were time dependent effect.
This kind of approach is suitable for base load plant or plant where the time dependent operation
prevails over cyclic operation. For peak load plants characterized by frequent starts and stops where
the cyclic wear prevails, this shall be considered as a separate effect. For this reason, the inspection
plan is based on the combined effect of EOH and starts.
Page 3 of 15
21.07.16
§ INSPECTION INTERVALS
Normally, the maintenance plan of the AE94.3A should be optimised on the whole operating life of
the plant and taking into account the operating conditions and load profile required for the gas
turbine.
Three different types of scheduled outages are defined as reported in Table 1:
Ø Minor Inspection (m)
Ø Hot Gas Path Inspection (HGPI)
Ø Major Inspection (M)
Schedule of outages and related scope of work can be modified on the basis of inspections,
operational experience and technical developments if any.
Off-line compressor cleaning is strongly recommended as preparation for all inspections.
The maintenance plan is based on the main fuel. Special conditions (if any) are stated in the Service
Contract or Service Agreement (if applicable).
Values indicated in the below table 1 are guide values, which may be extended by up to 10% as a
function of local conditions and the findings of previous inspections. Some components can be
replaced on the basis of inspections carried out by Ansaldo Energia fact finders. The inspection
interval may be shortened by Ansaldo Energia fact finders due to some critical findings.
Table 1: Inspection intervals
Type of inspection Interval

(1)
Minor Inspection (m) 8.000 EOH
Hot gas path inspection (HGPI) (2) 33.000 EOH or 900 start (3) up (what comes first)
Major inspection (M) (2) 66.000 EOH or 1.800 start up (what comes first)
Notes:
1) In case of reduced operating hours and long periods in standstill, at least 1 minor inspection per
year is suggested.
Page 4 of 15
21.07.16
Special instructions for the inspection intervals and scope of work should be provided in case of
gas turbine in conservation.
2) The scope of work of a Major Inspection includes the Hot Gas Path Inspection scope with
additional activities / check on the cold parts. In the following, sometimes Hot Gas Path Inspection
and Major Inspection are both abbreviated as HGPI.
3)number of EOH and starts for the maintenance intervals depends on several factors, in particular
the specific hardware installed and operating conditions
§ REPAIR AND REPLACEMENT INTERVALS OF MAJOR ITEMS
Table 2 gives a guideline on the items which need to be repaired / replaced based on scheduled
intervals. The purpose of this table is to give indication for planning the budget for replacement
parts. However, these information depend from the specific installed hardware and other factors, for
this reason the specific instructions for each GT should be followed. They could also change during
the lifetime of the GT.
The table 2 is based on the following assumption:
ü Working fluids are according to section TGO2-0160, TGO2-0171, TGO2-0172.
ü Operator has followed all the Manufacturer’s instruction included in this manual (TGO)
ü Ordinary maintenance, inspections and major inspections have been performed as stated by
the Manufacturer’s guidelines and instructions.
Page 5 of 15
21.07.16
Table 2: Repair and Replacement Intervals of Major Items
Item Repair/ Replacement interval

(1)
Refurbishing interval
Compressor blades 66.000 (2) Based on inspection findings
Combustion chamber tiles -- Based on inspection findings
Turbine 1st stage guide ring 33.000/900 66.000/1800
Stage 1 moving blades 33.000/900 66.000/1800
(3)
Stage 4 moving blades 100.000/2700
Stage 1 Vanes 33.000/900 66.000/1800
Stage 2 Vanes 33.000/900 66.000/1800
Stage 3 Vanes 33.000/900 66.000/1800
(3)
Stage 4 Vanes 100.000/2700
1) According to the inspection findings, it may be required to replace/refurbish individual items

2) Only coated stages (stator 0-4, rotor 1-4) – Based on inspection findings
3) Only Visual Inspection and Non-Disruptive Evaluation; repair or refurbishment only based on
inspection findings
When reaching 100.000 EOH or 3000 starts the gas turbine shall be checked item by item in order to
evaluated the residual life of the components (LIFETIME EXTENSION PROGRAM). Furthermore,
components that normally are not included in the standard scope of a major inspection are now
carefully evaluated, in particular rotor items.
Since the plant life can be between 20 - 40 years, the design service life of hot gas path items is
exceeded and it is necessary for the gas turbine operator to contact the Manufacturer in order to
plan a lifetime extension program after the 100.000 equivalent operating hours or 3000 starts.
In general it is possible to upgrade part of the gas turbine with new hot gas path items or other
improvement packages which can be available at time of the scheduled maintenance intervention,
to increase plant efficiency, output, availability and other aspects of plant operation.
Page 6 of 15
21.07.16
§ MAINTENANCE PROGRAM
NOTE:
This section is given as reference only.
It can be changed according to Ansaldo Energia Service Contract or Service
Agreement.
The AE94.3A gas turbines have simple and robust design, longevity and easy maintenance, as it can
be noted through the following characteristics:
ü inspections are simple due to ready accessibility of the machine via manholes
ü first and last stages of turbine blades are accessible via manholes, directly visible and easy to
inspect
ü Simple replacement of combustion chamber wall elements
ü burners are readily accessible from both the inside and outside
ü all items can be readily inspected thanks to endoscope ports
ü good accessibility of all items is provided by horizontal casing joints
ü upper and lower sections of stationary blade carriers can be removed without removing with
the rotor in place
ü individual blades in both the compressor and turbine can be replaced without dismantling the
rotor
ü compressor and turbine bearings can be removed with the rotor in place
ü rotor is of a disk and tie bolt design, film cooling of disks minimizes thermal stresses and cyclic
material fatigue
ü individual turbine vanes (as opposed to segments comprising two or more vanes) minimize
thermal stresses and cyclic material fatigue
ü no damping elements in the hot gas path
ü high startup torques and therefore moderate startup temperatures with rapid acceleration
mean that natural frequency speeds are passed through quickly.
Page 7 of 15
21.07.16
According to the intervals shown in table 1, the inspection activities involve the following activities:
• Minor inspection: the fact finder enters the accessible regions of the machine and perform a
careful and extended visual inspection. The annular combustor is inspected (see figure 1).
Assembly / disassembly activities involve mainly the opening of the manholes and the removal of
the manhole inserts.
Figure 1: Inspection the Annular Combustor
Compressor cleaning is strongly recommended as preparation for the inspection.

The manholes in the intake structure, on the combustion chamber and at the exhaust diffuser are
opened for inspection purposes.
The inspection is focused on the following items:

- Compressor inlet and intake structure;
- Combustion chamber, heat shields, burners;
- First and last turbine stage
- Exhaust casing and exhaust section
This inspection does not require dismantling of the combustion chambers or time-consuming
endoscopic examination.
As a rule, direct visual evaluation is substantially more reliable than endoscopic inspection.
Endoscopic inspection may be useful as a supplementary measure in the case of unusual events, for
example when a foreign object damage is detected on gas turbine items.
See section TGO4-1000 for Endoscopic Inspection Ports.
Page 8 of 15
21.07.16
WARNING:
In case of endoscopic inspection, it is suggested to call for the assistance of an Ansaldo inspector
because performance of endoscopic inspection and interpretation of the results require extensive
experience.
Generally it is required 24 hours of turning gear operation after shut down before entering the
combustion chambers. However this period can be shortened by Ansaldo Energia to 18-12 hours of
turning operation depending on the site conditions or other specific conditions. This time period can
be utilized for other work in the compressor region and outside the gas turbine. For safety reasons, it
is not possible to have access close to rotating parts during turning gear operation.
The proper items that need to be checked and inspected are part of a Service Check List.
Normally it is not necessary to replace hot gas path items in the combustion chamber (for example
ceramic and metallic heat shields or tile holders) during the minor inspection, however if findings
indicate that replacement of these items is necessary, they can be removed and replaced without
lifting off the casing.
Additional information about tile replacement are in section TGO4-1700. In case of a defective tile,
depending on its location, if it is not adjacent to a metallic dummy, it is required the removal of the
other adjacent tiles up and including the dummy.
Propagation of cracks in combustion chamber tiles depends on the gas turbine operation mode and it
is expected that replacement rates are different from gas turbine to gas turbine.
The same concept applies for tile holders, burner supports, metallic heat shields and their
attachment bolts.
After the minor inspection, the manhole covers are closed and turning gear operation must be
resumed.
If appropriate preparations are made and skilled personnel is employed, it is possible to perform an
inspection during a weekend outage (see table 4). Fact finders and inspectors of Ansaldo Energia are
highly recommended for this inspection.
Page 9 of 15
21.07.16
• Hot gas path inspection (HGPI): this is essentially a major inspection restricted to hot gas path
items. The main activities foresee the opening of the outer casing in turbine region, lifting off the
upper sections of the turbine vane carrier, rolling out the lower sections of the turbine vane
carrier and removing turbine blades/vanes for refurbishment/replacement. As a rule, the
compressor section is not opened and the rotor remains in the machine.
In principle it must be assumed that the gas turbine hot gas path items, especially the turbine blades
and vanes, are designed for a limited service life due to the higher thermal and mechanical stress
they are subdue. The blades and vanes have a limited coating thickness and a limited protective
elements. The protective layer has a considerably shorter service life than the base material and it
must be renewed at regular intervals (refer to table 3).
Since the hot gas path components are the most critical items to be focused on during the Hot Gas
Path Inspection, the main activities include all the inspection already included in a minor inspection
and the activity on the hot gas path components (which is the prevailing part of this kind of
inspection).
Therefore it is necessary to remove the outer casing in the region of the combustion chamber and
turbine and to lift off the sections of the turbine vane carriers (including roll-out of the corresponding
lower section).
As a rule, the compressor section is not opened and the rotor remains in the machine, however it is
possible that, based on findings, the scope of work of the HGPI is extended and the compressor is
opened. For instance, this can be necessary when the compressor shall be cleaned by strong deposits
or contaminants or when the planning of additional concurrently activities gives the chance to
inspect also the compressor.
Page 10 of 15
21.07.16
Table 3: maintenance measures performed on main components
Components Hot gas path inspection Major inspection
(HGPI)
1. Turbine blades and vanes
1.1 Stage 1 and 2 blades Disassembly(0) Disassembly(0)
1.2 Stage 3 blades Disassembly(0) Disassembly(0)
1.3 Stage 4 blades Disassembly and Visual Disassembly and
inspection/NDE1) Inspection/NDE1)at 1°
Replacement at 2°
1.4 Stage 1 and 2 and 3 vanes Disassembly(0) Disassembly(0)
1.5 Stage 4 vanes Disassembly and Visual Disassembly and
inspection/NDE1) Inspection/NDE1)at
1°Replacement at 2°
1.6 1st stage guide ring Disassembly(0) Disassembly(0)
1.7 Stage 1 – 4 moving blade seal strips Refurbishment Refurbishment
2. Compressor blades and vanes
2.1 Coated rows 6)
Visual inspection/NDE1)
Refurbishment based on
findings
6)
2.2 Uncoated rows Visual inspection/NDE1)
3. Stationary blade carriers/vane rings
3.1 Turbine Visual inspection/NDE1) Visual inspection/NDE1)
6)
3.2 Compressor Visual inspection/NDE1)
4. Casing hot gas path boundary items
4.1 Ceramic heat shields Visual inspection2) Visual inspection2)
4.2 Metallic heat shields (cast) Visual inspection2) Visual inspection2)
4.3 Metallic dummy heat shields (plate) + Replacement3) Replacement3)
attachment bolts
4.4 Burner inserts Visual inspection2) Visual inspection2)
4) 4)
5. Rotor
6. Burners Visual inspection/NDE1) Visual inspection/NDE1)
7. Open and closed-loop control Function test, Function test,
equipment, auxiliaries, piping pressure/leaktightness pressure/leaktightness
test, condition-based test, condition-based
repairs or replacements 7) repairs or replacements 7)
Page 11 of 15
21.07.16
Components Hot gas path inspection Major inspection
(HGPI)
7.1 Jacking oil hose for compressor bearing Replacement no later than Replacement no later than
four years after date of four years after date of
manufacture manufacture
0) When turbine blades and vanes are disassembled, the replacement or refurbishment depends on
blade/vane operating hours / starts and findings (refer to table 2)
1) Non-destructive evaluation (NDE)
2) As with minor inspection, replacement based on findings
3) Depending on inspection findings, may be unnecessary. In the case of replacement, both shields
and attachment bolts must be replaced.
4) Unstacking may be required on the basis of findings or operating symptoms , for example when
the smoothness of running behavior declines. The first scheduled unstacking to check rotor
components is not performed until 3000 starts or 100k EOH have been logged.
5) May be omitted if inspection findings indicate that refurbishment is unnecessary (dependent on
operating mode).
6) When the compressor section is opened (“extended-scope HGPI”), NDE and cleaning of accessible
components.
7) Based on inspection findings, operating conditions and instructions of original vendors.
• Major inspection (M): it includes extensive dismantling of the machine, detailed visual
inspections and non-destructive examinations as well as scheduled and condition-based repair
measures. Unstacking of the rotor is not necessary as a general rule, but may be deemed
necessary on the basis of inspection findings. This activity requires assembly work since if
foresees extensive dismantling of the gas turbine and the rotor removal.
The activity of the major inspection includes the items of the regular hot gas path inspection,
therefore the hot parts components are replaced / refurbished (see table 3).
In addition, the compressor section is opened and blades and vanes are subjected to non-destructive
examination (NDE). Depending on the condition of the coating, refurbishment of the coated
compressor airfoils may be necessary at this time; i.e. removal of the upper casing sections from the
compressor is performed as a general rule.
During a major inspection it is therefore necessary activities of:
- Dismantling
- Inspections as per major inspection checklist
- Replacement of parts/components based on inspection findings
- Reassembly
Unstacking of the whole rotor for inspection of inaccessible rotor parts is not called for as a general
rule, but may be deemed necessary on the basis of inspection findings. Major inspections at plants
Page 12 of 15
21.07.16
where 3000 starts have been logged or will be logged during the next interval constitute an
exception to this rule. In such cases non-destructive examination of rotor parts is required.
During a major inspection, all gas turbine items are checked for changes which could endanger
operational reliability and availability. These changes include, for example, leaks, permanent
deformation, wear, cracks, fouling and corrosion. Severe consequential damage can occur if these
changes are not promptly detected and eliminated. Furthermore, restoration of smooth turbine
blade surfaces during a hot gas path inspection or major inspection and resetting of radial blade
clearances are performed.
§ OUTAGE TIMES
Preparations for the hot gas path inspection or major inspection made by the operator and
manufacturer include the following topics:
ü Findings of previous inspection
ü Recommended technical modifications
ü Replacement parts requirements
ü Ansaldo specialist personnel requirements
ü Rented tool requirements
ü Organizational sequence.
Those activities require a high level of specialist expertise and special inspection methods and
equipment as well as specific previous experiences, therefore it is highly recommended the
employment of Ansaldo Energia qualified personnel staff.
To a large extent, the hot gas path inspection or major inspection can be performed in the power
plant. A few inspection and maintenance tasks, for example regenerative heat treatments, could
however be performed at Manufacturer’s workshop or another suitable facility. Planning must be
tailored accordingly.
The activity of hot gas path inspections and major inspections includes the following major steps:
ü Acquisition of operating data prior to shutdown
ü Recording the requisite installation clearances
ü Supporting the machine, dismantling of necessary components
ü Fact-finding inspection and non-destructive examination of items as per check-list
ü Repair or replacement of worn items, cleaning of components
ü Reassembly of the gas turbine, including recording of the actual condition as per check-list
Page 13 of 15
21.07.16
ü Recommissioning, plant restart, functional tests and adjustments, including recording of key
operating data
ü Release of the machine for operation.
The manpower and outage time required for a hot gas path inspection and major inspection depend
on several factors:
- Availability of the spare parts needed during the inspection
- Sufficiently experienced and trained specialists
- Adequate crane capacity, availability of requisite installation tools
- Suitable laydown areas and access routes
- Extraordinary inspection findings and documentation stating the history of the machine.
The outage times can be as per table 4.

These are reference values only, please refer to the Service Agreement for the applicable correct
values for the specific GT.
Table 4: Outage Times
Estimated Outage time in days (1)

Minor Inspection 3
Hot gas path inspection 28*
Major inspection 37
* This time is not applicable in case of extended HGPI.
Note (1): the reported time are based on the following assumptions:
o Two shifts per working day

o 10 hour work shift
o Working conditions correspond to EU industrial standard
o Fact-finding inspection reveals no significant grounds for objection
o Major inspection fact-finding inspection reveals no significant grounds for objection!
o Spare and replacement parts are available
o Beginning of the inspection/major inspection = shutdown of turning gear (after
machine has cooled down)
o End of inspection/major inspection = restart of turning gear
o The use of replacement parts requires little or no alignment work
o All the activities performed by Ansaldo Energia (or approved by Ansaldo Energia)
personnel
Page 14 of 15
21.07.16
o All minor inspections are performed by Ansaldo Energia personnel
o Cleanliness is ensured in and around the turbine building
o Special tools and devices included in C54 C55 are available at the power plant and
are in proper working order (see section TGO4-1002)
o All requisite lifting and handling equipment are available at the power plant
o Adequate storage and laydown areas are available
o No acoustic enclosure provided
o Turbine building is equipped with crane of sufficient capacity
o No interferences.
Page 15 of 15
21.07.16
GENERAL COMPONENT TEST
This section gives general information on the required tests to check the functionality of the main
components of the GT on occasion of:
ü Restarting following a scheduled major inspection (HGPI or MI)
ü Restarting following repairs (even when not scheduled).
The checklist is by no means complete and must be modified and/or supplemented by plant
personnel on the basis of the specific needs of the plant.
The checks in this checklist must be thoroughly documented.
Ansaldo Energia recommends that individual tests are dated and confirmed by signature.
Prerequisites for the Start of commissioning and checks

The following prerequisites must be satisfied before beginning commissioning:
• the entire GT plant is kept in a clean, accessible and safe condition for the duration of
commissioning
• safety and firefighting equipment available and ready for operation.
• Records regarding cleaning, pressure and leak tightness testing during installation are available.
• Lube oil and fuel are available and in compliance with all requirements indicated in Section
TGO2-0160, 0171, 0172 of the Operation Manual. The respective delivery systems are
operational.
Page 1 of 4
GENERAL COMPONENT TEST TGO5-0230-E00003
17.11.14
Component Test:
Pumps
• Check operability of auxiliaries (cooling, shaft glands, lubrication)
• Check local and central control room instrumentation
• Test interlocks
• Ensure that measured values are correctly displayed
• Record operating data
Compressor
• Test auxiliaries (cooling, lubrication)
• Check general operating behaviour
• Ensure that measured values are properly displayed
Motorized actuators
• Check actuator interlocks
• Check limit switches and torque switches
• Check for proper direction of rotation
• Record
• Steady – state operating data
Fans
• Test auxiliaries (cooling, seals)
• Test interlocks
• Check general operating behaviour
• Record steady-state operating data
Page 2 of 4
17.11.14
Safety valve
• Check instrument lines for free passage
• Check spring tension setting
• Check local and central control room displays
• Test operating behaviour
Manually actuated valves

• Ensure that valves are properly installed (direction of flow)
• Ensure that valve lift is accurately indicated
• Check locking mechanism
• Test under operating conditions
Valves with Motorised Actuators

• Check manual / motorized operation interlock
• Ensure that valve lift is accurately indicated
• Check for proper direction of rotation
• Check setpoints for torque switches and limit switches against the list of Setting
• Check remote control display
• Check operating behaviour
Solenoid valves
• Check that position indication is correct.
• Check local and remote control, if applicable.
• Check operating behaviour.
Page 3 of 4
17.11.14
Tanks
• Check internals (impingement plates, strainers) braces, and external attachments (stairs, railings)
• Check safety equipment and interlocks (for pressure, fill level and temperature)
• Under operating conditions, test tank for leaktightness, operating fill level and operating
pressure
Pneumatic valves
• Check air line connections.
• Check that position indication is correct.
• Check that direction of opening/closing is correct.
• Verify specified limit positions.
• Check local and remote control.
• Check operating behaviour
Heat exchangers
• Check supervisory equipment and interlocks where applicable( for pressure, level and
temperature).
• Check heat exchangers under operating conditions (vent, leak tightness, pressure, levels and
temperatures).
Filters
• Check instrumentation where applicable. Differential pressure, level indicators.
• Check related alarms and interlocks.
• Check filter unit under operating conditions (vent, tightness, differential pressure, levels).
• Check filter changeover under operating conditions where applicable.
Page 4 of 4
17.11.14

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Project MC: Owner:

MAZANDARAN II 450 MW SINGLE

DOCUMENT TITLE: OPERATION AND MAINTENANCE MANUAL

OPERATION AND MAINTENANCE

OWNER DOCUMENT REVISION

Rev. DATE DESCRIPTION PREPARATION CHECKED VERIFIED VERIFIED APPROVED

IN-HOUSE DOCUMENT REVISION

B 27/02/2018 According to MAZ-UED-AEN-E-0213-GT F. ROSELLINI F. PERPIGLIA L. PIZZIMENTI T. CAPOTOS P. PESCE

A 22/03/2017 FIRST EMISSION M. CUGINO B. SANTOLINI L. PIZZIMENTI T. CAPOTOS P. PESCE

Rev. DATE DESCRIPTION PREPARATION CHECKED VERIFIED VERIFIED APPROVED

Doc. No.: 0558S1MB*S071

O&M MANUAL TGO1-0000-E71000

The second number is progressive.

About this Section

Risk of equipment damage!

Hearing protection required!

Isolate before commencing work!

Identification of Important Information

Proper Use of the Gas Turbine

The following measures reduce or eliminate the risk of injury:

Cellular phones, two-way radios and CD players prohibited!

The following measures reduce or eliminate the risk of injury:

Modifications and Alterations to the Turbine

The following measures reduce or eliminate the risk of injury:

To ensure full compensation in the event of transport damage:

The following measures reduce or eliminate the risk of equipment damage:

The following measure eliminates the risk of injury:

The following measures reduce or eliminate the risk of equipment damage:

The following measure eliminates the risk of burns:

 Ensure compliance with legal codes on noise abatement.

Hearing protection required!

The following measures reduce or eliminate the risk of injury:

The following measures reduce or eliminate the risk of explosion or fire:

Fire, open flames and smoking prohibited!

The following measures eliminate the risk of burns:

The following measure reduces or eliminates the risk of electric shock:

The following measures reduce or eliminate the risk of equipment damage:

Cellular phones, two-way radios and CD players prohibited!

Shutting Down the Gas Turbine

The following measures reduce or eliminate the risk of injury:

The following measures reduce or eliminate the risk of equipment damage:

The following measures reduce or eliminate the risk of injury:

The following measures reduce or eliminate the risk of explosion or fire:

The following measures eliminate the risk of burns:

The following measures reduce or eliminate the risk of electric shock:

Isolate before commencing work!

la manutenzione di una turbina a gas.

la manutenzione di una turbina a gas.

In particular, the hazardous areas a re subdivided into three zones:

The gas or vapour density identifies the hazard degree.

Structure of the identifier

The build-up of an identifier is explained with the following example.

Es: MBP 21 AA 001-S01

MB: (GAS TURBINE).

Es: MBP 21 AA 001-S01

Es: MBP 21 AA 001-S01

Es: MBP 21 AA 001-S01

AA: (Equipment Unit)

Es: MBP 21 AA 001-S01

For measuring instruments: