Guideline For Technical Regulation Vol.2 - Design of Thermal Power Facilities Book 6.12 Gas Fuel Handling Facility

SOCIALIST REPUBLIC OF VIETNAM
Ministry of Industry and Trade (MOIT)
Guideline for
Technical Regulation
Volume 2
Design of Thermal Power Facilities

Book 6/12
« Gas Fuel Handling Facility »
Final Draft
June 2013
Japan International Cooperation Agency
Electric Power Development Co., Ltd.

Shikoku Electric Power Co., Inc.
West Japan Engineering Consultants, Inc.
IL
CR(2)
13-092
Table of Contents
Chapter-1. Comparison between Technical Regulation and Technical Guideline of gas fuel handling
facility ....................................................................................................................... 1
Chapter-2. Each Items of Guideline ................................................................................................... 5
Chapter-3. Technical Standards for pipeline .................................................................................... 88
Chapter-4. Reference International Technical Standards.................................................................. 95
Chapter-5. Reference Japanese Technical Standards ...................................................................... 110
Chapter-6. Reference TCVN ......................................................................................................... 112
Chapter-7. Comparison table of regislation related to pipeline. ..................................................... 114
Chapter-8. Referenced Literature and Materials ............................................................................ 121
List of Tables
Table- 1: Comparison between Technical Regulation and Technical Guideline of gas fuel
handling facility .................................................................................................................. 1
Table- 2: Composition, heating value, etc. of gas fuel ................................................................ 5
Table- 3: Categorization of Fluids ............................................................................................ 14
Table- 4: Classification of Gas Pressure for Gas Facilities ....................................................... 14
Table- 5: Spanning of valve station (shutoff device) ................................................................ 19
Table- 6: Design temperature and coating for gas pipeline ....................................................... 22
Table- 7: Suggested pipe support spacing (ASME B31.1-2004) ............................................... 23
Table- 8: Pipeline material stipulated in API 5L/ISO 3183 ....................................................... 33
Table- 9: Hoop stress design factors Fh for pipelines on land ................................................... 43
Table- 10: Hoop stress design factors Fh for offshore pipelines ................................................ 44
Table- 11: Equivalent stress design factors Feq ......................................................................... 45
Table- 12: Joint method of pipeline .......................................................................................... 47
Table- 13: Effective areas acc. to API 526 ............................................................................... 56
Table- 14: Values of coefficient C ............................................................................................ 56
Table- 15: Calculation of rate equation .................................................................................... 62
Table- 16: Classification of city gas ......................................................................................... 63
Table- 17: Required numbers of fire extinguisher depending on storage capacity..................... 70
Table- 18: Calculation of gas storage capacity ......................................................................... 83
Table- 19: Pipeline industry standards incorporated by reference in 49 CFR part 192, 193 and
195 .................................................................................................................................. 88
Table- 20: Reference International Technical Standards ........................................................... 95
Table- 21: Reference Japanese Technical Standards ............................................................... 110
Table- 22: Reference TCVN .................................................................................................. 112
Table- 23: Comparison table of legislations related to pipeline .............................................. 114
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List of Figures
Fig- 1: Temperature dependence of flammability limit of methane-air mixture .......................... 7
Fig- 2: Pressure dependence of flammability limit of methane-air mixture ................................ 7
Fig- 3: Relationship between lower explosive limit and combustion heat ................................... 7
Fig- 4: Flammability limit of an gas mixture methane with air and inert gas .............................. 8
Fig- 5: High calorie gas fuel system (NFPA-8502-1999) ............................................................ 9
Fig- 6: Low calorie gas fuel system ........................................................................................... 9
Fig- 7: Construction concept of fuel handling for gas thermal power plant (1) ......................... 11
Fig- 8: Constitution concept of fuel handling for gas thermal power plant (2) .......................... 12
Fig- 9: Constitution concept of fuel handling for gas thermal power plant (3) .......................... 13
Fig- 10: Natural gas compression station ................................................................................. 16
Fig- 11: Water seal valve for BFG gas ..................................................................................... 20
Fig- 12: U-shape water sela valve ............................................................................................ 21
Fig- 13: Steel joint flanges ....................................................................................................... 26
List of Photos
Photo- 1: Gas rig in Nam Con Son ........................................................................................... 15
Photo- 2: Gas compression module .......................................................................................... 15
Photo- 3: Natural gas pipeline in Nam Con Son ....................................................................... 16
Photo- 4: Gas piprline from Nam Con son field ....................................................................... 16
Photo- 7: Fuel gas for Phu My 3 power plant ........................................................................... 16
Photo- 8: Warning sign for buried pipeline .............................................................................. 19
Photo- 9: Buried gas pipeline ................................................................................................... 19
Photo- 10: Buried gas pipeline ................................................................................................. 20
Photo- 11: Buried gas pipeline ................................................................................................. 20
Photo- 12: U-shape water sela valve ........................................................................................ 21
Photo- 13: Flange joint ............................................................................................................ 27
Photo- 14: Flange joint ............................................................................................................ 27
Photo- 15: Purging of gas pipeline ........................................................................................... 30
Photo- 18: Venting station on natural gas pipeline ................................................................... 30
Photo- 19: Natural gas pipeline on land ................................................................................... 49
Photo- 20: Natural gas pipeline on land ................................................................................... 49
Photo- 21: Natural gas wellhead .............................................................................................. 49
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Photo- 22: Shutoff valve for Natural gas pipeline .................................................................... 49
Photo- 23: Laying off-sore pipeline ......................................................................................... 50
Photo- 24: Welding of off-shoe pipeline................................................................................... 50
Photo- 25: Laying off-sore pipeline ......................................................................................... 51
Photo- 26: Welding of subsea pipeline ..................................................................................... 51
Photo- 27: Compressor for pressure test .................................................................................. 51
Photo- 28: Compressor for pressure test .................................................................................. 51
Photo- 29: Arc welding of buried pipeline ............................................................................... 53
Photo- 30: Arc welding of pipeline on the land ........................................................................ 53
Photo- 31: Mig welding ........................................................................................................... 53
Photo- 32: Arc welding ............................................................................................................ 53
Photo- 33: Flash butt welding .................................................................................................. 54
Photo- 34: Tig welding ............................................................................................................ 54
Photo- 35: Welding house ........................................................................................................ 54
Photo- 36: Welding tent ........................................................................................................... 54
Photo- 37: Reactor (Link energy) ............................................................................................. 64
Photo- 38: GTLplant (Link energy) ......................................................................................... 64
Photo- 39: Production well (Carbon energy) ............................................................................ 64
Photo- 40: Gas generation plant ............................................................................................... 65
Photo- 41: Coal gasification plant ............................................................................................ 65
Photo- 42: Flaire stack ............................................................................................................. 74
Photo- 43: Landfill gas flaire stack .......................................................................................... 74
Photo- 44: Flaire stack ............................................................................................................. 74
Photo- 45: Flaire stackignition nozzle ...................................................................................... 74
Photo- 46: Gas holder for BFG ................................................................................................ 81
Photo- 47: Spherical gas holder ............................................................................................... 81
Photo- 48: Bio gas hoilder ....................................................................................................... 81
Photo- 49: Membrane gas holder ............................................................................................. 81
Photo- 50: Warning board for gas tank ..................................................................................... 85
Photo- 51: Warning board for gas tank ..................................................................................... 85
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List of Acronyms/Abbreviations
API American Petroleum Institute
AS Australia Standard
ASME American Society of Mechanical Engineers
ASTM American Society for Testing
BFG Blast Furnace Gas
BS British Standard
CFR Code of Federal Regulations
CG Converter Gas
COG Coke Oven Gas
CSA Canadian Standards Association
EN European Norm
FBE Fusion Bonded Epoxy
HPCC High Performance Composite Coating
IEC International Electrotechnical Commission
IGCC Integrated Gasification Combined Cycle
ISO International Organization for Standardization
JIS Japanese Industrial Standard
JGA Japan Gas Association
LDG Linz-Donawitz Converter Gas
LNG Liquefied Natural Gas
3LPE 3-Layer Poly Ethylene
LPG Liquefied Petroleum Gas
3LPP 3-Layer Poly Propylene
MAOP Maximum Allowable Operating Pressure
MSS Manufacturers Standardization Society
NFPA National Fire Protection Association
SYMS Specific Minimum Yield Strength
WES Welding Engineering Society
WPS Welding Procedure Specification
iv
Chapter-1. Comparison between Technical Regulation and Technical Guideline of gas fuel handling
facility
The article number of this guideline is shown in the Table-1 contrasted technical regulation with
technical guideline for easy understanding.
Table- 1: Comparison between Technical Regulation and Technical Guideline of gas fuel handling
facility
Technical Regulation Technical Guideline
Article 114. General provision for gas receiving and Article 114. General provision for gas receiving and
transportation facility transportation facility
-1. General provision -1. General provision
Article 115. Classification of gas pressure for gas Article 115. Classification of gas pressure for gas facilities
facilities
-1. Classification of gas pressure for gas -1. Classification of gas pressure for gas facility
facility
Article 116. Incoming gas pipeline Article 116. Incoming gas pipeline
-1. Length of pipeline -1. Length of pipeline
-2. Buried pipeline -2. Buried pipeline
-3. Drain slope -3. Drain slope
-4. Water seal valve -4. Water seal valve
-5. Purge system -5. Purge system
-6. Insulation against direct sunshine -6. Insulation against direct sunshine
-7. Supporting system -7. Supporting system
-8. Joint of gas pipeline -8. Joint of gas pipeline
-9. Trace heating for water seal valve -9. Trace heating for water seal valve
-10. Painting -10. Painting
-11. Location of vent pipe -11. Location of vent pipe
-12. Purge steam or gas -12. Purge steam or gas
-13. Vent pipe -13. Vent pipe
-14. Vent valve and purge valve -14. Vent valve and purge valve
-15. Drain system -15. Drain system
Article 117. Material of gas transportation facility Article 117. Material of gas transportation facility
-1. Material of gas transportation facility -1. Material of gas transportation facility
Article 118. Structure, etc. of gas facility Article 118. Structure, etc. of gas facility
-1. Pipeline installed in the sea or on land -1. Pipeline installed in the sea or on land
-2. Pressure part -2. Pressure part
-3. Air-tightness -3. Air-tightness
-4. Foundation -4. Foundation
Article 119. Welding part of gas transportation facility Article 119. Welding part of gas transportation facility
-1. Welding of pipeline -1. Welding of pipeline
-2. Welding procedure -2. Welding procedure
-3. Welding management -3. Welding management
Article 120. Safety valve of gas transportation facility Article 120. Safety valve of gas transportation facility
1
-1. Safety valve -1. Safety valve
Article 121. Instrument device, etc. for gas Article 121. Instrument device, etc. for gas transportation
transportation facility facility
-1. Instrument device -1. Instrument device
Article 122. Warning device for transportation facility Article 122. Warning device for transportation facility
-1. Warning device -1. Warning device
Article 123. Fail-safe control and interlock for gas Article 123. Fail-safe control and interlock for gas
transportation facility transportation facility
-1. Fail-safe control -1. Fail-safe control
-2. Interlock -2. Interlock
Article 124. Back-up power, etc. for gas transportation Article 124. Back-up power, etc. for gas transportation
facility facility
-1. Back-up power -1. Back-up power
Article 125. Measure of odor for gas transportation Article 125. Measure of odor for gas transportation facility
facility
-1. Odrization -1. Odrization
Article 126. General provision for gas generation Article 126. General provision for gas generation facility
facility
Article 127. Off Limit to gas generation and supply Article 127. Off Limit to gas generation and supply facility
facility
-1. Off limit -1. Off limit
Article 128. Security communication facility for gas Article 128. Security communication facility for gas
generation and supply facility generation and supply facility
-1. Safety communication facility -1. Safety communication facility
Article 129. Off-set distance for gas generation and Article 129. Off-set distance for gas generation and supply
supply facility facility
-1. Separation distance from boundary -1. Separation distance from boundary
-2. Separation distance from school, hospital, -2. Separation distance from school, hospital, etc.
etc.
Article 130. Security compartment of gas generation Article 130. Security compartment of gas generation and
and supply facility supply facility
-1. Security compartment -1. Security compartment
Article 131. Firefighting facility for gas generation and Article 131. Firefighting facility for gas generation and
supply facility supply facility
-1. Firefighting facility -1. Firefighting facility
Article 132. Prevention of gas accumulation for gas Article 132. Prevention of gas accumulation for gas
-1. Prevention of gas accumulation indoor -1. Prevention of gas accumulation indoor
-2. Gas detector -2. Gas detector
Article 133. Explosion-proof structure of electric Article 133. Explosion-proof structure of electric facility for
facility for gas generation and supply gas generation and supply facility
facility
-1. Distance from flammable gas facility -1. Distance from flammable gas facility
Article 134. Distance from flammable gas facility of Article 134. Distance from flammable gas facility of gas
gas generation and supply facility generation and supply facility
-1. Distance from flammable gas facility -1. Distance from flammable gas facility
Article 135. Gas displacement of gas generation and Article 135. Gas displacement of gas generation and supply
2
-1. Gas replacement -1. Gas replacement
-2. Vent-stack -2. Vent-stack
-3. Heat radiation -3. Heat radiation
Article 136. Material of gas generation and supply Article 136. Material of gas generation and supply facility
facility
-1. Material -1. Material
Article 137. Structures, etc. of gas generation and Article 137. Structures, etc. of gas generation and supply
-1. Structure -1. Structure
-2. Foundation -2. Foundation
Article 138. Welding parts of gas generation and Article 138. Welding parts of gas generation and supply
-1. Welding part -1. Welding part
-2. Welding procedure -2. Welding procedure
-3. Welding management -3. Welding management
Article 139. Safety valve for gas generation and supply Article 139. Safety valve for gas generation and supply
facility facility
-1. Safety valve -1. Safety valve
Article 140. Instrument device, etc. for gas generation Article 140. Instrument device, etc. for gas generation and
Article 141. Alarm device for gas generation and Article 141. Alarm device for gas generation and supply
-1. Alarm device -1. Alarm device
Article 142. Fail-safe control and instrument for gas Article 142. Fail-safe control and instrument for gas
-1. Fail-safe control -1. Fail-safe control
-2. Interlock -2. Interlock
Article 143. Back-up power, etc. for gas generation and Article 143. Back-up power, etc. for gas generation and
supply facility supply facility
-1. Back-up power -1. Back-up power
Article 144. Measurement of odor for gas generation Article 144. Measurement of odor for gas generation and
-1. Odorization -1. Odorization
Article 145. Control room for gas generation and Article 145. Control room for gas generation and supply
-1. Control room -1. Control room
Article 146. General provision of gas storage facility Article 146. General provision of gas storage facility
Article 147. Material of gas storage tank Article 147. Material of gas storage tank
-1. Material -1. Material
Article 148. Structure of gas storage tank Article 148. Structure of gas storage tank
-1 Structure -1 Structure
-2. Drain discharge -2. Drain discharge
-3. Volume of gas storage -3. Volume of gas storage
Article 149. Shut-off device for gas storage tank Article 149. Shut-off device for gas storage tank
-1. Shut-off valve -1. Shut-off valve
3
Article 150. Indication for gas storage tank Article 150. Indication for gas storage tank
-1. Indication -1. Indication
Article 151. Safety valves, etc. for gas storage tank Article 151. Safety valves, etc. for gas storage tank
-1. Quantity of safety valve -1. Quantity of safety valve
-2. Negative pressure -2. Negative pressure
Article 152. Instrument device for gas storage tank Article 152. Instrument device for as storage tank
-2. Pressure detector and thermometer -2. Pressure detector and thermometer
Article 153. Alarm device for gas storage tank Article 153. Alarm device for gas storage tank
-1. Alarm device -1. Alarm device
4
Chapter-2. Each Items of Guideline
Article 114. General provision for gas receiving and transportation facility
Article 114-1. General provision
1. Characteristics of the gas fuel
There are types of gas fuel such which is obtained by dry distillation of coal, obtained by
decomposition of petroleum products, natural gas in natural state and by-products that is obtained in
steel mills. Generally gaseous fuels has characteristics that it is high combustion efficiency, few
excess air for complete combustion, there are features such as sulfur oxides does not occur, since it
does not contain sulfur.
LNG（Liquefied Natural Gas）that was cooled down to -162 oC at atmospheric pressure is composed
mainly methane, ethane, propane, butane and the like. It is clean energy, since sulfur and other
impurities are removed in the course of liquefaction pretreatment process. LPG（Liquefied Petroleum
Gas）is the petroleum type hydrocarbon gas which is easy to liquefy under a slight pressure at room
temperature, and composed mainly propane and butane and has characteristic that is high heating
value and less sulfur.
COG（Coke Oven Gas）is generated during the coke production as the by-product in steel mill. It
contains methane and hydrogen and is excellent to burn due to high calorific value. BFG（Blast
Furnace Gas）is produced as by-product from blast furnace in the steel mill, which contains dust,
carbon dioxide and nitrogen gas as an inert gas and has low calorific value. Table-2 shows an
example of the properties of gaseous fuels.
Table- 2: Composition, heating value, etc. of gas fuel
Heating value
Composition (%) 3
Gas fuel (kJ/m N )
H2 CH4 C2 H6 C3 H8 C4 H10 C5 H12 CO2 CO O2 N2 Higher Lower
Alaska (Kenai) ― 99.8 0.1 0.0 0.0 0.0 ― ― ― 0.1 39,780 35,800
Brunei (Lumut) ― 88.6 5.2 3.6 1.6 0.0 ― ― ― 0.0 44,800 40,610
Abu Dhabi (Das) ― 80.4 17.5 2.0 0.0 0.0 ― ― ― 0.1 46,060 41,870
Natural gas
Indonesia (Badack) ― 89.6 5.7 3.3 1.4 0.0 ― ― ― 0.0 44,380 41,030
Indonesia (Arum) ― 86.1 8.8 4.1 1.0 0.0 ― ― ― 0.0 45,220 41,450
Malaysia (Sarawak) ― 91.6 4.1 2.7 1.5 ― ― ― ― 0.1 44,170 39,820
Australia (Karratah) ― 89.0 7.4 2.5 1.1 0.0 ― ― ― 0.0 44,380 40,190
Japan (Niigata) ― 96.4 2.4 0.4 0.3 0.1 0.4 ― ― ― 40,950 36,930
Blast furnace gas (BFG) 2.8 ― ― ― ― ― 21.9 21.9 ― 53.4 3,100 3,060
Converter gas (LDG) 1.1 ― ― ― ― ― 13.1 76 ― 9.8 9,760 9,710
Coke-oven gas (COG) 55.2 28.1 CmHn =3.1 2.7 8.0 0.3 2.6 21,350 18,840
Producer gas 12.1 3.6 CmHn =0.4 4.8 25.5 0.2 53.4 6,490 6,070
Heating value
Composition (%) 3
Gas fuel (kJ/m N )
C2 H6 C3 H8 C4 H10 C5 H12 Higher Lower
Liquefied petroleum gas (LPG)
JIS type-2 No.1 standard product 2.0 96 2.0 ― 100,440 93,580
JIS type-2 No.4 standard product ― 3.0 95.0 2.0 133,390 123,010
Reference: Handbook for thermal and nuclear power engineerings/2008 6-13 "Composition, Heating Value, etc. of Gas Fuel (Example)"
5
Reference: P-51 of Journal (No.611: Aug. /2007): TENPES
2. Combustion characteristics of gas fuel

1) It is possible to burn spreading fuel mixed with air under low pressure (0.04~0.25MPa) and the
combustion process will not have short flame without spraying steam such as heavy oil
combustion. Flame characteristics such as reaction rate, flame temperature are governed by the
condition of mixture with air.
2) Generally, the flame emissivity is low luminous flame, since low ratio of C/H of the components
and there is no formation of soot in combustion process.
3) It has high water content in the combustion gases and high emissivity of the gases.
4) The combustion efficiency is high and there is no occurrence of unburned under proper
combustion air ratio. However, if air lacks, unburned such as CO, etc is occurs and soot occurs
in extreme cases.
5) Large turn-down of the burner, combustion is also easy to adjust. However, the shape of an
improper air ratio out of range, the ignition will be instable. In extreme cases, it causes vibration
combustion with resonance of the furnace natural frequencies.
6) Fuel contains little sulfur, nitrogen and impurities, there is no contamination, wear and
corrosion of boiler. In addition, measure for public pollution is easy, low NOx, SOx and no dust
emissions.
7) It has risk of explosion as well as other fuels in ignition failure, since flammable range is wide.
3. Flammable limit
Fuel gas and air mixture can be burn in a range of mixture. The upper and lower limit of this range is
called “Flammable limit” and they are represented in concentration of fuel in the mixture. Fig-1
shows the flammable limit in mixture of each single gas at atmosphere and 25℃. The flammable
limit is wider with the increase of mixture temperature and pressure, more significant changes to the
cap in general. Fig-1 and 2 shows the relation between flammable limit and temperature and pressure
of methane (CH4). In addition, the production of the lower limit concentration of hydrocarbon fuel
(C1) and combustion heat (Q) has a constant relation ship as shown in Fig-3. The flammable limit is
important to consider safety measure such as explosion proof, anti-backfire, purging of gas piping.
For example, flammable limit can be narrowed by adding an inert gas as shown in Fig-4. Generally,
N2 gas is used for purging of gas piping.
6
Temperature ( C)
o
Combustible range
CH4 concentration in gas mixture (%)
Fig- 1: Temperature dependence of flammability limit of methane-air mixture

Reference: P-106 of Journal (No.517: Oct. /1999): TENPES
Pressure (MPa)
Combustible range
CH4 concentration in gas mixture (%)
Fig- 2: Pressure dependence of flammability limit of methane-air mixture

Fig- 3: Relationship between lower explosive limit and combustion heat
7
O2 concentration in gas mixture (%)
Methane concentration in gas mixture (%)

CO2
H2O
N2
Theoretical gas mixture He
Ar
Inert gas concentration in gas mixture (%)
Fig- 4: Flammability limit of an gas mixture methane with air and inert gas
4. Fuel supply facility

Gas burner, gas shutoff valve, gas vent valve, gas flow rate measuring device and gas flow rate
control device is installed in the fuel supply system for fuel gas according to NFPA (National Fire
Protection Association) standard and the like. Flow rate in the gas service pipe is planned in
30~40m/s in order to reduce pressure loss in the pipe and the sound of fluid. Also, the gas fuel heater
may be provided for blast furnace gas (BFG) in order to improve the efficiency of the boiler.
High calorie gas such as LNG or LPG will be injected from the tip of the burner in high speed and be
burnt. Dual shutoff valves are installed for each burner and the vent valve is installed between two
shutoff valves as shown in Fig-5.
By-product gas such as BFG or COG has low calorific value and low gas pressure, it is required
much gas flow. Therefore, it is necessary to turn the fuel and cross gas and air alternately, to promote
of gas and air to keep good combustion. When applying exhaust gas such as BFG or COD generated
from steel mill as the fuel for the boiler, the U-shaped water seal valve as shown in Fig-9, 10 and
Photo-12 is provided on the boundary between the steel mill and the power plant for shutoff and the
emergency gas shutoff valve to separate boiler is provided in general. The highly toxic carbon
monoxide (CO) has been contained in these gases; it is necessary special attention as security
measures such as gas detection of leakage or remaining gas in the pipe by CO gas detector. In
addition, piping purge by nitrogen gas or steam and safety arrangement of vent pipe must be pay
sufficient attention for safety.
8
C2
C1
B B
Q Main burner
T
to other boilers R
K S Other main burners

T O T M
M J A D
J
I P C1
transportation pipeline D1
T
Ignition burner
《Valves》《Equipments》
A: Gas shutoff valve I: Charge valve for leak check M: Flow meter
B: Burner inlet shutoff valve J: Gas pressure reducing valve O: Strainer
C1 : Burner header vent valve K: Relief valve P: Orifice
C2 : Burner inlet vent valve D: Gas flow control valve Q, R: Alarm for high gas pressure, pressure switch for low trip
D1 : Minimum gas pressure holding valve T: Manual stop valve S: Header pressure
Fig- 5: High calorie gas fuel system (NFPA-8502-1999)

Purge valve Vent valve Purge valve Purge valve Gas burner
Vent valve
Sampling
Gas flow meter Gas flow control damper Sampling
U-shape waterseal valve Gas shutoff valve
Fig- 6: Low calorie gas fuel system

5. Public safety and protection of the environment

National requirements which take precedence over the requirements in this International Standard
must be specified by the country in which the pipeline is located. The requirements in this
International Standard for public safety and protection of the environment must apply where no
specific national requirements exist. On-land pipeline systems for category D and E fluids must meet
the requirements for public safety of annex B where specific requirements for public safety have not
been defined by the country in which the pipeline is located.
9
6. Requirements for operation and maintenance:
The requirements for the operation and maintenance of the pipeline system must be established and
documented for use in the design and the preparation of procedures for operations and maintenance.
Aspects for which requirements must be specified may include:
1) requirements for identification of pipelines, components and fluids transported;

2) principles for system control, including consideration of manning levels and instrumentation;
3) location and hierarchy of control centers;
4) voice and data communications;
5) corrosion management;
6) condition monitoring;
7) leak detection;
8) pigging philosophy;
9) access, sectionalizing and isolation for operation, maintenance and replacement;
10) interfaces with upstream and downstream facilities;
11) emergency shut-in;
12) depressurization with venting and/or drainage;
13) shutdowns and restart;
14) requirements identified from the hydraulic analysis.
7. Public safety
Pipelines conveying category B, C, D and E fluids must, where practicable, avoid built-up areas or
areas with frequent human activity. In the absence of public safety requirements in a country, a
safety evaluation must be performed in accordance with the general requirements of annex A for:
1) pipelines conveying category D fluids in locations where multi-storey buildings are prevalent,
where traffic is heavy or dense, and where there may be numerous other utilities underground;
2) pipelines conveying category E fluids.
8. Environment
An assessment of environmental impact must consider as a minimum:
1) temporary works during construction, repair and modification;

2) the long-term presence of the pipeline;
3) potential loss of fluids.
10
Fig- 7: Construction concept of fuel handling for gas thermal power plant (1)
11
Power Plant Premise
Gas Fire Plant & Expander
Blast Furnace Expander
Blast Furnace Gas Conventional Power Plant
Blast Furnace Gas Holder
Coal Handling & Supply System GT Combined Cycle Plant

same as coal therma power plant
①KOBELCO commenced construction 2,000,000ton/year ITmk3 method ironworks in northern Nghe An province in 2011
②POSCO of Korea construct 4,500,000ton/year capacity iconsistent ronworks with VINASHIN
③Taiwan plastic planns to construct 7,500,000ton/year capacity ironworks in Ha Tinh province
④Tyoons Wordwide Steel of Taiwan plans to construct 5,000,000 ton/year capacity ironworks
⑤ Tata of India plan to construct 4,500,000ton/year capacity ironworks with Vietnam national steel
Fig- 8: Constitution concept of fuel handling for gas thermal power plant (2)
12
Fig- 9: Constitution concept of fuel handling for gas thermal power plant (3)
13
Article 115. Classification of gas pressure for gas facilities
Article 115-1. Classification of gas pressure for gas facility
1. The fluids to be transported must be placed in one of the following five categories as shown in Table-3
according to the hazard potential in respect of public safety:
Table- 3: Categorization of Fluids

Category A Typically non-flammable water-based fluids.
Flammable and/or toxic fluids which are liquids at ambient temperature and at atmospheric pressure
Category B conditions. Typical examples are oil and petroleum products. Methanol is an example of a flammable
and toxic fluid.
Non-flammable fluids which are non-toxic gases at ambient temperature and atmospheric pressure
Category C
conditions. Typical examples are nitrogen, carbon dioxide, argon and air.
Category D Non-toxic, single-phase natural gas.
Flammable and/or toxic fluids which are gases at ambient temperature and atmospheric pressure
conditions and are conveyed as gases and/or liquids. Typical examples are hydrogen, natural gas (not
Category E
otherwise covered in category D), ethane, ethylene, liquefied petroleum gas (such as propane and
butane), natural gas liquids, ammonia and chlorine.
Reference: 5.2 of ISO 13623-2000
Gases or liquids not specifically included by name must be classified in the category containing fluids most
closely similar in hazard potential to those quoted. If the category is not clear, the more hazardous category
must be assumed.
2. Pressure for the gas pipeline is classified into 4 categories according to the maximum operating pressure as
shown in Table-4.
Table- 4: Classification of Gas Pressure for Gas Facilities

Class Pressure (MPag) Object
Very High Pressure 7.0 ≤ P Long range transportation from gas field by pipeline
High Pressure 1.0 ≤ P < 7.0 Middle range transportation from gas base by pipeline
Middle Pressure 0.2 ≤ P < 1.0 Short range transportation by pipeline
Low Pressure P < 0.2 For home use
14
Article 116. Incoming gas pipeline
1. Gas fuel for gas-fired power plant is supplied in the following major routes.
1) Natural gas that has been mined in the onshore gas field is supplied to the power plant by pipeline.
2) Natural gas that has been mined in the offshore gas field is supplied to the power plant by pipeline.
3) Imported LNG or LPG is brought into power plant premise and use vaporized gas as gas fuel.
4) Vaporized gas from imported LNG or LPG in the base is supplied to power plant by pipeline.
5) Residual gas generated from the adjacent oil refinery plant is supplied to power plant by pipeline.
6) Blast furnace gas, converter gas and coke oven gas that has been generated in the steel mill is
supplied to the power plant by pipeline.
7) Gas that is gasificated from coal which is brought into power plant is applied to the fuel for IGCC.
8) Gasificated gas from coal reserved in the coal seam is extracted and supplied to the power plant by
pipeline.
9) Coal seam gas that is reserved in the underground coal seam is extracted and supplied to the power
plant by pipeline.
10) Bio-gas generated from biomass processing facility is supplied to power plant.
2. The construction concept of transportation path and combination of transportation facility are shown in
Fig-5, 6 and 7.
3. Natural gas drilled in the offshore gas field as shown in Photo-1 is compressed by compressor on the
platform as shown in Photo-2 and Fig-8, land on the beach and switch to the onshore pipeline as shown in
Photo-3 after transporting by offshore pipeline. It is transported to inland power plant by buried pipeline or
pipeline on the land as shown in Photo-4 and 5 in a long distance. It is received as shown in Photo-6 and 7,
and combusted in the boiler or gas turbine after the pressure adjustment.
Photo- 1: Gas rig in Nam Con Son Photo- 2: Gas compression module
http://menasassociates.blogspot.com/2010/07/mounting-interest-in http://www.khi.co.jp/news/detail/20101206_1.html
-bps-nam-con-son.html
15
Fig- 10: Natural gas compression station Photo- 3: Natural gas pipeline in Nam Con Son
http://www.powerverdeenergy.com/natural-gas/ http://www.aerialmarine.com/bp-nam-con-son-onshore-aerial-viet
nam-BP-lan-tay
Photo- 4: Gas piprline from Nam Con son field Photo- 5: Natural gas pipeline in Nam Con Son
http://www.aerialmarine.com/bp-nam-con-son-onshore-aerial-viet http://www.vrbank.com.vn/NewsShow1.aspx?id=131&lang=en
nam-BP-lan-tay
Photo- 6: Natural gas pipeline in Nam Con Son Photo- 7: Fuel gas for Phu My 3 power plant
http://www.uni-bros.com/en/news.php/more_than_440mil_usd_in http://www.vrbank.com.vn/NewsShow1.aspx?id=131&lang=en
vested_in_nam_con_son_gas_pipeline_2_project/id=18264/cid=3
Article 116-1. Length of pipeline

1. Route selection
(1) General
Route selection must take into account the design, construction, operation, maintenance and abandonment
of the pipeline in accordance with this International Standard. To minimize the possibility of future
16
corrective work and limitations, anticipated urban and industry developments must be considered.
Factors which must be considered during route selection include:
1) safety of the public, and personnel working on or near the pipeline;

2) protection of the environment;
3) other property and facilities;
4) third-party activities;
5) geotechnical, corrosivity and hydrographical conditions;
6) requirements for construction, operation and maintenance;
7) national and/or local requirements;
8) future exploration.
Note: Annex-C provides guidance on the planning of a route selection. Annex D provides examples of
factors which must be addressed during the considerations required in 6.2.1.1 to 6.2.1.7.
(2) Public safety

Pipelines conveying category B, C, D and E fluids should, where practicable, avoid built-up areas or areas
with frequent human activity. In the absence of public safety requirements in a country, a safety evaluation
must be performed in accordance with the general requirements of annex A for:
1) pipelines conveying category D fluids in locations where multi-storey buildings are prevalent, where
traffic is heavy or dense, and where there may be numerous other utilities underground;
(3) Environment

(4) Other facilities

Facilities along the pipeline route which may affect the pipeline must be identified and their impact
evaluated in consultation with the operator of these facilities.
(5) Third-party activities

Third-party activities along the route must be identified and should be evaluated in consultation with these
parties.
17
(6) Geotechnical, hydrographical and meteorological conditions
Adverse geotechnical and hydrographic conditions must be identified and mitigating measures defined. In
some instances, such as under arctic conditions, it may be necessary also to review meteorological
conditions.
(7) Construction, testing, operation and maintenance

The route must permit the required access and working width for the construction, testing, operation and
maintenance, including any replacement, of the pipeline. The availability of utilities necessary for
construction, operation and maintenance must also be reviewed.
2. Surveys — Pipelines on land

Route and soil surveys must be carried out to identify and locate with sufficient accuracy the relevant
geographical, geological, geotechnical, corrosivity, topographical and environmental features, and other
facilities such as other pipelines, cables and obstructions, which could impact the pipeline route selection.
3. Surveys — Offshore pipelines

Route and soil surveys must be carried out on the proposed route to identify and locate:
1) geological features and natural hazards;

2) pipelines, cables and wellheads;
3) obstructions such as wrecks, mines and debris;
4) geotechnical properties.
Meteorological and oceanographical data required for the design and construction planning must be
collected. Such data may include:
1) bathymetry;
2) winds;
3) tides;
4) waves;
5) currents;
6) atmospheric conditions;
7) hydrologic conditions (temperature, oxygen content, pH value, resistivity, biological activity,
salinity);
8) marine growth;
9) soil accretion and erosion.
18
4. Spanning of valve station (shutoff device).
It is the best way to keep gas pressure high and prevent pressure drop in order to transport large amount of
gas efficiently. However, the proper balance of both is required, since numbers of pumping station is
required and the capital investment increases. When 2~3MPa pressure drop from discharge pressure
(8~9MPa) occurs, which the pressure in the pipeline is ensured in average 6MPa, the new pumping station
will be installed in general. The different system may be established due to different requirement, the
method to install two pipelines instead of pumping station to avoid pressure drop is employed depending
on the pipeline route. In any case, the consideration of laying space for route selection and how to set the
pipeline diameter and pressure is the biggest issue in order to establish optimal pipeline system.
Table- 5: Spanning of valve station (shutoff device)

ANSI/ASME B31.8 (US) Pipeline Business Act (JP)
Classification Span Remarks Span Remarks
32km Sparsely polluted area such as wasteland, desert, Necessary

Class-1 River crossing
(20mile) meadow part
24km Periphery of towns and city districts, industrial

Class-2 10km Non-urban area
(15mile) zones
16km
Class-3 Residential development district on outskirts 4km Urban area
(10mile)
8km Downtown (many high-rise buildings and large House densed

Class-4 1km
(5mile) volume of traffic) Area (1)
Note-(1): The population density which is calculated for each parcel of land roughly the following formatting 50ha, the area of land that
have been more than 40 men/ha and the area that has population not less than 5,000.
Article 116-2. Buried pipeline
Photo- 8: Warning sign for buried pipeline Photo- 9: Buried gas pipeline
http://www.tsc.uk.net/search.php?group=1&searchtext=&start=40 http://www.geograph.org.uk/photo/899546
19
Photo- 10: Buried gas pipeline Photo- 11: Buried gas pipeline
http://news.bbc.co.uk/2/hi/in_pictures/6147424.stm http://www.hydrocarbons-technology.com/projects/southwalesgas/
southwalesgas4.html
Article 116-3. Drain slope

1. The most important consideration when building pipelines is accounting for the slope the pipeline will
follow. Slope is the gradual and sustained downward angle the pipeline follows so gravity can move the
media to its destination. Although some pipelines are pressurized to pump media, even in these designs, the
slope is still necessary for them to successfully cover great distances.
2. A pipeline does not always have to travel downhill. It can be flat or even go uphill for some distance. The
important calculation, however, is that the overall length of pipeline ends in a lower location than it begins.
Accounting for the slope of just 1 foot over several thousand feet can be the difference between a
well-functioning pipeline and a clogged pipe moving very little.
Article 116-4. Water seal valve

1. When large volume and low pressure BFG, COD and LDG generated in the steel mill is used as the fuel for
thermal power plant, the water seal valve as shown in Fig-12m Photo-12 is installed at the boundary
between steel mill and power plant, and gas is blocked reliably apart from the boiler emergency gas shutoff
valve. In addition, the reverse flow from gasholder to each furnace in the steel mill is prevented by the
water seal valve with check valve function as shown in Fig-11.
Gas flow towards cargo tanks Backpressure in cargo tanks
Venturi
Fig- 11: Water seal valve for BFG gas

http://www.tc.gc.ca/eng/marinesafety/tp-tp4295-part-iii-2241.htm
20
Gas
Supply
water
water
Drain
Seal tank
H:Gas pressure L:Seal water pressure
Fig- 12: U-shape water sela valve Photo- 12: U-shape water sela valve
Reference: P-51 of Journal (No.590: Nov. /2005): TENPES http://www.shinkoen-m.jp/product/kikai/sske/haikan.html
Article 116-5. Purge system

1. Purging of Pipelines and Mains
(1) When a pipeline or main is to be placed in service, the air in it must be displaced. The following are some
acceptable methods:
1) Introduce a moderately rapid and continuous flow of gas into one end of the line and vent the air out
the other end. The gas flow must be continued without interruption until the vented gas is free of air.
2) If the vent is in a location where the release of gas into the atmosphere may cause a hazardous
condition, then a slug of inert gas must be introduced between the gas and air. The gas flow must then
be continued without interruption until all of the air and inert gas have been removed from the facility.
The vented gases must be monitored and the vent must be closed before any substantial quantity of
combustible gas is released to the atmosphere.
(2) In cases where gas in a pipeline or main is to be displaced with air and the rate at which air can be supplied
to the line is too small to make a procedure similar to but the reverse of that described in (a) above feasible,
a slug of inert gas must be introduced to prevent the formation of an explosive mixture at the interface
between gas and air. Nitrogen or carbon dioxide can be used for this purpose.
(3) If a pipeline or main containing gas is to be removed, the operation may be carried out in accordance with
para.
2. The line may be first disconnected from all sources of gas and then thoroughly purged with air, water, or
inert gas before any further cutting or welding is done.
21
(1) If a gas pipeline, main or auxiliary equipment is to be filled with air after having been in service and there
is a reasonable possibility that the inside surfaces of the facility are wetted with volatile inflammable liquid,
or if such liquids might have accumulated in low places, purging procedures designed to meet this situation
must be used. Steaming of the facility until all combustible liquids have been evaporated and swept out is
recommended. Filling of the facility with an inert gas and keeping it full of such gas during the progress of
any work that might ignite an explosive mixture in the facility is an alternative recommendation. The
possibility of striking static sparks within the facility must not be overlooked as a possible source of
ignition.
3. Whenever the accidental ignition in the open air of gas-air mixture might be likely to cause personal injury
or property damage, precautions must be taken. For example:
1) Prohibit smoking and open flames in the area.

2) Install a metallic bond around the location of cuts in gas pipes to be made by means other than cutting
torches.
3) Take precautions to prevent static electricity sparks.
4) Provide a fire extinguisher of appropriate size and type, in accordance with ANSI/NFPA 10
Article 116-6. Insulation against direct sunshine

1. Natural gas is moved through a pipeline under pressure. As natural gas flows through a pipeline, it loses
pressure due to friction against the inside of the pipe. To keep the natural gas moving at the desired rate,
the pressure must be increased. This is accomplished with compressor stations located along a pipeline.
2. The temperature of the natural gas will slowly decrease in the pipeline, along with the pressure. The
temperature decreases due to the pressure reduction. As a result, the natural gas cools. The pressure of the
natural gas must be increased along the pipeline through the use of compressor stations. When compressor
stations increase the pressure of the natural gas, the temperature of the natural gas rises. The natural gas
must be cooled to minimize impacts on the pipeline and permafrost.
3. Design temperature and coating for gas pipeline.
Table- 6: Design temperature and coating for gas pipeline

Temperature (oC) Coating type
Region Actual Actual pipe Max. operating
Design Type
ambient surface temperature
65 3LPP 110 ~ 140

Desert 110 35 ~ 45
and more 3LPE 85 ~ 90
65
Rainforest 90 35 ~ 47 FBE 85 ~ 90
and more
X100 3LPE 85 ~ 90
Cold climate -35 ~ -45 ?
X120 HPCC 85
22
Note: 3LPP: 3-layer polypropylene, 3PE: 3-layer polyethylene, FBE: fusion bonded epoxy, HPCC: High performance composite
coating
Reference: “High temperature pipeline coatings – Fielde joint challenges in remote construction”: (Wayne Hodgins and others of
Canusa-CPS)
Article 116-7. Supporting system

1. Pipeline spanning
Spans in pipelines must be controlled to ensure compliance with the strength criteria in Table-13. Due
consideration must be given to:
1) support conditions;
2) interaction with adjacent spans;
3) possible vibrations induced by wind, current and waves;
4) axial force in the pipeline;
5) soil accretion and erosion;
6) possible effects from third-party activities;
7) soil properties.
2. Support
The typical support of pipeline is shown in Fig-23 and Photo-60, 61
(1) Support span
Table- 7: Suggested pipe support spacing (ASME B31.1-2004)

Suggested maximum span
Nominal pipe size
Water service Steam, gas or air service
NPS (ft) (m) (ft) (m)
1 7 2.1 9 2.7
2 10 3.0 13 4.0
3 12 3.7 15 4.6
4 14 4.3 17 5.2
6 17 5.2 21 6.4
8 19 5.8 24 7.3
12 23 7.0 30 9.1
16 27 8.2 35 10.7
20 30 9.1 39 11.9
24 32 9.8 42 12.8
23
3. Attachment of supports or anchors
The pipeline and equipment must be adequately supported, so as to prevent or to damp out excessive
vibration, and must be anchored sufficiently to prevent undue loads on connected equipment. Branch
connections for pipelines on land must be supported by consolidated backfill or provided with adequate
flexibility.
When openings are made in a consolidated backfill to connect new branches to an existing pipeline on land,
a firm foundation must be provided for both the header and the branch to prevent both vertical and lateral
movements. Braces and damping devices required to prevent vibration of piping must be attached to the
carrier pipe by full encirclement members.
All attachments to the pipeline must be designed to minimize the additional stresses in the pipeline.
Proportioning and welding strength requirements of attachments must conform to standard structural
practice. Structural supports, braces or anchors must not be welded directly to pipelines designed to
operate at a hoop stress of 50 % or more of SMYS. Instead, such devices must be supported by a full
encirclement member.
Where it is necessary to provide positive support, as at an anchor, the attachment must be welded to the
encircling member and not to the pipe. The connection of the pipe to the encircling member must be by
continuous circumferential rather than intermittent welds.
Supports not welded to the pipeline must be designed to allow access for inspection of the pipeline
underneath the supports. Design of anchor blocks to prevent axial movement of a pipeline must take into
account the pipeline expansion force and any pipe-to-soil friction preventing movement. The design of the
full encirclement member must include the combined stress in the carrier pipe of the functional,
environmental, construction and accidental loads. Attachment of the full encirclement member may be by
clamping or continuous full encirclement welds.
The axial force, F, to be resisted for fully restrained pipelines must be calculated as follows:
24
[
F = A × E × a × (T2 − T1 ) − v × σ hp ]
Where
F : axial force
A : cross-section area of pipewall
E : modulus of elasticity
α : linear coefficient of thermal expansion
T1 : installation temperature
T2 : maximum or minimum metal temperature during
operation
αhp : hoop stress due to internal pressure, based on
nominal wall thickness
v : poisson ratio
Significant residual installation loads shall also be taken into account when determining axial pipeline
forces.
Article 116-8. Joint of gas pipeline

1. “The measure to make it possible to check the joints and to prevent spread of dangerous material” must be
taken in the place where the dangerous material may scatter outside the premise when leaking from the
flange joint which is installed in the premise. And it must be pursuant to as follows;
(1) The check box must have watertight, robust and durable structure with drain valve and lid.
(2) Material of the check box must be used the steel plates with at least 1.6mm thickness.
(3) Corrosion protection measures must be performed by corrosion protection coating.
(4) The check box must not interfere with the structure of piping and the effective depth (distance between
bottom of joint and bottom of the check box) must be at least 10cm.
(5) The reservoir must be provided, if the distance from ground level to the lowest point of check box is more
than 5cm.
2. Flanged connections
(1) Flanged connections must meet the requirements of ISO 7005-1, or other recognized codes such as ASME
B16.5 or MSS SP-44. Proprietary flange designs are permissible. They must conform to relevant sections
of ASME Section VIII, Division 1 as shown in Photo-44, 45 and Fig-17.
25
(2) Compliance with the design requirements of ASME B16.5 must be demonstrated when deviating from the
flange dimensions and drillings specified in ASME B16.5 or MSS SP-44.
(3) Consideration must be given to matching the flange bore with the bore of the adjoining pipe wall to
facilitate alignment for welding.
(4) Gaskets must be made of materials which are not damaged by the fluid in the pipeline system and must be
capable of withstanding the pressures and temperatures to which they will be subjected in service. Gaskets
for services with operating temperatures above 120 °C must be of non-combustible materials.
(5) Bolt material must be in accordance with ASTM A193 B7 or equivalent. Nut material must be in
accordance with ASTM A194 2H or equivalent. Bolts or stud bolts must completely extend through the
nuts.
Fig- 13: Steel joint flanges

http://www.rjsales.com/products/ansi_asme_flanges/misc/b.html
26
Photo- 13: Flange joint Photo- 14: Flange joint
http://www.flickr.com/photos/norbar/6079336087/in/set-721576 http://www.flickr.com/photos/norbar/6079420175/in/set-721576
26473837695 26473837695
Article 116-9. Trace heating for water seal valve

1. It is not necessary to consider the prevention measure for freeze of water in the seal water valve except in
cold climate region.
Article 116-10. Painting

1. External coating
All external and internal coatings must comply with a recognized standard or specification, covering the
following requirements:
1) type of coating and reinforcement, where relevant;

2) thickness of individual layers and total thickness;
3) composition and/or base material;
4) mechanical properties;
5) temperature limitations;
6) surface preparation requirements;
7) adhesion requirements;
8) requirements for materials, application and curing, including possible requirements for health, safety
and environmental aspects;
9) requirements for qualification testing of coating system and personnel where relevant;
10) requirements for testing and inspection;
11) repair procedures where relevant.
2. Internal coatings/linings
Internal coating must in general comply with the requirements of paragraph-3 if applied to mitigate internal
corrosion. Anti-friction coatings must as a minimum comply with API RP 5L2 and have a minimum
thickness of 40 μm. The coating may consist of an epoxy base and a curing agent based on epoxy
aliphatic/cycloaliphatic amine or polyamide.
27
3. Internal coatings or linings
Coatings or linings may be applied to reduce internal corrosion provided that it is demonstrated that
incomplete protection, at areas such as holidays and other defects, does not lead to unacceptable corrosion.
Factors to be considered during coating or lining selection must include:
1) internal coating of field joints;

2) application methods;
3) availability of repair methods;
4) operating conditions;
5) long-term effects of the fluid(s) on the coating/lining;
6) resistance to pressure change;
7) influence of temperature gradients over the coating;
8) compatibility with pigging operations.
4. Field coating
Field-applied coatings must satisfy the requirements of paragraph-1. The preparation of the pipe surface
and the application of the field joint coating must be performed in accordance with a qualified procedure
that meets the requirements of the coating manufacturer's recommendations. Coating must be applied by
competent operators who have received adequate instruction.
Article 116-11. Location of vent pipe

1. Pressure relief station
It consists of equipment installed to vent gas from a system being protected to prevent the gas pressure
from exceeding a predetermined limit. The gas may be vented into the atmosphere or into a lower pressure
system capable of safely absorbing the gas being discharged. Included in the station are piping and
auxiliary devices, such as valves, control instruments, control lines, the enclosure, and ventilating
equipment, installed in accordance with the pertinent requirements of this Code.
2. Purging of pipelines and mains
(1) When a pipeline or main is to be placed in service, the air in it must be displaced. The following are some
acceptable methods:
1) Introduce a moderately rapid and continuous flow of gas into one end of the line and vent the air out
the other end. The gas flow must be continued without interruption until the vented gas is free of air.
2) If the vent is in a location where the release of gas into the atmosphere may cause a hazardous
condition, then a slug of inert gas must be introduced between the gas and air. The gas flow must then
be continued without interruption until all of the air and inert gas have been removed from the facility.
The vented gases must be monitored and the vent must be closed before any substantial quantity of
28
combustible gas is released to the atmosphere.
3. Venting
Vent lines provided to exhaust the gas from the pressure relief valves to atmosphere must be extended to a
location where the gas may be discharged without undue hazard. Vent lines must have sufficient capacity
so that they will not inhibit the performance of the relief valve.
Article 116-12. Purge steam or gas

1. When pipeline segments are taken out of service for operational or maintenance purpose, it is common
practice to depressurize the pipeline and vent the natural gas to the atmosphere. To prevent these emissions,
partners reported using pigs and inert gas to purge pipelines.
In implementing this practice, a pig is inserted into the isolated section of pipeline. Inert gas is then
pumped in behind the pig, which pushes natural gas through the product line. At the appropriate shutoff
point, the pig is caught in a pig trap and the pipeline blocked off. Once the pipeline is “gas-free” the inert
gas is vented to the atmosphere.
2. For existing main:
1) Purge line with N2. Use detector in % Vol only (purge) mode (also measures O2) to verify that O2
reading is 0.5% or less, and gas reading 2% or less, to verify purge.
2) Open line and perform service. This will introduce air into the main.
3) Purge again with N2. Use detector in % Vol only mode (also measures O2) to verify that O2 reading is
0.5% or less.
4) Open upstream valve to charge line with gas. Use detector in % Vol only mode (also measures O2) to
verify that gas reading is 98% or more.
3. For new main:
1) Purge line with N2. Use detector in % Vol only mode (also measures O2) to verify that O2 reading is
0.5% or less, to verify purge of air from line.
2) Open upstream valve to charge line with gas. Use detector in % Vol only mode (also measures O2) to
verify that gas reading is 98% or more.
Article 116-13. Vent pipe

1. When new natural gas mains are installed or existing mains removed from service, crews must purge the
mains with an inert gas to eliminate the potential hazard of a combustible mixture. The most commonly
used and preferred purge gas is nitrogen. After the purge is conducted an upstream valve is opened to allow
natural gas to enter. A service valve on the line (usually a needle valve) with a stand pipe or diffuser
attached is cracked to allow venting gas or nitrogen to escape.
29
Photo- 15: Purging of gas pipeline Photo- 16: Purging of gas pipeline
http://www.csb.gov/newsroom/detail.aspx?nid=319 http://www.nao.com/txeasternpipeline.htm
Article 116-14. Vent valve and purge valve

1. “Blow” and “purge” are terms that have different definitions in various segment of the natural gas industry.
Blow (also called “blowdown”) emissions refer to the venting of natural gas contained inside a pressure
vessel, pipeline, or other equipment to the atmosphere. Purge is the process of clearing air from equipment
by displacing it with natural gas; in the process, some purge gas is emitted as the air is evacuated from the
equipment.
2. Maintenance activities requiring blowdown provide a safe working environment when it is necessary to
enter a vessel, in which case, all flammable gas must be removed. Linkewise, a reduction in the internal
flammable gas inventory may be required for external equipment maintenance. Conversely, when
equipment previously open to the atmosphere is placed back in cervices, air must be removed (or purged)
to prevent a flammable mixture of gas and oxygen. An operation may displaced the air directly with natural
gas or with an inert gas, such as nitrogen, and then displace the nitrogen with natural gas. Depending on the
specific company equipment and practices, an operator may also vent some of the nitrogen and natural gas
mixture to the atmosphere to reduce the inert gas concentration before the equipment is placed back in
service.
Photo- 17: Purging of gas pipeline Photo- 18: Venting station on natural gas
http://www.rkiinstruments.com/pages/application_briefs/Purge_ pipeline
Test_Procedure.htm
30
Article 116-15. Drain system
1. Installation of Service Lines
Where there is evidence of condensate in the gas in sufficient quantities to cause interruptions in the gas
supply to the customer, the service line shall be graded so as to drain into the main or to drips at the low
points in the service line.
Article 117. Material of gas transportation facility

Article 117-1. Material of Gas Transportation Facility
1. Material for pipeline and the like
Piping materials such as deformed straight pipe and bend for pipeline must conform to the following
standards (hereinafter so called “standard material”);
1) JIS B 2312（1997） “Steel butt-welding pipe fittings”

2) JIS B 2316（1997） “Steel socket-welding pipe fittings”
3) JIS B 2313（1997） “Steel plate butt-welding pipe fittings”
4) JIS B 2311（1997） “Steel butt-welding pipe fittings for ordinary use”
5) JIS G 3103（1987） “Carbon steel and molybdenum alloy steel plates for boilers and pressure vessels”
6) JIS G 3106（2004） “Rolled steels for welded structure”
7) JIS G 3114（1998） “Hot-rolled atmospheric corrosion resisting steels for welded structure”
8) JIS G 3115（1990） “Steel plates for pressure vessels for intermediate temperature service”
9) JIS G 3126（1990） “Carbon steel plates for pressure vessels for low temperature service”
10) JIS G 3131（1996） “Hot-rolled mild steel plates, sheet and strip”
11) JIS G 3201（1988） “Carbon Steel Forgings for General Use”
12) JIS G 3454（1988） “Carbon steel pipes for pressure service”
13) JIS G 3455（1988） “Carbon steel pipes for high pressure service”
14) JIS G 3456（1988） “Carbon steel pipes for high temperature service”
15) JIS G 3457（1988） “Arc welded carbon steel pipes”
16) JIS G 3458（1988） “Alloy steel pipes”
17) JIS G 3459（1997） “Stainless steel pipes”
18) JIS G 3460（1988） “Steel pipes for low temperature service”
19) JIS G 3461（1988） “Carbon steel boiler and heat exchanger tubes”
20) JIS G 3462（1988） “Alloy steel tubes for boiler and heat exchanger”
21) JIS G 3463（1994） “Stainless steel boiler and heat exchanger tubes”
22) JIS G 4051（1979） “Carbon steels for machine structural use”
23) JIS G 4303（1998） “Stainless steel bars”
24) JIS G 4304（1999） “Hot-rolled stainless steel plate, sheet and strip”
25) JIS G 4305（1999） “Cold-rolled stainless steel plate, sheet and strip”
26) JIS G 4312（1991） “Heat-resisting Steel Plates and Sheets”
31
27) JIS G 5101（1991） “Carbon steel castings”
28) JIS G 5102（1991） “Steel castings for welded structure”
29) JIS G 5111（1991） “High tensile strength carbon steel castings and low alloy steel castings for
structural purposes”
30) JIS G 5121（1991） “Corrosion-resistant cast steels for general applications”
31) JIS G 5122（1991） “Heat-resistant cast steels and alloys for general applications”
32) JIS G 5131（1991） “High manganese steel castings”
33) JIS G 5151（1991） “Steel castings for high temperature and high pressure service”
34) JIS G 5152（1991） “Steel castings for low temperature and high pressure service”
35) JIS G 3101（1995） “Rolled steels for general structure”
36) JIS G 3453-2（2007）“Coated steel pipes for water service-Part2: Fittings”
37) JIS G 3452（1997） “Carbon steel pipes for ordinary piping”
38) JIS G 5502（2001） “Spheroidal graphite iron castings”
39) JIS G 5526（1998） “Ductile iron pipes”
40) JIS G 5527（1998） “Ductile iron fittings”
41) JIS G 5705（2000） “Malleable iron castings”
42) JIS H 5202（1992） “Aluminum alloy castings”
43) JIS H 5302（1990） “Aluminum alloy die castings”
44) JIS K 6774（2005） “Polyethylene pipes for the supply of gaseous fuels”
45) JIS K 6775-1（2005）“Polyethylene pipe-fittings for the supply to gaseous fuels-Part 1: Heat fusion
fittings”
46) JIS K 6775-2（2005）“Polyethylene pipe-fittings for the supply to gaseous fuels-Part 2: Spigot
fittings”
47) JIS K 6775-3（2005） “Polyethylene pipe-fittings for the supply to gaseous fuels-Part 3: Electro
fusion fittings”
48) JIS H 3100（1992） “Copper and copper alloy sheets, plates and strips”
49) JIS H 3250（1992） “Copper and copper alloy rods and bars”
50) JIS H 3300（1997） “Copper and copper alloy seamless pipes and tubes”
51) JIS H 4311（1993） “Lead and lead alloy tubes for common industries”
52) JIS H 5120（1997） “Copper and copper alloy castings”
53) JIS H 5121（1997） “Copper alloy continuous castings”
54) JIS K 6741（1999） “Unplasticized poly vinyl chloride pipes”
55) JIS K 6742（1999） “Unplasticized poly vinyl chloride pipes for water supply”
56) JIS G 3443（1987） “Coated steel pipes for water service-Part 1: Pipes”
57) JIS G 3118（1987） “Carbon steel plates for pressure vessels for intermediate and moderate
temperature services”
58) ISO 3183（API 5L）（2007） “Line pipe”
32
Table- 8: Pipeline material stipulated in API 5L/ISO 3183
Grade YS min. /max. (MPa) TS min. /max. (MPa)
L245/B 245/ 450 415/ 760
L290/X42 290/ 495 415/ 760
L320/X46 320/ 525 435/ 760
L360/X52 360/ 530 460/ 760
L390/X56 390/ 545 490/ 760
L415/X60 415/ 565 520/ 760
L450/X65 450/ 600 535/ 760
L485/X70 485/ 635 570/ 758
L555/X80 555/ 705 625/ 825
L625/X90 625/ 775 695/915
L690/X100 690/ 840 760/ 990
L830/X120 830/ 1050 915/ 1145
Note: YS: Yield stress, TS: tensile strength
59) ASTM A694（2008） “Standard specification for carbon and alloy steel forgings for pipe flanges,
fittings, valves and parts for high-pressure transmission service”
60) ASTM standard material stipulated in Annex1-3 of the interpretation of technical regulation for gas
facility of Japan.
2. Use condition of the material listed above are as follows;

(1) Item-15) listed above can be used for those which the maximum operating pressure is less than 1.6MPa.
(2) Item-4), 35) to 43) and 56) listed above can be used for those which the maximum operating pressure is
less than middle pressure. However, item-42) and 44) must not be used for buried part.
(3) Item-44) to 47) can be used for the part where protection measures as shown in following 1) to 3) are taken
and the buried part where the maximum operating pressure is less than 0.3MPa. However, pipeline on the
land is admitted as a special temporally measure in emergency case such as disaster. Note that a temporary
period is until the restoration work is completed in case of disaster or other emergency.
1) A part from the rising or falling portion of pipeline engaging from underground to building and where
the sheath tube or other protective measures are taken.
2) A part of culvert or pit to engaging to pipeline into building and where the sheath tube or other
protective measures are taken.
3) A pipeline other than pipeline engaging into building and those which protective measure are taken.
(4) Item-48) to 55) listed above can be used for those which the maximum operating pressure is low. However,
33
they can not be used as follows;
1) Item-50) to 26), 54), 55) listed above for the buried part.
2) Item-48), 49), 52), 53) listed above for the buried part and there is risk to loading by vehicle.
3) Item-51), 26) listed above for other than the inlet part of gas meter and the part from gas meter to gas
tap.
4) Item-54), 55) listed above for the following condition;
a. Those which are installed in the inlet part of gas meter and the part from gas meter to gas tap.
b. Where other than flammable natural gas, liquefied petroleum gas and its reformed gas passing
through.
(5) The use condition of item-60) listed above must be applied those of equivalent JIS material.
3. Material of vessel for the gas generation facility (limited that a volume is more than 0.04m3 or inner
diameter is more than 200mm and length is more than 1,000mm) and which the maximum operating
pressure is more than 0.2MPa must be pursuant to the provision of gas generation facility.
4. Material of the gas pipeline for other than the gas generation facility (exclude control air piping and
instrument piping) must be pursuant to the provision of “Material for pipeline”.
5. Allowable stress
The allowable stress of the gas generation facility must be pursuant as follows;
(1) The allowable stress of gas generation facility must be pursuant to item-1) to item-7).
1) The JIS material stipulated in annex-1-1 and annex-2-1 of the interpretation for technical regulation of
gas facility, the WES material, ISO material, API material, ASTM material and those that are used
within the temperature range according to the allowable stress in the table.
2) The high tensile steel forgings to meet WES standard material that chemical composition, weld crack
susceptibity composition, mechanical properties and impact properties are stipulated in annex-1-1 of
the interpretation for technical regulation of gas facility and are used within the temperature range
according to the allowable stress in the table.
3) The ASME material stipulated in ASME Boiler & Pressure Vessel Code Sec. Ⅷ Div.1 (1998
Edition) that are used within the temperature range in such standard and is used within the
temperature range in the equivalent JIS material (same as stipulation of item-2)).
4) The ASTM material stipulated in annex-1-3 of the interpretation for technical regulation of gas
facility (limited to those there is equivalent ASME material in that table), that are used within the
stipulated temperature range in the equivalent JIS material (same as stipulation of item-2)). The
equivalent temperature range material means that are same range with ASME material.
34
5) The ASTM material stipulated in annex-1-3 of the interpretation for technical regulation of gas
facility (limited to those there is equivalent ASME material in that table), that are used within the
stipulated temperature range in the equivalent JIS material (same as stipulation of item-2)). The
equivalent temperature range material means that are same range with JIS material.
6) The material stipulated in annex-1-4 f the interpretation for technical regulation of gas facility and is
used within the temperature range according to the allowable stress.
7) The type-1 clad steel stipulated in JIS G3601-2002 “Stainless clad steel”, JIS G3602-1992 “Nickel
and nickel alloy clad steel”, JIS G3603 “Titanium clad steel”, JIS B3604 “Copper and copper alloy
clad steel” must be pursuant to JIS B8265-2008 “Construction of pressure vessel –General”.
(2) The allowable compressive stress of the material must be pursuant to “4.3.3: allowable compressive stress”
of JIS B8265-2008 “Construction of pressure vessel—General”.
(3) The allowable shearing stress of the material “4.3.2: allowable shearing stress” of JIS B8265-2008
“Construction of pressure vessel—General”.
(4) The allowable bending stress at each temperature which does not reach to creep range of material must be
pursuant to following item-1) to 3).
1) The allowable bending stress of carbon steel, low alloy steel and high alloy steel must be one of the
larger yield points at each temperature, half of the 0.2% tensile strength or allowable tensile stress at
each temperature.
2) The allowable bending stress of cast iron products must be 1.5 times of the allowable tensile stress
values at each temperature.
3) The allowable bending stress of spheroidal graphite cast iron, black heart malleable cast iron, ductile
iron cast iron, mareable cast iron and cast steel must be 1.2 times of the allowable tensile stress at
each temperature (1.0 times in case of austenitic stainless cast steel and ferritic stainless cast steel).
(5) The material for membrane gas holder must be pursuant to “3.4.3: allowable stress” of “Guideline
pertaining to the membrane gas holder”of “Chapter-3: design”.
6. The allowable tensile stress for the pipeline must be as follows;
(1) In case of the material listed 1) to 59) in Article 116-12, the allowable stress prescribed in the interpretation
of gas facility of Japan;
(2) Those for the material listed in Article 116-12-60) must be the value prescribed as follows;
1) The allowable stress of ASME standard material prescribed in ASME Boiler & Pressure Vessel Code
Sec.-8 Div. 1 (1998), if listing as ASME standard material.
2) The equivalent allowable stress of JIS standard material, if ASME standard material is not prescribed.
35
Article 118. Structure, etc. of gas facility
Article 118-1. Pipeline installed in the sea or on land
1. Design principles
The extent and detail of the design of a pipeline system must be sufficient to demonstrate that the integrity
and serviceability required by this International Standard can be maintained during the design life of the
pipeline system.
Representative values for loads and load resistance must be selected in accordance with good engineering
practice. Methods of analysis may be based on analytical, numerical or empirical models, or a combination
of these methods.
Principles of reliability-based limit state design methods may be applied, provided that all relevant ultimate
and serviceability limit states are considered. All relevant sources of uncertainty in loads and load
resistance must be considered and sufficient statistical data must be available for adequate characterization
of these uncertainties.
Reliability-based limit state design methods must not be used to replace the requirement in 10.2 for the
maximum permissible hoop stress due to fluid pressure.
Note: Ultimate limit states are normally associated with loss of structural integrity, e.g. rupture, fracture, fatigue or collapse, whereas
exceeding serviceability limit states prevents the pipeline from operating as intended.
2. Route selection
Route selection must take into account the design, construction, operation, maintenance and abandonment
of the pipeline in accordance with this International Standard. To minimize the possibility of future
corrective work and limitations, anticipated urban and industry developments must be considered. Factors
which shall be considered during route selection include:
1) safety of the public, and personnel working on or near the pipeline;

2) protection of the environment;
3) other property and facilities;
4) third-party activities;
5) geotechnical, corrosivity and hydrographical conditions;
6) requirements for construction, operation and maintenance;
7) national and/or local requirements;
8) future exploration.
3. Public safety
Pipelines conveying category B, C, D and E fluids must, where practicable, avoid built-up areas or areas
with frequent human activity. In the absence of public safety requirements in a country, a safety evaluation
must be performed in accordance with the general requirements of Annex A for:
36
1) pipelines conveying category D fluids in locations where multi-storey buildings are prevalent, where
traffic is heavy or dense, and where there may be numerous other utilities underground;
4. Environment

5. Other facilities
Facilities along the pipeline route which may affect the pipeline must be identified and their impact
evaluated in consultation with the operator of these facilities.
6. Surveys
6.1 Pipelines on land
Route and soil surveys must be carried out to identify and locate with sufficient accuracy the relevant
geographical, geological, geotechnical, corrosivity, topographical and environmental features, and other
facilities such as other pipelines, cables and obstructions, which could impact the pipeline route selection.
6.2 Offshore pipelines

Route and soil surveys must be carried out on the proposed route to identify and locate:
1) geological features and natural hazards;

2) pipelines, cables and wellheads;
3) obstructions such as wrecks, mines and debris;
4) geotechnical properties.
Meteorological and oceanographical data required for the design and construction planning must be
collected. Such data may include:
1) bathymetry;
2) winds;
3) tides;
4) waves;
5) currents;
37
6) atmospheric conditions;
7) hydrologic conditions (temperature, oxygen content, pH value, resistivity, biological activity,
salinity);
8) marine growth;
9) soil accretion and erosion.
7. Loads
7.1 General
Loads, which may cause or contribute to pipeline failure or loss of serviceability of the pipeline system,
must be identified and accounted for in the design. For the strength design, loads must be classified as:
1) functional; or
2) environmental; or
3) construction; or
4) accidental.
7.2 Functional loads

(1) Classification
Loads arising from the intended use of the pipeline system and residual loads from other sources must be
classified as functional.
Note：The weight of the pipeline, including components and fluid, and loads due to pressure and temperature are examples of
functional loads arising from the intended use of the system. Pre-stressing, residual stresses from installation, soil cover, external
hydrostatic pressure, marine growth, subsidence and differential settlement, frost heave and thaw settlement, and sustained loads
from icing are examples of functional loads from other sources. Reaction forces at supports from functional loads and loads due to
sustained displacements, rotations of supports or impact by changes in flow direction are also functional.
(2) Internal design pressure

The internal design pressure at any point in the pipeline system must be equal to or greater than the
maximum allowable operating pressure (MAOP). Pressures due to static head of the fluid must be included
in the steady-state pressures. Incidental pressures during transient conditions in excess of MAOP are
permitted, provided they are of limited frequency and duration, and MAOP is not exceeded by more than
10 %.
Note: Pressure due to surges, failure of pressure control equipment, and cumulative pressures during activation of over-pressure
protection devices are examples of incidental pressures. Pressures caused by heating of blocked-in static fluid are also incidental
pressures, provided blocking-in is not a regular operating activity.
(3) Temperature
The range in fluid temperatures during normal operations and anticipated blowdown conditions must be
38
considered when determining temperature-induced loads.
7.3 Environmental loads

(1) Classification
Loads arising from the environment must be classified as environmental, except where they need to be
considered as functional (see 7.2) or when, due to a low probability of occurrence, as accidental (see 7.4).
Examples: Loads from waves, currents, tides, wind, snow, ice, earthquake, traffic, fishing and mining are examples of environmental
loads. Loads from vibrations of equipment and displacements caused by structures on the ground or seabed are also examples of
environmental loads.
(2) Hydrodynamic loads

Hydrodynamic loads must be calculated for the design return periods corresponding to the construction
phase and operational phase. The return period for the construction phase must be selected on the basis of
the planned construction duration and season and the consequences of the loads associated with these
return periods being exceeded. The design return period for the normal operation phase should be not less
than three times the design life of the pipeline system or 100 years, whichever is shorter. The joint
probability of occurrences in magnitude and direction of extreme winds, waves and currents should be
considered when determining hydrodynamic loads. The effect of increases in exposed area due to marine
growth or icing shall be taken into account. Loads from vortex shedding shall be considered for aerial
crossings and submerged spanning pipeline sections.
(3) Earthquakes
The following effects shall be considered when designing for earthquakes;
1) direction, magnitude and acceleration of fault displacements;
2) flexibility of pipeline to accommodate displacements for the design case;
3) mechanical properties of the carrier pipe under pipeline operating pressure (conditions);
4) design for mitigation of pipeline stresses during displacement caused by soil properties for buried
crossings and inertial effects for above-ground fault crossings;
5) induced effects (liquefaction, landslides);
6) mitigation of exposure to surrounding area by pipeline fluids.
(4) Soil and ice loads

The following effects shall be considered when designing for sand loads:
1) sand dune movement;

2) sand encroachment.
The following effects shall be considered when designing for ice loads:
39
1) ice frozen on pipelines or supporting structures;
2) bottom scouring of ice;
3) drifting ice;
4) impact forces due to thaw of the ice;
5) forces due to expansion of the ice;
6) higher hydrodynamic loads due to increased exposed area;
7) effects added on possible vibration due to vortex shedding.
(5) Road and rail traffic

Maximum traffic axle loads and frequency shall be established in consultation with the appropriate traffic
authorities and with recognition of existing and forecast residential, commercial and industrial
developments.
7.4 Accidental loads

Loads imposed on the pipeline under unplanned but plausible circumstances must be considered as
accidental. Both the probability of occurrence and the likely consequence of an accidental load must be
considered when determining whether the pipeline should be designed for an accidental load.
Examples: Loads arising from fire, explosion, sudden decompression, falling objects, transient conditions during landslides,
third-party equipment (such as excavators or ship's anchors), loss of power of construction equipment and collisions.
7.5 Combination of loads

When calculating equivalent stresses (see 8.2), or strains, the most unfavorable combination of functional,
environmental, construction and accidental loads which can be predicted to occur simultaneously must be
considered.
If the operating philosophy is such that operations will be reduced or discontinued under extreme
environmental conditions, then the following load combinations must be considered for operations:
1) design environmental loads plus appropriate reduced functional loads;

2) design functional loads and coincidental maximum environmental loads.
Unless they can be reasonably expected to occur together, it is not necessary to consider a combination of
accidental loads or accidental loads in combination with extreme environmental loads.
8. Strength requirements--Calculation of stresses

8.1 Hoop stress due to fluid pressure
The circumferential stress, due to fluid pressure only (hoop stress), must be calculated from the following
40
formula:
 Do − t min 
σ hp = ( pid − p od ) 
 2t min 
Where
σhp : circumferential stress due to fluid pressure;

pid : internal design pressure;
pod : minimum external hydrostatic pressure;
Do : nominal outside diameter:
tmin : specified minimum wall thickness.
Note: The specified minimum wall thickness is the nominal wall thickness less the allowance for manufacturing per the applicable
pipe specification and corrosion. For clad or lined pipelines (see 8.2.3), the strength contribution of the cladding or lining is
generally not included.
Carbon steel line pipe must conform to ISO 3183-1, ISO 3183-2 or ISO 3183-3. ISO 3183-2 or ISO 3183-3
line pipe must be used for applications where fracture toughness is required by ISO 13623-8.1.5 and 8.1.6.
The design and internal corrosion evaluation must address whether the internal stainless steel or
non-ferrous metallic layer must be metallurgically bonded (clad) or may be mechanically bonded (lined) to
the outer carbon steel pipe. The minimum thickness of the internal layer must not be less than 3 mm in the
pipe and at the weld. The requirement of pipe-end tolerances closer than specified in the appropriate part of
ISO 3183 for welding must be reviewed and specified if deemed necessary.
8.2 Other stresses

Circumferential, longitudinal, shear and equivalent stresses must be calculated taking into account stresses
from all relevant functional, environmental and construction loads. Accidental loads must be considered as
indicated in 7.4. The significance of all parts of the pipeline and all restraints, such as supports, guides and
friction, must be considered. When flexibility calculations are performed, linear and angular movements of
equipment to which the pipeline has been attached must also be considered. Calculations must take into
account flexibility and stress concentration factors of components other than plain straight pipe. Credit may
be taken for the extra flexibility of such components. Flexibility calculations must be based on nominal
dimensions and the modulus of elasticity at the appropriate temperature(s). Equivalent stresses must be
calculated using the von Mises equation as follows:
41
σ eq = (σ h2 + σ i2 − σ hσ i + 3τ 2 )
1/ 2
Where
σeq : equivalent stress;

σh : circumferential stress;
σi : longitudinal stress;
τ : shear stress.
Equivalent stresses may be based on nominal values of diameter and wall thickness. Radial stresses may be
neglected when not significant.
9. Minimum thickness (See ASME B31.4—2006 404.1.2)
Pi × D
t=
2× S
Where
t : pressure design wall thickness ;

Pi : internal design gage pressure;
D : outer diameter of pipe
S : applicable allowable stress value;
(0.72×E×SMYS)
E : weld joint factor.
tn = t + A
Where
tn : nominal wall thickness satisfying

requirements for pressure and allowances;
t : pressure design wall thickness;
A : sum of allowances for threading, grooving
and corrosion protective measure
10. Strength criteria
10.1 General
42
Pipelines must be designed for the following mechanical failure modes and deformations:
1) excessive yielding;
2) buckling;
3) fatigue;
4) excessive ovality.
10.2 Yielding
The maximum hoop stress due to fluid pressure must not exceed:
σ hp ≤ Fh × σ y
Where
σhp : minimum hoop stress;

Fh : hoop stress design factor, obtained from
Table-6 for pipelines on land and Table-7 for
offshore pipelines;
σy : specified minimum yield strength (SMYS)
at the maximum design temperature.
Note: σy should be documented for design temperatures above 50 °C in accordance with 8.1.7.
The mechanical properties at the maximum operating temperature of materials for operations above 50 °C
must be documented unless specified in the referenced product standard or complementary justification.
Table- 9: Hoop stress design factors Fh for pipelines on land

Location Fh
(1)
General route 0.77
Crossings and parallel encroachments (2)
-Minor roads 0.77
-major roads, railways, canals, rivers, diked flood defenses and lakes 0.67
Pig traps and multi-pipe slug catchers 0.67
Piping in stations and terminals 0.67
Special constructions such as fabricated assemblies and pipelines on bridges 0.67
The hoop stress factors of following table must apply for category D and E pipelines to be designed to meet
the requirements of annex-B.
43
Location Fh
These factors apply to pipelines pressure-tested with water. Lower design factors may be necessary when
tested with air.
(1) The hoop stress factor may be increased to 0.83 for pipelines conveying category C and D fluids at
locations subject to infrequent human activity and without permanent human habitation (such as deserts
and tundra regions)
(2) See ISO 13623-6.9 for the description of crossings and encroachments.
Reference: 6.4.2.2 of ISO 13623-2000
Table- 10: Hoop stress design factors Fh for offshore pipelines

Location Fh
General route (1) 0.77
Shipping lanes, designated anchoring areas and harbor entrances 0.77
Landfalls 0.67
Pig traps and multi-pipe slug catchers 0.67
Risers and station piping 0.67
(1) The hoop stress factor may be increased to 0.83 for pipelines conveying category C and D fluids.
Reference: 6.4.2.2 of ISO 13623-2000
Fluid category D E D and E

Location class 1 1 2 3 4 5
General route 0.83 0.77 0.77 0.67 0.55 0.45
Crossing and parallel encroachments (1)
- minor roads 0.77 0.77 0.77 0.67 0.55 0.45
- major roads, railway, canals, rivers, diked, flood 0.67 0.67 0.67 0.67 0.55 0.45
defenses and lakes
Pig traps and multiple slug catchers 0.67 0.67 0.67 0.67 0.55 0.45
Piping in stations and terminals 0.67 0.67 0.67 0.67 0.55 0.45
Special constructions such as fabricated assemblies 0.67 0.67 0.67 0.67 0.55 0.45
and pipelines on bridges
(1) See ISO 13623-Annex B-6.9-2000 for the description of crossings and encroachments.
Reference: Annex-B of ISO 13623-2000
44
The maximum equivalent stress must not exceed.
σ hp ≤ Fh × σ y
Where
σhp : minimum hoop stress;

Fh : equivalent stress design factor, obtained
from Table-8.
σy : specified minimum yield strength (SMYS)
at the maximum design temperature.
Table- 11: Equivalent stress design factors Feq

Location Feq
Construction and environmental 1.00
Functional and environmental 0.90
Functional, environmental and accidental 1.00
Reference: 6.4.2.2 of ISO 13623-2000
The criterion for equivalent stress may be replaced by a permissible strain criterion where:
1) the configuration of the pipeline is controlled by imposed deformations or displacements; or

2) the possible pipeline displacements are limited by geometrical constraints before exceeding the
permissible strain.
A permissible strain criterion may be applied for the construction of pipelines to determine the allowable
bending and straightening associated with reeling, J-tube pull-ups, installation of a bending shoe riser and
similar construction methods.
A permissible strain criterion may be used for pipelines in service for:
1) pipeline deformations from predictable non-cyclic displacement of supports, ground or seabed, such
as fault movement along the pipeline or differential settlement;
2) non-cyclic deformations where the pipeline will be supported before exceeding the permissible strain,
such as in case of a pipeline offshore which is not continuously supported but with sagging limited by
the seabed;
3) cyclic functional loads provided that plastic deformation occurs only when the pipeline is first rose to
its “worst-case” combination of functional loads and not during subsequent cycling of these loads.
45
The permissible strain must be determined considering fracture toughness of the material, weld
imperfections and previously experienced strain. The possibility of strain localization, such as for
concrete-coated pipelines in bending, must be considered when determining strains.
Note: BS 7910 provides guidance for determining the level of permissible strain.
10.3 Buckling
The following buckling modes must be considered:
1) local buckling of the pipe due to external pressure, axial tension or compression, bending and torsion,
or a combination of these loads;
2) buckle propagation;
3) restrained pipe buckling due to axial compressive forces induced by high operating temperatures and
pressures.
Note: Restrained pipe buckling can take the form of horizontal snaking for unburied pipelines or vertical upheaval of trenched or
buried pipelines.
10.4 Fatigue
Fatigue analyses must be performed on pipeline sections and components that may be subject to fatigue
from cyclic loads in order to:
1) demonstrate that initiation of cracking will not occur; or

2) define requirements for inspection for fatigue.
Fatigue analyses must include a prediction of load cycles during construction and operation and a
translation of load cycles into nominal stress or strain cycles.
The effect of mean stresses, internal service, external environment, plastic prestrain and rate of cyclic
loading must be accounted for when determining fatigue resistance.
Assessment of fatigue resistance may be based on either S-N data obtained on representative components
or a fracture mechanics fatigue life assessment.
The selection of safety factors must take into account the inherent inaccuracy of fatigue-resistance
predictions and access for inspection for fatigue damage. It may be necessary to monitor the parameters
causing fatigue and to control possible fatigue damage accordingly.
10.5 Ovality
Ovality or out-of-roundness that could cause buckling or interference with pigging operations must be
avoided.
46
(1) Stability
Pipelines must be designed to prevent horizontal and vertical movement, or must be designed with
sufficient flexibility to allow predicted movements within the strength criteria of this International
Standard. Factors which must be considered in the stability design include:
1) hydrodynamic and wind loads;

2) axial compressive forces at pipeline bends and lateral forces at branch connections;
3) lateral deflection due to axial compression loads in the pipelines;
4) exposure due to general erosion or local scour;
5) geotechnical conditions including soil instability due to, for example, seismic activity, slope failures,
frost heave, thaw settlement and groundwater level;
6) construction method;
7) trenching and/or backfilling techniques.
Note: Stability for pipelines on land can be enhanced by such means as pipe mass selection, anchoring, and control of backfill
material, soil cover, soil replacement, drainage, and insulation to avoid frost heave. Possible stability improvement measures for
subsea pipelines are pipe mass, mass coating, trenching, burial (including self-burial), gravel or rock dumping, anchoring and the
installation of mattresses or saddles.
11. The joint method of pipeline must be pursuant as follows;

11.1 The joint method must be pursuant to the method listed in the right column depending on the classification
of maximum allowable operation pressure listed in the left column and the type of material of pipeline
listed in middle column. The measure to prevent the extraction means the measure to prevent extraction by
means of those which have the function by spigot, lock ring, ball band and gland, method by stay and
protection n by pile and concrete.
Table- 12: Joint method of pipeline

Classification of Type of material
maximum operating Joint method
pressure (MPqa) for pipeline
Very high pressure Welding, flange joint

Steel pipe
(7.0 ≤ P)
High pressure Welding, flange joint or mechanical joint (limited to those that
Steel pipe prevention measures have been taken out of the extraction.)
(1.0 ≤ P < 7.0)
Welding, flange joint or mechanical joint (limited to those that
Steel pipe
Middle pressure (1) prevention measures have been taken out of the extraction.)
0.3 ≤ P < 1.0 Welding, flange joint or mechanical joint (limited to those that
Cast iron pipe
prevention measures have been taken out of the extraction.)
47
Classification of Type of material
maximum operating Joint method
pressure (MPqa) for pipeline

Steel pipe prevention measures have been taken out of the extraction.) or gas
type joint.
Middle pressure (2) Welding, flange joint or mechanical joint (limited to those that
0.2 ≤ P < 0.3 Cast iron pipe prevention measures have been taken out of the extraction.) or gas
type joint.
Fusion joint, mechanical joint (limited to those that prevention
Polyethylene pipe
measures have been taken out of the extraction.).
prevention measures have been taken out of the extraction.) or gas
Steel pipe
type joint, union joint, bite fitting or taper joint (limited to the joint
of polyethylene pipe and tube or vinyl chloride).
Cast iron pipe prevention measures have been taken out of the extraction.) or gas
Low pressure type joint.
(P < 0.2) Hard vinyl chloride Fusion joint, mechanical joint (limited to those that prevention
pipe or measures have been taken out of the extraction.) or gas type joint.
polyethylene pipe
Flange joint, mechanical joint, union joint, brazing, bite fitting or
Steel or brass pipe flair joint.
Lead pipe Mechanical joint.
Reference: Article 41 of guideline for gas facility Japan
12. Support for pipeline

(1) The pipeline which is installed on a dedicated bridge, etc. must be supported by the safety supporting
structure against wind force and earthquake, etc.
(2) The pipeline installed in the building must be supported by safety support methods against earthquake.
13. Measures for prevention damage due to uneven settlement

(1) The pipeline installing in the soft ground and installing in the place to penetrate outer wall of building must
be taken the measures to prevent damage due to uneven settlement pursuant to the following about entire
piping system of pipeline and by the way how to combine two or more appropriately.
1) The method to absorb the displacement by the flexibility using a steel pipe jointed by welding or a
polyethylene pipe jointed by fusion joint.
2) The method to absorb the displacement by the flexibility in the strait part using a mechanical joint
having a displacement absorption capacity.
3) The method to absorb the displacement by the flexible combination of bends by means of screw joint,
mechanical joint or welding joint.
4) The method to use expansion joint.
5) The method to absorb the displacement by the gap between pipeline and sheath tube by means of
installing pipeline in the sheath tube.
48
14. Supports for Buried Piping
In pipelines, especially those that are highly stressed from internal pressure, uniform and adequate support
of the pipe in the trench is essential. Unequal settlements may produce added bending stresses in the pipe.
Lateral thrusts at branch connections may greatly increase the stresses in the branch connection itself,
unless the fill is thoroughly consolidated or other provisions are made to resist the thrust. Rock shield shall
not be draped over the pipe unless suitable backfill and padding are placed in the ditch to provide a
continuous and adequate support of the pipe in the trench.
Photo- 19: Natural gas pipeline on land Photo- 20: Natural gas pipeline on land
http://theuglytruth.wordpress.com/2011/07/30/us-israeli-mercen http://www.txchnologist.com/2011/the-clean-fossil-fuel-natural-
aries-blow-up-iran-turkey-gas-line/ gas-under-fire
Photo- 21: Natural gas wellhead Photo- 22: Shutoff valve for Natural gas pipeline
http://www.mjpaintingcontractor.com/gaswellheads.htm http://www.exponent.com/gas_processing_monetization/
15. Measures to absorb expansion

(1) The pipeline other than those which is buried underground ( except that is installed in the culvert and
exposed by drilling) must be taken measure to absorb expansion due to the change in temperature by the
either method listed in the following items or in combination.
49
1) The measure to absorb the change in length by a flexible piping system such as expansion joint
(bellows type, dresser type and including telescopic tube), loop pipe, bend pipe, etc.
2) The measure to absorb thermal stress generated in the pipeline in the allowable stress.
16. Stability of the pipeline to be installed on the seabed

(1) It is deemed that the pipeline designated based on DNV RP W305 “On-bottom stability design of
submarine pipelines” does not move.
(2) The pipeline must have harmful vibration. In addition, it is deemed that the pipeline designated based on
DNV Guideline14 “Free spanning pipelines” have no harmful vibration.
17. Construction of submarine pipeline
(1) The construction standard of pipeline which is installed deeper than 50m water depth (herein after so called
“submarine pipeline”) must be pursuant to follows;
1) The upper limit of the stress generated by the assumed combination load must not exceed 90.0% of the
yield point of the material.
2) The design factor (percentage of the material yield point of circumferential stress occurs when it took
pressure) must not exceed 0.72.
3) The thickness of pipe must be more than equal to 12.5mm.
4) The high-speed ductile fracture must be capable to stop.
(2) The method to joint pipeline must be welding.
Photo- 23: Laying off-sore pipeline Photo- 24: Welding of off-shoe pipeline
http://maritimecollectibles.prestigious-hosting.com/2011/07/12/n http://www.sciencephoto.com/media/153281/enlarge
igeria-brass-lng-opens-bid-for-subsea-pipeline-construction/
50
Photo- 25: Laying off-sore pipeline Photo- 26: Welding of subsea pipeline
http://www.gazprom.com/press/news/2010/april/article97626/ http://rangeroffshoreinc.com/pipeline_subsea_construction.htm
Article 118-2. Pressure part

1. The “pressure part” of the gas pipeline must be pursuant the definition in the design technical regulation
Article 118-1.
Article 118-3. Air-tightness

1. General
Pipeline systems must be pressure-tested in place after installation but before being put into operation to
demonstrate their strength and leak-tightness. Prefabricated assemblies and tie-in sections may be pretested
before installation provided their integrity is not impaired during subsequent construction or installation.
The requirements for pressure testing can govern the necessary pipe wall thickness and/or steel grade in
terrain with significant elevations.
2. Test medium
Test medium available, when disposal of water is not possible, when testing is not expedient or when water
contamination is unacceptable. Pneumatic tests (when necessary) may be made using air or a non-toxic gas
as shown in Photo-85, 86.
Photo- 27: Compressor for pressure test Photo- 28: Compressor for pressure test
http://www.aabbxair.com/about.html http://www.atlascopco.us/hurricane/applications/pipeline/
51
3. Pressure test requirements
Pressure tests shall be conducted with water (including inhibited water), except when low ambient
temperatures prevent testing with water, when sufficient water of adequate quality cannot be made.
Note: Rerouting of short pipeline sections or short tie-in sections for pipelines in operation are examples of situations for which
pressure tests with water may not be expedient.
4. Pressure levels and test durations

The pipeline system must be strength-tested, after stabilization of temperatures and surges from
pressurizing operations, for a minimum period of 1h with a pressure at any point in the system of at least:
1) 1.25 × MAOP for pipelines on land; and

2) 1.25 × MAOP minus the external hydrostatic pressure for offshore pipelines.
If applicable, the strength test pressure must be multiplied by the following ratios:
1) the ratio of σy at test temperature divided by the derated value for σy at the design temperature in case
of a lower specified minimum yield strength σy at the design temperature than exists during testing;
and
2) the ratio of tmin plus corrosion allowance divided by tmin in case of corrosion allowance.
The strength test pressure for pipelines conveying category C and D fluids at locations subject to infrequent
human activity and without permanent habitation may be reduced to a pressure of not less than 1.20 times
MAOP, provided the maximum incidental pressure cannot exceed 1.05 times MAOP.
Following a successful strength test, the pipeline system shall be leak-tested for a minimum period of 8h
with a pressure at any point in the system of at least:
1) 1.1 × MAOP for pipelines on land; and

2) 1.1 × MAOP minus the external hydrostatic pressure for offshore pipelines.
The strength and leak test may be combined by testing for 8 h at the pressure specified above for strength
testing. The requirement for a minimum duration of a leak test is not applicable to pipeline systems
completely accessible for visual inspection, provided the complete pipeline is visually inspected for leaks
following a hold-period of 2h at the required leak-test pressure. The additional test requirements of clause
B.6 must apply for category D and E pipelines to which Annex B of ISO 13623-2000 applies.
5. Acceptance criteria
Pressure variations during strength testing must be acceptable if they can be demonstrated to be caused by
factors other than a leak. Pressure increases or decreases during leak testing must be acceptable provided
52
they can be demonstrated through calculations to be caused by variations in ambient temperature or
pressure, such as tidal variation for offshore pipelines. Pipelines not meeting these requirements must be
repaired and retested in accordance with the requirements of this International Standard.
Article 118-4. Foundation

1. When openings are made in a consolidated backfill to connect new branches to an existing line, care must
be taken to provide firm foundation for both the header and the branch to prevent vertical and lateral
movements.
Article 119 Welding part of gas transportation facility

Article 119-1. Welding of pipeline
1. Welding of pipeline must be performed according to the proven and reliable international standards such as
ISO 13847, API 1104, JIS Z3104, ASME Section-9 or EN 3480.
Photo-29, 30 and 31 shows the arc welding procedure, Photo-34 shows the Tig welding procedure and
Photo-33 shows the flash-butt welding procedure.
Photo- 29: Arc welding of buried pipeline Photo- 30: Arc welding of pipeline on the land
http://teeic.anl.gov/er/transmission/activities/act/index.cfm http://www.gazprom.com/press/news/2011/july/article115149/
Photo- 31: Mig welding Photo- 32: Arc welding

http://www.indiazooms.com/?p=2896 http://rattlestan.com/projects.html
53
Photo- 33: Flash butt welding Photo- 34: Tig welding
http://www.pskovelectrosvar.ru/pages_en.html?id=28 http://newsroom.lincolnelectric.com/Image/Awards+Events/
Article 119-2. Welding procedure

1. “Welding” must be pursuant to as follows;
(1) Welding of pipeline must be performed according to the appropriate WPS.

(2) Welding equipment such as the welding machine, dryer, and windbreak must conform to the welding
method or welding conditions specified in WPS.
(3) Welding or consumables such as the welding rod, welding wire, flux, electrode and seal gas must conform
to WPS.
(4) A butt weld must be applied for the mains. And V-shape or U-shape groove must be applied to welding
joint shape.
Article 119-3. Welding management

1. The appropriate measure to obtain good circumstance for welding such as wind break, waterproof, lighting,
worming equipment must be provided as shown in Photo-35 and 36.
Photo- 35: Welding house Photo- 36: Welding tent

http://www.gazprom.com/production/projects/pipelines/shvg/ http://www.weldcrawler.com/pipeline-welding/
54
Article 120. Safety valve of gas transportation facility
Article 120-1. Safety valve
1. The following formulae extracted from API Recommended Practice 520 are provided to enable the
selection of effective discharge areas. The effective discharge areas will be less than the actual discharge
areas, therefore these formulae must no be used for calculating certified discharge capacities. After
determining the required effective area selected from Table-16 the orifice with an area equal to or greater
then the required effective discharge area.
W T ×Z
A= ×
0.00759 × C × K d × P1 × K b M
Where
(Metric units)
A : required effective discharge area of the valve mm2

W : flow rate kg/h
C : Coefficient determined from an expression of the ratio of the —
specific heats of the gas or vapour at standard conditions. (see
Table-**)
k :ratio of specific heats for an ideal gas
Kd : effective coefficient of discharge related to the effective flow areas —
acc. To API 526;
for steam, gases and vapours (=0.975)
P1 : relieving pressure: for liquids (= set pressure+allowable bar
overpressure)
Kb : capacity correction factor due to back pressure (for balanced —
bellows values and gases vapour only)
with back pressure < 20% P1 (=1)
T :Relieving temperature K
Z :Compressibility factor for the deviation of the actual gas from a —
perfect gas (Z=1 for a perfect gas)
M : Molecular weight of the gas or vapour —
55
Table- 13: Effective areas acc. to API 526
Orifice Effective areas (mm2)
D 71
E 126
F 198
G 324
H 506
J 830
K 1,185
L 1,840
M 2,322
N 2,800
P 4,116
Q 7,129
R 10,322
T 16,774
Table- 14: Values of coefficient C

k C
1.01 317
1.05 321
1.10 327
1.15 332
1.20 337
1.25 342
1.30 347
1.35 352
1.40 356
1.45 360
1.50 365
1.55 369
1.60 373
1.65 376
1.70 380
1.80 387
1.90 394
2.00 400
56
Article 121. Instrument device, etc. for gas transportation facility
Article 121-1. Instrument device
1. “Appropriate instrumentation equipment to measure and check” stipulated in design technical regulation
Article 121-1 means those which is capable to measure and confirm following items;
(1) Those which is capable to measure the following matters, with regard to the gas generation facility which
the maximum operation pressure is low.
1) Flow rate and pressure, in case of those which the raw material is petroleum, liquefied petroleum gas
or natural gas.
2) Air flow or pressure, in case of burning a part of raw material with air into furnace.
3) Flow rate and pressure (outlet temperature, with regard to those having steam saturation tower), in
case of those which use steam.
4) Furnace pressure and outlet temperature of reactor or furnace, in case those which has reactor.
5) Pressure, in case of those which use fluid to operate the autopilot.
the maximum operation pressure is high or medium.
or natural gas.
2) Flow rate and pressure, in case of those which use steam to generate gas.
3) Inlet and outlet temperature, and inlet and outlet pressure of reactor.
4) Flow rate and pressure of fuel, in case of the external type thermal reactor.
5) Liquid surface, in case of condensed water separator which have construction to discharge water by
hand.
(3) Those which is capable to measure the stored gas capacity, with regard to the gasholder which maximum
operating pressure is low.
(4) Those which are capable to measure the stored gas pressure, with regard to the gasholder which maximum
operating pressure is middle and high.
(5) Following matters, with regard to the blower and compressor.
1) Those which are capable to measure outlet gas temperature.

2) Those which are capable to measure inlet and discharge gas pressure of compressor.
3) Those which are capable to measure temperature and pressure of lubricant, in case of those that have
forced lubrication equipment.
57
4) These which are capable to measure flow of its cooling water, in case of those that have blower or
compressor that has construction applying cooling water.
2. The level gauge used for paragraph-1 must be the tubular glass gauge (measures to prevent destruction of
glass tube must be taken and automatic and manual stop valve on the connection pipe must be provided),
Klinger type liquid level gauge, float type liquid level gauge, differential pressure type liquid level gauge,
capacitive type liquid level gauge, displacer type liquid level gauge, radio type liquid level gauge,
ultrasonic type liquid level gauge or those which has the function of safety and equal to greater than them.
Those which use glass must be used the glass stipulated in JIS B8211 “boiler water gauge glass” or a glass
having strength equal to greater than them (pressure resistance, thermal shock resistance and corrosion
resistance). However, other than tubular glass gauge must be applied to the gas facility which passing
through high pressure gas or liquefied gas.
Article 122. Warning device for transportation facility

Article 122-1. Warning device
1. “Appropriate warning device” stipulated in design technical regulation Article 122-1 means those
pursuant as follows. However, if the equipment doesn’t be such state, this must not be applied.
(1) In case of the gas generation facility, the following cases;
1) When the pressure of operation fluid drops abnormally, with regard to those which use fluid to
operate the autopilot equipment.
2) When the water supply to the water seal vessel stop or the liquid surface of the water seal vessel drops
abnormally, with regard to those which has the water seal vessel.
3) When the pressure of steam drops abnormally, with regard to those which feed steam into the furnace.
4) When the pressure of combustion gas drops abnormally, with regard to those which feed air into
furnace and burn a part of raw material.
5) When the pressure of fed fuel drops abnormally, with regard to those which is heated externally.
6) When the pressure of the part where gas passing raises abnormally, with regard to those which is high
pressure or middle pressure.
(2) When the gas pressure raises abnormally, with regard to the gas purification facility that the maximum
operation pressure is high or medium.
(3) When the amount of gas storage has decreased abnormally, with regard to the gasholder that the maximum
operation pressure is low (limited to those which discharge gas by blower or compressor).
(4) When the hydraulic pressure of the lubricating oil has dropped abnormally, with regard to the blower and
compressor (limited to those which has the external forced lubricating equipment).
58
Article 123. Fail-safe control and interlock for gas transportation facility
Article 123-1. Fail-safe control
1. “Measures to prevent mistake and to ensure the operation” stipulated in design technical regulation Article
123-1 means as follows;
(1) The shutoff device must be indicated the open or close direction (which has important impact on the safety
in the gas facility, including the indication it’s open or close status) must be explicit.
(2) The piping related to the emergency shutoff device (except those can be operated by operation button )
which has important impact on the safety in the gas facility must be provided the type and direction of gas
or other fluid in the pipe by the method can be easily distinguished adjacent to the shutoff device.
(3) The emergency shutoff device which has important impact on the safety in the gas facility and is not used
in normal (except those used for emergency) must be locked; sealed and similar measures must be taken.
Article 123-2. Interlock

1. Many routine pipeline operating procedures are potentially dangerous if executed incorrectly or in unsafe
conditions, with the scope for injury and/or damage significantly increased when high temperature, high
pressure or toxic/flammable product is present.
Key interlock systems are dual-keyed mechanical locking devices which operate on a 'key transfer'
principle to control the sequence in which process equipment may be operated. They are widely accepted
as an effective safety management tool and are being adopted by many of the world’s oil, gas and
chemicals majors. Interlocks are also recommended in a number of internationally recognized standards for
specific process applications including:
1) API RP 14E - Design & Installation of Offshore Production Platform Piping Systems (Para. 5.8. b2) -
Relief Device Piping.
2) API RP 520 - Pressure Relieving Systems for Refinery Services (Part II: Section 4 - Isolation Valve
Requirements).
3) NFPA 12 - National Fire Protection Association (USA) - Carbon Dioxide Extinguishing Systems -
1993 Edition.
4) BS 5306 - British Standard - Part 4 1986 - Specification for Carbon Dioxide Systems.
5) BS 8010 - Code of Practice for Pipelines (Part 2 1992 - Sect. 2.8).
6) BS 8010 - Code of Practice for Pipelines (Part 3 1993 - Sect. 6.6).
7) 1996 No. 825 - (UK) The Pipelines Safety Regulations (Section 6 - Para. 37 of Guidance on
Regulations - published by UK Health & Safety Executive).
Key interlocks date back to the 1890's where they were first used in the French railway system to control
track switching operations. Modern key interlock systems for oil and gas, chemical processing and
pipelines systems did not emerge until the early 1980's. Since then, acknowledgement of their effectiveness
59
has led to increasing levels of usage and growing recommendations within international standards and
codes of practice. The hardware is relatively simple and is based on specialized mechanical locks designed
as integral-fit attachments to the host equipment.
Typically they are applied to valves, closures, switches or any form of equipment which is operated by
human intervention. The 'open’ or 'closed' status of an interlocked valve, or the 'on’ or 'off' status of an
interlocked switch can only be changed by inserting a unique coded key; inserting the key unlocks the
operating mechanism (e.g. handwheel or push-button) enabling operation of the valve or switch.
Operating the unlocked equipment immediately traps the initial (i.e. inserted) key; when the operation is
complete, a secondary (previously trapped) key may then be released thereby locking the equipment in the
new position. This secondary key will be coded in common with the next lock (item of equipment) in the
sequence. By this simple coded key transfer principle a ‘mechanical logic' system is created which denies
any scope for operator error.
While padlocks and chains provide a lock-off capability, they do not provide any control over the sequence
of operations, nor do they assure or confirm the status of the equipment to which they are fixed. So,
removing a key from a padlock ensures neither that the equipment is locked nor its ‘open/closed' or 'on/off'
status. While a padlock and chain may be suitable and sufficiently robust in low risk applications, they
have virtually no mechanical integrity and are a minimal solution offering (at best) a visual restriction
against unauthorized operation.
Mechanical key interlock systems are ideally suited for integration with Permit-to- Work (PtW)
procedures; indeed, the Cullen Report on the public inquiry into the Piper Alpha offshore rig disaster
(1990) strongly recommends the use of locking systems integrated with PtW procedures, especially where
routine procedures cannot be accomplished in the time-scale of a single work shift.
In the same vein, ongoing surveillance of the UK chemicals industry by the Health & Safety Executive
(HSE) found that one third of all accidents in the chemical industry were maintenance related – the most
significant factor being the absence of, or an inadequacy in, PtW systems.
In addition to the standards referred to earlier, the Technical Guidance Notes (published by the HSE)
supporting interpretation of the UK Pipeline Safety Regulations (1996) Act [PSR 1996] recommend
interlocks as a suitable safety system in the operation of pig traps.
http://www.smithflowcontrol.com/new/Downloads/news/SFC02-06-Pipeline-article.pdf
60
Article 124. Back-up power, etc. for gas transportation facility
Article 124-1. Back-up power
1. “Safety apparatus needed to safely close the incoming gas and transportation facility” stipulated in design
technical regulation Article124-1 must be pursuant as follows;
1) Emergency lighting system.

2) Equipment to ensure rapid communication in case of emergency (except telephone subscriber
equipment)
3) Fire prevention and firefighting equipment.
4) Gas leak detection and alarm equipment.
5) Emergency shutoff valve.
6) Emergency shutoff device.
7) Cooling equipment.
8) Water spraying system or equivalent facility that has the capacity to prevention of fire and
firefighting.
9) Water spraying system or equivalent facility that is effective for fire prevention.
Article 125. Measure of odor for gas transportation facility

Article 125-1. Confirmation of odor
1. “Odor in order for easy detection” and “it is possible to detect odor” stipulated in design technical
regulation Article 125-1 means that it is possible to confirm smell 1/1000 gas in the air by volume mix
ratio measured in any of the following method and frequency.
(1) In case of the panel method, the odor concentration in the gas must be found by means of preparing a dilute
gas by either of following method, determining the presence or absence of odor by 4 or more judge having
a normal sense of smell, obtaining the perceived dilution from dilution of each panel that was able to sense.
However, if there is data of less than 1/10 times or more than 10 times of its arithmetic mean value which
are determined from arithmetic mean value of the perceived dilution of each panel, such data must not
adopted.
1) In case of the odor meter method, to mix the test gas flow into constant flow of odorless air.
2) In case of the syringe method, to collect a certain amount of test gas in the syringe and dilute by
odor-free air transferring into syringe for dilution.
3) In case of the sachet method, to add test odor gas into the sachet that filled with 3 liters of odorless air
by syringe.
(2) In case of the measurement method of odorant concentration, the odor concentration in the gas must be
determined using conversion formula (linear regression equation) from odorant concentration in the gas
61
(mg/m3) that is measured by either of the following methods. The conversion formula must be calculated
using the data which are measured standard odor concentration and odorant concentration at the same time
(hereinafter referred to “measurement data”) according to the methods listed in the right column of the
table and the classification of either of following listed in the left column of the table. Administrative value
of the odor concentration in this method must be more than 2,000 times (smell can be checked in the
mixing volume ratio of gas in the air in a 1/2,000).
1) In case of FPD gas chromatograph method, it must meet “5.2.3: analysis conditions” of JIS K0091
“Gas analysis method of carbon disulfide in the exhaust gas”.
2) In case of the detector tube method, the detection tube to meet JIS K0804 “Detector tube type gas
detector”.
3) In case of the THT instrument method, a certain amount of test gas must be passed through a certain
amount of absorption solution containing iodine, generated complex (THT-iodine) and the degree of
absorption at 308nm of the complex must be measured.
Table- 15: Calculation of rate equation

Classification Calculation method
In case the odorant is not 1: When calculating the rate of equation, data
contained in the gas prior must be taken back and forth of odorizer.
to the most downstream However, if the standard odorant concentration
odorizer, is 1,000 times and more (it is possible to
confirm smell in 1/1,000 volume mix ratio gas
in the air), it can be calculate the odor
concentration before odorizing as zero after
taking data back and forth of such odorizer.
In case the odorant is In case such odorant is Ditto
contained in the gas forth same as the odorant
of the most downstream which is added by gas
odrizer, producer,
Ditto In case such odorant is 2: When calculating the rate of equation, data
different with the odorant must be taken back and forth of odorizer. The
which is added by gas odor concentration of produced gas back and
producer, forth of odorizer must be measured after
creating a conversion formula for the odorant
added by the gas producer.
(1) The odor concentration of production gas
forth of odorizer must be calculated from the
odor concentration of production such gas.
(2) The rate equation in case of no measurement
of the odor concentration of production gas
prior to odorizer must be calculated as the
odor concentration forth of odorizer zero.
In case the odorant is not 3: It must be calculated according to 1: assuming
added in gas production the gas backward of odrizer.
plant by gas producer,
62
2. The measurement of odor concentration must be performed at least once a month in the place where odor
concentration in the supply gas can be measured (exit of gas generation facility or exit of the factory which
receive gas from others by pipeline).
3. The stipulation as follow means “those which can be perceived presence or absence of odor gas in the air
with mixing volume ratio 1/1,000.” “Baseline” means those which can be perceived smell in case that gas in
the air mixing volume ratio is 1 in 1,000.
(1) In case of gas generation facility or gas factory which is supplied gas from others by pipeline, the writing
which certifies the odor concentration in the supplied gas beyond the standard level.
Article 126. General provision for gas generation facility

1. Natural gas which is drilled in the onshore or offshore gas field is used directly for the gas-fired thermal
power plants or GTCC plants. In addition, natural gas as shown in Table-2 is imported in the state of
liquefied gas after desulfurization for the country where does not produce natural gas.
2. City gas is produced at gas production plant from natural gas, liquefied natural gas, liquefied petroleum gas,
naphtha and coal, and is used as household fuel. Also, city gas is used as the main fuel for small power
generation facilities or emergency power generation facilities, if they don’t have a fuel storage facility.
Table- 16: Classification of city gas

Heating value
Classification of gas 3
(kcal/m ) (kJ/m3)
13A 10,000 ~15,000 41,861 ~ 62,791
12A 9,070 ~11,000 37,967 ~ 46,047
6A 5,800 ~7,000 24,279 ~ 29,302
City gas 5C 4,500 ~5,000 18,837 ~20,930
L1 (6B, 6C, 7C) 4,500 ~5,000 18,837 ~ 20,930
L2 (5A, 5B, 5AN) 4,500 ~5,000 18,837 ~ 20,930
L3 (4A, 4B, 4C) 3,600 ~4,500 15,070 ~18,837
LP gas ― ― ―
Reference: http://home.tokyo-gas.co.jp/userguide/shurui.html
3. On the other hand, it is believed that the use of coal seam gas (CBM: Coalbed Methane) or gasified gas
from coal or underground coal such as Fig-9 in future.
63
Photo- 37: Reactor (Link energy) Photo- 38: GTLplant (Link energy)
http://www.brain-c-jcoal.info/worldcoalreport/S03-02-03.html http://www.brain-c-jcoal.info/worldcoalreport/S03-02-03.html
Photo- 39: Production well (Carbon energy)

http://www.brain-c-jcoal.info/worldcoalreport/S03-02-03.html
Article 127. Off limit to gas generation and supply facility

Article 127-1. Prevention of off limit
1. “Appropriate measures” stipulated in design technical regulation Article127-1 means to provide fence ,
wall, barbed wire and hedge (referred to as “fence”) and to display prohibiting to close to gas facility in
the gas production and supply premises. However, it deemed appropriate measures have been taken, if
the sea, rivers, lakes, cliffs, etc. has become a boundary.
2. “Appropriate measures” must be as follows;
(1) To provide fence, etc. and display prohibiting to close to gas facility, in case of the large mobile gas
generation facility.
(2) To provide fence, etc., in case of the mobile gas generation facility (excluding the large mobile gas
generation facility). In addition, when installing in the garden such as a person other than the home demand
individual and providing cover that cannot be operated facility, it may be deemed to have provided such
fence.
64
(3) The following measures, in case of pressure regulator;
1) Measures to install pressure regulator in the room (including box, etc.).

2) Measures to install pressure regulator in the underground manhole or pit, etc.
3) Measures to install pressure regulator in the height that the public cannot operate without good reason.
4) Measures to install pressure regulator with construction which public cannot operate without good
reason.
3. Security
Access to stations and terminals must be controlled. They must be fenced, with gates locked or attended.
Permanent notices must be located at the perimeter indicating the reference details of the station or
terminal and a telephone number at which the pipeline operating company may be contacted. Security
requirements for pipeline facilities within a station, terminal or installation must be established in
conjunction with the requirements for the station, terminal or installation.
Photo- 40: Gas generation plant Photo- 41: Coal gasification plant
http://jointfukuoka.seesaa.net/category/7241665-5.html http://www.jpower.co.jp/news_release/news070507_1.html
Article 128. Security communication facility for gas generation and supply facility
Article 128-1. Safety communication facility
1. “Appropriate communication facility” stipulated in design technical regulation Article128-1 means
equipments which is capable to communicate between the workplace to manage gas production, supply
or pipeline, or between control centers if there is a control center to give appropriate instructions to
determine the status of these facilities to each other between control center and through the control center,
and refers to any of the followings;
(1) Subscriber telephone equipment (refers to the communication equipment to set up a communication line
between the equipment and the subscriber location specified by the exchange).
(2) Dedicated telephone facilities (refers to the communication equipment using the communication line to be
established in the specified interval).
65
(3) Wireless telephone communication facility (refers to the communication equipment to send or receive
audio, etc. using radio waves).
Article 129. Off-set distance for gas generation and supply facility
Article 129-1. Separation distance from boundary
1. “Separation distance required for safety” stipulated in design technical regulation Article 129-1 means the
distance as follows;
(1) Separation distance required for safety must be at least 1m.

(2) Open space must be provided around stations and terminals for the free movement of fire-fighting
equipment. Sufficient access and clearance must be provided at stations and terminals for movement of
fire-fighting and other emergency equipment. Layouts of stations and terminals must be based on
minimizing the spread and consequences of fire. Areas within stations and terminals with possible
explosive gas mixtures must be classified in accordance with IEC 60079-10 and the requirements for plant
and equipment defined accordingly.
(3) Spacing of tankage must be in accordance with NFPA 30. Piping must be routed such that trip or overhead
hazards to personnel are avoided, and access to piping and equipment for inspection and maintenance is
not hindered. Requirements for access for replacement of equipment must also be considered when routing
primary piping. Vent and drain lines to atmosphere must be extended to a location where fluids may be
discharged safely. Particular attention must be paid to safety in locating vent and drain lines near living
quarters on offshore installations.
Article 129-2. Separation distance from school, hospital, etc.

1. When installing the gas generation facility above a certain size, it is necessary to prevent danger to the
surrounding security properties such as critical facilities and homes and the like when the accident
occurred in it.
1) Elementary school, middle school, high school, secondary school, vocational high school, special
needs schools and kindergarten.
2) Hospital (which has a facility for patients to be hospitalized for more than 20 peoples).
3) Theater, cinema, hall, auditorium and similar facilities to accommodate more than 300 peoples.
4) Protecting living facility, child welfare facilities, welfare facilities for the aged, nursing home care
facilities, welfare aid for persons with disabilities, maternal and child welfare facilities and the like
which has admission capacity more than 20 peoples.
5) Important cultural building properties, Important tangible folk cultural properties, building and
museums that is designated as historic sites, scenic natural monument or important cultural
monuments.
6) Main building of the station and platform which more than 20,000 passengers per day by an average
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are getting on and off.
Content of separation distance Separation distance

Between gas generation facility and other gas generation facility of 5 m and more
flammable gas
Between gas generation facility and facility to dwal with fire 8 m and more
Between gas generation equipment and boundary of premise 20 m and more
Between gas generation facility and above security property 50 m and more
Article 130. Security compartment of gas generation and supply facility

Article 130-1. Security compartment
1. “Appropriate security compartment for security” must be as follows;
(1) The area of security compartment must be less than or equal to 20,000m2.
(2) The sum of heating combustion value of the gas facility that passing through high pressure gas or liquefied
gas in the security compartment must be less than or equal to 6.0×108.
2. The calculation method of the area of the security compartment must be as follows;
(1) The area of security compartment must be sum of the area (1) and (2).
(2) The security compartment stipulated in paragraph-(1) must be the area surrounded by passage more than
5m or a border of the factory and compartment for gas facility (except storage tank and its ancillary
equipment), and is surrounded by a polygon so that they don’t have signed all the interior angle s is greater
than 180 degrees horizontal projection surface bounding line of gas facility.
3. Width of passage stipulated in above item-(2) must be measured by the following standard;
(1) The width must be measured as a base curb, gutter, etc., if passage has been clearly demarcated by curb,
gutter, and etc.
(2) If the boundaries of the passage are not clear, it must be measured with the boundary line of passage and
pulse the width of 1m to the outer edge of the horizontal projection surface of the gas facility in the
security compartment.
(3) “The distance necessary for safety” means at least 30meters against the high pressure gas facility in the
security compartment adjacent to the security compartment.
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Article 131. Firefighting facility for gas generation and supply facility
Article 131-1. Firefighting facility
1. “An appropriate firefighting facility *** in the proper location” stipulated in design technical regulation
Article 131-1 means those facility which installed according to the followings;
(1) The firefighting facility for the large scale gas facility.
1) The fire protection equipment must be provided for the gas facility listed in a. must be installed
pursuant from 2) to 6).
a. Fire protection equipment must be provided to the followings as listed (a) to (d) (except those
are dangerous due to watering sprinkling , since the inner surface is touching water or steam and
has high temperature surface).
(a) Gas generation facility

(b) Gas purification facility
(c) Vessel belonging to the ancillary facility (excluding those belonging to the liquefied gas
storage tank)
(d) Loading arm which is used for unloading of flammable liquefied tanker with 2,5000 gross
tons and more
2) The gas facility from (a) to (d) of a. and those passing through high, medium gas or liquefied gas with
maximum operation pressure must be provided following fire protection facility;
a. The facility that has been installed in the height more than 20 m above ground (including
equipment that has been installed in more than 20 m) and containing liquefied gas (excluding
those which can isolate by remote shutoff device and transport immediately liquefied gas
retaining in the facility) must be installed sprinkle equipment and water hydrant or water cannon
must be installed in two or more places within the 40m from outer surface of such facility.
b. The facility other than 2)-a. must be provided sprinkle equipment and water hydrant or water
cannon must be installed in two or more places within the 40m from outer surface of such
facility. In addition, fixed water cannon can be regards as a water cannon or fixed fire hydrant
water facility or such fire hydrant water facility that is placed in the center of a circle of 40meter
radius to encompass equipment involved in the provision of 2)-a and b.
3) The fire protection facility for the gas facility stipulated in a.-(a) to (d) and passing through low
pressure gas must be installed fire water hydrant for each 75m walking distance around the target
partition.
4) The water curtain facility that has a sufficient capacity in the vicinity of a.-(d) must be installed.
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5) The fire protection facility must have following performance depending on its type.
a. In principle, the sprinkle facility or spray equipment must be fixed for every single facility.
However, it can be regarded as consolidated watering facility depending on the placement of
equipments and configuration, etc. Location to sprinkle must be made from the top of the
equipment in principle, and it must be placed so as to allow watering of more than 5 liters per
minute per unit area of the facility (one square meter). However, the facility which is covered by
rock wool with more than 25mm or the material which has equivalent strength or fire resistance
may be the amount of watering in 2.5 liter per minute. In addition, if such facility exceeds
5meters in height above ground (10m in case of a large scale gas generation facility) can be said
that the surface area when cut into in the horizontal place of the 5m interval (10m in case of a
large scale gas generation facility) so as to maximize the surface area. Also, measures such as
installing a sprinkler pipe or auxiliary water spray header must be taken even if insufficient in
installing spray pipe on the top or in case in appropriate method for the object.
b. The fixed deck gun must be installed fixed target, have water pressure at least 0.34MPa at water
cannon and have water flow at least 400 liters per minute.
c. The water hydrant must have hose, water cannon, handle and the like and have water pressure at
least 0.34MPa at the tip of water cannon and have water flow at least 400 liters per minute.
6) The supply facility of fire protection water must be pursuant following standard;
a. Sufficient amount of water that can be supplied continuously for at least 30 minutes watering
must be retained in consideration such placement of equipment in gas production plant and the
area take them valid and appropriate fire prevention activity in the plant, and require large
amounts of water for fire protection.
b. The supply valve and operation valve for fire protection water supply facility must be installed
in the safety position and be operated remotely depending on the situation of the facility.
7) The firefighting equipment which is stipulated for each must be provided for following gas facilities
listed in from a. to c.
a. At least one or more powder fire extinguisher with B-10 unit capacity per 10 tons of flammable
gas held inside each group of target equipment such as the gas generation facility, gas
purification facility, blower, compressor and ancillary vessel (excluding those belonging to the
liquefied gas). In this case, the minimum quantity is 3 for high pressure and 2 for other than high
pressure.
b. At least three powder fire extinguishers with B-10 unit capacity must be provided for the
gasholder with maximum operation pressure high. At least 2 powder fire extinguishers with
B-10 unit capacity must be provided for the gasholder with maximum operation pressure
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medium.
c. The gas facility which liquefied gas is passing through as listed below must be pursuant to
following provisions;
(a) The numbers of lower column of the Table-** powder fire extinguishers with B-10 unit
capacity must be provided to storage tank depending on the classification of storage
capacity listed in the upper column of the table for each storage tank. In addition, 2 or more
fire extinguishers with B-10 unit capacity must be installed for 50meters walking distance
around the protective dikes in case the storage capacity of 1,000tons.
Table- 17: Required numbers of fire extinguisher depending on storage capacity

Storage capacity 100 ton or less 100 ton and more
Number of powder
3 4
fire-extinguisher
(b) At least 3 or more powder fire extinguishers with B-10 unit capacity must be provided for
each group of the liquefied gas pump.
(c) At least 3 or more powder extinguishers with B-10 unit capacity must be provided for each
group of the liquefied gas vaporizers which generate gas from liquefied gas.
(d) At least 3 or more powder fire extinguishers with B-10 unit capacity must be provided in
the vicinity of the liquefied gas handling facility in the place where incoming and outgoing
by tank lorry.
(e) The number of powder fire extinguisher installed for two or more from (a) (limited to those
which has not dikes) to (d) can be equivalent to the value obtained by dividing the site area
including storage facility by 50 square meter (round up), notwithstanding the provisions of
from (a) to (d). In case of this, the minimum number of required fire extinguisher must be 3.
In addition, in case of 100 tons storage tank, the required minimum number must be 4.
(f) The equipment which can release 2 tons and more of dry chemical must be installed in the
vicinity of the loading arms that are used for loading and unloading of flammable liquefied
gas tanker of 25,000 gross tons and more on berth.
(g) At least 2 or more powder fire extinguishers with B-10 unit capacity must be provided in
the vicinity of the liquefied gas facility in the place where fire is used.
(2) The firefighting equipment for large scale gas facility must be pursuant as follows;
1) In case of bulk storage tank, the following facility must be provided.
a. In case the storage capacity of less than 3 tons.
2 or more if storage capacity is less than 2 tons, 3 or more if storage capacity is more than 2 tons,
powder fire extinguishers must be provided in the safety place around them.
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b. In case the storage capacity of 3 tons and more.
(a) 3 or more powder fire extinguishers with B-10 unit capacity must be provided in the safety
place around them.
(b) Following fire protection equipment (sprinkler or water hydrant) must be provided.
a) Sprinkle equipment can be watering the amount of water which is more than 5 liters
per minute per square meter of surface area of bulk storage tanks.
b) The water hydrant must be capable to discharge from two or more directions and to
discharge either amount of water greater than equal to 1.6 times the capacity of
sprinkle equipment or 350 liters per minute.
c) The facility for water supply to fire-proof must be connected to the water source that
can intake continuously for at least 30minutes fire fighting and the place to operate
facility such as valves must be more than 15 m away and in a safe place. However, if
the shielding device and safe for fire is expected around the storage tank, this must
not applied.
2) The following equipments must be provided for the storage tank.

a. At least three fire extinguishers which have unit capacity more than B-10 must be provided in a
safe surrounding place.
b. The following fire protection equipments (sprinkler or water hydrant) must be installed.
(a) The sprinkler equipment can be watering the amount of water at least 5 liters per minute
per square meter of surface area of storage tank.
(b) The water hydrant must be either those which can be discharging from two or more
direction or discharge at least 1.6 times of sprinkler capacity or 350 liters per minute.
(c) The facility for water supply to fire-proof must be connected to the water source that can
intake continuously for at least 30minutes fire fighting and the place to operate facility
such as valves must be more than 15 m away and in a safe place. However, if the shielding
device and safe for fire is expected around the storage tank, this must not applied.
c. The equipment for incoming and outgoing of liquefied petroleum gas must be provided at least 2
powder extinguishers with B-10 unit capacity in the vicinity of parking area of tank lorry.
3) In case of high gas pressure, following facility must be provided;

a. In case the storage capacity of less than 3 tons.
Fire extinguisher with B-10 unit capacity of at least numbers obtained by dividing area of
container yard by 50 square meters must be provided. In addition, fire extinguisher must be
placed in the position where the work does not interfere to bring in or carry-out containers in
principle.
b. In case the storage capacity of 3 tons and more.
(a) Firefighting equipment stipulated in a. must be provided.
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(b) Fire protection equipment for storage tank stipulated in 2) must be provided. However, if
the wall of the container yard has fireproof performance, it must be deemed to be fire
protection wall.
2. “Appropriate fire protection and firefighting equipment” related to the large capacity movable gas
generation facility means one or more powder fire extinguisher with B-10 unit capacity.
Article 132. Prevention of gas accumulation for gas generation and supply facility
Article 132-1. Prevention of gas accumulation indoor
1. “Structure shall allow for no accumulation of gas” stipulated in design technical regulation Article 132-1
means those which conform to followings;
(1) One which has following structures considering the nature of the gas, the amount of gas processing or
storage, the characteristics of equipment and the size of room an the like.
1) The structure with an opening of at least two directions with sufficient area for ventilation.
2) The structure which is capable to ventilate effectively and mechanically.
2. “Suitable place where gas may be possible to accumulate in the gas manufacturing works” stipulated in
design technical regulation Article132-2 means the place where it is considered the circumstances
surrounding placement of equipment, properties of gas, draft, ventilation and the like.
Article 132-2. Gas detector

1. “Suitable place where gas may be possible to accumulate in the gas manufacturing works” stipulated in
design technical regulation Article 132-2 means those which can be secure security measures equivalent to
odorization.
Article 133. Explosion-proof structure of electric facility for gas generation and supply
facility
Article 133-1. Explosion-proof of electric facility
1. “Explosion-proof type depending on the conditions of place and the kind of gas” stipulated in design
technical regulation Article133 means those which are conform to the appropriate standards for
explosion-proof electrical equipment, are considered the selection of electrical equipment and wiring
depending on the classification to type of flammable gas and explosion risk and are installed.
2. Electrical equipment and wiring installed in stations must conform to the requirements of IEC 60079-14.
Electrical installations which are to remain in operation during an emergency must be based on the zone
applicable during the emergency.
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Article 134. Distance from flammable gas facility of gas generation and supply facility
Article 134-1. Distance from flammable gas facility
1. “Sufficient distance” stipulated in design technical regulation Article 134-1 means 8m and more from
such gas generation facility to the equipment handling fire. However, it may be the distance as prescribed
as follows; either of the following measures is taken in order to prevent leaked gas flowing to the
equipment handling a fire between such gas facility and the equipment handling a fire.
(1) Equipment must be placed at least 8m in horizontal distance detour, when providing barrier with sufficient
height between equipment and a fire.
(2) It can be at least 0m when installing gas leak detection and alarm device adjacent to the equipment
handling the fire, when detecting a gas leak and when measures are taken immediately to be able to
extinguish the fire by interlocking equipment.
2. “The equipment handling a fire” above mentioned means boiler, furnaces, incinerators, smoking room and
the like that is usually placed stationally.
Article 135. Gas displacement of gas generation and supply facility

Article 135-1. Gas replacement
1. “To replace gas safely” stipulated in design technical regulation Article 135-1 means to replace flammable
gas with an inert gas such as nitrogen in order to prevent accident in halt, corrosion protection and secure
environment during repair work ( to prevent gas explosion and poisoning). The methods are divided into
following ;
1) To supply liquefied nitrogen from outside to installed vaporizer for liquid nitrogen and supply nitrogen
gas to gas pipeline.
2) To supply nitrogen gas directly to gas pipeline by nitrogen pipe.
3) To supply inert gas that is generated by inert gas generator.
Article 135-2. Vent-stack

1. “Appropriate measures” stipulated in design technical regulation Article 135-2 means the installation of
vent-stack taking into account the installation of valves that is capable to control the height, position or
diffusion depending on the surroundings, etc.
Article 135-3. Heat radiation

1. “Keep from damaging its surroundings due to heat radiation and to be able to release gas safely”
stipulated in design technical regulation Article 135-3 must be pursuant as follows;
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(1) The material must withstand the generated heat on that flairstack.
(2) Its height and location must not give failure to surroundings from the radiation heat generated on the
flairstack.
(3) The flair stack must be taken measures to prevent explosions.
Photo- 42: Flaire stack Photo- 43: Landfill gas flaire stack
http://jp.123rf.com/photo_8179285_sphere-and-flare-stack http://www.ukexportnews.co.uk/news/1269/Landfill-Gas-Analys
s.htm is-Telematics-In-Slovenia-On-Line-In-UK
Photo- 44: Flaire stack Photo- 45: Flaire stackignition nozzle

http://www.dreamstime.com/royalty-free-stock-ph http://www.flares-stacks.com/combustion_process_equipment_company_blog/2
otos-gas-plant-flare-stack-2-image3157278 011/11
Article 136. Material of gas generation and supply facility

Article 136-1. Material
1. See Article 117-1.
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Article 137. Structures, etc. of gas generation and supply facility
Article 137-1. Structure
1. The construction of vessel and piping for the gas generation facility and gas purifier must be pursuant to
the provision for gas generation facility and gas purification facility stipulated in the interpretation of
technical regulation for gas facility or JIS B8265-2008 “Construction of pressure vessel—General”. And
the allowable stress for gas generation facility must be pursuant the allowable stress stipulated in stipulated
in the interpretation of technical regulation for gas facility.
Article 137-2. Foundation

1. See Article118-4.
Article 138. Welding parts of gas generation and supply facility

Article 138-1. Welding part
1. “Welded part” is the generic part that includes the welded metal and heat affected zone. Generally, the part
subjected to welding consists of continuous set with different nature, the base metal which is not heat
affected zone out of heat affected zone and the heat affected zone which consist of welded metal and heat
affected part.
Article 138-2. Welding procedure

1. “Welding” must be pursuant to as follows;
(1) Welding of pipeline must be performed according to the appropriate WPS.

(2) Welding equipment such as the welding machine, dryer, and windbreak must conform to the welding
method or welding conditions specified in WPS.
(3) Welding or consumables such as the welding rod, welding wire, flux, electrode and seal gas must conform
to WPS.
(4) A butt weld must be applied for the mains. And V-shape or U-shape groove must be applied to welding
joint shape.
Article 138-3. Welding management

1. The appropriate measure to obtain good circumstance for welding such as wind break, waterproof, lighting,
worming equipment must be provided as shown in Photo-35 and 36.
Article 139. Safety valve for gas generation and supply facility
Article 139-1. Safety valve
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Article 140. Instrument device, etc. for gas generation and supply facility
1. “Appropriate instrumentation equipment to measure and check” stipulated in design technical regulation
Article 140-1 means those which is capable to measure and confirm following items;
the maximum operation pressure is low.
or natural gas.
2) Air flow or pressure, in case of burning a part of raw material with air into furnace.
3) Flow rate and pressure (outlet temperature, with regard to those having steam saturation tower), in
case of those which use steam.
4) Furnace pressure and outlet temperature of reactor or furnace, in case those which has reactor.
the maximum operation pressure is high or medium.
or natural gas.
2) Flow rate and pressure, in case of those which use steam to generate gas.
3) Inlet and outlet temperature, and inlet and outlet pressure of reactor.
4) Flow rate and pressure of fuel, in case of the external type thermal reactor.
5) Liquid surface, in case of condensed water separator which have construction to discharge water by
hand.
(3) Those which is capable to measure the stored gas capacity, with regard to the gasholder which maximum
(4) Those which are capable to measure the stored gas pressure, with regard to the gasholder which maximum
(5) Following matters, with regard to the blower and compressor.

76
Article 141. Alarm device for gas generation and supply facility
Article 141-1. Alarm device
1. “Appropriate warning device” stipulated in design technical regulation Article 141-1 means those pursuant
as follows. However, if the equipment doesn’t be such state, this must not be applied.
(1) In case of the gas generation facility, the following cases;
1) When the pressure of operation fluid drops abnormally, with regard to those which use fluid to
operate the autopilot equipment.
2) When the water supply to the water seal vessel stop or the liquid surface of the water seal vessel
drops abnormally, with regard to those which has the water seal vessel.
3) When the pressure of steam drops abnormally, with regard to those which feed steam into the
furnace.
4) When the pressure of combustion gas drops abnormally, with regard to those which feed air into
furnace and burn a part of raw material.
5) When the pressure of fed fuel drops abnormally, with regard to those which is heated externally.
6) When the pressure of the part where gas passing raises abnormally, with regard to those which is high
pressure or middle pressure.
(2) When the gas pressure raises abnormally, with regard to the gas purification facility that the maximum
operation pressure is high or medium.
(3) When the amount of gas storage has decreased abnormally, with regard to the gasholder that the maximum
operation pressure is low (limited to those which discharge gas by blower or compressor).
(4) When the hydraulic pressure of the lubricating oil has dropped abnormally, with regard to the blower and
compressor (limited to those which has the external forced lubricating equipment).
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Article 142. Fail-safe control and instrument for gas generation and supply facility
Article 142-1. Fail-safe control
1. “Measures to prevent mistake and to ensure the operation” stipulated in design technical regulation Article
142-1 means as follows;
(1) The shutoff device must be indicated the open or close direction (which has important impact on the safety
in the gas facility, including the indication it’s open or close status) must be explicit.
(2) The piping related to the emergency shutoff device (except those can be operated by operation button )
which has important impact on the safety in the gas facility must be provided the type and direction of gas
or other fluid in the pipe by the method can be easily distinguished adjacent to the shutoff device.
(3) The emergency shutoff device which has important impact on the safety in the gas facility and is not used
in normal (except those used for emergency) must be locked; sealed and similar measures must be taken.
Article 142-2. Interlock

1. The interlock mechanism must be provided on the generation facility of flammable gas or the important
place of instrumentation circuit of these facility where is necessary for security to prevent the abnormal
operation other than normal operation or to cut off the supply of raw materials for generation facility
automatically when equipment is deviated from the normal condition in order to control the production in
the generation facility.
Article 143. Back-up power, etc. for gas generation and supply facility
Article 143-1. Back-up power
1. “For the safety apparatus needed to safety stop the gas generation facility” stipulated in the design
technical regulation Article 143-1 means as follows;
1) Emergency lighting system.

2) Equipment to ensure rapid communication in case of emergency (except telephone subscriber
equipment)
3) Fire prevention and firefighting equipment.
4) Gas leak detection and alarm equipment.
5) Emergency shutoff valve.
6) Emergency shutoff device.
7) Cooling equipment.
8) Water spraying system or equivalent facility that has the capacity to prevention of fire and
firefighting.
9) Water spraying system or equivalent facility that is effective for fire prevention.
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Article 144. Measurement of odor for gas generation and supply facility
Article 144-1. Odorization
Article 145. Control room for gas generation and supply facility
Article 145-1. Control room
1. “Shall be capable of controlling the gas safely in an emergency” stipulated in the design technical
regulation Article 145 means those that can be ensure following function;
1) Operation and maneuver of gas generation facility.

2) Operation of firefighting equipment.
3) Emergency contact.
2. Monitoring and communication systems

The requirements for monitoring pressure, temperature, flow rate, physical characteristics of the fluid being
conveyed, information on pumps, compressors, valve positions, meters and tank levels, together with alarm
conditions such as power supply failure, high temperature of electric motor windings and rotating
machinery bearings, excessive vibration levels, low suction pressures, high delivery pressures, seal leakage,
abnormal temperatures, and the detection of fire and hazardous atmosphere shall be defined and included
in the system design in accordance with clause 5. Supervisory control and data acquisition (SCADA)
systems may be used for controlling equipment. Operating requirements of the pipeline system, as well as
safety and environmental requirements shall be the basis for determining the need for redundant
monitoring and communication components, and back-up power supply.
Article 146. General provision of gas storage facility

1. The gasholder is installed in the factory or gas production plant in order to storage gas in time s of low
demand and to supply gas in high demand, which acts to regulate the transmission of gas. Gasholder is
made of steels plates with together and has enough strength to withstand a big earthquake. The foundation
has a structure that piling until firm ground according to a survey basis for ground for gasholder and struts
or body is permanently fixed on the basis on reinforced concrete. In addition, Oil damper and the
emergency shutoff valve that can be remote control and the expansion that absorb vibration at the junction
of gasholder and gas piping.
2. The gasholder occur explosion or fire even heating from outside or putting the ignition source inside in the
gasholder without air, since gas explosion can be occurred with certain mixture percentage of air. If gas
blow out from hole on the holder, gas is only burn without immediate explosion, since there is no oxygen
required for combustion.
3. There were water seal type, cylindrical type and spherical type, what were once almost cylindrical, but has
79
now been placed almost spherical.
Article 147. Material of gas storage tank

Article 147-1. Material
Article 148. Structure of gas storage tank

Article 148-1 Structure of gasholder
1. The structure of the gasholder must be pursuant by any of followings. In addition, the shape of must be
spherical in case of the high maximum operating pressure, spherical or cylindrical in case other cases.
However, it must not be the cylindrical with flat bottom in case of those of medium pressure or high
pressure of maximum operating pressure. In addition, standard pertaining to seismic safety are limited to
more than 300m3 of storage capacity.
(1) The structure of gasholder must conform to following 1) to 5);
1) The foundation of gasholder must withstand gross weight of gasholder filled with gas and including
supports and wind load stipulated in 2).
2) The gasholder and its support must withstand wind load calculated according to “4.5.2 (5) of
Guideline for spherical gas holder: JGA (Japan Gas Association) 104-03”.
3) Earthquake resistance of gasholder (including supports) must conform to the provision of “Seismic
Design Guidelines for gas production facility: JGA (Japan Gas Association) 101-01.
4) The gasholder which has high and medium maximum operating pressure must be pursuant to the
following provision a. to h. In addition, the allowable stress of materials stipulated in Article 117-1
must be applied.
a. Measures for incoming and outgoing piping to absorb expansion due to change in temperature
and pressure must be taken.
b. Inspection hole or manhole must be provided according to standard.
c. The thickness of gasholder must be conformed to the minimum thickness according to standard.
d. The thickness of nozzle neck must be conformed to the minimum thickness according to
standard.
e. The thickness of dished head plate must be conformed to the minimum thickness according to
standard.
f. The stiffener of hole must be conformed to the minimum thickness according to standard.
g. The installation procedure of piping on the gasholder must be conformed to the minimum
thickness according to standard.
h. The installation procedure of flanges on the gasholder must be conformed to the minimum
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thickness according to standard.
5) The minimum thickness limit excluding corrosion allowance of the gasholder which has low
maximum operation pressure must be 1.6mm.
(2) The structure of spherical gasholder must conform to the provision“4.4.7 (3): design, 8.1: general, 8.4:
design criteria, 8.5: structure and design, incoming and outgo piping of Guideline for spherical gas holder:
JGA (Japan Gas Association) 104-03”. However, the allowable tensile stress for pressure part of gasholder
body must conform to the provision Article 117-1.
2. The structure of membrane gasholder must conform to the provision “Design: Guideline for membrane
gasholder (Nuclear Safety Agency Japan No.1).
Photo- 46: Gas holder for BFG Photo- 47: Spherical gas holder
http://en.wikipedia.org/wiki/File:Lazarus_Thick_Shell_Gashold http://pinktentacle.com/2011/03/decorated-gas-tanks/
er.jpg
Photo- 48: Bio gas hoilder Photo- 49: Membrane gas holder
http://www.thewatertreatmentplant.com/gas-holder.html http://www.esi.info/detail.cfm/The-Utile-Engineering-Co-Ltd/Sa
ttler-double-membrane-gas-holder/_/R-25867_NN95UG
3. Storage and working tankage (ISO 13623-7.11 2000)

(1) Tanks for storage or handling of fluids shall be designed and constructed in accordance with the following
81
standards:
1) API 650 “Welded steel tanks for oil storage-10th edition ” for fluids with a vapour pressure less than
0.035 bar(g);
2) API 620 “Design and construction of large, welded, low-pressure storage tanks. - 11th edition.” for
fluids with a vapour pressure higher than 0.035 bar(g) but not more than 1 bar(g);
3) this International Standard for pipe-type holders used for fluids with a vapour pressure of more than 1
bar(g);
4) applicable standards for holders other than pipe-type holders for fluids with a vapour pressure of more
than1 bar (g).
Foundations shall be designed and constructed in accordance with plans and specifications which shall take
into account local soil conditions, type of tank, usage and general location.
Article 148-2. Drain discharge

1. It is possible that the separation of heavy minutes in the material which passes through the bottom of
piping, storage vessel or tank and accumulation. The work to extract this heavy fraction and condensate is
referred to as “work down”. The drain of LPG or light hydrocarbons is often accompanied water and
condensation and freezing is likely to occur. Valve must be duplicated, the upstream side valve must be
fully open and the degree of opening of the downstream side secondary valve must be adjusted.
Article 148-3. Volume of gas storage

1. The storage capacity of gas must be calculated according to the following formula.
82
Table- 18: Calculation of gas storage capacity
Classification Storage capacity
Storage tanks and vessels for

Q = (10 × P + 1) × V1
compressed gas
Storage tanks for liquefied gas W = C1 × w × V2
V2
Vessels for liquefied gas W =
C2
Q : Storage capacity (m3)

P : 35oC (MPa)
V1 : Volume of the tank or vessel (m3)
W : Storage capacity (kg)
w : Specific gravity of liquefied gases at regular temperature (kg/ℓ)
V2 : Volume of the tank or vessel (ℓ)
C1 : 0.9 (ratio of the part can be store liquefied gas in the volume in case of low —
temperature storage tank, 0.85 for bulk storage tank other than those above
2,000ℓ in volume and placed underground)
C2 : Value stipulated in article 22 of safety rule for vessel —
Reference: http://www.pref.saitama.lg.jp/uploaded/attachment/358855.pdf
Article 149. Shut-off device for gas storage tank

Article 149-1. Shut-off valve for gasholder
1. “Appropriate equipment to promptly shutoff the inflow and outflow of gas shall be provided” stipulated in
design technical regulation Article 149 means the followings;
(1) In case of the gasholder with low maximum operating pressure, it means to provide the remote control
valve or water seal valve adjacent to the connection of gasholder and pipes (limited those which are use
gas discharge or incoming). In addition, such remote control valve must be capable to operate at a distance
of more than 5m (0m in case of buried pipe and water seal gasholder) from the outside surface of piping
(limited to such remote control valve from the gasholder) and the gas holder.
(2) In case of the gasholder with high or medium maximum operating pressure, it must conform to following
1) and 2);
83
1) In case of such gasholder, it means to provide the emergency shutoff valve adjacent to the connection
of gasholder and pipes (limited those which are use gas discharge or incoming). In addition, such
emergency shutoff valve must be capable to operate at a distance of more than 5m (10m in case of
large scale site and 0m in case of buried pipe and water seal gasholder) from the outside surface of
piping (limited to such remote control valve from the gasholder) and the gas holder.
2) It means to provide the manual valve or the remote control valve adjacent to the connection of
gasholder and pipes (limited those from such gasholder to the emergency shutoff valve). However,
this is not applied, if installing the emergency shutoff valve stipulated in 1) between gasholder and
expansion part which absorb changes in thermal expansion due to temperature and pressure.
2. Each blower or compressor station must be provided with an emergency shutdown system that is readily
accessible, locally and/or remotely operated, and which will shut down all prime movers. Consideration
must also be given to isolating the station from the pipeline and to relieving or venting the piping system
when required. Operation of the emergency shutdown system must also permit the shutdown of any
gas-fired equipment that could jeopardize the safety of the site provided it is not required for emergency
purposes. Uninterrupted power supply must be provided for personnel protection and those functions that
are necessary for protection of equipment.
3. Gas shutoff valve on the main or branch of pipeline

(1) “The appropriate equipment which is capable to shutoff gas immediately” means the equipment to stop gas
immediately in emergency case.
(2) “The proper location” is the turning point or other the place where it is necessary to maintain pipeline, the
riser part in case of offshore pipeline.
Article 150. Indication for gas storage tank

Article 150-1.Indication for gas storage tank
1. Signs must be placed to identify hazardous, classified and high-voltage areas. Access to such areas must be
controlled. Fences must not hinder the escape of personnel to a safe location. Escape gates must open
outward and be capable of being opened from the inside without a key when the enclosure is occupied.
Adequate exits and unobstructed passage to a safe location must be provided for each operating floor of
main pump and compressor buildings, basements, and any elevated walkway or platform. Exits must
provide a convenient possibility of escape. Appropriate fire and gas detection and fire-fighting facilities
must be provided. For stations and terminals on land, the requirements for such facilities must be
established in consultation with the local fire authorities. Tanks, dikes and firewalls must meet the
requirements of NFPA 30.
Ventilation must be provided to prevent the exposure of personnel to hazardous concentrations of
84
flammable or noxious liquids, vapours or gases in enclosed areas, sumps and pits during normal and
abnormal conditions such as a blown gasket or packing gland. Equipment for the detection of hazardous
concentrations of fluids must be provided. Hot and cold piping which may cause injury to personnel must
be suitably insulated or protected.
Photo- 50: Warning board for gas tank Photo- 51: Warning board for gas tank
http://www.megacoolstuff.com/GasStorageArea.asp http://www.prosportstickers.com/products/Natural-Gas-Danger-
Sign.html
Article 151. Safety valves, etc. for gas storage tank

Article 151-1. Quantity of safety valve
1. “Safety valve” stipulated in design technical regulation Article 151 must be provided pursuant to the
followings in addition to Article 120-1;
(1) Two or more safety valves that are configured to operate at pressure below maximum allowable working
pressure of gasholder. However, it may be less than 1.07 times of the maximum operating pressure, if there
is a device which automatically stops gas flow at pressure below maximum allowable operating pressure of
gas going into the holder.
(2) The total capacity of blowing of safety valves must be greater than the maximum amount of discharge gas
when the pressure of gasholder equal to the maximum operating pressure, even if any one of the safety
valve provided on the gasholder is omitted.
Article 151-2. Negative pressure

1. This article is not applied to the gasholder, since the negative pressure id particular for the liquefied gas
storage tank.
85
Article 152. Instrument device for gas storage tank
“Instrumentation equipment to measure the operation conditions” stipulated in design technical regulation
Article 152-1 means those which is capable to measure and confirm following matters.
(1) Those which is capable to measure the stored gas capacity, in case of the gasholder which maximum
(2) Those which are capable to measure the stored gas pressure, in case of the gasholder which maximum
(3) Following matters, in case of the blower and compressor.

Article 152-2. Pressure detector and thermometer

1. Provisions such as pressure control valves or automatic shutdown of pressurizing equipment must be
installed, or procedures implemented, if the operating pressure can exceed the maximum allowable
operating pressure anywhere in the pipeline system. Such provisions or procedures must prevent the
operating pressure exceeding MAOP under normal steady-state conditions. Overpressure protection, such
as relief or source isolation valves, must be provided if necessary to prevent incidental pressures exceeding
the limits anywhere in the pipeline system.
86
Article 153. Alarm device for gas storage tank
Article 153-1. Alarm device
1. “Warning equipment” stipulated in design technical regulation Article 153 means those alarming in
following cases. Furthermore, this is not applied, if these states will not happen due to structural reason.
(1) When the volume of stored gas decreased abnormally, in case of gasholder which maximum operating
pressure is low (limited to those deliver gas by blower and compressor).
(2) When lubrication oil pressure decrease abnormally, in case of blower and compressor (limited to those that
has the external forced lubricating oil system).
87
Chapter-3. Technical Standards for pipeline
The comparison table of technical standard for gas and oil pipeline is shown in Table-19.
Table- 19: Pipeline industry standards incorporated by reference in 49 CFR part 192, 193 and 195
SDO acronomy Standards Title Latest edition Federal reference
rd
American Gas AGA XK0101 Purging principles and practices 3 Edition, §§193.2513;
Association 2001 193.2517; 193.2615
(AGA)
American ANSI/API Specification for line pipe 47th Edition §§192.55 (e);
Petroleum Spec 5L/ISO 2007 192.113; item-1 of
3183 Appendix-B
Institute (API)
(API) RP5L1 Recommended Practice for Railroad 6th Edition, § 192.65(a)
Transportation of Line Pipe 2002
(API) RP5LW Recommended Practice for 2nd Edition § 192.65(b)
Transportation of Line Pipe on Barges 1996
and Marine Vessel...
(API) Spec. 6D/ISO Pipeline Valves 23rd Edition § 192.145(a)
14313 and Errata
June 2008
(API) RP 80 Guidelines for the Definition of 1st Edition, §§192.8(a);
Onshore Gas Gathering Lines 2000 192.8(a)(1);
192.8(a)(2);
192.8(a)(3);
192.8(a)(4).
192.8(a);
192.8(a ...
(API) Std. 1104 Welding of Pipelines and Related 20th Edition §§ 192.227(a);
Facilities and Errata2, 192.229(c)(1);
2008 192.241(c);
Item -2, Appendix-B
(API) RP1162 Public Awareness Programs for 1st Edition, §§ 192.616(a);
Pipeline Operators 2003 192.616(b);
192.616(c)
(API) ANSI/API Specification for Shop Welded Tanks 11th Edition §§195.132(b)(1);
Spec. 12F for Storage of Production Liquids and Errata, 195.205(b)(2);
2007 195.264(b)(1);
195.264(e)(1);
195.307(a);
195.56 ...
(API) Stan. 510 Pressure Vessel Inspection Code: 9th Edition, §§195.205(b)(3);
Maintenance Inspection, Rating, 2006 195.432(c).
Repair, and Alt ...
(API) Stan. 620 Design and Construction of Large, 11th Edition, §§195.132(b)(2);
Welded, Low- Pressure Storage Tanks 2008 195.205(b)(2);
195.264(b)(1);
195.264(e)(3);
195.307(b).
88
(API) Stan. 650 Welded Steel Tanks for Oil Storage 11th Edition, §§195.132(b)(3);
2007 195.205(b)(1);
195.264(b)(1);
195.264(e)(2);
195.307I;
195.307( ...
(API) RP651 Cathodic Protection of Aboveground 3rd Edition, §§195.565;
Petroleum Storage Tanks Jan. 2007 195.579(d).
(API) RP652 Lining of Aboveground Petroleum 3rd edition, §195.579(d).

Storage Tank Bottoms Oct. 2005
(API) Stan. 653 Tank Inspection, Repair, Alteration, 3rd Edition, §§195.205(b)(1);
and Reconstruction Addendum 1- 195.432(b).
3 and
Errata,2008
(API) Stan. 1130 Computational Pipeline Monitoring for 1st edition, §§195.134; 195.444.
Liquid Pipelines September,
2007
(API) Stan. 2000 Venting Atmospheric and Low- 5th Edition §§195.264(e)(2);
Pressure Storage Tanks and Errata, 195.264(e)(3).
1999
(API) RP2003 Protection Against Ignitions Arising 7th Edition, §195.405(a).
Out of Static, Lightning, and Stray 2008
Current...
(API) Stan. 2026 Safe Access/Egress Involving Floating 2nd Edition, §195.405(b).
Roofs of Storage Tanks in Petroleum Reaffirmation,
Servic ... 2006
(API) RP2350 Overfill Protection for Storage Tanks In 3rd Edition, §195.428I.
Petroleum Facilities Jan. 2005
(API) Stan. 2510 Design and Construction of LPG 8th Edition, §§195.132(b)(3);
Installations 2001 195.205(b)(3);
195.264(b)(2);
195.264(e)(4);
195.307(e);195.428 .
..
American B16.1–2005 ANSI/ASME B16.1-2005 Gray Iron 2006 Edition §192.147(c).
Society of Pipe Flanges and Flanged Fittings:
Classes 25, 12...
Mechanical
Engineers
(ASME)
(ASME) B16.5–2003 Pipe Flanges and Flanged Fittings 2003 Edition §§192.147(a);
192.279.
(ASME) B16.9–2007 Factory-Made Wrought Steel Butt 2007 Edition §195.118(a).

Welding Fittings
(ASME) B31.4–2006 Pipeline Transportation Systems for 2006 Edition §195.452(h)(4)(i).
Liquid Hydrocarbons and Other Liquids
89
(ASME) B31G–1991 Manual for Determining the Remaining 1991 Edition §§192.485(c);
Strength of Corroded Pipelines 192.933(a).;
§§195.452(h)(4)(i)(
B);
195.452(h)(4)(iii)(D
).
(ASME) B31.8–2007 Gas Transmission and Distribution 2007 Edition §192.619(a)(1)(i).;
Piping Systems §195.5(a)(1)(i);
195.406(a)(1)(i).
(ASME) B31.8S–2004 Supplement to B31.8 on Managing 2004 Edition §§192.903(c);
System Integrity of Gas Pipelines 192.907(b); 192.911,
Introductory text;
192.911(i);
192.911(k);
19 ...
(ASME) ASME ASME Boiler and Pressure Vessel 2007 Edition §192.153(a).
Section I Code, Section I, “Rules for
Construction of Powe ...
(ASME) ASME ASME Boiler and Pressure Vessel 2007 Edition §§192.153(a);
Section VIII - Code, Section-8, Division 1, Rules for 192.153(b);
Constr ... 192.153(d);
DIV. 1
192.165(b)(3).;
§193.2321;
§§195.124;
195. ...
(ASME) ASME ASME Boiler and Pressure Vessel 2007 Edition §§192.153(b);
Section VIII - Code, Section-8, Division-2, Rules for 192.165(b)(3);
Constr ...
Div. 2 §193.2321;
§195.307(e).
(ASME) AMSE ASME Boiler and Pressure Vessel 2007 Edition §§192.227(a);
Section-9 Code, Section-9, Welding and Brazing Item-2,
Qualificat ... Appendix-B.;
§195.222.
American A53/A53M–07 Standard Specification for Pipe, Steel, 2007 Edition §§192.113; Item-1,
Society for Black and Hot- Dipped, Zinc- Coated, Appendix-B.;
Welde...
Testing and §195.106(e).
Materials
(ASTM)
(ASTM) A106/A106M– Standard Specification for Seamless 2008 Edition §§192.113; Item-1,
08 Carbon Steel Pipe for High- Appendix-B.;
Temperature Servi ...
§195.106(e).
(ASTM) A333/A333M– Standard Specification for Seamless 2005 Edition §§192.113; Item -1,
05 and Welded Steel Pipe for Low- Appendix-B.;
Temperature Se ...
§195.106(e).
(ASTM) A372/A372M– Standard Specification for Carbon and 2008 Edition §192.177(b)(1).
08 Alloy Steel Forgings for Thin-Walled
Press ...
(ASTM) A381–96 Standard Specification for Metal-Arc 2005 Edition §§192.113; Item-1,
Welded Steel Pipe for Use With High- Appendix-B.;
Pressur ...
§195.106(e).
90
(ASTM) A671–06 Standard Specification for Electric- 2006 Edition §§192.113; Item-1,
Fusion-Welded Steel Pipe for Appendix-B.;
Atmospheric and ...
§195.106(e).
(ASTM) A672–08 Standard Specification for Electric- 2008 Edition §§192.113; Item-1,
Fusion-Welded Steel Pipe for Appendix-B.;
High-Pressure S ...
§195.106(e).
(ASTM) A691–98 Standard Specification for Carbon and 2007 Edition §§192.113; Item-1,
Alloy Steel Pipe, Electric- Appendix-B.;
Fusion-Welded f ...
§195.106(e).
(ASTM) D638–03 Standard Test Method for Tensile 2003 Edition §§192.283(a)(3);
Properties of Plastics 192.283(b)(1).
(ASTM) D2513–87 Standard Specification for 1987 Edition §192.63(a)(1).
Thermoplastic Gas Pressure Pipe,
Tubing, and Fittings
(ASTM) D2513–99 Standard Specification for 1999 Edition §§192.191(b);
Thermoplastic Gas Pressure Pipe, 192.281(b)(2);
Tubing, and Fittings
192.283(a)(1)(i);
Item-1,
Appendix-B.
(ASTM) D2517–00 Standard Specification for Reinforced 2000 Edition §§192.191(a);
Epoxy Resin Gas Pressure Pipe and 192.281(d)(1);
Fittings
192.283(a)(1)(ii);
Item-1,
Appendix-B.
(ASTM) F1055–98 Standard Specification for 1998 Edition §192.283(a)(1)(iii).
Electrofusion Type Polyethylene
Fittings for Outside ...
Gas GRI 02/0057 Internal Corrosion Direct Assessment 2002 Edition §192.927(c)(2).
Technology of Gas Transmission Pipelines
Methodology
Institute (GTI)
Gas GTI-04/0032 LNGFIRE: A Thermal Radiation Model 2004 Edition §193.2057.
Technology for LNG Fires
Institute (GTI)
Gas GTI–04/0049 LNG VaporDispersion Prediction with 2004 Edition §193.2059.
Technology the DEGADIS2.1: Dense Gas
Dispersion Model ...
Institute (GTI)
(GTI) GRI– Evaluation of Mitigation Methods for 1996 Edition §193.2059.
96/0396.5 Accidental LNG Releases, Volume 5:
Using FE ..
Manufacturers SP-44-2006 Steel Pipe Line 2006 Edition §192.147(a).
Standardization Flanges
Society of the
Valve and
Fittings
Industry, Inc. (
...
91
Manufacturers SP–75–2004 Specification for High Test Wrought 2004 Edition §195.118(a).
Standardization Butt Welding Fittings
Society of the
Valve and
Fittings
Industry, Inc. (
...
National SP0169–2007 Control of External Corrosion on 2007 Edition §§195.3; 195.571;
Association of Underground or Submerged Metallic 195.573(a)(2)
Piping System ...
Corrosion
Engineers
(NACE)
(NACE) SP0502–2008 Pipeline External Corrosion Direct 2008 Edition §§ 192.923;
Assessment Methodology 192.925;
192.931; 192.935;
192.939
National Fire NFPA 30 Flammable and Combustible Liquids 2008 Edition §192.735(b);
Protection Code §195.264(b)(1).
Association
(NFPA)
(NFPA) NFPA 58 Liquefied Petroleum Gas Code (LP-Gas 2004 Edition §192.11(a);
Code) 192.11(b);
192.11(c).
(NFPA) NFPA 59 Utility LP-Gas Plant Code 2004 Edition §§192.11(a);
192.11(b);
192.11(c).
(NFPA) NFPA 70 National Electrical Code 2008 Edition §§192.163(e);
192.189(c).
(NFPA) NFPA 59A Standard for the Production, Storage, 2001 Edition §§193.2019;
and Handling of Liquefied Natural 193.2051;
Gas(LNG ... 193.2057; 193.2059;
193.2101; 193.2301;
193.2303;
193.2401 ...
Plastics Pipe TR–3/2008 Policies and Procedures for Developing 2008 Edition §192.121.
Institute, Inc. Hydrostatic Design Basis(HDB),
Pressure ...
(PPI)
American Gas RSTRENG A Modified Criterion for Evaluating the 1993 Edition §§192.933(a)(1);
Association 3.0 User's Remaining Strength of Corroded Pipe 192.485(c).
(AGA) Manual and
Software
(Includes:
L51688B,
Modified
Criterion fo ...
American ANSI/API RP Design of Risers for Floating 1st N/A
Petroleum 2RD Production Systems(FPSs) and
Tension-Leg Platform ...
Institute (API)
92
American ANSI/API RP Pressure Testing of Steel Pipelines for 5th N/A
Petroleum 1110 the Transportation of Gas, Petroleum
Gas...
Institute (API)
(API) Pub 1161 Guidance Document for the 1st N/A
Qualification of Liquid Pipeline
Personnel
(API) Std 1163 In-Line Inspection Systems 1st N/A
Qualification Standard
(API) RP 1165 Recommended Practices for Pipeline 1st N/A
SCADA Displays
(API) RP 1167 Alarm Management 1st N/A
(API) RP 1168 Pipeline Control Room Management 1st N/A
American ANSI/ASME Pipeline Personnel Qualification 2006 N/A
Society of B31Q
Mechanical
Engineers
(ASME)
American ANSI/ASNT In-line Inspection Personnel 2005 N/A
Society for ILI-PQ Qualification and Certification
Nondestructive
Testing (ASNT)
National RP 0102 In-line Inspection of Pipelines 2002 N/A
Association of
Corrosion
Engineers
(NACE)
(NACE) TG 256 "Electrodes, Field-Grade Test Under N/A
Methods“Internal Corrosion Direct Development
(NACE) NACE Assessment Methodology for Pipelines 2006 N/A
SP0206 Carrying Normall ...
(NACE) NACE Internal Corrosion Direct Assessment 2008 N/A

SP0208 Methodology for Liquid Petroleum
Pipelines
Gas Piping ANSI/GPTC Guide for Gas Transmission and 2003 N/A
Technology Z380.1 Distribution Piping Systems Addenda 1
Committee through 12
(GPTC)
Gas Piping ANSI/GPTC DIMP Guidance N/A
Technology Z380.1
Committee
(GPTC)
National SP0106-2006 Internal Corrosion Control in Pipelines 192
Association of
Corrosion
Engineers
(NACE)
93
(NACE) TM0106-2006 Detection, Testing and Evaluation of 192 and 195
Micorbially Inlfuenced Corrosion(MIC)
on E ...
(NACE) SP0207 Performing Close-Interval Potential 192 and 195
Surveys and DC Surface Potential
Gradient Su ...
(NACE) SP0200-2008 Steel-Cased Pipelines Practices 195
(formerly
RP0200)
94
Chapter-4. Reference International Technical Standards
The reference international standards for designing gas fuel handling facility are organized in Table-20.
Table- 20: Reference International Technical Standards

Number Rev. Title Content
ISO 13623 2009 Petroleum and natural gas ISO 13623:2009 specifies requirements and
industries—Pipeline transportation gives recommendations for the design,
systems materials, construction, testing, operation,
maintenance and abandonment of pipeline
systems used for transportation in the petroleum
and natural gas industries.
ISO 13623:2009 applies to pipeline systems on
land and offshore, connecting wells,
production plants, process plants, refineries
and storage facilities, including any section of
a pipeline constructed within the boundaries of
such facilities for the purpose of its
connection. A figure shows the extent of
pipeline systems covered by ISO 13623:2009.
ISO 13623:2009 applies to rigid, metallic
pipelines. It is not applicable for flexible
pipelines or those constructed from other
materials, such as glass-reinforced plastics.
ISO 13623:2009 is applicable to all new
pipeline systems and can be applied to
modifications made to existing ones. It is not
intended that it apply retroactively to existing
pipeline systems.
ISO 13623:2009 describes the functional
requirements of pipeline systems and provides
a basis for their safe design, construction,
testing, operation, maintenance and
abandonment.
ISO 15649 2001 Petroleum and natural gas 1.1 This International Standard specifies the
industries—Piping requirements for design and construction of
piping for the petroleum and natural gas
industries, including associated inspection and
testing.
1.2 This International Standard is applicable to
all piping within facilities engaged in the
processing or handling of chemical,
petroleum, natural gas or related products.
EXAMPLE Petroleum refinery, loading
terminal, natural gas processing plant
(including liquefied natural gas facilities),
offshore oil and gas production platforms,
chemical plant, bulk plant, compounding
plant, tank farm.
1.3 This International Standard is also
applicable to packaged equipment piping
which interconnects individual pieces or
stages of equipment within a packaged
equipment assembly for use within facilities
engaged in the processing or handling of
chemical, petroleum, natural gas or related
products.
1.4 This International Standard is not
applicable to transportation pipelines and
95
associated plant.
ISO 13628 2011 Petroleum and natural gas industries -- ISO 13628-15:2011 addresses
Design and operation of subsea recommendations for subsea structures and
production systems -- Part 15: Subsea manifolds, within the frameworks set forth by
structures and manifolds recognized and accepted industry
specifications and standards. As such, it does
not supersede or eliminate any requirement
imposed by any other industry specification.
ISO 13628-15:2011 covers subsea manifolds
and templates utilized for pressure control in
both subsea production of oil and gas, and
subsea injection services.
ISO 13628-1 2005 Petroleum and natural gas industries -- ISO 13628-1:2005 provides general
Design and operation of subsea requirements and overall recommendations for
production systems -- Part 1: General development of complete subsea production
requirements and recommendations systems, from the design phase to
decommissioning and abandonment. ISO
13628-1:2005 is intended as an umbrella
document to govern other parts of ISO 13628
dealing with more detailed requirements for the
subsystems which typically form part of a
subsea production system. However, in some
areas (e.g. system design, structures, manifolds,
lifting devices, and color and marking) more
detailed requirements are included herein, as
these subjects are not covered in a subsystem
standard. The complete subsea production
system comprises several subsystems necessary
to produce hydrocarbons from one or more
subsea wells and transfer them to a given
processing facility located offshore (fixed,
floating or subsea) or onshore, or to inject
water/gas through subsea wells. ISO
13628-1:2005 and its related subsystem
standards apply as far as the interface limits
described in Clause 4. Specialized equipment,
such as split trees and trees and manifolds in
atmospheric chambers, are not specifically
discussed because of their limited use.
However, the information presented is
applicable to those types of equipment.
ISO 13628-2 2006 Petroleum and natural gas industries -- ISO 13628-2:2006 defines the technical
Design and operation of subsea requirements for safe, dimensionally and
production systems -- Part 2: Unbonded functionally interchangeable flexible pipes that
flexible pipe systems for subsea and are designed and manufactured to uniform
marine applications standards and criteria. Minimum requirements
are specified for the design, material selection,
manufacture, testing, marking and packaging of
flexible pipes, with reference to existing codes
and standards where applicable.
ISO 13628-2:2006 applies to unbonded flexible
pipe assemblies, consisting of segments of
flexible pipe body with end fittings attached to
both ends. ISO 13628-2:2006 applies to both
static and dynamic flexible pipes used as
flowlines, risers and jumpers. The applications
addressed by this ISO 13628-2:2006 are sweet
and sour service production, including export
and injection applications for production
products including oil, gas, water and injection
chemicals.
ISO 13628-2:2006 does not cover flexible pipes
96
of bonded structure or flexible pipe ancillary
components or to flexible pipes for use in
choke-and-kill line applications.
ISO 13628-3 2000 Petroleum and natural gas industries -- ―
Design and operation of subsea
production systems -- Part 3: Through
flowline (TFL) systems
ISO 14556 2000 Steel -- Charpy V-notch pendulum ―

impact test -- Instrumented test method
ISO 148 2009 Metallic materials -- Charpy pendulum ISO 148-1:2009 specifies the Charpy pendulum
impact test -- Part 1: Test method impact (V-notch and U-notch) test method for
determining the energy absorbed in an impact
test of metallic materials.
ISO 3183 2007 Petroleum and natural gas industries -- ISO 3183:2007 specifies requirements for the
Steel pipe for pipeline transportation manufacture of two product specification levels
systems (PSL 1 and PSL 2) of seamless and welded steel
pipes for use in pipeline transportation systems
in the petroleum and natural gas industries.
ISO 7005-1 2011 Pipe flanges -- Part 1: Steel flanges for ISO 7005-1:2011 establishes a base
industrial and general service piping specification for pipe flanges suitable for
systems general purpose and industrial applications
including, but not limited to, chemical process
industries, electric power generating industries,
petroleum and natural gas industries. It places
responsibility for the selection of a flange series
with the purchaser.
It is applicable to flanges within facilities
engaged in the processing or handling of a wide
variety of fluids, including steam, pressurized
water and chemical, petroleum, natural gas or
related products.
ISO 7005-1:2011 is also applicable to packaged
equipment piping, which interconnects
individual pieces or stages of equipment within
a packaged equipment assembly for use within
facilities engaged in the processing or handling
of a variety of fluids, including steam and
chemical, petroleum, natural gas or related
products
ISO 10474 1991 Steel and steel products _Inspection Defines the different types of inspection
documents. documents supplied to the purchaser. Shall be
used in conjunction with: ISO 404 for steel and
steel products; ISO 4990 for steel castings.
ISO 13847 2000 Petroleum and natural gas industries _ ―
Pipeline transportation systems _ Field
and shop welding of pipelines.
ISO 14313 2007 Petroleum and natural gas industries ISO 14313:2007 specifies requirements and
_Pipeline transportation systems provides recommendations for the design,
_Pipeline valves manufacturing, testing and documentation of
ball, check, gate and plug valves for application
in pipeline systems meeting the requirements of
ISO 13623 for the petroleum and natural gas
industries.
ISO 14313:2007 is not applicable to subsea
pipeline valves, as they are covered by a
separate International Standard (ISO 14723).
97
ISO 14723 2009 Petroleum and natural gas industries ISO 14723:2009 specifies requirements and
_Pipeline transportation systems gives recommendations for the design,
_Subsea pipeline valves. manufacturing, testing and documentation of
ball, check, gate and plug valves for subsea
application in offshore pipeline systems meeting
the requirements of ISO 13623 for the
petroleum and natural gas industries.
ISO 15761 2002 Steel gate, globe and check valves for ISO 15761 specifies the requirements for a
sizes DN 100 and smaller, for the series of compact steel gate, globe and check
petroleum and natural gas industries valves for petroleum and natural gas industry
applications. It is applicable to valves of
nominal sizes (DN) 8, 10, 15, 20, 25, 32, 40, 50,
65, 80 and 100, to corresponding nominal sizes,
to nominal pipe sizes (NPS) of a quarter, three
eighths, half, three quarters, one, one and a
quarter, one and a half, two, two and a half,
three and four, and to pressure designation
classes 150, 300, 600, 800 and 1500. It includes
provisions for a wide range of valve
characteristics and is applicable to valve end
flanges in accordance with ASME B16.5 and
valve body ends having tapered pipe threads to
ISO 7-1 or ASME B1.20.1.
ISO 17292 2004 Metal ball valves for petroleum, ISO 17292:2004 specifies the requirements for a
petrochemical and allied industries series of metal ball valves suitable for
petroleum, petrochemical, natural gas plants,
and related industrial applications. It covers
valves of the nominal sizes DN 8, 10, 15, 20,
25, 32, 40, 50, 65, 80, 100, 150, 200, 250, 300,
350, 400, 450 and 500, corresponding to
nominal pipe sizes NPS 1/4, 3/8, 1/2, 3/4, 1, 1
1/4, 1 1/2, 2, 2 1/2, 3, 4, 6, 8, 10, 12, 14, 16, 18
and 20, and is applicable for pressure
designations of Class 150, 300, 600 and 800
(the last applicable only for valves with reduced
bore and with threaded and socket welding end),
and PN 16, 25 and 40.
ISO 16708 2006 Petroleum and natural gas industries -- ISO 16708:2006 specifies the functional
Pipeline transportation systems -- requirements and principles for design,
Reliability-based limit state methods operation and re-qualification of pipelines in the
petroleum and natural gas industries using
reliability based limit state methods as permitted
by ISO 13623. Reliability-based limit state
methods provide a systematic way to predict
pipeline safety in design and operation.
ISO 16708:2006 supplements ISO 13623 and
can be used in cases where ISO 13623 does not
provide specific guidance and where limit states
methods can be applied, such as, but not limited
to
- qualification of new concepts, e.g. when new
technology is applied or for design scenarios
where industry experience is limited,
- re-qualification of the pipeline due to a
changed design basis, such as service-life
extension, which can include reduced
uncertainties due to improved integrity
monitoring and operational experience,
- collapse under external pressure in deep water,
- extreme loads, such as seismic loads (e.g. at a
fault crossing), ice loads (e.g. by impact from
98
ice keels),
- situations where strain-based criteria can be
appropriate.
ISO 16708:2006 applies to rigid metallic
pipelines on-land and offshore used in the
petroleum and natural gas industries.
ISO 13628 2011 Petroleum and natural gas industries -- ISO 13628-15:2011 addresses
Design and operation of subsea recommendations for subsea structures and
production systems -- Part 15: Subsea manifolds, within the frameworks set forth by
structures and manifolds recognized and accepted industry
specifications and standards. As such, it does
not supersede or eliminate any requirement
imposed by any other industry specification.
ISO 13628-15:2011 covers subsea manifolds
and templates utilized for pressure control in
both subsea production of oil and gas, and
subsea injection services.
IEC 60079-10 1995 Electrical apparatus for explosive gas Is concerned with the classification of
atmospheres _ Part 10: Classification of hazardous areas where flammable gas or vapor
hazardous areas. risks may arise, in order to permit the proper
selection and installation of apparatus for use in
such hazardous areas.
IEC 60079-14 1996 Electrical apparatus for explosive gas This part of IEC 60079 contains the specific
atmospheres _ Part 14: Electrical requirements for the design, selection and
installations in hazardous areas (other erection of electrical installations in hazardous
than mines). areas associated with explosive atmospheres.
Where the equipment is required to meet other
environmental conditions, for example,
protection against ingress of water and
resistance to corrosion, additional methods of
protection may be necessary. The method used
should not adversely affect the integrity of the
enclosure. The requirements of this standard
apply only to the use of equipment under
normal or near normal atmospheric conditions.
The significant technical changes with respect
to the previous edition are: Equipment
Protection Levels (EPLs) have been introduced
and are explained in the new Annex I and dust
requirements included from IEC 61241 14, Ed.
1.0.
ASME B31.3 1996 Process piping. Rules for piping typically found in petroleum
refineries; chemical, pharmaceutical, textile,
paper, semiconductor, and cryogenic plants; and
related processing plants and terminals. This
code prescribes requirements for materials and
components, design, fabrication, assembly,
erection, examination, inspection, and testing of
piping. This Code applies to piping for all fluids
including: (1) raw, intermediate, and finished
chemicals; (2) petroleum products; (3) gas,
steam, air and water; (4) fluidized solids; (5)
refrigerants; and (6) cryogenic fluids. Also
included is piping which interconnects pieces or
stages within a packaged equipment assembly.
ASME B31.4 2006 Pipeline Transportation Systems for The B31.4 Code prescribes requirements for the
Liquid Hydrocarbons and Other Liquids design, materials, construction, assembly,
inspection, and testing of piping transporting
liquids such as crude oil, condensate, natural
gasoline, natural gas liquids, liquefied
petroleum gas, carbon dioxide, liquid alcohol,
99
liquid anhydrous ammonia and liquid petroleum
products between producers' lease facilities,
tank farms, natural gas processing plants,
refineries, stations, ammonia plants, terminals
(marine, rail and truck) and other delivery and
receiving points. Piping consists of pipe,
flanges, bolting, gaskets, valves, relief devices,
fittings and the pressure containing parts of
other piping components. It also includes
hangers and supports, and other equipment
items necessary to prevent overstressing the
pressure containing parts. It does not include
support structures such as frames of buildings,
buildings stanchions or foundations
Requirements for offshore pipelines are found
in Chapter IX. Also included within the scope of
this Code are: (A) Primary and associated
auxiliary liquid petroleum and liquid anhydrous
ammonia piping at pipeline terminals (marine,
rail and truck), tank farms, pump stations,
pressure reducing stations and metering stations,
including scraper traps, strainers, and prover
loop; (B) Storage and working tanks including
pipe-type storage fabricated from pipe and
fittings, and piping interconnecting these
facilities; (C) Liquid petroleum and liquid
anhydrous ammonia piping located on property
which has been set aside for such piping within
petroleum refinery, natural gasoline, gas
processing, ammonia, and bulk plants; (D)
Those aspects of operation and maintenance of
liquid pipeline systems relating to the safety and
protection of the general public, operating
company personnel, environment, property and
the piping systems.
ASME B16.5 1996 Pipe flanges and flanged fittings _NPS This Standard covers pressure-temperature
1/2 through NPS 24. ratings, materials, dimensions, tolerances,
marking, testing, and methods of designating
openings for pipe flanges and flanged fittings.
Included are:
flanges with rating class designations 150, 300,
400, 600, 900, and 1500 in sizes NPS 1/2
through NPS 24 and flanges with rating class
designation 2500 in sizes NPS 1/2 through NPS
12, with requirements given in both metric and
U.S. Customary units with diameter of bolts and
flange bolt holes expressed in inch units
flanged fittings with rating class designation
150 and 300 in sizes NPS 1/2 through NPS 24,
with requirements given in both metric and U.S.
Customary units with diameter of bolts and
flange bolt holes expressed in inch units
flanged fittings with rating class designation
400, 600, 900, and 1500 in sizes NPS 1/2
through NPS 24 and flanged fittings with rating
class designation 2500 in sizes 1/2 through NPS
12 that are acknowledged in Nonmandatory
Appendix E in which only U.S. Customary units
are provided
ASME B16.9 2007 Factory-Made wrought butt-welding This Standard covers overall dimensions,
fittings tolerances, ratings, testing, and markings for
wrought carbon and alloy steel factory-made
buttwelding fittings of NPS 1/2 through 48. It
100
covers fittings of any producible wall thickness.
This standard does not cover low pressure
corrosion resistant buttwelding fittings. See
MSS SP-43, Wrought Stainless Steel
Butt-Welding Fittings.
Short radius elbows and returns, which were
previously included in ASME B16.28-1994, are
included in this standard.
B16.9 is to be used in conjunction with
equipment described in other volumes of the
ASME B16 series of standards as well as with
other ASME standards, such as the Boiler and
Pressure Vessel Code and the B31 Piping
Codes.
ASTM 1998 Standard specification for alloy-steel and This specification covers alloy steel and
A193A/193M stainless steel bolting materials for high stainless steel bolting material for pressure
temperature service. vessels, valves, flanges, and fittings for high
temperature or high pressure service, or other
special purpose applications. Ferritic steels shall
be properly heat treated as best suits the high
temperature characteristics of each grade.
Immediately after rolling or forging, the bolting
material shall be allowed to cool to a
temperature below the cooling transformation
range. The chemical composition requirements
for each alloy are presented in details. The steel
shall not contain an unspecified element for
ordered grade to the extent that the steel
conforms to the requirements of another grade
for which that element is a specified element.
The tensile property and hardness property
requirements are discussed, the tensile property
requirement is highlighted by a full size
fasteners, wedge tensile testing.
ASTM 1998 Standard specification for carbon and This specification covers a variety of carbon,
A194A/194M alloy steel nuts for bolts for high alloy, and martensitic and austenitic stainless
pressure or high temperature service, or steel nuts. These nuts are intended for
both. high-pressure or high-temperature service, or
both. Bars from which the nuts are made shall
be hot-wrought. The material may be further
processed by centerless grinding or by cold
drawing. Austenitic stainless steel may be
solution annealed or annealed and
strain-hardened. Each alloy shall conform to the
chemical composition requirements prescribed.
Hardness tests, proof of load tests, and cone
proof load tests shall be made to all nuts to meet
the requirements specified.
ASTM A350M 2007 Standard specification for carbon and This specification covers several grades of
low-alloy steel forgings, requiring notch carbon and low alloy steel forged or ring-rolled
toughness testing for piping flanges, forged fittings and valves for
components. low-temperature service. The steel specimens
shall be melt processed using open-hearth, basic
oxygen, electric furnace or vacuum-induction
melting. A sufficient discard shall be made to
secure freedom from injurious piping and undue
segregation. The materials shall be forged and
shall undergo heat treatment such as
normalizing, tempering, quenching and
precipitation heat treatment. Heat analysis and
product analysis shall be performed wherein the
steel materials shall conform to the required
chemical compositions of carbon, manganese,
101
phosphorus, sulfur, silicon, nickel, chromium,
molybdenum, copper, columbium, vanadium,
and nitrogen. The materials shall also undergo
tension tests and shall conform to the required
values of tensile strength, yield strength and
elongation. Impact tests shall also be performed
and the steel materials shall conform to the
required values of minimum impact energy,
temperature, and minimum equivalent absorbed
energy. Hardness and hydrostatic tests shall also
be performed.
API RP 5L1 2002 Railroad transportation of line pipe The recommendations provided herein apply to
the transportation on railcars of API
Specification 5L steel line pipe in sizes 23/8 and
larger in lengths longer than single random.
These recommendations cover coated or
uncoated pipe, but they do not encompass
loading practices designed to protect pipe
coating from damage.
API RP 5L2 2002 Recommended practice for internal This Recommended Practice provides for the
coating of line pipe for non-corrosive internal coating of line pipe used for
gas transmission service. non-corrosive natural gas service. It is limited to
the application of internal coatings on new pipe
prior to installation.
API RP 1102 2007 Steel pipelines crossing railroads and This recommended practice, Steel Pipelines
highways Crossing Railroads and Highways, gives
primary emphasis to provisions for public
safety. It covers the design, installation,
inspection, and testing required to ensure safe
crossings of steel pipelines under railroads and
highways. The provisions apply to the design
and construction of welded steel pipelines under
railroads and highways. The provisions of this
practice are formulated to protect the facility
crossed by the pipeline, as well as to provide
adequate design for safe installation and
operation of the pipeline.
API RP5LW Transportation of line pipe on barges and The recommendations in this document apply to
marine vessels transportation of API Specification 5L steel line
pipe by ship or barge on both inland and marine
waterways, unless the specific requirement of a
paragraph in this document references only
marine or only inland waterway transport.
Inland waterways are defined as those
waterways with various degrees of protection,
such as rivers, canals, intracoastal waterways,
and sheltered bays. These waterways can be
fresh or saltwater but are usually traversed by
barges. Marine waterways are defined as
waterways over open seas with limited or no
protection from wind, current, waves, and the
like. These areas are normally traversed by
sea-going vessels. These recommendations
apply to steel line pipe that has 2 3/8-in. outside
diameter (OD) and larger.
These recommendations cover coated or
uncoated pipe, but they do not encompass
loading practices designed to protect pipe
coating from damage. These recommendations
are not applicable to pipe-laying vessels or
supply vessels. They must be considered as
supplementary to the existing rules of governing
102
agencies.
These recommendations are supplemental to
shipping rules for the convenience of purchasers
and manufacturers in the specification of
loading and shipping practices and are not
intended to inhibit purchasers and
manufacturers from using other supplemental
loading and shipping practices by mutual
agreement.
API/ANSI 600 2009 Bolted Bonnet Steel Gate Valves for This International standard specifies the
Petroleum and Natural Gas Industries - requirements for a heavy-duty series of bolted
Modified National Adoption of ISO bonnet steel gate valves for petroleum refinery and
10434 related applications where corrosion, erosion and
other service conditions would indicate a need for
full port openings, heavy wall sections and large
stem diameters.
API Std 620 1996 Design and construction of large, This standard covers the design and
welded, low-pressure storage tanks. construction of large, welded, low-pressure
carbon steel above ground storage tanks
(including flat-bottom tanks) that have a single
vertical axis of revolution. This standard does
not cover design procedures for tanks that have
walls shaped in such a way that the walls cannot
be generated in their entirety by the rotation of a
suitable contour around a single vertical axis of
revolution.
The tanks described in this standard are
designed for metal temperatures not greater than
250°F and with pressures in their gas or vapor
spaces not more than 15 lbf/in.2 gauge.
The basic rules in this standard provide for
installation in areas where the lowest recorded
1-day mean atmospheric temperature is –50°F.
Appendix S covers stainless steel low-pressure
storage tanks in ambient temperature service in
all areas, without limit on low temperatures.
Appendix R covers low-pressure storage tanks
for refrigerated products at temperatures from
+40°F to –60°F. Appendix Q covers
low-pressure storage tanks for liquefied
hydrocarbon gases at temperatures not lower
than –270°F.
The rules in this standard are applicable to tanks
that are intended to (a) hold or store liquids with
gases or vapors above their surface or (b) hold
or store gases or vapors alone. These rules do
not apply to lift-type gas holders.
Although the rules in this standard do not cover
horizontal tanks, they are not intended to
preclude the application of appropriate portions
to the design and construction of horizontal
tanks designed in accordance with good
engineering practice. The details for horizontal
tanks not covered by these rules shall be equally
as safe as the design and construction details
provided for the tank shapes that are expressly
covered in this standard.
API Std 650 1993 Welded steel tanks for oil storage. API Std 650 establishes minimum requirements
for material, design, fabrication, erection, and
testing for vertical, cylindrical, aboveground,
closed- and open-top, welded carbon or stainless
steel storage tanks in various sizes and
capacities for internal pressures approximating
103
atmospheric pressure (internal pressures not
exceeding the weight of the roof plates), but a
higher internal pressure is permitted when
additional requirements are met. This Standard
applies only to tanks whose entire bottom is
uniformly supported and to tanks in
non-refrigerated service that have a maximum
design temperature of 93°C (200°F) or less.
API Std 1104 Welding of pipeline and related This standard covers the gas and arc welding of
facilities butt, fillet, and socket welds in carbon and
low-alloy steel piping used in the compression,
pumping, and transmission of crude petroleum,
petroleum products, fuel gases, carbon dioxide,
nitrogen and, where applicable, covers welding
on distribution systems. It applies to both new
construction and in-service welding. The
welding may be done by a shielded metal-arc
welding, submerged arc welding, gas
tungsten-arc welding, gas metal-arc welding,
flux-cored arc welding, plasma arc welding,
oxyacetylene welding, or flash butt welding
process or by a combination of these processes
using a manual, semiautomatic, mechanized, or
automatic welding technique or a combination
of these techniques. The welds may be produced
by position or roll welding or by a combination
of position and roll welding.
This standard also covers the procedures for
radiographic, magnetic particle, liquid
penetrant, and ultrasonic testing, as well as the
acceptance standards to be applied to production
welds tested to destruction or inspected by
radiographic, magnetic particle, liquid
penetrant, ultrasonic, and visual testing
methods.
The values stated in either inch-pound units or
SI units are to be regarded separately as
standard. Each system is to be used
independently of the other, without combining
values in any way.
Processes other than those described above will
be considered for inclusion in this standard.
Persons who wish to have other processes
included shall submit, as a minimum, the
following information for the committee's
consideration:
MSS SP-25 1998 Standard marking system for valves, American standard by Manufacturers
fittings, flanges and unions. Standardization Society for valve, fitting, flange
and union.
MSS SP-44 1996 Steel pipeline flanges. American standard by Manufacturers
Standardization Society for steel pipeline
flange.
MSS SP-75 2008 Specification for high-test, wrought, Covers factory-made, seamless and
butt-welding fittings electric welded carbon and low alloy
steel, butt-welding fittings for use in high
pressure gas and oil transmission and
distribution systems, including pipelines,
compressor stations, metering and
regulating stations, and mains. Governs
dimensions, tolerances, ratings, testing,
materials, chemical and tensile properties,
heat treatment, notch toughness
properties, manufacture and marking for
104
high-test, butt-welding fittings NPS 60
and smaller. Dimensional requirements for
NPS 14 and smaller are provided by
reference to ASME B16.9. The term
"welding fittings" applies to buttwelding
fittings such as elbows, segments of
elbows, return bends, caps, tees, single or
multiple-outlet extruded headers,
reducers, and factory-welded extensions
and transition sections.(1) Fittings may be
made to special dimensions, sizes, shapes,
and tolerances, or of wrought materials
other than those covered by this Standard
Practice by agreement between the
manufacturer and the purchaser. When
such fittings meet all other stipulations of
this Standard Practice they shall be
considered as being in partial compliance
there with, providing they are
appropriately marked. Fittings
manufactured in partial compliance, as
provided in Section 1.4, shall be
identified with "Part" following the
respective grade designation.
CSA Z245.20 2002 External fusion bonded epoxy coating This Standard covers the qualification,
for steel pope application, inspection, testing, handling, and
storage of materials required for plant-applied
fusion bond epoxy (FBE) coating applied
externally to bare steel pipe. The coated pipe is
intended primarily for buried or submerged
service for oil or gas pipeline systems. This
Standard does not cover dual powder FBE
coating systems or high temperature (a glass
transition temperature higher than 110 °C) FBE
coating systems.
BS 4164 2002 Specification for coal tar based hot Coatings, Protective coatings, Corrosion
applied coating materials for protecting protection, Primers (paint), Coal tar, Coal
iron and steel , including a suitable products, Fillers, Packaging, Marking, Sampling
primer methods, Determination of content, Volatile
matter determination, Density, Test equipment,
Testing conditions, Softening point,
Softening-point determination, Penetration tests,
Viscosity, Sag (deformation), Cracking, Bend
testing, Specimen preparation, Impact testing,
Peeling tests, Mechanical testing,
Low-temperature testing, Viscosity
measurement, Density measurement, Grades
(quality), Adhesion tests, Ignition-loss tests,
Distillation methods of analysis
BS 5353 1989 Specification for steel plug valves Design, materials, dimensions,
pressure/temperature ratings, wall thicknesses,
testing and marking of lubricated, and soft
seated and lined valves. Gives requirements for
anti-static features plus the option of a fire
tested design.
BS 6651 1999 Code of practice for the protection of This British Standard provides guidance on the
structures against lightning design of systems for the protection of
structures against lightning and on the selection
of materials. Recommendations are made for
special cases such as explosives stores and
temporary structures, e.g. cranes and spectator
stands constructed of metal scaffolding.
Guidance is also provided on the protection of
105
electronically stored data. This British Standard
outlines the general technical aspects of
lightning, illustrating its principal electrical,
thermal and mechanical effects. Guidance is
provided on how to assess the risk of being
struck and how to compile an index figure as an
aid to deciding whether a particular structure is
in need of protection.
BS 7430 1998 Code of practice for earthing This British Standard gives guidance on the
methods that may be adopted to earth an
electrical system for the purpose of limiting the
potential (with respect to the general mass of the
earth) of current-carrying conductors forming
part of the system, and non-current-carrying
metalwork associated with equipment,
apparatus, and appliances connected to the
system. This standard applies only to land-based
installations; it does not apply to ships, aircraft
or offshore installations, nor does it deal with
the earthing of medical equipment or the special
problems encountered with solid state electronic
components and equipment due to their
sensitivity to static electricity.
49CFR195 2012 Transportation of hazardous liquid by US federal regulation
pipeline This part prescribes safety standards and
reporting requirements for pipeline facilities
used in the transportation of hazardous liquids
or carbon dioxide.
NFPA 30 2008 Flammables and combustible liquids This code shall apply to the storage, handling,
code. and use of flammable and combustible liquids,
including waste liquids, as herein defined and
classified. 1.1.2 This code shall not apply to the
following: (1)* Any liquid that has a melting
point of 100°F (37.8°C) or greater (2)* Any
liquid that does not meet the criteria for fluidity
given in the definition of liquid in Chapter 3 and
in the provisions of Chapter 4 (3) Any cryogenic
fluid or liquefied gas, as defined in Chapter 3
(4)* Any liquid that does not have a flash point,
but which is capable of burning under certain
conditions (5)* Any aerosol product (6) Any
mist, spray, or foam (7)* Transportation of
flammable and combustible liquids as governed
by the U.S. Department of Transportation (8)*
Storage, handling, and use of fuel oil tanks and
containers connected with oil-burning
equipment A.1.1.1 This code is recommended
for use as the basis for legal regulations. Its
provisions are intended to reduce the hazard to a
degree consistent with reasonable public safety,
without undue interference with public
convenience and necessity, of operations that
require the use of flammable and combustible
liquids. Compliance with this code does not
eliminate all hazards in the use of flammable
and combustible liquids. (See the Flammable
and Combustible Liquids Code Handbook for
additional explanatory information.) A.1.1.2(1)
Liquids that are solid at 100°F (37.8°C) or
above, but are handled, used, or stored at
temperatures above their flash points, should be
reviewed against pertinent sections of this code.
A.1.1.2(2) The information in A.1.1.2(1) also
106
applies here. A.1.1.2(4) Certain mixtures of
flammable or combustible liquids and
halogenated hydrocarbons either do not exhibit
a flash point using the standard closed-cup test
methods or will exhibit elevated flash points.
However, if the halogenated hydrocarbon is the
more volatile component, preferential
evaporation of this component can result in a
liquid that does have a flash point or has a flash
point that is lower than the original mixture. In
order to evaluate the fire hazard of such
mixtures, flash point tests should be conducted
after fractional evaporation of 10, 20, 40, 60, or
even 90 percent of the original sample or other
fractions representative of the conditions of use.
For systems such as open process tanks or spills
in open air, an open-cup test method might be
more appropriate for estimating the fire hazard.
A.1.1.2(5) See NFPA 30B, Code for the
Manufacture and Storage of Aerosol Products.
A.1.1.2(7) Requirements for transportation of
flammable and combustible liquids can be
found in NFPA 385, Standard for Tank Vehicles
for Flammable and Combustible Liquids, and in
the U.S. Department of Transportation’s
Hazardous Materials Regulations, Title 49,
Code of Federal Regulations, Parts 100–199.
A.1.1.2(8) See NFPA 31, Standard for the
Installation of Oil-Burning Equipment.
NFPA 220 2012 Standard on types of building This standard defines types of building
construction. construction based on the combustibility and the
fire resistance rating of a building’s structural
elements. Fire walls, nonbearing exterior walls,
nonbearing interior partitions, fire barrier walls,
shaft enclosures, and openings in walls,
partitions, floors, and roofs are not related to the
types of building construction and are regulated
by other standards and codes, where
appropriate.
AS 2885 2003 A modern standard for design, The suite of Standards that makes up the
construction, operation and maintenance Australian Standard AS2885 "Pipelines – Gas
of high integrity petroleum pipelines. and liquid petroleum" has been benchmarked
against equivalent international and national
Standards including ASME B31.8, CSA Z662,
ISO 13623, API 1104, and ISO 13847. The
benchmarking shows that AS2885 is superior in
many detailed technical respects to its
counterparts elsewhere, and that it better
represents the current international state of the
art in the design, construction, testing, operation
and maintenance of petroleum pipelines.
It is accepted by all of the stakeholders as the
single and sufficient set of technical
requirements . It uses an integral risk
assessment and threat mitigation process in
design and for the whole of the life of the
pipeline in operation and maintenance. It has
explicit requirements for the design,
documentation, and approval of key processes
such as prevention of external interference,
control of fracture, and welding procedure
qualification. And it assigns responsibility for
the key processes to suitably qualified,
experienced, and trained people who take
107
responsibility for their actions in writing.
Amongst other reasons that has allowed the
development of a worlds best practice Standard
in Australia is the relatively small and agile
committee process, and the involvement of
many of the key contributors to the Standard in
industry sponsored research projects. This
involvement has simultaneously ensured that
they are abreast of the latest developments, and
that they are able to incorporate those
developments in the Standard as and when they
happen.
BS PD8010 2009 Code of practice for pipelines PD 8010-2:2004 gives recommendations for
and guidance on the design, use of materials,
construction, installation, testing,
commissioning and abandonment of carbon
steel subsea pipelines in offshore, nearshore and
landfall environments. Guidance on the use of
flexible composite pipelines is also given.
It is not intended to replace or duplicate
hydraulic, mechanical or structural design
manuals.
This part of PD 8010 is applicable to subsea
pipelines intended for the conveyance of
hydrocarbon liquids, hydrocarbon gases and
other gases, liquids and gases in two-phase flow,
fluid-based slurries and water. UK standard.
CSA Z662 2011 Oil and gas pipeline systems The 2011 edition of CSA Z662 provides
guidance in the design, operation and
maintenance of Canada's oil and gas pipeline
systems. The sixth edition addresses relevant
industry changes related to legislation,
regulation, management systems and
technology. It is a Canadian national standard
and is incorporated in federal and provincial
pipeline safety legislation.
DNV OS-F101 2010 Submarine Pipeline Systems Norway standard.
The revised Submarine Pipeline Standard
complies now with the new ISO 3183 on line
pipe material, with additional and modified
requirements. This is the only pipeline standard
in the world in compliance with ISO 13623 on
pipeline design. The DNV standard also has
increased focus on pipeline integrity during the
operational phase. Further, the document is
easier to follow and gives improved guidance
and interpretations compared with the previous
revision.
The ISO requirements are repeated, with any
additional or modified requirements clearly
marked. DNV's intention is therefore to get the
best out of two worlds; in compliance with ISO
but still self-contained.
In addition to the line pipe section, the
component section has been updated to reflect
new ISO standards. A list of other relevant
standards, although not compulsory, has been
included.
DNV’s intention is for this document to now
stipulate most of the additional requirements
that purchasers normally specify regarding
ISO/API.
108
DVGW G463 2009 Gas supply systems—Pipelines for German standard.
maximum operating pressure over 16
bar
IGE/TD/1 2001 Steel pipelines for high-pressure gas UK standard.
transmission (provisional section on
pipeline sleeving).
SNiP 1985 Construction regulation and rules. Trunk This Code covers design and engineering of
2.05.06-85 pipelines new mainline cross-country pipelines, as well as
those under construction, and bran¬ches from
these pipelines, the nominal pipe size being up
to 1400 mm inclusive, with the gauge pressure
of the carried fluid ranging from 1.2 MPa (12
kgf/cm2) to 10 MPa (100 kgf/cm2) (in the case
of laying a single pipeline or parallel pipelines
along a single lane), which pipelines are
intended for transporting the following
products: a) crude oil, petroleum products
(including stable condensate and stable
gasoline), natural, associated petroleum and
manufac¬tured hydrocarbon gases from the
areas of recovery (from the oil and gas fields or
storage sites, to the consumers (petroleum
storage , transfer tank farms, filling stations, gas
distributing stations, individual industrial or
agricultural enterprises, and terminals); b)
liquefied hydrocarbon gases of fractions C3 and
C4 and mixtures of these, unstable gasoline and
associated gas condensate, as well as other
liquefied hydrocarbons having saturated vapor
pressure at a temperature of plus 40°C not
exceeding 1.6 MPa (16 kgf/ cm2), from the
areas of their recovery (producing fields) or
production (from the origin pump stations) to
the consumers; c) commodity products within
the area of compressor stations (CS), and pump
stations (PS), underground gas storage stations
(UGSS),. booster compressor stations (BCS),
gas distributing stations (GDS), and gas meter
stations (GMS); d) control, fuel and starting gas
for CSs, UGSSs, BCSs, GDSs, GMSs, and city
gate stations (CGS) or pressure reducing
stations (PRS).
SNiP 1981 Construction code and guidelines. Trunk Russian standard.
3.42-80 pipelines This code shall govern construction of new and
reconstruction of working trunk pipelines and
their branches having a nominal diameter up to
1400 mm, inclusive, and access pressure not
exceeding 10 MPa (100 kgf/cm2.)
109
Chapter-5. Reference Japanese Technical Standards
The reference Japanese industrial standards for designing gas fuel handling facility are organized in
Table-21.
Table- 21: Reference Japanese Technical Standards

JIS K0091 2008 Method for determination of carbon This stipulates how to analyze the carbon
disulfide in fuel gas disulfide in the exhaust gas.
JIS K0804 2008 Gas detector tube measurement system This stipulates about the tube-shaped gas
(length-of-strain type) measuring detector for a short period time.
JIS G3476 2011 Petroleum and natural gas This stipulates about seamless steel pipe and
industries—Steel pipe for pipeline welded steel pipe products (Grade PSL1 and
transportation systems PSL2) used for transportation in oil and gas
industry.
JIS Z3050 2010 Method of nondestructive examination This stipulates the non-destructive testing
for weld of pipeline methods of for circumferential butt weld joint
with its diameter is more than 100mm and less
than 2,000mm, with its thickness more than
6mm and less than 40mm for the pipeline to
transport oil and gas by using pipe in normal
operation pressure 0.98MPa and more.
JIS Z2300 2008 Terms and definitions of nondestructive This stipulates major terms and definitions used
in industrial non-destructive testing.
JIS Z2306 2009 Radiographic image quality indicators for This stipulates about penertometer to be used
non-destructive testing for X-ray or γ-ray radiographic testing.
JIS Z2343-1 2010 Non-destructive testing － Penetrant This stipulates penetrant testing method and
testing－Part 1 : General principles－ classification method of indication patterns
Method for liquid penetrant testing and which is used detect crack opening the surface
classification of the penetrant indication such as crack, overlapping, wrinkles, porosity
and incomplete fusion.
JIS Z2343-2 2006 Non-destructive testing---Penetrant This stipulates technical requirement for type
testing—Part2: Testing of penetrant testing and lot testing of liquid penetrant,
materials procedure of testing, management and method
on site.
JIS Z2343-3 2010 Non-destructive testing---Penetrant This stipulates 3 types of specimen of
testing—Part3: Reference test blocks comparison tests. Type-1 is used to determine
the sensitivity levels of both penetrant and
fluorescent dye penetrant products. Type-2 and
3 specimens are used to periodically examine
the performance of equipment and agents for
penetrant and fluorescent dye penetrant.
JIS Z2343-4 2010 Non-destructive testing---Penetrant This stipulates the characteristics of test
testing—Part4: Equipment equipment used for liquid penetrant
examination.
JIS Z2345 2010 Standard test blocks for ultrasonic testing This stipulates the standard specimens which is
used to calibration, adjustment of ultrasonic test
equipment and the sensitivity adjustment.
JIS Z3060 2011 Method for ultrasonic examination for This stipulates detection method, measurement
welds of ferritic steel of location and dimension defects of the full
penetrated weld for ferritic steel with more than
6mm thickness by ultrasonic test using
pulse-echo technique by manual.
110
JIS Z3104 2010 Methods of radiographic examination for This stipulates the radiographic transmission
welded joints in steel testing of steel welding joint by direct shooting
method and by using X-ray or γ-ray using
industrial X-ray film.
JIS Z4560 2008 Industry γ-ray apparatus for radiography This stipulates about industrial γ-ray equipment
used for γ-ray transmission testing.
JIS Z4561 2008 Viewing illuminators for industrial This stipulates industrial observation
radiograph instruments for grading of radiographic photos
obtained by X-ray or γ-ray transmission testing.
JIS Z4606 2000 Industrial---X-ray apparatus for This stipulates about industrial X-ray
radiographic testing equipment used for X-ray transmission testing.
JIS K2251 2007 Crude petroleum and petroleum This stipulates method to sample specimens of
products---Sampling crude oil, petroleum products, semi-finished
products, residue in the tank and sediment from
static tank, tank lorry, drum, oil tanker, barge
and pipeline.
JGA-104-03 2004 Guideline for spherical gas storage tank ―
2006 Guideline for high pressure gas pipeline ―
2008 Check point of the welding procedure ―
1998 Guideline for cylindrical gasholder ―
1982 Guideline for water seal gasholder ―
JGA-106-05 1992 Guideline for LPG storage tank ―
2011 Guideline of seismic design for gas ―
generation facility
111
Chapter-6. Reference TCVN
The reference Vietnamese national standards for designing gas fuel handling facility are organized in
Table-22.
Table- 22: Reference TCVN

TCVN 3745-2 2008 System for design documentation. Rules Lập những quy tắc lập bản vẽ ống, đường ống
of making drawings of pipes, pipelines và hệ thống đường ống nằm trong bộ tài liệu
and pipe line systems thiết kế của sản phẩm thuộc tất cả các ngành
công nghiệ
TCVN 4090 1985 Main pipelines for transporting oil and Ap dụng khi thiết kế mới, thiết kế cải tạo, phục
oil products. Design standard hồi và mở rộng các công trình đường ống chính
dẫn dầu và sản phẩm dầu và đường ống nhánh
bằng thép có đường kính không lớn hơn 1400
mm
TCVN 4606 1988 Main pipeline used for transportation of Ap dụng để thi công và nghiệm thu các đường
petrol and petrol products. Rules for ống chính và đường ống nhánh bằng thép có
implementation and acceptance đường kính không lớn hơn 1000 mm, có áp suất
bơm chuyển không lớn hơn 1000 N/cm2, dùng
để vận chuyển dầu mỏ, sản phẩm dầu mỏ và khí
đốt
TCVN 5066 1990 Underground pipelines transferring áp dụng cho việc thiết kế mới phục hồi cải tạo,
gases, petroleum and petroleum products. mở rộng đường ống chính dẫn khí đốt, dầu mỏ
General requirements for design and và sản phẩm dầu mỏ đặt ngầm dưới đất
corrosion protection
TCVN 5422 1991 System of design documents. Symbols of Qui định ký hiệu qui ước và đơn giản của
pipelines đường ống và các phần tử của đường ống
TCVN 6022 1995 Petroleum liquids. Automatic pipeline Qui định các qui trình lấy mẫu tự động để nhận
sampling được các mẫu đại diện của dầu thô và các sản
phẩm dầu mỏ lỏng chuyên chở đường ống
TCVN 6475-1 2007 Rules for Classification and Technical Tiêu chuẩn này quy định các yêu cầu về phân
Supervision of Subsea Pipeline Systems. cấp và giám sát kỹ thuật trong quá trình thiết
Part 1: General Requirement kế, chế tạo và khai thác các hệ thống đường ống
biển, kể cả các hệ thống đường ống đặt ở các
cửa sông và vùng biển Việt Nam dùng để vận
chuyển riêng lẻ hoặc hỗn hợp các chất hydrô
cácbon ở trạng thái lỏng hoặc khí, như dầu thô,
các sản phẩm của dầu, các loại khí.
Part 2: Classification of Subsea Pipeline kế, chế tạo và khai thác các hệ thống đường ống
Systems biển, kể cả các hệ thống đường ống đặt ở các
Part 3: Requalification kế, chế tạo và khai thác các hệ thống đường ống
112
Part 4: Design Philosophy kế, chế tạo và khai thác các hệ thống đường ống
các sản phẩm của dầu, các loại khí. Tiêu chuẩn
này đưa ra các quy định về các nguyên tắc thiết
kế một hệ thống đường ống biển.
TCVN 6475-5 2007 Rules for Classification and Technical Tiêu chuẩn này quy định các yêu cầu mấu chốt,
Supervision of Subsea Pipeline Systems. cần thiết trong việc thiết kế, lắp đặt, vận hành
Part 5: Design Premises và chứng nhận lại các hệ thống đường ống biển.
TCVN 6475-6 2007 Rules for Classification and Technical Tiêu chuẩn này đưa ra các quy định về điều
Supervision of Subsea Pipeline Systems. kiện tải trọng và hiệu ứng tải trọng đặc trưng
Part 6: Loads được sử dụng trong thiết kế các hệ thống đường
ống biển tỏng cả giai đoạn xây lắp và giai đoạn
vận hành.
TCVN 6475-7 2007 Rules for Classification and Technical Tiêu chuẩn này quy định các chỉ tiêu thiết kế và
Supervision of Subsea Pipeline Systems. các chỉ tiêu chấp nhận các dạng phá huỷ kết cấu
Part 7: Design Criteria có thể xảy ra đối với hệ thống đường ống biển.
TCVN 6475-8 2007 Rules for Classification and Technical Tiêu chuẩn này quy định các yêu cầu đối với
Supervision of Subsea Pipeline Systems. vật liệu, quá trình chế tạo, thử nghiệm và hồ sơ
Part 8: Linepipe của hệ thống đường ống về các tính chất đặc
trưng của vật liệu sau khi nhiệt luyện, giãn nở
và tạo dáng lần cuối.
TCVN 6475-9 2007 Rules for Classification and Technical Tiêu chuẩn này quy định những yêu cầu về thiết
Supervision of Subsea Pipeline Systems. kế, chế tạo, lắp đặt, thử nghiệm và hồ sơ của
Part 9: Component and Assemblies các bộ phận đường ống và các hạng mục kết
cấu. Ngoài ra, tiêu chuẩn này còn quy định
những yêu cầu về chế tạo và thử nghiệm các
ống đứng, các vòng dãn nở, các đoạn ống dùng
để cuộn ống và kéo ống.
TCVN 6475-10 2007 Rules for Classification and Technical Phạm vi áp dụng của phần này bao gồm chống
Supervision of Subsea Pipeline Systems. ăn mòn bên trong và bên ngoài đường ống và
Part 10: Corrosion Protection and Weight ống đứng cũng như lớp bọc bê tông gia tải để
Coating chống nổi đường ống.
TCVN 6475-11 2007 Rules for Classification and Technical Tiêu chuẩn này được áp dụng cho việc lắp đặt
Supervision of Subsea Pipeline Systems. và kiểm tra các đường ống và ống đứng cứng
Part 11: Installation được thiết kế và chế tạo theo các yêu cầu cảu
tiêu chuẩn này.
TCVN 6475-12 2007 Rules for Classification and Technical Tiêu chuẩn này áp dụng cho tất cả các quá trình
Supervision of Subsea Pipeline Systems. chế tạo trong xưởng hoặc ngoài hiện trường,
Part 12: Weldings bao gồm cả quá trình xử lý nhiệt sau khi hàn.
TCVN 6475-13 2007 Rules for Classification and Technical Tiêu chuẩn này quy định các yêu cầu đối với
Supervision of Subsea Pipeline Systems. các phương pháp, thiết bị, quy trình, chỉ tiêu
Part 13: Non Destructive Testing chấp nhận, chứng nhận các chứng chỉ cho các
nhân sự thực hiện kiểm tra bằng mắt thường và
kiểm tra không phá huỷ (NDT) vật liệu thép
C-Mn, thép duplex, các loại thép không gỉ khác
và các vật liệu thép có lớp phủ chống ăn mòn,
các đường hàn được sử dụng trong các hệ thống
đường ống.
113
Chapter-7. Comparison table of regislation related to pipeline.
Table- 23: Comparison table of legislations related to pipeline
Act Gas Business Act (JP) Mining Act (JP) High Press. Gas Safety Act (JP) Electric Business Act (JP) Oil pipeline Business Act (JP) Act of each countries
Technical Technical regulation for gas Technical regulation for facilities Schedule of high press. Gas Technical regulation for power Technical regulation for oil
49 CFR 192 “Transportation of natural and other gas by pipeline”
Regulation facility used for mining activity ordinance generation facility pipeline facility
Interpretation for technical Guideline for technical regulation KHK standard, JIS standard, etc. Interpretation for technical
Standard regulation for gas facility for facilities used for mining regulation for power generation ― ASME B31.8-1999 ISO 13623-2000
activity facility
Material ・Main material for gas facility ・ The steel pipe for oil ・Same as the item of structure. ・Main material for pressure part ・ Material for pipe, fitting and ・ Specification names of main ・ Materials used for pipeline
must have the safety mechanical transportation must withstand the must have the safety mechanical valve (hereinafter called materials are listed in main body, system must have necessary
property under the maximum and maximum operating pressure and property under the maximum and “pipeline, etc.”) must conform to available standard name are mechanical properties to satisfy
minimum operating temperature. load applied at the installed point. minimum operating temperature. the standards prescribed by notice listed in annex. the design requirements such as
・Gas is included in the oil. or must have mechanical strength and toughness.
properties equivalent them. ・To be suitable for assembly and
・JIS, API, etc are quoted. ・ No specific quotation from ・JIS is quoted. ・JIS, API are quoted. ・ JIS is quoted according to ・ASTM, API are quoted. construction methods.
standard. notice.
Structure ・ The structure must be proper ・ The steel pipe for oil ・ The structure must have ・ The structure must be proper ・The structure of pipeline, etc. ・Design must be performed in ・Load that may cause destruction
under the working load, transportation must withstand the sufficient strength for maximum under the working load, must be safe against stress caused consideration with following of pipeline or loss of function
maximum pressure at maximum maximum operating pressure and stress generated in the normal maximum pressure at maximum by the weight of oil to be fracture mode properly; must be identify are design stage
working temperature and load applied at the installed point. operation pressure or temperature working temperature and transported, inner pressure and (1) yield and be considered.
minimum temperature. ・Gas is included in the oil. depending on the shape, minimum temperature. the like. (2) Buckling ・ Functional, environmental,
dimension, allowable stress on ・ The minimum thickness is (3) Fatigue, etc. construction, accidental load and
material at normal operation stipulated for every pipe their combination must be
temperature and welding diameter. considered.
efficiency, etc. of such pipeline,
or must have sufficient strength
corresponding to the normal
operating pressure and is
produced by the producer who is
allowed as appropriate producer
who has the production
technical or inspection
technology of pipe by METI .
114
Calculation ・The equation for minimum wall ・No provision. ・ The calculation formula for ・ The calculation formula for ・ Expected load such as inner ・ The minimum wall thickness ・Formula of the minimum wall
of piping thickness against inner pressure minimum wall thickness against minimum wall thickness against pressure, soil pressure, hydraulic against inner pressure (wall thickness in the circumferential
thickness and the calculation formula for inner pressure is set forth. inner pressure, earth pressure and pressure, train and vehicle is thickness varies with coefficients direction against inner pressure
minimum wall thickness against road load is set forth. prescribed by the ordinance. designed by Location Class). (wall thickness varies with
earth pressure and road load is set ・To be thicken, if a large force coefficients designed by Location
forth and the greater one is Generated stress by the load is; such as scour, landslides, Class) and composite stress.
adopted. Primary load, etc. ≦0.5σ y earthquake and liquefaction is
・（Outer pressure） Pressure load≦0.4σ y possible to apply.
2.5(K f W f ＋K tWt )
t＝ Do＋C
σ There is the regulation equation;
Combination of primary load
and secondary load≦0.9σy
・（Inner pressure）・No provision. ・（Inner pressure）・（Inner pressure）・（Inner pressure）・（Inner pressure）・（Inner pressure）
(1) When the ratio between outer (1) When the ratio between outer (1) When the ratio between outer ・The formula is provided. 2S t (D0 − t min )
P＝ FET σ hp＝( pid − p od )
diameters to inner diameter is 1.5 diameters to inner diameter is 1.5 diameters to inner diameter is 1.5 D 2 × t min
or less. or less. or less. F＝0.4～0.8
PDo PDo PDo

t＝＋C t＝＋C t＝＋C
2σ aη＋0.8 P 2σ aη＋0.8 P 2σ aη＋0.8 P
(2) When the ratio between outer (2) When the ratio between outer (2) When the ratio between outer
diameters to inner diameter is diameters to inner diameter is diameters to inner diameter is
more than 1.5. more than 1.5. more than 1.5.
Do  aａη－P  Do  aａη－P  Do  aａη－P 

t＝ 1－ ＋C t＝ 1－ ＋C t＝ 1－ ＋C
2  a aη－P  2  a aη－P  2  a aη－P 
Earthquake ・Quoted seismic design of gas ・No provision. ・ No stipulation in the general ・Refer to safety rule related the ・Provision by notice. ・No specific provision. ・ The formula has not been
resistant facility. rule. complex rule ( No.717/1987/ ・Consideration based on stress. shown, though earthquake has
Middle and low pressure: (Complex rule: The construction Environmental Protection and been to consider as environmental
Guideline for seismic design of of pipeline must be safe against Industrial Location Bureau load.
middle and low pressure gas the stress caused by earthquake
pipeline. *** and other secondary load.)
High pressure: Guideline for
seismic design of high pressure
pipeline and guideline for ・Allowable stress design method ・Allowable stress design method ・Allowable stress design method
liquefaction seismic design of Level-1 Level-1 Level-1
high gas pipeline.
・ Level-2 earthquake is
115
considered in case of high
pressure pipeline.
Pressure test ・Pressure test for pressure part ・To pass the pressure test under ・To withstand pressure test under ・Pressure test for pressure part ・Hydro pressure test for pipeline, ・ Different with each class ・More than 1.25 times, at least
must be performed by appropriate at least 1.5 times of maximum at least 1.5 times of normal must be performed by appropriate etc. must be performed 1.5 times locations. (design factor, one hour by water, or air when
method. (excluding those that operating pressure. operation pressure. method. of operating pressure by the location) water is unavailable. (1.20 times
have passed RT ・Pressure test or air tightness test ・At least 1.25 times in case of ・1.5 times of maximum operating method specified in the notice. Class1, Dev.1 ： more than 1.25 is possible for C, D fluid that
・1.5 times of maximum operating must be performed. gas. pressure. times by water does not exceed 1.05 times.)
pressure. Class1, Dev.2 ： more than 1.1 ・More than 1.1 times, at least 8
times by water or air hours as leak test after the
Class2 ：more than 1.25 times by strength test.
water or air
Class3&4：more than 1.4 times by
water
Air tightness ・ No leakage when performing ・To pass the air-tight examination ・To pass the air-tight examination ・ No leakage when performing ・No provision. ・No provision. ・No provision.
test air-tight examination in more than 1.1 times of maximum more than normal operation air-tight test.
appropriate method. operation pressure. pressure. ・ 1.1 times of the maximum
・ Air-tight examination under ・ Air-tight examination or operating pressure.
maximum operating pressure or pressure test must be performed.
normal operating pressure must
be performed.
Welding part ・Welding part of the gas facility ・ Pipe joint must be made by ・ Non-destructive testing is ・ Welding part of the electric ・ The welding of pipeline, etc. ・Welding procedure and welder ・Welding procedure and welder
where gas passing through and welding method that has required when testing by gas facilities where gas passing must be performed by the welding must be pursuant to API 1104. must be pursuant to ISO 13847.
bear 0MPa and more must have equivalent effect of other than arc pressure only. through and bear 0.98MPa and method such as arc welding
good melting, no harmful defects welding. However, it may be more must have safety shape. stipulated in notice.
due to crack by welding and have other safety method that has (liquefied gas pipeline) ・The welding equipment, welding
strength at least as required as necessary strength for safety ・ Welding part must not have consumables used for welding of
design strength. when welding is not proper. cracking and could arise cracks. pipeline must have performance
・Confirmation of WPS, welder ・Confirmation of WPS, welder equivalent or more than standard
test, appropriate non-destructive test, appropriate non-destructive stipulated in notice.
testing and criteria for RT in case testing and criteria for RT must ・The welding method and other
of high pressure and middle be pursuant to JIS Z3104. necessary matter for welding
pressure pipeline with 150mm must be stipulated in notice.
diameter and more must be
pursuant to JIS Z3104.
116
Gas drip box ・Gas drip box must be provided ・ Measure to remove moisture ・Measure to remove water must ・No provision. ・No provision. ・No provision. ・No provision.
on pipeline which may between natural gas pipeline and be taken.
accumulate water. its connected compressor must be
taken.
Corrosion ・ Measure to prevent corrosion ・ Appropriate measures for ・ Measure to prevent corrosion ・The appropriate measures must ・ The painting, coating and ・ Must be painted or covered ・ Corrosion control must be
protection must be taken, if there is risk of corrosion protection must be must be taken when burring be taken if there is a risk of electrical corrosion protection inconsideration with installation performed to prevent the risk of
corrosion. taken for pipeline that installed in underground. corrosion. must be applied the pipeline conditions, operation non-operation due to destruction
the place where the much risk of installed underground or on environment and cathodic by corrosion during design life.
corrosion is. seabed. protection condition. ・ The outer electricity supply
method is stipulated.
Protection ・Measure to prevent damage due ・Protective equipment and sign ・Signs must be installed when ・Appropriate protective measures ・The protection equipment must ・Pipeline must be protected from ・No provision.
measures to contact exposed pipeline on the must be provided if there is a risk installing pipeline on the ground, must be taken if there is a risk of be installed according to notice if damage or accidents by vehicles
road with vehicles must be taken. of damage due to collision to pipeline must be buried under damage. there is a risk of damage on in exposed places such as
vehicle when installing on a more than 0.6m and provided pipeline or support due to the intersection with pipe-rack or
ground. signs when installing pipeline collision of vehicle, vessel and bridge by means of separation or
・Protective measure to prevent buried under the ground surface. the like. barrier.
damage of the riser pipe by vessel ・When installing in the water,
must be taken and must be appropriate depth that no affect
provided sign when installing on by vessel and wave.
the seabed, etc. ・（ Complex rule stipulates to
install pipeline in the protective
structure when burying it raid
across the road, railroad, river or
waterway.
Interrupting ・Emergency shutoff device for ・ Gas shutoff device must be ・ No stipulation in general ・Shutoff equipment to block the ・Every 4km for an specified area ・ The interval between section ・Section shutoff valves must be
device pipeline that are buried in provided in the junction point of rule.( Complex rule: Emergency inflow and outflow of gas must be in an ordinance. shutoff valves must be less than provided at start, end and the
alongside the road such as gas pipeline. Pipeline must be placed shutoff device must be provided provided at the main entrance of ・Specified in notice; following; points for following items on
shutoff device. in a suitable position when in every 4km for pipeline gas equipment. Every 4km for back and forth of (1) Class1：20mile pipeline;
pipeline across the city, etc. crossing urban area, etc. At the ・（ The last place entering the river and channel crossing, (2) Class2：15mile (1) Operation and maintenance
same time, measure that can common culvert and junction necessary place for safety (3) Class3：10mile (2) Emergency control
transport gas to every section and point and other point where management of mountain slope (4) Class4：5mile (3) Limit of runoff
be replaced by an inert gas must necessary for maintenance of and city area, every 10km for
be taken. ) pipeline.） outside town.
Leak ・No provision. ・ Leak detection equipment or ・ No provision in general rule. ・Appropriate measures to prevent ・Leak detection equipment and ・No provision. ・Testing and recording must be
detection leak detection hole must be (Complex rule: gas leak detection harm must be taken in case of gas leak detection hole must be performed periodically to confirm
117
device provided where necessary. alarm equipment or leak detection leak. provided on pipeline system. the suitability of operation
mouth must be provided on the ・（ Ventilation equipment in requirements.
flammable gas pipeline.) common duct, leak detection
alarm equipment must be
provided where gas may leak. ）
Protection ・No provision. ・To provide operation condition ・ No provision in general rule. ・No provision. ・Monitoring device to monitor ・ No specific provision. (The ・ Emergency shutdown system,
device monitoring equipment. (Complex rule: alarm device must the operating status of equipment provision of emergency shutoff pressure regulating system,
・To provide alarm system in the be provided for abnormal such as compressor and valves device that can isolate and monitoring system and
event of abnormal fluctuation of pressure and flow on pipeline.) must be provided on pipeline. dissipate gas is stipulated in the communication system must be
pressure and flow rate. ・Warning device to indicate in item of compressor station.) provided in station.
the event of an abnormal situation
such as unusual changes in
pressure or flow rate must be
provided according to notice.
Installation ・・・・Protection measure for buried ・To be buried underground. ・ Stipulated according to ・With little human activity：0.8m
condition under road must be taken. ・To keep clearance at least 0.3m. classification rules; Farmland：0.8m
for pipeline （ 0.15m when crossing with ・Distance with ground level. 【Piping cover：item-841.142】 Road, railroad：0.8m
(except underground object and at least (1) Forest wilderness：at least (1) Class1 ：24inch
seabed) 0.3m in parallel case.） 0.9m (2) Class2 ：30inch
(2) Other area：at least 1.2m (3) Calss3&4：30inch
Safety ・No provision for pipeline. ・Safety valve and other safety ・ Measure to avoid exceeding ・No provision for pipeline. ・ Control device to control ・ (The provision of pressure ・ The equipment to prevent
device, etc. device to avoid exceeding the normal operation temperature and pressure due to normal operation safety device is stipulated in the overpressure such as relief valve,
maximum working pressure. measure that can be returned to or oil hammering must be item of compressor station.) isolation valve must be provided
reduce pressure to below normal provided so as not to exceed 1.1 in order to prevent the occurrence
operation pressure, if the pressure times of normal operating of incidental pressure.
exceeds the normal operating pressure.
pressure. ・ Pressure safety device must
have enough capacity to fully
absorb pressure fluctuation of
pipeline.
Items ・No provision. ・ Pressure sensing devices and ・No provision in the general rule. ・No provision. ・ Seismic sensor and strong ・No provision.
provided backflow prevention devices for (Complex rule: Seismic sensor motion seismograph must be
specifically the marine pipeline must be must be provided in the necessary provided along the pipeline
provided in the appropriate place along the pipeline and pursuant to the notice.
location. measures to prevent disaster must
118
be taken.)
Safety ・ No provision for pipeline. ・ Control function that ・ No provision in general rule. ・No provision for pipeline. ・ Pipeline must be provided ・ Stipulated in item about
control (Stipulated in ordinance Article compressor or pump does not (Control function that compressor safety control device that has compressor station.
device 23, 26 and 27 related to work without ensuring that the or pump does not work without following function. (control
production) control circuit for the safety ensuring that the control circuit function that blower does not
equipment such as monitoring for the safety equipment such as work without ensuring that the
equipment of operating condition monitoring equipment of control circuit for the safety
is normal for pipeline which is operating condition is normal for equipment such as pressure safety
installed in the complex area. pipeline which is installed in the equipment, automatic oil leak
・Control function to gracefully complex area. Control function to detection equipment, emergency
shut down compressor and pump gracefully shut down compressor shutoff valve, seismoscope, and
or close emergency shutoff and pump or close emergency other safety equipments is normal
equipment by automatic or shutoff equipment by automatic and control function to gracefully
manual in the event of abnormal or manual in the event of shut down blower or close
conditions. abnormal conditions.) emergency shutoff equipment by
automatic or manual in the event
of abnormal conditions.)
Protective ・No provision. ・Earthling must be provided, if ・No provision in the general rule. ・No provision. ・Earthling must be provided if ・No specific provision. ・No specific provision.
grounding required for safety. (Complex rule: Earthing must be required for safety.
provided for safety, if necessary.)
Insulation ・No provision. ・Measure must be taken such as ・No stipulation in general rule. ・No provision. ・ Pipeline system must be ・No specific provision. ・ The following items must be
insulation from support or other (Complex rule: Measures must be insulated from other structure taken into account for the
structure, application of taken such as insulation from such as support, if there is selection of the insulation;
insulating fittings and necessary support or other structures, necessity for safety. (1) Risk for fluid
measure for insulation when application of insulating fittings ・ The insulated joint must be (2) Insulation systems and
installing pipeline in close and necessary measure for applied to pipeline system, if other safety requirements
proximity to location of the insulation must be taken if there is necessity for safety. (requirement as operation
arrester must be taken if necessary for safety.) ・ Necessary insulation measure management）
necessary for safety.) must be taken when installing
pipeline in close proximity to
location of the arrester.
Lightning ・No provision. ・To be provided, if required for ・ No provision in the general ・No provision. ・The lightning protection system ・No specific provision. ・No specific provision.
protection safety. rule.( Complex rule: measures to must be provided for the part that
system avoid the effects of lightning are placed on the ground pursuant
must be taken , if necessary.) to notice.
119
Others ・No provision. ・No provision. ・ Complex rule: Power for ・No provision. ・Emergency reporting equipment ・No specific provision. ・No specific provision.
security, patrol vehicle and and a facility to notify fire
equipment storage must be authority must be provided along
provided. the pipeline.
・ Chemical fire engine, patrol
vehicle and equipment storage
must be provided along pipeline
pursuant to notice.
Leak test ・HP ：once every 14 months ・ No provision. (according to ・No provision.（Airtight test is ・ No provision. （ Inspection ・No provision. ・No specific provision. ・No specific provision.
・Others：once every 40 months safety manual) required as a security check） frequency must be done in
accordance with Gas Business
Act.）
Pressure ・ Prevention measures due to ・Pressure regulator at appropriate ・No provision. ・No provision. ・No provision. ・No specific provision. ・No specific provision.
regulator fire caused by gas leakage location, gas isolating equipment
(high pressure), shutoff device at the entrance of regulator and
and impurity removal safety device at the outlet must be
equipment at entrance, provided for pipeline if necessary.
prevention apparatus for

pressure rise, flood protection
device, anti-icing system,
support to withstand
earthquake and overhaul
maintenance for if gas is
supplied to one user.
120
Chapter-8. Referenced Literature and Materials
The referenced books, literatures, standards to establishing this guide line are organized as follows.
1. Interpretation of technical regulation for thermal power facility(10/Jul/1007): NISA (Nuclear and Industrial Safety
Agency) of METI (Ministry of Economy, Trade and Industry)
2. Guideline for gas facility Japan (Mar /2010): NISA (Nuclear and Industrial Safety Agency) of METI (Ministry of
Economy, Trade and Industry)
3. Gas combustion technology (Lournal: A.Fujimoto and others: No.517: Oct/1999) TENPES (Thermal and Nuclear
Engineering Society of Japan)
4. The outline—boiler (Journal: No.583: Apr/2006): TENPES (Thermal and Nuclear Engineering Society of Japan)
5. Fuel and combustion (Journal: No. 590: Nov/2005): TENPES (Thermal and Nuclear Engineering Society of
Japan)
6. Management of fuel (Fuel for therma; power plant) (Journal: No.611: Aug/2007): TENPES (Thermal and Nuclear
Engineering Society of Japan)
7. “High temperature pipeline coatings – Fielde joint challenges in remote construction”: (Wayne Hodgins and others of
Canusa-CPS)
121

Guideline For Technical Regulation Vol.2 - Design of Thermal Power Facilities Book 6.12 Gas Fuel Handling Facility

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SOCIALIST REPUBLIC OF VIETNAM

Ministry of Industry and Trade (MOIT)

Design of Thermal Power Facilities

Japan International Cooperation Agency

Electric Power Development Co., Ltd.

Table- 2: Composition, heating value, etc. of gas fuel

H2 CH4 C2 H6 C3 H8 C4 H10 C5 H12 CO2 CO O2 N2 Higher Lower

Malaysia (Sarawak) ― 91.6 4.1 2.7 1.5 ― ― ― ― 0.1 44,170 39,820

Liquefied petroleum gas (LPG)

JIS type-2 No.1 standard product 2.0 96 2.0 ― 100,440 93,580

2. Combustion characteristics of gas fuel

CH4 concentration in gas mixture (%)

Fig- 1: Temperature dependence of flammability limit of methane-air mixture

CH4 concentration in gas mixture (%)

Fig- 2: Pressure dependence of flammability limit of methane-air mixture

Fig- 3: Relationship between lower explosive limit and combustion heat

O2 concentration in gas mixture (%)

Methane concentration in gas mixture (%)

Inert gas concentration in gas mixture (%)

4. Fuel supply facility

K S Other main burners

Fig- 5: High calorie gas fuel system (NFPA-8502-1999)

Gas flow meter Gas flow control damper Sampling

U-shape waterseal valve Gas shutoff valve

Fig- 6: Low calorie gas fuel system

5. Public safety and protection of the environment

1) requirements for identification of pipelines, components and fluids transported;

1) temporary works during construction, repair and modification;

Gas Fire Plant & Expander

Blast Furnace Expander

Blast Furnace Gas Conventional Power Plant

Blast Furnace Gas Holder

Coal Handling & Supply System GT Combined Cycle Plant

Table- 3: Categorization of Fluids

and toxic fluid.

Category D Non-toxic, single-phase natural gas.

butane), natural gas liquids, ammonia and chlorine.

Reference: 5.2 of ISO 13623-2000

Table- 4: Classification of Gas Pressure for Gas Facilities

Article 116-1. Length of pipeline

1) safety of the public, and personnel working on or near the pipeline;

(2) Public safety

1) temporary works during construction, repair and modification;

(4) Other facilities

(5) Third-party activities

(7) Construction, testing, operation and maintenance

2. Surveys — Pipelines on land

3. Surveys — Offshore pipelines

1) geological features and natural hazards;

Table- 5: Spanning of valve station (shutoff device)

Classification Span Remarks Span Remarks

32km Sparsely polluted area such as wasteland, desert, Necessary

24km Periphery of towns and city districts, industrial

8km Downtown (many high-rise buildings and large House densed

Article 116-2. Buried pipeline

Article 116-3. Drain slope

Article 116-4. Water seal valve

Gas flow towards cargo tanks Backpressure in cargo tanks