Drilling plan for well KJDG_Z

Compiled by

Planning, Technology and Monitoring Group

Drilling Services, Cauvery Asset,

Oil and Natural Gas Corporation Limited

2022-23
 Drilling Well on Paper for Development well:
KJDG_Z

Prepared by
Drilling Services B Jyotish, CGM(D)
Drilling Fluid Services A Malaichamy, DGM(Chem.)
Drilling Services Mohd Firoz Khan, SE(D)
Drilling Services Krishnanunni C, EE(D)
Drilling Services Anand Shankar V, EE(D)
Cementing Services Mayank Raj, EE(Cmtg)

Drilling Services, Cauvery Asset,

Oil and Natural Gas Corporation Limited
2022-23
 Health, Safety & Environment

General Attentions: Remember To Do Everything Safely And Take Care Of People First!!!

 All operations at site will be conducted in compliance with ONGC Cauvery Asset
environmental, safety and health guidelines.
 Only trained/qualified personnel will be allowed to work during all drilling operations.
These personnel must adhere completely all safety guidelines of ONGC without
reservations.
 All the rig crew members must use proper personal protective equipment (PPE) while
on job. All safety meeting, instructions, refreshments courses, drills and other events
must be recorded and reported.
 Work permits to be issued for any specific job.
 All different types of mock drill are to be conducted by all the shift crews in an evenly
distributed manner. BOP and Accumulator test to be performed as per guidelines.
 Pressures at slow circulation rates must be recorded and reported every day and
whenever there is a change of bit/BHA/mud weight.
 Report all kind of tests on IADC DPR and specific format for record.
 Drill pipe, drill collar, casing & tubing to be handled with safety slings.
 Casing spools, BOP, Tubing spool and X-Mas tree to be installed & tested under specific
safety plan for each size.
 Environment protection is of high priority. Proper sized waste pits must be dug before
the commencement of work. Spillage of waste water must be avoided and work plan for
preventing any spillage must be drafted before spud in.
 Tool box safety meetings and proper handing over between Shift I/Cs is essential for
maintaining good operational efficiency and safety. Day and night tool pushers must be
present on the rig floor during crew change/handovers. Shift I/c and Tool Pusher should
have enough time for detailed handing over. Detailed Job safety analysis to be carried
out in case of any special well specific operation.
 All these drills and meetings should be noted in ONGC DPR.

1
 General Data

Proposed Well Name KJDG_Z

Well Depth 2184m MD (KB) / 2141 m TVD (KB)

Well Type Development ‘B’

Profile Inclined - ‘L’ Profile. K.O.P @ 250 m

379.29 mts at 2127m TVD (KB), Inc: 12.71°;

Horizontal Drift Requirement
Azimuth: 0.32° N

Primary Target To Produce gas from Sand BS-10 of Bhuvanagiri Formation

Reference Wells KJ#18, KJ#15, KJ#14, KJ#12 and KJ#22

Ground Level/ Kelly Bush 7.385 m / 15.075 m above MSL

WBS Element KK.22D.AREA3.KJ#KJDG_Z

Basin/ Structure/ Prospect Cauvery/ Kanjirangudi

License Detail / Block Detail Kanjirangudi PML/Nomination Block, KJ PML

NELP / Nomination Nomination Block

Anticipated Spud Date October 2022

Rig Name E-760-14

Rig Type Electrical – Type – I

Rig Contractor ONGC

Well Head 21 ¼” x 13 5/8" x 11" x 7 1/16" - 4CP x 5M

BOP Type 13 5/8" x 5M (Annular & Double RAM BOP)

09° 16’ 31.44” N

Sub Surface location
78° 48’ 49.83” E

09° 16’ 19.10” N

Surface location
78° 48’ 49.90” E

2
Formation pressure:
Depth (m) Pressure (psi) MWE (g/cc)
2105m (TVD) from KJ#22 2908 0.97
1880M (TVD) from KJ#15 2682 1.00

Anticipated Temperature data:-

Depth (m) Temperature (°C) Temperature (°F)
2105m (TVD) at KJ#22 85.17 185.3

Expected Hydrocarbon Shows:

Depth from (m) Depth to (m) Oil/Gas

1922 1953 Gas
1957 1996 Gas
1999 2015 Gas
2127 2140 Gas
2144 2162 Gas

LOT/PIT values of offset wells:

Depth (m) Fracture pressure ( MW equivalent -

gm/cc)
KJ#12 – 165m 1.38 - PIT
KJ#12 – 1001m 1.42 - PIT
KJ#14 – 271m 1.26 - PIT
KJ#14 – 1359m 1.38 - PIT
KJ#15 – 1007m 1.80 - PIT
KJ#15 – 2153m 1.85 - LOT
KJ#18 – 1573m 1.60 - PIT
KJ#22 – 1030m 1.55 - LOT

*For information only.

Prognosed Formation:

DEPTH FROM DEPTH TO PROGNOSED AGE PROGNOSED FORMATION

0 321 Mio Pliocene Tittacherry
321 449 Mid Miocene Madanam
449 620 Tiruthuraipundi
E. Miocene to M. Eocene
620 955 Tirupundi
955 1666 Eocene Karaikal
1666 1922 Portonova
1922 2020 Nannilam
Upper Cretaceous
2020 2127 Kudavasal
2127 2184 Bhuvanagiri

3
 Prognosed Lithology (MD):
Depth
Depth To Lithology Depth From Depth To Lithology
From
0 11 KB 1219 1224 SILTSTONE
11 198 BLANK 1224 1455 CLAYSTONE
198 225 SAND 1455 1650 SHALE
225 250 CLAY 1650 1666 SHALE SANDY
250 300 SANDSTONE 1666 1922 SHALE
300 321 CLAYSTONE 1922 1953 SANDSTONE
321 449 LIMESTONE 1953 1958 SHALE
449 471 SANDSTONE 1958 1996 SANDSTONE
471 486 CLAYSTONE 1996 2001 SHALE
486 496 SANDSTONE 2001 2020 SANDSTONE
496 527 CLAYSTONE 2020 2127 SHALE
527 537 SANDSTONE 2127 2140 SANDSTONE
537 548 LIMESTONE 2140 2144 SHALE
548 558 COAL 2144 2178 SANDSTONE
558 578 SANDSTONE 2178 2184 SHALE
578 583 COAL
585 604 SANDSTONE
604 609 COAL
609 620 SANDSTONE
620 637 LIMESTONE
637 652 SANDSTONE
652 657 LIMESTONE
657 668 SANDSTONE
668 681 LIMESTONE
681 696 SANDSTONE
696 717 LIMESTONE
717 727 SANDSTONE
727 737 LIMESTONE
737 742 SANDSTONE
742 756 LIMESTONE
756 810 SANDSTONE
810 845 LIMESTONE
845 891 CLAYSTONE
891 896 SILTSTONE
896 922 CLAYSTONE
922 932 LIMESTONE
932 938 CLAYSTONE
938 955 LIMESTONE
955 1060 CLAYSTONE
1060 1065 SILTSTONE
1065 1091 CLAYSTONE
1091 1116 SILTSTONE
1116 1168 CLAYSTONE
1168 1173 SILTSTONE
1173 1219 CLAYSTONE

4
WELL SCHEMATIC: KJDG_Z
20” Casing (J55/94 ppf) shoe already
set at 198m
Whip-stock to be set at 250m inside
13 3/8” casing (J-55/61 ppf)

12 1/4” HOLE - K.O.P @ 250 m

H. Drift: 379.29m @ 2086 TVD/2127 MD

Inclination = 12.71°; Azimuth = 0.32° N

12 1/4” HOLE (250 m - 1350m)

9 5/8” Casing Shoe @ 1350 m
Casing Grade: N-80, 43.5 PPF
Mud Type : GEL POLYMER
Mud Wt : 1.05 - 1.12

8 1/2” HOLE (1350 m – 2184 m)

5 1/2” Casing Shoe @ 2184 m
Casing Grade: N-80, 17 PPF
Mud Type : KCL-PHPA-Polyol
Mud Wt : 1.12 - 1.18 (RIN)

5
PLANNED WELL TRAJECTORY

6
7
8
 Lag & Cycle Strokes:

String
Hole Annular Total MP Litre Lag Cycle
DEPTH Capacity
Size Vol (L) Volume (L) Liner( in) /Stroke Stroke Stroke
(L)
300 18,675 1,730 20,405 823 899
400 25,023 2,658 27,681 1,102 1,219
500 31,371 3,587 34,957 1,382 1,540
600 37,718 4,515 42,233 1,662 1,860
700 44,066 5,443 49,509 1,941 2,181
800 50,414 6,371 56,785 2,221 2,502
12 ¼”

900 56,762 7,299 64,061 7 22.7 2,501 2,822

1000 63,110 8,227 71,337 2,780 3,143
1100 69,458 9,155 78,612 3,060 3,463
1200 75,805 10,083 85,888 3,339 3,784
1300 82,153 11,011 93,164 3,619 4,104
1400 88,501 11,939 1,00,440 3,899 4,425
1500 94,849 12,867 1,07,716 4,178 4,745

Mud Pump Type Make Stroke length (in)

MP:1 TPK – 1600 12
MP:2 TPK – 1600 12

Hole DEPTH Annular String Total MP Litre Lag Cycle

Size Vol (L) Capacity Volume (L) Liner( in) /Stroke Stroke Stroke
(L)
1600 40,922 13,792 54,714 1,803 2,410
1700 43,320 14,720 58,040 1,908 2,557
1800 45,718 15,648 61,366 2,014 2,703
8 ½”

1900 48,116 16,576 64,693 7 22.7 2,120 2,850

2000 50,515 17,504 68,019 2,225 2,996
2100 52,913 18,432 71,345 2,331 3,143
2184 54,928 19,212 74,140 2,420 3,266

9
 Operational Steps and Times
Duration, Cumulative MD
Operation
days days m BRT
Making Arrangement for Side track
18 18 250
(18 Days)
Drilling of 12-1/4" Hole directionally (12 Days) 12 30 1350
9 5/8” Casing lowering, Cmtg, WOC, IWH up to PIT
3 33 1350
(3 days)
Drilling of 8-1/2" Hole directionally
16 49 2184
(16 days)
Logging, 5 1/2" Csg, Cmtg, WOC,IWH up to H/T
6 55 2184
(6 Days)

Proposed Casing Policy:-

The CSD are selected tentatively on the basis of formation pressure, LOT / PIT values (off set
wells) as provided by the basin. As these values are tentative in nature, the selected shoe depths
are also tentative and these may vary according to LOT values obtained in course of actual
drilling.

 20” Surface Casing (198 m): Already lowered.

 13-3/8” Surface Casing (699 m): The 13-3/8” surface casing is already lowered up to
699m in the well. Whip-stock is to be set at 250m.
 9 ⅝” Intermediate Casing (1350 m): The 9 ⅝” casing is to be lowered to 1350 m in the
well.
 5-1/2” production casing (2184 m): The 5 ½” casing is to be lowered to 2184 m at
Target depth in Bhuvanagiri formation.

Casing Design:
Casing Design is based on Mechanical Loading imposed during drilling and production.

Anticipated
OD/Weight MD Drift
BHP* Surface
String Conn. Interval Dia.
(PSI) Pressure*
/Grade (m) (in)
(PSI)
Intermediate 9⅝",
BTC 0-1350 8.755 3592 3066
Casing N-80, 43.5 ppf

Production 5 ½”,
BTC 0-2184 4.892 3592 3066
Casing N-80, 17 ppf

* Calculations done as per maximum mud weight planned in the respective phase.

10
 Casing Design Loads & Safety Factor:

Burst (PSI) Collapse (PSI) Tension (Tons)

Casing
Load Rating S.F Load Rating S.F Load* Rating S.F
9⅝",
43.5 ppf, 3066 6330 2.08 2114 3810 1.80 99 456 4.61
N-80

5 ½”,
17 ppf, 3066 7740 2.54 3592 6390 1.79 55 157.9 2.87
N-80

Minimum Safety
Minimum Safety Factor 1.0 - 1.10 1.125 (Uncemented) Minimum Safety Factor 1.80 -2.0
Factor
* Tension Load in Air

COMPLICATION DETAILS OF NEARBY WELLS OF THE LOCATION KJDG_Z

 Complications in well KJ#12 (KJDE):

No major drilling complications were encountered in this well.
 Complications in well KJ#14 (KJDA):
No major drilling complications were encountered in this well.
 Complications in well KJ#15 (KJDI):
No major drilling complications were encountered in this well.
 Complications in well KJ#18 (KJDG):
No major drilling complications were encountered in this well.
 Complications in well KJ#22 (KJDO):
After lowering the 7” casing, during circulation before casing cementation found no returns.
Cementation was carried out and during displacement observed no returns in the shale
shaker.

Drilling Operations
Preparation

This programme commences after the rig is on location and generally ready for well related
operations. This Programme is a guide to help and ensure that safe and efficient operations are
carried out. Operations are to be carried out safely, in accordance with good oilfield practices
and in compliance with the ONGC’s Drilling and Technical Manuals. Operations should be
executed to minimise adverse impact on the environment.

11
 Confirm that the following have been completed:

 All safety equipment has been checked and functional (gas detectors, alarms, shut-down
systems, fire-fighting equipment and teams etc.).
 All the equipment for the 12-1/4” phase is in place.
 Rig stocks of barite, Bentonite, fuel, drill and potable water are available.
 Communications are rigged up and functional.

Hold a Safety Meeting with the entire crew explaining ONGC’s view on Health and Safety and
the environment. Stress that no job is so important that HSE will be compromised in the interests
of time. Health and Safety is the individual’s responsibility and every job should be assessed
for safety first and the appropriate safety equipment used.

Ensure that all the steps as mentioned in side-track plan has been completed.

1. 12-1/4” Hole / 9 5/8” Casing

Start Depth 250 m

End Depth 1350 m
Basis of End Depth Karaikal Formation
Cement Rise 400 m from Shoe (1530 - 950 m).
Casing Specifications
Weight
Size(in) Grade Connection Burst(psi) Collapse(psi) Tensile(Ton)
(ppf)
9-5/8” N-80 43.5 BTC 6330 3810 456

Preparation

1. BOP pressure testing should be done with proper test plug of the casing spool. W/H
side valve should be kept open while pressure testing.
2. Ensure that 7” liner is installed in mud pump. Clean Mud pump Strainers. Carry out all
the necessary preventive maintenance checks.
3. Keep IBOP & FOSV ready in open position on rig floor with required X-overs (4”IF
Pin X 4-1/2” IF Box).
4. Ensure that the distance of all rams and annular BOP from rotary is displayed in the
dog house.
5. Ensure that SCADA system is fully functional and online.
6. Ensure that the Drill watch is fully operational.
7. Ensure well shut-in procedures are displayed in the dog house.
8. Check Proper Shale Shaker screen mesh size is installed. (Capable of handling
maximum expected flow rate, to avoid unnecessary mud dilution and over flow).

12
 9. Run a preliminary check over mud and solid control system (High pressure line, flow
line, tanks, shale shakers, de-sander, de-silter etc.).
10. Record SCR at the beginning of every shift and after every change in mud weight/BHA.
11. Inspect the rings and grooves of well head flanges, BOP for cut/pitting prior to N/UP
well head & BOP.

Sequence of Drilling Operations:

1. Hold a pre-job safety meeting to inform all personnel involved in the operation, of
related risks and to review drilling and well control procedures.
2. Test the BOP stack, choke & kill manifolds.
3. Record the dimensions and grades of the different tubular (including BHA) used in the
Drill string along with the Fish neck details.
4. RIH with 12-1/4” bit and directional BHA as per program.
5. Drill ahead according to directional drilling plan. Planned K.O.P is 250 m.
6. Optimize flow rate and drilling parameters to maximize ROP (Perform drill off tests to
optimize RPM and WOB).
7. Drill ahead to 9-5/8” casing shoe setting depth of 1350 m.
 Set alarms for pit volume, return flow rate and ROP on the Drill watch.
 Record all the drilling parameters every 30 minutes.
 Monitor and record Standpipe pressure continuously during drilling to interpret any
abnormal behaviours. The same is to be recorded along with any change in
BHA/String/Nozzle/Mud weight.
 Record and report standpipe pressure along with the discharge imparted during any
circulation carried out at any depth.
 Monitor shakers for change in shape and volume of cuttings and pit levels for any
mud loss/gain and cavings.
 Flow check to be conducted for all the drilling breaks encountered and to be report
in the DPR.
 Record SCR at the beginning of every shift and after every change in mud
weight/BHA.
 Carefully monitor the hole condition for tight spots, pack-off, partial / total mud
losses and record the depth range.
 Check and record drag with pumps off and on during every connection to analyse
any down-hole problem.
 Monitor connection gas and trip gas and report the same in DPR.
 Prior to a connection, circulate and rotate to ensure that cuttings are lifted clear of
BHA.
 Minimize stationary time when surveying or making pipe connections.
 The driller should record up, down and rotating string weights in order to monitor
the well behaviour.

13
  If required, sweep the hole with High Vis pill intermittently and circulate the hole
clean.
 Make wiper/short trips as hole conditions indicate. Use Trip tank and trip sheet to
monitor the well volume.
 Always be cautious while tripping out/tripping in across the Kick-off portion and the
previous casing shoe. (String may
got stuck up against
get stuck aroundthekick
kickoff
off point)
 Flow checks are to be conducted before Pulling out from the bottom, after pulling
out inside the casing shoe, before pulling out BHA and after pull out is completed.
 At section TD (9-5/8” casing shoe), circulate out the hole clean.
 Make a wiper trip to 13-3/8” csg casing shoe. Report tight spots. Do not pull into tight
K.O.P.
spot. Run to bottom, clearing any tight spots and circulate to condition mud.
8. POOH to run 9-5/8” casing. Check & clean the Mud pump strainers.
9. While pulling out and once inside the 13-3/8” casing, mud pumps should be checked to
ensure reliability during cement displacement.
10. Change the pipe rams to 9-5/8” casing rams.
11. Prepare and Check the 9-5/8” casing tally in advance so that the options regarding the
string length are known. Mark each casing joint with progressive number. Check the
NRV function of casing shoe and float collar prior to make up with the casing joint.
12. Hold a pre job safety meeting to inform all personnel involved in the operation, of
related risks and to review casing handling & running procedures.
13. Check and replace (if required) all the sealing elements required for High pressure hoses
to be used during Casing lowering, circulation post casing lowering and cementation.
14. Rig up 9-5/8” casing handling equipment and run 9-5/8” casing as per the casing tally.
a. Make up 9-5/8” casing shoe and float collar with the respective 9-5/8” casing joint
and seal with thread lock compound. Check float function of the float shoe and float
collar after making up with the casing string.
b. Ensure sufficient casing dope is available and use the same for sealing the casing
joint.
c. Run casing in open hole at controlled speed to prevent fracturing and lost circulation.
Fill the casing string with mud at regular intervals.
d. C&C with treated and conditioned mud for one cycle at 50 m above 12-1/4" previousK.O.P.
casing
shoe.
e. Test the Mud pump lines till cementing head at 1.5 times the maximum plug bumping
pressure or as per cementing plan.
f. Casing filling should be carried out with treated and conditioned mud using two tank
mud system at regular intervals.
g. Set last casing joint in rotary table, Make up circulating head and establish circulation
slowly and confirm full returns.
h. Gradually increase pump rate and circulate a minimum of 1.5 times the annulus
volume for homogeneity of mud and control the mud parameters as per cementing
program.

14
 i. SIC/Tool Pusher must be present during loading the top and bottom plugs into the
cementing head.
j. Nipple Down circulating head and Make up Cementing Head (ensure minimum time
is taken) and carry out the cementation job as per cementing plan.
 Confirm with well site chemist for available well site water salinity.
 In view of safety, cordon off and restrict access to high pressure cementing lines
during pressure testing and cementation job.
 Record initial Pit level and report any loss on return while cementation (with due
consideration of volume pumped by cementing unit). If there is any loss in returns
during displacement, slow down pumping rate to regain circulation. If returns
cannot be regained, continue to displace with lowest permissible rate and record
return volume.
 Reduce flow rate at the end of displacement to avoid any sudden pressure surge
when bumping plug.
 If plugs fail to bump, do not over displace more than half shoe track (casing shoe
to top float collar).
 Check for back flow, if casing shoe & Float Collar does not hold, shut-in
cementing head at surface with the differential pressure head and W.O.C.

Weight of Uncemented casing: As per Plan

Cement Rise Uncemented Casing Weight of Uncemented

PPF Length (m)
9-5/8” CSG (m) casing (Tons)
43.5 400 950 61.5
* Add Travelling block weight in order to get hook load

2. 8-1/2” Hole / 5 1/2” Casing

Start Depth 1350 m

End Depth 2184 m
Basis of End Depth Bhuvanagiri Formation
Cement Rise 500m from Shoe (2184 - 1684 m).
Casing Specifications
Weight
Size(in) Grade Connection Burst(psi) Collapse(psi) Tensile(Ton)
(ppf)
5-1/2” N-80 17 BTC 7740 6390 158
Preparation

1. BOP pressure testing should be done with proper test plug of the casing spool. W/H side
valve should be kept open while pressure testing.
2. Ensure that 7” liner is installed in mud pump. Clean the Mud pump Strainers. Carry out
all the necessary preventive maintenance checks.

15
 3. Keep IBOP & FOSV ready in open position on rig floor with required X-overs (4”IF
Pin X 4-1/2” IF Box).
4. Ensure that the distance of all rams and annular BOP from rotary is displayed in the dog
house.
5. Ensure that SCADA system is fully functional and online.
6. Ensure that the Drill watch is fully operational.
7. Ensure well shut-in procedures are displayed in the dog house.
8. Check Proper Shale Shaker screen mesh size is installed. (Capable of handling
maximum expected flow rate, to avoid unnecessary mud dilution and over flow).
9. Run a preliminary check over mud and solid control system (High pressure line, flow
line, tanks, shale shakers, de-sander, de-silter etc.).
10. Record SCR at the beginning of every shift and after every change in mud weight/BHA.
11. Inspect the rings and grooves of well head flanges, BOP for cut/pitting prior to N/UP
well head & BOP.

Sequence of Drilling Operations:

1. Hold a pre job safety meeting to inform all personnel involved in the operation, of related
risks and to review drilling and well control procedures.
2. Test the BOP stack, choke & kill manifolds.
3. Record the dimensions and grades of the different tubular (including BHA) used in the
Drill string along with the Fish neck details.
4. RIH with 8-1/2” bit and BHA as per program.
5. Tag float collar and carryout CIT.
6. Drill Float Collar, Cement and Float Shoe.
7. Drill through cement and shoe (0.5 m below shoe) with 2-3 T WOB and 50-60 RPM.
8. Circulate out the hole clean and conduct SIT.
9. Wash down to bottom of 12-1/4” hole and drill 3 m fresh hole.
10. Circulate and condition the mud. Pull out the string inside shoe and conduct PIT.
11. Drill ahead according to directional drilling plan.
12. Optimize flow rate and drilling parameters to maximize ROP (Perform drill off tests to
optimize RPM and WOB.)
13. Drill ahead to 5-1/2” casing shoe setting depth of 2184 m.
 Set alarms for pit volume, return flow rate and ROP on the Drill watch.
 Record all drilling parameters every 30 minutes.
 Monitor and record Standpipe pressure continuously during drilling to interpret any
abnormal behaviours. The same is to be recorded along with any change in
BHA/String/Nozzle/Mud weight.
 Record and report standpipe pressure along with the discharge imparted during any
circulation carried out at any depth.
 Monitor shakers for change in shape and volume of cuttings and pit levels for any
mud loss/gain.

16
  Flow check to be conducted for all the drilling breaks encountered and to be report
in the DPR.
 Record SCR at the beginning of every shift and after every change in mud
weight/BHA.
 Carefully monitor the hole condition for tight spots, pack-off, partial / total mud
losses and record the depth range.
 Check and record drag with pumps off and on during every connection to analyse
any down-hole problem.
 Monitor connection gas and trip gas and report the same in DPR.
 Prior to a connection, circulate and rotate to ensure that cuttings are lifted clear of
BHA.
 Minimize stationary time when surveying or making pipe connections.
 The driller should record up, down and rotating string weights in order to monitor
well behaviour.
 If required, sweep the hole with High Vis pill intermittently and circulate the hole
clean.
 Make wiper/short trips as hole conditions indicate. Use Trip tank and trip sheet to
monitor the well volume.
 Flow checks are to be conducted before Pulling out from the bottom, after pulling
out inside the casing shoe and after pull out is completed.
 At section TD (5-1/2” casing shoe), circulate out the hole clean.
 Make a wiper trip to 9-5/8” casing shoe. Report tight spots. Do not pull into tight
spot. Run to bottom, clearing any tight spots and circulate to condition mud.
14. Rig up for logging. During logging, monitor the well through trip tank.
15. Round trip after logging, check for fill and ream if necessary.
16. Circulate and condition the mud. Ensure conditioning of mud prior to pulling out.
17. POOH to run 5-1/2” casing. Check & clean the Mud pump strainers.
18. While pulling out and once inside the 9-5/8” casing, mud pumps should be checked to
ensure reliability during cement displacement.
19. Change the pipe rams to 5-1/2” casing rams.
20. Prepare and Check the 5-1/2” casing tally in advance so that the options regarding the
string length are known. Mark each casing joint with progressive number. Check the
NRV function of casing shoe and float collar prior to make up with the casing joint.
21. Hold a pre job safety meeting to inform all personnel involved in the operation, of
related risks and to review casing handling & running procedures.
22. Check and replace (if required) all the sealing elements required for High pressure hoses
to be used during Casing lowering, circulation post casing lowering and cementation.
23. Rig up 5-1/2” casing handling equipment and run 5-1/2” production casing as per casing
tally.

17
 a. Make up 5-1/2” casing shoe and float collar with respective 5-1/2” joint and seal
with thread lock compound. Check float function of the float shoe and float collar
after making up with the casing string.
b. Ensure sufficient casing dope is available and use it for sealing casing joint.
c. Run casing in open hole at controlled speed to prevent fracturing and lost
circulation. Fill casing with mud at regular interval.
d. C&C with treated and conditioned mud for one cycle at 50 m above previous casing
shoe.
e. Test Mud pump lines till circulating head/cementing head at 1.5 times the maximum
plug bumping pressure or as per cementing plan.
f. Casing filling should be carried out with treated and conditioned mud using two
tank mud system at regular intervals.
g. Set last casing joint in rotary table, Make up circulating head and establish
circulation slowly and confirm full returns.
h. Gradually increase pump rate and circulate a minimum of 1.5 times annulus volume
for homogeneity of mud and bring down mud parameters as per cementing
program.
i. SIC/Tool Pusher must be present during loading the top and bottom plugs into the
cementing head.
j. Nipple Down circulating head and Make up Cementing Head (ensure minimum
time is taken) and carry out cementation job as per cementing plan.
 Check the installation of top and bottom cementing plugs.
 Confirm with well site chemist for available well site water salinity.
 In view of safety, cordon off and restrict access to high pressure cementing
lines during pressure testing and cementation job.
 Record initial Pit level and report any loss on return while cementation (with
due consideration of volume pumped by cementing unit). If there is any loss
in returns during displacement, slow down pumping rate to regain circulation.
If returns cannot be regained, continue to displace with lowest permissible
rate and record return volume.
 Reduce flow rate at the end of displacement to avoid any sudden pressure
surge when bumping plug.
 If plugs fail to bump, do not over displace more than half shoe track (casing
shoe to top float collar).
 Check for back flow, if casing shoe & Float Collar does not hold, shut-in
cementing head at surface with differential pressure head and W.O.C.

Weight of Uncemented casing: As per Plan

Cement Rise Uncemented Casing Weight of Uncemented
PPF Length (m)
5-1/2” CSG (m) casing (Tons)
17 500 1684 42.6*
* Add Travelling block weight in order to get hook load

18
 BHA Programme

 Note that these BHA’s are provisional and may be updated / changed.
 All Drill Collar, HWDP, Drill Pipe & Crossovers must be visually inspected prior to use.

Bit
Hole
Type & Provisional BHA*
Size
Recommendations
12 ¼” Bit, TFA: 1.037 in2
2 bits 8" SDMM (3” ID)
12.25" Stabilizer (8.25” Fish neck OD,
IADC 1-1-7 (P) 2.125" ID)
12 1/4”
250 - 900 m, 2 Sin 8” NMDCs (2.813” ID) with
Section TD = 1350m
Meterage: 650 m MWD tool
6 Sin 6 ½” DCs (2.813” ID)
IADC 4-1-7 (P) 4 Sin 5” HWDP (3 “ ID)
900 - 1350 m 6 ½” D/JAR (2.813” ID)
Meterage: 450 m 10 Sin 5” HWDP (3” ID)
5" Drill pipe (19.5 ppf, G)

2 bits 8 ½” Bit, TFA: 0.746 in2

6.75" SDMM (3” ID)
IADC 4-1-7 (P) 8 1/2" Stabilizer (6.75” Fish neck OD,
8 1/2” 1350 - 1800 m 2.125" ID)
2 Sin 6.5” NMDCs (2.875” ID) with
Section TD = 2184m Meterage: 450 m
MWD tool
6 Sin 6 ½” DCs (2.813” ID)
IADC 4-3-7 (P) 4 Sin 5” HWDP (3 “ ID)
1800 - 2184m 6 ½” D/JAR (2.813” ID)
Meterage : 384 m 10 Sin 5” HWDP (3” ID)
5 “ Drill pipe (19.5 ppf, G, S)
*Actual BHA shall be as per the directional drilling requirements.

19
 Hydraulics Program: 12-1/4” Hole
Start 250
Depth
End 1350
W.O.B As per Directional Drilling
Drill Parameter
R.P.M As per Directional Drilling
GEL POLYMER Mud/KCL PHPA
MudP Type
Polymer Mud
Mud Rheology Mud Wt(S.G) 1.05 - 1.12
Funnel Viscosity (sec) 45 – 55
YP(lb/100ft2) 20 – 26
Liner(in) 7
Rig Pumps Ltr/Stk (Efficiency 100%) MP-1: 22.7 & MP-2: 22.7
MP-1: TPK – 1600 Max Discharge Pressure MP-1/MP-2: 3428
2915 psi
MP-2: TPK – 1600 SPM(Stk/ min) [53 + 53] [57 + 57]
Flow Rate(LPM) 2400 2600
SPP(psi) 1538 1733
Pressure Losses* String(psi) 1025 1138
12-1/4” Hole

(Increases with depth) Surface Equipment’s(psi) 74 83

Annulus(psi) 31 32
TFA(in2) 0.920
Nozzles
No. X Dia(1/32”) 3 * 20
HHP 151 192
HSI 1.2 1.6
Pressure Drop(psi) 408 479
Bit Hydraulics
Percent Power at Bit (%) 26.54 27.66
Nozzle Velocity(m/sec) 67.36 72.98
Impact Force(Newton) 3018 3542
Velocity(m/min) 36.05 39.16
Annulus ECD at Previous Shoe 1.142 1.142
ECD at bit (Section T.D) 1.143 1.143
Hook load with Drill Trip Out 66
String at Trip In 54
Section T.D(Tons) Rotate Off Bottom 60
Rotate Off Bottom 3455
Torque(ft-lbs)
Rotate On Bottom 7607
Hook load with Trip Out 83
Casing at
Section T.D(Tons) Trip In 67
* Calculated at section target depth with maximum mud weight planned in the phase.

20
 Hydraulics Program: 8-1/2” Hole

Start 1350
Depth
End 2184
W.O.B As per Directional Drilling
Drill Parameter
R.P.M As per Directional Drilling
Mud Type KCL-PHPA-Polyol-Polymer
Mud Wt(S.G) 1.12 - 1.18 (RIN)
Mud Rheology
Funnel Viscosity (sec) 45 – 55
YP(lb/100ft2) 20 – 30
Liner(in) 7
Rig Pumps Ltr/Stk (Efficiency 100%) MP-1: 22.7 & MP-2: 22.7
MP-1: TPK – 1600 Max Discharge Pressure MP-1/MP-2:3428
2915psi
MP-2: TPK – 1600 SPM(Stk/ min) [40 + 40] [43 + 43]
Flow Rate(LPM) 1800 1950
SPP(psi) 1849 2037
Pressure Losses* String(psi) 1211 1319
(Increases with depth) Surface Equipment’s(psi) 48.56 55.26
8-1/2” Hole

Annulus(psi) 221 230

TFA(in2) 0.746
Nozzles
No. X Dia(1/32”) 3 * 18
HHP 102.32 130.09
HSI 1.7 202
Pressure Drop(psi) 368 433
Bit Hydraulics
Percent Power at Bit (%) 19.95 21.25
Nozzle Velocity(m/sec) 62.37 67.57
Impact Force(Newton) 2208 2591
Velocity(m/min) 70.56 75.84
Annulus ECD at Previous Shoe 1.25 1.25
ECD at bit (Section T.D) 1.26 1.26
Hook load with Drill Trip Out 86
String at Trip In 68
Section T.D(Tons) Rotate Off Bottom 77
Rotate Off Bottom 4659
Torque(ft-lbs)
Rotate On Bottom 8718
Hook load with Trip Out 56
Casing at
Section T.D(Tons) Trip In 45
* Calculated at section target depth with maximum mud weight planned in the phase.

21
 EXPECTED STANDPIPE PRESSURES WHILE DRILLING

12 1/4" Hole Drilling*

SPP @ SPP @ SPP @

Sl No. TVD (m) MD (m)
2400 LPM 2500 LPM 2600 LPM
1 300 300 1041 1109 1179
2 498.58 500 1138 1213 1288
3 693.71 700 1229 1309 1389
4 888.81 900 1322 1407 1492
5 1083.92 1100 1415 1505 1596
6 1279.02 1300 1500 1594 1690
7 1327.8 1350 1538 1635 1733

8 1/2" Hole Drilling*

SPP @ SPP @
Sl no. TVD (m) MD (m)
1800 LPM 1950 LPM
1 1376.57 1400 1517 1671
2 1474.32 1500 1561 1720
3 1571.68 1600 1606 1769
4 1669.23 1700 1650 1818
5 1766.78 1800 1703 1877
6 1864.33 1900 1741 1918
7 1961.89 2000 1778 1959
8 2059.44 2100 1816 2001
9 2141.38 2184 1849 2037

*Calculated values are approximate values only. Actual values can vary based on the drill string
components and mud weight used.
*The mud weights used for calculation of SPP at various depths have been taken from the reference
well KJ#18. During the course of drilling this well, the drilling fluids policy detailed within this
document shall be followed.
*Provisional BHA/drill string components used for the above calculations are given in the page no. 19.
.

22
 12 1/4" Hole Drilling
SPP v/s Measured Depth
1800

1700

1600

1500
Standpipe Pressure (psi)

1400

1300

1200

1100

1000

900
250 450 650 850 1050 1250 1450
Measured Depth (metres)

SPP @ 2400 LPM SPP @ 2500 LPM SPP @ 2600 LPM

23
12 ¼” Hole - Stresses along the string while rotating on bottom

24
 12 ¼” Hole - Stresses along the string while Tripping out

Stress Limit
Bending

25
12 ¼” Hole – Torque while drilling at bottom

Torque Limit

26
 8 1/2" Hole Drilling
SPP v/s Depth

2050

1950

1850
Standpipe Pressure (psi)

1750

1650

1550

1450
1300 1500 1700 1900 2100 2300
Measured Depth (metres)

SPP @ 1800 LPM SPP @ 1950 LPM

27
8 ½” Hole - Stresses along the string while rotating on bottom

Stress Limit

28
 8 ½” Hole - Stresses along the string while Tripping out

Stress Limit
Bending

29
8 ½” Hole – Torque while drilling at bottom

Torque Limit

30
 DRILLING FLUID POLICY FOR THE WELL KJDG_Z
Well Schematic:
Interval
Hole Size Casing Size Length Mud Weight
(meters) Mud System
(inches) (inches) Casing Program (Sp. Gr.)
MD

26” 20” 198M

17 ½” 13 3/8” (250M-KOP)

1100M GEL
12 ¼” 9 ⅝” (250-1350) POLYMER 1.05-1.12(RIN)

834M KCl-PHPA-
8 ½” 5 ½” 1.12-1.18 (RIN)
(1350-2184) POLYOL
Drilling Fluid Policy for the Well: KJDG_Z

Hole size 12¼” 8 ½”

Casing Size 9 ⅝” 5 ½”

Depth Interval 250M-1350M 1350M-2184M

Mud System Gel-Polymer KCl-PHPA-Polyol.

Mud Density 1.05-1.12

1.12-1.18(RIN)
g/cc (RIN)

Funnel Viscosity
45-55 45-55
(sec)

F/L ml 8-10 5-8

YP (lbs./100 ft2 ) 20-26 20-30

pH 9.0-9.5 9.0-9.5

Solids % 6-10 10-14

G0/G10/G30 10-15/15-25/25-30 07-10/15-20/20-25

* Change if necessary

Remarks:

1. The drilling fluid policy is prepared based on data provided by Asset / Basin.

2. Drilling Fluids parameters are tentative and can be changed as per requirement and
problems encountered during actual course of drilling.

PRE-SPUD PREPARATION

1. Maintain QHSE compliance.

 All Mud labourers should be briefed about the hazardous nature of chemicals and
their safe handling practices.
 Confirm MSDS book of all chemicals is available at the drill site.
 Confirm NaOH, KOH and other hazardous materials are stored properly in the
designated area.
 All Mud Services personnel and Mud labourers should be equipped with suitable PPE
while working in the drill site.
2. All solid control equipment should be tested and repair if any to be undertaken, the
same has to be informed to mechanical in charge/RIC to take necessary action prior
to spudding the well.
3. Check all the mud tanks for leakages and ensure that channelling is not there between
mud tanks and make sure that all drum valves are in good condition
 4. Make a total inventory of all chemicals and ensure all contingency chemicals are
present.
5. Check the availability of different size of screens of shale shaker and mud cleaner and
if there is any shortage, the same has to be informed to mechanical in charge/RIC for
timely action.

1) 12¼” hole from 250M - 1350 M

Gel Polymer Mud system

The approximate composition of drilling fluid is as follows:

Product Function Concentration

Bentonite Viscosifier 3-3.5 % (as required)

Caustic Soda Alkalinity As required for pH

Soda Ash Calcium Treatment 0.025-0.1 %

PGS Fluid Loss 0.5-1 %

CFD Deflocculant 1-2%

Biocide Germicide As per dose

Prevent balling /drop sand

DD/EP-LUBE 1-1.5%
/lubricity

Limestone powder Weighting Agent As required

 For lost circulation pills fibre, granular, chips material should be kept ready at site for use
as contingency plan. Intermittent High Vis pills should be pumped for hole cleaning in
order to avoid annulus loading

 Continuously run De-sander and De-silter and keep undesired solids at minimum level.

2) 8 ½” Hole from 1350M- 2184M

KCl-PHPA-Polyol Mud System:

The approximate composition of drilling fluid is as follows:

Product Function Concentration

KCl Shale stabilizer 5-6 % (as required)

NaOH Alkalinity As required for pH

Soda Ash Calcium Treatment 0.025-0.1 %

PAC Fluid Loss 1-1.5 %

PHPA Encapsulation 0.5-0.8 %

XC-Polymer Viscosifier 0.3-0.4 %

Biocide Germicide As per dose

Limestone Weighting Agent As required

Polyol Shale stabilizer 3%

Seal micro fractures /

Sulphonated Asphalt 1.5% - 2%
borehole stability

 All the mud tanks including reserve tanks should be ensured with perfect isolation
and be provided with Agitators in working condition.
 Shale Shakers should be provided with sufficient number of finer screens.
 Desander and Mud Cleaner should be made available in efficient working
condition.
 Degasser should be functional and lined up. Trip tank should be used for Hole
filling and return of mud during tripping.
 Drill with proper dosage of KCl, PHPA to impart inhibition and minimize cuttings
dispersion.
 Treat the mud with XC Polymer, PAC (RG), PAC (LV) to maintain low end
rheology in the specified range for better Hole cleaning efficiency and to achieve
minimum cake thickness and good control of fluid loss.
 pH of the system should be between 9.0- 9.5
 Mud cleaner should be continuously run with 180-200 mesh screens in this phase of
drilling.
 Pump Hi-Vis sweeps at regular intervals to help assist hole cleaning.
 TENTATIVE CEMENTATION PLAN # KJDG_Z

9 5/8” Casing Cementation

 Casing Shoe Depth (m) MD : 1350 m

 Length of Cement column planned : 400 m (Cement Top: 950m)
 Density & Type of slurry planned : 1.90 SG / Normal Slurry
 Density of spacer planned : 1.00 SG

Note:
1. Mechanical aids to be fixed at the time of casing lowering as per plan
given by Cementing.
2. Float collar to be lowered and fixed at the box of IInd casing pipe from
the casing shoe.
3. LOT/PIT to be carried out before commencement of 8 ½” phase.

5 1/2” Casing Cementation

 Casing Shoe Depth (m)-MD : 2184 m
 Float Collar : 2159.5 m
 Top of object(MD) : 1920 m (MD-approx.)
 Length of Cement column planned : 500 m (Cmt. Top- 1684m)
 Density & Type of slurry planned : 1.90 SG/ Normal Slurry
 Density of spacer planned : 1.00 SG (SAPP solution)
 Displacement Fluid : Water

Note:
1. Mechanical aids to be fixed after the preparation of casing tally prior
to casing lowering as per plan given by Cementing services.
2. Float collar to be lowered and fixed at the box of second casing pipe
above float shoe.
3. Production Casing to be racked in such a manner that it should allow
fixing of centralizers and other mechanical aids in 45 casing pipes.
 TENTATIVE CEMENTATION PLAN # KJDG_Z

Evaluation based on Simulation studies

 Considered pore pressure : 0.972 SG at the bottom(ref well: KJ#15)
 Considered fracture pressure : 1.60 SG at 9 5/8” C/S (ref well KJ#18)
1.60 SG at the bottom.
Considered mud weight : 1.18 SG
 Considered average hole size : 9”
 Final Mud Circulation : Feasible.
Circulation pressure 900 psi @ 2.0 m3 / minute
 Cementation job feasibility : Feasible.
 Displacement Fluid : Water
Expected maximum pump pressure : Around 1800 psi
Safe circulation / Displacement rate as per simulation: 2.0 Cu. m / Min

Stage Fluid Type Fluid Rate Volume Top of Length Surface

No. (m³/min) (m³) Fluid (m) Pressure
(m)

1 Drilling Fld (Mud) 8-1/2" Hole Drill 2.0 0.0 0.0 1312.06 900 psi
2 Spacer/Flush SAPP 0.8 8.0 1312.06 371.94
3 Cement Cement #1 0.8 10.936 1684.0 500.0
Top Plug
4 Displacement Fluid DISPLACEMENT 1.5 23.0 262.78 1896.72 1100 psi
WATER
5 Displacement Fluid DISPLACEMENT 0.8 3.187 0.0 262.78 1300 psi
WATER
 TENTATIVE CEMENTATION PLAN # KJDG_Z

Downhole Pressure Profile:-

 TENTATIVE CEMENTATION PLAN # KJDG_Z

Calculated Wellhead/ Surface Pressure:-

TENTATIVE CEMENTATION PLAN # KJDG_Z

Cementation Plan: Summary

Size of 9-5/8” 5 1/2’’

Casing Casing Casing

Shoe 1350 m 2184 m

depth(m) -
MD
Cement Top 950 m 1684m
desired

Cement 400 m 500 m

column (m)
from shoe
depth
Slurry SG 1.90 1.90

1.00 SG
Spacer 1.00 SG
(SAPP)