RP-205 R7 Wellhead WIP

Transformer R7 Wellhead System

Running

Procedure

Prepared By: Reviewed By: Approved By: RP-205

WIP

Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 1

of 46 5-3-GL-GL-WES-00036 May 2013 May 2013 May 2013

Transformer R7

Wellhead System

Running Procedure

Publication: RP-071 Release Date: June 2013

©2013 Weatherford International Ltd. All rights reserved.


Running

Procedure


WIP

Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 2


Table of Contents

System Details

Figure 1. Dimensional Data.................................................................................................................. 3

Figure 2. Wellhead Components.......................................................................................................... 4

Table 1. Bill of Materials ..................................................................................................................... 5

Running Procedure

STAGE 1 Site Preparation .................................................................................................................... 8

STAGE 2 Installing the Casing Head .................................................................................................... 9

STAGE 3 Installing the Drilling Adapter ............................................................................................ 13

STAGE 4 Testing the BOP Stack I ...................................................................................................... 14

STAGE 5 Running and Retrieving the Wear Bushing......................................................................... 16

STAGE 6 Running the 5-1/2" Casing .................................................................................................. 20

STAGE 7 Installing and Testing the Packoff ...................................................................................... 25

STAGE 8 Installing the Casing Head Cap........................................................................................... 27

STAGE 9 Installing the Flange ........................................................................................................... 28

STAGE 10 Installing the Tubing Spool ................................................................................................. 29

STAGE 11 Testing the BOP Stack II ..................................................................................................... 30

STAGE 12 Installing Contingency Equipment...................................................................................... 31

Additional Reference Information

APPENDIX A Recommended Procedure for Field Welding Pipe to Wellhead Parts for Pressure Seal ..... 39

APPENDIX B - Recommended Procedure for API 6A Flange Connections ................................................. 42


Running

Procedure


WIP

Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 3


Figure 1. Transformer R7 Wellhead Dimensional Data


Running

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:

Rob Hastings

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Bruce Ross Page 4


Figure 2. Transformer R7 Wellhead Components


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Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 5


Table 1. Transformer R7 Wellhead – Bill of Materials

Item Qty Part Number Description

Casing Head Assembly

1 1 951634

WFT-RL-R07 Casing Head, 11" 5M x 9-5/8" LC, 14.50-4 Left Hand (Male), (2) 2.0" Line Pipe Outlets, 10.0-4 Stub Left Hand (Female)

for Running and Retrieval, API 6A, Material Class EE-NL, Temperature Class L-U. Product Specification Level 2, Performance Requirement 1.

2 1 TBD Pup Joint, 9-5/8" LTC Pin x Pin, 4 Feet Long.

3 1 901756 WFT-RL Landing Base, for 9-5/8" casing x 16" conductor with

flowby slots, 14.75“ 500,000 Lbs Capacity, Material Spec ification WS103.

4 1 1230385 WFT-RL Landing Ring, Slip-On, 20" OD x 16" casing with 16” Single O-Ring ID, 20" OD, 15.25" ID.

5 1 7955019 Nipple, 2" line pipe x 6" long, A106B XXH.

6 1 1160264 Ball Valve, 5M, 2" line pipe, Female Threaded Ends, 3/5K RWP,

Restricted Port, OEMG, API 6D - CST, NACE MR0175, API 598, API 608.

7 1 189180 Bull Plug, solid, 2" line pipe XXH, Material 75K 4130.

8 1 1233430

WFT-TR Fluted Mandrel Casing Hanger Assembly, 11" x 5-1/8" 10M x 5-1/2" 10M, LTC Box Bottom with 5" Type H Back Pressure

Valve Prep, 9.375" Left Hand Threads and Lockring, Monogrammed API 6A, Performance Requirement 1, Product Specification Level 2, Temperature Class P-U, Material Class DD

PSL2

9 1 1233451

WFT-TR Packoff, 11" with 9.375" Left Hand Threads for 5-1/2" Mandrel Hanger with Latch Ring, Activation Plate Assembly, 11-10K, 9.375-4 Stub Left Hand x Double O-Ring Seal, Manual

Running and Retrieval, API 6A, Material Class DD, Specification Level PSL2, Temperature Class P-U, Performance Requirement 1.

10 1 1183301

WFT-RL-R07 Casing Head Cap, 14.50" Left Hand Internal Engagement Thread With O-Ring Trash Seal, 5000 WP, Product

Specification Level 2, Temperature Class P-I. Material Specifications SO, EE2U.

*Not Shown

Continued on Following Page


Running

Procedure


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:

Rob Hastings

:

Bruce Ross Page 6


Table 1. Transformer R7 Wellhead – Bill of Materials (Continued)


Tubing Spool Assembly

11 1 1278605

WFT-TCM Tubing Spool, 5-1/8" 10M x 7-1/16" 5M with Two 2-

1/16" 5M Studded Side Outlet, (4) ET Style Lockscrews, 5.130 Minimum Bore, Monogrammed API 6A, Material Class EE-0,5, Specification Level 2, Temperature Classification P-U, Performance

Requirement 1.

12 2 1268220

WFT-WSG Manual Gate Valve , 2-1/16" 5M, Flanged Ends, Cast Body, Hand Wheel Operated, Monogrammed API 6A, Material Class EE-NL, Specification Level 2, Temperature Classification P-

U, Performance Requirement 1.

13 2 900375 Companion Flange , 2-1/16" 5M x 2" line pipe, Monogrammed API 6A, Material Class EE-NL, Product Specification Level 2, Temperature Classification L-U, Performance Requirement 2.

14 1 199361 Bull Plug, 2" line pipe x 1/2" line pipe, Material 75K 4130

15* 1 189180 Bull Plug, XXH, solid, 2" line pipe, Material 75K 4130.

16 4 206269 R-24 Ring Gasket.

17* 16 478350 Stud With Two Nuts, 7/8" x 6" Long, Material Grade B7.

18* 1 478484 Needle Valve, MXF Angle, 1/2" NPT 10M Male x Female .

19* 1 477809 Pressure Gauge, 0-5M, 4 Inch Dial, Fitting Connection ½” NPT Male Bottom .

20 1 237469 BX-169 Ring Gasket.

Contingency Equipment

21* 1 952467 WFT-22-RL Casing Head, 11" 5M x 9-5/8" SOW Bottom Without

Ring, Two 2" Line Pipe Outlets, Material Class EE- NL, Temperature Classification P-U, Product Specification 2.

22* 1 479056 C-22 Casing Hanger, 11" x 5-1/2" API 6A AA U.

23* 1 879255 WFT-RL Flange,11" 5M x 14.50" Left Hand Threads, API 6A AA U.

24* 12 204273 Stud With Two Nuts, 1-7/8" 8UN x 14" Long, B7/2HM.

25* 1 205564 R-54 Ring Gasket.

26* 1 1291360 WFT-SPCL Crossover Spool, 11" 5M x 5-1/8" 10M with 5-1/2" Double FS Seal Bottom Prep, 5 HBPV, EE2PU1.

*Not Shown

Continued on Following Page


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Rob Hastings

:

Bruce Ross Page 7


Table 1. Equipment – Component Bill of Materials (Continued)


Service Tools

27* 1 1181933 WFT-RL Drilling Adapter, 11" 5M Rapid-Lok x 11" 5M flange w/ Ring Groove.

28* 1 1181970 WFT-RL Casing Head Running and Retrieving Tool, 14.50" left

hand thread box bottom x 9-5/8" LTC box top with anti-rotation groove.

29* 1 1124978 WFT-RL Diverter Adapter, 20" slip on with 20” O-Ring Groove.

30* 1 1183670 Test Plug, 11" x 4-1/2" IF box top x pin bottom.

31* 1 188309 WFT-22 Wear Bushing, 11" x 8-1/2" ID and J-slot running

Profile

32* 1 879256 WFT-RL Casing Head Hub, 11" 3/5M x 14.50, 4 left hand thread,

API 6A AA/BB/DD/EE, Product Specification Level 2, Temperature Classification P-U.

33* 1 1183538 WFT 22, WFT 29 Wear Bushing Running and Retrieving Tool, 11" x 4-1/2" for J-Slot Wear Bushing, IF Box Top x Pin Bottom.

34* 1 TBD Casing Hanger Running Tool, 9.125” Left Hand Threads x 5 ½”

LTC Box Top.

35* 1 1183661 WFT-TCM Test Plug, 7-1/16" x 3-1/2" IF Box Top x Pin Bottom.

*Not Shown


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:

Rob Hastings

:

Bruce Ross Page 8


STAGE 1 – Site Preparation

This procedure begins assuming all initial

wellhead preparations have been made,

with sufficient clear area to

accommodate the equipment and a

suitable work area to install and maintain

the equipment.

1. Determine the correct elevation for the

wellhead system and cut the 16”

conductor accordingly.

Ensure the cut on the conductor is level,

as this will determine the orientation of the remainder of the wellhead equipment.

2. Remove excess 16” pipe and set aside.

3. Bevel the 16” conductor with a 3/16” x

3/8” bevel and remove any sharp edges

from the OD of the casing.

4. Break a 1/8” x 45 degree bevel on the ID

of the casing.


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STAGE 1 - Site Preparation (Continued)

5. Examine the Landing Ring. Verify the

following:

Landing ring is clean and undamaged.

O-Ring is clean, undamaged and properly installed.

6. Wipe the ID of the landing ring with a

light coat of oil or grease.

7. Install the landing ring over the 16"

conductor to a positive stop

(RP102144).

8. Examine the Diverter Adapter. Verify

the following:

Diverter adapter is clean and undamaged.

O-Ring is clean, undamaged and

properly installed.

9. Wipe the ID of the adapter with a light

coat of oil or grease.

10. Install the adapter over the landing ring

to a positive stop (RP102191).


Running

Procedure


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Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 10


STAGE 2 – Installing the Casing Head

1. Run the 9-5/8" casing to the required

depth and cement per the program.

2. Examine the WFT-R7 Casing Head.

Verify the following:

Bore is clean and free of debris.

Seal areas, threads and ring grooves are clean and undamaged.

All peripheral equipment is intact and undamaged.

Landing base is properly installed and secure.

Pup joint is properly installed,

square, secure and the exposed pin threads are clean, undamaged and protected.

Flush fitting plugs are installed in the outlets and secure.

Any bare threads where the coating has been removed should be recoated with a

dry-moly lubricant.

3. Examine the Casing Head Running

Tool. Verify the following:


O-Ring and threads are clean and undamaged.

Landing joint is properly installed, secure and the exposed box threads

are clean, undamaged and protected.

4. Wipe the O-Ring of the tool with a light


5. Ensure the threads of the head and

running tool have been coated with a dry

moly lubricant or phosphate.


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Stage 2. Installing the Casing Head (Continued)

6. Wipe the threads of the head with a coat

of anti-seize lubricant.

Do not use pipe dope on these threads, as this can cause galling.

7. Carefully slide the running tool over the

top of the casing head until the threads of

the tool make contact with the threads of

the casing head.

8. Using two sets of chain tongs located

180° apart on the landing joint, and

maintaining a neutral weight, rotate the

running tool, first clockwise until the

thread jump can be felt, then

counterclockwise approximately 10

turns to a positive stop.

Do not torque this connection.

9. Rotate the tool clockwise and align

the anti-rotation slots of the running tool

with the tapped holes in the casing head.

These holes are located immediately below the running threads of the casing head.

10. Determine the elevation from the drilling

rig floor to the top of the landing ring and

record this dimension.

11. Locate the landing point on the landing base and measure

the previously recorded dimension up the running tool

landing joint and mark the landing joint with a horizontal

mark.

12. Install the anti-rotation lugs into the tapped holes securely.

13. Lift the casing head/running tool assembly to the rig floor.

14. Make up the casing head into the casing string like any other

casing joint and torque to the thread manufacturer’s

recommended optimum torque.


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:

Rob Hastings

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Bruce Ross Page 12



15. Remove the anti-rotation lugs from the

tapped holes of the casing head.

16. Release the 9-5/8" casing from the floor

slips and lower the casing head/running

tool through the diverter until it lands on

the landing ring.

The horizontal mark made on the landing joint should be level with the rig floor.

17. Make a vertical mark on the landing joint

as a rotation indicator.


180° apart, rotate the running tool

clockwise 1 full turn.

19. Hold back up on the chain tongs on the

landing joint to prevent counterclockwise

rotation.

20. Land the casing head on the landing ring,

ensuring the landing joint does not rotate.

21. Using the chain tongs installed

previously, rotate the running tool

counterclockwise 1 full turn.


22. Remove the chain tongs.

23. Cement the 9-5/8" casing as per the

program, taking returns through the flutes

in the landing base.

24. Once the cement operations are

complete, reinstall the two sets of chain

tongs 180° apart on the landing joint.


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Procedure


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:

Rob Hastings

:

Bruce Ross Page 13



25. Holding backup on the landing joint,

remove the cement head from the

landing joint.

26. Rotate the landing joint clockwise

approximately 10 turns, until the running

tool comes free of the casing head

(RP102209).

27. Remove the tool with a straight vertical

lift.

28. Lay the running tool down.

29. Once the casing head running tool is

removed, remove the connection from

the diverter assembly flowline.

30. Lift the diverter assembly a minimum of

20" in order to allow the diverter adapter

to clear the casing head.

31. Remove the diverter assembly with a

straight vertical lift and lay down.

32. Thoroughly clean the entire casing head

assembly, ensuring all threads and

sealing surfaces are clean.

33. Remove the flush plugs from the outlets

of the casing head and install the outlet

equipment as required.

34. Ensure the outlet valve is closed.

35. Measure the distance from the top of the

casing head to the rig floor (RKB) and

record this dimension.


Running

Procedure


WIP

Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 14


STAGE 3 – Installing the Drilling Adapter

1. Examine the WFT-R7 Adaptor Hub.


Hub is clean and undamaged.

Threads are clean and undamaged.

Any bare threads where the coating has been removed should be recoated with a dry-moly lubricant.

2. Ensure the external threads of the casing

head are clean and undamaged.

3. Wipe the threads of the hub with an anti-

seize compound.

Do not use pipe dope or other metal based compound, as this can cause

galling.

4. Install the hub onto the threads of the

casing head with counterclockwise

rotation (RP102154).

When fully installed, the face of the hub will be 1.25" below the face of the casing head.


Running

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:

Rob Hastings

:

Bruce Ross Page 15


STAGE 3 – Installing the Drilling Adapter (Continued)

5. Examine the WFT-RL Drilling Adapter.



O-Ring is properly installed and

undamaged.

Ring grooves are clean and undamaged.

Lockscrews and actuation dogs are fully retracted from the bore.

6. Wipe the ID of the drilling adapter with a


7. Carefully lower the drilling adapter over

the top of the casing head and land it on

the face of the casing head.

8. Locate the 8 drive screws of the drilling

adapter and engage each dog in an

alternating cross fashion to a positive

stop.

Excessive torque, cheater bars or power

torque wrenches are not required to make up this connection.

9. Install a new R-54 Ring Gasket into the

ring groove in the top of the drilling

adapter and make up the BOP per rig

procedure.

In an effort to save time, the drilling adapter may be made up to the bottom of

the BOP stack offline.


Running

Procedure


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Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 16


STAGE 4 – Testing the BOP Stack

Immediately after mak ing up the BOP stack

and periodically during the drilling of the hole

for the next string, the BOP stack

(connections and rams) must be tested.

1. Examine the 11” WFT-22 Test Plug.


O-Rings and plugs are properly installed, clean and undamaged.

All threads are clean and undamaged.

2. Orient the test plug with O-Rings up and

drill pipe pin connection down.

3. Make up a joint of drill pipe to the top of

the tool.

Remove the ½” NPT pipe plug from the

weep port if pressure is to be supplied through the drill pipe.


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:

Rob Hastings

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Bruce Ross Page 17


STAGE 4 – Testing the BOP Stack (Continued)

4. Fully retract the lockscrews (for the

drilling adapter). Ensure the lockscrews

are fully retracted.

5. Open the outlet valve on the casing

head.

6. Wipe the O-Rings of the test plug with a


7. Lower the test plug through the BOP and

drilling adapter until it lands on the load

shoulder 18.76" below the face of the

drilling adapter

8. Close the BOP rams on the drill pipe and

test to 5,000 psi maximum.

9. Monitor the open outlet for signs of

leakage past the test plug.

10. After a satisfactory test is achieved,

release the pressure, and open the rams.

11. Drain as much fluid from the BOP stack

as possible.

12. Retrieve the test plug assembly slowly to

avoid damage to the seals. Close the

outlet valve on the casing head.

13. Repeat this procedure as required during

the drilling of the hole.


Running

Procedure


WIP

Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 18


STAGE 5 – Running and Retrieving the Wear Bushing

The WFT-22 Wear Bushing protects the load

shoulders and sealing surfaces during

drilling. The tool is run and retrieved at

various times during set-up and operation.

Running the Wear Bushing

1. Examine the Wear Bushing Running



Lift lugs are properly installed and secure.

All threads are clean and

undamaged.

2. Examine the Wear Bushing. Verify the

following:


Stop lug is secure.

J-slots are clean and free of debris.

3. Orient the running tool with the drill pipe

pin connection down.

Always use a wear bushing while drilling to protect the load shoulders and sealing surfaces from damage by the drill bit or

rotating drill pipe.

The wear bushing must be retrieved prior to running the casing.


Running

Procedure


WIP

Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 19


STAGE 5 – Running and Retrieving the Wear Bushing (Continued)


the running tool.

5. Lower the tool into the wear bushing and

rotate the bushing 1/4 turn

counterclockwise .

6. Verify both lockscrews in the drilling

adapter are fully retracted from the bore.

7. Slowly lower the tool/bushing assembly

through the BOP stack until it lands on

the load shoulder 18.76" below the face

of the casing head.

8. Run in both lockscrews of the drilling

adapter snug tight.

Do not overtighten the lockscrews.

9. Remove the tool from the wear bushing

by rotating the drill pipe counterclockwise

1/4 turn and lifting straight up.

10. Drill as required.

Retrieving the Wear Bushing

1. Make up a joint drill pipe to the tool.

Ensure the pin connection is down.

2. Slowly lower the tool through the BOP

stack and into the wear bushing.

3. Rotate the tool clockwise until the drill pipe drops

approximately 2". This indicates the lugs have aligned with

the J-slots of the wear bushing.

4. Slack off all weight to make sure the tool is down.

5. Rotate the tool clockwise 1/4 turn to fully engage the

lugs in the wear bushing.

6. Fully retract both lockscrews of the drilling adapter and

retrieve the wear bushing.

7. Remove the bushing and the tool from the drill string.


Running

Procedure


WIP

Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 20


STAGE 6 – Running the 5 ½” Casing

1. Examine the WFT-TR Mandrel Casing

Hanger. Verify the following:


All threads are clean and

undamaged.

Lockring is properly installed and undamaged.

Ensure the pup joint is properly installed, square, secure and the exposed pin threads are clean, undamaged and protected.

Protector plate is properly installed and secure.

Flowby flutes are clear and

unobstructed.

Any bare threads where the coating has

been removed should be recoated with a dry-moly lubricant.

2. Orient the hanger with the pup joint

down.

3. Examine the Casing Hanger Running




O-Ring is clean and undamaged.

Any bare threads where the coating has been removed should be recoated with a

dry-moly lubricant.

4. Orient the tool with the landing joint up.


Running

Procedure


WIP

Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 21


STAGE 6 – Running the 5 ½” Casing (Continued)

In the event 5-1/2" casing becomes stuck and the mandrel casing hanger cannot be utilized, reference the contingency

processes section in this book.

5. Wipe the running tool O-Ring with a light


6. Ensure the threads of the hanger and

running tool have been coated with a dry-

moly lubricant or phosphate.

7. Wipe the threads of the hanger with a

coat of anti-seize lubricant.

Do not use pipe dope or other metal

based compound, as this can cause galling.


180° apart on the landing joint and

maintaining a neutral weight, rotate the

running tool, first clockwise until the

thread jump can be felt, then

counterclockwise approximately 7

turns to a positive stop (RP102162).


9. Rotate the tool clockwise and align

the anti-rotation slots of the running tool

with the tapped holes in the hanger.

These holes are located immediately below the running threads of the hanger.


Running

Procedure


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:

Rob Hastings

:

Bruce Ross Page 22



10. Determine the elevation from the drilling

rig floor to the top of the drilling adapter

and record this dimension.

11. Measure the dimension from the top of

the drilling adapter to the rig floor plus

18.76" (the distance from the top of the

drilling adapter to the top of the load

shoulder in the casing head), up the

running tool landing joint and mark the

landing joint with a horizontal mark.

12. Install the anti-rotation lugs into the

tapped holes securely.

13. Lift the hanger/running tool assembly to

the rig floor.

14. Make up the casing hanger into the

casing string like any other casing joint

and torque to the thread manufacturer's

recommended optimum torque.

15. Open the outlet on the casing head and

drain the BOP Stack.

16. Remove the anti-rotation lugs from the

tapped holes of the hanger.

Failure to remove the anti-rotation lugs will prevent the running tool from being

backed off the hanger from the rig floor.

17. Release the 5-1/2" casing from the floor

slips and lower the hanger/running tool

through the BOP until it lands on the load

shoulder in the casing head.

18. Make a vertical mark on the landing joint

as a rotation indicator.

The horizontal mark made on the landing joint should be level with the rig floor.

19. Using two sets of chain tongs located 180° apart, rotate the

running tool clockwise 1 full turn.

20. Hold back up on the chain tongs on the landing joint to

prevent counterclockwise rotation.

21. Install the cement head on the landing joint, ensuring the

landing joint does not rotate.

22. Using the chain tongs installed previously, rotate the running

tool counterclockwise 1 full turn.



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Procedure


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:

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Bruce Ross Page 23



23. Remove the chain tongs.

24. Cement the 5-1/2" casing as per the

program.

In the event the 5-1/2" casing is to be reciprocated during the cement process, lift the hanger a minimum of 12" above

the load shoulder and make a horizontal mark on the landing joint. Do not reciprocate the 5-1/2" casing past this

mark.

If the casing begins to stick, immediately

land the hanger on the load shoulder of the casing head.

25. Once the cement operations are

complete, reinstall the two sets of chain

tongs 180° apart on the landing joint.

26. Holding backup on the landing joint,

remove the cement head from the

landing joint.

27. Rotate the landing joint clockwise

approximately 7 turns until the running

tool comes free of the casing hanger

(RP102163).

28. Remove tool with a straight vertical lift.

29. Lay the running tool down.


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Rob Hastings

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Bruce Ross Page 24



30. With well safe and under control, install a

back pressure valve into the prep in the

casing hanger using a dry rod

(RP102165).

31. Fully retract each of the dogs of the

drilling adapter to a positive stop

(RP102166).

The head of the drive screw will be

approximately flush with the OD of the drilling adapter when the dogs are fully retracted.

32. Holding the BOP/drilling adapter steady,

carefully lift it clear of the casing head

and set aside per rig procedure.


Running

Procedure


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Marion Robertson

:

Rob Hastings

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Bruce Ross Page 25


STAGE 7 – Installing and Testing the Packoff

Installing the Packoff

1. Thoroughly wash the ID of the Casing

Head, removing all debris from the

casing hanger threads, lockring and the

lockring groove.

2. Examine the WFT-TR Packoff. Verify the

following:


All O-Rings are properly installed, clean and undamaged.

Test port is unobstructed.

3. Wipe all O-Rings of the packoff with a


4. Wipe the threads of the hanger with a

coat of anti-seize lubricant.

Do not use pipe dope on these threads, as

this can cause galling.

5. Install the packoff over the hanger neck

and make it up onto the threads of the

hanger with a counterclockwise

rotation, approximately 7 turns, until the

face of the packoff is flush with the face

of the casing head.

When engaging the O-Rings of the packoff and the lockring of the hanger, an

increase in torque will be noticed.


Running

Procedure


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:

Rob Hastings

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Bruce Ross Page 26


STAGE 7 – Installing and Testing the Packoff (Continued)

Testing the Packoff

1. Locate the 1/8" test port on the top of the

packoff and remove the fitting

(RP102170).

2. Install a test pump to the open port and

inject test fluid to 5000 psi maximum.

3. Hold and monitor the test pressure for 15

minutes or as required by the drilling

supervisor.

4. Monitor the open outlet valve of the

casing head and the top of the casing

head for signs of leakage.

5. In the event a leak is detected, bleed off

all test pressure, remove the test pump

and remove the packoff from the casing

head.

6. Remove and replace all of the packoff O-

Rings and inspect the OD of the hanger

and ID of the casing head for damage.

7. Replace the packoff as previously

described.

8. Re-test the packoff as per this procedure.

9. Once a satisfactory test is achieved,

bleed off all test pressure, remove the

test pump and replace the fitting in the

test port.

The fitting should be flush with the face of

the hanger when properly installed.

10. Close the outlet valve of the casing head.


Running

Procedure


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Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 27


STAGE 8 – Installing the Casing Head Cap

1. Examine the WFT-TR Casing Head

Cap. Verify the threads are clean and

undamaged.

It may be necessary to insert a 1" bar in the holes in the OD of the cap in order to examine the WFT-TR Casing Head Cap.


2. Thoroughly clean the OD running threads

and face of the casing head.

3. Install an O-Ring into the ring grove of

the casing head.

The O-Ring serves as a trash seal only.

4. Wipe the threads of the head with a coat

of anti-seize lubricant.

Do not use pipe dope or other metal based compounds on these threads, as

this can cause galling.

5. Install the casing head cap over the

hanger neck and make it up to the

running threads of the casing by rotating

the cap counterclockwise

approximately 7 turns (RP102172).


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STAGE 9 – Installing the Flange

1. Examine the 5-1/8" WFT-TR Flange.

Verify the threads are clean and

undamaged.


2. Orient the flange with the raised face up.

3. Thoroughly clean the threads and all

exposed portions of the casing hanger.

4. Thoroughly lubricate the threads of the

casing hanger with an anti-seize

compound.

Do not use pipe dope or other metal based compound, as this can cause galling.

5. Install the 5-1/8" flange onto the threads

of the casing hanger with

counterclockwise rotation to a

positive stop (RP102174).

When fully made up, the raised face of the flange will be slightly below the face of

the hanger.

6. Remove the protector plate from the top

of the hanger.


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STAGE 10 – Installing the Tubing Spool

1. Examine the WFT-TCM Tubing Spool.



All ring grooves and seal areas are

clean and undamaged.

All lockscrews are fully retracted from the bore.

2. Thoroughly clean the ring groove in the

bottom of the tubing spool.

3. Remove the nuts from the studs in the

bottom of the tubing spool.

4. Install a new BX-169 Ring Gasket into

the ring groove of the casing hanger.

5. Orient the tubing spool as per the drilling

superintendent’s instructions.

6. Install the tubing spool onto the 5-1/8"

flange.

The flange may need to be rotated in order to properly align the tubing spool

with the casing head. Do not rotate the flange such that the raised face of the flange is above the face of the casing

hanger.

7. Install the nuts onto the studs and make

up the connection in an alternating cross

fashion as required.

8. Remove the back pressure valve from

the casing hanger and replace it with a

two way check valve.

9. Place a new R-46 Ring Gasket in the

top of the tubing spool and make up the

BOP stack per rig procedure.

10. Ensure the outlet valve of the tubing

spool is closed.

11. Close the blind rams of the BOP stack and inject pressure

through the outlet below the rams to 5000 psi maximum.

12. Hold and monitor the test pressure for 15 minutes or as

required by the drilling supervisor.

13. Once a satisfactory test is achieved, carefully bleed off all

test pressure and open the blind rams.

14. Remove the two way check valve.


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STAGE 11 – Testing the BOP Stack

Immediately after mak ing up the BOP stack

and periodically during the drilling of the hole

for the next string, the BOP stack

(connections and rams) must be tested.

1. Examine the 7-1/16" WFT-TCM Test

Plug. Verify the following:

O-Rings and plugs are properly installed, clean and undamaged.


2. Orient the test plug with the O-Rings up

and the drill pipe pin connection down.


the tool.

Remove 1/2" NPT pipe plug from the weep

port if pressure is to be supplied through the drill pipe.

4. Fully retract the lockscrews of the tubing

head (RP102178).

5. Open the outlet valve on the tubing head.

6. Wipe the O-Rings of the test plug with a


7. Lower the test plug through the BOP and

drilling adapter until it lands on the load

shoulder 7.12" below the face of the

tubing head.

8. Close the BOP rams on the drill pipe and

test to 5,000 psi maximum.

9. Monitor the open outlet for signs of

leakage past the test plug.

10. After a satisfactory test is achieved,

release the pressure, and open the rams.

11. Close the outlet valve.

12. Remove as much fluid from the BOP stack as possible.

13. Retrieve the test plug assembly slowly to avoid damage to

the seals.

14. Repeat this procedure as required during the drilling of the

hole.


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STAGE 12 – Installing Contingency Equipment

Contingency 9 5/8” Casing Procedure

In the event the 9 5/8” casing becomes stuck

during running, refer to this procedure for the

installation of the WFT-R7 Casing Head.

1. Cement the 9-5/8" casing in position as

required per drilling program.

2. Lift the diverter assembly as high as

possible and rough cut the 9-5/8" casing.

The intended casing head overall length is 19.50”. The emergency casing head

with the slip on weld bottom is 17.75”. In order to maintain the same overall wellhead height, the 9-5/8" casing must be

cut 6.75" above the top of the 16" conductor.

3. Remove the landing ring from the

conductor pipe.

4. Final cut the 9-5/8" casing at the correct

elevation.

Ensure the cut on the conductor is level, as this will determine the orientation of the remainder of the wellhead equipment.

5. Remove the excess 9-5/8" casing and

lay down the casing head/running tool

assembly.

6. Bevel the 9-5/8" casing with a 3/16" x

3/8" bevel and remove any sharp edges

from the OD of the casing (RP102180).

7. Break a 1/8" x 45° bevel on the ID of the

casing.

8. Examine the WFT-R7 Casing Head with the slip on and

weld bottom. Verify the following:


Seal areas, threads and ring grooves are clean and

undamaged.

All peripheral equipment is intact and undamaged.

9. Wipe the ID of the O-Ring with a light coat of oil or grease.


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STAGE 12 – Installing Contingency Equipment (Continued)

Excessive oil or grease will prevent a positive seal from forming.

10. Lower the casing head over the 9-5/8

casing stub to a positive stop.

11. Remove the fitting from the test port and

set aside.

12. Orient the casing head outlets as per the

drilling superintendent’s instructions.

13. Ensure the casing head is plumb and

level, and weld and test the 9-5/8" casing

to the casing head as per the

RECOMMENDED WELDING

PROCEDURE located in the back of this

running procedure.


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Contingency 5 ½” Casing Procedure

In the event the 5 ½” casing becomes stuck

during running, refer to this procedure for the

installation of the WFT-22 Casing Hanger.

1. Cement the hole as required.

2. Drain the wellhead assembly through the

casing head side outlet valve.

3. Lift and suspend the drilling adapter

above the casing head a minimum of 18"

as previously described in this manual.

4. Open the outlet valve on the casing head

and wash out the casing head bowl as

required.

5. Examine the 11" x 5-1/2" WFT-22

Casing Hanger. Verify the following:

Slip segments and internal bore are clean and undamaged.

All screws are in place.

6. Place two boards on the lower housing

flange against the casing to support the

hanger.

7. Open the hanger and wrap it around the

casing, allowing the support boards to

carry the weight.

8. Remove the slip retaining screws from

the OD of the hanger body and allow the

slip segments to settle around the

casing.

9. Supporting the weight of the hanger,

remove the support boards and lower the

hanger into the casing head bowl.


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10. Once the hanger is down, pull tension on

the casing to the desired hanging weight

and slack off.

A sharp decrease on the weight indicator will signify that the hanger has taken weight and at what point. If this does not

occur, pull tension again and slack off once more.

11. Rough cut the casing approximately 12”

above the top of the casing head and

remove the excess casing.

12. Final cut the casing at 6.25" ±1/8" above

the face of the casing head.

13. Grind the casing stub level and place a

3/16" x 3/8" bevel on the OD and break

the ID edge.

14. Close the outlet valve on the casing

head.


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Casing Head Flange Installation

Installation of a contingency casing head

flange may be necessary during the running

process.

1. Examine the 11" WFT-TR Flange.

Verify the threads are clean and

undamaged.


2. Orient the flange with the threads down.

3. Thoroughly clean the threads of the

casing head.

4. Thoroughly lubricate the threads of the

casing head with an anti-seize

compound.

Do not use pipe dope, as this can cause

galling.

5. Install the 11” flange onto the threads of

the casing head with counterclockwise

rotation to a positive stop

(RP102186).

When fully made up, the face of the flange will be level with the face of the casing head.


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Crossover Spool Installation

Installation of a crossover spool may be

necessary during the running process.

1. Examine the WFT-SPCL Crossover

Spool. Verify the following:


Ring grooves, seal areas and BPV threads are clean and undamaged.

FS seals are properly installed, clean and undamaged.

2. Clean the mating ring grooves of the

casing head and adapter.

3. Lightly lubricate the ID of the FS seals

and casing stub with a light oil or grease.

Excessive grease may prevent a positive

from forming.

4. Install a new R-54 Ring Gasket in the

ring groove of the casing head.

5. Ensure the bolt holes of the flange on the

casing head are properly aligned (two-

holed).

6. Orient the adapter as required and

carefully lower the adapter over the

casing stub and land it on the ring

gasket.

7. Make up the flange connection with the

studs and nuts provided, tightening them

in an alternating cross pattern as

required (RP102188).

Any damage to the FS seal elements

could impair their sealing ability.


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Stage 12 – Installing Contingency Equipment (Continued)

Seal Testing the Adapter

1. Locate the SEAL TEST fitting and the

FLG TEST fitting on the adapter lower

flange and remove the dust cap from

both fittings.

2. Attach a bleeder Tool to the FLG TEST

fitting and open the Tool (RP102189).

3. Attach a test pump to the SEAL TEST

fitting and inject clean test fluid between

the FS seals to 10,000 psi or 80% of

casing collapse pressure — whichever is

less.


minutes or as required by the drilling

supervisor.

5. Monitor the open outlet valve of the

casing head, ID of the adapter and open

bleeder tool for signs of leakage.

Once a satisfactory test is achieved, remove the test pump and drain the test fluid.


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Stage 12 – Installing Contingency Equipment (Continued)

Flange Testing the Adaptor

1. Attach a test pump to the FLG TEST

fitting.

2. Attach a bleeder tool to the SEAL TEST

fitting and open the tool (RP102190).

3. Inject clean test fluid into the void area

between the flanges to 5,000 psi or 80%

of casing collapse — whichever is less.


minutes, or as required by the drilling

supervisor.

5. Monitor the open outlet valve of the casing head, ring gasket

and open bleeder tool for signs of leakage.

6. Once a satisfactory test is achieved, remove the test pump

and bleeder tool, drain all test fluid pressure, and reinstall

the dust caps.

7. Install the tubing spool as previously described.


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APPENDIX A: Recommended Welding Procedure for Field

Welding Pipe to Wellhead Parts for Pressure Seal

1. Introduction and Scope. The following recommended procedure has been prepared with particular regard to attaining pressure-tight weld

when attaching casing heads, flanges, etc., to casing. Although most of the high strength casing used (such as N-80) is not normally considered

field weldable, some success may be obtained by using the following or similar procedures.

Caution: In some wellheads, the seal weld is also a

structural weld and can be subjected to high tensile stresses. Consideration must therefore be given by competent authority to the mechanical

properties of the weld and its heat affected zone.

a. The steels used in wellhead parts and in casing are high strength steels that are susceptible to

cracking when welded. It is imperative that the finished weld and adjacent metal be free from cracks. The heat from welding also affects the

mechanical properties. This is especially serious if the weld is subjected to service tension stresses.

b. This procedure is offered only as a

recommendation. The responsibility for welding lies with the user and results are largely governed by the welder's skill. Weldability of the several makes

and grades of casing varies widely, thus placing added responsibility on the welder. Transporting a qualified welder to the job, rather than using a less-

skilled man who may be at hand, will, in most cases, prove economical. The responsible operating representative should ascertain the

welder's qualifications and, if necessary, assure himself by instruction or demonstration, that the welder is able to perform the work satisfactorily.

2. Welding Conditions. Unfavorable welding conditions must be avoided or minimized in every way possible, as even the most skilled welder

cannot successfully weld steels that are susceptible to cracking under adverse working conditions, or when the work is rushed. Work

above the welder on the

drilling floor should be avoided. The weld should be protected

from dripping mud, water, and oil and from wind, rain, or other adverse weather conditions. The drilling mud, water, or

other fluids must be lowered in the casing and kept at a low level until the weld has properly cooled. It is the responsibility of the user to provide

supervision that will assure favorable working conditions, adequate time, and the necessary cooperation of the rig personnel.

3. Welding. The welding should be done by the shielded metal-arc or other approved process.

4. Filler Metal. Filler Metals. For root pass, it’s

recommended to use E6010, E6011 (AC), E6019 or equivalent electrodes. The E7018 or E7018-A1 electrodes may also be used for root pass

operations but has the tendency to trap slag in tight grooves. The E6010, E6011 and E6019 offer good penetration and weld deposit ductility with

relatively high intrinsic hydrogen content. Since the E7018 and E7018- A1 are less susceptible to hydrogen induced cracking, it is recommended for

use as the filler metal for completion of the weld groove after the root pass is completed. The E6010, E6011 (AC), E6019, E7018 and E7018-A1

are classified under one of the following codes AWS A5.1 (latest edition): Mild Steel covered electrodes or the AWS A5.5 (latest edition): Low

Alloy Steel Covered Arc-Welding Electrodes. The low hydrogen electrodes, E7018 and E7018-A1, should not be exposed to the atmosphere until

ready for use. It’s recommended that hydrogen electrodes remain in their sealed containers. When a job arises, the container shall be opened and all

unused remaining electrodes to be stored in heat electrode storage ovens. Low hydrogen electrodes exposed to the atmosphere, except water, for more

than two hours should be dried 1 to 2 hours at 600ºF to 700 ºF (316ºC to 371 ºC) just before use. It’s recommended for any low hydrogen electrode

containing water on the surface should be scrapped.


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APPENDIX A: (Continued)

5. Preparation of Base Metal. The area to be welded

should be dry and free of any paint, grease/oil and dirt. All rust and heat-treat surface scale shall be ground to bright metal before welding.

6. Preheating. Prior to any heating, the wellhead member shall be inspected for the presence of any O-Rings or other polymeric seals. If any O-Rings or

seals are identified then preheating requires close monitoring as noted in paragraph 6a. Before applying preheat, the fluid should be bailed out of

the casing to a point several inches (>6” or 150 mm) below the weld joint/location. Preheat both the casing and wellhead member for a minimum

distance of three (3) inches on each side of the weld joint using a suitable preheating torch in accordance with the temperatures shown below in

a and b. The preheat temperature should be checked by the use of heat sensitive crayons. Special attention must be given to preheating the

thick sections of wellhead parts to be welded, to insure uniform heating and expansion with respect to the relatively thin casing.

a. Wellhead members containing O-Rings and other polymeric seals have tight limits on the preheat and inter-pass temperatures. Those temperatures

must be controlled at 200ºF to 325ºF or 93 ºC to 160ºC and closely monitored to prevent damage to the o-ring or seals.

b. Wellhead members not containing O-Rings and other polymeric

seals should be maintained at a preheat and inter-pass

temperature of 400ºF to 600ºF or 200ºC to 300ºC.

7. Welding Technique. Use a 1/8 or 5/32-inch (3.2 or

4.0 mm) E6010 or E7018 electrode and step weld the fi rst bead (root pass); that, weld approximately 2 to 4 inches (50 to 100 mm) and then move

diametrically opposite this point and weld 2 to 4 inches (50 to 100 mm) halfway between the first two welds, move diametrically opposite this weld,

and so on until the first pass is completed. This second pass should be made with a 5/32-inch (4.0 mm) low hydrogen electrode of the proper strength

and may be continuous. The balance of the welding groove may then be filled with continuous passes without back stepping or lacing, using a

3/16-inch (4.8 mm) low hydrogen electrode. All beads should be stringer beads with good penetration. There should be no undercutting and

weld shall be workmanlike in appearance.

a. Test ports should be open when welding is performed to prevent pressure buildup within the

test cavity.

b. During welding the temperature of the base metal on either side of the weld should be maintained at

200 to 300°F (93 to 149°C).

c. Care should be taken to insure that the welding cable is properly grounded to the casing, but

ground wire should not be welded to the casing or the wellhead. Ground wire should be firmly clamped to the casing, the wellhead, or fixed in

position between pipe slips. Bad contact may cause sparking, with resultant hard spots beneath which incipient cracks may develop. The welding

cable should not be grounded to the steel derrick, nor to the rotary-table base.


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APPENDIX A: (Continued)

8. Cleaning. All slag or flux remaining on any welding

bead should be removed before laying the next bead. This also applies to the completed weld.

9. Defects. Any cracks or blow holes that appear on

any bead should be removed to sound metal by chipping or grinding before depositing the next bead.

10. Post-heating. Post-heating should be performed at the temperatures shown below and held at that temperature for no less than one hour followed by

a slow cooling. The post-heating temperature should be in accordance with the following paragraphs.

a. Wellhead members containing O-Rings and other polymeric seals have tight limits on the post-heating temperatures. Those temperatures must

be controlled at 250ºF to 300ºF or 120 ºC to 150ºC and closely monitored to prevent damage to the o-ring or seals.

b. Wellhead members not containing O-Rings and other

polymeric seals should be post-heated at a

temperature of 400ºF to 600ºF or 200ºC to 300ºC.

11. Cooling. Rapid cooling must be avoided. To assure

slow cooling, welds should be protected from extreme weather conditions (cold, rain, high winds, etc.) by the use of suitable insulating material. (Specially designed

insulating blankets are available at many welding supply stores.) Particular attention should be given to maintaining uniform cooling of the thick sections of the

wellhead parts and the relatively thin casing, as the relatively thin casing will pull away from the head or hanger if allowed to cool more rapidly. The welds

should cool in air to less than 200°F (93°C) (measured with a heat sensitive crayon) prior to permitting the mud to rise in the casing.

12. Test the Weld. After cooling, test the weld. The weld must be cool otherwise the test media will

crack the weld. The test pressure should be no more than 80% of the casing collapse pressure.

Test Media

Acceptable Medias Unacceptable

Medias

Water Oxygen

Water Soluble Oil Acetylene

Inert Gas Hydraulic Oil

Nitrogen Motor Oil

Argon Gas Brake Fluid


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APPENDIX B: Recommended Procedure for API 6A Flange Connections

Inspection and Preparation 1. Inspect the gasket seating surfaces. Look for tool marks, cracks,

scratches or pitting by corrosion and make sure that the gasket seating surface is proper for the type of gasket being used.

Radial tool marks on a gasket seating surface are virtually impossible to seal regardless of the type gasket being used, therefore every attempt must be made to minimize these.

2. Inspect the gasket. Make sure the material is as specified, look for any possible defects or damage in the gasket.

3. Inspect and clean each stud or bolt, each nut, each washer, and

the facing on the flanges against which the nuts will rotate. Look for severe galling, pitting, etc. If any of the above mentioned items are damaged beyond repair, replace that item.

4. Lubricate all thread contact areas and nut facings. The importance of proper lubrication cannot be overstressed. No joint should be made up without the proper lubricant being applied to

the threaded surfaces and to the nut facings. When flanges will be subjected to high temperatures, the use of an anti-seize compound should be considered to facilitate subsequent

disassembly. There are available on the market today a vast variety of suitable lubricants that can be selected to provide the necessary low coefficient of friction for installation and adequate

anti-seize properties for high temperature application. The better the lubricant, the more consistent will be the actual achieved bolt stress at installation.

5. With raised face and flat face installation, loosely install the stud bolts on the lower half of the flange. Insert the gasket between the flange facing to allow the bolts to center the gasket on the assembly. Install the balance of the bolts and nuts and bring all to a hand-tight or snug condition. (if the gasket is being installed in

a recess or a groove, center the gasket midway into the recess or the groove. If the joint is vertical it may be necessary to use some cup grease or a small amount of gasket cement or some other adhesive compatible with the process fluids, to keep the gasket in position until the flanges are tightened.)

Know Your Bolts and Studs Studs nuts must meet the requirements of the applicable ASTM specs unless otherwise noted. Dimension and

thread pitch will be per ASTM A -193 for studs and ASTM A 194 for nuts. The mechanical properties as

specified in API Specification 6A/ISO 10423. API flanges takes precedence from those required by ASTM.

Inspect all bolts and studs for any coatings or irregular surfaces that will change torque requirements during final assembly.


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APPENDIX B: (Continued)

API Flange - Bolt Sizes and Quantities

Flange Size

2000 PSI 3000 PSI 5000 PSI

Numbe

r of

Studs

Diamet

er

Nut

Size

ATF

Numbe

r of

Studs

Diamet

er

Nut

Size

ATF

Numbe

r of

Studs

Diame

ter

Nut

Size

ATF

1 13/16

2 1/16 8 5/8 1 1/16 8 7/8 1 7/16 8 7/8 1 7/16

2 9/16 8 3/4 1 1/4 8 1 1 5/8 8 1 1 5/8

3 1/16

3 1/8 8 3/4 1 1/4 8 7/8 1 7/16 8 1 1/8 1 13/16

4 1/16 8 7/8 1 7/16 8 1 1/8 1 13/16 8 1 1/4 2

5 1/8

7 1/16 12 1 1 5/8 12 1 1/8 1 13/16 12 1 3/8 2 3/16

9 12 1 1/8 1 13/16 12 1 3/8 2 3/16 12 1 5/8 2 9/16

11 16 1 1/4 2 16 1 3/8 2 3/16 12 1 7/8 2 15/16

13 5/8 20 1 1/4 2 20 1 3/8 2 3/16 16 1 5/8 2 9/16

16 3/4 20 1 1/2 2 3/8 20 1 5/8 2 9/16 16 1 7/8 2 15/16

18 3/4 20 2 3 1/8

20 3/4 20 2 3 1/8

21 1/4 24 1 5/8 2 9/16 24 2 3 1/8

26 3/4 20 1 3/4 2 3/4 24 2 3 1/8

Flange Size

10,000 PSI 15,000 PSI 20,000 PSI

Numbe

r of

Studs

Diamet

er

Nut

Size

ATF

Numbe

r of

Studs

Diamet

er

Nut

Size

ATF

Numbe

r of

Studs

Diame

ter

Nut

Size

ATF

1 13/16 8 3/4 1 1/4 8 7/8 1 7/16 8 1 1 5/8

2 1/16 8 3/4 1 1/4 8 7/8 1 7/16 8 1 1/8 1 13/16

2 9/16 8 7/8 1 7/16 8 1 1 5/8 8 1 1/4 2

3 1/16 8 1 1 5/8 8 1 1/8 1 13/16 8 1 3/8 2 3/16

3 1/8

4 1/16 8 1 1/8 1 13/16 8 1 3/8 2 3/16 8 1 3/4 2 3/4

5 1/8 12 1 1/8 1 13/16

7 1/16 12 1 1/2 2 3/8 16 1 1/2 2 3/8 16 2 3 1/8

9 16 1 1/2 2 3/8 16 1 7/8 2 15/16 16 2 1/2 3 7/8

11 16 1 3/4 2 3/4 20 2 3 1/8 16 2 3/4 4 1/4

13 5/8 20 1 7/8 2 15/16 20 2 1/4 3 1/2 20 3 1/8 4 13/16

16 3/4 24 1 7/8 2 15/16

18 3/4 24 2 1/4 3 1/2 20 3 4 5/8

20 3/4

21 1/4 24 2 1/2 3 7/8

26 3/4


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Bolting and Tensioning Sequences 6. Torque bolts in a minimum of four stages as listed in

Steps 7, 8, 9, and 10.

7. Torque the bolts up to a maximum of 30 percent of the final torque value required, following the sequence

recommended. Number bolts so that torque requirements can be followed. With any gasket material, it is extremely important to follow a proper bolting

sequence. If this sequence is not followed, the flanges can be cocked. Then,

regardless of the amount of subsequent torque, they cannot be brought back

parallel. This problem, of course, is maximized on metallic gaskets more so

than on nonmetallic.

8. Repeat step 7, increasing the torque to

approximately 60 percent of the final torque required.

9. Repeat step 8,

increasing the torque to the final torque value.

10. On high-pressure, high-

temperature applications, it is suggested that the flanges be retightened to

the required stress after 24 hours at operating pressures and

temperatures to compensate for any relaxation or creep that

may have occurred.


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Tightening Methods The two most common methods for tightening of bolted flange joints are either by torque using torque wrenches

or by direct tension using hydraulic stud bolt tensioners. Regardless of the method selected a pre-bolting inspection is essential if an accurate and leak free joint is to be achieved first time, every time. The inspection must include checking for any damage to the gasket and sealing surfaces, ensuring that the stud bolts and

nuts are the correct size and material, are not damaged in any way and that the correct lubricant is to be used. Additionally it is vitally important that the two flanges are correctly aligned to each other and that the stud bolts can be easily fitted through the bolt holes. If any of the above checks are not satisfactory immediate

remedial action must take place before starting to bolt up the joint.

Tightening Using Torque Wrenches Insert the stud bolts through both flanges and hand tighten the nuts on both sides ensuring that there is full thread

engagement on both nuts of every stud bolt. Square up the joint and ensure that all stud bolts are freely moving through the bolt holes and that the nuts are hand tightened against the outer flange faces. Number all bolts sequentially in a diametrically opposed fashion as shown in the illustrations on the preceding page.

Commence tightening of the bolts sequentially starting with a first pass at 30% of the final specified and required torque figure, a second pass at 60% and then a third pass at 100%. Finally a check pass should be carried out in either a clockwise or anti-clockwise direction at 100% of the required torque to ensure

all bolts are uniformly tightened.

Tensioning Procedure Using Hydraulic Stud Bolt Tensioners Insert the stud bolts through both flanges and hand tighten the nuts on both sides ensuring that there is full thread

engagement on both sides. Take care to ensure that on the selected flange face, to which the tensioners are to be affixed, that there is at least 1 x diameter of the stud bolt thread protruding above the nut face. This is required for the Tensioner puller to attach to and if insufficient thread is exposed then the tensioning

procedure must not proceed. The exact number and positioning of the hydraulic stud bolt tensioners must then be ascertained i.e. 30%, 60% or 100% simultaneous tensioning of all the bolts in the respective joint. After deciding the number of stud bolt tensioners to be used simultaneously, affix them to the exposed thread

end of the stud bolts, equally spaced around the flange for 30% or 60% simultaneous tensioning, or on every stud bolt in the case of 100% simultaneous tensioning.

Final Check Regardless of Tensioning Method Whether tightening the bolts using a torque wrench or stud bolt tensioners it is a good idea to carry out a final

check for tightness of all the bolts by simply tapping each nut with a hammer and listen to see if a high pitched ringing sound is achieved. A dull sound indicates that the respective bolt is still loose.


Running

Procedure


WIP

Marion Robertson

:

Rob Hastings

:

Bruce Ross Page 46



Recommended Torque Values for Flange Bolting Reference: API Specification 6A/ISO 10423 (Appendix D)

Torque for Flange Bolting (B7/L7 Studs)*

Stud Diameter Tension PTFE Coated Bolt coefficient of Friction Plain Bolt coefficient of Friction

Size Ib/ft

Torque Torque Torque Torque

Inch Nm Ft. lbs Nm Ft. lbs

f =0.07 f =0.07 f =0.13 f =0.13

1/2" 7450 48 35 80 59

5/8" 11865 92 68 155 115

3/4" 17559 160 118 270 200

7/8" 24241 253 188 429 319

1" 31802 376 279 639 474

1 1/8" 41499 540 401 925 686

1 1/4" 52484 745 553 1285 953

1 3/8" 64759 996 739 1727 1281

1 1/2" 78322 1297 962 2261 1677

1 5/8" 93173 1653 1226 2894 2146

1 3/4" 109313 2069 1534 3636 2696

1 7/8" 126741 2549 1890 4493 3332

2" 145458 3097 2297 5476 4061

2 1/4" 186758 4418 3276 7851 5822

2 1/2" 233212 6068 4500 10828 8030

2 5/8" 233765 6394 4716 11429 8430

2 3/4" 257694 7354 5424 13168 9712

3" 309050 9555 7047 17156 12654

3 1/4" 365070 12154 8965 21878 16136

3 3/4" 491099 18685 13782 33766 24905

3 7/8" 525521 20620 15208 37293 27506

4" 561108 22683 16730 41057 30282

*This chart is for general practice purposes only and should not be used in the engineering or design of any products. The most

current edition of the API specification may be obtained on the API Standards website to make sure you have the most

current edition of API 6A. For most the accurate references in critical situations torque values should be replaced with field

measured tension values. Accurate stud tension is difficult to attain using torque, because friction has a significant effect on

the torque–tension relationship. Any thread damage (however minor), additional lubrication, or standard deviations within a

bolt or stud material range, can all contribute to inconsistent results.

Documents

RP-205 R7 Wellhead WIP