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 465-3-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.

Transformer
R7 Wellhead System
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

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
Rob Hastings
:
Bruce Ross Page 3
Figure 1. Transformer R7 Wellhead Dimensional Data

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
Rob Hastings
:
Bruce Ross Page 4
Figure 2. Transformer R7 Wellhead Components

Transformer
R7 Wellhead System
Running
Procedure
WIP
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 Specification
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

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
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

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
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

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
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.

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
Rob Hastings
:
Bruce Ross Page 9
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).

Transformer
R7 Wellhead System
Running
Procedure
WIP
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.

Transformer
R7 Wellhead System
Running
Procedure
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:
Rob Hastings
:
Bruce Ross Page 11
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.

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
Rob Hastings
:
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.

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
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.

Transformer
R7 Wellhead System
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.
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.

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
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.

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
Rob Hastings
:
Bruce Ross Page 16
STAGE 4 – Testing the BOP Stack
Immediately after making 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.

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
Rob Hastings
:
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.

Transformer
R7 Wellhead System
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.
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.

Transformer
R7 Wellhead System
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.

Transformer
R7 Wellhead System
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:
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.
dry-moly lubricant.
2. Orient the hanger with the pup joint
down.
3. Examine the Casing Hanger Running
undamaged.
 O-Ring is clean and undamaged.
dry-moly lubricant.
4. Orient the tool with the landing joint up.

Transformer
R7 Wellhead System
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.
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.

Transformer
R7 Wellhead System
Running
Procedure
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Marion Robertson
:
Rob Hastings
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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.

Transformer
R7 Wellhead System
Running
Procedure
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:
Rob Hastings
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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.

Transformer
R7 Wellhead System
Running
Procedure
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Marion Robertson
:
Rob Hastings
:
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.

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
Rob Hastings
:
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:
undamaged.
 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
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.

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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.

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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.
dry-moly lubricant.
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.
based compounds on these threads, as
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.
dry-moly lubricant.
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.
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
 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 making 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.
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
 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.
dry-moly lubricant.
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

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
Rob Hastings
:
Bruce Ross Page 44
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.

Transformer
R7 Wellhead System
Running
Procedure
WIP
Marion Robertson
:
Rob Hastings
:
Bruce Ross Page 45
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.

Transformer
R7 Wellhead System
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 PTFECoated BoltcoefficientofFriction 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 chartis for general practice purposes only and should notbe used in the engineering or design ofany products. The most
currentedition of the API specification may be obtained on the API Standards website to make sure you have the most
currentedition 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 significanteffect on
the torque–tension relationship.Any thread damage (however minor),additional lubrication,or standard deviations within a
boltor stud material range,can all contribute to inconsistentresults.

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