RP-002393 Cab Comp Integral Cameron

EXCO Resources

13-5/8" 5M MB-ND

RUNNING PROCEDURE

RP111934 5-1/2" CASING 2-3/8" TUBING 20" CONDUCTOR 13-3/8" CASING 9-5/8" CASING 13-5/8" 5M BX-160 Ring Gasket 7-1/16" 10M BX-156 Ring Gasket 2-1/16" 5M R-24 Ring Gasket 2-1/16" 5M R-24 Ring Gasket 2-1/16" 5M R-24 Ring Gasket 1-13/16" 10M BX-151 Ring Gasket

RP-002393

Rev 02

Page 2

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

This document alone does not qualify an individual to Install/Run the Equipment. This document is

created and provided as a reference for Qualified Cameron Service Personnel and does not cover

all scenarios that may occur.

© 2011 Cameron International Corporation. All rights reserved. This material is the copyrighted work of Cameron

International Corporation and may not be reproduced, displayed, modified or distributed without the express prior

written permission of the copyright holder.

Safety Hazard Indicators

STOP

Indicates a hazardous situation which, if not avoided, could result in minor or moderate injury

Indicates a hazardous situation which, if not avoided, could result in death or serious injury

Indicates a hazardous situation which, if not avoided, will result in death or serious injury

Preferred to address practices not related to personal injury

Table of Contents

System Drawing ... 4

Bill of Materials ... 5

WKM Model M Power R- Seal Gate Valves ... 6

Cameron Type FL & FLS Gate Valves... 7

Make-up Requirements for API FlangeConnections... 7

Running Procedure General Warning ... 8

Stage 1.0 — 20" Casing ... 9

1.1

Install the Load Ring ... 9

1.2

Install the Riser Adapter ... 10

1.3

Energize the WQ Seals ... 11

1.4

Test Between the Seals ... 12

Stage 2.0 — 13-3/8" Casing ... 13

2.1

Install the Casing Head ... 13

Stage 3.0 — 9-5/8" Casing ... 16

3.1

Test the BOP Stack ... 16

3.2

Run the Wear Bushing Before Drilling ... 17

3.3

Retrieve the Wear Bushing After Drilling ... 18

3.4

Hang Off the Casing ... 19

3.5

Installing the Packoff Bushing ... 22

3.6

Test Between the Seals ... 23

Stage 4.0 — 5-1/2" Casing ... 24

4.1

Test the BOP Stack ... 24

4.2

Run the Wear Bushing Before Drilling ... 25

4.3

Retrieve the Wear Bushing After Drilling ... 26

4.4

Hang Off the Casing ... 27

4.5

Recommended Procedure Wash Out for the Seal Assembly ... 30

4.6

Install the Seal Assembly ... 31

4.7

Testing the Seal Assembly ... 33

Stage 5.0 — 2-3/8" Tubing... 34

5.1

Install the Tubing Spool ... 34

5.2

Energize the P Seal ... 35

5.3

Test the Connection ... 35

5.4

Install the Tubing Hanger ... 36

5.5

Install the Christmas Tree ... 38

Torque Chart ... 39

RP-002393

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13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

System Drawing

RP111934 13-3/8" CASING 9-5/8" CASING 5-1/2" CASING 2-3/8" TUBING 20" CONDUCTOR 13-5/8" 5M BX-160 Ring Gasket 7-1/16" 10M BX-156 Ring Gasket 2-1/16" 5M R-24 Ring Gasket 2-1/16" 5M R-24 Ring Gasket 2-1/16" 5M R-24 Ring Gasket 1-13/16" 10M BX-151 Ring Gasket A2 A1 B9 B10 A4 A3 A5 A7 A6 A8 B11 B12 B1 B2 B3 B5 B4 B6 B7 B8 C8 C14 C9 C1 C2 C10 C11 C4 C5 C6 C7 C3 C12 C13

Item Qty Description

A1 1 Casing Head Housing,

MB-ND, 13-5/8" 5M x 13-3/8" LTC casing bottom, w/ two 2-1/ 16" 5M SSOs

Part # 2345472-01 A2 1 Load Ring f/ 20" casing

Part # 2329762-02-01 A3 2 Ball Valve, 3.00" x 3.00"

Part # 2168114-10-31 A4 2 Nipple, 3.00" LP x 6.00" long

Part # 021013-24

A5 2 Gate Valve, AOP

Commer-cial, 2-1/16" 5M, flanged Part # 2737400-01-01 A6 2 Companion Flange, 2-1/16" 5M X 2" LP Part # 142362-01-03-01 A7 4 Ring Gasket, R-24 Part # 702001-24-02 A8 16 Studs w/ two Nuts 7/8 X 6"

long

Part # Y51201-20220201

CHRISTMAS TREE ASSEMBLY

Item Qty Description

C1 1 Tubing Head Adapter, A5P

7-1/16" 10M x 2-1/16" 5M Part # 2737476-01

C2 4 Gate Valve, AOP

Commer-cial, 2-1/16" 5M, flanged Part # 2737400-01-01 C3 1 Cross, 2-1/16" 5M all

stud-ded

Part # 257493-01-03-01 C4 1 Tree Cap, 2-1/16" 5M x 2-3/

8" 8rd lift thread

Part # Y22337-00100121

C5 1 Gate Valve, AOP w/BNT and

Pneumatic Diaphragm Ac-tuator Part # 2031071-01-72 C6 1 Choke, 2" 5M, flanged Part # 2716465 C7 2 Companion Flange, 2-1/16" 5M x 2" LP Part # 142362-01-03-01 C8 1 Ring Gasket, BX-156 Part # 702003-15-62 C9 12 Stud w/ two Nuts, 1-1/2" x

11-1/4" long

Part # Y51201-20621601 C10 10 Ring Gasket, R-24

Part # 702001-24-02 C11 40 Stud w/ two Nuts, 7/8" x 6.00"

long Part # Y51201-20220201 C12 1 Valve, Needle 1/2" NPT 10M Part # 007482-40 C13 1 Pressure Gauge 0-5M Part # 038236-05

C14 1 TC-1A-EN Tubing Hanger,

7-1/16" x 2-3/8" EUE, w/ 2" H BPV prep

Part # 2133797-17-01

Bill of Materials

CASING HEAD ASSEMBLY TUBING SPOOL ASSEMBLY

Item Qty Description

B1 1 Tubing Spool, Type 'C', 13-5/ 8" 5M x 7-1/16" 10M, w/ two 1-13/16" 10M SSOs, w/ 11" NX prep bottom

Part # 2247641-04-01 B2 1 'NX' Bushing, 11" nom x 7"

OD casing, w/ integral bit Part # 2161829-01-01

B3 2 Gate Valve, manual, FLS,

1-13/16" 10M, flanged Part # 141510-41-91-01 B4 2 Companion Flange, 1-13/ 16" 10M x 2" LP Part # 142359-01-03-02 B5 4 Ring Gasket, BX-151 Part # 702003-15-12 B6 16 Stud w/ two Nuts, 3/4"-10 x

5-1/4" long

Part # Y51201-20120201 B7 16 Stud & Nuts, 1.625 x 12.75"

long

Part # 621650-11

B8 1 Ring Gasket, BX-160

Part # 702003-16-02

B9 1 Casing Hanger, Mandrel,

MB-ND, 13-5/8" nom x 9-5/8" Buttress Box bottom x 10.000"- 4 tpi Stub Acme LH running threads

Part # 2345509-01

B10 1 Bushing, Packoff Support,

MB-ND, 13-5/8" Nom, f/ 9-5/ 8" mandrel casing hanger Part # 2161673-10-01 B11 1 Tubing Hanger, MB-ND, 11"

nom x 5-1/2" 20lb/ft Tenaris Blue box thread bottom x 7.500"-4 tpi LH Stub Acme running threads, w/ 5" Type 'H' BPV, w/ 7" slick neck top Part # 2345649-02

B12 1 Assy Seal Packoff, f/ 11" nom MB-ND, w/ 9.875-4tpi LH Stub Acme running threads Part # 2217588-02-01

RP-002393

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13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

WKM Model M

Power R- Seal Gate Valves

For Operation and Maintenance

refer to:

Publication: TC9084-2

(Operation and Maintenance

Manual)

STOP

TC9084-2

SERVICE TOOLS

Item Qty Description

ST1 1 Riser Adapter

Part # PART NOT AVAILABLE

ST2 1 Housing Running Tool, 13-3/8" LTC Box thread top x 18-250 OD-4TPI LH Stub Acme running thread

Part # 2017488-09

ST3 1 Test Plug, Type 'C', 13-5/8" nom x 4-1/2" IF Box bottom x top

Part # 2247044-01-01

ST4 1 Wear Bushing Running & retrieving Tool, IC-2, 13-5/8" nom x 4-1/2" IF box top x bottom Part # 2301310-02

ST5 1 Wear Bushing, 13-5/8" nom w/ 4 stop rings Part # 2135031-21

ST6 1 MB-ND Hanger Running Tool, 13-5/8" nom x 10.000"-4TPI LH Stub Acme bottom thread x 9-5/ 8" 8rd LC top thread, w/ 3 centralizing ribs Part # 2161757-03-01

ST7 1 Running Tool f/ 13-5/8" nom Seal Packoff w/ 4-1/ 2" IF and 12.375-4TPI LH Stub Acme thread Part # 2017712-04-01

ST8 1 Test Plug, Running and Retrieving Tool, IC-2, 11" nom x 4-1/2" IF Box bottom x top

Part # Y29301-71200711

ST9 1 Wear Bushing f/ 11" nom type MB-ND Part # 2125720-04

ST10 1 MB-ND Hanger Running Tool, 11" nom x 7.500-4TPI LH Stub Acme internal thread bottom x 5-1/ 2" Tenaris Blue Box top w/ 3 centralizing ribs Part # 2161757-41-01

ST11 1 Wash Tool, Weldment, 11" x 23.00" long w/ 4-1/ 2" IF Box top

Part # 2017726-05-01

ST12 1 Running Tool f/ 11" nom Seal Assembly w/ 4-1/ 2" IF bottom and 9-875"4TPI LH Stub Acme running thread

Cameron Type FL & FLS

Gate Valves

For Operation and Maintenance

refer to:

Publication: TC148-2

(FL & FLS Gate Valves

Operation and Maintenance

Manual)

STOP

TC148-Make-up Requirements

for API Flange

Connections

Refer to:

Publication: RP-002153

RP-002393

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13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

RUNNING PROCEDURE GENERAL WARNING

READ AND UNDERSTAND ALL INSTRUCTIONS. Failure to follow may result in serious personal injury and damage not only to the equipment but also the environment.

1. Safety is a combination of staying alert, common sense, and experience with the oil field equipment and environment. Read this Running Procedure prior to operating and installing the equipment. Be familiar with the operation terminologies of oil field equipment.

2. This document includes basic installation guidance. The field service personnel shall be fully trained in all

aspects of handling pressure control equipment as well as of the job that they are going to perform. If any

of the procedures and policies listed in this procedure cannot be followed, contact a Cameron Representative for the best course of action.

3. Proper Personal Protective Equipment (PPE) shall be utilized according to Company policies. Always use proper tools when servicing the equipment.

4. A Job Hazard Analysis (JHA) must be performed prior to beginning any service on a well location. A JHA review meeting will be held with all affected rig personnel PRIOR to the commencement of work to review the results of the JHA, evacuation routes, emergency contacts, etc. All meeting attendees and a Company Representative will sign-off on the JHA to acknowledge this meeting has taken place

5. Be aware of unexpected circumstances that may arise when operating or servicing the equipment. Utilize

the Step Back 5X5 Process in order to assess the hazards posed before, during, and after the servicing of equipment under pressure or with the potential of hazardous chemicals present. Be familiar with the company’s and facility’s Lockout/Tagout program in order to ensure all sources of energy (i.e. electrical, pneumatic, pressure) are isolated and/or de-energized prior to beginning work.

6. All governmental or Company safety requirements shall be met before working on the equipment.

Require-ments of fully tested pressure barriers prior to servicing the equipment shall be observed. Cameron recommends that two mechanical pressure barriers is the preferred practice. Additional precautions

should be taken to ensure that the mechanical pressure barriers are functioning correctly prior to any work being carried out on this particular equipment.

7. Always check for any trapped pressure before servicing the equipment. All valves downstream of the pressure barriers must be cycled several times to release any trapped pressure.

8. Ensure the chemical and physical properties of the fluid flow product inside the equipment are known. Obtain applicable Material Safety Data Sheets (MSDS) for commonly encountered chemicals such as hydrogen sulfide, cements, etc. in order to identify appropriate PPE to use, emergencies, procedures, and methods or exposure control.

9. Always use correct lifting devices and follow safety rules in handling heavy products. The actual weight can vary for the system configurations. Never attempt to lift the equipment by hand.

10. Cameron manufactures a variety of oil field equipment with different features and operating requirements. Be certain of the equipment model and refer to the appropriate procedure, before attempting any operation or service on the equipment. This procedure is to assist field personnel in the operation and installation of the

equipment that is listed in this document. Different procedures are available for other oil field products.

SD-045055-01 Rev 01 - RP General Warning M.Contreras 25/OCT/2010

1.1

Install the Load Ring

1.1.1. Run the 20" Conductor as re-quired.

1.1.2. Cut the 20" Conductor at the required height to allow for proper installation of the Load Ring.

The cut on the 16" conductor should be square and only a slight bevel should be ground on the OD edge, no larger than 1/16" x 45 deg, to allow it to pass the WQ seals.

1.1.3. Examine the Load Ring (A2). Verify the following:

•

bore is clean and free of debris.

•

set screws are properly in-stalled and undamaged. 1.1.4. Orient the Load ring with set

screws down.

1.1.5. Carefully land the load ring onto the 20" conductor until it sets onto conductor.

1.1.6. Tighten the set screws.

Stage 1.0 — 20" Conductor

SAFETY NOTE

:

Always wear proper PPE (Personal Protective Equipment) such as safety shoes,

safety glasses, hard hat, gloves, etc. to handle and install equipment.

RP-002393

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13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

1.2

Install the Riser

Adapter

1.2.1. Examine the Riser Adapter

(Item ST1). Verify the following:

• bore is clean and free of debris

• WQ seals are properly in-stalled and undamaged 1.2.2. Orient the Adapter as illustrated. 1.2.3. Wipe the ID of the WQ seals

with a light coat of oil.

Excessive oil may prevent a positive seal from forming.

1.2.4. Carefully slide the Adapter over the 20" conductor until it lands on the Load Ring.

Stage 1.0 — 20" Conductor

RP111937 Load Ring Riser Adapter 20" Conductor 'WQ' Seals RP112352

1.3

Energize the WQ

Seals

1.3.1. Locate the ports on the Adapter for energizing the upper WQ seal and remove the dust cap from each fitting.

1.3.2. Install a grease pump to one fitting and remove the opposite fitting.

1.3.3. Inject grease into the seal until a continuous stream flows from opposite port.

1.3.4. Reinstall the fitting and con-tinue to inject fluid to 80% of the

casing collapse maximum.

1.3.5. Hold and monitor the injection pressure until it has stabilized. 1.3.6. Once the pressure has stabi-lized, carefully bleed off the pump pressure.

1.3.7. Remove the grease pump and

replace the dust cap.

1.3.8. Repeat this procedure for the lower WQ seal.

Stage 1.0 — 20" Conductor

Install Bleeder Remove Cap and Inject Fluid RP111938

RP-002393

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13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

1.4

Test Between the

Seals

1.4.1. Locate the port for testing be-tween the seals and remove the fitting.

1.4.2. Install a test pump and inject test fluid to 80% of casing

col-lapse maximum.

1.4.3. Hold and monitor the test pres-sure for 15 minutes or as re-quired by the drilling supervi-sor.

1.4.4. Once a satisfactory test is achieved, carefully bleed off the test pressure and remove the test pump.

1.4.5. Reinstall the fitting.

Stage 1.0 — 20" Conductor

RP111939

Remove Fitting and Inject Fluid

Stage 2.0 — 13-3/8" Casing

2.1

Install the Casing Head

2.1.1. Run the 13-3/8" casing and space out as required. Retrieve the landing joint

2.1.2. Examine the Casing Head Running Tool (Item ST2). Verify the following:

• bore is clean and free of debris • all threads are clean and undamaged • o-ring seal is clean and undamaged

2.1.3. Examine the Casing Head (Item A1). Verify the fol-lowing:

• bore is clean and free of debris

• casing hanger seal area is clean and undam-aged

• all threads are clean and undamaged

• all peripheral equipment is intact and undam-aged

• Inspect knurled surface of casing head. 2.1.4. Remove the outlet equipment of the Casing Head

and replace with Flush Plugs.

Casing Head Running Tool

18.50 19.88 12.92 13-3/8 LTC Thread Left Hand Running Threads RP111940 Left Hand Running Threads RP111941 13-3/8" Casing

MB-ND Casing Head

13-3/8" LTC Box bottom

RP-002393

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13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

Stage 2.0 — 13-3/8" Casing

2.1.6. Wipe the o-ring of the Tool and the running threads of both Head and Tool with a light coat of oil.

Excessive oil may prevent a positive seal from forming.

2.1.7. Lower the tool into the casing head until the running threads make contact. Turn the tool first to the right until thread jump is felt. Then make up the connection with left hand rotation to a positive stop.

2.1.8. Carefully lower the Casing Head Assembly until the mating threads of the 13-3/8" casing and the pin threads of the pup joint make contact. Make up to the thread manufacturers recommended optimum torque per rig procedure.

Flush Plug Installed Casing Head Casing Head Running Tool Landing Joint RP111942 13-3/8" Casing

2.1.9. Release the casing from the floor slips, and carefully lower the Casing Head through the diverter and Riser Adapter and land Casing Head on Load Ring. 2.1.10. Rotate outlets as required.

2.1.11. Cement as required.

2.1.12. Rotate the landing joint to the right to remove the Running Tool from the Head.

2.1.13. Retrieve the Tool to the rig floor and remove from the landing joint.

2.1.14. Clean, grease and store the Tool as required. 2.1.15. Install a bleeder tool to the upper then the lower

fittings of the Riser Adapter and vent all trapped pressure.

2.1.16. The Drilling Adapter may now be stripped over the Casing Head.

2.1.17. Once the Drilling Adapter is removed, remove the four fittings for injecting fluid into the WQ seals and replace them with 1/2" pipe plugs.

2.1.18. Clean, grease and store the Adapter as required. 2.1.19. Remove flush plugs and install outlet equipment. 2.1.20. Install the Threaded Flange to the top of the Casing

Head.

Stage 2.0 — 13-3/8" Casing

13-3/8" Casing Casing Head Casing Head Running Tool Landing Joint RP111943 RP111944 Outlet Equipment Installed Install Threaded Flange

RP-002393

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13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

Stage 3.0 — 9-5/8" Casing

3.1

Test the BOP Stack

Previously used BOP Test Plug must be in-spected for damage due to wear. Where warranted such as highly deviated wells the Test Plug must be checked periodically to insure integrity.

Immediately after making up the BOP stack and periodically during the drilling of the hole for the next casing/tubing string, the BOP stack (connections and rams) must be tested.

3.1.1. Examine the Test Plug (Item ST3). Verify the following:

• dovetail seal is in place and undamaged • 1/2" pipe plug is installed, if required • all threads are clean and undamaged 3.1.2. Orient the Tool with elastomer down and lift lugs

up.

3.1.3. Make up a joint of drill pipe to the top of the Tool. 3.1.4. Wipe the dovetail seal of the Tool with a coat of

light oil.

Ensure the elastomer is down and the lift lugs are up.

3.1.5. Open the annulus valve of the Head, and drain fluid to land the Tester. Leave valve open.

3.1.6. Slowly lower the Tool through the BOP until it lands on the load shoulder in the Casing head

3.1.7. Close the BOP rams on the drill pipe and test to 5000 psi

maximum.

3.1.8. Monitor the annulus valve for signs of pressure. 3.1.9. After a satisfactory test is achieved, release pressure,

close the annulus valve and open the rams.

3.1.10. Remove as much fluid from the BOP stack as possible. 3.1.11. Retrieve the Test Plug slowly to avoid damage to the seal.

It may be necessary to open the annulus valve when starting to retrieve the Test Plug to relieve any vacuum that may occur. Leaving annulus valve open during testing insures safety of surface casing. Pin 4-1/2" RP050117 'WQ' Seal Box 4-1/2" 1/2" LP Weephole Pipe Plug

Test Plug Type 'C'

Stage 3.0 — 9-5/8" Casing

Previously used BOP Testers must be in-spected for damage due to wear. Where warranted such as highly deviated wells the Tester must be checked periodi-cally to insure integrity.

Always use a Wear Bushing while drilling to protect the load shoulder from damage by the drill bit or rotating drill pipe. The Wear Bushing must be retrieved prior to running the casing.

3.2

Run the Wear Bushing Before

Drilling

3.2.1. Examine the Running Tool (Item ST4). Verify the following:

• dovetail seal is in place and undamaged • lift lugs are intact and undamaged • all threads are clean and undamaged

3.2.2. Orient the Tool with the lift lugs down and the elas-tomer up.

3.2.3. Make up a joint of drill pipe to the top of the Tool. 3.2.4. Examine the Wear Bushing (Item ST5). Verify the

following:

• bore is clean and free of debris • stop lugs are properly installed • J-slots are clean and free of debris

•

O-ring seals are in place and undamaged. 3.2.5. Wipe OD of Wear Bushing and O-ring seals with a

light coat of oil.

Excessive oil may prevent a positive seal from forming.

Make sure the lift lugs are down and the

elas-tomer is up when latching into the Wear Bushing.

3.2.6. Lower the Tool into the Wear Bushing and rotate the drill pipe 1/4 turn clockwise.

3.2.7. Slowly lower the Test Plug/Wear Bushing Assembly through the BOP until it lands on the load shoulder of the Casing Head.

3.2.8. Run in the lockscrews of the Casing Head. 3.2.9. Disengage the Tool from the Wear Bushing by

rotat-ing the drill pipe counterclockwise 1/4 turn and liftrotat-ing straight up. 3.2.10. Drill as required.

Running Tool

Wear Bushing

4-1/2" IF 4-1/2" IF Lift Pins (4) 28.00 14.93 12.32 RP112354

RP-002393

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13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

Stage 3.0 — 9-5/8" Casing

3.3

Retrieve the Wear

Bushing After

Drilling

3.3.1. Make up the Tool to the drill pipe with the lift lugs down and the elastomer up.

3.3.2. Slowly lower the Tool into the Wear Bushing.

3.3.3. Rotate the Tool clockwise until the drill pipe drops approxi-mately 2". This indicates the lugs have aligned with the Wear Bushing slots.

3.3.4. Rotate clockwise 1/4 turn to fully engage the lugs in the Wear Bushing.

3.3.5. Retract the lockscrews of the Casing Head from the bore. 3.3.6. Slowly retrieve the Wear

Bush-ing and remove it and the Tool from the drill string.

3.3.7. Clean, grease and store the Tool and Wear Bushing.

RP112355 Landing Joint Running Tool Wear Bushing Casing Head Retract Lockscrews BOP Stack

3.4

Hang Off the Casing

In the event the 5-1/2" casing should become stuck, and the mandrel hanger is unable to be used, refer to the emergency 5-1/2" casing in the back of this procedure.

3.4.1. Run the 9-5/8" casing and space out appropriately. 3.4.2. Hang off the last joint of casing to be run in the floor slips at height that will enable easy handling and make up of the hanger and landing joint.

3.4.3. Examine the Running Tool (Item ST6). Verify the following:

• bore is clean and free of debris • all threads are clean and undamaged

• internal seal is properly installed and undam-aged

3.4.4. Orient the Running Tool with the stub acme running threads down.

3.4.5. Examine the Casing Hanger (Item B9). Verify the following:

• bore is clean and free of debris • all threads are clean and undamaged

Stage 3.0 — 9-5/8" Casing

Running Tool

MB-ND Casing Hanger

9-5/8" Casing Thread O-Ring 10" Left Hand Running Thread Slick Neck 10" Left Hand Running Thread 9-5/8" Casing Thread 16.38 17.06 8.91 13.44 RP111948

RP-002393

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13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

Stage 3.0 — 9-5/8" Casing

Ensure the Lockscrews of the BOP are fully retracted from the bore

3.4.6. Make up a joint of casing to the top of the Running Tool.

3.4.7. Wipe the running threads of both the Tool and the Hanger and also the seal of the Tool with a light oil or grease.

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

3.4.8. Lift and suspend the Tool over the Hanger. 3.4.9. Lower the Tool onto the Hanger until the mating

threads make contact.

3.4.10. While balancing the weight, rotate the Tool to the right until the thread 'jump' can be felt then to the left to a positive stop. Approximately 7 turns.

DO NOT Torque the connection.

3.4.11. Back the tool off 1/2 turn to the right to keep the threads from binding up.

3.4.12. Ensure the lockscrews of the Casing Head are fully retracted from the bore.

3.4.13. Lift the Hanger above the casing hung off in the floor. 3.4.14. Lower the hanger assembly until the mating threads of the 9-5/8 casing and the pin threads of the pup joint make contact.

When making up the Hanger to the casing do not use the seal neck area for back up.

3.4.15. While balancing the weight, rotate the assembly to the left until the thread 'jump' can be felt then to the right to the thread manufacturer's recommended optimum torque. Running Tool Landing Joint Casing Hanger 9-5/8" Casing RP111949

3.4.16. Open the side outlet valve on the casing head, release the casing from the floor slips and lower it into the well, tallying the casing as it is low-ered, until the Hanger lands on the load shoulder of the Casing Head. 3.4.17. Cement as required.

Cement returns may be taken through the flutes of the Hanger and out of the BOP.

3.4.18. Release the Tool from the Hanger by rotating the Tool to the right. 3.4.19. Retrieve the Tool to the rig floor. 3.4.20. Clean, grease and store the Tool.

Stage 3.0 — 9-5/8" Casing

RP111950 BOP Stack Landing Joint Running Tool Casing Hanger

RP-002393

Rev 02

Page 22

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

3.5

Installing the Packoff Bushing

3.5.1. Examine the Packoff Bushing Running Tool

(Item ST7). Verify the following:

•

bore is clean and free of debris

•

all threads are clean and undamaged 3.5.2. Examine the Packoff Bushing (Item B10). Verify

the following:

•

bore is clean and free of debris

•

all seals are in place and undamaged 3.5.3. Orient the Packoff as illustrated.

3.5.4. Wipe the runnning threads of the Running Tool and Packoff Bushing with a light coat of oil.

Excessive grease may prevent a positive seal from forming.

3.5.5. Lower the Tool on the Packoff until the running threads make contact. Turn the Tool first to the right until thread jump can be felt. Then make up the connection with left hand rotation to a posi-tive stop.

3.5.6. Wipe the ID and OD seals with a light coat of oil or grease.

Excessive grease may prevent a positive seal from forming.

3.5.7. Carefully lower the Packoff into the bowl of the Casing Head until the Packoff rests on the Casing Mandrel

3.5.8. Verify that packoff is landed and run in lockscrews of the Casing Head.

Stage 3.0 — 9-5/8" Casing

21.32 8.90

MB-ND Packoff Bushing

Dovetail

Seals

T Seals

Dovetail

Seals

RP111951

RP111952

3.6

Test Between the Seals

3.6.1. Locate the test port on the Casing Head and remove fitting.

3.6.2. Install a test pump to the test port and inject test fluid to 5000 psi.

3.6.3. Hold and monitor the test pressure for fifteen minutes or as required by the Drilling Supervisor.

3.6.4. Once a satisfactory test is achieved, carefully bleed off the test pressure, remove the test pump and install the fitting.

3.6.5. Rotate the landing joint to the right to remove the Running Tool from the Packoff.

3.6.6. Retrieve the Tool to the rig floor and remove from landing joint.

3.6.7. Clean, grease and store the Tool as required.

Stage 3.0 — 9-5/8" Casing

RP111953

Remove

Fitting

and Inject

Test Fluid

RP-002393

Rev 02

Page 24

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

Stage 4.0 — 5-1/2" Casing

4.1

Test the BOP Stack

Previously used BOP Test Plug must be in-spected for damage due to wear. Where warranted such as highly deviated wells the Test Plug must be checked periodically to insure integrity.

Immediately after making up the BOP stack and periodically during the drilling of the hole for the next casing/tubing string, the BOP stack (connections and rams) must be tested.

4.1.1. Examine the Combination Tool (Item ST8). Verify the following:

• dovetail seal is in place and undamaged • 1/2" pipe plug is installed, if required • all threads are clean and undamaged 4.1.2. Orient the Tool with elastomer down and lift lugs

up.

4.1.3. Make up a joint of drill pipe to the top of the Tool. 4.1.4. Wipe the dovetail seal of the Tool with a coat of light

oil.

Ensure the elastomer is down and the lift lugs are up.

4.1.5. Open the annulus valve of the Head, and drain fluid to land the Tester. Leave valve open.

4.1.6. Slowly lower the Tool through the BOP until it lands on the load shoulder in the Packoff.

4.1.7. Close the BOP rams on the drill pipe and test to 5000

psi maximum.

4.1.8. Monitor the annulus valve for signs of pressure. 4.1.9. After a satisfactory test is achieved, release pressure,

close the annulus valve and open the rams.

4.1.10. Remove as much fluid from the BOP stack as possible. 4.1.11. Retrieve the Test Plug slowly to avoid damage to the

seal.

It may be necessary to open the annulus valve when starting to retrieve the Test Plug to relieve any vacuum that may occur. Leaving annulus valve open during testing insures safety of surface casing.

WARNING: 4-1/2" IF

Configuration

4-1/2" IF

11" Test Plug

RP921199 Elastomer (1-1/8" Hex) 1-1/4" LP, VR Plug and Lift Lugs are Up

Elastomer is down

1/2" NPT Weep Hole

4 Lift Lugs Socket Pipe Plug

for Wear Bushing Fitted With Allen

Casing Head Test Plug Landing Joint RP111954 BOP Stack

Previously used BOP Testers must be in-spected for damage due to wear. Where warranted such as highly deviated wells the Tester must be checked periodi-cally to insure integrity.

Always use a Wear Bushing while drilling to protect the load shoulder from damage by the drill bit or rotating drill pipe. The Wear Bushing must be retrieved prior to running the casing.

4.2

Run the Wear Bushing Before

Drilling

4.2.1. Examine the Combination Tool (Item ST8). Verify the following:

• dovetail seal is in place and undamaged • lift lugs are intact and undamaged • all threads are clean and undamaged

4.2.2. Orient the Tool with the lift lugs down and the elas-tomer up.

4.2.3. Make up a joint of drill pipe to the top of the Tool. 4.2.4. Examine the Wear Bushing (Item ST9). Verify the

following:

• bore is clean and free of debris • stop lugs are properly installed • J-slots are clean and free of debris

•

O-ring seals are in place and undamaged. 4.2.5. Wipe OD of Wear Bushing and O-ring seals with a

light coat of oil.

Excessive oil may prevent a positive seal from forming.

Make sure the lift lugs are down and the elas-tomer is up when latching into the Wear Bushing.

4.2.6. Lower the Tool into the Wear Bushing and rotate the drill pipe 1/4 turn clockwise.

4.2.7. Slowly lower the Test Plug/Wear Bushing Assembly through the BOP until it lands on the load shoulder of the Casing Head.

4.2.8. Disengage the Tool from the Wear Bushing by rotat-ing the drill pipe counterclockwise 1/4 turn and liftrotat-ing straight up. 4.2.9. Drill as required.

Stage 4.0 — 5-1/2" Casing

11" Running Tool

11" Wear Bushing

4-1/2" IF

Lift Lugs (4)

4-1/2" IF

8.88 13.75

O-Rings

RP111955

RP-002393

Rev 02

Page 26

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

4.3

Retrieve the Wear

Bushing After Drilling

4.3.1. Make up the Tool to the drill pipe with the lift lugs down and the elastomer up.

4.3.2. Slowly lower the Tool into the Wear Bushing.

4.3.3. Rotate the Tool clockwise until the drill pipe drops approxi-mately 2". This indicates the lugs have aligned with the Wear Bushing slots.

4.3.4. Rotate clockwise 1/4 turn to fully engage the lugs in the Wear Bushing.

4.3.5. Retract the lockscrews of the Drilling Adapter from the bore. 4.3.6. Slowly retrieve the Wear Bush-ing and remove it and the Tool from the drill string.

4.3.7. Clean, grease and store the Tool and Wear Bushing.

Stage 4.0 — 5-1/2" Casing

BOP Stack Wear Bushing Test Plug Landing Joint RP111956

4.4

Hang Off the Casing

4.4.1. Run the 5-1/2" casing and space out appropriately. 4.4.2. Hang off the last joint of casing to be run in the floor slips at height that will enable easy handling and make up of the hanger and landing joint.

4.4.3. Examine the Running Tool (Item ST10). Verify the following:

• bore is clean and free of debris • all threads are clean and undamaged

• internal seal is properly installed and undam-aged

4.4.4. Orient the Running Tool with the stub acme running threads down.

4.4.5. Examine the Casing Hanger (Item B11). Verify the following:

• bore is clean and free of debris • all threads are clean and undamaged 4.4.6. Orient the Hanger with the casing thread down.

Stage 4.0 — 5-1/2" Casing

11" Running Tool

11" MB-ND Hanger

5-1/2" Casing

Thread

O-Ring

7-1/2"

Running

Thread

Slick Neck

BPV Prep

5-1/2" Casing

Thread

RP111957

7-1/2"

Running

Thread

RP-002393

Rev 02

Page 28

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

Ensure the Lockscrews of the BOP are fully retracted from the bore

4.4.7. Make up a joint of casing to the top of the Running Tool.

4.4.8. Wipe the running threads of both the Tool and the Hanger and also the seal of the Tool with a light oil or grease.

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

4.4.9. Lift and suspend the Tool over the Hanger. 4.4.10. Lower the Tool onto the Hanger until the mating

threads make contact.

4.4.11. While balancing the weight, rotate the Tool to the right until the thread 'jump' can be felt then to the left to a positive stop. Approximately 7 turns.

DO NOT Torque the connection.

4.4.12. Back the tool off 1/2 turn to the right to keep the threads from binding up.

4.4.13. Ensure the lockscrews of the Drilling Adapter are fully retracted from the bore.

4.4.14. Lift the Hanger above the casing hung off in the floor. 4.4.15. Lower the hanger assembly until the mating threads of the 5-1/2 casing and the pin threads of the pup joint make contact.

When making up the Hanger to the casing do not use the seal neck area for back up.

4.4.16. While balancing the weight, rotate the assembly to the left until the thread 'jump' can be felt then to the right to the thread manufacturer's recommended optimum torque.

Stage 4.0 — 5-1/2" Casing

Running Tool

Landing

Joint

Casing

Hanger

5-1/2" Casing

RP111958

4.4.17. Wipe the OD seal of the Hanger with a light oil or grease.

Excessive oil or grease may prevent a positive seal from form-ing.

4.4.18. Release the casing from the floor slips and lower it into the well, tallying the casing as it is lowered, until the Hanger lands on the load shoulder of the Packoff.

4.4.19. Cement as required.

Cement returns may be taken through the flutes of the Hanger and out of the BOP.

4.4.20. Release the Tool from the Hanger by rotating the Tool to the right.

4.4.21. Retrieve the Tool to the rig floor. 4.4.22. Clean, grease and store the

Tool. BOP Stack Casing Hanger Running Tool Landing Joint RP111959

RP-002393

Rev 02

Page 30

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

4.5

Recommended Procedure Wash Out

for the Seal Assembly

4.5.1. Examine the Wash Tool (Item ST11). Verify the follow-ing:

•

all ports are clean and free of debris

•

all threads are clean and undamaged

4.5.2. Orient the Wash Tool with the 4-1/2" IF connection up. 4.5.3. Make up a joint of drill pipe to the top of the Wash Tool. 4.5.4. Slowly lower the wash tool through the BOP stack until it contacts the top of the casing hanger load shoulder. 4.5.5. Raise the tool 2" above this point to wash the profile. 4.5.6. Open the Valve on the side outlet of the casing head to

take wash returns.

4.5.7. Pump fresh fluid through the wash tool taking returns through side outlet for 3 minutes.

4.5.8. Continue to wash in intervals allowing the water to drain through the side outlets to get the full impact of the jetting tool.

4.5.9. Retrieve the tool, clean, grease and store as required. 4.5.10. Close Valve.

Stage 4.0 — 5-1/2" Casing

Wash Tool

23.00 8.09

Wash

Ports

4-1/2" IF

RP111960

BOP Stack Casing Hanger Wash Tool Landing Joint RP111961

4.6

Install the Seal Assembly

4.6.1. Examine the Seal Assembly Running Tool (Item

ST12). Verify the following:

• bore is clean and free of debris

• threads are clean and undamaged

4.6.2. Orient the Running Tool with the internal running threads down.

4.6.3. Examine the Packoff Seal Assembly (Item B12). Verify the following:

• bore is clean and free of debris

• threads are clean and undamaged

• all internal and external seals are properly in-stalled and undamaged

4.6.4. Orient the Seal Assembly with the external running threads up.

4.6.5. Lubricate all of the threads of the Seal Assembly and Running Tool with a light oil or grease.

Stage 4.0 — 5-1/2" Casing

Seal Assembly Running Tool

Seal Assembly

20.00 8.00 10.91 7.75 4-1/2" IF Left Hand Running Thread Left Hand Running Thread Lockring Compression Spring Latch Pin O-Rings RP111962

RP-002393

Rev 02

Page 32

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

4.6.6. Make up a joint of drill pipe to the top of the Running Tool. 4.6.7. Carefully lower the Running Tool onto the Seal

Assem-bly until the threads make contact.

4.6.8. Make up the connection by first turning the Tool to the right until the thread 'jump' can be felt then to the left until the Tool engages the lockring.

4.6.9. Once the lockring is engaged remove the Installation Tool.

Ensure the lockring is flush or below of the OD of the Seal Assembly.

4.6.10. Lift and suspend the Assembly over the Casing Hanger. 4.6.11. Lightly lubricate all ID and OD seals with a light oil or

grease.

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

4.6.12. Open the uppermost 2-1/16" 5M side outlet valve on the Casing Head.

The side outlet valve is to remain open during the setting of the Seal Assembly.

4.6.13. Lower the Seal Assembly through the BOP stack and set it over the Casing Hanger.

Stage 4.0 — 5-1/2" Casing

4.6.14. Using chain tongs, slowly rotate the run-ning tool to the right 3 turns to release the lockring into its mating groove in the Com-pact Spool.

4.6.15. Pick up and over pull 5,000 lbs to confirm the lockring has properly engaged.

Landing Joint Running Tool Lockring Compressed Seal Assembly RP111963 Landing Joint Seal Assembly Lockring Engaged RP111964 BOP Stack Casing Hanger Running Tool

4.7

Testing the Seal

Assembly

4.7.1. Locate the upper test port on the Compact Spool.

4.7.2. Remove the fitting from the port. 4.7.3. Attach a hydraulic test pump to the open test port and inject fluid into the seal assembly to the 5,000 psi maximum.

Do Not over pressurize! 4.7.4. Hold and monitor the test

pres-sure for 15 minutes or as re-quired by the Drilling Supervi-sor.

4.7.5. After a satisfactory test is achieved, remove the test pump, reinstall fitting in the open port.

4.7.6. Retrieve the running tool by ro-tating the drill pipe (with chain tongs) to the right approximately 4 turns or until it comes free from the seal assembly. A straight lift will retrieve the run-ning tool.

4.7.7. Remove the running tool from the drill string. Clean, grease, and store the tool.

Stage 4.0 — 5-1/2" Casing

Remove Fitting and Inject Test Fluid RP111965

RP-002393

Rev 02

Page 34

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

Stage 5.0 — 2-3/8" Tubing

5.1

Install the Tubing

Spool

5.1.1. Examine the Tubing Spool (Item

B1). Verify the following:

• bore is clean and free of de-bris

• 'NX' Bushing (Item B2) is stalled, P seal is properly in-stalled and undamaged • ring grooves and seal areas

are clean and undamaged • peripheral equipment is

in-tact and undamaged 5.1.2. Run in lockscrews until flush with

the bore, verify this using a straight edge. Measure the radial distance from the flange OD to the outside of each lockscrew. Save these measurements and mark each identified lockscrews. 5.1.3. Lubricate the ID of the P seals and

the OD of the casing stub with light oil or grease.

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

5.1.4. Install a new Ring Gasket

BX-160 into the ring groove of the

Adapter Flange.

5.1.5. Lift and suspend the Tubing Spool over the casing stub, ensuring it is level.

5.1.6. Carefully lower the Tubing Spool over the casing stub until it lands on the ring gasket.

Do Not damage the 'P' seal or its sealing ability will be impaired.

5.1.7. Tighten the connection using the studs and nuts of the Adapter Flange in alternating cross fash-ion to the torque referenced in the chart in the back of this manual.

'C' Type Tubing Spool

13-5/8" 5M x 7-1/16" 10M

'NX Bushing w/ P Seal 27.31 6.37 RP111966 RP111967

Stage 5.0 — 2-3/8" Casing

5.2

Energize the P Seal

5.2.1. Locate the port on the bottom flange of the Tubing Spool for injecting plastic packing into the P seal and remove the pipe plug.

5.2.2. Install a plastic injection gun into the port and inject plastic. 5.2.3. Continue to inject plastic to

10,000 psi.

5.2.4. Hold and monitor injection pres-sure until it has stabilized. 5.2.5. Once the injection pressure has

stabilized, carefully bleed off in-jection pressure and remove injection gun.

5.2.6. Replace the pipe plug into the open port.

For proper injection gun preparation, refer to the page in the back of this manual labeled "Injection Gun Prepa-ration".

5.3

Test the Connection

5.3.1. Install a test pump to the port for testing the connection and in-ject test fluid to either 5,000 psi

or 80% of casing collapse-whichever is less.

5.3.2. Hold and monitor test pressure for fifteen minutes or as re-quired by Drilling Supervisor. 5.3.3. Once a satisfactory test is

achieved, carefully bleed off test pressure and remove the test pump.

5.3.4. Reinstall the fitting.

Remove Pipe Plug and Inject Packing RP111968 Remove Fitting and Inject Test Fluid RP111969

RP-002393

Rev 02

Page 36

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

Stage 5.0 — 2-3/8" Tubing

5.4

Install the Tubing Hanger

5.4.1. Run the tubing as required and space out appropri-ately.

5.4.2. Examine the Tubing Hanger (Item C14). Verify the following:

• bore is clean and free of debris

• threads are clean and undamaged

• packing element is properly installed and un-damaged

• compression ring is properly installed, moves freely and is properly retained

5.4.3. Orient the Hanger as illustrated.

5.4.4. At a predetermined position in the tubing string, set the tubing in floor slips and remove the tubing collar from the last joint run.

5.4.5. Pick up the Tubing Hanger and make it up to the tubing string, tightening the connection to thread manufacturer's recommended optimum torque. 5.4.6. Make up a landing joint to the top of the Hanger and

tighten to the thread manufacturer's recommended shoulder torque.

5.4.7. Wipe the packing element with a light coat of oil.

Excessive oil may prevent a positive seal from forming.

TC-1A-EN

Tubing Hanger

O-Rings No Pipe Wrench on Extended Hanger Neck Landing Joint Tubing Hanger Tubing

Stage 5.0 — 2-3/8" Tubing

5.4.8. Ensure all of the lockscrews are fully retracted from bore of the Tubing Spool

5.4.9. Open side outlet valve and drain BOP.

Side outlet valve to remain open while landing the Hanger.

5.4.10. Calculate the distance of the load shoulder of the Tubing Spool to the rig floor by measuring from the face of the Spool to the rig floor and add the distance from the flange face to the top of the load shoulder.

The distance from the flange face to the top of the load shoulder is as follows: 7" Spool = 7.12"

5.4.11. Pick up the tubing string, remove the floor slips. Carefully lower the Tubing Hanger into the well, tally-ing the tubtally-ing every three feet and land the Tubing Hanger on the load shoulder in the Spool. Slack off all weight.

5.4.12. With the Hanger properly landed, run in all lock screws in an alter-nating cross pattern to torque ref-erenced in the chart in the back of this manual. Verify full engage-ment by measuring from the flange OD to the end of the lockscrews with the measure-ment of ___" less than the mea-surement marked for the flush lockscrews.

5.4.13. Retrieve landing joint and install the appropriate size one way back pressure valve.

Installation and/or Removal of the Type ‘H’ Left Hand threaded Back Pressure Valve to be performed by a Qualified Cameron Technician.

5.4.14. With the well safe and under con-trol, the BOP stack may be

re-Landing Joint Tubing Hanger Run In All Lockscrews RP111970 Tubing Hanger RP111971 BPV INstalled

RP-002393

Rev 02

Page 38

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

Stage 5.0 — 2-3/8" Tubing

5.5

Install the Christmas Tree

5.5.1. Examine the Christmas Tree Assembly. Verify the following:

• bore is clean and free of debris

• threads are clean and undamaged

5.5.2. Orient the Tree as illustrated.

5.5.3. Place a new BX-156 Ring Gasket into the

gasket prep of the tubing spool.

5.5.4. Lift and suspend Tree Assembly over Tubing Spool.

5.5.5. Orient the Tree Assembly as required per Drill-ing Supervisor and carefully lower the Tree Assembly until the Adapter lands on the ring gasket of the Tubing Spool.

5.5.6. Make up the connection with the Studs and

Nuts, tightening them in an alternating cross

patter to the torque referenced in the chart in the back of this manual.

RP111972

Torque Chart

• The information in this table is based on API-6A’s recommended torques for a given bolt size. The information is presented for the convenience of the user and is based on assumptions of certain coefficients of friction (cf). The coefficients of friction are based on approximations of the friction between the studs and nuts, as well as the nuts and flange face. A coefficient friction of 0.13 assumes the threads and nut bearing surfaces are bare metal and are well lubricated with thread compound. A coefficient of friction of 0.07 assumes the thread and nuts are coated with a fluoropolymer material.

• Lubrication

It is essential that threads and nut faces be well lubricated with an appropriate grease prior to assembly. Cameron clamps and fast clamps require lubrication on the hub-clamp contact area. Acceptable lubricants include thread joint compounds which meet the formulation, evaluation and testing requirements specified in API Recommended Practice 5A3/ISO13678.

Studs and nuts coated with Xylan/PTFE compound in accordance with Cameron proceudre do not require lubrication. However, a light coat of API Recommended Practice 5A3/ISO13678 thread compound is recommended for Xyland-coated bolting as an

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RP-002393

Rev 02

Page 40

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

'N' Style Lockscrew Charts

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Operational Sequence

1. Ensure the well is safe and under control and the area of the lockscrew is free of pressure.

2. Loosen the Gland Nut only minimum amount.

CAUTION Well bore pressure may exist inboard of lock

screw packing. Therefore, it is imperative to only relieve the gland the minimum amount required to permit rotation of the lock srew for prevention pressure release escape of well bore.

3. Retighten the Gland Nut to approximately 50 ft/lbs 4. Run in and tighten all lockscrews in an alternating cross manner to the required torque listed in the

Lockscrew torque charts.

5. Retighten the packing gland to the required torque listed in the Recommended Gland Nut Torque for 'N'

Style Lockscrew chart.

w e r c s k c o L e l y t S N r o f s e u l a V e u q r o T s r e g n a H r e m o t s a l E e g n a l F e z i S e r u s s e r P g n i t a R ) i s p ( d e d n e m m o c e R e u l a V e u q r o T ) . M . N ( s b L -t F m u m i x a M e u l a V e u q r o T ) . M . N ( s b L -t F " 6 1 / 1 -4 0 0 0 , 0 1 ) 0 0 2 ( 0 5 1 300(400) 0 0 0 , 5 1 " 6 1 / 1 -7 0 0 0 2 ) 0 0 2 ( 0 5 1 ) 0 4 3 ( 0 5 2 0 0 0 3 0 0 0 5 0 0 0 , 0 1 ) 0 1 6 ( 0 5 4 0 0 0 , 5 1 0 0 0 , 0 2 550(750) " 9 0 0 0 2 ) 0 7 2 ( 0 0 2 300(400) 0 0 0 3 0 0 0 5 175(240) ) 0 1 6 ( 0 5 4 0 0 0 , 0 1 ) 0 0 2 ( 0 5 1 0 0 0 , 5 1 550(750) 0 0 0 , 0 2 1350(1830) " 1 1 0 0 0 2 ) 0 7 2 ( 0 0 2 300(400) 0 0 0 3 0 0 0 5 175(240) ) 0 1 6 ( 0 5 4 0 0 0 , 0 1 ) 0 0 2 ( 0 5 1 0 0 0 , 5 1 0 0 0 , 0 2 1350(1830)

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" 1 1 " 2 / 1 -4 78,000 " 5 74,000 " 2 / 1 -5 70,000 " 8 / 5 -6 59,000 " 7 55,000 " 8 / 5 -7 48,000 " 8 / 5 -3 1 " 2 / 1 -5 120,000 " 7 106,000 " 8 / 5 -7 99,000 " 8 / 5 -8 86,000 " 8 / 5 -9 72,000 " 4 / 3 -0 1 54,000

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" 4 / 3 -6 1 " 8 / 5 -9 146,000 " 4 / 3 -0 1 128,000 " 4 / 3 -1 1 110,000 " 8 / 7 -1 1 109,000 " 8 / 3 -3 1 79,000 " 4 / 1 -1 2 / " 4 / 3 -0 2 " 4 / 3 -0 1 228,000 " 8 / 3 -3 1 180,000 " 8 / 5 -3 1 175,000 " 6 1 120,000

RP-002393

Rev 02

Page 42

13-5/8" 5M Compact Wellhead System

20" X 13-3/8" X 9-5/8" X 5-1/2" X 2-3/8" 5M

1. Maintaining the Injection Gun at ambient temperatures, prepare Test Pump and Injection Gun for injecting P seals. 2. Operate Test Pump to inject fluid into Injection gun.

3. Monitor open end of Injection Gun for signs of plastic packing.

4. After plastic packing begins to flow from open end of Injection Gun continue to inject fluid from Test Pump increasing pressure an additional 200 to 400 psi.

5. Stop pumping Test Pump and monitor plastic packing movement and pressure on the pressure gauge.

6. Once packing has stopped flowing and the pressure gauge has stabilized observe the reading on gauge and record the pressure.

NOTE: The pressure recorded will become "0". This is the pressure required to move the plastic packing and is not included

in the actual injection pressure.

EXAMPLE: If the plastic packing begins to flow at 900 psi and the fluid pressure from the Test Pump is increased to 1200

psi, after allowing the pressure to fall the plastic packing and needle on the pressure gauge cease to move at 850 psi, then 850 psi becomes "0". If the flange rating is 5000 psi and 80% of casing collapse exceeds 5000 psi then the final gauge reading when the P seal is fully energized will be 5850 psi.

NOTE: The amount of pressure required to force plastic packing to flow from the Injection Gun is dependent on several

factors including outside temperature and the plastic injection gun itself. The example given above is for illustration purposes only. Gauge Setup Falls Pressure Rises Pressure

Plastic Packing Stops Flowing from Injection Gun

Flows from Injection Gun Plastic Packing Injection Gun Operate Test Pumping Stop Pump Test Pump Test Hose RP020799 To Wellhead