11''-10K Annular Latched Type OPM Final - APPROVED

11”- 10K WGK Annular

Blowout Preventer

Latched Type

Operation & Maintenance

www.womusa.com

11''- 10K WGK Annular-Latched Type


3

Preface

The information in this operator’s manual describes the 11-5K WGK Annular BOP Latched Type

manufactured by Worldwide Oilfield Machine, Inc. in Houston, Texas.

If any questions arise concerning this manual, contact WOM’s BOP factory at:

Worldwide Oilfield Machine, Inc.

5800 Cunningham Road, Houston, Texas 77041

Phone: 1+ (713) 937-0795

Fax: 1+ (713) 937-8574

Date of Publication:

March 4, 2019

Manual Identification Number: ABOP-OPM-1110-V2

© 2013 Worldwide Oilfield Machine, Inc. All rights reserved. No part of the material protected by this

copyright may be reproduced or utilized in any form or by any means, electronic or mechanical, including

photocopying, recording, broadcasting or by any information storage and retrieval system, without

permission in writing from Worldwide Oilfield Machine, Inc.

4



Table of Contents

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26

Table of Contents

Certifications

Major Features & Components

Components

Hydraulic Control System

Parts Description

Physical Data

Dimensions

Engineering Data

Parts

Part Numbers

Bolting Torque Sequence

Packing Unit

Packing Unit Selection

Packing Unit Replacement

Packing Unit Testing

Care and Maintenance

Disassembly & Assembly

Disassembly

Lid Removal

Remove Lid Clamp

Packing Unit Removal

Piston Removal

Slotted Body Cage Removal

Jaw and Jaw Operating Screw Assembly Removal

Assembly

Clean and Inspect all Parts Before Assembly

Slotted Body Cage Installation

Piston Installation

Packing Unit Installation

Jaw and Jaw Operating Screw Assembly Installation

Install O-Ring

Lid Installation

Operational Characteristics: PR1

Sealing Characteristics

Fatigue Life

Stripping

Packing Element (Packer) Access

Temperature Verification

Appendices

Figure

Table



5

Certifications

WOM is licensed under the latest edition of API 6A and

API 16A and has fully implemented API Q1 quality system.

The API 16A license applies to drill-through equipment.

WOM is certified to ISO 9001.

Products are designed to NACE MR- 01-75 materials

standards for resistance to sulfide stress cracking.

6



Major Features & Components

Lid

Wear Plate

Packing Unit

Piston

Cage

Opening Chamber

Closing Chamber

Body

Figure 1: View of Major Components

Only Two Moving Parts (piston and packing unit) on the Annular BOP mean few areas are subject to

wear. The BOP is safer and more efficient, requiring less maintenance and less downtime.

Long Piston with a length to diameter ratio approaching one eliminates tendencies to cock and bind

during operations with off-center pipe or unevenly distributed accumulations of sand, cuttings, or other

elements. This design enhances the ability of the packing unit to reopen to full bore position.

Conical Bowl Design of the Piston provides a simple and efficient method of closing the packing unit.

With the piston serving as a sealing surface against the rubber packing unit, there is no metal-to-metal

wear on the sealing surface and thus longer life results.

Field Replaceable Wear Plate in the BOP Lid serves as an upper non-sealing wear surface for the

movement of the packing unit, making field repair fast and economical.

Maximum Packing Unit Life is possible with the provision for measuring piston stroke. This measurement

indicates remaining packing unit life without disassembly and ensures the longest and safest use of the

packing unit.

Three Choices of Packing Unit Rubber Compounds permit more flexible applications.



7

Major Features

Large Pressure Energized Seals are used for dynamically sealing piston chambers to provide safe

operation, long seal life, and less maintenance.

Piston Sealing Surfaces Protected by Operating Fluid lowers friction and protects against galling

and wear to increase seal life and reduce maintenance.

Operating Chambers are Tested to Full BOP Working Pressure to ensure strength, reliability, and

the ability to over-pressurize the chambers in emergencies.

NACE MR-01-75 Materials Standards for resistance to sulfide stress cracking are standard. The surface

hookup of the WGK connects the hydraulic control lines to the opening and closing chambers of the BOP.

Pressure applied to the closing chamber raises the piston and affects the initial seal between the packing

unit and drill pipe. Well pressure or test pressure also acts on the piston below the sealed off packing unit

and further increases the closing force acting on the packing unit. As the well pressure or test pressure

exceeds the required level the preventer is maintained closed by well pressure alone. As well pressure

increases, the closing force on the packing unit also increases. Closing pressure should be proportionally

reduced as well pressure is increased in order to maintain optimum closing force on the packing unit and

prolong packing unit life.

During normal drilling operations, it is recommended that the pressure regulator valve for the WGK be

set at the initial closing pressure for the size pipe being used. This pressure will ensure that initial seal off is

achieved should a “kick” be encountered.

During BOP testing operations, once initial seal off is achieved, closing pressure should be proportionally

reduced as well pressure is increased.

8



Components

Major Components

Lid

Wear Plate

Packing Unit

Opening Chamber

Piston

Cage

Closing Chamber

Body




9

Hydraulic Control System

Figure 3: Annular Hydraulic Control System

WOM’s Type WGK BOP was designed especially

for surface installations and is also used on offshore

platforms.

The WGK is a universal annular blowout preventer

with a long record of proven, quality performance.

Standard operation requires both opening and

closing pressure.

Seal-off is affected by hydraulic pressure applied to

the closing chamber which raises the piston, forcing

the packing unit into a sealing engagement.

Any normal closing unit having a separate pressure regulator valve for the annular BOP and sufficient

accumulator volume can be used to operate the WGK.

The WGK is designed to be well pressure assisted in maintaining packing unit seal off once initial seal off

has been effected. As well pressure further increases, closure is maintained by well pressure alone.

Large Pressure Energized Seals are used for dynamically sealing piston chambers to provide safe

operation, long seal life, and less maintenance.

Piston Sealing Surfaces Protected by Operating Fluid lowers friction and protects against galling

and wear to increase seal life and reduce maintenance.

Operating Chambers are Tested to Full BOP Working Pressure to ensure strength, reliability, and

the ability to over-pressurize the chambers in emergencies.

Average Closing Pressure (psi)

Pipe OD 11" - 10,000

6-5/8" -

5'' -

4-1/2'' 420

3-1/2'' 700

2-7/8'' 780

2-3/8'' 870

CSO 1150

Table 1: Average Closing Pressure

10



Parts Description

22

18

17

12 11

14 13

16 15

7

9

25

19

26

8

30

Figure 4: Exploded View of Annular

Table 2: 11-10K Annular Latched Part Description

29

28

23

6

4

5

20

10

3

21

2

24

1

27

Item Description

1 Body

2 Cage

3 Piston

4 Lid

5 Wear Plate

6 Clamp

7 Jaw

8 Jaw Operating Screw

9 Spacer Sleeve

10 Packing Element

11 Double U-Seal: Open

12 Non-Extrusion Ring

13 Double U-Seal: Lower


15 Double U-Seal


17 Head Gasket

18 O-Ring, Head

19 O-Ring, Jaw Operating Screw

20 Hex Head Cap Screw

21 Cap Screw

22 Pressure Plug

23 Ferry Head Cap Screw

24 Relief Fitting

25 Hex Head Cap Bolt

26 Pressure Plug, Socket Head

27 Pressure Plug, Hex Head

28 Stud

29 Nut

30 Shackle



11

Physical Data

Dimensions

Figure 5: 11" Annular Dimensions

A B C D E F G H J K L M N

10K 15K 10K 10K 10K 10K 10K 10K 10K 10K 10K 10K 15K

62.69'' 65.51'' 25.46'' 10.88'' 23.60'' 11.41'' 63.50'' 58.06'' 49.12'' 51.50'' 4.00'' 36.59'' 37.54''

Table 3: Dimensions Data

12



Engineering Data

Measurements

Bore

Working Pressure

Shell Test Pressure (Factory Test Only)

Closing Chamber Test Pressure (Factory Test Only)

Opening Chamber Test Pressure (Factory Test Only)

Volume Closing Chamber

Volume Opening Chamber

Piston Stroke

Port Size

Weight - (Approximate, varies with end connections)

11 inches

10,000 psi

15,000 psi

2,250 psi

2,250 psi

25.1 gallons

18.9 gallons

8 inches

1 NPT

24,100 pounds

Table 4: Engineering Data for 11-10K Annular Latched Type

Figure 6: 11" Annular Cut Out View



13

Parts

29

28

18

22

23

17

6

4

12

11

5

20

10

14 13

3

21

16 15

26

19

25

9

7

2

1

24

8

27

30


Seal Kit Part Number: W-1004051

14



Part Numbers

Item Qty. Part No. Description

1 1 W-1004041 Body

2 1 W-1002170 Cage

3 1 W-1004045 Piston

4 1 W-1004043-04 Lid

5 1 W-1004868 Wear Plate

6 4 W-1002351 Clamp

7 20 W-1004050 Jaw

8 20 W-1004049 Jaw Operating Screw

9 20 W-1002454 Spacer Sleeve

10 1 W-3104633-02 Packing Element

11 1 W-40691 Double U-Seal: Upper

12 2 W-1002712-02 Non-Extrusion Ring: Upper

13 1 W-40693 Double U-Seal: Middle

14 2 W-1002712-03 Non-Extrusion Ring: Middle

15 1 W-40695 Double U-Seal: Lower

16 2 W-1002712-01 Non-Extrusion Ring: Lower

17 1 W-1004925 Head Gasket

18 1 W-51191 O-Ring: Head

19 20 W-1900001-329 O-Ring: Jaw Operating Screw

20 6 981-050-002 Hex Head Cap Screw

21 12 981-147-300 Cap Screw FH

22 1 981-120-005 Pressure Plug, Socket Head

23 1 981-163-300 Cap Screw FH

24 1 W-1900085-03 Relief Fitting

25 20 981-091-300 Hex Head Cap Bolt

26 20 981-120-003 Pressure Plug, Socket Head

27 2 981-112-300 Pressure Plug, Hex Head

28* 16 985-087-300-BSL2 Stud

29* 16 983-011-300-BSL2 Nut

30 4 1018598 Shackle

Table 5: Part Numbers for 11"10K Annular

*Parts are available in BSL3 for offshore application



15

Bolting Torque Sequence

Torque bolts and nuts in a CRISS-CROSS sequence using a minimum of three torque passes and the

maximum bolt stress as defined. Torque incremental is done in four pass.

• PASS 1: Torque to a maximum of 20% of the final torque value in accordance with the torque seque.

Check that gasket is getting compressed uniformly.

• PASS 2: Torque to a maximum of 50% of the final torque value.

• PASS 3: Torque to a maximum of 75% of the final torque value.

• PASS 4: Torque to the final torque value (100%).

After the three basic torque passes are completed, repeat torqueing the nuts or bolts at least once using the

final torque in a CRISS-CROSS manner until no further rotation of the nut is observed. Below are different

illustration.

Hole

Pattern

Torque Sequence (Bolt/Nut Number)

4 1, 3, 2, 4

8 1, 5, 3, 7, 2, 6, 4, 8

12 1, 7, 4, 10, 2, 8, 5, 11, 3, 9, 6, 12

16 1, 9, 5, 13, 3, 11, 7, 15, 2, 10, 6, 14, 4, 12, 8, 16

20 1, 11, 6, 16, 3, 13, 8, 18, 5, 15, 10, 20, 2, 12, 17, 4, 14, 9, 19

24 1, 13, 7, 19, 4, 16, 10, 22, 2, 14, 8, 20, 5, 17, 11, 23, 6, 18, 12, 24, 3, 15, 9, 21

28 1, 15, 8, 22, 4, 18, 11, 25, 6, 20, 13, 27, 2, 16, 9, 23, 5, 19, 12, 26, 3, 17, 10, 24, 7, 21, 14, 28

32 1, 17, 9, 25, 5, 21, 13, 29, 3, 19, 11, 27, 7, 23, 15, 31, 2, 18, 10, 26, 6, 22, 14, 30, 8, 24, 16, 32,

4, 20, 12, 28

Table 6: Torque Sequence Number

4-Bolts

8-Bolts

12-Bolts

16-Bolts

For easy handling, bolt numbering shall

be done clockwise around the flange

with the following sequence.

20-Bolts

24-Bolts

16



Packing Unit

The heart of the WGK blowout preventer is the packing unit. The unit is manufactured from high quality

rubber, reinforced with flanged steel segments. Each unit has a large volume of tough, feedable rubber to

meet any requirement.

The molded in steel segments have flanges at the top and bottom. These segments anchor the packing unit

within the blowout preventer and control rubber extrusion and flow when sealing off well pressures. Since

the rubber is confined and kept under compression, it is resistant to tears, cuts, and abrasion.

Figure 8: Packing Unit



17

Packing Unit Selection

All annular blowout preventer packing units are subjected to wear during closure and stripping. The design

of the WGK blowout preventer causes closure wear to occur on the outside of the packing unit while

stripping wear occurs on the inside. Thus, the stripping life of the packing unit is little affected by wear

from routine closures.

Natural Rubber is compounded for drilling with water-base drilling fluids. Natural rubber can be used

at operating temperatures between 20º F to 250º F.

Nitrile Rubber (a synthetic compound) is for use with oil-base or oil-additive drilling fluids. It provides

the best service with oil-base muds, when operated at temperatures between 20º F to 190º F.

Neoprene Rubber is for low-temperature operating service and oil-base drilling fluids. It can be used at

operating temperatures between 20º F to +170º F. Neoprene rubber provides better service with oil-base

drilling fluids than Natural rubber. It has better cold temperature elasticity than Nitrile rubber; but it is

detrimentally affected by extended high temperature applications.

Seals are manufactured from a special Nitrile rubber material which provides long, trouble free service in

sealing against oil, gas, or water.

Expected H2S Service does not affect selection of packing unit material. H2S Service will reduce the

service life of rubber products, but the best overall service life is obtained by matching the packing unit

material with the requirements of the specific drilling fluid. Performance of elastomeric materials can vary

significantly, depending on the nature and extent of exposure to hydrogen sulfide. The operator should

monitor pressure sealing integrity frequently to assure no performance degradation has occurred.

Storage conditions such as light, heat, or adverse conditions, are significant factors in the storage life of

packing units. Non-metallic sealing components qualified for temperature rating class ‘BD’ and class ‘BF’.

18



Packing Unit Replacement

To replace the packing unit, use the

following procedure:

1. Remove Lid Clamps (#20) and Hex

Head Screws (#21).

2. Retract the jaw operating screws (#8)

four turns to release the jaws from the

lid.

3. Remove the preventer lid (#4).

4. Lift out the packing unit (#6) and

lubricate the piston bowl (#3).

5. Install the new packing unit (#6).

6. Intall the lid (#4).

7. Tighten jaw operating screws four

turns and torque to 300-400 lb-ft. (#8).

8. Reinstall Lid Clamps (#20) and Hex

Head Screws (#21)

Note: If the lid was improperly installed

at last reassembly, it may be necessary

to apply considerably more torque on

the lid by the use of a catline or wrench

while alternately applying and releasing

pressure to the opening chamber (1,500

psi maximum). DO NOT attempt to

loosen the lid by applying heat.

18

17

12 11

14 13

22

29

28

23

4

5

20

10

3

6

Packing unit replacement is also

possible with pipe in the hole. After

removing worn packing unit, cut new

packing unit completely and smoothly

through one side between any two steel

segments preferably 90º from eyebolt

holes to achieve easier handling. Cut

should bemade with a sharp knife as

this will not affect the efficiency of the

packing unit. Spring segment apart with

a pry bar to put rubber in tension for

easier cutting.

DO NOT use a saw or other rough

cutting tool. Spring packing unit open

sufficiently to pass around pipe, drop

unit into position in blowout preventer

body, and replace lid.

16 15

26

19

25

8

7

9

30

21

2

24

1

27

Figure 9: 11" 10K Annular Exploded View



19

Packing Unit Testing

Proper Procedure for pressure testing any

annular blowout preventer ensures subsequent

seal off and maximum packing unit life. Reliable

pressure seal off tests are made by closing the

packing unit with prescribed closing chamber

pressure on recommended size test pipe, and by

determining the remaining piston travel after

seal off is achieved. Optimum packing unit life

is obtained by testing at low rubber stress levels.

Minimum packing unit stress is achieved by

use of the minimum closing chamber pressure

that will initiate and maintain a seal off on the

recommended size test pipe.

The WGK Blowout Preventer is designed

to be well pressure assisted in maintaining

packing unit seal off once initial seal off has been

effected. Initial seal off is effected by applying

pressure to the closing chamber. As well pressure

is increased, the closing force on the packing

unit also increases.

Piston Stroke can be measured on WGK blowout

preventers through a vertical passage in the top of the

BOP lid. Piston stroke remaining at seal off is a direct

indicator of remaining packing unit life. Record the

piston stroke and the closing pressure at initial seal

off for each test. Compare with previous results and

with maximum piston stroke for the BOP to ensure

subsequent seal offs. A valid test on any annular BOP

is only achieved when the remaining piston stroke is

measured at test seal off.

4

3

2

1

As well pressure exceeds the required level, the

packing unit is maintained closed on pipe by

well pressure alone. During routine BOP testing,

once initial seal off is achieved, closing pressure

should be proportionally reduced as well pressure

is increased.

Initial Closing pressure required to affect

initial seal off may vary between packing units.

Begin the test with the recommended initial

closing pressure (see Average Closing Pressure

Table-page 9).y6

Figure 10: Packing Unit Testing

20



Care & Maintenance

Prior to placing the WGK Blowout Preventer into service, the following visual inspections

should be performed:

1. Inspect upper and lower connections for pitting, wear, and damage especially in ring grooves and stud

bolt holes. Worn or damaged ring grooves must be welded, machined, and stress relieved. Worn or damaged

stud bolt holes can be drilled and tapped to the next larger size and fitted with step-studs.

2. Check the body for wear and damage, especially in the internal cylinder walls for pits and vertical scores.

Minor pits and scores can be removed in the field with emery cloth. Repaired surface should be coated with

silicon grease or castor oil. Severe pits and scores may require machining and/or welding which should be

performed in a WOM approved machine shop. Cracks must be corrected.

3. Inspect the vertical bore for wear and damage from drill string and drill tools, especially in the area of the

ring grooves. If wear is excessive, the area must be repaired.

4. Check for piston damage and wear, especially the inner and outer walls for pits and vertical scores and

the tapered bowl for pits and gouges. Minor pits and scores on the walls can be removed in the field with

emery cloth. Repaired surface should be coated with silicon grease or castor oil. Severe pits and scores may

require machining and/or welding which should be performed by a WOM approved machine shop. Pits

and gouges in the tapered bowl should be filled with a permanent type adhesive, such as epoxy. Sharp or

rolled edges should be removed with emery cloth or a grinder. Repair will be satisfactory when a relatively

smooth surface is achieved.

5. Check the wear plate in the inner bottom face of the lid for any abrasion. In addition to the aging process

of time and use, wear of this metal surface is produced by the combination of vertical (upward thrust) and

lateral forces. These forces are generated each time the packing unit is closed. Severe wear is exhibited in the

form of grooves or channels shaped by the steel segments of the packing unit. The inner bottom face of the

lid serves as a wall to prevent upward movement of the packing unit. Friction between these metal surfaces

is controlled at a level which does not impair lateral movement of the packing unit. Repair of this surface is

accomplished by replacing the wear plate.

6. Inspect the packing unit for wear, cracking, hardness, and correct elastomer composition.

7. Check seal ring for nicks, cuts, fraying of lips, and abrasion. Worn or damaged seal rings should be

replaced.



21

Disassembly and Assembly

Disassembly

LID REMOVAL (#4)

Close and open the packing unit to break loose any accumulation of drilling fluid or debris which may

restricting full downward travel of the piston.

Vent Opening and closing chambers to atmosphere ensuring that no trapped pressure exists which will

cause personnel and / or equipment damage. Open valves in control system to have an exhaust and/or

loosen hydraulic connections to allow leakage.

REMOVE LID CLAMP (#6) Release jaws (#7) by rotating jaw operating screws (#8) four turns

counterclockwise until jaw shoulders against body. Excessive torque at shouldering should be avoided to

prevent thread damgage.

Install two (1 1/8” -8UN) eyebolts in top of lid. Lift lid slowly and assure a good vertical alignment.

PACKING UNIT REMOVAL (#10)

Install two (5/8” -11NC) eyebolts into packing unit. Lift packing unit out of piston. Use a sling of adequate

length to prevent side loading of eyebolts.

PISTON REMOVAL (#3)

Install two (3/4”- 10UN) eyebolts in top of piston. Place a wooden spacer block (approximately ½” thick)

between each eyebolt and the piston wall to protect the piston sealing surface.

Gently lift piston vertically to free from preventer body. If a vertical lift is unfeasible of if the piston does

not freely lift out, slowly apply low (50 psi) hydraulic pressure to the closing chamber – DO NOT USE

AIR OR GAS!

SLOTTED BODY CAGE REMOVAL (#2) Remove the 12 slotted body cage. Lift out the slotted body

cage with a sling and hooks under the slots. Some model BOP's have a welded body cage which is

not removable.

JAW & JAW OPERATING SCREW ASSEMBLY REMOVAL (#8, #9, #19, #25 & #26)

Hold Jaw Operating Screw (#8) and remove the Pipe Plug (#11) and Jaw Holding Capscrew (#9).

Remove the Jaw Operating Screw (#8) from the body.

The Jaws (#7) can now be removed from inside the blow-out preventer body. Mark jaw sequence to

assure same position on reassembly. If a new jaw is installed within a set of well worn jaws, the new

jaw should be polished to match existing jaws thereby ensuring equal load sharing.

22



29

28

18

22

23

17

6

4

12

11

5

20

10

14 13

3

21

16 15

26

19

25

9

7

2

1

24

8

27

30

Figure 11: 11"10K Annular Exploded View



23

Assembly

CLEAN AND INSPECT ALL PARTS BEFORE ASSEMBLY Inspect all seals and replace any damaged

seals or seals in use over one year. Seal rings MUST BE installed in positions shown by cross section.

Lubricate all seal rings prior to installation. (Silicon grease or castor oil is best).

SLOTTED BODY CAGE INSTALLATION (#2) Install slotted body cage (#2) into inside bottom of

blowout preventer body. Install 12 slotted body cage bolts (#21) and torque to 70-90 lb-ft. ome model

BOP's have a welded body cage which is not removable.

PISTON INSTALLATION (#3) Lubricate and install lower U-seals (#15, #16) in seal grooves in lower

segment of piston. Lubricate and install middle U-seals (#13, #14) seal in seat grooves in middle segment

of piston. Install two (3/4”- 10UN) eyebolts in top of piston with wooden spacer blocks between eyebolt

and piston wall. Lubricate all mating surfaces before lowering piston into body. Install piston into preventer

body. Ensure that vertical alignment between piston and body is achieved prior to lowering piston. After

proper alignment is obtained, the weight of the piston alone willl take the piston its full normal stroke to

the bottom of the preventer body. Be careful to prevent seal damage during assembly. Remove eyebolts and

spacer blocks.

PACKING UNIT INSTALLATION (#10) Lubricate piston bowl. Lift packing unit with two (5/8”-11UN)

eyebolts and set into piston bowl, already installed in preventer.

JAW AND JAW OPERATING SCREW ASSEMBLY INSTALLATION ( #8, #9, #19, #25 & #26)

Install jaws (#7) into cavity in body with square corner of teeth facing up and in the same sequence as

disassembled. If a new jaw is installed within a set of well worn jaws, the new jaw should be polished to

match existing jaws, thereby assuring equal load sharing. Install O-ring (#19) in the external groove of the

Jaw operating screw (#8). Install jaw operating screw (#8) into body and screw in fully (hand tight).

Do not over tighten causing jaw to extend beyond cavity in body.

INSTALL O-RING (#12) in the external groove of the Jaw Holding Cap Screw (#9). Install jaw holding

capscrew into jaw operating screw and screw into jaw already installed in body cavity until tight (50 lb-ft.).

Ensure all jaws are fully retracted into cavity by rotating jaw operating screw counterclockwise until jaws

shoulder against body.

LID INSTALLATION (#4) Lubricate and install lid seal (#18) into groove on outside of blowout preventer

lid, just above the locking grooves. Lubricate and install upper-U Seals (#11) in seal groove on outside of

lid. Lubricate and install lid gasket (#17) and Lid O-Ring (#18) in seal groove on outside of lid just below

the locking grooves. Clean and lubricate looking groove on outside diameter of lid. Lift Lid (#4) and lower

into the body. The weight of the lid will cause it to shoulder against the body, provided the alignment is

truly vertical. Ensure that the lid is fully shouldered agains the body. Rotate the jaw operating screws

clockwise until the jaws fully engage th locking grooves in the lid. Torque to about 300-400 lb-ft. Remove

eyebolts from lid. Install Lid Clamp (#6) and Cap Screw. The blowout preventer is ready for use/testing.

24



Operational Characteristics: PR1

Sealing Characteristics

The Packing Element was evaluated for the following characteristics to seal wellbore

pressure:

1. Constant Wellbore Pressure: Testing has confirmed that the BOP requires the recommended

minimum hydraulic closing pressure to close and achieve wellbore pressure seal around the drill pipe.

2. Constant Closing Pressure: Testing has confirmed that the BOP requires an increase in hydraulic

pressure as the wellbore increases to achieve wellbore pressure seal around the drill pipe.

3. Full Closure Pressure: Testing conducted at half of the rated working pressure for complete shut-off

of Packing Element successfully achieved wellbore seal with recommended hydraulic closing pressure.

Fatigue Life

The sealing reliability and life cycle were qualified by conducting an API 16A operational characteristics

fatigue test. API 16A fatigue test consists of 364 close and open cycles of the blowout preventer. A low

and high pressure wellbore pressure test is conducted on every seventh closure. The packing element

successfully completed all 52 wellbore pressure tests during the 364 close/open cycle fatigue tests.

Stripping

Stripping operations are the most severe application for any annular preventer because of the wear the

packing element is exposed to as the drill string with tool joint is moved through the annular preventer

under pressure. To increase the life of packing element, it is important to use recommended hydraulic

operating pressure when stripping. Tool joint stripping speeds will reduce surge pressures.

A Stripping test should be performed to ensure the functionality of the system and components in a BOP

during stripping of drill pipe with tool joint through the wellbore during the closed condition of BOP. This

test confirms the ability of the Packing Element to seal-off annular pressure.

Approximately 9.567 total feet of pipe was stripped during the test cycles and approximately 7,523

feet of pipe are accepted in correlation with the 2,034 cycles. One tool joint was passed thru the

packing element per each cycle. The test mandrel was running at a medium velocity of 24 inch/sec.

Packing Element (Packer) Access

Tests are performed to determine the ability of the BOP to undergo repeated packing element changes

without affecting operating characteristics. The tests have shown that the packing element were accessed

and performed wellbore pressure tests after every 20th packing element access cycle, a total of 200 packing

element access cycles without failure of the sealing were evaluated.



25

Temperature Verification

Successfully passed API-16A temperature testing requirements for packing element and seal off the

pressure at extreme temperatures, at low and high pressure tests with recommended hydraulic operator

pressure. Non-metallic sealing components and molded sealing assemblies are qualified for temperature

rating class 'DA'.

Note: The above design qualification testing exceeds or meeting the requirement or

minimum performance criteria, PR1.

26



Appendices

Index of Figures

6

8

9

10

11

12

13

16

18

19

22



Figure 3: Annular Hydraulic Control System


Figure 5: Annular Dimensions

Figure 6: Annular Cut Out View


Figure 8: Packing Unit


Figure 10: Packing Unit Testing


Index of Tables

9

10

11

11

14

15

Table 1: Average Closing Pressure

Table 2: 11-10 K Annular Latched Part Description

Table 3: Dimension Data

Table 4: Engineering Data for 11-10K Annular Latched Type

Table 5: Part Numbers for 11" Annular

Table 6: Torque Sequence Number

CONTACT US:

WOM USA

Headquarters/U.S.A


11809 Canemont Street

Houston, Texas 77035 USA

Phone: +(713) 729-9200

Fax: +1 (713) 729-7321


5800 Cunningham


Phone: +(713) 937-0795

Fax: +1 (713) 937-8574

Worldwide Oilfield Machine, Inc

11625 Fairmont St.


Phone: +(713) 721-5200

Fax: +1 (713) 721-5205

Worldwide Oilfield Machine, Inc

Subsea

11400 Tanner Rd.


Phone: +(713) 937-8323

Phone: +1 (713) 937-8574

WOM India

Worldwide Oilfield Machine Pvt. Ltd.

Gat No. 778, at Post Velu

Pune Satara Rd.

Tal. Bhor, Dist. Pune. 412 205. India

Phone: +91-8308210300

+91-8308215300

WOM Turkmenistan

Worldwide Oilfield Machine,Inc.

Yimpash Business Centre

Turkmenbashy Shayoly 54

Office #308, 3rd Floor

Ashgabat- Turkmenistan 744000

Phone: +99-365-820130

+99-365-309757

WOM Middle East

Worldwide Oilfield Machine M.E.

Jebel Ali Free Zone (JAFZA) South,

Plot# S61302, Near Gate #12,

P.O. Box: 32478

Dubai (U.A.E)

Phone: (971-4) 8163 600

Fax: (971-4) 8163 601

WOM Magnum Technology Center

Plot# S61302, Naer Gate #12

Jebel Ali Free Zone (JAFZA) South

Dubai (U.A.E)

Phone: (971-4) 81 63 600

Fax: (971-4) 81 63 601

WOM UK

Worldwide Oilfield Machine (UK) Ltd.

7 St Machar Road

Aberdeen

AB24 2UU

Scotland

Tel: +44 (01224) 484400

Fax: +44 (01224) 489740

WOM Singapore

WOM Asia Pacific Pvt. Ltd.

17 Gul Way

Singapore 629194

Phone: +65 6690 1700

Fax: +65 6560 3859

WOM Indonesia

PT Worldwide Oilfield Machine

#11-08 One Pacific Place

Sudirman Central Business District

Jl. Jenderal Sudirman Kav. 52-53

Jakarta 12190

Phone: +1-832-372-0674

WOM Korea

Worldwide Oilfield Machine

#1012, 481-10, Byucksan Digital Vally-II,

Gasandong,Gumchon Gu,

Seoul, Korea 153-803

Phone: +82 2 854 6806

© Worldwide Oilfield Machine, Inc. www.womusa.com

Disclaimer. This manual is published for informational purposes only. All previous version

are not valid and should not be used as a reference in any form. Revised: May 15, 2019

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