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11”- 10K WGK Annular
Blowout Preventer
Latched Type
Operation & Maintenance
www.womusa.com
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
Table of Contents
4
5
6-7
8
9
10
11
11
12
13
14
15
16
17
18
19
20
21
21
21
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21
21
21
22
23
23
23
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23
23
23
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24
24
24
24
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25
26
26
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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.
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
Components
Major Components
Lid
Wear Plate
Packing Unit
Opening Chamber
Piston
Cage
Closing Chamber
Body
Figure 2: View of Major Components
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
14 Non-Extrusion Ring
15 Double U-Seal
16 Non-Extrusion Ring
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''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
Figure 7: Exploded View of Annular
Seal Kit Part Number: W-1004051
14
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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.
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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.
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
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
11''- 10K WGK Annular-Latched Type
Operation & Maintenance
Appendices
Index of Figures
6
8
9
10
11
12
13
16
18
19
22
Figure 1: View of Major Components
Figure 2: View of Major Components
Figure 3: Annular Hydraulic Control System
Figure 4: Exploded View of Annular
Figure 5: Annular Dimensions
Figure 6: Annular Cut Out View
Figure 7: Exploded View of Annular
Figure 8: Packing Unit
Figure 9: Exploded View of Annular
Figure 10: Packing Unit Testing
Figure 11: Exploded View of Annular
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
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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