OPERATOR’S MANUAL - storage.googleapis.comstorage.googleapis.com/wzukusers/user-19992182/documents...OPERATOR’S MANUAL MSP 21 1/4"-2000 psi Annular Blowout Preventer Please contact

OPERATOR'S MANUALMSP 21 1/4"-2000 psi Annular Blowout Preventer

Please contact Hydril Pressure Control Equipment for any assistance or questions concerning the informa-tion in this manual. All information in this manual is the exclusive property of Hydril Company LP.

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PRESSURE CONTROL EQUIPMENT

HYDRIL COMPANY LP / P.O. BOX 60458 / HOUSTON TEXAS 77205PHONE: (281) 449-2000 / FAX: (281) 985-2828 / WEB: www.hydril.com

© 2001 HYDRIL COMPANY LP PRINTED IN U.S.A. MAY 2001 REV. B, JANUARY 2002

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OPERATOR�S MANUALMSP 21 1/4-2000 psiAnnular Blowout Preventer

2

TABLE OF CONTENTS

PAGE

OPERATOR QUICK REFERENCE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3

SECTION 1.0 – INSTALLATION AND OPERATION

1.1 Surface Operation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 81.2 Subsea Operation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10

SECTION 2.0 – PHYSICAL DATA

2.1 Engineering Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142.2 Bolt and Wrench Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142.3 Outside Dimensions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 152.4 Inside Dimensions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 172.5 API Ring Joint Flange Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 192.6 Clamp Hub Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19

SECTION 3.0 – PACKERS AND SEALS

3.1 Packing Units . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 203.2 Seals . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25

SECTION 4.0 – MAINTENANCE AND TESTING

4.1 Maintenance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 264.2 Seal Testing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 274.3 Packing Unit Testing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 284.4 BOP Modifications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 29

SECTION 5.0 – DISASSEMBLY AND ASSEMBLY

5.1 Disassembly — Screwed Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 315.2 Assembly — Screwed Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 325.1 Disassembly — Latched Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 345.2 Assembly — Latched Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35

SECTION 6.0 – PARTS AND STORAGE

6.1 Parts List — Screwed Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 386.2 Parts List — Latched Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 396.3 Preventor Storage . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 406.4 Rubber Goods Storage . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40

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CLOSINGPRESSURE

OPENINGPRESSURE

Control Pressures

▲▲▲▲▲Surface Control Pressure —psi

WELL PRESSURE—psi

Close cautiously to prevent collapse of casing.

▲ *Use closing pressure shown at initial closure to establish seal off and reduce closing pressure proportionally aswell pressure is increased. Well pressure will maintain closure after exceeding the required level. See Section 1 forcontrol pressure graphs. Closing pressures are average and will vary slightly with each packing unit.

Optimum stripping is obtained by adjusting the Control Pressure to achieve a slight drilling fluid leakage as the tooljoint passes through the packing unit.

10 lb./gal. 3 psi

12 lb./gal. 7 psi

14 lb./gal. 11 psi

16 lb./gal. 15 psi

18 lb./gal. 19 psi

Subsea Operation

Drilling Fluid Density Closing Pressure Increase Per 100 Foot Water Depth

Initial*Pipe Size Closure 500 1000 1500 2000

3 1/2 1275 830 570 320 200

4 1/2"-7" 900 670 420 200 200

9 5/8" 600 420 240 200 200

13 3/8"-16" 400 270 * * *

CSO 1300 1300 1300 1300 1300

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1

2

3

5/16" RodTape Measure

Proper Procedure for pressure testing any annular blow-out preventer (BOP) ensures subsequent seal off andmaximum packing unit life. Reliable seal off tests aremade by initially closing the packing unit with prescribedclosing chamber pressure on the recommended size testpipe, proportionally reducing closing pressure as wellpressure is increased, and by determining the remainingpiston travel after seal off is achieved. Optimum packingunit life is obtained by testing at low rubber stress levels.Minimum packing unit stress is achieved by use of theminimum closing chamber pressure that will initiate andmaintain seal off on the recommended size test pipe.

The MSP blowout preventer is designed to be wellpressure assisted in maintaining packing unit seal offonce initial seal off has been effected. Initial seal off iseffected by applying pressure to the closing chamber. Aswell pressure or test pressure is increased, the closingforce on the packing unit also increases. As well pressureexceeds the required level the packing unit is maintainedclosed on the recommended size test pipe by well pres-sure alone. Once initial seal off is achieved, it is recom-mended that closing pressure be proportionally reduced

as well pressure is increased in order to maintain theoptimum closing force on the packing unit. Optimumclosing forces for high well pressures may require carefulapplication of pressure to the opening chamber. Closingpressure required to effect initial seal off may vary slightlybetween individual packing units. Begin the test with therecommended initial closing pressure.

Piston Stroke can be measured on GK blowoutpreventers through a vertical passage in the top of theBOP head.* The maximum and minimum distances fromthe top of the head to the top of the piston are stamped onthe BOP head and are also listed in the table below.Piston stroke remaining at seal off is a direct indicator ofremaining packing unit life. Record the piston stroke andthe closing pressure at seal off for each test. Comparewith previous results and with maximum piston stroke forthe BOP to ensure subsequent seal offs. A valid test onany annular BOP is only achieved when the remainingpiston stroke is measured at test seal off.

*0lder model BOPs may not have vertical passage in head. SeeSection 4.3 for information on field modification.

OPERATIONAL DATA

Bore *21 1/4 in. 538.8 mm

Closing Chamber 31.1 117.6Volume gal. (U.S.) liters

Opening Chamber 18.9 71.5Volume gal. (U.S.) liters

Recommended TestPipe Size 4 1/2 in. 114.3 mm

Full Piston Stroke 11 1/4 in. 286 mm

Distance From Top of Head To Top of Piston

Screwed HeadMaximum — Piston Full

Down 15 1/2 in. 394 mm

Minimum — Piston at FullStroke 4 1/4 in. 108 mm

Latched HeadMaximum — Piston Full

Down 15 1/2 in. 394 mm

Minimum — Piston at FullStroke 4 1/4 in. 108 mm

Sales Headquarters / P.O. Box 60458 / Houston, Texas 77205Telephone: (281) 449-2000 / FAX: (281) 985-2828Eastern Hemisphere / Hydril U.K. Ltd. Minto Avenue Altens Industrial EstateAberdeen, AB1 4JZ Scotland / Telephone: +441-224-878-824 / FAX: +441-224-898-524

ANNULAR BOP TESTING AND OPERATION

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*BOPs with 3000 psi top and bottom connectors have 20 3/4" bore.

Pressure Control Equipment

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Figure 1-1Cutaway view of MSPwith packing unitfully open

CLOSINGCHAMBER

BODY

PISTON

OPENINGCHAMBER

HEAD

PACKINGUNIT

WEARPLATE

PISTONINDICATOR

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Figure 1-2Upward force exertedby the piston squeezespacking unit rubber inward intoa sealing engagement.

The Hydril® MSPblowout preventer is an annular blowoutpreventer which will close and seal off on drill pipe, tooljoints, tubing, casing, or wireline in the wellbore orcompletely seal off the open hole to full rated workingpressure by compression of a reinforced elastomer pack-ing element. This preventer has been developed for useon surface installations and it can also be used subsea. Inaddition, the GK meets the requirements of API Recom-mended Practices – R.P. 53*.

Hydraulic pressure applied to the closing chamber (referto Figures 1-2 through 1-6) raises the piston forcing thepacking unit into a sealing engagement. Wellbore pres-sure (or test pressure) acting on the piston from below thesealed off packing unit further increases the closing force.Drill pipe can be rotated and tool joints stripped through aclosed packing unit while maintaining a full seal on thepipe.

Any normal closing unit having a separate pressureregulator valve for the annular blowout preventers andsufficient accumulator volume (see Section 2.1 of thismanual for chamber volumes) can be used to operate theGK blowout preventer. The hydraulic operating fluid maybe clean, light petroleum hydraulic oil, or water with watersoluble oil added. In cold climates, antifreeze should beadded to prevent freezing.

The closing time of the preventer is determined by therate at which the hydraulic fluid can be delivered to theclosing chamber. Minimum closing time is achieved byusing short, large diameter control lines, large bore controlvalves, and a large accumulator volume. An excessivelyhigh setting on the pressure regulator valve will have littleeffect on BOP closing time.

*API Recommended Practices for Blowout PreventionEquipment Systems - R.P 53 is available from the Ameri-can Petroleum Institute, Production Department, 1220 LStreet, Northwest, Washington, DC 20005.

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Figure 1-6. Cutaway view of MSP BOP with packingunit closed on open hole. Complete closure of packingunit safely holds well pressure, without leakage, equal tothe rated working pressure of the preventer.

Figure 1-5 . Cutaway view of MSPBOP with packingunit closed on square kelly. The packing unit seals off onsquare or hexagonal kellys to rated pressure.

Figure 1-3 . Cutaway view of MSP BOP with packingunit fully open. The Hydril® GK opens to full bore to allowpassage of large-diameter tools through open bore as wellas maximum annulus flow of drilling fluids. Packing unitalways returns to the open position due to normal resil-iency of rubber packing unit. Retention of opening cham-ber pressure will provide positive control of piston andreduce wear caused by vibration.

Figure 1-4 . Cutaway view of MSP BOP with packingunit closed on drill pipe. The packing unit seals off on tooljoints, drill pipe, casing, tubing, or wireline to ratedpressure.

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1.1.1 Surface Hookup

The surface hookup of the msp shown in Figure 1-7connects the hydraulic control lines to the opening andclosing chambers of the BOP

Pressure applied to the closing chamber raises thepiston and effects the initial seal between the packing unitand drill pipe. Well pressure or test pressure also acts onthe piston below the sealed off packing unit and furtherincreases the closing force acting on the packing unit. Asthe well pressure or test pressure exceeds the requiredlevel the preventer is maintained closed by well pressurealone. As well pressure further increases, the closing forceon the packing unit also increases. Closing pressureshould be proportionally reduced as well pressure isincreased in order to maintain optimum closing force onthe packing unit and prolong packing unit life.

The Control Pressure Graph, Figure 1-8, shows therelationship of closing pressure and well pressure requiredto effect optimum seal off for the MSP 21 1/4"-2000 BOP.

During normal drilling operations, it is recommended thatthe pressure regulator valve for the msp be set at the initialclosing pressure shown for the size pipe being used. Thispressure will ensure that initial seal off is achieved shoulda “kick” be encountered.

During BOP testing operations, once initial seal off isachieved, closing pressure should be proportionallyreduced as well pressure is increased.

CLOSINGPRESSURE

OPENINGPRESSURE

CSO

3 1/2" PIPE4 1/2"-7" PIPE

9 5/8" PIPE*13 3/8"-16" PIPE

CLO

SIN

G P

RE

SS

UR

E-P

SI

1500

1000

500

0 400 800 1200 1600 2000

WELL / TEST PRESSURE-PSI

Figure 1-8: Average Control Pressure - MSP 21 1/4-2000

Figure 1-7

*Closing pressures are average and will vary slightly with eachpacking unit. Use closing pressure shown at initial closure to establish sealoff and reduce closing pressure proportionally as well pressure is increased.Well pressure will maintain closure after exceeding the required level.**Close cautiously to prevent collapse of casing.Operating pressure may vary at temperatures other than 70 oF.

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Example Precharge Calculation:500 psi well pressure, 4 1/2" drill pipePrecharge = 0.50 (Closing Pressure).From Figure 1-8:Closing Pressure = 670 psiPrecharge = 0.50 x 670 psiPrecharge = 335 psi

Opening Pressure

Closing Pressure

1.1.2 Surface Stripping Operations

Drill pipe can be rotated and tool joints stripped through aclosed MSP packing unit while maintaining a full seal offon the pipe. Longest life for the packing unit is obtained byadjusting the closing forces low enough to maintain a sealon the drill pipe with a slight amount of drilling fluid leakageas the tool joint passes through the packing unit. Thisdrilling fluid leakage indicates optimum seal off for mini-mum packing unit wear and provides lubrication for thedrill pipe motion through the packing unit.

Slow tool joint stripping speeds reduce surge pres-sures, and thus prolong packing unit life. The pressureregulator valve should be set to provide and maintain theproper control pressure. If the pressure regulator valvedoes not respond fast enough for effective BOP control,a surge absorber (accumulator) should be installed in theclosing chamber control line adjacent to the blowoutpreventer. Precharge the accumulator to one-half of theclosing pressure required to effect a seal off at theexisting well pressure for the pipe size in use.

Opening Pressure

Closing Pressure

Surface Hookup

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EXAMPLE: Method 14 1/2" pipe, initial closure, 16 lb./gal. drilling fluid,500 ft. water depth.Subsea Closing

Pressure = Surface Closing Pressure +Adjustment Pressure ( DP).

From the Control Pressure Graph, Figure 1-8:Initial Closing Pressure = 900 psi.Adjustment Pressure ( DP)_(0.052 x 16 lb/gal. x 500 ft.) – (0.45 psi/ft. x 500 ft.)_

2.56Adjustment Pressure ( DP) = 74.6 psiInitial Subsea Closing

Pressure = 900 psi + 74.6 psi = 975 psi.Proportionally reduce the closing pressure as wellpressure increases, as shown in Figure 1-8.

1.2.1 Subsea Hookup

Opening Pressure

Closing PressureFigure 1-9

When operating the MSP subsea, an adjustment pressure

(DP) must be added to the closing pressure. The adjust-

ment pressure (DP) compensates for the hydrostatic pres-sure of the drilling fluid column in the marine riser, which

exerts an opening force on the BOP DP for the GK 13 5/8-5000 subsea hookup is calculated from the followingformula:

Adjustment Pressure ( DP) =(0.052 x Wm x Dw) – (0.45 x Dw)

p

Where:Wm = drilling fluid density in lb./gal.Dw = water depth in feet0.052 = conversion factorp = 2.56 = the ratio of closing chamber area to the

difference between the closing chamberand the opening chamber areas for theMSP 21 1/4"-2000.

0.45 psi/ft. = pressure gradient for seawater using aspecific gravity of seawater = 1.04 and0.433 psi/ft. pressure gradient for freshwater.

The optimum closing pressure for subsea operation isobtained using the following formula:Subsea Closing

Pressure = Surface Closing Pressure + Ad-justment Pressure (DP).

This can be done by one of two different methods:

Method 1 . Calculate the adjustment pressure (DP) andadd it to the surface closing pressure found in the SurfaceControl Pressure Graph, Figure 1-8.

ORMethod 2 . Find the adjustment pressure (DP) in theAdjustment Pressure Graph, Figure 1-10, and add it tothe closing pressure found in the Control PressureGraph, Figure 1-8.

1.2.1 Subsea Operations

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EXAMPLE: Method 24 1/2" pipe, initial closure, 16 lb./gal. drilling fluid, 500 ft. water depth.Subsea Closing Pressure = Surface Closing Pressure + Adjustment Pressure ( DP).From Figure 1-8: Initial Closing Pressure = 900 psi.From Figure 1-10: Adjustment Pressure ( DP) = 74.6 psi.Subsea Closing Pressure = 900 psi + 74.6 psi = 690 psi.

Figure 1-10: Adjustment Pressure (DP) – MSP 21 1/4"-2000 Subsea Hookup

Figure 1-8: Average Control Pressure - MSP 21 1/4-2000

100

200 400 600

50

150

0

AD

JUS

TM

EN

T P

RE

SS

UR

E (

DP

) –

PS

I

800 1000

18 lb./gal.

16 lb./gal.

14 lb./gal.

12 lb./gal.

10 lb./gal.

200

WATER DEPTH - FEET

CSO

3 1/2" PIPE4 1/2"-7" PIPE

9 5/8" PIPE*13 3/8"-16" PIPE

CLO

SIN

G P

RE

SS

UR

E-P

SI

1500

1000

500

0 400 800 1200 1600 2000WELL / TEST PRESSURE-PSI

*Check specifications forcollapse pressure of casing.

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1.2.2 Subsea Stripping OperationsDrill pipe can be rotated and tool joints stripped through aclosed subsea MSP packing unit, while maintaining a sealoff on the pipe.

Longest packing unit life is obtained by adjusting theclosing forces low enough to maintain a seal with a slightamount of drilling fluid leakage around the drill pipe. Thedrilling fluid leakage indicates the optimum seal off forminimum packing unit wear and provides lubrication forthe drill pipe motion through the packing unit.

The pressure regulator valve should be set to maintainthe proper control pressure. In subsea installations, asurge absorber (accumulator) of approximately 10-gallonsize should be connected to the closing chamber. This

surge absorber prevents pressure surges when strippingtool joints through a closed packing unit. Slow tool jointstripping speeds reduce surge pressures, thus prolong-ing packing unit life. The closing chamber surge absorbershould be precharged to the hydrostatic pressure of thecontrol fluid column plus 100 psi.

An opening chamber surge absorber may be appliedwhen the blowout preventer control system does notpermit free bidirectional control fluid flow from and to theopening chamber during stripping operations. Prechargeto 80% of the sea bottom water pressure (normally 0.45psi/ft.).

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The precharge pressure for the closing chamber surgeabsorber can be calculated using the following exampleor taken directly from Figure 1-11.EXAMPLE:4 1/2"-5 1/2" pipe, 500 ft. water depth.

Precharge: .41 (Dw) + 100 psiWhere:Dw = water depth in feet0.41 psi/ft. = pressure gradient for control fluid (water

and water soluble oil) using a specificgravity of the mixture = 0.95 and 0.433 psi/ft. pressure gradient for fresh water.

Precharge = (0.41 psi/ft. x 500 ft.) + 100 psi.Precharge = 305 psi.

Figure 1-11: Closing Chamber Surge Absorber Precharge Pressure – MSP 21 1/4"-2000 Subsea Hookup

WA

TE

R D

EP

TH

– F

EE

T

0 100 200 300 400 500 600 700 800 900 1000

PRECHARGE PRESSURE – PSI

1000

900

800

700

600

500

400

300

200

100

Closing Chamber Surge Absorber PrechargeSubsea Hookup

Opening Pressure

Closing Pressure

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2.1 Engineering DataEnglish Metric

Bore . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . **21 1/4 inches 539.8 mm

Working Pressure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2000 psi 138 BAR

Shell Test Pressure (Factory Test Only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3000 psi 207 BAR

Closing Chamber Test Pressure (Factory Test Only) . . . . . . . . . . . . . . . . . . . . . . . . 3000 psi 207 BAR

Opening Chamber Test Pressure (Factory Test Only) . . . . . . . . . . . . . . . . . . . . . . 3000 psi 207 BAR

Volume—Closing Chamber . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31.1 gallons 117.7 liters

Volume—Opening Chamber . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18.9 gallons 71.5 liters

Piston Stroke . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 1/4 inches 286 mm

Port Size . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 NPT* . . .

Weight-Single (Approximate—varies with connectors . . . . . . . . . . . . . . . . . . . . . . . 15,100 lb 6849 kg

* 1 1/4" or 1 1/2" NPT available on request.

** BOPs with 3000 psi top and bottom connections have 20 3/4" bore.

2.2 Bolt and Wrench Data

Ref. Description Thread Wrench Recommended TorqueNo. Size Lb/Ft Kg-m

2 Pipe Plug—Piston Indicator 1/2" NPT 3/8" Hex Key 50 6.9

4 Head Lock Screw 3/4"-10UNC 1 1/8" Hex 100 13.8

13 Capscrew, Outer Body Sleeve 1"-8UNC 1" 12pt Socket 250 34.6

34 Wear Plate Cap Screw 1/2-13UNC 1/2" -12pt. Socket 70 9.7

35 Capscrew, Inner Body Sleeve 3/4"-10UNC 3/4" 12pt Socket 120 16.6

. . . Eyebolt, Piston 3/4"-10NC . . . Snug Snug

. . . Eyebolt, Head 1 1/4"-7NC . . . Snug Snug

. . . Screw, Protector Plate 1/2"-13UNC 3/4" Hex Snug Snug

LATCHED HEAD ONLY

16 Head Clamp Screw 7/8"-9UNC 3/4" Hex Key 250 34.6

18 Jaw Operating Screw 2 1/4"-8UN 2 1/2" Hex 300-400 41.4-55.2

19 Jaw Holding Cap Screw 1/2"-14 NPT 3/4" Hex Key 50 6.9

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2.3 Outside Dimensions–Screwed Head

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

52 1/2 Hub 18 . . . 12 1/2 23 1/8 Hub 18 7 1/2 6 3/16 27 3/8 45 1/4 51 3/4 58 3/4 52 3/4 50 1 3/451 6

Hub Hub50 1/2 5 1/2

Nominal Dimensions–Inches–with 2000 psi Bottom Connections


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

541/2 Hub 17 . . . 12 1/2 23 1/8 Hub 17 9 1/4 6 3/16 27 3/8 45 1/4 51 3/4 58 3/4 52 3/4 50 1 3/450 1/2 6

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2.3 Outside Dimensions–Latched Head

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

. . . . . . . . . 23 5/8 10 3/8 8 5/16 21 3/16 58 3/4 56 5/8 50 . . . 1 3/4 45 1/4 51 3/4


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

52 1/2 46 . . . 23 5/8 10 3/8 8 5/16 21 3/16 58 3/4 56 5/8 50 7 1/2 1 3/4 45 1/4 51 3/4

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2.4 Inside Dimensions–Screwed Head

INCHES

O.D.UpperPiston

42

NOMINAL DIMENSION H J K L M Ø

INCHES

*Bore

21 1/4

I.D.Piston

24 7/8

I.D.Body

47 1/2

I.D. PistonSealingSurface

38

Stroke

11 1/4

PackingUnit

Height

11 3/4

Top of Headto Top

of Piston(Full Down)

15 1/2

PistonHeight

25 1/4

HeadHeight

19 1/4

Top of Headto Bottomof Wear

Plate

9 7/8 25o

PistonTaper

* BOPs with 3000 psi top and/or bottom connections have 20 3/4" bore.

NOMINAL DIMENSION A B C D E F

Top ofSleeve toBottom of

Head

11 15/16

G

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2.4 Inside Dimensions–Latched Head

INCHES

O.D.UpperPiston

42

NOMINAL DIMENSION H J K L M Ø

INCHES

*Bore

21 1/4

I.D.Piston

24 7/8

I.D.Body

47 1/2

I.D. PistonSealingSurface

38

Stroke

11 1/4

PackingUnit

Height

11 3/4

Top of Headto Top

of Piston(Full Down)

15 1/2

PistonHeight

25 1/4

HeadHeight

19 1/4

Top of Headto Bottomof Wear

Plate

9 7/8 25o

PistonTaper

* BOPs with 3000 psi top and/or bottom connections have 20 3/4" bore.

NOMINAL DIMENSION A B C D E F

Top ofSleeve toBottom of

Head

11 15/16

G

19

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20 21 1/4 2000 32 3 7/8 23 RX-73 24 1 5/8"-8UN 12 1/2 8 1/4 28 1/2

20 20 3/4 3000 33 3/4 4 3/4 23 RX-74 20 2"-8UN 15 1/4 11 29 1/2

2.5 API Ring Joint Flange Connections

2.6 Clamp Hub Connections

B

C

ABolted Flange,Using Stud Bolts

Studded Flange,Using Studs

C

SEAL RINGFLANGE

NominalSize

(Inches)

BoreDia.

(Inches)

BOLTS & STUDS a

O.D.(Inches)

Thickness(Inches)

Max. APIService

PressureRating (PSI)

† Dia. C(Inches)

APIRing

Stud Bolts

BoltCircleDia.

Length b

(Inches)SizeNo.

Req.Studs

B

Max. Point Height Inchesa Bolt material shall be of a quality and strength not less

than specified by ASTM A-320, Grade L7. Nuts shallbe of a quality not less than ASTMA-194, Grade 2H. Stud bolts are threaded full length.

b Lengths shown herein are overall lengths, includingpoint at both ends, as shown in table.

† Dimensions shown are outside diameters of 6BX flangegrooves.

Bolt Diameter, Inches

1/2 to 7/8 . . . . . . . . . . . . . . . . . . . . . . 1/8Over 7/8 to 1 1/8 . . . . . . . . . . . . . . . . 3/16Over 1 1/8 to 1 5/8 . . . . . . . . . . . . . . 1/4Over 1 5/8 to 1 7/8 . . . . . . . . . . . . . . 5/16Over 1 7/8 to 2 1/2 . . . . . . . . . . . . . . 3/8

POINT HEIGHT OF STUD BOLTS

HUB

HubSize

(Inches)

Clamp Dimensions (Inches) ▲▲▲▲▲

BXSeal Ring No.

BoreSize

A(Inches)

RatedWorkingPressure

Hub Dimensions (Inches)

B CRX D J

RX OnlyStandoff

E F G H

▲ Clamp dimensions may vary from those shown.

J

G

B

E

F

A

H

CA

B

E

F

G

HSwing Bolted(with BX Gasket Hubs)

Swing Bolted(with RX Gasket Hubs)

NO.

CLAMP

20 21 1/4 2000 73 . . . 26 3/8 4 1/8 19/32 . . . 32 3/8 38 3/4 7 1/8 9 1/2 18

20 20 3/4 3000 73 . . . 25 5/8 3 3/4 19/32 . . . 31 37 7/8 6 13/16 9 1/4 17

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3.1 Packing UnitsThe heart of the MSP blowout preventer is the packingunit. The unit is manufactured by Hydril from highquality rubber, reinforced with flanged steel segments.Each unit has a large volume of tough, feedable rubberto meet any requirement.

The molded-in steel segments have flanges at the topand bottom These segments anchor the packing unitwithin the blowout preventer and control rubber extru-sion and flow when sealing off well pressures. Since therubber is confined and kept under compression, it is

resistant to tears and abrasion.All annular blowout preventer packing units are sub-

jected to wear during closure and stripping. The design ofthe Hydril® MSP blowout preventer causes closure wear tooccur on the outside of the packing unit while stripping wearoccurs on the inside. Because the packing unit uses theprinciple of feeding rubber from the back of the packing unitto the bore, stripping life may be affected by a packing unitthat is worn on the backside.

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3.1.1 Packing Unit SelectionBecause of the importance of the packing unit to theoperation of the blowout preventer and to the safety of thecrew and rig, only genuine Hydril® packing units should beused as replacements for original equipment. All Hydril®

packing units are tested to full rated pressure inside a testblowout preventer at the factory as part of standardperformance tests before being furnished to the con-sumer.

Packing units for Hydril® blowout preventers are manu-factured from compounded natural rubber or nitrile rub-ber.

Natural Rubber is compounded for drilling with water-base drilling fluids. Natural rubber can be used atoperating temperatures down to –30oF (–35oC). Whenproperly applied, the compounded natural rubber pack-ing unit will usually provide the longest service life. Thisall-black packing unit is identified by a serial number withthe suffix "R" or "NR."

Nitrile Rubber (a synthetic compound) is for use withoil-base or oil-additive drilling fluids. It provides the bestservice with oil-base muds, when operated at tempera-tures below 20oF (–7oC). The nitrile rubber packing unitis identified by a red colored band and a serial numberwith the suffix "S" or "NBR."

Seals for Hydril® blowout preventers are manufacturedfrom a special nitrile rubber material which provides long,trouble-free service in sealing against oil gas, or water.

Expected H 2S Service does not affect selection ofpacking unit material. H2S service will reduce the servicelife of rubber products, but the best overall service life isobtained by matching the packing unit material with therequirements of the specific drilling fluid.

Performance of elastomeric materials can vary signifi-cantly, depending on the nature and extent of exposure tohydrogen sulfide. The operator should monitor pressuresealing integrity by frequently performing a packing unitseal test to assure no performance degradation hasoccurred. Hydril recommends replacement of all rubbergoods after H2S exposure.

Storage Conditions such as light, heat or adverseconditions are significant factors in the storage life ofpacking units, as covered in Section 6.3, and should beavoided.

Figure 3-2Natural Rubber PackingUnit – No Band

Figure 3-3Synthetic Rubber PackingUnit – Red Band

Red Band

No Band

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3.1.2 Packing Unit Replacement–Screwed HeadTo replace the packing unit, use the followingprocedure:1. Remove head lock screw.2. Unscrew blowout preventer head

(counter-clockwise).3. Lift off blowout preventer head.4. Lift out packing unit.5. Lubricate piston bowl.6. Install new packing unit.7. Clean and lubricate head and body

threads with zinc base API modified tooljoint lubricant.

8. Replace head and tighten to align hole forlock screw.

9. Install head lock screw and torque to 100lb-ft.

NOTE: If the head was improperly installed at lastreassembly, it may be necessary to apply consid-erably more torque on the head by the use of acatline or winch while alternately applying andreleasing pressure to the opening chamber (1500psi maximum). Do not attempt to loosen the headby applying heat. Refer to Assembly/DisassemblySection for further information.

OPENING TORQUE

Figure 3-4

Figure 3-5

Figure 3-6

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Figure 3-8 Retract jaw operating screws 4 turns

Figure 3-11 On assembly, if standoff betweenhead and body occurs, use head clamps and screws topull head fully into place.

Figure 3-10 Head clamps and head have beenremoved, but all latching mechanisms remain in body.

Figure 3-9 Head in place, but head clamps andscrews have been removed, and jaw operating screwshave beenretracted (4 turns).

Figure 3-7 Head latched in place and jaw operat-ing screws tightened.

3.1.2 Packing Unit Replacement –Latched HeadThe latched head design of the MSP blowout preventerallows for easy replacement of the packing unit andeliminates loose parts that can be lost downhole oroverboard. To replace the packing unit, use the follow-ing procedure:

1. Retract the jaw operating screws four turns to re-lease the jaws from the head (see Figures 3-7 and 3-8).

2. Remove the head clamps and screws from top ofhead.

3. Lift out blowout preventer head.4. Lift out old packing unit, lubricate the piston bowl,

and.install the new packing unit.5. Replace head and install head clamps and screws to

pull head fully into place.6. Tighten jaw operating screws four turns and torque

to 300 - 400 lb-ft.

Head Clamp Screw

Head Clamp

Head O-Ring

Jaw Operating Screw

Washer & Seal

O-Ring

Jaw

Head Gasket

Head

Jaw Holding Capscrew

Standoff

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Figure 3-13

Figure 3-12Photo shows proper method forcutting through packing unitwith a sharp knife.

3.1.3 Splitting Packing UnitsPacking unit replacement is also possible with pipe in thehole. After removing worn packing unit, cut new packingunit completely and smoothly through one side betweenany two steel segments perferably 90o from eyebolt holesto achieve easier handling. Cut should be made with asharp knife as this will not affect the efficiency of thepacking unit. Spring segment apart with a pry bar to putrubber in tension for easier cutting. Do Not use a saw orother rough cutting tool. Spring packing unit open suffi-ciently to pass around pipe, drop unit into position inblowout preventer body, and replace head.

NOTE: The packing unit should be split only in thecase of an emergency. The packing unit should bereplaced as soon as possible with a unit that has notbeen split.

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3.2 SealsThe seal rings for Hydril® blowout preventers are man-ufactured from a special synthetic rubber material for longtrouble-free sealing service. To prevent seal damage, DoNot use synthetic fluids in the hydraulic operating system.The hydraulic operating fluid may be clean, light petro-leum hydraulic oil, or water with soluble oil added. In coldclimates, antifreeze should be added to prevent freezing.

The dynamic seals are all molded, lip-type, pressure-energized rings.

The static seals are of O-ring or square ring config-uration.

For seal replacement procedure, see Section 5.2.

DYNAMIC SEALS STATIC SEALS

DOUBLE U-SEALcross-sectionwithnonextrusionrings

U-SEALcross-section

O-RINGcross-section

SQUARE RINGcross-section

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1

1

6

5

3

8

8

3 4

2

7

4.1 MaintenancePrior to placing the MSP blowout preventer into service,the following visual inspections (as noted in Figure 4-1)should be performed:1. Inspect upper and lower connections for pitting, wear,and damage—especially in ring grooves and stud boltholes. Worn or damaged ring grooves must be welded,machined, and stress relieved. Worn or damaged studbolt holes can be drilled and tapped to the next larger sizeor to the same size by installing inserts.

NOTE: The Hydril ® MSP blowout preventer is aprimary pressure vessel. When requested, theblowout preventer surfaces exposed to wellborefluids will meet NACE Standard MR-01-75. Properhandling and repair are required to maintain anyoriginal integrity. Field welding is not recom-mended as it induces undesirable stresses whichmust be relieved by proper heat treating proce-dure or controlled by special welding procedures.

2. Check the body for wear and damage—especially inthe internal cylinder walls for pits and vertical scores.Minor pits and scores can be removed in the field withemery cloth. Repaired surface should be coated withsilicon grease or castor oil. Severe pits and scores mayrequire machining and/or welding which should be per-formed in a Hydril authorized machine shop.3. Inspect the vertical bore for wear and damage fromdrill string and drill tools—especially in the area of the ringgrooves. If wear is excessive, the area must be repaired.4. Check the inner and outer body sleeves for wear,damage, and looseness. Check slots in sleeve for cuttingswhich may restrict piston movement. Older model BOPshave a welded body sleeve and may be field repaired byconversion to a bolted sleeve (see Section 4.4).

5. Check for piston damage and wear—especially theinner and outer walls for pits and vertical scores and thetapered bowl for pits and gouges.

Minor pits and scores on the walls can be removed inthe field with emery cloth. Repaired surface should becoated with silicon grease or castor oil. Severe pits andscores may require machining and/or welding which shouldbe performed in a Hydril approved machine shop.

Pits and gouges in the tapered bowl should be filledwith a permanent type adhesive, such as epoxy. Sharp orrolled edges should be removed with emery cloth or agrinder. Repair will be satisfactory when a relativelysmooth surface is achieved.6. Check the wear plate in the inner bottom face of thehead for wear. In addition to the aging process of time anduse, wear of this metal surface is produced by the combi-nation of vertical (upward thrust) and lateral forces. Theseforces are generated each time the packing unit is closed.Severe wear is exhibited in the form of grooves or chan-nels shaped by the steel segments of the packing unit.

The inner bottom face of the head serves as a wall toprevent upward movement of the packing unit. Frictionbetween these metal surfaces is controlled at a levelwhich does not impair lateral movement of the packingunit.

Repair of this surface is accomplished by replacing thewear plate. Some models of this BOP do not have thewear plate, but may be converted.7. Inspect the packing unit for wear, cracking, hardness,and correct elastomer composition. See Section 3 forpacking unit information and Section 4.3 for packing unittesting.8. Check seal ring for nicks, cuts, fraying of lips, andabrasion. Worn or damaged seal rings should be re-placed. See Section 4.2 for pressure testing of seals.

Figure 4-1

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4.2 Seal TestingWhen it is known or suspected that a seal within the MSPblowout preventer is leaking, it is recommended that allseals be replaced. However, if only the seal in question isto be replaced, it must first be determined which seal isleaking. The following procedure is provided:1. Test seals 9 (lower) and 10 (lower), and 14.

a. Pressurize closing chamber. The test pressureto be used in the closing chamber should be theinitial closing pressure required using the recom-mended test mandrel if a packing unit is installed(1500 psi if no packing unit is installed).

b. Open opening chamber to atmosphere.IF: Closing fluid is seen at opening chamber—seal

9 (lower) is leaking.IF: Closing chamber pressure gauge is dropping

and no fluid is seen at opening chamber—seal10 (lower) or seal 14 is leaking.

2. Test seals 7(lower), 9 (upper), and 5.a. Pressurize opening chamber (1500 psi).b. Open closing chamber to atmosphere.IF: Fluid is seen coming from area between body

and head—seal 5 is leaking.IF: Fluid is seen coming into the wellbore—seal 7

(lower) is leaking.IF: Fluid is seen at closing chamber—seal 9 (upper)

is leaking.3. Test seals 7 (upper) and 10 (upper), and 14.

a. Open closing chamber to atmosphere.b. Open opening chamber to atmosphere.c. Pressurize wellbore (2000 psi maximum). (Re-

quires blind flange on top, as packing unit isopen.)

IF: Fluid is seen coming from the opening cham-ber—seal 7 (upper) is leaking.

IF: Fluid is seen coming from the closing chamber—seal 10 (upper) or seal 14 is leaking.

4. For packing unit testing, see Section 4.3.

5

7 UPPER

7 LOWER

10 UPPER10 LOWER

9 UPPER9 LOWER

14

Figure 4-2

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Older model BOPs may not have the Piston Indicator Hole asshown in Figure 4-3 above. See Section 4.4 for modilcation.

Figure 4-3: Piston Stroke Measurement

4.3 Packing Unit TestingProper procedure for pressure testing any annular blow-out preventer ensures subsequent seal off and maximumpacking unit life. Reliable pressure seal off tests are madeby closing the packing unit with prescribed closing cham-ber pressure on recommended size test pipe and by

4.3.2 Packing Unit Testing-SubseaPrior to putting the MSP subsea, a surface packing unittest should be performed (see 4.3.1).

When testing subsea, refer to Section 1.2 for SubseaControl Pressure. The closing pressure to effect initialseal off may vary with individual packing units. Begin thetest with the recommended closing pressure and use theminimum closing pressure that will establish and maintainseal off.

determining the remaining piston travel after seal off isachieved. Optimum packing unit life is obtained by testingat low rubber stress levels. Minimum packing unit stressis achieved by use of the minimum closing chamberpressure that will initiate and maintain a seal off on therecommended size test pipe.

4.3.1 Packing Unit Testing—SurfaceThe MSP blowout preventer is designed to be well pres-sure assisted in maintaining packing unit seal off onceinitial seal off has been effected. Initial seal off is effectedby applying pressure to the closing chamber. As wellpressure or test pressure increases, the closing force onthe packing unit also increases.

Once initial seal off is achieved, closing pressure shouldbe proportionally reduced as well pressure is increased(see the Control Pressure Graph, Figure 1-8).

Closing pressure required to effect initial seal off mayvary between packing units. Begin the test with therecommended initial closing pressure shown in Figure 1-8. Use the minimum closing pressure that will establishand maintain a seal off.

Piston Stroke can be measured on MSP blowout pre-venters through a vertical passage in the top of the BOPhead. The maximum and minimum distances from the topof the head to the top of the piston are stamped on theBOP head and are also listed in the table below. Pistonstroke remaining at seal off is a direct indicator of remain-ing packing unit life. Record the piston stroke and theclosing pressure at initial seal off for each test. Comparewith previous results and with maximum piston stroke forthe BOP to ensure subsequent seal offs. A valid test onany annular BOP is only achieved when the remainingpiston stroke is measured at test seal off.

Distance From Top of Head Screwed Latchedto Top of Piston Head Head

Maximum (piston in fulldown position) 151/2" 15 1/2"

Minimum (piston at fullstroke) 4 1/4" 4 1/4"

5/16" RodTapeMeasure

1

2

3

4

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R = 20.250"

4.4 BOP Modifications

4.4.1 Piston Indicator Hole ModificationOlder Model BOPs without piston indicator holes may bemodified as shown in Figure 4-4 below.

PISTON INDICATOR BOP

Figure 4-4: Field modification for addition of PistonIndicator Hole to older model BOPs.

The procedure* for adding the piston indicator hole is asfollows:1. Drill one .339" diameter hole through the BOP head at

a point located on the 20.25" radius from the centerline( ) of the BOP Head.

2. Counterbore with .719 " diameter drill. x 1 3/8" deep.3. Tap the .719" diameter hole with a 1/2"-14 NPT tap.4. Insert a 1/2"-14NPT pipe plug and torque to 50 lb-ft.

* A drill press should be used.

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4.4.2. Bolted Body Sleeve ModificationTo maintain original integrity without welding, older modelBOPs having a welded body sleeve may be repairedthrough conversion to a bolted sleeve. This conversion isaccomplished by using the Field Replacement SleeveKit, part number 50894-K.

The Field Replacement Sleeve Kit contains the follow-ing:1. 1—Drill Template2. 1—27/64" Dia. Pilot Drill3. 1—19/32" Dia. Counterbore Drill4 1—1/2"-13NC Tap5. 1—Bolted Body Sleeve6. 12—1/2"-13NC X 1 1/4" Lg. Hex Head Cap Screws

The procedure for converting the BOP from a slottedbody sleeve to a bolted sleeve is as follows:1. Remove old body sleeve.2. Grind out all weld from the counterbore and the 20o

bevel that would interfere with the new sleeve (seeFigure 4-5).

3. Insert drill template as shown in Figure 4-6.4. Drill one 27/64" diameter hole, 1 1/4" deep, through

one of the 27/64" diameter holes in the template.NOTE: Template has eleven 27/64" diameter holesand one 9/16" diameter hole.

5. Remove the template and counterbore hole with19/32" diameter drill (see Figure 4-7).

6. Tap the hole with 1/2"-13NC tap, 3/4" deep.7. Re-insert the template and bolt to the BOP through the

9/16" hole in the template.8. Drill a 27/64" diameter hole, 1 1/8" deep, in the 11

remaining places.9. Remove the template and counterbore 19/32" diam-

eter in 11 places.10.Tap 11 holes with 1/2"-13NC tap.11. Install new sleeve and bolt down tight (see Figure 4-8).

Grind All Weld FromCounterbore And 20o Bevel 27/64" Dia. Drill Drill Template

9 5/16 + 1/16" To Top Of Body19/32" Dia. Counterbore DrillWith 27/64" Dia. Pilot

BoltedBody Sleeve

Figure 4-5 Figure 4-6

Figure 4-7

Figure 4-8

9/16" Hole19/32" Counterbore

1/2"-13NC Thread

27/64" Dia.

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5.1 Disassembly—Screwed Head5.1.1 HEAD REMOVAL (ITEM 1)Close and open the packing unit to break loose anyaccumulation of drilling fluid or debris which may berestricting full downward travel of the piston (Item 8).

Vent opening and closing chambers to atmosphereensuring that no trapped pressure exists which will causepersonnel and/or equipment damage. Open valves incontrol system to have an exhaust and/or loosen hydrau-lic connections to allow leakage.

Release head by removing the lock collar and capscrew(items 3 and 4). Install two (1 1/4"-7NC) eyebolts in the topof the head in the holes provided. Use a piece of strongpipe or rod (3" -4" pipe) 12 to 14 feet long as a leveragainst the eyebolts to apply counterclockwise torque(left hand) on the head. Rotate head (approximately 10turns) to release, then lift clear of BOP. A vertical lift maybe applied to the eyebolts to take the weight of the headoff of the threads while applying torque to the head. Thislift will reduce the required opening torque. If the headwas improperly installed at the last reassembly, it may benecessary to apply considerably more torque on the headby the use of a winch or catline while alternately applyingand releasing pressure to the opening chamber (1500 psimaximum).

DO NOT attempt to loosen the head by applying heaton the thread area.5.1.2 PACKING UNIT REMOVAL (ITEM 6)Install two (5/8"-11NC) eyebolts into packing unit. Liftpacking unit out of piston. Use a sling of adequate lengthto prevent side loading of eyebolts.5.1.3 PISTON REMOVAL (ITEM 8)Install two (3/4"-10NC) eyebolts in top of piston. Gentlylift piston vertically to free from preventer body. If a verticallift is unfeasible or if the piston does not freely lift out,slowly apply low (50 psi) hydraulic pressure to the closingchamber-DO NOT USE AIR OR GAS!5.1.4 INNER BODY SLEEVE (ITEM 29)

Remove the 16 inner body sleeve capscrews (Item 35)from around the sleeve. Lift out body sleeve by hookingsling through slots. Some model BOPs have a weldedinner body sleeve which is not removable.5.1.5 OUTER BODY SLEEVE REMOVAL (ITEM 12)Remove the 16 outer body sleeve capscrews (item 13)from around the body sleeve. Lift out body sleeve.

Figure 5-1:Exploded View MSP 21 1/4"-2000 psi

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Figure 5-2:Exploded View MSP 21 1/4"-2000 psi

5.2 Assembly—Screwed Head5.2.1 CLEAN AND INSPECT ALL PARTS BEFOREASSEMBLYInspect all seals and replace any damaged seals or sealsin use over one year. Install seal rings in positions shownby cross section! Coat all seal rings and seal ring grooveswith silicon grease or castor oil prior to installation.5.2.2 INNER BODY SLEEVE INSTALLATION(ITEM 29)Install slotted body sleeve (item 29) into inside bottom ofblowout preventer body. Install 16 inner body sleevecapscrews (item 35) and torque to 120 lb-ft. Some modelBOPs have a welded body sleeve which is not removable.5.2.3 OUTER BODY SLEEVE INSTALLATION(ITEM 12)Lubricate and install O-ring (Item 14) on outer bodysleeve. Lubricate and install inner U-seals (Item 10) inseal grooves at top of outer body sleeve.

Lubricate mating surface of sleeve and body. Installsleeve in preventer body. Exercise caution to preventpinching of the O-ring between the body and sleeve. Alignsleeve with holes in the body and install 16 socket headcap screws (Item 13) and torque to 250 lb-ft.5.2.4 PISTON INSTALLATION (ITEM 8)Lubricate and install lower U-seals (item 9) in seal groovesin piston.

Lubricate and install middle U-seals (item 9) in sealgrooves in middle segment of piston.

Install two (3/4"-10NC) eyebolts in top of piston. Lubri-cate all mating surfaces and install piston into preventerbody. Ensure that vertical alignment between piston andbody is achieved prior to lowering piston. After alignmentis achieved, the weight of the piston alone will take thepiston its full normal stroke to the bottom of the preventerbody.

Remove eyebolts.5.2.5 PACKING UNIT INSTALLATION (ITEM 6)Lubricate piston bowl. Lift packing unit with two (5/8"-11NC) eyebolts and set into piston bowl.5.2.6 HEAD INSTALLATION (ITEM 1)Lubricate and install upper U-seals (item 7) in seal grooveson inside of head.

Lubricate and install head gasket (item 5) on outside ofhead just above screw threads. Clean threads of foreignmatter and check threads for burrs or rough edges. Applya generous coating of antiseize compound. This lubrica-tion will ensure easy removal at the next disassembly.

Locate and mark hole in body for the lock collar andscrew (items 3 and 4).

Lift head using the two (1 1/4" -7NC) eyebolts and chainsling assembly.

Align the lead thread of the head with the lead thread inthe body.

Screw head clockwise (right hand) into body until itshoulders against top of body. Line up lock screw hole inhead with hole in body and install head lock collar and capscrew (items 3 and 4).

Remove eyebolts from head. Preventer is ready for use/testing.

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Screwed Head BOP

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5.1 Disassembly—Latched Head5.1.1 HEAD REMOVAL (ITEM 1)Close and open the packing unit to break loose anyaccumulation of drilling fluid or debris which may berestricting full downward travel of the piston.

Vent opening and closing chambers to atmosphereensuring that no trapped pressure exists which will causepersonnel and/or equipment damage. Open valves incontrol system to have an exhaust and/or loosen hydraulicconnections to allow leakage.

Release jaws (item 17) by rotating jaw operating screws(item 18) four turns counterclockwise until jaw shouldersagainst body. Excessive torque at shouldering should beavoided to prevent thread damage.

Remove 4 head clamp screws (Item 16) and headclamps (Item 15).

Install two (1 1/4"-7NC) eyebolts in top of head. Lift headslowly and assure a good vertical alignment.5.1.2 PACKING UNIT REMOVAL (ITEM 6)Install two (5/8"-11NC) eyebolts into packing unit. Liftpacking unit out of piston. Use a sling of adequate lengthto prevent side loading of eyebolts.5.1.3 PISTON REMOVAL (ITEM 8)Install two (3/4"-10NC) eyebolts in top of piston.

Gently lift piston vertically to free from preventer body.If a vertical lift is unfeasible or if the piston does not freelylift out, slowly apply low (50 psi) hydraulic pressure to theclosing chamber—DO NOT USE AIR OR GAS!5.1.4 INNER BODY SLEEVE REMOVAL (ITEM 29)Remove the 16 inner body sleeve bolts (item 35) fromaround the body sleeve. Lift out slotted body sleeve witha sling and hooks under the slots. Some model BOPs havea welded body sleeve which is not removable.5.1.5 OUTER BODY SLEEVE REMOVAL (ITEM 12)Remove the 16 outer body sleeve capscrews (item 13)from around the body sleeve (Item 12). Lift out bodysleeve.5.1.6 JAW & JAW OPERATING SCREW ASSEMBLYREMOVAL (ITEMS 17 through 22)Hold Jaw Operating Screw (item 18) and remove the JawHolding Capscrew (item 19). Remove the Jaw OperatingScrew from the body.

The Jaws (item 17) can now be removed from inside theblowout preventer body. Mark jaw sequence to assuresame position on reassembly. If a new jaw is installedwithin a set of well worn jaws, the new jaw should bepolished to match existing jaws thereby ensuring equalload sharing.

Figure 5-4:Exploded View MSP 21-2000 psi—Latched Head BOP

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5.2 Assembly—Latched Head5.2.1 CLEAN AND INSPECT ALL PARTS BEFOREASSEMBLYInspect all seals and replace any damaged seals or sealsin use over one year.

Seal rings MUST BE installed in positions shown bycross section! Lubricate all seal rings and seal ringgrooves prior to installation (Silicon grease or castor oil isbest).5.2.2 INNER BODY SLEEVE INSTALLATION(ITEM 29)Install slotted body sleeve (item 29) into inside bottom ofblowout preventer body. Install 16 inner body sleevecapscrews (item 35) and torque to 120 lb-ft. Some modelBOPs have a welded body sleeve which is not remova-ble.5.2.3 OUTER BODY SLEEVE INSTALLATION(ITEM 12)Lubricate and install O-ring (Item 14) on outer bodysleeve. Lubricate and install inner U-seals (Item 10) inseal grooves at top of outer body sleeve.

Lubricate mating surface of sleeve and body. Installsleeve in preventer body. Exercise caution to preventpinching of the O-ring between the body and sleeve.Align sleeve with holes in the body and install 16 sockethead cap screws (Item 13) and torque to 250 lb-ft.5.2.4 PISTON INSTALLATION (ITEM 8)Lubricate and install lower U-seals (item 9) in seal groovesin piston.

Lubricate and install middle U-seals (item 9) in sealgrooves in middle segment of piston.

Install two (3/4"-10NC) eyebolts in top of piston. Lubri-cate all mating surfaces and install piston into preventerbody. Ensure that vertical alignment between piston andbody is achieved prior to lowering piston. After alignmentis achieved, the weight of the piston alone will take thepiston its full normal stroke to the bottom of the preventerbody.

Remove eyebolts.5.2.5 PACKING UNIT INSTALLATION (ITEM 6)Lubricate piston bowl.

Lift packing unit with two (5/8"-11NC) eyebolts and setinto piston bowl.

5.2.6 JAW AND JAW OPERATING SCREW ASSEM-BLY INSTALLATION (ITEMS 17 THRU 22)Install jaws (Item 17) into cavity in body with square cornerof teeth facing up and in the same sequence as disas-sembled. If a new jaw is installed within a set of well wornjaws, the new jaw should be polished to match existingjaws, thereby assuring equal load sharing.

Install 0-ring (Item 22) in the external groove of the Jawoperating screw (item 18). Install jaw operating screw intobody and screw in fully (hand tight). Do not over tightencausing jaw to extend beyond cavity in body.

Install jaw holding capscrew seal (item 20) and non-extrusion ring (item 21) on the jaw holding capscrew (item19). See drawing for placement and cross section.

Install jaw holding capscrew into jaw operating screwand screw into jaw already installed in body cavity untiltight (50 lb-ft.)

Ensure all jaws are fully retracted into cavity by rotatingjaw operating screw counterclockwise until jaws shoulderagainst body.5.2.7 HEAD INSTALLATION (ITEM 1)Lubricate and install Head O-ring (Item 24) into groove onoutside of blowout preventer head, just above the lockinggrooves.

Lubricate and install upper U-seals (item 7) in sealgrooves on inside of head.

Lubricate and install head gasket (item 5) in sealgrooves on outside of head, just below the locking grooves.

Clean and lubricate locking groove on outside diameteroif head.

Lift head (Item 1) and lower into body. Install headclamps (Item 15) and head clamp screws (Item 16) andpull head fully down until it shoulders against the BOP.

Ensure that the head is fully shouldered against thebody. Rotate the jaw operating screws clockwise tobottom jaws fully into the locking grooves in the head.Torque to about 300-400 lb-ft.

Remove eyebolts from head. Preventer is ready foruse/testing.

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Figure 5-5:Exploded View MSP 21-2000 psi—Latched Head BOP

NOTE: Seal Rings MUST BE installed in position shownby cross-section.

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Latched Head BOP

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Standard Assembly 1 15,100 10025601 Blowout Preventer Head 1 4,280 10025632 Pipe Plug, Piston Indicator 1 .06 1900065-053 Lock Collar 1 .3 10037004 Head Lock Screw 1 .25 1900049-

120125 Head Gasket 1 4 37377

▲6 Packing Unit-Natural Rubber (NR) 1 853 1003273-1Packing Unit-Nitrile Rubber (NBR) 1 856 1003273-2Packing Unit-Neoprene Rubber 1 856 1003273-3

7 U-Seal, Upper 2 3.8 373798 Piston 1 2,816 10025659 U-Seal, Lower 2 3.25 37378

10 U-Seal, Inner 2 3.25 3738011 Body 1 5,625 100256112 Body Sleeve, Outer 1 891 100256913 Capscrew, Outer Body 16 .9 1920026-

Sleeve 1602414 O-Seal, Body Sleeve 1 .75 3738129 Body Sleeve, Inner 1 322 1006144

*33 Wear Plate 1 65 1002030*34 Capscrew, Wear Plate 6 .38 1920026-

0800735 Capscrew, Inner Body 16 .50 1920026-

Sleeve 12012 ▲ Seal Set- Complete 29.5 1002571

.. . Field ReplacementSleeve Kit 50894-K

... Chain Sling Assembly 1 65 36000-M

... Eyebolt, Piston1"-8 NC x 17" Lg. 2 1.13 38872-M

... Eyebolt, Head1 1/4"-7 NC x 1 3/4" Lg. 2 4.25 32006

... Protector Plate 1 100 35999

... Capscrew, Protector Plate 4 .13 1900049-08010

6.1 Parts List — Screwed HeadApprox.Net Wt.

(Lb)Part

NumberNo.

Req.Part NameItemNo.

ACCESSORIES

▲ Recommended Spares for One Year Foreign Service.

• For converting welded sleeve on some model BOPs to boltedsleeve only. Sleeve does not interchangee with Item 4.

Figure 6-1:Screwed Head MSP 21 1/4"-2000 psi

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BOP Assembly 1 16,320 10025601 BOP Head 1 4,461 10025832 Pipe Plug, Piston Indicator 1 .06 1900065-05345 Head Gasket 1 4 1004922

▲6 Packing Unit-Natural Rubber (NR) 1 853 1003273-1Nitrile Rubber (NBR) 1 856 1003273-2Neoprene Rubber 1 856 1003273-3

7 U-Seal, Upper 2 3.8 373798 Piston 1 2,816 10025659 U-Seal, Lower 2 3.25 37378

10 U-Seal, Inner 2 3.25 3738011 BOP Body 1 6,110 1002581-AA12 Body Sleeve, Outer 1 891 100256913 Capscrew, Outer Body 16 .9 1920026-

Sleeve 1602414 O-Seal, Body Sleeve 1 .75 3738115 Head Clamp 4 .81 100235116 Head Clamp Screw 4 .62 1900041-

1402417 Jaws 20 7.88 100258418 Jaw Operating Screw 20 3.5 1002350-219 Capscrew, Jaw Holding 20 .88 1002352-220 Seal, Jaw Holding Screw 20 .03 100330021 Non-Extrusion Washer 20 .02 100235322 O-Ring, Jaw Operating 20 .06 190001-

Screw 32823 Relief Fitting 1 .02 1900085-0324 Head O-Ring 1 .77 4928329 Body Sleeve, Inner 1 322 1006144-2

*33 Wear Plate 1 65 1002030*34 Capscrew, Wear Plate 6 .38 1920026-

0800735 Capscrew, Inner Body 16 .50 1920026-

Sleeve 12012 ▲ Seal Set- Complete 29.5 1002586

.. . Field ReplacementSleeve Kit

... Chain Sling Assembly 1 65 36000-M

... Eyebolt, Piston1"-8 NC x 17" Lg. 2 1.13 38872-M

... Eyebolt, Head1 1/4"-7 NC x 1 3/4" Lg. 2 4.25 32006

... Protector Plate 1 100 35999-C

... Capscrew, Protector Plate 4 .13 1900049-08010

6.1 Parts List — Latched HeadApprox.Net Wt.

(Lb)Part

NumberNo.

Req.Part NameItemNo.

ACCESSORIES

▲ Recommended Spares for One Year Foreign Service.

• For converting welded sleeve on some model BOPs to boltedsleeve only. Sleeve does not interchangee with Item 4.

Figure 6-2:Latched Head MSP 21 1/4"-2000 psi

Order by BOPSerial Number

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6.2 Preventer StorageAt the conclusion of each well, or prior to placing theblowout preventer in storage for even a brief period, it isrecommended that the preventer be disassembled,cleaned, inspected, lubricated thoroughly with non-petroleum base oil such as castor oil or rapeseed oil, andreassembled. Replacement of worn packing units, orpackers, seal rings, and other parts can be made conve-niently at this time.

Flange or Hub faces and ring grooves should be pro-tected with wooden covers and ports should be plugged.

6.3 Rubber Goods StorageThe term rubber goods includes synthetic compoundssuch as Nitrile Copolymers and Neoprene, as well asnatural rubber parts.

The ideal storage situation for rubber goods would bein vacuum-sealed containers maintained in a cool, dry,dark storage area. The following recommendations willallow vendors and users of oil field equipment to maximizenormally available storage facilities for rubber goods.1. Keep the rubber storage area as dark as possible-preferably indoors, not outdoors, and away from directsunlight, skylights, windows, and direct, artificial lighting.2. Select a cool location (approximately 65o F) that is awayfrom heaters, stoves and direct blasts of space heaters.3. Keep rubber goods away from electrical machinery(motors, switch gear, or any high voltage equipmentproducing corona). Avoid locations susceptible to draftsthat will carry the atmosphere from electrical machinery tothe rubber goods storage area.4. The practice of first-in, first-out is essential with rubbergoods.5. Store rubber goods in a relaxed position in their normalshape. For example, do not hang O-Rings on nails. Do notkeep assemblies in stretched attitudes, e.g., O-Rings onglands, BOP testers and operators parts. For rubbergoods that must be stored in a stretched attitude, periodicinspection should be accomplished to detect aging signsas quickly as possible. Rubber goods that are stored in astretched attitude should be treated with age resistantcompounds.6. Rubber goods storage areas should be kept as dry aspossible. Remove oil, grease or other foreign materialsfrom the storage area to preclude spillage on rubbergoods.7. If storage for extended periods is anticipated, sealedcontainers are recommended. Impervious surface cov-erings such as waxing will increase shelf life.

Factors that accelerate the deterioration of rubbergoods are atmosphere, light and heat. The term “aging”means cumulative effects of all three of these attackingagents over a period of time. Other factors that will affectrubber goods include stretching or bending from normalshape, cold, chemical reactions with solvents and pe-troleum products, and exposure to electrical currents.

Exposure to the atmosphere allows oxygen, a veryactive element, to react with the rubber goods. Ozone(03), a very active form of oxygen, is especially detrimentalto rubber goods. Two principal sources of ozone contrib-

ute to rubber goods deterioration - (1) atmospheric ozone,and (2) ozone created by electrical discharges such aslightning, high voltage corona or electrical machinery.Points of strain in rubber goods are attacked first by ozoneand will be characterized by deep cracks. Ozone andnormal oxygen (02) will attack rubber goods much as steelrusts. Oxidation is characterized by a hard skin whicheventually crazes in small cracks and may turn chalky orassume a bark-like appearance.

Strong, direct light, especially sunlight, has a harmfuleffect on rubber goods. The ultraviolet content of the lightspectrum accelerates cracking. Light, especially sunlight,is undesirable and should be avoided at all times.

Heat, whether the result of sunlight, artificial or acci-dental heating, will also have harmful effects upon rubbergoods. Heat results in a gradual hardening of the rubbergoods. This process is greatly accelerated when ozone oroxygen is present.

In extremely cold climates, some rubber goods willbecome so brittle that they will shatter when dropped orhandled roughly.

Any stretching or bending of rubber goods in storagefrom a relaxed, normal shape will result in acceleratedaging or cracking.

Rubber goods, both natural and synthetic, possesssome degree of susceptibility to deterioration from varioussolvents, especially oil field liquid hydrocarbons. Thesematerials cause swelling/shrinkage of the rubber goodswith which they are in contact.

Since the aging of a rubber product is dependent uponall of the above factors plus its size, specific composition,and function, no precise figure is available for “storagelife”. Generally speaking, the greater the ratio of surfacearea to volume, the more susceptible a part is to beingrendered useless by aging. For example, a relatively largepart (by volume), such as a packing unit, might be ex-pected to have a much longer useful shelf life than a thinwalled, large-diameter O-Ring.

No general rule can be drawn regarding usability. Alarge, heavy part might suffer the same total amount ofaging as a small, light piece and still be usable, whereasthe light piece would be rendered useless. Thus, judge-ment becomes the rule and, where there is doubt, replacethe part.

Prior to using rubber goods that have been stored forperiods of time, these checks should be made:1) Is there “chalking” or “barking”?2) Has the part developed a “hard skin”?3) Do cracks appear? Do cracks appear when the part isstretched? (Sometimes cracks will be obvious; stretch orbend the part in question so that any incipient cracks orvery thin cracks will reveal themselves).4) Will a suspect part pass a hardness test with a Shore “A”Durometer? (in the event that the hardness runs 15 pointshigher than the normal hardness of the part, it is consid-ered non-usable). Note: Hardness is affected by tempera-ture, and readings should be taken with the rubber part at70o to 100o F. The hardness measurement should bemade on a flat surface of the rubber having a minimumthickness of 1/4 inch.

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OPERATOR’S MANUAL - storage.googleapis.comstorage.googleapis.com/wzukusers/user-19992182/documents...OPERATOR’S MANUAL MSP 21 1/4"-2000 psi Annular Blowout Preventer Please contact