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Manual
OPERATOR'S MANUAL
Manual 0101A Operator's
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Compact GK® 13 5/8"-5000 psi Annular BOP
Compact GK® 13 5/8"- 5000 psi Annular Blowout Preventer
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Operator's Manual Compact GK® 13 5/8"-5000 psi Annular BOP
CONTENTS PAGE
OPERATOR QUICK REFERENCE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
3
SECTION 1.0 – INSTALLATION AND OPERATION 1.1 Principle of Operation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.2 Surface Operation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5 8
SECTION 2.0 – PHYSICAL DATA 2.1 2.2 2.3 2.4 2.5 2.6 2.7
Physical Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Bolt and Wrench Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Lubricant List . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . API Ring Joint Flange Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Clamp Hub Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Inside Dimensions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Outside Dimensions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
11 11 12 12 13 14 15
SECTION 3.0 – PACKERS AND SEALS 3.1 Packing Units . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.2 Seals . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
16 18
SECTION 4.0 – MAINTENANCE AND TESTING 4.1 Maintenance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.2 Seal Testing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.3 Packing Unit Testing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
19 20 21
SECTION 5.0 – DISASSEMBLY AND ASSEMBLY 5.1 Disassembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.2 Assembly. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
22 22
SECTION 6.0 – PARTS AND STORAGE 6.1 Parts List. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.2 Preventor Storage . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.3 Rubber Goods Storage . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
24 26 26
HYDRIL BOP SALES AND SERVICE LOCATIONS
Please contact Hydril Pressure Control Equipment for any assistance or questions concerning the information in this manual. All information contained in this manual is the exclusive property of Hydril Company LP.
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Pressure Control Equipment
©2001 Hydril Company LP
HYDRIL COMPANY LP/P.O. BOX 60458/HOUSTON, TEXAS 77205 TELEPHONE: (281) 449-2000 FAX: (281) 985-2828 / WEB: www.hydril.com Printed In The USA April 2001
Rev. A, January 2002
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Compact GK® 13 5/8"-5000 psi Annular BOP
OPERATOR QUICK REFERENCE
Standard Hookup Closing Pressure Opening Pressure
Control Pressures ▲Surface Control Pressure —psi WELL PRESSURE—psi
Initial* Closure
500
1500
2500
3500
5000
2 3/8
950
850
600
350
100
50
2 7/8"
750
650
400
150
50
50
3 1/2"
700
550
300
50
50
50
4 1/2"-5 1/2"
650
500
150
50
50
50
7"-9 5/8"
600
400
50
50
50
50
1150
1150
Pipe Size
Close cautiously to prevent collapse of casing. CSO
1150
1150
1150
1150
▲ *Use closing pressure shown at initial closure to establish seal off and reduce closing pressure proportionally as well pressure is increased. Well pressure will maintain closure after exceeding the required level. See Section 1 for control 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 tool joint passes through the packing unit.
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Operator's Manual Compact GK® 13 5/8"-5000 psi Annular BOP
ANNULAR BOP TESTING AND OPERATION Proper Procedure for pressure testing any annular blowout preventer (BOP) ensures subsequent seal off and maximum packing unit life. Reliable seal off tests are made by initially closing the packing unit with prescribed closing chamber pressure on the recommended size test pipe, proportionally reducing closing pressure as well pressure is increased, 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 seal off on the recommended size test pipe. The HYDRIL® Compact GK® 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 or test pressure increases, the closing force on the packing unit also increases. As well pressure exceeds the required level, the packing unit is maintained in the closed position on the recommended size test pipe by well pressure alone. Once initial seal off is
achieved, it is recommended that closing pressure be reduced proportionally as well pressure is increased in order to maintain the optimum closing force on the packing unit. Optimum closing forces for high well pressures may require careful application of pressure to the opening chamber. Closing pressure required to effect initial seal off may vary slightly between individual packing units. Begin the test with the recommended initial closing pressure. Piston Stroke can be measured on the Compact GK® blowout preventers through a vertical passage in the top of the BOP head. The maximum and minimum distances from the top of the head to the top of the piston are stamped on the BOP head and are also listed in the table below. Piston stroke remaining at seal off is a direct indicator of remaining packing unit life. Record the piston stroke and the closing pressure at 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.
OPERATIONAL DATA
3
Bore
13 5/8 in.
346.1 mm
Closing Chamber Volume
17.98 gal. (U.S.)
68.1 liters
Opening Chamber Volume
14.16 gal. (U.S.)
53.6 liters
Recommended Test Pipe Size
5 in.
114 mm
Full Piston Stroke
8 1/2 in.
216 mm
TAPE MEASURE
5/16" ROD 2
1
Distance From Top of Head To Top of Piston Screwed Head Maximum — Piston Full Down Minimum — Piston at Full Stroke
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13 1/2 in.
343 mm
5 in.
127 mm
Sales Headquarters / P.O. Box 60458 / Houston, Texas 77205 / Telephone: (281) 449-2000 Eastern Hemisphere / Hydril U.K. Ltd. Minto Avenue Altens Industrial Estate Aberdeen, AB1 4JZ Scotland / Telephone: +441-224-878-824 / Fax: +441-224-898-524
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Compact GK® 13 5/8"-5000 psi Annular BOP
1.0 INSTALLATION AND OPERATION 1.1 Principle of Operation
HEAD
WEAR PLATE
PACKING UNIT
OPENING CHAMBER
PISTON HOIST RING
CLOSING CHAMBER
BODY
SLOTTED BODY SLEEVE
Figure 1-1.
Cross-section of Compact GK® With Packing Unit Fully Open.
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Operator's Manual Compact GK® 13 5/8"-5000 psi Annular BOP
The HYDRIL® Compact GK® 13 5/8"-5000 blowout preventer is an annular blowout preventer which will close and seal off on drillpipe, tool joints, tubing, casing, or wireline in the wellbore or completely seal off the open hole to full rated working pressure by cornpression of a reinforced elastomer packing element (refer to API Recommended Practice 53*). Seal off is effected by raising the piston which causes the packing unit to be squeezed inward to a sealing engagement with anything in the bore or with itself on the open hole. See Figures 1-3 through 16. The piston is raised by applying hydraulic pressure to the closing chamber. The optimum closing pressure is the minimum pressure that will maintain a complete seal under existing operational conditions. Drill pipe can be rotated and tool joints stripped through a closed packing unit while maintaining a full seal on the pipe. Any normal closing unit having a separate regulator valve for the annular blowout preventers and sufficient accumulator volume can be used to operate the Compact GK® annular blowout preventer. The hydraulic operating fluid may be clean, light petroleum hydraulic oil with aniline point higher than 160oF, or water with soluble oil added. In cold climates, antifreeze should be added to prevent freezing. CAUTION: Do not use synthetic fluids or fuel oils as serious seal damage will result. The closing time of the preventer is determined by the rate at which the hydraulic fluid can be delivered to the closing chamber. Minimum closing time can be achieved by using short, large-diameter control lines and a large accumulator volume.
Packing Unit
Piston
Figure 1-2. Upward force exerted by the piston squeezes packing rubber inward into a sealing engagement. *API Recommended Practices for Blowout Prevention Equipment Systems R.P. 53 is available from the American Petroleum Institute, 1220 L Street, Northwest, Washington, DC 20005.
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Operator's Manual Compact GK® 13 5/8"-5000 psi Annular BOP
Figure 1-3.
Cutaway view of HYDRIL® Compact GK® BOP with packing unit fully open. The Compact GK opens to full bore to allow passage of large-diameter tools through open bore as well as maximum annulus flow of drilling fluids. Packing unit always returns to full open position due to normal resiliency of rubber packing unit. Retention of opening chamber pressure will ensure positive control of piston and reduce wear caused by vibration.
Figure 1-4.
Figure 1-5.
Figure 1-6.
Cutaway view of Compact GK® BOP with packing unit closed on square kelly. The packing unit seals off on square or hexagonal kellys to rated pressure.
Cutaway view of Compact GK® BOP with packing unit closed on drillpipe. The packing unit seals off on tool joints, any size pipe, casing or wireline to rated pressure.
Cutaway view of Compact GK® BOP with packing unit closed on open hole. Complete closure of packing unit safely holds well pressure, without leakage, equal to the rated working pressure of the preventer.
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Operator's Manual Compact GK® 13 5/8"-5000 psi Annular BOP
1.2 Surface Operation 1.2.1 Surface Hookup The surface hookup for the HYDRIL® Compact GK® (refer to Figure 1-7) connects the hydraulic control lines to the opening and closing chambers of the BOP. Pressure applied to the closing chamber raises the piston and causes the seal off between the packing unit and drillpipe. 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 kept closed by well pressure alone. As well pressure further increases, the closing force on the packing unit also increases. Closing pressure should be reduced proportionally as well pressure is increased in order to maintain optimum closing force on the packing unit and prolong the life of the packing unit. The control pressure graph (Figure 1-8/1-8a) shows the relationship of closing pressure and well pressure for optimum seal off. During normal drilling operations, it is recommended that the pressure regulator valve for the GK® be set at the initial closing pressure shown 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 reduced proportion-
Closing Pressure Opening Pressure
Figure 1-7.
Standard Hookup
ally as well pressure is increased. The control Pressure graph, Figure 1-8a, shows the relationship of closing pressure and well pressure required to effect optimum seal off for the GK 13 5/8"5000 BOP when supplied with the long life packing unit.
1500
▲ CLOSING PRESSURE-PSI
PAGE 8
CSO
1000 *Closing pressures are average and will vary slightly with each packing unit. Use closing pressure shown at initial closure to establish seal off 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.
500 * *7 41 "t /2" hr thr 31 u9 u5 /2" 5/8 PIP 1/2 E "P "P IPE IP E
27
/8"
PIP
23
E
/8"
PIP
E
0 0
1000
2000
3000
WELL PRESSURE-PSI
Figure 1-8.
Operating Curves – Compact
GK®
13 5/8"-5000 PSI Annular BOP
4000
5000
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Compact GK® 13 5/8"-5000 psi Annular BOP
2200 * Closing pressures are average and will vary slightly with each packing unit. Use closing pressure shown at initial closure to establish seal off 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.
▲ CLOSING PRESSURE-PSI
2000
1500 CSO
1000 5" P
IPE
27 /8" thru 3
1/2 "P IPE
23
/8"
PIP
E
500 ** 7 "P IPE
0 0
1000
2000
3000
4000
5000
WELL PRESSURE-PSI
Figure 1-8a:
Average Control Pressure – Compact GK® 13 5/8"-5000 PSI BOP, Long Life Packing Unit
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Operator's Manual Compact GK® 13 5/8"-5000 psi Annular BOP
1.2.2 Surface Stripping Operations Although not recommended as a routine practice, if necessary drillpipe can be rotated and tool joints stripped through a closed GK® packing unit while maintaining a full seal. Longest life for the packing unit is obtained by adjusting the closing chamber pressure low enough to maintain a seal on the drillpipe with a slight amount of drilling fluid leakage as the tool joint passes through the packing unit. The drilling fluid leakage indicates optimum seal off for minimum packing unit wear and provides lubrication for the drill pipe motion through the packing unit.
Surface Hookup
Slow tool joint stripping speeds reduce surge pressures and prolong packing unit life. The pressure regulator valve should be set to provide and maintain the proper control pressure. If the pressure regulator valve does not respond fast enough for effective BOP control, a surge absorber (accumulator) should be installed in the closing chamber control line adjacent to the blowout preventer. Precharge the accumulator to one-half of the closing pressure required to effect a seal off at the existing well pressure for the
Surface Hookup With Surge Absorber
Example Precharge Calculation: 500 psi well pressure, 4 1/2" - 5 1/2" drillpipe Precharge = 0.50 X Closing Pressure From Figure 1-8: Closing Pressure = 500 psi Precharge = 0.50 x 500 psi Precharge = 250 psi
Closing Pressure Opening Pressure
Figure 1-9.
Hookup for Surface Stripping Operations
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Compact GK® 13 5/8"-5000 psi Annular BOP
2.0 PHYSICAL DATA
2.1 Engineering Data 13 5/8"-5000 English
Metric
Bore .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Working Pressure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
13 5/8 inches 5000 psi
346 mm 345 Bar
Maximum Operating Pressure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Shell Test Pressure (Factory Test Only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
3000 psi 10,000 psi
207 Bar 690 Bar
Closing Chamber Test Pressure (Factory Test Only) . . . . . . . . . . . . . . . . . . . . . . . . . . . Opening Chamber Test Pressure (Factory Test Only) . . . . . . . . . . . . . . . . . . . . . . . . . .
5000 psi 5000 psi
345 Bar 345 Bar
Volume—Closing Chamber . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Volume—Opening Chamber . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
17.98 gallons 68.05 liters 14.16 gallons 53.59 liters
Piston Stroke . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hydraulic Connection, Open and Close . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
8 1/2 inches 1.0-inch NPT
216 mm
BOP Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Weight Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
11,200 lb 3,200 lb
5080 kg 1452 kg
Piston .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pad Eye Safe Working Load (Each) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
1,300 lb 15,000 lb
590 kg 6.80 tonne
2.2 Bolt and Wrench Data Ref. No.a
a b
Description
Thread
Wrench Size
Torque Lb/Ft (N•m)b
5
Cap Screw - Slotted Sleeve
3/4"-10UNRC
3/4" 12-Pt Key
50 (68)
7
Cap Screw - Wear Plate
1/2"-11UNC
3/4" Hex
50 (68)
8
Lock Screw - Head
3/4"-10UNC
1 1/4" Hex
100 (135)
...
Eyebolt - Piston
5/8"-11UNC
....
Snug
...
Eyebolt - Head
1"- 8UNC
....
Snug
...
Pipe Plug - Open & Close Ports
1"-11 1/2 NPT
3/8" Hex Key
Snug
...
Pipe Plug - Piston Indicator Port
1/2"-14 NPT
5/8" Hex Key
Snug
Refers to Figure 5-1. Torque values based on use of Never-Seize Thread Lubricant (coefficient of friction is 0.069) or equivalent.
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Compact GK® 13 5/8"-5000 psi Annular BOP
2.3 Lubricant List Seals . . . . . . . . . . . . . . . . . . . . . . . Packing Unit . . . . . . . . . . . . . . . . . Internal Metal Surfaces . . . . . . . . . BOP Body & Head Threads . . . . . Screw & Nut Threads . . . . . . . . . .
Castor Oil or Silicon Grease Castor Oil Castor Oil Zinc Base (lead-free) Tool Joint Lubricant Never-Seize Thread Lubricant (coefficient of friction = 0.069) or Equivalent
2.4 API Ring Joint Flange Data C
C
B A
Studded Flange, Using Studs.
Bolted Flange, Using Stud Bolts.
FLANGE
SEAL RING
Nominal Size Inches (MM)
Bore Dia. Inches (MM)
Max. API Service Pressure Rating PSI (BAR)
O.D. Inches (MM)
Thickness Inches (MM)
† Dia. C
13 5/8 (346)
13 5/8 (346)
5000 (345)
26 1/2 (673)
4 7/16 (113)
16.063 (408)
BX160
13 5/8 (346)
13 5/8 (346)
10,000 (690)
30 1/4 (760)
6 5/8 (168)
17.033 (433)
BX159
Inches (MM)
API Ring
BOLTS & STUDSa No. Req.
Size
Lengthb Inches (MM) Stud Bolts A
Studs B
Bolt Circle Dia. Inches (MM)
16
1 5/8-8UN
13 (330)
8 1/4 (210)
23 1/4 (591)
20
1 7/8-8UN
18 (457)
11 3/4 (298)
26 1/2 (673)
a
Bolt material shall be of a quality and strength not less than specified by ASTM A-193, Grade B7. Nuts shall be of a quality not less than ASTM A-194, Grade 2H. Stud bolts are threaded full length.
b c
Lengths shown herein are overall lengths, including point at both ends, as shown in table.
Dimensions shown are outside diameters of 6BX flange grooves.
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Compact GK® 13 5/8"-5000 psi Annular BOP
2.5 Clamp Hub Connections
J
A
C
A
G
G
B
B
E
E
F
F
H
H
HUB Hub Size Inches (MM)
Bore Size A Inches (MM)
Rated Working Pressure PSI (BAR)
Seal Ring No.
RX
BX
B
Hub Dimensions - Inches (MM) RX Only Standoff D C J
13 5/8 (346) 13 5/8 (346)
5000 (345)
...
160
20 5/8 (524)
...
...
4 7/8 (124)
13 5/8 (346) 13 5/8 (346)
10,000 (690)
...
159
22 1/4 (565)
...
...
5 3/8 (137)
NOTE: API 16A 1st Edition Nov 1, 1986 Does Not Include Clamps.
Clamp Dimensions - Inches (MM) ▲
E
F
26 3/4 (679)
31 (787)
G
H
7 11/16 (195) 9 1/4 (235)
30 3/8 (772) 35 5/8 (905) 9 1/2 (241)
10 3/8 (264)
▲ Clamp dimensions may vary from those shown.
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Operator's Manual Compact GK® 13 5/8"-5000 psi Annular BOP
2.6 Inside Dimensions
A
K
M L
H
G B
Ø
J
C D
F
E
2.6.1 Inside Dimensional Data – Inches (MM) NOMINAL DIMENSION
5000
NOMINAL DIMENSION
5000
O
21o
A
B
C
D
E
F
Bore
O.D. Upper Piston
I.D. Upper Body
I.D. Piston
I.D. Lower Body
Piston Height
13 5/8 (346)
30.25 (768)
37.50 (953)
16.25 (413)
28 (711)
23.69 (602)
G
H
J
K
L
Sleeve Top to Head Bottom
Packing Unit Height
Stroke
Head Top to Piston Top (Full Down)
Head Height
Head Top to Wear Plate Bottom
13.93 (354)
13.50 (343)
8.50 (216)
13.50 (343)
15.75 (400)
7.75 (197)
M
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Compact GK® 13 5/8"-5000 psi Annular BOP
2.7 Outside Dimensions
G
H
B
D Open Chamber F A
Close Chamber C E
2.7.1 Outside Dimensional Data – Inches (MM) NOMINAL DIMENSIONS A
B
C
D
E
F
G
H
49.84 (269)
45.25 (362)
33.19 (843)
16.65 (423)
22.69
12 (305)
52.75 (1340)
60.25 (1530)
(576)
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Operator's Manual Compact GK® 13 5/8"-5000 psi Annular BOP
3.0 PACKING UNITS AND SEALS 3.1 Packing Units The heart of the GK® blowout preventer is the packing unit (refer to Figure 3-1 and 3-1a). The unit is manufactured by Hydril from quality proprietary rubber compounds and 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
Figure 3-1 Cutaway drawing showing how rubber is molded around steel segments.
Figure 3-1a Long Life Packing Unit
confined and kept under compression, it resists tears and abrasion. All annular blowout preventer packing units are subjected to wear during closure and stripping. The design of the HYDRIL® GK® compact blowout preventer is intended to result in closure wear on the outside of the packing unit while stripping wear results on the inside. Thus, the stripping life of the packing unit is affected by wear from routine closures.
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Compact GK® 13 5/8"-5000 psi Annular BOP
3.1.1 Packing Unit Selection Because of the importance of the packing unit to the operation of the blowout preventer and to the safety of the crew and rig, only genuine HYDRIL® packing units should be used as replacements for original equipment. All HYDRIL® packing units are tested to full rated pressure inside a test blowout preventer at the factory as part of rigid standard acceptance tests before being furnished to the consumer. Packing units for HYDRIL® blowout preventers are manufactured from proprietary compounds or natural rubber, nitrile rubber, or neoprene rubber. Natural Rubber is compounded for drilling with water-base drilling fluids. Natural rubber can be used at operating temperatures between –30oF to 200oF (–35oC to 93oC). When properly applied, the compounded natural rubber packing unit will usually provide the longest service life. This all-black packing unit is identified by a serial number with the suffix R or NR (refer to Figure 3-1). 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 40oF to 180oF (4oC to 82oC). The nitrile rubber packing unit is identified by a red colored band and a serial number with the suffix S or NBR . Seals for HYDRIL® blowout preventers 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 are important for realizing the maximum life of the packing unit. Packing units should be stored in a cool, dry dark storage area. Atmosphere, light, and heat accelerate deterioration of rubber goods. It is also essential to practice first-in, first-out inventory management when storing packing units. Other significant storage factors are covered in Section 6.3 of this manual.
Flanged Steel Segments
Feedable Rubber
I.D. Band Natural Rubber-NR – No Band Nitrile Rubber-NBR – Red Band
Figure 3-1. Packing Unit Construction
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Operator's Manual Compact GK® 13 5/8"-5000 psi Annular BOP
3.1.2 Packing Unit Replacement Screwed Head The screwed head design of the GK® compact blowout preventer allows for easy replacement of the packing unit and eliminates loose parts that can be lost downhole or overboard. To replace the packing unit, refer to Figure 51 and follow Steps 5.1.1 and 5.1.3 of the "Disassembly" procedure and Steps 5.2.4 and 5.2.6 of the "Assembly" procedure.
3.1.3 Splitting Packing Units Packing unit replacement is also possible with the pipe in the hole. After removing the worn packing unit, cut the new packing unit completely and smoothly through one side between any two steel segments preferably 90o from eyebolt holes to achieve easier handing (refer to Figure 32). The cut should be made 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 the pipe as shown in Figure 3-2), drop the unit into position in blowout preventer body, and install the head. NOTE: The packing unit should be split only in the case of an emergency. The packing unit should be replaced as soon as possible with a unit that has not been split.
Figure 3-2. Proper Method for Cutting Through Packing Unit With a Sharp Knife DYNAMIC SEALS DOUBLE U-SEAL Cross-Section With Non-ExtrusionRings
STATIC SEALS SQUARE RING Cross-Section
3.2 Seals The seal rings for HYDRIL® blowout preventers are manufactured from a special synthetic rubber material for long trouble-free sealing service. To prevent seal damage, Do Not use synthetic fluids in the hydraulic operating system. The hydraulic operating fluid may be clean, light petroleum hydraulic oil with aniline point higher than 160oF, or water with soluble oil added. In cold climates, antifreeze should be added to prevent freezing. The types of seal rings used are dynamic and static (refer to Figure 3-3). The dynamic seals are double Useals with non-extrusion rings. The static seals are square ring configuration. Replacement of the seals requires disassembly and assembly of the blowout preventer as outlined in Section 5. For seal maintenance and testing, refer to Section 4.
Figure 3-3.
Seal Cross-Section.
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Compact GK® 13 5/8"-5000 psi Annular BOP
4.0 MAINTENANCE AND TESTING 4.1 Maintenance Prior to placing the GK® Compact blowout preventer into service, the following visual inspections (as noted in Figure 4-1) should be performed. 1. Inspect the 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 in a Hydril authorized machine shop. NOTE: The HYDRIL ® GK ® Compact blowout preventer is a primary pressure vessel. As supplied, the blowout preventer surfaces exposed to well bore fluids meet the requirements for H2S service. Proper handling and repair are required to maintain the original integrity. Field welding should be avoided as it induces undesirable stresses which must be relieved by proper heat treating procedures or controlled by special welding procedures. 2. Check the body for wear and damage—especially in the internal cylinder walls for pits and vertical scores. Remove minor pits and scores with emery cloth. Coat the repaired surface with silicone grease or castor oil. Severe pits and scores that require machining and/or welding must be repaired in a Hydril authorized machine shop.
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 the inner body sleeve for wear, damage, and looseness. Check slots in inner body sleeve for cuttings which may restrict piston movement. 5. Check the piston for damage and wear—especially the seal surfaces for pits and vertical scores and the tapered bowl for pits and gouges. Remove minor pits and scores on the walls with emery cloth. Coat the repaired surface with silicone grease or castor oil. Severe pits and scores that require machining and/or welding must be repaired in a Hydril authorized repair facility. Contact Hydril for nearest location. Remove sharp or rolled edges with emery cloth or a grinder. The repair is satisfactory when the surface is relatively smooth. 6. Check the wear plate in the inner bottom face of the head for wear. In addition to the results 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. Typically, wear is severe and is exhibited in the form of grooves or channels shaped by the steel segments of the packing unit. 6
1
3 7 8
5
2 8
3 4 1
Figure 4-1.
Areas and Parts Requiring Maintenance
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Operator's Manual Compact GK® 13 5/8"-5000 psi Annular BOP
The wear plate of the head serves as a bearing surface 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 requires replacement of the wear plate. 7. Inspect the packing unit for wear, cracking, hardness,
and correct elastomer composition. Refer to Section 3 for packing unit information and Section 4 for packing unit testing. 8. Check the seal rings for nicks, cuts, fraying of lips, and abrasion. Replace worn or damaged seal rings. Refer to Section 4 for seal testing.
4.2 Seal Testing When it is known or suspected that a seal within the GK® blowout preventer is leaking, it is recommended that all seals be replaced. However, if only the seal in question is to be replaced, it must first be determined which seal is leaking. To find the leaking seal, refer to Figure 4-2 and use the following procedure: Seal number callouts refer to Figure 6-1 in Parts and Storage Section. 1. Test seals 12 (middle piston) and 10 (lower piston). a. Pressure closing chamber. The test pressure to be used in the closing chamber should be the initial closing pressure required using the recommended 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 well bore—seal 10 (lower piston) is leaking. IF: Closing chamber pressure gauge is dropping and fluid is seen at opening chamber—seal 12 (middle piston) is leaking. 2. Test seals 14 (head I.D.), 12 (middle piston), and 9 (head O.D.). a. Pressurize opening chamber to 1500 PSI. b. Open closing chamber to atmosphere. IF: Fluid is seen coming from area between body and head—Seal 9 (head gasket) is leaking. IF: Fluid is seen coming into wellbore—seal 14 (head I.D.) is leaking. IF: Opening fluid is seen at closing chamber—seal 12 (middle piston) is leaking. 3. Test seals 14 (head I.D.) and 10 (lower piston). a. Open closing chamber and opening chamber to atmosphere. b. Pressurize wellbore (3000 PSI maximum). NOTE: Blind flange on top is required as packing unit is open. IF: Fluid is seen at opening chamber—seal 14 (head I.D.) is leaking. IF: Fluid is seen coming from closing chamber—seal 10 (lower piston) is leaking.
Gasket Head O.D. (9)
Dual U-Seal Head I.D. (14)
Dual U-Seal Middle Piston (12)
Dual U-Seal Lower Piston (10)
Figure 4-2.
Seal Location
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4
4.3 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.
TAPE MEASURE 3
2
5/16" (8mm) ROD
1
4.3.1 Packing Unit Testing— Surface The GK® compact 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 or test pressure is increased, the closing force on the packing unit also increases. As well pressure exceeds the required level, the packing unit is held closed on pipe by well pressure alone. During routine BOP testing, once initial seal off is achieved, closing pressure should be reduced proportionally as well pressure is increased (see Control Pressure Graph, Figure 1-8/1-8a). Piston stroke can be measured through a vertical passage in the top of the BOP head. The maximum and minimum distances from the top of the head to the top of the piston are stamped on the BOP head and are listed in the table below. 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 the BOP is achieved only when the remaining piston stroke is measured at test seal off. Distance From Top of Head to Top of Piston Piston Position
5000 PSI
Maximum (piston in full down position)
13.50 in. 343 mm
Minimum (piston at full stroke)
Figure 4-3.
.
5 in. 127 mm
Piston Stroke Measurement
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5.0 DISASSEMBLY AND ASSEMBLY 5.1 Disassembly Refer to Figure 5-1 while following this procedure. 5.1.1 Remove the Head (Item 2). 1. Close and open the packing unit to break loose any accumulation of drilling fluid or debris which may restrict the full downward travel of the piston. 2. Vent the opening and closing chambers to atmosphere ensuring that no trapped pressure exists which will cause damage to personnel and/or equipment. 3. Open valves in the control system to have an exhaust and/or loosen hydraulic connections to allow leakage. WARNING: STAND CLEAR OF ESCAPING PRESSURE TO AVOID INJURY! 4. Release the head by removing the head lock screw (item 8). 5. Install two 1 “-8UNC eyebolts in the top of the head in the holes provided. 6. Rotate the head approximately 10 turns counterclockwise to release it. Then, lift the head clear of the BOP. NOTE: Use a 10 to 12-foot long piece of strong pipe (3”-4" in diameter) or a rod as a lever against the eyebolts to apply force to the head. A vertical lift may be applied to the eyebolts to take the weight of the head off of the threads while applying force to the head. The lift will reduce the required opening force. If the head was improperly installed at the last reassembly, it may be necessary to apply considerably more force on the head by the use of a winch or catline while alternately applying and releasing pressure to the opening chamber (600 - 800 psi maximum). CAUTION: DO NOT attempt to loosen the head by applying heat on the thread area. 5.1.2 Remove the Wear Plate (Item 6). 1. Remove the cap screws (item 7) from the wear plate. 2. Remove the wear plate. 5.1.3 Remove the Packing Unit (Item 19). 1. Install two 5/8"-1 1 UNC eyebolts into the packing unit. 2. Lift the packing unit out of the piston. Use a sling of adequate length to prevent side loading of the eyebolts. 5.1.4 Remove the Piston (item 3). 1. Install two 5/8"-11UNC eyebolts in the top of piston. 2. Place a wooden spacer block (approximately 1/2" thick) between each eyebolt and the piston wall to protect the sealing surface of the piston. 3. Gently lift the piston to free it from the preventer body. If the piston does not lift out freely, slowly apply low (50 psi) hydraulic pressure to the closing chamber. CAUTION: DO NOT USE AIR OR GAS!
5.1.5 Remove the Slotted Sleeve (Item 4). 1. Remove the cap screws (item 5) from the slotted sleeve. 2. Lift out the slotted sleeve with a sling and hooks under the slots.
5.2 Assembly 5.2.1 Clean and Inspect All Parts Before Assembly. 1. Ensure that working surfaces are free of burrs, rough edges, and other defects. 2. Inspect all seals and replace any damaged seals or seals in use over one year. Hydril recommends head gasket replacement whenever the head is removed. IMPORTANT: Seal rings MUST BE installed in positions shown by the cross-section (Figure 5-1)! 3. Lubricate all seal rings prior to installation with castor oil or silicon grease. Lubricate the packing unit and internal metal surfaces with castor oil. CAUTION: Use of petroleum base oil or grease will reduce seal life. Lubricate cap screw threads with Never-Seize thread lubricant. 5.2.2 Install the Slotted Sleeve (Item 4). 1. Install the slotted sleeve into the inside bottom of the blowout preventer body. 2. Install the cap screws (item 5) and torque to 50 lb-ft (68 N•m). 5.2.3 Install the Piston (Item 3). 1. Lubricate and install the lower U-seals (items 10 and 11) into the seal grooves in the lower segment of the piston. 2. Lubricate and install the middle U-seals (items 12 and 13) in the seal grooves in the middle segment of the piston. 3. Install two 5/8"-11 UNC eyebolts in top of the piston with wooden spacer blocks between the eyebolt and the piston wall. 4. Lubricate all mating surfaces before lowering the piston into the body. 5. Install the piston into the preventer body. Align the piston vertically with the body prior to lowering the piston. After proper alignment is made, the weight of the piston alone will cause the piston to travel its full normal stroke to the bottom of the preventer body. CAUTION: Be careful to prevent seal damage during assembly. 6. Remove the eyebolts and spacer blocks. 5.2.4 Install the Packing Unit (Item 19). 1. Lubricate the piston bowl with castor oil. 2. Lift the packing unit with two 5/8”-11 UNC eyebolts and set it into the piston bowl that is already installed in the preventer.
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3.
Remove the eyebolts from packing unit.
next disassembly. Locate and mark hole in body for the head lock screw (item 8). 5. Lift the head using the two 1 “-8UNC eyebolts and a chain sling assembly. 6. Align the thread lead of the head with the thread lead in the body. 7. Screw the head clockwise into the body until it shoulders against the top of the body. 8. Line up the lock screw hole in the head with the hole in the body. 9. Install the head lock screw (item 8) and torque to 50 lbft (68 N•m). 10. Remove the eyebolts from the head. 4.
5.2.5 Install the Wear Plate (Item 6). 1. Position the wear plate on the head. 2. Install the cap screws (item 7) and torque to 50 lb-ft (68 N•m). 5.2.6 Install the Head (Item 2). 1. Lubricate and install the upper U-seals (items 14 and 15) and the head gasket (item 9) onto the head. 2. Clean any foreign matter from the threads and remove burrs or rough edges with emery cloth or light grinding. 3. Apply a generous coating of zinc base (lead-free) tool joint lubricant to the threads of the head and body. This lubrication will ensure easy removal of the head at the
Wear Plate Cap Screw (8) Pipe Plug (26) Wear Plate (7) Head Lock Screw (8) Head (2)
Head Gasket (9) Packing Unit (19)
Body (1)
Double U-Seal (14, 15) Hoist Ring (18)
Piston (3)
Double U-Seal (12, 13) Slotted Sleeve (4)
Double U-Seal (10, 11)
Figure 5-1.
Cutaway View of Compact GK® for Disassembly and Assembly
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6.0 PARTS AND STORAGE 6.1 Parts List (Figure 6-1) Item No.
Part Name
No. Req.
Part Number
1
Body
1
3129004
2
Head
1
3129023
3
Piston
1
3129027
4
Slotted Sleeve
1
3129029
5
Cap Screw, Sleeve
6
1920026-12012
6
Wear Plate
1
1001788
7
Cap Screw, Wear Plate
6
1920097-08006
8
Lock Screw, Head
1
1002149
▼ 9
Head Gasket
1
38150
▼10
U-Seal, Lower Piston
1
3129413
▼11
Non-Extrusion Ring
2
3129415
▼12
U-Seal, Middle Piston
1
3129417
▼13
Non-Extrusion Ring
2
3129419
▼14
U-Seal, Head
1
3130166
▼15
Non-Extrusion Ring
2
3130164
16
Top Connection Stud Bolt
16
1900491-13066
17
Nut, Top Connection
16
1900490-13
Hoist Ring
4
1920752-7
Packing Unit NR
1
1003263-01
18 ▼19 20
Packing Unit NBR
1
1003263-02
Name Plate
1
1920042
21
Tag, Opening Chamber
1
1002535
22
Tag, Closing Chamber
1
1002536
23
Drive Screw
12
1900061-12
24
Hydril Name Plate
1
1002390
25
Cap Screw, Name Plate
2
1900097-06006
26
Pipe Plug, Piston Indicator
1
1900065-05
Seal Kit
1
3130391
▼
ACCESSORIES —
Pipe Plug, Hyd Connection
2
1900065-07
—
Protector Cover
1
3113411-38
—
Chain Sling Assembly
1
1900179-0260
—
Lifting Device, Piston
2
3129285
—
Eyebolt, Head
2
3117168
—
Ring Gasket
2
1920103-160
▼ Recommended spares for one year foreign service. NOTE: Seal kit contains items 9 - 15. Packing Unit is not part of seal kit.
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6
7
2
26
16
8
17
9
1
15
20 14
21 22
15
23
19
24
3
25 13 12 18
13 4 11 10 11 12
Figure 6-1.
Cutaway View for Parts Identification
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6.2 Preventer Storage At the conclusion of each well or prior to placing the blowout preventer in storage for even a brief period, it is recommended that the preventer be disassembled, cleaned, inspected, lubricated thoroughly with non-petroleum base oil such as castor oil, silicon oil, or rapeseed oil, and reassembled. Replacement of worn packing units, or packers, seal rings, and other parts can be made conveniently at this time. Flange or hub faces and ring grooves should be protected with covers, and ports should be plugged.
6.3 Rubber Goods Storage The term rubber goods includes synthetic compounds such as Nitrile Copolymers and Neoprene, as well as natural rubber parts. The ideal storage situation for rubber goods would be in vacuum-sealed containers maintained in a cool, dry, dark storage area. The following recommendations will allow vendors and users of oil field equipment to maximize normally available storage facilities for rubber goods: 1. Keep the rubber storage area as dark as possible —preferably indoors, not outdoors, and away from direct sunlight, skylights, windows, and direct artificial lighting. 2. Select a cool location (approximately 65oF) that is away from heaters, stoves, and direct blasts of space heaters. 3. Keep rubber goods away from electrical machinery (motors, switch gear, or any high voltage equipment producing corona). Avoid locations susceptible to drafts that will carry the atmosphere from electrical machinery to the rubber goods storage area. 4. The practice of first-in, first-out inventory management is essential with rubber goods. 5. Store rubber goods in a relaxed position in their normal shape. For example, do not hang O-rings on nails. Do not keep assemblies in stretched attitudes, e.g., O-rings on glands, BOP testers, and operator parts. 6. Rubber goods storage areas should be kept as dry as possible. Remove oil, grease or other foreign materials from the storage area to preclude spillage on rubber goods. 7. If storage for extended periods is anticipated, sealed containers are recommended. Impervious surface coverings such as waxing will increase shelf life. Factors that accelerate the deterioration of rubber goods are atmosphere, light, and heat. The term “aging” means cumulative effects of all three attacking agents over a period of time. Other factors that will affect rubber goods include stretching or bending from normal shape, extreme cold, chemical reactions with solvents and petroleum products. Exposure to the atmosphere allows oxygen to react with the rubber goods. Ozone (O3), a very active form of oxygen, is especially detrimental to rubber goods. The principal sources of ozone contributing to rubber goods deterioration —(1) atmospheric ozone, and (2) ozone cre-
ated by electrical discharges such as lighting, high voltage corona, or electrical machinery. Points of strain in rubber goods are attacked first by ozone and will be characterized by deep cracks. Ozone and normal oxygen (O2) will attack rubber goods much as steel rusts. Oxidation is characterized by a hard skin which eventually crazes in small cracks and may turn chalky or assume a bark-like appearance. Strong, direct light, especially sunlight, has a harmful effect on rubber goods. The ultraviolet content of the light spectrum accelerates cracking. Light, especially sunlight, is undesireable and should be avoided at all times. Heat, whether the result of sunlight, artificial or accidental heating, will also have harmful effects upon rubber goods. Heat results in a gradual hardening of the rubber goods. The process is greatly accelerated when ozone or oxygen is present. In extremely cold climates, some rubber goods will become so brittle that they will shatter when dropped or handled roughly. Any stretching or bending of rubber goods in storage from a relaxed, normal shape will result in accelerated aging or cracking. Rubber goods, both natural and synthetic, possess some degree of susceptibility to deterioration from various solvents, especially oil field liquid hydrocarbons. These materials cause swelling/shrinkage of the rubber goods with which they are in contact. Since the aging of a rubber product is dependent upon all of the above factors plus its size, specific composition, and function, no precise figure is available for “storage life.” Generally, the greater the ratio of surface area to volume, the more susceptible a part is to being rendered useless by aging. For example, a relatively large part (by volume), such as a packing unit, might be expected to have a much longer useful shelf life than a thin-walled, large-diameter Oring. No general rule can be drawn regarding usability. A large, heavy part might suffer the same total amount of aging as a small, light piece and still be usable, whereas the light piece would be rendered useless. Thus, judgement becomes the rule and where there is doubt - replace the part. Prior to using rubber goods that have been stored for periods 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 is stretched? (Sometimes cracks will be obvious; stretch or bend the part in question so that any incipient cracks or very thin cracks will be revealed). 4. Will suspect part pass a hardness test with a Shore “A” Durometer? (In the event that the hardness runs 15 points higher than the normal hardness of the part, it is considered nonusable). NOTE: Hardness is affected by temperature, and readings should be taken with the rubber part at 70o to 100oF. The hardness measurement should be made on a flat surface of the rubber part having a minimum thickness of 1/4 inch.
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Worldwide Sales, Service, and Manufacturing Operator's Manual ® Canada, Alberta, Calgary
United Kingdom, Villhermosa Compact GK 13 Mexico, 5/8"-5000 psi Annular BOP
Sales Office Hydril Canadian Company, Ltd. First Executive Centre 350 7th Avenue S.W., Suite 3000 Calgary, Alberta T2P3N9 Canada Telephone: (403) 531-1590 Fax: (403) 264-0585
Sales Office, Field Service Hydril S.A. de C.V. Av. Gregorio Mendez #836 Colonia Centro 1 Villahermosa, Tabasco Mexico 86000 Telephone: +52-931-449-44 +52-931-449-42 Fax: +52-931-225-06
Aberdeen, Scotland
Nigeria, Port Harcourt
U.S.A., Alaska, Anchorage
Hydril International Tubular Sales Minto Avenue Altens Industrial Estate Aberdeen, AB1 3JZ Scotland Telephone: +44-1224-299-554 Fax: +44-1224-299-578
Canada, Alberta, Edmonton Sales Office, Field Service, Manufacturing Plant Hydril Canadian Company, Ltd. 2307 8th Street Nisku, Alberta T9E7Z3 Canada Telephone: (403) 955-2045 Fax: (403) 955-7627
Indonesia, Batam Manufacturing Plant P.T. Hydril Indonesia Kabil Industrial Estate Jl. Hang Kesturi 1 Kav. 23 & 24 Kabil - Batam Indonesia Telephone: 62-778-711318 Fax: 62-778-711112
Mexico, Mexico City Sales Office, Field Service Hydril S.A. de C.V. Genova 20-302 Col. Juarez C.P. 06600 Mexico, D.F. Mexico Telephone: +52-5-208-7208 Fax: +52-5-208-7861
Mexico, Ciudad del Carmen Sales Office, Field Service Hydril S.A. de C.V. Calle 38 x 61 Num. 263 Cd. del Carmen, Campeche C.P. 24120 Telehone: +52-938-21085; +52-938-210523 Fax: +52-938-26942
Mexico, Renosa Sales Office, Field Service Hydril S.A. de C.V. Chihuahua No. 1192-A esq. Culiacan Col. Rodriguez, Reynosa Tamaulipas C.P. 88630 Mexico Telephone: +52-89-252360 +52-89-252361 Fax: +52-89-252362
Sales Office, Field Service Hydril Africa/TDPS 4 Evergreen Street Ogbonda Estate Port Harcourt Nigeria Telephone: 234-84-332281 (Pressure) 234-84-611201 (Tubular) Fax: 871-762-154-648
Nigeria, Warri Sales Office, Field Service Service Center Hydril Africa/TDPS F21 Idugboe Estate Ogunu, Warri Nigeria Telephone: 234-53-252-565 (Pressure) 871-762-154-478 (Tubular) Fax: 871-762-154-480
Republic of Singapore, Singapore Sales Office, Field Service, Hydril Private Ltd. 27 Benoi Sector Singapore 629859 Republic of Singapore Telephone: +65-261-2566 Fax: +65-261-2502 (Pressure) +65-261-0204 (Tubular)
United Kingdom, Aberdeen, Scotland Sales Office, Field Service, Manufacturing Plant Hydril U.K. Ltd. Minto Avenue Altens Industrial Estate Aberdeen, AB1 3JZ Scotland Telephone: +44-1224-878-824 Fax: +44-1224-898-524
Sales Office, Field Service, Hydril Company 7900 King Street Anchorage, AK 99518 Telephone: (907) 522-2550 Fax: (907) 522-1995
U.S.A., California Bakersfield Sales Office, Field Service, Service Center Hydril Company 3237 Patton Way Bakersfield, CA 93308-5717 Telephone: (661) 588-9332 Fax: (661) 588-2550
U.S.A., Louisiana, Lafayette Sales Office, Field Service, Service Center Hydril Company 101 Derick Road Broussard, LA 70518-7114 Telephone: (318) 837-6654 Fax: (318) 837-8988
U.S.A., Louisiana, Westwego Manufacturing Plant Hydril Company 201 Klein Westwego, LA 70094 Telephone: (504) 348-3348 Fax: (504) 348-3629
U.S.A., Texas, Corpus Christi Sales Office, Field Service, Hydril Company 730-F Diamond Cut Road Corpus Christi, TX 78409 Telephone: (512) 289-5031 (Pressure) (512) 289-5034 (Tubular) Fax: (512) 289-0258
U.S.A., Texas, Houston Hydril Elastomer & Industrial Products Manufacturing Plant Hydril Company P.O. Drawer 1888 Humble, TX 77347-1888 18000 Eastex Freeway Humble, TX 77347-1888 Telephone: (281) 446-0041 Fax: (281) 446-4709
U.S.A., Texas, Houston Hydril Technology Center, Sales Office, Field Service, Manufacturing Plant Hydril Company P.O. Box 60458 Houston, TX 77205-0458 3300 N. Sam Houston Parkway E. Houston, TX 77032-3411 Telephone: (281) 449-2000 Fax: (281) 985-2828 Toll Free: (800) 231-0023
U.S.A., Texas, Houston Field Service, Manufacturing McCarty Plant Hydril Company 302 McCarty Drive Houston, TX 77029 Telephone: (713) 672-3502 Fax: (713) 672-3525
U.S.A., Texas, Houston Manufacturing Valvcon Manufacturing Plant Hydril Company 3300 N. Sam Houston Parkway E. Houston, TX 77032-3411 Telephone: (281) 449-2000 Fax: (281) 985-3262
U.S.A., Texas, Odessa Permian Sales Office, Field Service, Hydril Company 8317 Andrews Highway Odessa, TX 79768 Telephone: (915) 552-7850 Fax: (915) 366-6501
U.S.A., Wyoming, Casper Sales Office, Service Center Hydril Company P.O. Box 124 Casper, WY 82602 3501 North Poplar Casper, WY 82601 Telephone: (307) 266-2120 Fax: (307) 234-2192
Venezuela, Puerto La Cruz Mexico, Veracruz Manufacturing Plant Hydril S.A. de C.V. Av. Araucarias Mz. XII Lote 1 Cd. Industrial Bruno Pagliai Veracruz, C.P. 91697 Mexico Telephone: +52-29-810213 Fax: +52-29-810102
Headquarters Hydril Company P.O. Box 60458 • Houston, TX 77205-0458 3300 N. Sam Houston Parkway E. • Houston, TX 77032-3411 Telephone: (281) 449-2000 • Fax: (281) 985-2828 R
1-800-999-1601 Toll Free in the U.S.A. and Canada www.hydril.com
Sales Office, Field Service Av. Intercomunal C.C. Colonial, Piso 1, Oficina 7 Barcelona, Anzoatequi Venezuela Telephone: +58-81-762083 +58-81-741651 Fax: +58-81-761-271
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Operator's Manual
OPERATOR'S MANUAL
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Compact GK® 13 5/8"-5000 psi Annular BOP
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Pressure Control Equipment
