US3496999A - Self-contained benthonic blowout prevention control apparatus and method - Google Patents

Self-contained benthonic blowout prevention control apparatus and method Download PDF

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US3496999A
US3496999A US699001A US3496999DA US3496999A US 3496999 A US3496999 A US 3496999A US 699001 A US699001 A US 699001A US 3496999D A US3496999D A US 3496999DA US 3496999 A US3496999 A US 3496999A
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valve
blowout
vessel
blowout prevention
assembly
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Paul Robert Rowley
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Atlantic Richfield Co
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/06—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers
    • E21B33/064—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers specially adapted for underwater well heads
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
    • E21B33/0355—Control systems, e.g. hydraulic, pneumatic, electric, acoustic, for submerged well heads

Definitions

  • This application relates to the control of fluid operated equipment on the ocean floor during drilling operations conducted from a floating vessel through a riser extending between the ocean floor and the vessel.
  • Hydraulic fluid is stored in a benthos reservoir, from which it is pumped to a group of accumulators by a motor pump assembly.
  • the pressurized hydraulic fluid is piped through a valve and manifold assembly to the individual components of the blowout preventer stack.
  • the valve and manifold assembly consists of a series of electrically actuated valves which control the fluid applied to the individual blowout preventer units, and which are electrically controlled from the vessel to provide means for controlling the blowout preventers from the vessel.
  • the reservoir, accumulators, and motor pump assembly are each arranged annularly around the lower end of the riser adjacent the blowout preventer stack.
  • Ocean floor drilling equipment such as blowout preventers, latching mechanisms, etc.
  • blowout preventers, latching mechanisms, etc. are normally controlled by fluid pressure applied through hoses extending between the vessel and the individual blowout preventer units.
  • hoses are shown, for example, in US. Patent No. 3,236,- 308 to Leake. Relatively high fluid pressure is normally maintained in these hoses and they frequently fail under Working and flexure conditions at such pressures.
  • Replacement of the hoses to the individual blowout preventers is costly in that it is time consuming and requires the use of divers, or in deep water installations may require retrieval of the blowout prevention equipment to the vessel for replacement of the hoses.
  • a well 10 is drilled in a water covered formation 12 from a floating drilling vessel 14 in the conventional manner and a blowout preventer stack 16 installed at the ocean bottom on the lower end of a riser 18 which extends from the vessel to the well opening.
  • the blowout prevention equipment, referred to generally as 16 is conventional equipment which may be fluid or hydraulically operated through control hoses extending from a valve and manifold assembly 20 to the individual blowout preventers 22 and 24.
  • the valve and manifold assembly receives hydraulic fluid from a series of annularly spaced accumulators 26 which are manifolded together and receive pressurized hydraulic fluid from motor-pump assembly 27 which is arranged annularly around sub 29.
  • blowout preventers 22 and 24 are individually controlled by an electrical cable 32 extending between the valve and manifold assembly and the vessel 14 and containing suflicient wires to serve each of the blowout preventer units.
  • the valve and manifold assembly may also be used to regulate the hydraulic control fluid to other benthos well head equipment, e.g. kill line valve 50.
  • the accumulators 26 receive pressurized hydraulic fluid from water pump assembly 27.
  • the motor-pump assembly 27 shown in cutaway view, may contain several vertically oriented motors and pumps and a pressure switch in an oil-filled annular space between the riser sub 29 and an outer casing 33.
  • the pumps within the motor-pump assembly 27 are small but relatively high pressure pumps driven by electrical motors which receive electrical energy through the electrical cable 35 which extends to the vessel with electrical cable 32.
  • the motor pump assembly has two lines, one line 37 to the reservoir 31, and line 57 leading to the oil side of the accumulators.
  • the annular reservoir 31 may be of any suitable design such as a sleeve-type bladder 39 within the annular space between reservoir casing 41 and the riser sub 43.
  • a line 45 provides fluid communication between the valve and manifold assembly 20 and the reservoir 31 to release the hydraulic pressure from the blowout preventer units.
  • the surface pipe 34 may first be run and cemented in any conventional manner. Normally a base 36 is lowered on the drill string (not shown) and set on the ocean bottom 12 and the well drilled sufficiently to receive the surface pipe 34. The surface pipe is then guided into the hole on the guidelines 38 with a bit guide (not shown) and hung with a landing mandrel 35 attached to the upper end of the surface pipe, either on the base 38 or a conductor pipe, and the surface pipe is then cemented to the formation 12.
  • the surface pipe may be run into the hole on a conventional safety release joint 42 which preferably is internally actuatable.
  • the blowout preventer stack 16 is attached to the lower end of the riser 18 with a conventional safety release joint 40 and run until the lower end of the blowout preventer stack is latched to the upper end of the surface casing mandrel 35 with safety release joint tool 42. Drilling is conducted by operating through the riser 18, a drill pipe (not shown) having a bit on its lower end. Conventional rotary equipment (not shown) is positioned on the vessel for rotating the drill pipe.
  • the blowout preventer stack 16 as shown includes a double Shaffer gate 24 and a Hydril bag-type blowout preventer 22.
  • Each of the units 22 and 24 are hydraulically controlled through their control hoses 22a and 24a, respectively, which interconnect these units with the valve and manifold assembly 20.
  • a kill line valve 50 is shown on the casing of the blowout preventer 24 for injection of weighting mud through a kill line for killing the well in the event of a high pressure condition below.
  • the valve and manifold assembly 20 consists of a group of remotely actuable valves 46 which control the flow of hydraulic pressure from the accumulators 26 to the hydraulically controlled units 22 and 24.
  • a valve 46 which is shown in the cutaway portion of valve and manifold assembly 20, is actuated from the vessel through electrical conductors in cable 32, to admit, for example, hydraulic pressure from the accumulators 26 to the Hydril unit 22 to close the Hydril rubber seal element (not shown) around the drill pipe in the conventional manner.
  • the valve and manifold assembly 20 contains sufficient valves 46 to control each of the hydraulically operated units in the blowout preventer stack 16.
  • valves are positioned in an oilfilled annular space within the external protective casing or cylinder 48.
  • the valve and manifold assembly 20 has eight hydraulic lines or hoses connected thereto, two each for the operation of units 22 and 24 and the kill line 50a and one line connected to hydraulic fluid reservoir, and a line 54 interconnecting the valve and manifold assembly with the annular accumulator manifold 56.
  • the accumulator assembly comprises sufl'icient accumulators 26 necessary to store the amount of energy required.
  • An accumulator may be a conventional accumulator which is essentially a high-pressure vessel with a diaphragm inside which separates hydraulic fluid from a high pressure gas, the purpose of the accumulator being merely to store energy in a compressed gas.
  • the expansion of the gas forces hydraulic fluid through the control lines when the switch valves 46 in the valve and manifold assembly 20 are opened.
  • three accumulators are symmetrically spaced around a riser sub and manifolded together at the outlet 56 and inlet manifold 58.
  • the annular manifolds may serve as connecting means which are aflixed to the riser pipe sub 60 in any convenient manner, as with a bracket on a frame supporting the annular manifold.
  • the line 54 between the accumulators and the valve and manifold assembly may be a solid pipe.
  • a flexible charging line 57 conveys a high pressure fluid from the motor pump assembly to the manifolded accumulators 26.
  • the accumulator assembly, the motor pump assembly 27, the reservoir 31, and each of the blowout preventer elements 22 and 24 may be considered part of the riser in that they have a central opening which is contiguous with the central opening of the riser pipe 18.
  • These units are arranged on special subs, for example, the accumulator sub 60 which is flanged at 64 and 66 above and below, respectively.
  • Electrical controls on the boat permit remote operation of the valves and valve and manifold assembly 20 and the motor pump assembly 27 to permit remote control of the various hydraulically controlled units 22, 24, and kill line valve 50.
  • a system for controlling blowout prevention equipment aflixed to the lower end of a riser extending between a formation underlying a body of water and a structure proximate the surface of said water comprising in combination:
  • valve and manifold assembly proximate said blowout prevention equipment arranged and constructed to control the flow of hydraulic fluid from said accumulators to said blowout prevention equipment through hydraulic control valves, said valve and manifold assembly being in fluid communication with said accumulators and said reservoir, and
  • valve and manifold assembly is connected to said blowout prevention equipment to provide for discharge of hydraulic fluid from said blowout prevention equipment.
  • a system for controlling blowout prevention equipment aflixed to the lower end of a riser extending between a formation underlying a body of water and a structure proximate the surface of said water comprising in combination:

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Description

Feb. 24, 1970 P. R. ROWLEY 3,496,999
SELF-CONTAINED BENTHONIC BLOWOUT PREVENTION CONTROL APPARATUS AND METHOD Filed Dec. 26, 1967 INVENTOR. PAUL l3. ROM/LE) BYMM ATTORNEK United States Patent SELF-CONTAINED BENTHONIC BLOWOUT PRE- VENTION CONTROL APPARATUS AND METHOD Paul Robert Rowley, Long Beach, Calif., assignor to At lantic Richfield Company, Philadelphia, Pa., a corporation of Pennsylvania Filed Dec. 26, 1967, Ser. No. 699,001 Int. Cl. E21b 7/12 US. Cl. 166.5 4 Claims ABSTRACT OF THE DISCLOSURE This application relates to the control of fluid operated equipment on the ocean floor during drilling operations conducted from a floating vessel through a riser extending between the ocean floor and the vessel. Hydraulic fluid is stored in a benthos reservoir, from which it is pumped to a group of accumulators by a motor pump assembly. From the accumulators, the pressurized hydraulic fluid is piped through a valve and manifold assembly to the individual components of the blowout preventer stack. The valve and manifold assembly consists of a series of electrically actuated valves which control the fluid applied to the individual blowout preventer units, and which are electrically controlled from the vessel to provide means for controlling the blowout preventers from the vessel. The reservoir, accumulators, and motor pump assembly are each arranged annularly around the lower end of the riser adjacent the blowout preventer stack.
Ocean floor drilling equipment, such as blowout preventers, latching mechanisms, etc., are normally controlled by fluid pressure applied through hoses extending between the vessel and the individual blowout preventer units. Such hoses are shown, for example, in US. Patent No. 3,236,- 308 to Leake. Relatively high fluid pressure is normally maintained in these hoses and they frequently fail under Working and flexure conditions at such pressures. Replacement of the hoses to the individual blowout preventers is costly in that it is time consuming and requires the use of divers, or in deep water installations may require retrieval of the blowout prevention equipment to the vessel for replacement of the hoses. Having a multiplicity of hoses running from the vessel to the ocean floor increases the incidence of failure and also gives rise to hose entangling which often requires the services of a diver for untanglement. The elimination of all high pressure hydraulic hoses from the vessel to the ocean floor equipment is desirable to avoid the aforementioned complications. Accordingly, it is considered desirable to provide a system for controlling benthos blowout prevention equipment by supplying only electrical energy to the benthos well head equipment.
It is an object of my present invention to provide a system for drilling from a floating vessel with the blowout prevention equipment positioned on the ocean floor without the need for high pressure, hydraulic control lines extending between the vessel and the benthos equipment.
It is also an object of my present invention to provide a system for drilling a benthos well from a floating vessel with the blowout prevention hydraulic control equipment located on the ocean floor, but operated remotely from the vessel.
It is a further object of my present invention to provide a system for drilling an underwater well from a 3,496,999 Patented F eb. 24, 1970 floating drilling vessel, with the hydraulic control fluid stored and distributed to the individual blowout preventers from equipment positioned on the lower end of the riser pipe proximate the ocean floor.
Other objects and a more complete understanding of my present invention will be appreciated by reference to the drawing wherein an offshore drilling arrangement is shown diagrammatically with the floating drilling vessel arranged over the benthos well.
Referring more particularly to the drawings, a well 10 is drilled in a water covered formation 12 from a floating drilling vessel 14 in the conventional manner and a blowout preventer stack 16 installed at the ocean bottom on the lower end of a riser 18 which extends from the vessel to the well opening. The blowout prevention equipment, referred to generally as 16, is conventional equipment which may be fluid or hydraulically operated through control hoses extending from a valve and manifold assembly 20 to the individual blowout preventers 22 and 24. The valve and manifold assembly receives hydraulic fluid from a series of annularly spaced accumulators 26 which are manifolded together and receive pressurized hydraulic fluid from motor-pump assembly 27 which is arranged annularly around sub 29. The blowout preventers 22 and 24 are individually controlled by an electrical cable 32 extending between the valve and manifold assembly and the vessel 14 and containing suflicient wires to serve each of the blowout preventer units. In addition to the blowout preventers, the valve and manifold assembly may also be used to regulate the hydraulic control fluid to other benthos well head equipment, e.g. kill line valve 50.
The accumulators 26 receive pressurized hydraulic fluid from water pump assembly 27. The motor-pump assembly 27, shown in cutaway view, may contain several vertically oriented motors and pumps and a pressure switch in an oil-filled annular space between the riser sub 29 and an outer casing 33. The pumps within the motor-pump assembly 27 are small but relatively high pressure pumps driven by electrical motors which receive electrical energy through the electrical cable 35 which extends to the vessel with electrical cable 32. The motor pump assembly has two lines, one line 37 to the reservoir 31, and line 57 leading to the oil side of the accumulators. The annular reservoir 31 may be of any suitable design such as a sleeve-type bladder 39 within the annular space between reservoir casing 41 and the riser sub 43. A line 45 provides fluid communication between the valve and manifold assembly 20 and the reservoir 31 to release the hydraulic pressure from the blowout preventer units.
As a typical manner of installing and operating the system of the present invention, the surface pipe 34 may first be run and cemented in any conventional manner. Normally a base 36 is lowered on the drill string (not shown) and set on the ocean bottom 12 and the well drilled sufficiently to receive the surface pipe 34. The surface pipe is then guided into the hole on the guidelines 38 with a bit guide (not shown) and hung with a landing mandrel 35 attached to the upper end of the surface pipe, either on the base 38 or a conductor pipe, and the surface pipe is then cemented to the formation 12. The surface pipe may be run into the hole on a conventional safety release joint 42 which preferably is internally actuatable.
The blowout preventer stack 16 is attached to the lower end of the riser 18 with a conventional safety release joint 40 and run until the lower end of the blowout preventer stack is latched to the upper end of the surface casing mandrel 35 with safety release joint tool 42. Drilling is conducted by operating through the riser 18, a drill pipe (not shown) having a bit on its lower end. Conventional rotary equipment (not shown) is positioned on the vessel for rotating the drill pipe.
The blowout preventer stack 16 as shown includes a double Shaffer gate 24 and a Hydril bag-type blowout preventer 22. Each of the units 22 and 24 are hydraulically controlled through their control hoses 22a and 24a, respectively, which interconnect these units with the valve and manifold assembly 20.
A kill line valve 50 is shown on the casing of the blowout preventer 24 for injection of weighting mud through a kill line for killing the well in the event of a high pressure condition below.
The valve and manifold assembly 20 consists of a group of remotely actuable valves 46 which control the flow of hydraulic pressure from the accumulators 26 to the hydraulically controlled units 22 and 24. Hence when it is desired to close the blowout preventer 22 to seal around the drill pipe, a valve 46 which is shown in the cutaway portion of valve and manifold assembly 20, is actuated from the vessel through electrical conductors in cable 32, to admit, for example, hydraulic pressure from the accumulators 26 to the Hydril unit 22 to close the Hydril rubber seal element (not shown) around the drill pipe in the conventional manner. The valve and manifold assembly 20 contains sufficient valves 46 to control each of the hydraulically operated units in the blowout preventer stack 16. Preferably the valves are positioned in an oilfilled annular space within the external protective casing or cylinder 48. In the embodiment shown, the valve and manifold assembly 20 has eight hydraulic lines or hoses connected thereto, two each for the operation of units 22 and 24 and the kill line 50a and one line connected to hydraulic fluid reservoir, and a line 54 interconnecting the valve and manifold assembly with the annular accumulator manifold 56.
The accumulator assembly comprises sufl'icient accumulators 26 necessary to store the amount of energy required. An accumulator may be a conventional accumulator which is essentially a high-pressure vessel with a diaphragm inside which separates hydraulic fluid from a high pressure gas, the purpose of the accumulator being merely to store energy in a compressed gas. The expansion of the gas forces hydraulic fluid through the control lines when the switch valves 46 in the valve and manifold assembly 20 are opened. As shown in the drawing, three accumulators are symmetrically spaced around a riser sub and manifolded together at the outlet 56 and inlet manifold 58. The annular manifolds may serve as connecting means which are aflixed to the riser pipe sub 60 in any convenient manner, as with a bracket on a frame supporting the annular manifold. The line 54 between the accumulators and the valve and manifold assembly may be a solid pipe. A flexible charging line 57 conveys a high pressure fluid from the motor pump assembly to the manifolded accumulators 26.
The accumulator assembly, the motor pump assembly 27, the reservoir 31, and each of the blowout preventer elements 22 and 24 may be considered part of the riser in that they have a central opening which is contiguous with the central opening of the riser pipe 18. These units are arranged on special subs, for example, the accumulator sub 60 which is flanged at 64 and 66 above and below, respectively.
Hence, it can be readily seen by my invention that only electrical energy is provided to the ocean floor drilling equipment, thus eliminating hydraulic connections between the vessel and the ocean floor and eliminating a source of diver expense.
Electrical controls on the boat permit remote operation of the valves and valve and manifold assembly 20 and the motor pump assembly 27 to permit remote control of the various hydraulically controlled units 22, 24, and kill line valve 50.
While my invention is described with reference to an electrical device which would normally utilize a solenoid to actuate the valves 46 in the assembly 20, it is also within the scope of my present invention to employ electronic equipment which would eliminate the need for the electrical cable 32.
While my present invention has been described herein with respect to certain specific apparatus, it is to be understood that various modifications in my invention may be made by substitution of equivalent components without departing from the spirit of my invention, and hence my invention should be afforded the full scope of the appended claims.
I claim:
1. A system for controlling blowout prevention equipment aflixed to the lower end of a riser extending between a formation underlying a body of water and a structure proximate the surface of said water, comprising in combination:
(a) an accumulator assembly including a plurality of accumulators manifolded together proximate said blowout prevention equipment,
(b) a hydraulic motor-pump assembly positioned proximate said accumulator assembly with a line interconnecting said accumulator assembly with said motor-pump assembly,
(c) a hydraulic fluid reservoir in fluid communication with said motor-pump assembly,
(d) a valve and manifold assembly proximate said blowout prevention equipment arranged and constructed to control the flow of hydraulic fluid from said accumulators to said blowout prevention equipment through hydraulic control valves, said valve and manifold assembly being in fluid communication with said accumulators and said reservoir, and
(e) means for actuating said valves remotely to control said blowout prevention equipment from said structure.
2. The apparatus of claim 1 wherein said motor-pump assembly, said reservoir, said accumulator assembly, and said valve and manifold assembly are arranged annularly around each riser.
3. The apparatus of claim 1 wherein said valve and manifold assembly is connected to said blowout prevention equipment to provide for discharge of hydraulic fluid from said blowout prevention equipment.
4. A system for controlling blowout prevention equipment aflixed to the lower end of a riser extending between a formation underlying a body of water and a structure proximate the surface of said water, comprising in combination:
(a) a motor-pump assembly positioned proximate said blowout prevention equipment,
(b) means for supplying electrical energy to said motor-pump assembly from said structure,
(0) a hydraulic fluid reservoir annularly arranged around said riser proximate with said motor-pump assembly and in fluid communication therewith,
(d) a series of accumulators arranged proximate said motor-pump assembly and in fluid communication therewith whereby said motor-pump assembly pumps hydraulic fluid from said reservoir to said accumulators,
(e) means for distributing pressurized hydraulic fluid from said accumulators to said blowout prevention equipment, and
(f) means for remotely actuating said blowout prevention equipment from said structure.
(References on following page) 5 6 References Cited 3,219,118 11/1965 Lewis 166.6
UNITED STATES PATENTS 3,333,302 8/1967 H by 3064735 11/1962 B er t l 166 6 3,339,632 9/1967 L v 1s 1 r J an e a I 3,163,224 12/1964 Haeberet a1 166.6 5387 10/1968 et a1 1 166 5 X 3,186,486 6/1965 Rhodes et a1 5 CHARLES E. OCONNELL, Primary Examiner 3,199,595 8/1965 Lafitte et a1. 166.6
3,21 Hoch Assistant Examiner
US699001A 1967-12-26 1967-12-26 Self-contained benthonic blowout prevention control apparatus and method Expired - Lifetime US3496999A (en)

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Cited By (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3743013A (en) * 1970-02-25 1973-07-03 Inst Francais Du Petrole New device for the storage and use of hydraulic and/or pneumatic power, particularly for operation of submerged well heads
US3889747A (en) * 1973-07-23 1975-06-17 Regan Offshore Int Telescopic riser tensioning apparatus
DE2525817A1 (en) * 1974-06-10 1976-01-02 Chevron Res CONTROL SYSTEM FOR HYDRAULIC OPERATION
US3955621A (en) * 1975-02-14 1976-05-11 Houston Engineers, Inc. Riser assembly
FR2385887A1 (en) * 1977-04-01 1978-10-27 Tecnomare Spa CONTROL SYSTEM FOR SUBWELL HEADS
US4234043A (en) * 1977-10-17 1980-11-18 Baker International Corporation Removable subsea test valve system for deep water
FR2796105A1 (en) * 1999-07-08 2001-01-12 Elf Exploration Prod Charging underwater hydraulic pressure accumulator so the pressure difference between the inside and outside can be kept constant during immersion
US20090194290A1 (en) * 2007-08-09 2009-08-06 Dtc International, Inc. Control system for blowout preventer stack
US20110088913A1 (en) * 2009-10-16 2011-04-21 Baugh Benton F Constant environment subsea control system
US20120305258A1 (en) * 2011-06-06 2012-12-06 Benton Frederick Baugh Method for increasing subsea accumulator volume
US20190112893A1 (en) * 2017-10-13 2019-04-18 Onesubsea Ip Uk Limited Fluid tolerant subsea manifold system

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US3064735A (en) * 1959-08-17 1962-11-20 Shell Oil Co Wellhead assembly lock-down apparatus
US3163224A (en) * 1962-04-20 1964-12-29 Shell Oil Co Underwater well drilling apparatus
US3186486A (en) * 1959-02-24 1965-06-01 Mcevoy Co Well completion
US3199595A (en) * 1961-12-28 1965-08-10 Shell Oil Co Secondary control system for underwater wells
US3211223A (en) * 1961-12-26 1965-10-12 Phillips Petroleum Co Underwater well completion
US3219118A (en) * 1962-01-12 1965-11-23 Hydril Co Submarine well head tool servicing apparatus
US3338302A (en) * 1964-08-24 1967-08-29 Texaco Inc Control system for sub-sea apparatus
US3339632A (en) * 1964-01-21 1967-09-05 Hydril Co Underwater connector
US3405387A (en) * 1965-10-24 1968-10-08 Stewart & Stevenson Inc Jim Acoustical underwater control apparatus

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3186486A (en) * 1959-02-24 1965-06-01 Mcevoy Co Well completion
US3064735A (en) * 1959-08-17 1962-11-20 Shell Oil Co Wellhead assembly lock-down apparatus
US3211223A (en) * 1961-12-26 1965-10-12 Phillips Petroleum Co Underwater well completion
US3199595A (en) * 1961-12-28 1965-08-10 Shell Oil Co Secondary control system for underwater wells
US3219118A (en) * 1962-01-12 1965-11-23 Hydril Co Submarine well head tool servicing apparatus
US3163224A (en) * 1962-04-20 1964-12-29 Shell Oil Co Underwater well drilling apparatus
US3339632A (en) * 1964-01-21 1967-09-05 Hydril Co Underwater connector
US3338302A (en) * 1964-08-24 1967-08-29 Texaco Inc Control system for sub-sea apparatus
US3405387A (en) * 1965-10-24 1968-10-08 Stewart & Stevenson Inc Jim Acoustical underwater control apparatus

Cited By (18)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3743013A (en) * 1970-02-25 1973-07-03 Inst Francais Du Petrole New device for the storage and use of hydraulic and/or pneumatic power, particularly for operation of submerged well heads
US3889747A (en) * 1973-07-23 1975-06-17 Regan Offshore Int Telescopic riser tensioning apparatus
DE2525817A1 (en) * 1974-06-10 1976-01-02 Chevron Res CONTROL SYSTEM FOR HYDRAULIC OPERATION
DK155446B (en) * 1974-06-10 1989-04-10 Chevron Res PLANT FOR REMOTE CONTROL OF HYDRAULIC APPLIANCES IN AN UNDERGROUND BROWN REMOVAL
US3955621A (en) * 1975-02-14 1976-05-11 Houston Engineers, Inc. Riser assembly
FR2385887A1 (en) * 1977-04-01 1978-10-27 Tecnomare Spa CONTROL SYSTEM FOR SUBWELL HEADS
US4234043A (en) * 1977-10-17 1980-11-18 Baker International Corporation Removable subsea test valve system for deep water
FR2796105A1 (en) * 1999-07-08 2001-01-12 Elf Exploration Prod Charging underwater hydraulic pressure accumulator so the pressure difference between the inside and outside can be kept constant during immersion
US20090194290A1 (en) * 2007-08-09 2009-08-06 Dtc International, Inc. Control system for blowout preventer stack
US8020623B2 (en) 2007-08-09 2011-09-20 Dtc International, Inc. Control module for subsea equipment
US8820410B2 (en) 2007-08-09 2014-09-02 Dtc International, Inc. Control system for blowout preventer stack
US20110088913A1 (en) * 2009-10-16 2011-04-21 Baugh Benton F Constant environment subsea control system
US20120305258A1 (en) * 2011-06-06 2012-12-06 Benton Frederick Baugh Method for increasing subsea accumulator volume
US20150354309A1 (en) * 2011-06-06 2015-12-10 Reel Power Licensing Corp Method for increasing subsea accumulator volume
US9291036B2 (en) * 2011-06-06 2016-03-22 Reel Power Licensing Corp. Method for increasing subsea accumulator volume
US9885221B2 (en) * 2011-06-06 2018-02-06 Reel Power Licensing Corp. Method for increasing subsea accumulator volume
US20190112893A1 (en) * 2017-10-13 2019-04-18 Onesubsea Ip Uk Limited Fluid tolerant subsea manifold system
US10745995B2 (en) * 2017-10-13 2020-08-18 Onesubsea Ip Uk Limited Fluid tolerant subsea manifold system

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