US20230035783A1 - Method for a 20 KSI BOP Stack with shared differential - Google Patents
Method for a 20 KSI BOP Stack with shared differential Download PDFInfo
- Publication number
- US20230035783A1 US20230035783A1 US17/386,764 US202117386764A US2023035783A1 US 20230035783 A1 US20230035783 A1 US 20230035783A1 US 202117386764 A US202117386764 A US 202117386764A US 2023035783 A1 US2023035783 A1 US 2023035783A1
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- United States
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- sealing element
- blowout preventer
- lower sealing
- pressure
- relief valve
- Prior art date
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- Abandoned
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- 238000000034 method Methods 0.000 title claims abstract description 14
- 238000007789 sealing Methods 0.000 claims abstract description 52
- 238000013022 venting Methods 0.000 claims abstract 2
- 238000005553 drilling Methods 0.000 description 25
- 238000012360 testing method Methods 0.000 description 4
- 239000000463 material Substances 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 2
- 238000005755 formation reaction Methods 0.000 description 2
- 238000011068 loading method Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 238000013459 approach Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 235000012489 doughnuts Nutrition 0.000 description 1
- 210000002445 nipple Anatomy 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000012858 resilient material Substances 0.000 description 1
Images
Classifications
-
- 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
-
- 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
- E21B33/038—Connectors used on well heads, e.g. for connecting blow-out preventer and riser
-
- 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/02—Valve arrangements for boreholes or wells in well heads
Definitions
- the drilling mud will continue to travel back outside the drill pipe and inside the drilling riser, which is much large than the casing.
- the drilling riser has to be large enough to pass the casing strings run into the well, as well as the casing hangers which will suspend the casing strings.
- the bore in a contemporary riser will be at least twenty inches in diameter. It additionally has to be pressure competent to handle the pressure of the weighed mud, but does not have the same pressure requirement as the blowout preventer stack itself.
- the subsurface pressure and therefore the pressure which the blowout preventer stack must be able to withstand becomes greater and greater. This is the same for drilling on the surface of the land and subsea drilling on the surface of the seafloor.
- Early subsea blowout preventer stacks were of a 5,000 p.s.i. working pressure, and over time these evolved to 10,000 and 15,000 p.s.i. working pressure. As the working pressure of components becomes higher, the pressure holding components naturally become both heavier and taller. Additionally, in the higher pressure situations, redundant components have been added, again adding to the height.
- the 15,000 blowout preventer stacks have become in the range of 800,000 lbs. and 80 feet tall.
- blowout preventer stack working pressure is increased to 20,000 p.s.i. some estimates of the load is that it increases from 800,000 to 1,200,000 lbs. The height also increases, but how much is unclear at this time but it will likely approach 100 feet in height.
- a second complication is that a 20,000 p.s.i. working pressure requires a 30,000 p.s.i. test pressure. As the actual stresses in material is greater than the bore pressure, the differential between the actual stress level and the yield strength of the material becomes much narrower. Imagine for a 15,000 p.s.i. component the maximum stress is 32,000 p.s.i. at working pressure and 48,000 p.s.i. at the 22,500 p.s.i. required test pressure. If the best reasonably available material has a 75,000 p.s.i. yield strength at that point you are working with a 1.56/1 factor. If you simply increase the working pressure to 20,000 p.s.i. with a 30,000 p.s.i. test pressure, the stress at test pressure goes to 72,000 p.s.i. which has barely a 1.04/1 safety factor. With the complications of stress analysis, even doubling the weight of the components will not get the stress levels back down to a reasonable level.
- a second object of this invention is to vent the pressure on one blowout preventer above its rating to a downstream blowout preventer.
- a third object of this invention is to make the pressure differential between two blowout preventer rams in series adjustable.
- Another object of this invention is to make the differential seen by two blowout preventers in series equal.
- FIG. 1 is a view of a contemporary deep-water riser system.
- FIG. 2 is a perspective view of a blowout preventer stack utilizing the features of this invention.
- FIG. 5 is a perspective view of the upper portion of the blowout preventer stack of FIG. 2 , generally called the lower marine riser package or LMRP.
- FIG. 7 is a view of the blowout preventer stack of FIG. 2 , taken along lines “ 7 - 7 .
- FIG. 8 is a view of the blowout preventer stack of FIG. 2 , taken along lines “ 8 - 8 .
- FIG. 9 is a top view of FIG. 8 .
- FIG. 10 is cross section view of a double blowout preventer.
- FIG. 1 a view of a system 20 which might use the present invention is shown. It shows a floating vessel 22 on a body of water 24 and having a derrick 26 . Drill pipe 28 , drilling mud system 30 , control reel 32 , and control cable 34 are shown. A riser system 40 including a flex joint 42 is shown. During drilling the drilling mud circulated from the drilling mud system 30 , up the standpipe 44 , down the drill pipe 28 , through the drill bit 46 , back up through the casing strings 48 and 50 , through the blowout preventer stack 60 , up thru the riser system 40 , and out the bell nipple at 62 back into the mud system 30 .
- Blowout preventer stack 60 is landed on a subsea wellhead system 64 landed on the seafloor 66 .
- the blowout preventer stack 60 includes pressurized accumulators 68 , kill valves 70 , choke valves 72 , choke and kill lines 74 , choke and kill connectors 76 , choke and kill flex means 78 , and control pods 80 .
- the seafloor drilling system 100 comprises a lower blowout preventer stack 102 , a lower marine riser package 104 , a drilling riser joint 106 , and control cables 108 .
- FIG. 3 a subsea wellhead is shown which the seafloor drilling system lands on. It is the unseen upper portion of the subsea wellhead system 64 shown in FIG. 1 .
- the lower blowout preventer stack 102 comprises a lower structural section 120 , vertical support bottle 122 , and upper structural section 124 , accumulators 126 , choke and kill valves 128 , blowout preventers 130 and an upper mandrel 132 which will be the connection point for the lower marine riser package.
- the lower marine riser package 104 is shown comprising a lower marine riser package structure 140 , an interface 142 for a remotely controlled vehicle (ROV), annular blowout preventers 146 , choke and kill flex loops 148 , a flexible passageway 150 , a riser connector 152 , and an upper half of a riser connector 154 .
- ROV remotely controlled vehicle
- a drilling riser joint 106 is shown having a lower half of a riser connector 160 , a upper half of a riser connector 154 , and buoyancy sections 162 .
- FIG. 7 is a view of seafloor drilling system 100 taken along lines “ 7 - 7 ” of FIG. 1 showing wellhead connector 170 , lower marine riser connector 172 , a man 174 for size perspective, and choke and kill valves 176 .
- FIG. 8 is a view of seafloor drilling system 100 taken along lines “ 8 - 8 ” of FIG. 1 .
- FIG. 9 is a top view of seafloor drilling system 100 .
- blowout preventer 200 having a lower thick-walled body section 202 capable of withstanding 20,000 p.s.i., an upper thinner walled body section 204 capable of handling 10,000 p.s.i., a central bore 206 , a lower sealing element 208 , and upper sealing element 210 , a port 212 from the central bore below the lower ram 208 to a relief valve 214 set to a 10,000 p.s.i. pressure differential, and a port 216 to the central bore 218 between the lower sealing element 208 and the upper sealing element 210 .
- the sealing elements can be of a variety of types, with the most likely being such as the annular sealing elements shown in U.S. Pat. No. 3,572,627.
- Relief valve 214 can be remotely controlled as is illustrated by line 220 going to controller 222 in a different pattern such as the differential being evenly divided between the sealing elements such that at a 10,000 p.s.i. total differential each of the sealing elements withstand is the stress of a 5,000 p.s.i. differential.
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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)
Abstract
In a blowout preventer stack with two sealing elements which will not individually withstand the desired pressure differential the method of withstanding the desired pressure differential comprising providing a lower sealing element and an upper sealing element, providing a vent port in the bore below the lower sealing element to a relief valve, venting the outlet of the relief valve to the bore between the lower sealing element and the upper sealing element, adjusting the relief valve to limit the pressure allowed below the lower sealing element to a predetermined amount equal to or less than the working pressure of the lower sealing element.
Description
- This invention relates to the method of providing a 20,000 p.s.i. blowout preventer stack by using a shared pressure differential on components which cannot individually be rated to 20,000 p.s.i.
- Not applicable.
- Not applicable
- Not applicable
- Deepwater offshore drilling requires that a vessel at the surface be connected through a drilling riser and a large blowout preventer stack to the seafloor wellhead. The seafloor wellhead is the structural anchor piece into the seabed and the basic support for the casing strings which are placed in the well bore as long tubular pressure vessels. During the process of drilling the well, the blowout preventer stack on the top of the subsea wellhead provides the second level of pressure control for the well. The first level being provided by the weighted drilling mud within the bore.
- During the drilling process, weighted drilling mud circulates down a string of drill pipe to the drilling bit at the bottom of the hole and back up the annular area between the outside diameter of the drill pipe and the inside diameter of the drilled hole or the casing, depending on the depth.
- Coming back up above the blowout preventer stack, the drilling mud will continue to travel back outside the drill pipe and inside the drilling riser, which is much large than the casing. The drilling riser has to be large enough to pass the casing strings run into the well, as well as the casing hangers which will suspend the casing strings. The bore in a contemporary riser will be at least twenty inches in diameter. It additionally has to be pressure competent to handle the pressure of the weighed mud, but does not have the same pressure requirement as the blowout preventer stack itself.
- As wells are drilled into progressively deeper and deeper formations, the subsurface pressure and therefore the pressure which the blowout preventer stack must be able to withstand becomes greater and greater. This is the same for drilling on the surface of the land and subsea drilling on the surface of the seafloor. Early subsea blowout preventer stacks were of a 5,000 p.s.i. working pressure, and over time these evolved to 10,000 and 15,000 p.s.i. working pressure. As the working pressure of components becomes higher, the pressure holding components naturally become both heavier and taller. Additionally, in the higher pressure situations, redundant components have been added, again adding to the height. The 15,000 blowout preventer stacks have become in the range of 800,000 lbs. and 80 feet tall. This provides enormous complications on the ability to handle the equipment as well as the loadings on the seafloor wellhead. In addition to the direct weight load on the subsea wellheads, side angle loadings from the drilling riser when the surface vessel drifts off the well centerline are an enormous addition to the stresses on both the subsea wellhead and the seafloor formations.
- When the blowout preventer stack working pressure is increased to 20,000 p.s.i. some estimates of the load is that it increases from 800,000 to 1,200,000 lbs. The height also increases, but how much is unclear at this time but it will likely approach 100 feet in height.
- A second complication is that a 20,000 p.s.i. working pressure requires a 30,000 p.s.i. test pressure. As the actual stresses in material is greater than the bore pressure, the differential between the actual stress level and the yield strength of the material becomes much narrower. Imagine for a 15,000 p.s.i. component the maximum stress is 32,000 p.s.i. at working pressure and 48,000 p.s.i. at the 22,500 p.s.i. required test pressure. If the best reasonably available material has a 75,000 p.s.i. yield strength at that point you are working with a 1.56/1 factor. If you simply increase the working pressure to 20,000 p.s.i. with a 30,000 p.s.i. test pressure, the stress at test pressure goes to 72,000 p.s.i. which has barely a 1.04/1 safety factor. With the complications of stress analysis, even doubling the weight of the components will not get the stress levels back down to a reasonable level.
- Another complication is that the annular style blowout preventer which have the ability to seal on anything in the bore have been characteristically pressure limited, with 10,000 p.s.i. being the highest presently achieved working pressure rating. The large mass of rubber in the donut around the pipe simply fails at that point.
- This has been a problem especially since the working pressure of blowout preventers have exceeded 10,000 p.s.i. as the 15,000 and 20,000 p.s.i. differentials across the sealing elements has not been sustainable. The standard industry solution to this point is to accept the inability of annular blowout preventers to seal at this high pressure and to solely depend on the capabilities and limitations of ram blowout preventers when the pressure differential exceeded 10,000 p.s.i.
- The object of this invention is to give the capability of 15,000 and 20,000 p.s.i blowout preventer stacks to be fully related to 15,000 and 20,000 p.s.i. respectively.
- A second object of this invention is to vent the pressure on one blowout preventer above its rating to a downstream blowout preventer.
- A third object of this invention is to make the pressure differential between two blowout preventer rams in series adjustable.
- Another object of this invention is to make the differential seen by two blowout preventers in series equal.
-
FIG. 1 is a view of a contemporary deep-water riser system. -
FIG. 2 is a perspective view of a blowout preventer stack utilizing the features of this invention. -
FIG. 3 is a perspective view of a subsea wellhead housing which the blowout preventer stack of this invention would land on. -
FIG. 4 is a perspective view of the lower portion of the blowout preventer stack ofFIG. 2 , generally called the lower BOP stack. -
FIG. 5 is a perspective view of the upper portion of the blowout preventer stack ofFIG. 2 , generally called the lower marine riser package or LMRP. -
FIG. 6 is a perspective view of a section of the drilling riser which will be used to lower the blowout preventer stack. -
FIG. 7 is a view of the blowout preventer stack ofFIG. 2 , taken along lines “7-7. -
FIG. 8 is a view of the blowout preventer stack ofFIG. 2 , taken along lines “8-8. -
FIG. 9 is a top view ofFIG. 8 . -
FIG. 10 is cross section view of a double blowout preventer. - Referring now to
FIG. 1 , a view of asystem 20 which might use the present invention is shown. It shows a floatingvessel 22 on a body ofwater 24 and having aderrick 26.Drill pipe 28,drilling mud system 30,control reel 32, and controlcable 34 are shown. Ariser system 40 including a flex joint 42 is shown. During drilling the drilling mud circulated from thedrilling mud system 30, up the standpipe 44, down thedrill pipe 28, through thedrill bit 46, back up through the casing strings 48 and 50, through theblowout preventer stack 60, up thru theriser system 40, and out the bell nipple at 62 back into themud system 30. -
Blowout preventer stack 60 is landed on asubsea wellhead system 64 landed on theseafloor 66. Theblowout preventer stack 60 includespressurized accumulators 68, killvalves 70, chokevalves 72, choke and killlines 74, choke and killconnectors 76, choke and kill flex means 78, andcontrol pods 80. - Referring now to
FIG. 2 , theseafloor drilling system 100 comprises a lowerblowout preventer stack 102, a lowermarine riser package 104, a drilling riser joint 106, andcontrol cables 108. - Referring now to
FIG. 3 , a subsea wellhead is shown which the seafloor drilling system lands on. It is the unseen upper portion of thesubsea wellhead system 64 shown inFIG. 1 . - Referring now to
FIG. 4 , the lowerblowout preventer stack 102 comprises a lowerstructural section 120,vertical support bottle 122, and upperstructural section 124,accumulators 126, choke and killvalves 128,blowout preventers 130 and anupper mandrel 132 which will be the connection point for the lower marine riser package. - Referring now to
FIG. 5 the lowermarine riser package 104 is shown comprising a lower marineriser package structure 140, aninterface 142 for a remotely controlled vehicle (ROV),annular blowout preventers 146, choke and killflex loops 148, aflexible passageway 150, ariser connector 152, and an upper half of ariser connector 154. - Referring now to
FIG. 6 , a drilling riser joint 106 is shown having a lower half of ariser connector 160, a upper half of ariser connector 154, andbuoyancy sections 162. - Referring now to
FIG. 7 , is a view ofseafloor drilling system 100 taken along lines “7-7” ofFIG. 1 showing wellhead connector 170, lowermarine riser connector 172, aman 174 for size perspective, and choke and killvalves 176. - Referring now to
FIG. 8 , is a view ofseafloor drilling system 100 taken along lines “8-8” ofFIG. 1 . - Referring now to
FIG. 9 , is a top view ofseafloor drilling system 100. - Referring now to
FIG. 10 ,blowout preventer 200 is shown having a lower thick-walled body section 202 capable of withstanding 20,000 p.s.i., an upper thinnerwalled body section 204 capable of handling 10,000 p.s.i., acentral bore 206, alower sealing element 208, andupper sealing element 210, aport 212 from the central bore below thelower ram 208 to arelief valve 214 set to a 10,000 p.s.i. pressure differential, and aport 216 to thecentral bore 218 between thelower sealing element 208 and theupper sealing element 210. When both thelower sealing element 208 and theupper sealing element 210 are closed, any pressure up to 10,000 p.s.i. will be sealed by thelower sealing element 208 and theupper sealing element 210 will not see any pressure differential. As the pressure differential exceeds 10,000 p.s.i., therelief valve 214 will begin to relieve the excess pressure and theupper sealing element 210 will seal all excess pressures above the 10,000 p.s.i. The sealing elements can be of a variety of types, with the most likely being such as the annular sealing elements shown in U.S. Pat. No. 3,572,627. - As 10,000 p.s.i. differential across the
lower sealing element 208 puts very high stresses in the resilient materials, it may be preferable to distribute the pressure differential differently that a full 10,000 p.s.i. across the lower sealing element before beginning to load the upper sealing element.Relief valve 214 can be remotely controlled as is illustrated byline 220 going tocontroller 222 in a different pattern such as the differential being evenly divided between the sealing elements such that at a 10,000 p.s.i. total differential each of the sealing elements withstand is the stress of a 5,000 p.s.i. differential. - The particular embodiments disclosed above are illustrative only, as the invention may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the invention. Accordingly, the protection sought herein is as set forth in the claims below.
Claims (9)
1. In a blowout preventer stack with a bore and with two sealing elements which will not individually withstand the desired pressure differential,
a method of withstanding the desired pressure differential comprising
providing a lower sealing element and an upper sealing element,
providing a vent port in the bore below the lower sealing element to a relief valve,
venting the outlet of the relief valve to the bore between the lower sealing element and the upper sealing element,
adjusting the relief valve to limit the pressure allowed below the lower sealing element to a predetermined amount equal to or less than the working pressure of the lower sealing element.
2. The method of claim 1 , further comprising the upper sealing element and the lower sealing element are in the same blowout preventer body.
3. The method of claim 2 , further comprising the upper sealing element and the lower sealing element are in the same blowout preventer body and the portion of the blowout preventer body housing the lower sealing element is of a higher working pressure than the portion of the blowout preventer body housing the upper sealing element.
4. The method of claim 1 , further comprising the upper sealing element and the lower sealing element are in different blowout preventer bodies.
5. The method of claim 4 , further comprising the upper sealing element and the lower sealing element are in separate blowout preventer bodies and blowout preventer body housing the lower sealing element is of a higher working pressure than the blowout preventer body housing the upper sealing element.
6. The method of claim 1 , further comprising the relief valve is remotely controllable.
7. The method of claim 1 , further comprising the sealing elements are the sealing element of an annular blowout preventer.
8. The method of claim 1 , further comprising the sealing elements are the rams of a ram style blowout preventer.
9. The method of claim 1 , further comprising one of the sealing elements is the sealing element of an annular blowout preventer and one of the sealing elements is the sealing element of an annular blowout preventer.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
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US17/386,764 US20230035783A1 (en) | 2021-07-28 | 2021-07-28 | Method for a 20 KSI BOP Stack with shared differential |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
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US17/386,764 US20230035783A1 (en) | 2021-07-28 | 2021-07-28 | Method for a 20 KSI BOP Stack with shared differential |
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US20230035783A1 true US20230035783A1 (en) | 2023-02-02 |
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US17/386,764 Abandoned US20230035783A1 (en) | 2021-07-28 | 2021-07-28 | Method for a 20 KSI BOP Stack with shared differential |
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Citations (10)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2986367A (en) * | 1957-01-25 | 1961-05-30 | Cameron Iron Works Inc | Valve |
US4508313A (en) * | 1982-12-02 | 1985-04-02 | Koomey Blowout Preventers, Inc. | Valves |
US20110036560A1 (en) * | 2009-08-13 | 2011-02-17 | Vail Iii William Banning | Long-lasting hydraulic seals for smart shuttles, for coiled tubing injectors, and for pipeline pigs |
US20130140035A1 (en) * | 2011-11-11 | 2013-06-06 | Trevor Paul Deacon Smith | Systems And Methods For Collecting Hydrocarbons Vented From A Subsea Discharge Site |
US20130192847A1 (en) * | 2011-10-07 | 2013-08-01 | Thomas F. Bailey | Seal assemblies in subsea rotating control devices |
US20140196953A1 (en) * | 2001-08-19 | 2014-07-17 | James E. Chitwood | Drilling apparatus |
US20140262310A1 (en) * | 2013-03-12 | 2014-09-18 | Albert Michael Regan | Riser tension augmentation |
US20170114606A1 (en) * | 2015-10-27 | 2017-04-27 | Weatherford Technology Holdings, Llc | Radial seal pressure reduction using internal pump |
US20210108486A1 (en) * | 2019-10-11 | 2021-04-15 | Halliburton Energy Services, Inc. | Multi-ball valve assembly |
GB2588737A (en) * | 2015-01-13 | 2021-05-05 | Halliburton Energy Services Inc | Downhole pressure maintenance system using reference pressure |
-
2021
- 2021-07-28 US US17/386,764 patent/US20230035783A1/en not_active Abandoned
Patent Citations (10)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2986367A (en) * | 1957-01-25 | 1961-05-30 | Cameron Iron Works Inc | Valve |
US4508313A (en) * | 1982-12-02 | 1985-04-02 | Koomey Blowout Preventers, Inc. | Valves |
US20140196953A1 (en) * | 2001-08-19 | 2014-07-17 | James E. Chitwood | Drilling apparatus |
US20110036560A1 (en) * | 2009-08-13 | 2011-02-17 | Vail Iii William Banning | Long-lasting hydraulic seals for smart shuttles, for coiled tubing injectors, and for pipeline pigs |
US20130192847A1 (en) * | 2011-10-07 | 2013-08-01 | Thomas F. Bailey | Seal assemblies in subsea rotating control devices |
US20130140035A1 (en) * | 2011-11-11 | 2013-06-06 | Trevor Paul Deacon Smith | Systems And Methods For Collecting Hydrocarbons Vented From A Subsea Discharge Site |
US20140262310A1 (en) * | 2013-03-12 | 2014-09-18 | Albert Michael Regan | Riser tension augmentation |
GB2588737A (en) * | 2015-01-13 | 2021-05-05 | Halliburton Energy Services Inc | Downhole pressure maintenance system using reference pressure |
US20170114606A1 (en) * | 2015-10-27 | 2017-04-27 | Weatherford Technology Holdings, Llc | Radial seal pressure reduction using internal pump |
US20210108486A1 (en) * | 2019-10-11 | 2021-04-15 | Halliburton Energy Services, Inc. | Multi-ball valve assembly |
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