EP2726699B1 - Blowout-preventer dichtungskonstruktion und verfahren der verwendung - Google Patents

Blowout-preventer dichtungskonstruktion und verfahren der verwendung Download PDF

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Publication number
EP2726699B1
EP2726699B1 EP12727727.5A EP12727727A EP2726699B1 EP 2726699 B1 EP2726699 B1 EP 2726699B1 EP 12727727 A EP12727727 A EP 12727727A EP 2726699 B1 EP2726699 B1 EP 2726699B1
Authority
EP
European Patent Office
Prior art keywords
seal
blade
tubular
sealing system
carriage
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Revoked
Application number
EP12727727.5A
Other languages
English (en)
French (fr)
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EP2726699A2 (de
Inventor
Perry Lee Mcclanahan
James Allen DOUTY
Richard M. Ward
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
National Oilwell Varco LP
Original Assignee
National Oilwell Varco LP
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Filing date
Publication date
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Application filed by National Oilwell Varco LP filed Critical National Oilwell Varco LP
Publication of EP2726699A2 publication Critical patent/EP2726699A2/de
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Publication of EP2726699B1 publication Critical patent/EP2726699B1/de
Revoked legal-status Critical Current
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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
    • E21B33/061—Ram-type blow-out preventers, e.g. with pivoting rams
    • E21B33/062—Ram-type blow-out preventers, e.g. with pivoting rams with sliding rams
    • E21B33/063—Ram-type blow-out preventers, e.g. with pivoting rams with sliding rams for shearing drill pipes
    • 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
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
    • E21B33/1212—Packers; Plugs characterised by the construction of the sealing or packing means including a metal-to-metal seal element

Definitions

  • This disclosure relates generally to techniques for performing wellsite operations. More specifically, this disclosure relates to techniques for preventing blowouts involving, for example, shearing a tubular and/or sealing a wellbore.
  • Oilfield operations may be performed to locate and gather valuable downhole fluids.
  • Oil rigs are positionable at wellsites, and downhole tools, such as drilling tools, are deployed into the ground to reach subsurface reservoirs.
  • downhole tools such as drilling tools
  • casings may be cemented into place within the wellbore, and the wellbore completed to initiate production of fluids from the reservoir.
  • Downhole tubular devices may be positioned in the wellbore to enable the passage of subsurface fluids to the surface.
  • BOPs blowout preventers
  • Equipment such as blowout preventers (BOPs)
  • BOPs blowout preventers
  • BOPs may have selectively actuatable rams or ram bonnets, such as pipe rams or shear rams, that may be activated to sever a tubular in a wellbore.
  • BOPs for severing tubulars are provided in U.S. Patent/Application Nos. 20110000670 ; 7,814,979 ; and 7,367,396 .
  • Seals may optionally be provided in BOPs.
  • seals are provided in US Patent/Application Nos. 13/018217 , 2012/0012339 , 2012/0012340 , 2010/243926 , and 7967299 .
  • the disclosure relates to a shear sealing system of a blowout preventer of a wellbore.
  • the wellbore has a tubular therein and the blowout preventer includes a housing having a bore and a guideway therethrough.
  • the tubular is positionable in the bore.
  • the shear sealing system includes at least one carriage slidably positionable in the guideway of the blowout preventer, at least one blade and at least one seal.
  • the blade is carried by the carriage and movable thereby between a retracted position and an extended position.
  • the blade is engageable with the tubular when in the extended position.
  • the seal forming a seal about the tubular and with the blade when the blade is in the extended position
  • the blade may include an upper blade and a lower blade and the seal may include an upper seal and a lower seal.
  • the upper blade, the lower blade, the upper seal and the lower seal may be placed in sealing engagement.
  • the seal may be positionable in the housing.
  • the seal may form a metal to metal seal with the blade.
  • the seal may be a tubular member having an outer diameter positionable along an inner diameter of the bore.
  • the seal may have a bottom surface positionable along an inner diameter of the guideway. The bottom surface may be engageable with a top surface of the blade when the blade moves to the extended position.
  • the seal may include at least one seal collar, at least one coil spring, and/or at least one elastor seal.
  • the carriage may include a base having a blade pocket for receiving the blade.
  • the base may have spars extending from a front end thereof defining a seal pocket for receiving the seal.
  • the carriage may include a plurality of carriages and the blade may include a plurality of blades. Each of the carriages may have a blade pocket for receivingly supporting a corresponding one of the seals.
  • the seal may include an elastomeric material disposable about each of the carriages.
  • the carriages may include a base having a seal pocket shaped to receivingly and sealingly engage the blades carried by the carriages.
  • the seal pocket may be defined along a top and side surfaces of the base.
  • the disclosure relates to a blowout preventer positionable about a wellbore.
  • the wellbore has a tubular therein.
  • the blowout preventer may include a housing having a bore and a guideway therethrough (with the tubular positionable in the bore), and a shear sealing system.
  • the carriage may include upper and lower carriages, the blade may include upper and lower blades and the seal may include upper and lower seals.
  • the upper seals may be positionable in the housing above the upper blades in sealing engagement therewith, and the lower seals may be positionable in the housing below the lower blades in sealing engagement therewith.
  • the upper seals may be positionable about the upper blades of the upper carriage and the lower seals may be positionable about the lower blade of the lower carriage.
  • the upper seals may be sealingly engageable with the lower blade and the lower seals sealingly engageable with the upper blades.
  • the seal may form a metal to metal seal with the blade.
  • the seal may include an elastomeric material carried by the carriage and sealable with the blade.
  • the housing may have at least one receptacle for receiving the seal.
  • the disclosure relates to a method of forming a seal about a tubular of a wellbore.
  • the method involves providing a blowout preventer including a housing having a bore and a guideway therethrough (the tubular positionable in the bore) and a shear sealing system including at least one carriage (at least one blade carried by the carriage and a seal).
  • the method also involves engaging the tubular with the blade by slidably positioning the carriage in the guideway of the blowout preventer and moving the blade between a retracted position and an extended position, and forming a seal about the tubular and between the seal and the blade when the blade is in the extended position
  • the engaging may involve shearing the tubular, and the shearing may include piercing, cutting, raking, shaving, and/or severing.
  • the blade may include an upper blade and a lower blade, and the seal an upper seal and a lower seal.
  • the forming may involve forming a seal between the upper blade, the lower blade, the upper seal and the lower seal.
  • the forming may involve sealingly engaging the upper blade with the lower seal and sealingly engaging the lower blade with the upper seal, and/or sealing engaging the upper blade with the lower seal and the lower blade with the upper seal.
  • Blowout preventers may be positioned about a tubular and provided with devices for shearing a tubular and/or sealing a wellbore. Shearing may involve piercing, cutting, raking, shaving, severing or otherwise penetrating at least a portion of the tubular. In some cases, such shearing involves advancing blades of the BOP into the tubular to break the tubular into two pieces. In some cases, such sealing may involve creating a seal about the severed tubular to prevent fluid from passing from the tubular. Such seal may be positioned about the blades used to shear the tubular.
  • Tubulars may be, for example, pipes, certain downhole tools, casings, drill pipe, liner, coiled tubing, production tubing, wireline, slickline, or other tubular members positioned in the wellbore and associated components, such as drill collars, tool joints, drill bits, logging tools, packers, and the like.
  • Such shearing and/or sealing devices may provide a metal-to-metal and/or bi-directional differential pressure barrier against, for example, extreme conditions, such as low/high pressure hydrostatic and gas media with an effect temperature range of from about -30 F (-34.40 C) through about 400 F (204.44 C) or more.
  • These devices may be intended to provide one or more of the following, among others: reduced operational force, reduced failure, reduced wear, efficient part replacement, modular components, enhanced sealing, efficient shearing, metal-to-metal sealing, incorporation into (or use with) existing equipment and less maintenance time for part replacement, operability at extreme conditions (e.g., extreme temperatures and pressures), etc.
  • Figure 1 depicts an offshore wellsite 100 having a subsea system 104 and a surface system 102.
  • the surface system 102 may be used to facilitate the oilfield operations at the offshore wellsite 100.
  • the surface system 102 may include a rig 105, a platform 106 (or vessel) and a controller 108.
  • the subsea system 104 includes a conduit 110 extending from the platform 106 to a sea floor 112.
  • the subsea system further includes a wellhead 114 with a tubular 116 extending into a wellbore 118, a BOP 120 and a controller 108.
  • the BOP 120 has a shear sealing system 124 for shearing the tubular 116 and sealing the wellbore, as will be described further herein.
  • the surface system 102 and subsea system 104 may be provided with one or more controllers 108 located at various locations to control the surface system 102 and/or the subsea system 104.
  • Communication links 126 may be provided for communication between the controllers 108 and various parts of the wellsite 100.
  • BOP 120 is described herein as being used in subsea operations, it will be appreciated that the wellsite 100 may be land or water based, and the BOP 120 and/or shear sealing system 124 may be used in any wellsite environment.
  • Figures 2A-2C depict the BOP 120 in greater detail.
  • Figures 2A and 2B show the BOP 120 in the retracted position before actuation.
  • Figure 2C shows the BOP 120 in the extended position after actuation.
  • the BOP 120 may be similar to, for example, the BOP described in U.S. Patent/Application Nos. 20110000670 ; 7,814,979 ; and 7,367,396 .
  • the BOP 120 may have a body 212 with a bore 214 extending therethrough.
  • the tubular 116 may pass through the bore 214.
  • the body 212 may have a lower flange 216 and an upper flange 218 for connecting the BOP 120 to other equipment about the wellsite, such as the wellhead 114 ( Fig. 1 ).
  • the BOP 120 may have the one or more actuators 228 for actuating the shear sealing system 124 therein, for example, in order to shear the tubular 116 and sealing the wellbore.
  • Each of the actuators 228 may move a piston 230 within a cylinder 232 in order to move a rod 234.
  • Each rod 234 may couple to a carriage 240a,b of the shear sealing system 124.
  • Each of the carriages 240a,b carries a blade 242a,b.
  • the actuators 228 may move the blades 242a,b toward and away from the bore 214 in order to shear the tubular 116 within the bore 214.
  • the actuators 228 may actuate the blades 242a,b in response to direct control from the controller(s) 108 ( Fig. 1 ), an operator, and/or a condition, such as a pressure surge, in the wellbore 118 (as shown in Figure 1 ).
  • the actuators 228 may be hydraulically operated and driven by a hydraulic system (not shown), although any suitable means for actuating the shear sealing system 124 may be used, such as pneumatic, electric, and the like.
  • One or more ram guideways (or guides) 220 and 222 may guide each of the carriages 240a,b within the BOP 120 as the actuator 228 moves the blades 242a,b.
  • the ram guideways 220 and 222 may extend outwardly from opposite sides of the bore 214.
  • Figure 2B shows a top view of the BOP 120. The carriages 240a,b are shown holding the blades 242a,b in an unactuated (or retracted) position within the ram guideways 220 and 222.
  • the blades 242a,b of carriages 240a,b may be positioned to pass one another within the bore 214 while shearing the tubular 116.
  • the pair of blades 242a,b includes an upper cutting blade 242a on the carriage 240a and a lower cutting blade 242b on the carriage 240b.
  • the blades 242a,b may be movably positioned so that the upper blade 242a passes some distance above the blade 242b when shearing the tubular 116.
  • the shearing action of cutting blades 242a,b may pierce, rake, cut, shave, sever, and/or shear the tubular 116 such that the tubular is compressed or separated into upper portion 116a and lower portion 116b.
  • the lower portion of the tubular 116b may drop into the wellbore 118 (as shown in Figure 1 ) below the BOP 120.
  • a seal assembly 243 of the shear sealing system 124 positioned in the BOP 120 may form a seal with the blades 242a,b.
  • Figures 3A-3C depict various views of a BOP 320 having a shear sealing system 324 usable for shearing the tubular 116 and/or sealing the wellbore (see, e.g., Figure 1 ).
  • Figures 3A and 3B are cross-sectional views of the BOP 320 having a bore 314 therethrough for receiving the tubular 116 (see, e.g., Figure 1 ).
  • the shear sealing system 324 includes a carriage assembly 325 movably positionable in a guideway 321, and a seal assembly 330 positioned in receptacles 331a,b in the BOP 320.
  • the guideway 321 extends into the bore 314 to enable movement of the carriage assembly 325 therein for sealing engagement with seal assembly 330 and the tubular 116.
  • the carriage assembly 325 is in a retracted (or disengaged) position.
  • the carriage assembly 325 is advanced to an extended (or engaged) position.
  • the shear sealing system 324 includes a pair of carriages 326a,b, and a pair of blades (or blade inserts) 328a,b. Each of the carriages 326a,b carries a blade 328a,b such that the blades 328a,b may be advanced to pass through the tubular 116.
  • the guideway 321 of the BOP 320 may be shaped to slidingly receive the carriages 326a,b for back and forth movement therein.
  • the carriages 326a,b may be selectively extended and retracted in the guideway 321 such that the blades 328a,b carried by the carriages 326a,b may selectively engage the tubular 116 in the bore 314.
  • the carriages 326a,b may be provided with rails 337 for slidable movement within the guideway 321.
  • the rails 337 (and other components of the shear seal assembly 324) may be replaceable.
  • each blade 328a,b may be inserted into its corresponding carriage 326a,b and secured therein by conventional means, such as bolts 329.
  • Each blade 328a,b may be positioned in the carriage 326a,b at an end near the bore 314 for engagement with the tubular 116.
  • the blades 328a,b may be the same or different blades, such as those described in U.S. Patent/Application Nos. 20110000670 ; 7,814,979 ; and 7,367,396 .
  • the blades 328a,b may have protrusions (or points) 333 to first pierce and then shear the tubular 116 during a shearing operation.
  • the carriages 326a,b may be positioned in the BOP 320 and advanced such that the blade 328a passes a distance below the blade 328b to provide shearing engagement with the tubular 116 as shown in the extended position of Figure 3B .
  • An actuator (not shown) may be used to activate the shear sealing system 324 to move the carriages and the blades in a similar manner as shown in Figures 2A-2C .
  • the blades 328a,b may also engage and form a seal with the seal assembly 330.
  • the seal assembly 330 may be positioned in the receptacles 331a,b along the bore 314 and the guideway 321.
  • the seal assembly 330 includes seal collars 332a,b, coil springs 334a,b, and elastor seals 336a,b as shown in Figure 3C .
  • Figure 3C an end view of the carriage assembly 325 is depicted adjacent a cross-sectional view of the seal assembly 330 and BOP 320.
  • the seal assembly 330 (and/or its components) may be made of metal or non-elastomeric material to prevent deterioration over time and/or under harsh conditions.
  • the upper receptacle 331a has the corresponding upper seal collar 332a, coil spring 334a and elastor seal 336a therein.
  • the lower receptacle 331b has the corresponding lower seal collar 332b, coil spring 334b and elastor seal 336b therein.
  • the coil springs 334a,b may be used to support the seal collar 332a,b against the carriages 326a,b (see, e.g., FIG. 3B ), particularly in high pressure conditions.
  • Additional seals, such as the elastor seals 336a,b may be provided for additional sealing support about the seal collar 332. Additional seals may also be positioned about the shear sealing system to further prevent leakage.
  • the upper and lower seal collars 332a,b, coil springs 334a,b, and elastor seals 336a,b may be used to cooperatively seal with the blades 328a,b to provide a seal about the bore 314.
  • a metal-to-metal seal is formed therebetween.
  • the seal collars 332a,b are perpendicular to and in sealing engagement with a seal surface 338a,b of the blades 328a,b.
  • the coil springs 334a,b may be used to provide compressive forces to maintain a constant interface between the seal collars 332a,b and seal surfaces 338a,b, for example, to provide low pressure differential seal performance.
  • Figures 4A-4C depict the shear sealing system 324 in greater detail and in a retracted, partially extended and extended position, respectively.
  • the shear sealing system 324 is depicted outside of the BOP 320 in Figures 4A-4C .
  • the carriage 326b is in an inverted and opposing position relative to the carriage 326a.
  • the upper seal collar 332a, coil spring 334a and elastor seal 336a are also inverted from the lower seal collar 332b, coil spring 334b and elastor seal 336b therein.
  • each of the carriages 326a,b includes a base 440a,b and a rod 442a,b.
  • the rods 442a,b may be coupled to an actuator (not shown), such as the actuator 228 depicted in Figure 2 .
  • the rods 442a,b are also coupled to the bases 440a,b for selective extension and retraction thereof.
  • the bases 440a,b are shaped for sliding engagement within the guideway 321 of BOP 320 (see, e.g., Figures 3A-3C ).
  • the bases 440a,b are also shaped such that they may pass adjacent to each other as shown in Figures 4B-4C and to facilitate sealing with the seal assembly 330.
  • the base 440 includes a pair of side portions 444 with a rear portion 446 therebetween.
  • the base 440 also defines a blade pocket 447 for receiving and supporting a blade 328a,b.
  • the blade pocket 447 may be configured to support the blades 328a,b such that loads are applied to the base 440 to support the blades during operation.
  • the rear portion 446 may be connected to the rod 442a,b and provide a platform for receiving the blades 328a,b.
  • the pair of side portions 444 may extend a distance beyond the rear portion 446 and/or the blades 328a,b to define spars (or supports) 445 on an end of the side portions 444 that form a seal pocket 448 therebetween for receiving the seal collars 332a,b (see, e.g., Figures 3A-3C ).
  • the seal collars 332a,b are nestled into a staging position by the spars 445 to position the seal collar 332 in a readied state of use.
  • the side portions 444 may also have a shoulder 450 for engagement with the seal collar 332.
  • the seal collar 332 has a series of ribbed convolutions 452 circumferentially positioned on an outer surface thereof for facilitating sealing therewith. These convolutions 452 may be used, for example, to help form the metal-to-metal seal profile against the mating blade seal surface in the event of interference, such as misalignment or trapped debris.
  • One or more redundant or secondary elastomeric seals may be provided to further reinforce and/or prevent leakage of the seal collar 332a,b. Such redundant seals may be used to further bias the seal collar 332a,b towards the seal surface 338a,b.
  • the metal-to-metal interface of the seal assembly 330 may be self energizing to provide support during operation.
  • Secondary elastomer seals, such as elastors 336a,b may be reactive to wellbore pressure to enhance seal characteristics as wellbore pressures increase. Positioning the components of the seal assembly 330 both above and below the carriage assembly 325 may be used to create a bidirectional seal arrangement.
  • the shear sealing system as provided herein may be provided with various features, such as modular independent components that may be replaced independently regarding service life or wear condition.
  • the shear sealing system may also provide a metal-to-metal primary sealing interface between components, such as seal assembly 330 and carriage assembly 325. Additional sealing components, such as elastors 336a,b and/or other seals (of elastomeric or other materials) may optionally be provided.
  • FIGS 5A-5D depict an alternate shear sealing system 524 usable, for example, as the shear sealing system 124 of Figure 1 .
  • the shear sealing system 524 is similar to the shear sealing system 324, except that the shear sealing system 524 includes a pair of carriages 526a,b, and a pair of blades (or blade inserts) 528a,b with seals 530a,b on the carriages 526a,b.
  • Each of the carriages 526a,b carries a blade 528a,b such that the blades 528a,b may be advanced to pass through the tubular 116.
  • each of the carriages 526a,b has a top surface 552a,b, a bottom surface 554a,b and a side surface 556a.
  • a blade pocket 558a,b is formed about the top surface 552a,b for receiving the blade 538a,b.
  • a seal pocket 560a,b is formed about the bottom surface 554a,b to receive the blade 538b,a of the other carriage 526b,a.
  • Each of the seal pockets 560a,b has a receiving edge 562a,b that conforms to the profile of the blade 538a,b it is receiving to form a seal therewith.
  • the side surfaces 556a,b extend a distance from the receiving edge 562a,b to receivingly engage sides of the blades 538a,b to extend the seal thereabout.
  • the side surfaces 556a,b may extend sufficiently to engage the seal 530b,a of the other carriage 526b,a.
  • the seals 530a,b may extend over at least a portion of each carriage 526a,b sufficient to provide a seal about the blades 538a,b and/or carriage 526a,b.
  • a seal is formed about the blades (e.g., along the cutting profile and along the sides of the blades).
  • the seals 530a,b may be made of an elastomeric material (e.g., rubber) to form a seal with the blades 528a,b.
  • Additional coverage may also optionally be provided about the BOP.
  • one or more of the seals 330 can be used alone, separately or in combination with one or more of the seals 530a,b.
  • Various combinations of the shear sealing system 324 and the shear sealing system 524 may be provided.
  • the shear sealing systems may be used in a method 670 of forming a seal about a tubular of a wellbore.
  • the method involves providing 672 a blowout preventer including a housing and a shear sealing system.
  • the housing has a bore and a guideway therethrough.
  • the tubular is positionable in the bore.
  • the shear sealing system may include at least one carriage, at least one blade carried by the carriage and at least one seal.
  • the method may also involve engaging 674 the tubular with the blade by slidably positioning the carriage in the guideway of the blowout preventer and moving 676 the blade between a retracted position and an extended position, and forming a seal about the tubular with the seal.
  • the engaging may involve shearing the tubular.
  • the shearing may involve piercing, cutting, raking, shaving, and/or severing the tubular.
  • the forming may involve sealingly engaging the upper blade with the upper seal and sealingly engaging the lower blade with the lower seal, sealingly engaging the upper blade with the lower seal and the lower blade with the upper seal, and/or forming a seal between the housing and the blade.
  • the method may be performed in any order, and repeated as desired.
  • the techniques disclosed herein can be implemented for automated/autonomous applications via software configured with algorithms to perform the desired functions. These aspects can be implemented by programming one or more suitable general-purpose computers having appropriate hardware. The programming may be accomplished through the use of one or more program storage devices readable by the processor(s) and encoding one or more programs of instructions executable by the computer for performing the operations described herein.
  • the program storage device may take the form of, e.g., one or more floppy disks; a CD ROM or other optical disk; a read-only memory chip (ROM); and other forms of the kind well known in the art or subsequently developed.
  • the program of instructions may be "object code,” i.e., in binary form that is executable more-or-less directly by the computer; in "source code” that requires compilation or interpretation before execution; or in some intermediate form such as partially compiled code.
  • object code i.e., in binary form that is executable more-or-less directly by the computer
  • source code that requires compilation or interpretation before execution
  • some intermediate form such as partially compiled code.
  • the precise forms of the program storage device and of the encoding of instructions are immaterial here. Aspects of the subject matter may also be configured to perform the described functions (via appropriate hardware/software) solely on site and/or remotely controlled via an extended communication (e.g., wireless, internet, satellite, etc.) network.
  • extended communication e.g., wireless, internet, satellite, etc.
  • one or more shear sealing systems may be used in a BOP to shear a tubular and/or seal a wellbore, and one or more carriages and blades may be used in a shear sealing system.

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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)
  • Gasket Seals (AREA)
  • Package Closures (AREA)
  • Earth Drilling (AREA)

Claims (12)

  1. Schneid-Dichtungs-System (124, 324) von einem Blowout-Preventer (120) eines Bohrlochs (118), wobei das Bohrloch ein Rohr (116) darin hat, wobei der Blowout-Preventer ein Gehäuse (212) umfasst, das eine Bohrung (214) und eine Führung (321) hindurch hat, wobei das Rohr in der Bohrung positionierbar ist, wobei das Schneid-Dichtungs-System umfasst:
    mindestens einen Schlitten (326a, b), der verschiebbar in der Führung von dem Blowout-Preventer positionierbar ist;
    mindestens eine Schneide (328a, b), die von dem mindestens einen Schlitten getragen ist und dadurch zwischen einer zurückgezogenen Position und einer ausgefahrenen Position bewegbar ist, wobei die mindestens eine Schneide an dem Rohr angreifen kann, wenn sie in der ausgefahrenen Position ist;
    dadurch gekennzeichnet, dass das Schneid-Dichtungs-System mindestens eine Dichtung (330) umfasst, die eine Dichtung um [Engl.: about] das Rohr und mit der mindestens einen Schneide bildet, wenn die mindestens eine Schneide in der ausgefahrenen Position ist, wobei die mindestens eine Dichtung mindestens eine Dichtungsmanschette (332a, b) umfasst, die in dem Gehäuse von dem Blowout-Preventer positionierbar ist;
    wobei der mindestens eine Schlitten eine Basis (440) und Seitenteile (444) umfasst, die Holme (445) haben, die sich von einem vorderen Ende der Basis aus erstrecken, wobei die Holme zwischen sich eine Dichtungsaussparung (448) definieren, um das Rohr aufzunehmen und um an den Dichtungsmanschetten anzugreifen.
  2. Schneid-Dichtungs-System nach Anspruch 1, wobei die mindestens eine Schneide eine obere Schneide (328a) und eine untere Schneide (328b) umfasst und die mindestens eine Dichtung eine obere Dichtung (332a) und eine untere Dichtung (332b) umfasst und wobei die obere Schneide, die untere Schneide, die obere Dichtung und die untere Dichtung zu einer Dichtungseingriffsanordnung positionierbar sind.
  3. Schneid-Dichtungs-System nach einem der vorhergehenden Ansprüche, wobei die mindestens eine Dichtung eine Metall-zu-Metall Dichtung mit der mindestens einen Schneide bildet.
  4. Schneid-Dichtungs-System nach einem der vorhergehenden Ansprüche, wobei die mindestens eine Dichtung in dem Gehäuse positionierbar ist.
  5. Schneid-Dichtungs-System nach einem der vorhergehenden Ansprüche, wobei die mindestens eine Dichtung ein röhrenförmiges Element ist, das einen äußeren Durchmesser hat, der entlang von einem inneren Durchmesser () von der Bohrung positionierbar ist.
  6. Schneid-Dichtungs-System nach Anspruch 5, wobei die mindestens eine Dichtung eine untere Oberfläche hat, die entlang eines inneren Durchmessers von der Führung positionierbar ist, wobei die untere Oberfläche mit einer oberen Oberfläche von der mindestens einen Schneide ineinandergreifen kann, wenn sich die mindestens eine Schneide in die ausgefahrene Position bewegt.
  7. Schneid-Dichtungs-System nach einem der vorhergehenden Ansprüche, wobei die mindestens eine Dichtungsmanschette an einer Außenoberfläche von sich Umläufe (452) hat.
  8. Schneid-Dichtungs-System nach einem der vorhergehenden Ansprüche, wobei die mindestens eine Dichtung mindestens eine Spiralfeder und/oder mindestens eine Elastordichtung (336a, b) umfasst.
  9. Schneid-Dichtungs-System nach einem der vorhergehenden Ansprüche, wobei die Basis eine Schneidenaussparung (447) hat, um die mindestens eine Schneide aufzunehmen.
  10. Schneid-Dichtungs-System nach einem der vorhergehenden Ansprüche, wobei die mindestens eine Dichtung ein elastomeres Material (530a, b) umfasst, das um [Engl.: about] jeden von den mindestens einen Schlitten angeordnet werden kann.
  11. Verfahren zum Bilden einer Dichtung um [Engl.: about] ein Rohr (116) von einem Bohrloch (118), wobei das Verfahren umfasst:
    Bereitstellen von einem Blowout-Preventer (120), umfassend:
    ein Gehäuse (212), das eine Bohrung (214) und eine Führung (321) hindurch hat, wobei das Rohr in der Bohrung positionierbar ist; und
    ein Schneid-Dichtungs-System (330), das mindestens einen Schlitten (326a, b), mindestens eine Schneide (328a, b), die von dem mindestens einen Schlitten getragen ist, und mindestens eine Dichtung (330) umfasst;
    dadurch gekennzeichnet, dass die mindestens eine Dichtung mindestens eine Dichtungsmanschette (332a, b) umfasst, die in dem Gehäuse von dem Blowout-Preventer positionierbar ist, wobei der mindestens eine Schlitten eine Basis (440) und
    Seitenteile (444) umfasst, die Holme (445) haben, die sich von einem vorderen Ende der Basis aus erstrecken, wobei die Holme wischen sich eine Dichtungsaussparung (448) definieren, um das Rohr aufzunehmen und um an den Dichtungsmanschetten anzugreifen;
    Angreifen von dem Rohr mit der mindestens einen Schneide durch das verschiebbare Positionieren von dem mindestens einen Schlitten in der Führung von dem Blowout-Preventer und das Bewegten von der mindestens einen Schneide zwischen einer zurückgezogenen Position und einer ausgefahrenen Position; und
    Bilden von einer Dichtung um [Engl.: about] das Rohr und zwischen der mindestens einen Dichtung und der mindestens einen Schneide, wenn die Schneide in der ausgefahrenen Position ist.
  12. Verfahren nach Anspruch 11, wobei die mindestens eine Schneide eine obere Schneide (328a) und eine untere Schneide (328b) umfasst und die mindestens eine Dichtung eine obere Dichtung (332a) und eine untere Dichtung (332b) umfasst und wobei das Bilden das Bilden von einer Dichtung zwischen der oberen Schneide, der unteren Schneide, der oberen Dichtung und der unteren Dichtung umfasst.
EP12727727.5A 2011-06-29 2012-06-06 Blowout-preventer dichtungskonstruktion und verfahren der verwendung Revoked EP2726699B1 (de)

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US201161502683P 2011-06-29 2011-06-29
PCT/US2012/040966 WO2013002971A2 (en) 2011-06-29 2012-06-06 Blowout preventer seal assembly and method of using same

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EP2726699B1 (de) 2011-06-29 2015-07-15 National Oilwell Varco, L.P. Blowout-preventer dichtungskonstruktion und verfahren der verwendung
CA2868524C (en) 2012-04-10 2017-02-14 National Oilwell Varco, L.P. Blowout preventer seal assembly and method of using same
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GB201310613D0 (en) 2013-06-14 2013-07-31 Enovate Systems Ltd Well bore control system
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CA2840439A1 (en) 2013-01-03

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