US20140110611A1 - Blowout preventer seal assembly and method of using same - Google Patents
Blowout preventer seal assembly and method of using same Download PDFInfo
- Publication number
- US20140110611A1 US20140110611A1 US14/129,511 US201214129511A US2014110611A1 US 20140110611 A1 US20140110611 A1 US 20140110611A1 US 201214129511 A US201214129511 A US 201214129511A US 2014110611 A1 US2014110611 A1 US 2014110611A1
- Authority
- US
- United States
- 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.)
- Abandoned
Links
- 238000000034 method Methods 0.000 title claims description 24
- 238000007789 sealing Methods 0.000 claims abstract description 84
- 238000010008 shearing Methods 0.000 claims description 21
- 239000002184 metal Substances 0.000 claims description 15
- 238000005520 cutting process Methods 0.000 claims description 8
- 239000013536 elastomeric material Substances 0.000 claims description 6
- 239000012530 fluid Substances 0.000 description 7
- 238000004891 communication Methods 0.000 description 3
- 238000007792 addition Methods 0.000 description 2
- 229920001971 elastomer Polymers 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 230000004888 barrier function Effects 0.000 description 1
- 230000002457 bidirectional effect Effects 0.000 description 1
- 230000006866 deterioration Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000000806 elastomer Substances 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 238000010348 incorporation Methods 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000013011 mating Effects 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 210000003660 reticulum Anatomy 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 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
- 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.
- Seals may optionally be provided in BOPs. Examples of seals are provided in US Patent/application Ser. Nos. 13/018,217, 2012/0012339, 2012/0012340, 2010/243926, and U.S. Pat. No. 7,967,299. Despite the development of techniques for addressing blowouts, there remains a need to provide techniques for shearing a tubular and/or sealing a wellbore.
- 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.
- FIG. 1 shows a schematic view of an offshore wellsite provided with a blowout preventer (BOP) having a shear sealing system for shearing a tubular and sealing a wellbore.
- BOP blowout preventer
- FIGS. 2A-2B show schematic side and top views, respectively, partially in cross-section, of a BOP having a shear sealing system in a retracted position.
- FIG. 2C is a schematic side view, partially in cross-section, of a BOP having a shear sealing system in an extended position.
- FIGS. 3A-3B are horizontal and vertical cross-sectional views, respectively, of a BOP having a shear sealing system therein.
- FIG. 3C is a schematic view depicting an end view, partially in cross-section, of the BOP of FIG. 3B .
- FIGS. 4A-4C show perspective views of the shear sealing system of FIGS. 3A-3C having a pair of carriages in a retracted, partially extended, and fully extended position about a seal assembly.
- FIGS. 5A-5C depict side, top and perspective views, respectively, of an alternate seal assembly.
- FIG. 5D depicts a perspective view of a portion of the alternate seal assembly of FIG. 5B .
- FIG. 6 is a flow chart depicting a method of forming a sealing about a tubular of a wellbore.
- 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.
- FIG. 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.
- FIGS. 2A-2C depict the BOP 120 in greater detail.
- FIGS. 2A and 2B show the BOP 120 in the retracted position before actuation.
- FIG. 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; U.S. Pat. Nos. 7,814,979; and 7,367,396, the entire contents of which are hereby incorporated by reference herein.
- 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 240 a,b of the shear sealing system 124 .
- Each of the carriages 240 a,b carries a blade 242 a,b .
- the actuators 228 may move the blades 242 a,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 242 a,b in response to direct control from the controller(s) 108 ( FIG.
- 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 240 a,b within the BOP 120 as the actuator 228 moves the blades 242 a,b .
- the ram guideways 220 and 222 may extend outwardly from opposite sides of the bore 214 .
- FIG. 2B shows a top view of the BOP 120 .
- the carriages 240 a,b are shown holding the blades 242 a,b in an unactuated (or retracted) position within the ram guideways 220 and 222 .
- the blades 242 a,b of carriages 240 a,b may be positioned to pass one another within the bore 214 while shearing the tubular 116 .
- the pair of blades 242 a,b includes an upper cutting blade 242 a on the carriage 240 a and a lower cutting blade 242 b on the carriage 240 b .
- the blades 242 a,b may be movably positioned so that the upper blade 242 a passes some distance above the blade 242 b when shearing the tubular 116 .
- the shearing action of cutting blades 242 a,b may pierce, rake, cut, shave, sever, and/or shear the tubular 116 such that the tubular is compressed or separated into upper portion 116 a and lower portion 116 b .
- the lower portion of the tubular 116 b may drop into the wellbore 118 (as shown in FIG. 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 242 a,b.
- FIGS. 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., FIG. 1 ).
- FIGS. 3A and 3B are cross-sectional views of the BOP 320 having a bore 314 therethrough for receiving the tubular 116 (see, e.g., FIG. 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 331 a,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 326 a,b , and a pair of blades (or blade inserts) 328 a,b .
- Each of the carriages 326 a,b carries a blade 328 a,b such that the blades 328 a,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 326 a,b for back and forth movement therein.
- the carriages 326 a,b may be selectively extended and refracted in the guideway 321 such that the blades 328 a,b carried by the carriages 326 a,b may selectively engage the tubular 116 in the bore 314 .
- the carriages 326 a,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 328 a,b may be inserted into its corresponding carriage 326 a,b and secured therein by conventional means, such as bolts 329 .
- Each blade 328 a,b may be positioned in the carriage 326 a,b at an end near the bore 314 for engagement with the tubular 116 .
- the blades 328 a,b may be the same or different blades, such as those described in U.S. Patent/Application Nos. 20110000670; U.S. Pat. Nos. 7,814,979; and 7,367,396, previously incorporated herein by reference.
- the blades 328 a,b may have protrusions (or points) 333 to first pierce and then shear the tubular 116 during a shearing operation.
- the carriages 326 a,b may be positioned in the BOP 320 and advanced such that the blade 328 a passes a distance below the blade 328 b to provide shearing engagement with the tubular 116 as shown in the extended position of FIG. 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 FIGS. 2A-2C .
- the blades 328 a,b may also engage and form a seal with the seal assembly 330 .
- the seal assembly 330 may be positioned in the receptacles 331 a,b along the bore 314 and the guideway 321 .
- the seal assembly 330 includes seal collars 332 a,b , coil springs 334 a,b , and elastor seals 336 a,b as shown in FIG. 3C .
- FIG. 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 331 a has the corresponding upper seal collar 332 a , coil spring 334 a and elastor seal 336 a therein.
- the lower receptacle 331 b has the corresponding lower seal collar 332 b , coil spring 334 b and elastor seal 336 b therein.
- the coil springs 334 a,b may be used to support the seal collar 332 a,b against the carriages 326 a,b (see, e.g., FIG. 3B ), particularly in high pressure conditions. Additional seals, such as the elastor seals 336 a,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 332 a,b , coil springs 334 a,b , and elastor seals 336 a,b may be used to cooperatively seal with the blades 328 a,b to provide a seal about the bore 314 .
- a metal-to-metal seal is formed therebetween.
- the seal collars 332 a,b are perpendicular to and in sealing engagement with a seal surface 338 a,b of the blades 328 a,b .
- the coil springs 334 a,b may be used to provide compressive forces to maintain a constant interface between the seal collars 332 a,b and seal surfaces 338 a,b , for example, to provide low pressure differential seal performance.
- FIGS. 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 FIGS. 4A-4C .
- the carriage 326 b is in an inverted and opposing position relative to the carriage 326 a .
- the upper seal collar 332 a , coil spring 334 a and elastor seal 336 a are also inverted from the lower seal collar 332 b , coil spring 334 b and elastor seal 336 b therein.
- each of the carriages 326 a,b includes a base 440 a,b and a rod 442 a,b .
- the rods 442 a,b may be coupled to an actuator (not shown), such as the actuator 228 depicted in FIG. 2 .
- the rods 442 a,b are also coupled to the bases 440 a,b for selective extension and retraction thereof.
- the bases 440 a,b are shaped for sliding engagement within the guideway 321 of BOP 320 (see, e.g., FIGS. 3A-3C ).
- the bases 440 a,b are also shaped such that they may pass adjacent to each other as shown in FIGS. 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 328 a,b .
- the blade pocket 447 may be configured to support the blades 328 a,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 442 a,b and provide a platform for receiving the blades 328 a,b.
- the pair of side portions 444 may extend a distance beyond the rear portion 446 and/or the blades 328 a,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 332 a,b (see, e.g., FIGS. 3A-3C ).
- the seal collars 332 a,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 332 a,b .
- Such redundant seals may be used to further bias the seal collar 332 a,b towards the seal surface 338 a,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 336 a,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 336 a,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 FIG. 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 526 a,b , and a pair of blades (or blade inserts) 528 a,b with seals 530 a,b on the carriages 526 a,b .
- Each of the carriages 526 a,b carries a blade 528 a,b such that the blades 528 a,b may be advanced to pass through the tubular 116 .
- each of the carriages 526 a,b has a top surface 552 a,b , a bottom surface 554 a,b and a side surface 556 a .
- a blade pocket 558 a,b is formed about the top surface 552 a,b for receiving the blade 538 a,b .
- a seal pocket 560 a,b is formed about the bottom surface 554 a,b to receive the blade 538 b,a of the other carriage 526 b,a .
- Each of the seal pockets 560 a,b has a receiving edge 562 a,b that conforms to the profile of the blade 538 a,b it is receiving to form a seal therewith.
- the side surfaces 556 a,b extend a distance from the receiving edge 562 a,b to receivingly engage sides of the blades 538 a,b to extend the seal thereabout.
- the side surfaces 556 a,b may extend sufficiently to engage the seal 530 b,a of the other carriage 526 b,a .
- the seals 530 a,b may extend over at least a portion of each carriage 526 a,b sufficient to provide a seal about the blades 538 a,b and/or carriage 526 a,b .
- a seal is formed about the blades (e.g., along the cutting profile and along the sides of the blades).
- the seals 530 a,b may be made of an elastomeric material (e.g., rubber) to form a seal with the blades 528 a,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 530 a,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.
Landscapes
- 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)
Abstract
A shear sealing system of a blowout preventer of a wellbore is provided. The blowout preventer including a housing having a bore and a guideway therethrough. A tubular of the wellbore is positionable in the bore. The shear sealing system includes at least one carriage, at least one blade and at least one seal. The carriages are slidably positionable in the guideway of the blowout preventer. The blades are carried by the carriages and movable thereby between a retracted position and an extended position. The blades are engageable with the tubular when in the extended position. The seal forms a seal about the tubular and with the blade when the blade is in the extended position.
Description
- This application claims priority to the U.S. provisional patent application Ser. No. 61/502,683 filed on Jun. 29, 2011.
- 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. Once the downhole tools form a wellbore to reach a desired reservoir, 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.
- Leakage of subsurface fluids may pose an environmental threat if released from the wellbore. Equipment, such as blowout preventers (BOPs), may be positioned about the wellbore to form a seal about a tubular therein to prevent leakage of fluid as the fluid is brought to the surface. 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. Some examples of BOPs for severing tubulars are provided in U.S. Patent/Application Nos. 20110000670; U.S. Pat. Nos. 7,814,979; and 7,367,396. Seals may optionally be provided in BOPs. Examples of seals are provided in US Patent/application Ser. Nos. 13/018,217, 2012/0012339, 2012/0012340, 2010/243926, and U.S. Pat. No. 7,967,299. Despite the development of techniques for addressing blowouts, there remains a need to provide techniques for shearing a tubular and/or sealing a wellbore.
- In at least one aspect, 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.
- In another aspect, 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.
- In another aspect, 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.
- So that the above recited features and advantages of the present disclosure can be understood in detail, a more particular description of the subject matter, briefly summarized above, may be had by reference to the embodiments thereof that are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only example embodiments of the subject matter and are, therefore, not to be considered limiting of its scope. The figures are not necessarily to scale and certain features, and certain views of the figures may be shown exaggerated in scale or in schematic in the interest of clarity and conciseness.
-
FIG. 1 shows a schematic view of an offshore wellsite provided with a blowout preventer (BOP) having a shear sealing system for shearing a tubular and sealing a wellbore. -
FIGS. 2A-2B show schematic side and top views, respectively, partially in cross-section, of a BOP having a shear sealing system in a retracted position. -
FIG. 2C is a schematic side view, partially in cross-section, of a BOP having a shear sealing system in an extended position. -
FIGS. 3A-3B are horizontal and vertical cross-sectional views, respectively, of a BOP having a shear sealing system therein. -
FIG. 3C is a schematic view depicting an end view, partially in cross-section, of the BOP ofFIG. 3B . -
FIGS. 4A-4C show perspective views of the shear sealing system ofFIGS. 3A-3C having a pair of carriages in a retracted, partially extended, and fully extended position about a seal assembly. -
FIGS. 5A-5C depict side, top and perspective views, respectively, of an alternate seal assembly. -
FIG. 5D depicts a perspective view of a portion of the alternate seal assembly ofFIG. 5B . -
FIG. 6 is a flow chart depicting a method of forming a sealing about a tubular of a wellbore. - The description that follows includes exemplary apparatus, methods, techniques, and/or instruction sequences that embody techniques of the subject matter. However, it is understood that the described embodiments may be practiced without these specific details.
- Blowout preventers (BOPS) 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.
-
FIG. 1 depicts anoffshore wellsite 100 having asubsea system 104 and asurface system 102. Thesurface system 102 may be used to facilitate the oilfield operations at theoffshore wellsite 100. Thesurface system 102 may include arig 105, a platform 106 (or vessel) and acontroller 108. - The
subsea system 104 includes aconduit 110 extending from theplatform 106 to asea floor 112. The subsea system further includes awellhead 114 with a tubular 116 extending into awellbore 118, aBOP 120 and acontroller 108. TheBOP 120 has ashear sealing system 124 for shearing the tubular 116 and sealing the wellbore, as will be described further herein. - The
surface system 102 andsubsea system 104 may be provided with one ormore controllers 108 located at various locations to control thesurface system 102 and/or thesubsea system 104.Communication links 126 may be provided for communication between thecontrollers 108 and various parts of thewellsite 100. - Although the
BOP 120 is described herein as being used in subsea operations, it will be appreciated that thewellsite 100 may be land or water based, and theBOP 120 and/orshear sealing system 124 may be used in any wellsite environment. -
FIGS. 2A-2C depict theBOP 120 in greater detail.FIGS. 2A and 2B show theBOP 120 in the retracted position before actuation.FIG. 2C shows theBOP 120 in the extended position after actuation. TheBOP 120 may be similar to, for example, the BOP described in U.S. Patent/Application Nos. 20110000670; U.S. Pat. Nos. 7,814,979; and 7,367,396, the entire contents of which are hereby incorporated by reference herein. - As shown in
FIGS. 2A-2C , theBOP 120 may have abody 212 with abore 214 extending therethrough. The tubular 116 may pass through thebore 214. Thebody 212 may have alower flange 216 and anupper flange 218 for connecting theBOP 120 to other equipment about the wellsite, such as the wellhead 114 (FIG. 1 ). TheBOP 120 may have the one ormore actuators 228 for actuating theshear sealing system 124 therein, for example, in order to shear the tubular 116 and sealing the wellbore. - Each of the
actuators 228 may move apiston 230 within acylinder 232 in order to move arod 234. Eachrod 234 may couple to acarriage 240 a,b of theshear sealing system 124. Each of thecarriages 240 a,b carries ablade 242 a,b. Thus, theactuators 228 may move theblades 242 a,b toward and away from thebore 214 in order to shear the tubular 116 within thebore 214. Theactuators 228 may actuate theblades 242 a,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 inFIG. 1 ). As shown inFIGS. 2A-2C , theactuators 228 may be hydraulically operated and driven by a hydraulic system (not shown), although any suitable means for actuating theshear 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 240 a,b within theBOP 120 as theactuator 228 moves theblades 242 a,b. The ram guideways 220 and 222 may extend outwardly from opposite sides of thebore 214.FIG. 2B shows a top view of theBOP 120. Thecarriages 240 a,b are shown holding theblades 242 a,b in an unactuated (or retracted) position within theram guideways - The
blades 242 a,b ofcarriages 240 a,b may be positioned to pass one another within thebore 214 while shearing the tubular 116. As shown, the pair ofblades 242 a,b includes anupper cutting blade 242 a on thecarriage 240 a and alower cutting blade 242 b on thecarriage 240 b. Theblades 242 a,b may be movably positioned so that theupper blade 242 a passes some distance above theblade 242 b when shearing the tubular 116. - As shown in
FIG. 2C , the shearing action of cuttingblades 242 a,b may pierce, rake, cut, shave, sever, and/or shear the tubular 116 such that the tubular is compressed or separated intoupper portion 116 a andlower portion 116 b. After the tubular 116 is severed, the lower portion of the tubular 116 b may drop into the wellbore 118 (as shown inFIG. 1 ) below theBOP 120. In the closed position, aseal assembly 243 of theshear sealing system 124 positioned in theBOP 120 may form a seal with theblades 242 a,b. -
FIGS. 3A-3C depict various views of aBOP 320 having ashear sealing system 324 usable for shearing the tubular 116 and/or sealing the wellbore (see, e.g.,FIG. 1 ).FIGS. 3A and 3B are cross-sectional views of theBOP 320 having abore 314 therethrough for receiving the tubular 116 (see, e.g.,FIG. 1 ). Theshear sealing system 324 includes acarriage assembly 325 movably positionable in aguideway 321, and aseal assembly 330 positioned inreceptacles 331 a,b in theBOP 320. - The
guideway 321 extends into thebore 314 to enable movement of thecarriage assembly 325 therein for sealing engagement withseal assembly 330 and the tubular 116. As shown inFIG. 3A , thecarriage assembly 325 is in a retracted (or disengaged) position. As shown inFIG. 3B , thecarriage assembly 325 is advanced to an extended (or engaged) position. Theshear sealing system 324 includes a pair ofcarriages 326 a,b, and a pair of blades (or blade inserts) 328 a,b. Each of thecarriages 326 a,b carries ablade 328 a,b such that theblades 328 a,b may be advanced to pass through the tubular 116. - The
guideway 321 of theBOP 320 may be shaped to slidingly receive thecarriages 326 a,b for back and forth movement therein. Thecarriages 326 a,b may be selectively extended and refracted in theguideway 321 such that theblades 328 a,b carried by thecarriages 326 a,b may selectively engage the tubular 116 in thebore 314. Thecarriages 326 a,b may be provided withrails 337 for slidable movement within theguideway 321. The rails 337 (and other components of the shear seal assembly 324) may be replaceable. - The components of the
shear seal assembly 324 may be modular. For example, eachblade 328 a,b may be inserted into itscorresponding carriage 326 a,b and secured therein by conventional means, such asbolts 329. Eachblade 328 a,b may be positioned in thecarriage 326 a,b at an end near thebore 314 for engagement with the tubular 116. Theblades 328 a,b may be the same or different blades, such as those described in U.S. Patent/Application Nos. 20110000670; U.S. Pat. Nos. 7,814,979; and 7,367,396, previously incorporated herein by reference. Theblades 328 a,b may have protrusions (or points) 333 to first pierce and then shear the tubular 116 during a shearing operation. - During operation, the
carriages 326 a,b may be positioned in theBOP 320 and advanced such that theblade 328 a passes a distance below theblade 328 b to provide shearing engagement with the tubular 116 as shown in the extended position ofFIG. 3B . An actuator (not shown) may be used to activate theshear sealing system 324 to move the carriages and the blades in a similar manner as shown inFIGS. 2A-2C . As thecarriages 326 a,b move to the extended position ofFIG. 3B , theblades 328 a,b may also engage and form a seal with theseal assembly 330. - The
seal assembly 330 may be positioned in thereceptacles 331 a,b along thebore 314 and theguideway 321. Theseal assembly 330 includesseal collars 332 a,b, coil springs 334 a,b, andelastor seals 336 a,b as shown inFIG. 3C . InFIG. 3C , an end view of thecarriage assembly 325 is depicted adjacent a cross-sectional view of theseal assembly 330 andBOP 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 331 a has the correspondingupper seal collar 332 a,coil spring 334 a andelastor seal 336 a therein. Thelower receptacle 331 b has the correspondinglower seal collar 332 b,coil spring 334 b andelastor seal 336 b therein. The coil springs 334 a,b may be used to support theseal collar 332 a,b against thecarriages 326 a,b (see, e.g.,FIG. 3B ), particularly in high pressure conditions. Additional seals, such as the elastor seals 336 a,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 332 a,b, coil springs 334 a,b, andelastor seals 336 a,b may be used to cooperatively seal with theblades 328 a,b to provide a seal about thebore 314. Once thecarriages 326 a,b are advanced and theblades 328 a,b engage theseal collars 332 a,b as shown inFIG. 3B , a metal-to-metal seal is formed therebetween. In this position, theseal collars 332 a,b are perpendicular to and in sealing engagement with aseal surface 338 a,b of theblades 328 a,b. The coil springs 334 a,b may be used to provide compressive forces to maintain a constant interface between theseal collars 332 a,b and sealsurfaces 338 a,b, for example, to provide low pressure differential seal performance. -
FIGS. 4A-4C depict theshear sealing system 324 in greater detail and in a retracted, partially extended and extended position, respectively. For descriptive purposes, theshear sealing system 324 is depicted outside of theBOP 320 inFIGS. 4A-4C . As shownFIG. 4A , thecarriage 326 b is in an inverted and opposing position relative to thecarriage 326 a. Theupper seal collar 332 a,coil spring 334 a andelastor seal 336 a are also inverted from thelower seal collar 332 b,coil spring 334 b andelastor seal 336 b therein. - As further depicted in
FIGS. 4A and 4B , each of thecarriages 326 a,b includes a base 440 a,b and arod 442 a,b. Therods 442 a,b may be coupled to an actuator (not shown), such as theactuator 228 depicted inFIG. 2 . Therods 442 a,b are also coupled to thebases 440 a,b for selective extension and retraction thereof. - The
bases 440 a,b are shaped for sliding engagement within theguideway 321 of BOP 320 (see, e.g.,FIGS. 3A-3C ). Thebases 440 a,b are also shaped such that they may pass adjacent to each other as shown inFIGS. 4B-4C and to facilitate sealing with theseal assembly 330. The base 440 includes a pair ofside portions 444 with arear portion 446 therebetween. The base 440 also defines ablade pocket 447 for receiving and supporting ablade 328 a,b. Theblade pocket 447 may be configured to support theblades 328 a,b such that loads are applied to the base 440 to support the blades during operation. Therear portion 446 may be connected to therod 442 a,b and provide a platform for receiving theblades 328 a,b. - The pair of
side portions 444 may extend a distance beyond therear portion 446 and/or theblades 328 a,b to define spars (or supports) 445 on an end of theside portions 444 that form aseal pocket 448 therebetween for receiving theseal collars 332 a,b (see, e.g.,FIGS. 3A-3C ). Theseal collars 332 a,b are nestled into a staging position by thespars 445 to position the seal collar 332 in a readied state of use. Theside portions 444 may also have ashoulder 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. Theseconvolutions 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, such as elastor 336 a,b, may be provided to further reinforce and/or prevent leakage of the
seal collar 332 a,b. Such redundant seals may be used to further bias theseal collar 332 a,b towards theseal surface 338 a,b. The metal-to-metal interface of theseal assembly 330 may be self energizing to provide support during operation. Secondary elastomer seals, such as elastors 336 a,b, may be reactive to wellbore pressure to enhance seal characteristics as wellbore pressures increase. Positioning the components of theseal assembly 330 both above and below thecarriage 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 andcarriage assembly 325. Additional sealing components, such as elastors 336 a,b and/or other seals (of elastomeric or other materials) may optionally be provided. -
FIGS. 5A-5D depict an alternateshear sealing system 524 usable, for example, as theshear sealing system 124 ofFIG. 1 . Theshear sealing system 524 is similar to theshear sealing system 324, except that theshear sealing system 524 includes a pair ofcarriages 526 a,b, and a pair of blades (or blade inserts) 528 a,b withseals 530 a,b on thecarriages 526 a,b. Each of thecarriages 526 a,b carries ablade 528 a,b such that theblades 528 a,b may be advanced to pass through the tubular 116. - In this version, each of the
carriages 526 a,b has atop surface 552 a,b, abottom surface 554 a,b and aside surface 556 a. Ablade pocket 558 a,b is formed about thetop surface 552 a,b for receiving theblade 538 a,b. Aseal pocket 560 a,b is formed about thebottom surface 554 a,b to receive the blade 538 b,a of theother carriage 526 b,a. Each of the seal pockets 560 a,b has a receivingedge 562 a,b that conforms to the profile of theblade 538 a,b it is receiving to form a seal therewith. - The side surfaces 556 a,b extend a distance from the receiving
edge 562 a,b to receivingly engage sides of theblades 538 a,b to extend the seal thereabout. The side surfaces 556 a,b may extend sufficiently to engage theseal 530 b,a of theother carriage 526 b,a. As shown, theseals 530 a,b may extend over at least a portion of eachcarriage 526 a,b sufficient to provide a seal about theblades 538 a,b and/orcarriage 526 a,b. When theblades 538 a,b are moved to the extended position (see, e.g.,FIGS. 2C and 3B ), a seal is formed about the blades (e.g., along the cutting profile and along the sides of the blades). Theseals 530 a,b may be made of an elastomeric material (e.g., rubber) to form a seal with theblades 528 a,b. - Additional coverage may also optionally be provided about the BOP. For example, one or more of the
seals 330 can be used alone, separately or in combination with one or more of theseals 530 a,b. Various combinations of theshear sealing system 324 and theshear sealing system 524 may be provided. - In operation, as shown in
FIG. 6 , the shear sealing systems may be used in amethod 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.
- It will be appreciated by those skilled in the art that 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. 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.
- While the embodiments are described with reference to various implementations and exploitations, it will be understood that these embodiments are illustrative and that the scope of the inventive subject matter is not limited to them. Many variations, modifications, additions and improvements are possible. For example, 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.
- Plural instances may be provided for components, operations or structures described herein as a single instance. In general, structures and functionality presented as separate components in the exemplary configurations may be implemented as a combined structure or component. Similarly, structures and functionality presented as a single component may be implemented as separate components. These and other variations, modifications, additions, and improvements may fall within the scope of the inventive subject matter.
Claims (29)
1. A shear sealing system of a blowout preventer of a wellbore, the wellbore having a tubular therein, the blowout preventer comprising a housing having a bore and a guideway therethrough, the tubular positionable in the bore, the shear sealing system comprising:
at least one carriage slidably positionable in the guideway of the blowout preventer;
at least one blade carried by the at least one carriage and movable thereby between a retracted position and an extended position, the at least one blade engageable with the tubular when in the extended position; and
at least one seal forming a seal about the tubular and with the at least one blade when the at least one blade is in the extended position.
2. The shear sealing system of claim 1 , wherein the at least one blade comprises an upper blade and a lower blade and the at least one seal comprises an upper seal and a lower seal, and wherein the upper blade, the lower blade, the upper seal and the lower seal are positionable in sealing engagement.
3. The shear sealing system of claim 1 , wherein the at least one seal forms a metal to metal seal with the at least one blade.
4. The shear sealing system of claim 1 , wherein the at least one seal is positionable in the housing.
5. The shear sealing system of claim 4 , wherein the at least one seal is a tubular member having an outer diameter positionable along an inner diameter of the bore.
6. The shear sealing system of claim 5 , wherein the at least one seal has a bottom surface positionable along an inner diameter of the guideway, the bottom surface engageable with a top surface of the at least one blade when the at least one blade moves to the extended position.
7. The shear sealing system of claim 4 , wherein the at least one seal comprises at least one seal collar.
8. The shear sealing system of claim 7 , wherein the at least one seal collar has convolutions on an outer surface thereof.
9. The shear sealing system of claim 4 , wherein the at least one seal comprises at least one coil spring
10. The shear sealing system of claim 4 , wherein the at least one seal comprises at least one elastor seal.
11. The shear sealing system of claim 1 , wherein the at least one carriage comprises a base having a blade pocket for receiving the at least one blade.
12. The shear sealing system of claim 11 , wherein the base has spars extending from a front end thereof defining a seal pocket for receiving the at least one seal.
13. The shear sealing system of claim 1 , wherein the at least one carriage comprises a plurality of carriages and the at least one blade comprises a plurality of blades, each of the plurality of carriages having a blade pocket for receivingly supporting a corresponding one of the plurality of seals.
14. The shear sealing system of claim 13 , wherein the at least one seal comprises an elastomeric material disposable about each of the plurality of carriages.
15. The shear sealing system of claim 13 , wherein each of the plurality of carriages comprises a base having a seal pocket shaped to receivingly and sealingly engage one of the plurality of blades carried by one of the plurality of carriages.
16. The shear sealing system of claim 15 , wherein the seal pocket is defined along a top and side surfaces of the base.
17. A blowout preventer positionable about a wellbore, the wellbore having a tubular therein, comprising:
a housing having a bore and a guideway therethrough, the tubular positionable in the bore; and
a shear sealing system, comprising:
at least one carriage slidably positionable in the guideway of the blowout preventer;
at least one blade carried by the at least one carriage and movable thereby between a retracted position and an extended position, the at least one blade engageable with the tubular when in the extended position; and
at least one seal forming a seal about the tubular and with the at least one blade when the at least one blade is in the extended position.
18. The blowout preventer of claim 17 , wherein the at least one carriage comprises upper and lower carriages, the at least one blade comprises upper and lower blades and the at least one seal comprises upper and lower seals.
19. The blowout preventer of claim 18 , wherein the upper seals are positionable in the housing above the upper blades in sealing engagement therewith, and wherein the lower seals are positionable in the housing below the lower blades in sealing engagement therewith.
20. The blowout preventer of claim 18 , wherein the upper seals are positionable about the upper blades of the upper carriage and the lower seals are positionable about the lower blade of the lower carriage, the upper seals sealingly engageable with the lower blade and the lower seals sealingly engageable with the upper blades.
21. The blowout preventer of claim 17 , wherein the at least one seal forms a metal to metal seal with the at least one blade.
22. The blowout preventer of claim 17 , wherein the at least one seal comprises an elastomeric material carried by the at least one carriage and sealable with the at least one blade.
23. The blowout preventer of claim 17 , wherein the housing has at least one receptacle for receiving the at least one seal.
24. A method of forming a seal about a tubular of a wellbore, the method comprising:
providing a blowout preventer, comprising:
a housing having a bore and a guideway therethrough, the tubular positionable in the bore; and
a shear sealing system comprising at least one carriage, at least one blade carried by the at least one carriage and at least one seal;
engaging the tubular with the at least one blade by slidably positioning the at least one carriage in the guideway of the blowout preventer and moving the at least one blade between a retracted position and an extended position; and
forming a seal about the tubular and between the at least one seal and the at least one blade when the blade is in the extended position.
25. The method of claim 25 , wherein the engaging comprises shearing the tubular.
26. The method of claim 26 , wherein the shearing comprises one of piercing, cutting, raking, shaving, severing and combinations thereof.
27. The method of claim 25 , wherein the at least one blade comprises an upper blade and a lower blade and the at least one seal comprises an upper seal and a lower seal, and wherein the forming comprises forming a seal between the upper blade, the lower blade, the upper seal and the lower seal.
28. The method of claim 28 , wherein the forming comprises sealingly engaging the upper blade with the upper seal and sealingly engaging the lower blade with the lower seal.
29. The method of claim 28 , wherein the forming further comprises sealing engaging the upper blade with the lower seal and the lower blade with the upper seal.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US14/129,511 US20140110611A1 (en) | 2011-06-29 | 2012-06-06 | Blowout preventer seal assembly and method of using same |
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
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 |
US14/129,511 US20140110611A1 (en) | 2011-06-29 | 2012-06-06 | Blowout preventer seal assembly and method of using same |
Publications (1)
Publication Number | Publication Date |
---|---|
US20140110611A1 true US20140110611A1 (en) | 2014-04-24 |
Family
ID=46298688
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US14/129,511 Abandoned US20140110611A1 (en) | 2011-06-29 | 2012-06-06 | Blowout preventer seal assembly and method of using same |
Country Status (4)
Country | Link |
---|---|
US (1) | US20140110611A1 (en) |
EP (1) | EP2726699B1 (en) |
CA (1) | CA2840439A1 (en) |
WO (1) | WO2013002971A2 (en) |
Cited By (10)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20140264099A1 (en) * | 2013-03-15 | 2014-09-18 | National Oilwell Varco, L.P. | Blowout preventer with wedge ram assembly and method of using same |
US20160312904A1 (en) * | 2015-04-24 | 2016-10-27 | Cameron International Corporation | Shearing gate valve system |
US9976373B2 (en) * | 2015-09-02 | 2018-05-22 | Cameron International Corporation | Blowout preventer with shear ram |
US20190010777A1 (en) * | 2016-01-07 | 2019-01-10 | National Oilwell Varco, L.P. | Blowout Preventer with Interlocking Ram Assembly and Method of Using Same |
US10577884B2 (en) | 2017-03-31 | 2020-03-03 | General Electric Company | Blowout prevention system including blind shear ram |
US10677010B2 (en) | 2016-08-31 | 2020-06-09 | Enovate Systems Limited | Shear blade |
CN112004987A (en) * | 2018-04-10 | 2020-11-27 | 海德里美国分销有限责任公司 | Blind cable shearing flashboard |
US20220356777A1 (en) * | 2019-04-21 | 2022-11-10 | Schlumberger Technology Corporation | Blowout Preventer Shearing Ram |
USD1006845S1 (en) * | 2019-08-06 | 2023-12-05 | Nxl Technologies Inc. | Shear blade component for a shear blind assembly |
US12006781B2 (en) | 2019-04-21 | 2024-06-11 | Schlumberger Technology Corporation | Blowout preventer with multiple application ram blades |
Families Citing this family (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9045961B2 (en) | 2011-01-31 | 2015-06-02 | National Oilwell Varco, L.P. | Blowout preventer seal and method of using same |
EP2726699B1 (en) | 2011-06-29 | 2015-07-15 | National Oilwell Varco, L.P. | Blowout preventer seal assembly and method of using same |
CA2868524C (en) | 2012-04-10 | 2017-02-14 | National Oilwell Varco, L.P. | Blowout preventer seal assembly and method of using same |
GB201310613D0 (en) | 2013-06-14 | 2013-07-31 | Enovate Systems Ltd | Well bore control system |
US9238950B2 (en) | 2014-01-10 | 2016-01-19 | National Oilwell Varco, L.P. | Blowout preventer with packer assembly and method of using same |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4132266A (en) * | 1978-04-06 | 1979-01-02 | Cameron Iron Works, Inc. | Pipe shearing ram assembly for blowout preventer |
US6244336B1 (en) * | 2000-03-07 | 2001-06-12 | Cooper Cameron Corporation | Double shearing rams for ram type blowout preventer |
Family Cites Families (14)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4215749A (en) | 1979-02-05 | 1980-08-05 | Acf Industries, Incorporated | Gate valve for shearing workover lines to permit shutting in of a well |
US4313496A (en) | 1980-04-22 | 1982-02-02 | Cameron Iron Works, Inc. | Wellhead shearing apparatus |
US5515916A (en) | 1995-03-03 | 1996-05-14 | Stewart & Stevenson Services, Inc. | Blowout preventer |
US6601650B2 (en) | 2001-08-09 | 2003-08-05 | Worldwide Oilfield Machine, Inc. | Method and apparatus for replacing BOP with gate valve |
GB0423016D0 (en) * | 2004-10-16 | 2004-11-17 | Enovate Systems Ltd | Blow out preventers |
US7243713B2 (en) * | 2004-11-29 | 2007-07-17 | National-Oilwell Dht, L.P. | Shear/seal ram assembly for a ram-type blowout prevention system |
US7367396B2 (en) | 2006-04-25 | 2008-05-06 | Varco I/P, Inc. | Blowout preventers and methods of use |
GB0618555D0 (en) * | 2006-09-21 | 2006-11-01 | Enovate Systems Ltd | Improved well bore control vlave |
US8844898B2 (en) | 2009-03-31 | 2014-09-30 | National Oilwell Varco, L.P. | Blowout preventer with ram socketing |
US8567490B2 (en) | 2009-06-19 | 2013-10-29 | National Oilwell Varco, L.P. | Shear seal blowout preventer |
US7967299B2 (en) | 2009-07-16 | 2011-06-28 | National Oilwell Varco, L.P. | Body to bonnet seal on a blowout preventer |
US8544538B2 (en) | 2010-07-19 | 2013-10-01 | National Oilwell Varco, L.P. | System and method for sealing a wellbore |
US8540017B2 (en) | 2010-07-19 | 2013-09-24 | National Oilwell Varco, L.P. | Method and system for sealing a wellbore |
EP2726699B1 (en) | 2011-06-29 | 2015-07-15 | National Oilwell Varco, L.P. | Blowout preventer seal assembly and method of using same |
-
2012
- 2012-06-06 EP EP12727727.5A patent/EP2726699B1/en not_active Revoked
- 2012-06-06 WO PCT/US2012/040966 patent/WO2013002971A2/en active Application Filing
- 2012-06-06 US US14/129,511 patent/US20140110611A1/en not_active Abandoned
- 2012-06-06 CA CA2840439A patent/CA2840439A1/en not_active Abandoned
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4132266A (en) * | 1978-04-06 | 1979-01-02 | Cameron Iron Works, Inc. | Pipe shearing ram assembly for blowout preventer |
US6244336B1 (en) * | 2000-03-07 | 2001-06-12 | Cooper Cameron Corporation | Double shearing rams for ram type blowout preventer |
Cited By (13)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9249643B2 (en) * | 2013-03-15 | 2016-02-02 | National Oilwell Varco, L.P. | Blowout preventer with wedge ram assembly and method of using same |
US20140264099A1 (en) * | 2013-03-15 | 2014-09-18 | National Oilwell Varco, L.P. | Blowout preventer with wedge ram assembly and method of using same |
US10533667B2 (en) * | 2015-04-24 | 2020-01-14 | Cameron International Corporation | Shearing gate valve system |
US20160312904A1 (en) * | 2015-04-24 | 2016-10-27 | Cameron International Corporation | Shearing gate valve system |
US9976373B2 (en) * | 2015-09-02 | 2018-05-22 | Cameron International Corporation | Blowout preventer with shear ram |
US10883331B2 (en) * | 2016-01-07 | 2021-01-05 | National Oilwell Varco, L.P. | Blowout preventer with interlocking ram assembly and method of using same |
US20190010777A1 (en) * | 2016-01-07 | 2019-01-10 | National Oilwell Varco, L.P. | Blowout Preventer with Interlocking Ram Assembly and Method of Using Same |
US10677010B2 (en) | 2016-08-31 | 2020-06-09 | Enovate Systems Limited | Shear blade |
US10577884B2 (en) | 2017-03-31 | 2020-03-03 | General Electric Company | Blowout prevention system including blind shear ram |
CN112004987A (en) * | 2018-04-10 | 2020-11-27 | 海德里美国分销有限责任公司 | Blind cable shearing flashboard |
US20220356777A1 (en) * | 2019-04-21 | 2022-11-10 | Schlumberger Technology Corporation | Blowout Preventer Shearing Ram |
US12006781B2 (en) | 2019-04-21 | 2024-06-11 | Schlumberger Technology Corporation | Blowout preventer with multiple application ram blades |
USD1006845S1 (en) * | 2019-08-06 | 2023-12-05 | Nxl Technologies Inc. | Shear blade component for a shear blind assembly |
Also Published As
Publication number | Publication date |
---|---|
WO2013002971A2 (en) | 2013-01-03 |
EP2726699A2 (en) | 2014-05-07 |
WO2013002971A3 (en) | 2013-09-19 |
EP2726699B1 (en) | 2015-07-15 |
CA2840439A1 (en) | 2013-01-03 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
EP2726699B1 (en) | Blowout preventer seal assembly and method of using same | |
US8807219B2 (en) | Blowout preventer blade assembly and method of using same | |
GB2530415B (en) | Blowout preventer with wedge ram assembly and method of using same | |
EP2809875B1 (en) | Blowout preventer and method of using same | |
EP2836669B1 (en) | Blowout preventer with locking ram assembly and method of using same | |
CA2943208A1 (en) | Spherical blowout preventer with energizeable packer seal and method of using same | |
US10883331B2 (en) | Blowout preventer with interlocking ram assembly and method of using same |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: NATIONAL OILWELL VARCO, L.P., TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:MCCLANAHAN, PERRY LEE;DOUTY, JAMES ALLEN;WARD, RICHARD M.;REEL/FRAME:031853/0666 Effective date: 20110816 |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO PAY ISSUE FEE |