A wellhead monitoring system includes a conversion assembly (104), the conversion assembly (104) including an actuator element (108) for modifying an operating mode of a valve (102) from manual to remote. The system also includes one or more sensors (112, 114), associated at least one of a fracturing tree (100) or the conversion assembly (104), the one or more sensors (112, 114) obtaining wellhead operating conditions. The system further includes a control unit (500), adapted to receive information from the one or more sensors (112, 114), the control unit (500) presenting the information, on a display (504), and transmitting the information to a remote system for analysis.
E21B 15/00 - Supports for the drilling machine, e.g. derricks or masts
E21B 34/16 - Control means therefor being outside the borehole
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
2.
SYSTEM AND METHOD FOR AN EXPANDABLE LANDING LOCKING SHOULDER
A system for suspending a hanger (40) within a wellbore component (12) includes an actuation ring (82) circumferentially positioned about the hanger (40). The system also includes an arm (78) removably coupled to the actuation ring (82), the arm (78) extending longitudinally from the actuation ring (82) and including a head (116). The system further includes a landing profile (112) formed on the head (116), the landing profile (112) including a plurality of landing features (114). The system includes a tag shoulder (130) formed on the actuation ring (82), the tag shoulder (130) arranged to contact a protrusion (184) within the wellbore component (12) to drive upward axial movement of the actuation ring (82) along an axis (64), the upward axial movement being transferred to the arm (78) to move the arm (78) toward an activated position.
A system for determining a valve member position includes a valve (10) having a flow passage extending therethrough. The system also includes a valve member (20) coupled to a valve stem (16) that axially translates the valve member (20) between an open position and a closed position. The system includes an actuator (12) coupled to the valve stem (16) to drive axial movement of the valve member (20). The system includes a closure cap (50) coupled to the actuator (12), the closure cap (50) comprising a sensor feature (82) arranged within an interior portion (72) of the closure cap (50), the sensor feature (82) arranged to react to an input from an actuator piston (58) indicative of an actuator piston position within the interior portion (74) of the closure cap (50).
F16K 35/00 - Means to prevent accidental or unauthorised actuation
F16K 37/00 - Special means in or on valves or other cut-off apparatus for indicating or recording operation thereof, or for enabling an alarm to be given
An energizing ring (202, 402, 602, 802, 1002, 1120) for setting a downhole sealing element (204) includes a passage (216) extending through a width of the energizing ring (202, 402, 602, 802, 1002, 1102) and a wing (230) extending radially outward from a body (228) of the energizing ring (202, 402, 602, 802, 1002, 1102), the wing (230) includes a sealing arm (232) coupled to the body (228) at a joint (234) and a slot (238) arranged between at least a portion of the sealing arm (232) and the body (228), wherein the sealing arm (232) is configured to pivot relative to the joint (234) in response to a fluid pressure within the cavity (236).
An annulus seal (110) for sealing an interface between a wellhead housing (104) and a casing hanger (102). The annulus seal (110) includes a central body portion (114), a first seal leg (116) extending from the central body portion (114) in a first direction and a second seal leg (118) extending from the central body portion (114) in the first direction across from the first seal leg (116). The first seal leg (116) sealingly engages the casing hanger (102), and the second seal leg (118) sealingly engages the wellhead housing (104). At least one of the first seal leg (116) or the second seal leg (118) includes at least one of a first cavity (130) at least partially extending into the respective seal leg from the first direction or a second cavity (130) at least partially extending into the respective seal leg from the second direction.
Embodiments of the present disclosure include a system including a pair of wellbore tubulars (34) coupled together via a casing collar (38). The system also includes a hold down collar (42) arranged circumferentially about the casing collar (38). The system includes an actuating piston (50) including an actuating body (60), the actuating piston (50) being axially movable along the wellbore axis (100) between an activated position and a deactivated position. The system includes slip elements (78) arranged downstream of the actuating piston (50), the slip elements (78) receiving the actuating body (60) in a space (150) formed between the slip elements (78), wherein the actuating body (60) drives the respective slip elements (78) in opposite radial directions (82, 84) when in the activated position to secure the wellbore tubulars (34) within the wellbore (16).
Embodiments of the present disclosure include a method including receiving first impact data. The method includes receiving second impact data. The method includes applying a first filter to both the first impact data and the second impact data. The method includes applying a second filter to both the first impact data and the second impact data. Filtering includes time and frequency based discriminating filter to isolate specific signatures that representatively indicate impact signatures generated by the solid particles (80) on the interrogator. The method includes comparing the first impact data and the second impact data for corresponding signatures. The method includes identifying a corresponding signature in both the first impact data and the second impact data. The method includes determining the corresponding signature meets a threshold criterion. The method includes determining one or more particulate properties based at least in part on the corresponding signature.
G01F 1/74 - Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
G01F 1/66 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters
Embodiments of the present disclosure include a test dart for wellbore pressure isolation. The test dart includes a body extending from a first end to a second end, the body having a bore extending therethrough, a diameter of the bore being greater at a first end than the second end. The test dart also includes a groove formed proximate the first end and extending radially outward from the bore and into the body. Additionally, the test dart includes an anti-rotation pin positioned between the groove and the second end, the anti-rotation pin extending radially outward from the body. The test dart further includes a check valve positioned in the bore, the check valve enabling flow in a single direction and being moveable between an open position to enable the flow and a closed position to block the flow.
E21B 34/02 - Valve arrangements for boreholes or wells in well heads
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
Embodiments of the present disclosure include a system for installing a slip hanger assembly in a wellbore with a slip bowl comprising an aperture extending from an outer diameter of the slip bowl. The system also includes a slip coupled to the slip bowl, the slip comprising teeth on an inner face and a slot for receiving a shear pin extending through the aperture. The system further includes a running tool coupled to the slip bowl. The system includes a housing coupled to the running tool, the housing including a cylinder for receiving a reciprocating piston, the piston being movable between a first position and a second position, wherein the slip is in stored position while the piston is in the first position and an engaged position when the piston is in the second position.
Embodiments of the present disclosure include a system for installing a slip hanger assembly in a wellbore with a slip bowl comprising an aperture extending from an outer diameter of the slip bowl. The system also includes a slip coupled to the slip bowl, the slip comprising teeth on an inner face and a slot for receiving a shear pin extending through the aperture. The system further includes a running tool coupled to the slip bowl. The system includes a housing coupled to the running tool, the housing including a cylinder for receiving a reciprocating piston, the piston being movable between a first position and a second position, wherein the slip is in stored position while the piston is in the first position and an engaged position when the piston is in the second position.
Embodiments of the present disclosure include a system for installing a slip hanger assembly in a wellbore with a slip bowl comprising an aperture extending from an outer diameter of the slip bowl. The system also includes a slip coupled to the slip bowl, the slip comprising teeth on an inner face and a slot for receiving a shear pin extending through the aperture. The system further includes a running tool coupled to the slip bowl. The system includes a housing coupled to the running tool, the housing including a cylinder for receiving a reciprocating piston, the piston being movable between a first position and a second position, wherein the slip is in stored position while the piston is in the first position and an engaged position when the piston is in the second position.
Embodiments of the present disclosure include a valve assembly including a supply housing (64) with a first bore (72) and an injectable housing (66) coupled to the supply housing (64) with a second bore (74). The valve assembly further includes a piston (70) extending through at least a portion of the first and second bores (72, 74), the piston (70) being reciprocable axially along a longitudinal axis (76). The valve assembly also includes a first inlet (80) at a first end (78) of the supply housing (64) for directing a working fluid toward a first end (110) of the piston (70). The valve assembly includes a second inlet (84) extending through the injectable housing (66) toward a cavity (94) that receives an injectable material (152). The valve assembly also includes a second outlet (86) at a second end (88) of the injectable housing (66) that directs the injectable material (152) out of the injectable housing (66) as the piston (70) moves axially along the longitudinal axis (76).
Embodiments of the present disclosure include a method of replacing valve operation methods during fracturing operations including installing a first operator on a first valve of a first fracturing tree. The method also includes installing a second operator on a second valve of a second fracturing tree, the second fracturing tree being adjacent the first fracturing tree. The method also includes removing the first operator from the first valve, the first valve maintaining a position on the first fracturing tree after the first operator is removed. The method further includes removing the second operator from the second valve, the second valve maintaining a position on the second fracturing tree after the second operator is removed. The method also includes installing the first operator on the second valve after the first operator is removed from the first valve and after the second operator is removed from the second valve.
Embodiments of the present disclosure include a multi-inlet fracturing head (MIFH) having a first inlet channel extending through a body of the MIFH, the first inlet channel being substantially perpendicular to an axis of the MIFH and directing fluid into a first flow passage of the MIFH. The MIFH also includes a second inlet channel extending through the body of the MIFH, the second inlet channel being at an angle relative to the axis and directing fluid into the first flow passage of the MIFH.
GE Oil & Gas Pressure Control, L.P., GE Oil & Gas ESP, Inc., a Delaware Corporation and GE Energy Manufacturing, LLC, a Delaware Limited Liability Company ()
Embodiments of the present disclosure include a system for transmitting electrical energy to a downhole tool including a tubing head (12). The system also includes a tubing hanger (16) coupled to the tubing head, the tubing head receiving a downward force transmitted by at least a section of tubing (28) coupled to the tubing hanger onto a load shoulder (118) formed in the tubing head. The system includes one or more insulating features (116,108,120) for electrically isolating the tubing hanger from the tubing head.
A valve assembly includes a valve body with a flow passage intersected by a valve cavity. A valve member is axially movable in the valve cavity between a closed position and an open position, the valve member having an opening that registers with the flow passage when the valve member is in the open position. A valve stem is threadingly connected to the valve member, the valve stem rotatable to move the valve member between the closed position and the open position. A collar assembly is located within a slot of the valve member and circumscribes the valve stem, the collar assembly having an annular collar shoulder. The valve stem has an annular load shoulder sized to engage the collar shoulder, limiting axial movement of the valve member.
F16K 31/50 - Mechanical actuating means with screw-spindle
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
F16K 3/18 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor with special arrangements for separating the sealing faces or for pressing them together by movement of the closure members
F16K 3/314 - Forms or constructions of slidesAttachment of the slide to the spindle
A valve with a packing assembly can include a first stem packing (37) circumscribing a first portion of a valve stem, forming a seal between the valve stem (23) and a valve body assembly (12), and being located in the second bore portion (31b). A first packing retainer (41) can have a collar (43) that limits axial movement of the first stem packing and a first retainer body defining an inner cavity. A second stem packing (57) can circumscribe a second portion of the valve stem and be located in the inner cavity of the first packing retainer. A second packing retainer (67) can limit axial movement of the second stem packing. A piston member (50) can be located axially between the first stem packing and the second stem packing, the piston member being moveable to apply axial force to one of the first stem packing and the second stem packing.
Embodiments of the present disclosure include a remote well servicing system including a control unit 102 and a remote servicing manifold 104. The control unit 102 further includes a service fluid source 110 and a control system 108. The remote servicing manifold 104 further includes a fluid input line 114 coupled to the service fluid source 110, a fluid output line 118 couplable to a well component 105, and a valve coupled to the fluid input line 114 and the fluid output line 118, wherein the valve, when actuated, places the fluid input line in fluid communication with the fluid output line and permits delivery of a service fluid from the service fluid source 110 to the well component 105. The remote servicing manifold 104 also includes a control line coupling the valve and the control system, wherein the control system controls actuation of the valve via the control line.
Systems and methods for drilling multiple wells (57) include a landing template (12), the landing template having at least two through bores (14). Each through bore extends from a first face (16) of the landing template to an opposite second face (18) of the landing template. A skirt conductor (24) is secured to the landing template, the skirt conductor operable to be driven into a sea floor (26) so that the landing template is proximate to a mudline (28). A bore separator guide has a drill bit guide sized to register with one of the through bores. The bore separator guide is moveable to align with each of the at least two through bores one at a time.
A flow system (64) for use at a hydraulic fracturing well site, including a tree (14) attached to a wellhead (16), an inlet head (20) in fluid communication with at least one hydraulic fracturing pump (10) at the well site, and an adjustable fluid conduit (56) providing fluid communication between the inlet head and the tree. The flow system further includes a valve (66) in the fluid conduit and having an open position and a closed position, the valve permitting fluid flow through the fluid conduit when in the open position, and preventing fluid flow through the fluid conduit when in the closed position, at least a portion (56a) of the fluid conduit being positioned between the valve and the tree.
Systems and methods for gripping a polished rod (18) that extends into a hydrocarbon production well (10) include a clamping assembly (34) that is moveable between an unengaged position where the clamping assembly is spaced apart from the polished rod, and an engaged position where the clamping assembly engages the polished rod. The clamping assembly includes a recess (38) located in a moveable clamping member (33), the recess having a supporting surface (40). The clamping assembly also includes an adapter (42) sized to fit within the recess and to be supported on the supporting surface, the adapter having a gripping surface (46) facing out of the recess. The adapter is positioned to grip the polished rod with the gripping surface when the clamping assembly is in the engaged position.
Systems and methods for positioning tubular members within a subterranean well (10) include inner (18) and outer (16) tubular members extending into the well. An adjustment ring assembly (28) is located between the inner tubular member and the outer tubular member and has an outer ring (32) and an inner ring (30). The outer ring circumscribes, and is rotatable relative to, the inner ring to adjust the radial offset (26) between a central axis (24) of the wellhead assembly and a central axis (20) of the inner tubular member.
A system for securing a valve actuator (10) to a valve assembly includes an actuator housing (12) with a plurality of housing lugs (16) protruding radially. A cylinder assembly (60) is located within the actuator housing and has a horseshoe connector (34) to engage a valve stem nub (25) of a valve stem (24) and transfer axial movement of the horseshoe connector to axial movement of the valve stem. A bonnet (22) has a plurality of bonnet lugs (38) protruding radially from the bonnet to define a plurality of bonnet slots (40) therebetween, wherein each of the plurality of housing lugs are sized to pass axially through a respective one of the plurality of bonnet slots when the actuator housing is in a released postion, the actuator housing being rotatable to a locked postion such that the plurality of bonnet lugs prevent axial movement of the actuator housing in at least one direction.
F16K 31/122 - Operating meansReleasing devices actuated by fluid the fluid acting on a piston
F16K 37/00 - Special means in or on valves or other cut-off apparatus for indicating or recording operation thereof, or for enabling an alarm to be given
F16K 27/00 - Construction of housingsUse of materials therefor
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
Software for remote monitoring of oilfield equipment and
planning, tracking and documenting maintenance services. Providing on-line non-downloadable software for remote
monitoring of oilfield equipment and planning, tracking and
documenting maintenance services.
27.
CORRUGATED ENERGIZING RING FOR USE WITH A SPLIT LOCKDOWN RING
A wellhead assembly includes first and second wellhead members. An annular lock groove is located on an inner or an outer diameter surface of the first wellhead member. An annular lock ring is supported on an annular shoulder of the second wellhead member and is radially moveable between an unset position and a set position where a locking profile of the annular lock ring engages the annular lock groove. The second wellhead member is positioned concentrically with the first wellhead member, defining an annulus between the first and second wellhead members. An energizing ring is positioned in the annulus and axially movable between an unengaged position and an engaged position. The energizing ring has an engaging portion with a corrugated shape in cross section that is interference fit between the annular lock ring and the second wellhead member when the energizing ring is in the engaged position.
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
(1) Software for remote monitoring of oilfield equipment and planning, tracking and documenting maintenance services. (1) Providing on-line non-downloadable software for remote monitoring of oilfield equipment and planning, tracking and documenting maintenance services.
A hydraulic fracturing assembly includes a frac tree (15) that mounts to a wellhead (17). An injection tee (23) mounts to the tree (15), the injection tee (23) having an axial injection tee bore (27) that registers with an axial flow bore of the frac tree (15). A single inlet passage (29) in the injection tee (23) extends from a flowline (33) mounting face on an exterior portion of the injection tee (23) downward and inward into a junction with the axial flow bore (25). A wear resistant inlet passage sleeve extends from the mounting face of the injection tee (23) a selected distance into the inlet passage (29). The inlet passage sleeve is of a harder material than the injection tee.
A valve assembly for managing a flow of fluids in hydrocarbon development and production operations includes a valve body having an internal body cavity and a body bore intersecting the body cavity. A valve plug is located within the body cavity and is rotatable between an open position and a closed position. A sleeve is located between the valve plug and the valve body and is rotationally fixed to the valve body and remains rotationally static relative to the valve body as the valve plug rotates. A seal groove is located on a sidewall surface of the sleeve and circumscribes one of the sleeve openings. A seal assembly has a seal ring that is U shaped in cross section with an inner leg that engages the seal groove and an outer leg that extends out of the seal groove and engages one of the valve body and the valve plug.
F16K 5/04 - Taps or cocks comprising only cut-off apparatus having at least one of the sealing faces shaped as a more or less complete surface of a solid of revolution, the opening and closing movement being predominantly rotary with plugs having cylindrical surfacesPackings therefor
A valve assembly having a dynamic stem seal assembly includes a valve stem (29) for moving a valve member from a closed position to an open position, the valve stem extending through a stem opening (35) of a valve assembly body and having an axis. A packing assembly (37) seals between the valve stem and the stem opening. The packing assembly has a seal assembly (49) circumscribing the valve stem at a portion of the valve stem with a reduced outer diameter. The packing assembly also has a packing retainer assembly (61) releasably secured to the valve stem at the portion of the valve stem with the reduced outer diameter. The packing assembly is axially static relative to the valve stem.
A well fracturing component has a steel body with at least one passage and a connector for connecting the body to a source of pressurized frac fluid containing particulates for injecting into a well. An epoxy-based primer layer bonds to a side wall of the passage. A siloxane topcoat layer bonds to the primer layer. The topcoat layer has a greater thickness than the primer layer. The topcoat layer has less hardness than the primer layer and less hardness than the body.
E21B 33/068 - Well headsSetting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
B05D 7/22 - Processes, other than flocking, specially adapted for applying liquids or other fluent materials to particular surfaces or for applying particular liquids or other fluent materials to internal surfaces, e.g. of tubes
C09D 163/00 - Coating compositions based on epoxy resinsCoating compositions based on derivatives of epoxy resins
An apparatus for sealing at least one hub bore of a multi-bore fluid hub (12) associated with a wellhead assembly includes a plug body (26) having a plug bore opening (32) on an outer mating surface (34). A plug bore (28) extends from a first end (30) of the plug body (26) to the plug bore opening (32). The plug body (26) is selectively insertable into a hub housing (20) of the multi-bore fluid hub (12). An insert (44) is in engagement with the outer mating surface (34) and is moveable relative to the plug body (26) between an unengaged position, and an engaged position where the insert (44) seals across one of the hub bores. A stem member (38) is coupled to the plug body (26) and is moveable to selectively rotate the plug body (26) within the multi-bore fluid hub (12) so that the plug bore opening (32) aligns with one of the hub bores and the insert (44) aligns with another of the hub bores.
E21B 34/02 - Valve arrangements for boreholes or wells in well heads
F16K 5/02 - Taps or cocks comprising only cut-off apparatus having at least one of the sealing faces shaped as a more or less complete surface of a solid of revolution, the opening and closing movement being predominantly rotary with plugs having conical surfacesPackings therefor
F16K 5/16 - Special arrangements for separating the sealing faces or for pressing them together for plugs with conical surfaces
A wellhead assembly (10) includes an outer wellhead member (12), the outer wellhead member having a locking profile (15) on an inner surface. An inner tubular wellhead member (16) lands within the outer wellhead member, defining a seal pocket (22) between the inner tubular wellhead member and the outer wellhead member. A seal ring (30) is located in the seal pocket. A seal energizing ring (46) urges the seal ring into sealing engagement with the outer wellhead member and the inner tubular wellhead member. An annular lock ring (62) is carried with the seal energizing ring and engages the locking profile. A lock energizing ring (52) retains the annular lock ring in engagement with the locking profile.
An apparatus for actuating a valve includes an actuator with a cap. A plate that engages the inner diameter of the actuator housing is positioned within the actuator housing. A pressure chamber is located within the actuator housing between the plate and cap. A cap seal fluidly seals the pressure chamber between the cap and the actuator housing. The pressure chamber is fluidly sealed at the plate by one of a first plate seal assembly and a second plate seal assembly. The first plate seal assembly is formed by the diaphragm being secured between a seal nut and the plate. The second plate seal assembly is formed by an outer diameter sidewall seal located between the inner diameter of the actuator housing and the outer diameter of the plate and a retainer seal located between an outer diameter of the seal nut and an inner diameter of the plate.
F15B 15/10 - Fluid-actuated devices for displacing a member from one position to anotherGearing associated therewith characterised by the construction of the motor unit the motor being of diaphragm type
A conductor pipe connector assembly (14) for coupling a pressure containing component to a conductor pipe (10) of a subterranean well includes an annular slip bowl (24) circumscribing the conductor pipe. An annular slip segment (28)is located between the slip bowl and the conductor pipe. A slip actuation ring (40) is located between the slip bowl and the slip segment, the slip actuation ring having a beveled surface in sliding contact with one of the slip bowl and the slip segment. An elongate annular piston member (46) circumscribes the conductor pipe and is coupled to the slip action ring, the piston member is movable by a pressure medium, such as hydraulic fluid or pressurized gas, to an engaged position to urge the slip segment radially inward against the conductor pipe.
A locking apparatus (10) for attaching to an end of a valve actuator (12) includes an assembly body, the assembly body (36) releasably securable to a valve actuator. The assembly body has a stem bore (38) for receiving an actuator stem (28), and a plunger orifice (40) through a sidewall of the assembly body. An immobilizer assembly (42) has a plunger (44) extending through the plunger orifice, and biased radially outward (50) and moveable between a radially inner position where the immobilizer assembly extends over the stem bore, and a radially outer position where an inner end of the immobilizer assembly is radially outward of the stem bore. A segmented housing (58) circumscribes the assembly body and is moveable between a first position where the plunger is in the radially outer position and a second position where the plunger is in the radially inner position. A fusible band (66) selectively retains the segmented housing in engagement with the immobilizer assembly.
F16K 31/122 - Operating meansReleasing devices actuated by fluid the fluid acting on a piston
E21B 34/00 - Valve arrangements for boreholes or wells
E21B 41/00 - Equipment or details not covered by groups
F16K 31/56 - Mechanical actuating means without stable intermediate position, e.g. with snap action
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
F16K 17/38 - Safety valvesEqualising valves actuated in consequence of extraneous circumstances, e.g. shock, change of position of excessive temperature
An actuating apparatus (10) for operating a valve assembly (12) includes an actuator body (34) that selectively couples to the valve assembly (12) and an actuator stem (40) that has an end that extends into the actuator body (34). The valve assembly (12) has having a valve body (20), a valve member (26) in the valve body (20), a valve stem (18) attached to the valve member (26), and a profile on an end of the valve stem (18) distal from the valve member (26). The actuating apparatus (10) also includes an adapter assembly (42) in the actuator body (34) having a threaded end that engages the actuator stem (40), and a profiled end distal from the threaded end that engages the profile on the valve stem (18) and couples to the valve stem (18), so that selectively applying axial forces to the adapter assembly (42) moves the valve stem (18) and the valve member (26).
A termination block assembly 12 for fluidly coupling a fluid line 14 at a hydrocarbon production device includes a fluid line block 28 with an inner surface 32 selectively mated to a corresponding surface 30 of the hydrocarbon production device. The fluid line block 28 has a protruding member 36 extending from the inner surface 32. A primary seal 58 is located at an end of the protruding member 36. The primary seal 58 has an inner diameter selectively circumscribing the fluid line 14 extending from the hydrocarbon production device, and an outer diameter selectively engaging a sidewall passage surface of the hydrocarbon production device and sealing between the fluid line block 28 and the hydrocarbon production device. A secondary seal 68 circumscribes the protruding member 36, engaging both the inner surface of the fluid line block and the corresponding surface of the hydrocarbon production device and sealing between the fluid line block 28 and the hydrocarbon production device.
REMOTE MOBILE OPERATION AND DIAGNOSTIC CENTER FOR FRAC SERVICES [0046] A method for remotely controlling services to a well during hydraulic fracturing operations includes the steps of (a) generating a high pressure fluid and pumping the high pressure fluid into a subterranean geologic formation through a wellbore of a first well (30), the high pressure fluid being provided at a sufficient pressure to fracture the subterranean geologic formation: (b) performing a service on a second well (30), the second well being located within a pressure zone (32) defined around the first well and the second well; and (c) controlling the performance of the service from a remote operations hub (38). Step (a) and step (b) are performed simultaneously and step (c) is performed from the remote operations hub located outside of the pressure zone.
An apparatus for connecting an upper wellhead member (12) to a lower wellhead member (14) includes a box connector (48). The box connector has an upper portion that selectively circumscribes the upper wellhead member and a lower portion that selectively circumscribes the lower wellhead member. An adapter plate assembly (32) having an upper adapter ring (34) selectively engages a hub profile (28) of the lower wellhead member, and a separate lower adapter ring (36) selectively engages a generally opposite facing lower hub profile (24) of the lower wellhead member. A plurality of locking dog assemblies (42) drive the adapter plate assembly into engagement with the hub profile and the lower hub profile, the locking dog assemblies being spaced around the box connector.
A fluid fitting (14) for use with a hydrocarbon production device comprising: an annular fitting assembly (20) inserted into a port (16) formed in the hydrocarbon production device; a first outer diameter seal (44) located between the fitting assembly (20) and the port (16); and a packing assembly (52) in an annulus between the fitting assembly (20) and an inner surface of the port (16) and that defines a second outer diameter seal (46) between the fitting assembly (20) and the port (16), wherein the first outer diameter seal (44) is energized into sealing engagement by a first energizing means that is different from a second energizing means that energizes the packing assembly (52) in the annulus.
F16L 15/00 - Screw-threaded jointsForms of screw-threads for such joints
F16L 15/04 - Screw-threaded jointsForms of screw-threads for such joints with additional sealings
F16L 19/02 - Pipe ends provided with collars or flanges, integral with the pipe or not, pressed together by a screwed member
F16L 19/04 - Joints in which sealing surfaces are pressed together by means of a member, e.g. a swivel nut, screwed on, or into, one of the joint parts using additional rigid rings, sealing directly on at least one pipe end, which is flared either before or during the making of the connection
F16L 41/00 - Branching pipesJoining pipes to walls
F16L 41/14 - Joining pipes to walls or pipes, the joined pipe axis being perpendicular to the plane of a wall or to the axis of another pipe by screwing an intermediate part against the inside or outside of the wall
F16L 55/07 - Arrangement or mounting of devices, e.g. valves, for venting or aerating or draining
43.
SAFETY SYSTEMS FOR ISOLATING OVERPRESSURE DURING PRESSURIZED FLUID OPERATIONS
An overpressure safety system (10) for use with a distribution of pressurized fluid associated with hydrocarbon production operations includes a safety valve (20) in fluid communication with a main bore (16) of a fluid control manifold assembly. The safety valve (20) has a blocking condition where the safety valve blocks a flow of pressurized fluid through the safety valve, and a venting condition where the safety valve provides a fluid flow path for the pressurized fluid at a set overpressure to pass through the safety valve. A valve member (22) is moveable within the safety valve between a first position where a pressure side of the valve member blocks the flow of the pressurized fluid at a pressure below the set overpressure from passing through the safety valve, and a second position where the valve member provides a fluid flow path for the pressurized fluid at any pressure to pass through the safety valve.
E21B 33/068 - Well headsSetting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
E21B 34/00 - Valve arrangements for boreholes or wells
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
F16K 39/04 - Devices for relieving the pressure on the sealing faces for sliding valves
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
44.
SELECTOR VALVE FOR HIGH PRESSURE HYDROCARBON PRODUCTION OPERATIONS
An apparatus for directing a fluid from an inlet to one of a plurality of outlets that are associated with a wellhead assembly includes a block body having a block inlet and a plurality of block outlets. A selector plug is located within the block body, the selector plug having a plug inlet aligned with the block inlet along a central axis, a plug outlet at an angle relative to the central axis, and a plug bore extending from the plug inlet to the plug outlet. A stem member is moveable to selectively rotate the selector plug within the block body so that the plug outlet aligns with one of the plurality of block outlets, providing a fluid flow path from the block inlet to such one of the plurality of block outlets, and impeding fluid communication from the block inlet to the others of the plurality of block outlets.
F16K 11/085 - Multiple-way valves, e.g. mixing valvesPipe fittings incorporating such valvesArrangement of valves and flow lines specially adapted for mixing fluid with all movable sealing faces moving as one unit comprising only taps or cocks with cylindrical plug
A gate valve (11) includes a valve body (13) with a flow passage (17) intersected by a gate cavity (15). The gate valve also includes a gate (21) with a gate body. The gate body has a downstream gate body face (25), and an upstream gate body face (23) on an opposite side of the gate body. A seat ring is located between each gate body face and the valve body, at the intersection of the flow passage and the gate cavity. Each seat ring has a seat ring face proximate to the gate. At least one removable insert (49) is located between one of the seat ring faces and one of the gate body faces. The insert is removably coupled to one of the faces and formed of a material harder and more wear resistant as compared to the gate body and the seat ring.
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
46.
INERTIALLY STABLE ACTUATOR WITH TELESCOPING SUPPLY PORT
An apparatus for actuating a valve includes an actuator body with a proximal end having a connector for coupling to a valve assembly, and a distal end. A piston assembly having a piston disposed in a piston cylinder is located within the proximal end of the actuator body. A telescoping port assembly extends from the distal end to the piston assembly, the telescoping port assembly having an inner telescoping member and an outer telescoping member. The outer telescoping member has an inner cavity that reciprocatingly receives an end of the inner telescoping member. A bore extends axially through the telescoping port assembly and communicates pressure from a pressure source to the piston cylinder, so that when a pressure media is supplied from the pressure source to the bore, the piston actuates the valve assembly, and the outer telescoping member telescopes outward from the inner telescoping member.
An apparatus for actuating a valve includes an actuator body with a proximal end having a connector for coupling to a valve assembly, and a distal end. A piston assembly having a piston disposed in a piston cylinder is located within the proximal end of the actuator body. A telescoping port assembly extends from the distal end to the piston assembly, the telescoping port assembly having an inner telescoping member and an outer telescoping member. The outer telescoping member has an inner cavity that reciprocatingly receives an end of the inner telescoping member. A bore extends axially through the telescoping port assembly and communicates pressure from a pressure source to the piston cylinder, so that when a pressure media is supplied from the pressure source to the bore, the piston actuates the valve assembly, and the outer telescoping member telescopes outward from the inner telescoping member.
F16K 31/122 - Operating meansReleasing devices actuated by fluid the fluid acting on a piston
F15B 15/14 - Fluid-actuated devices for displacing a member from one position to anotherGearing associated therewith characterised by the construction of the motor unit of the straight-cylinder type
A valve with a packing assembly includes a valve body assembly (12) with a bore, a valve member (17) moveable between an open position and a closed position, and a valve stem (23) coupled to the valve member. A first stem packing (37) circumscribes a portion of the valve stem, and is located in an upper bore portion of the bore. A first packing retainer (41) has a collar that limits axial movement of the first stem packing, and also has a first retainer body defining an inner cavity. A second stem packing (57) circumscribes a portion of the valve stem and is located in the inner cavity of the first packing retainer. A second packing retainer (67) has a neck compressingly engaging the second stem packing, and a retainer shoulder that engages the first packing retainer. A retaining assembly (84) is coupled with the valve body assembly for applying axial force to the second packing retainer.
F16K 41/04 - Spindle sealings with stuffing-box with at least one ring of rubber or like material between spindle and housing
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
A valve with a packing assembly includes a valve body assembly (12) with a bore, a valve member (17) moveable between an open position and a closed position, and a valve stem (23) coupled to the valve member. A first stem packing (37) circumscribes a portion of the valve stem, and is located in an upper bore portion of the bore. A first packing retainer (41) has a collar that limits axial movement of the first stem packing, and also has a first retainer body defining an inner cavity. A second stem packing (57) circumscribes a portion of the valve stem and is located in the inner cavity of the first packing retainer. A second packing retainer (67) has a neck compressingly engaging the second stem packing, and a retainer shoulder that engages the first packing retainer. A retaining assembly (84) is coupled with the valve body assembly for applying axial force to the second packing retainer.
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
F16K 41/04 - Spindle sealings with stuffing-box with at least one ring of rubber or like material between spindle and housing
A casing head assembly for landing on a stem head of a floating structure can include a stem head adapter assembly that includes a ring shaped stem head adapter plate. A solid upper ring is spaced axially above the stem head adapter plate, defining an adapter gap between the upper ring and the stem head adapter plate. At least one load cell can have a first end that is supported by the stem head adapter plate and a second end that engages the upper ring. At least one piston assembly is selectively secured to the upper ring. The casing head assembly also includes a casing head landed on, and secured to, the upper ring of the stem head adapter assembly. The load cell is selectively constrained between the upper ring and the stem head adapter plate by a load on the casing head.
A tool for polishing a seal surface of a wellhead assembly includes a cylindrical tool body having a base member and a tubular skirt member (31) extending from the base member. Circumferentially spaced axial slots (59) extend through the skirt member and a polishing belt is woven through the slots.
A tool for polishing a seal surface of a wellhead assembly includes a cylindrical tool body with an axis. The tool body includes a base member with a first end, and a second end. A tubular skirt member extends from the second end of the base member. The skirt member has a sidewall, a base end connected to the base member, and an open end opposite the base end. A plurality of axial slots extend through the sidewall of the skirt member, the axial slots being spaced circumferentially around the skirt member. A polishing belt is woven through the axial slots of the skirt member.
A method for completing a well includes drilling a well through a wellhead having an annular bowl protector inserted therein. The bowl protector has an internal recess. A lower end of a casing string is lowered through the bowl protector. A centralizer having a plurality of lugs on an outer surface is installed on a retrieval joint of casing of the casing string. The retrieval joint of casing and the centralizer is lowered so the lugs engage the internal recess of the bowl protector. The retrieval joint of casing is raised to lift the centralizer and bowl protector out of the wellhead.
A gate valve (11) includes a body with a flow passage (17, 19) intersected by a gate cavity (15) and a gate (21) with an axis (20), the gate being axially movable in the gate cavity between a gate closed position and a gate open position. A lifting device (25) is in engagement with a stem (34) of the gate to move the gate to the gate open position. A port (57) extends from a first external surface (29) of the gate to a second external surface(53) of the gate. A seal member (59) is mechanically connected to the lifting device, the seal member being moveable in response to axial movement of the lifting device between a seal open position where fluids can flow through the port and a seal closed position where the seal member blocks fluids from flowing through the port.
F16K 39/04 - Devices for relieving the pressure on the sealing faces for sliding valves
E21B 34/06 - Valve arrangements for boreholes or wells in wells
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
An apparatus for assisting an actuator (13) to close a valve (107) has a cylindrical booster housing (11) with a central axis. The booster housing includes an upward facing piston cavity (45) and a downward facing lower cavity (51) with internal threads (36) for selectively coupling with external threads of a piston head (23) of a valve actuator. A bulkhead (61) is formed between the piston cavity (45) and the lower cavity (51). The bulkhead has an opening (63) for selectively accepting an actuator stem (35) of the valve actuator therethrough. A booster piston (67) is located within the piston cavity. The booster piston is moveable upwards in an axial direction to move the valve (107) from a lower open position to an upper closed position.
E21B 33/072 - Well headsSetting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells for cable-operated tools
E21B 34/02 - Valve arrangements for boreholes or wells in well heads
F16K 31/122 - Operating meansReleasing devices actuated by fluid the fluid acting on a piston
An apparatus for overriding a valve actuator to move a valve stem to a second position includes an override body with a central axis. A piston is located within the override body. A bushing is non-rotatably carried within the override body. An override shaft is in threaded engagement with the bushing and extends through a sealed orifice in the override body. Fluid pressure applied to the piston causes the bushing to engage the valve actuator and push the valve stem, and alternatively, rotation applied to the override shaft causes the bushing to move linearly to engage the valve actuator and push the valve stem.
F16K 31/122 - Operating meansReleasing devices actuated by fluid the fluid acting on a piston
F16K 31/50 - Mechanical actuating means with screw-spindle
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
An apparatus (11) for overriding a valve actuator (13) to move a valve stem (35) to a second position includes an override body (201) with a central axis. A piston (227) is located within the override body. A bushing (219) is non-rotatably carried within the override body (201). An override shaft (235) is in threaded engagement with the bushing (219) and extends through a sealed orifice in the override body (201). Fluid pressure applied to the piston (227) causes the bushing (219) to engage the valve actuator (13) and push the valve stem (35), and alternatively, rotation applied to the override shaft (235) causes the bushing to move linearly to engage the valve actuator and push the valve stem.
F16K 31/122 - Operating meansReleasing devices actuated by fluid the fluid acting on a piston
F16K 31/50 - Mechanical actuating means with screw-spindle
F16K 31/05 - Operating meansReleasing devices electricOperating meansReleasing devices magnetic using a motor specially adapted for operating hand-operated valves or for combined motor and hand operation
58.
VALVE PACKING SHIELD FOR USE IN HYDROCARBON OPERATIONS
A valve assembly includes a valve body (12) defining a flow passage and a body cavity (20) perpendicular to the flow passage. A bonnet (14) is secured to the valve body. A valve member is moveable between an open position and a closed position, the valve member blocking the flow passage in the closed position, and allowing flow through the flow passage in the open position. A valve stem (16) is coupled to the valve member. A debris barrier (38) circumscribes the valve stem (16). The debris barrier comprises a first disk shaped member (40) with a central opening through which the valve stem is inserted, and notches that extend radially from the central opening to define petals (44) with ends that abut the valve stem (16).
A valve assembly includes a valve body defining a flow passage and a body cavity perpendicular to the flow passage. A bonnet is secured to the valve body. A valve member is moveable between an open position and a closed position, the valve member blocking the flow passage in the closed position, and allowing flow through the flow passage in the open position. A valve stem is coupled to the valve member. A debris barrier circumscribes the valve stem. The debris barrier comprises a first disk shaped member with a central opening through which the valve stem is inserted, and notches that extend radially from the central opening to define petals with ends that abut the valve stem.
F16K 41/08 - Spindle sealings with stuffing-box with at least one ring provided with axially-protruding peripheral closing-lip
F16K 41/04 - Spindle sealings with stuffing-box with at least one ring of rubber or like material between spindle and housing
F16K 41/14 - Spindle sealings with conical flange on the spindle which co-operates with a conical surface in the housing
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
60.
COMBINATION FLUID PUMPING SUB AND HANGER LOCKDOWN TOOL
A tool (10) for retaining an activator ring (20) of a hanger (16) within a wellhead assembly (14) during a fluid pumping process includes an annular fluid pumping sub body (24) having an end selectively coupled with a supply of fluids and a distal end selectively coupled with the hanger. An outer ring assembly (36) circumscribes and rotates relative to the fluid pumping sub body. A retainer ring (46) circumscribes the fluid pumping sub body and selectively abuts the activator ring. A plurality of biasing assemblies (48) that are selectively compressible are located between the outer ring assembly and the retainer ring, so that when the fluid pumping sub body is coupled with the hanger, an axial lockdown force is maintained on the activator ring by the biasing assemblies during the fluid pumping process.
A modular, adjustable system (10) for distributing fluids to one or more wellheads (12) includes a plurality of modules (16) that can be arranged at a well site to create an appropriate manifold to enable selective fluid communication between a fluid pumping system (18) and the one or more wellheads. The modules each include a fluid inlet, a fluid outlet and a valve coupled therebetween to selectively permit or restrict fluid flow between the respective fluid inlets and fluid outlets. The modules are configured to be readily maneuvered, coupled and locked to one another at a well site.
A wellhead assembly (10) includes a casing head (20), tubing head (42), and a production tree mounted on the tubing head. An isolation sleeve (50) is set in a main bore (46) of the wellhead assembly that extends across an interface between the casing and tubing heads so that a portion resides in each. The isolation sleeve is configured so that a fracturing string (72), and its associated hanger (74), can be retrieved through the isolation sleeve; which significantly reduces the time and steps required to conduct a fracturing operation in a well. Moreover, the present isolation sleeve can be used without changes to existing casing or tubing heads.
37 - Construction and mining; installation and repair services
39 - Transport, packaging, storage and travel services
Goods & Services
(1) Services in the field of oil and gas exploration and development namely, maintenance, repair, and refurbishment of equipment; rental, leasing, and sales of equipment, all the aforementioned relating to equipment used in fracturing operations in shale oil and shale gas exploration; delivery and installation of equipment, all the aforementioned relating to equipment used in fracturing operations in shale oil and shale gas exploration.
An actuator for operating a linear valve, such as a gate valve, includes a quick connect coupling between the housing and at least one of a bonnet and a power head assembly. In embodiments, the quick connect coupling includes a plurality of lugs spaced apart around an annular actuator housing surface, and a plurality of lugs spaced apart around an annular surface of another member such as a bonnet or power head, each of the lugs defining a plurality of slots therebetween. The lugs pass through corresponding slots, and then the housing is rotated relative to the other member until at least a portion of the lugs of each component are axially aligned in a locked position. The rotation is less than one full revolution of the rotated component. A latch prevents the component from rotating out of the locked position.
F15B 15/12 - Fluid-actuated devices for displacing a member from one position to anotherGearing associated therewith characterised by the construction of the motor unit of the oscillating-vane or curved-cylinder type
F15B 15/14 - Fluid-actuated devices for displacing a member from one position to anotherGearing associated therewith characterised by the construction of the motor unit of the straight-cylinder type
An actuator for operating a linear valve, such as a gate valve, includes a quick connect coupling between the housing and at least one of a bonnet and a power head assembly. In embodiments, the quick connect coupling includes a plurality of lugs spaced apart around an annular actuator housing surface, and a plurality of lugs spaced apart around an annular surface of another member such as a bonnet or power head, each of the lugs defining a plurality of slots therebetween. The lugs pass through corresponding slots, and then the housing is rotated relative to the other member until at least a portion of the lugs of each component are axially aligned in a locked position. The rotation is less than one full revolution of the rotated component. A latch prevents the component from rotating out of the locked position.
F15B 15/12 - Fluid-actuated devices for displacing a member from one position to anotherGearing associated therewith characterised by the construction of the motor unit of the oscillating-vane or curved-cylinder type
F15B 15/14 - Fluid-actuated devices for displacing a member from one position to anotherGearing associated therewith characterised by the construction of the motor unit of the straight-cylinder type
66.
TENSION TUBING HANGER AND METHOD OF APPLYING TENSION TO PRODUCTION TUBING
A tubing hanger assembly (25) includes a tubular outer tubing hanger member (27) adapted to land in a bore of a wellhead (13). A tubular inner tubing hanger member (37) is adapted to be secured to a string of production tubing (39) and has an engaged position in a bore of the outer tubing hanger member. A retaining mechanism (35, 47, 73, 83) selectively allows the inner tubing hanger member to be lowered relative to the outer tubing hanger member, then selectively allowing the inner tubing hanger member to be returned back to the engaged position, to create tension in the string of production tubing. The retaining mechanism operates in response to rotational movement of the inner tubing hanger member while the outer tubing hanger member remains stationary with the wellhead.
An apparatus for actuating a valve includes a housing having an axis, a valve end, a cap end, and a cylindrical sidewall defining an inner diameter surface of the housing. A cap is connected to the cap end of the housing. An inlet is located in one of the cap and the housing. A plate is positioned within the housing, the plate having an outer diameter that slidingly engages the inner diameter surface of the housing. The plate moves between an extended position and a retracted position in response to pressure media from the inlet. A down stop is in contact with the plate. A seal nut has a first end in engagement with the down stop. The seal nut has a second end with an end surface, the end surface being spaced apart from the cap when the plate is in the extended position.
F16K 31/126 - Operating meansReleasing devices actuated by fluid the fluid acting on a diaphragm, bellows, or the like
F15B 15/10 - Fluid-actuated devices for displacing a member from one position to anotherGearing associated therewith characterised by the construction of the motor unit the motor being of diaphragm type
F15B 15/14 - Fluid-actuated devices for displacing a member from one position to anotherGearing associated therewith characterised by the construction of the motor unit of the straight-cylinder type
F15B 15/28 - Means for indicating the position, e.g. end of stroke
F15B 15/24 - Other details for restricting the stroke
A grease tool (63) lubricates a valve (11) having an actuator assembly (33) for moving a valve element (25) of the valve. The tool has a housing (65) with a piston (81) carried in a bore (71). The housing is open for inserting and sealing a portion of the actuator assembly (45 within 33) into the bore. A fill port (93) in the housing allows grease to be introduced into the bore. A piston rod (85) joins the piston and has external threads engaging internal threads of the housing, so that rotating the piston rod causes the piston to move axially. A lever (101) is mounted to the housing for imparting rotation to the housing. A lock pin (79) extends through a side wall of the housing to engage the actuator assembly to cause the actuator assembly to rotate in unison with the housing.
A grease tool (63) lubricates a valve (11) having an actuator assembly (33) for moving a valve element (25) of the valve. The tool has a housing (65) with a piston (81) carried in a bore (71). The housing is open for inserting and sealing a portion of the actuator assembly (45 within 33) into the bore. A fill port (93) in the housing allows grease to be introduced into the bore. A piston rod (85) joins the piston and has external threads engaging internal threads of the housing, so that rotating the piston rod causes the piston to move axially. A lever (101) is mounted to the housing for imparting rotation to the housing. A lock pin (79) extends through a side wall of the housing to engage the actuator assembly to cause the actuator assembly to rotate in unison with the housing.
A method of completing a well 11 includes lowering a wellhead 21 onto a base at an upper end of the well 11. A hub 37 with internal threads and an external circumferential stepped recess is secured to external threads 29 of the wellhead 21. A blowout preventer assembly 53 with an annular locking member 43 having a plurality of locking elements 45 is landed on the hub 37, and the locking elements 45 are engaged with the recess of the hub 37. The well 11 is drilled through the blowout preventer assembly 53 to a greater depth then the blowout preventer assembly 53 and the hub 37 are removed. A threaded flange 81 with a plurality of bolt holes spaced around the flange is secured to the external threads 29 of the wellhead 21 and a wellhead member 83 is bolted to the bolt holes of the threaded flange 81.
A fracturing system (17) includes a fracturing spool (18) that mounts onto a wellhead assembly (10) for injecting fracturing fluid into a well (12) beneath the wellhead assembly (10). An isolation sleeve (42) is included with the fracturing system (17) that couples to the fracturing spool (18) and extends into the wellhead (10) to isolate and protect portions of the wellhead assembly (10) from the fracturing fluid. A seal (52) is between the isolation sleeve (42) and bore (49) of the wellhead assembly (10), which is threaded to the isolation sleeve (42). Manipulating the threaded connection between the isolation sleeve (42) and seal (52) selectively positions the isolation sleeve (42) to designated axial positions within the wellhead assembly (10).
A fracturing system 22 includes a fracturing spool 24 that mounts onto a wellhead assembly 10 for injecting fracturing fluid into a well beneath the wellhead assembly 10. The fracturing system 22 includes an isolation sleeve 52 and fracturing spool 24. The isolation sleeve 52 inserts in an axial bore 53 of the fracturing spool 24, and has a lower end that extends into the wellhead to isolate and protect portions of the wellhead assembly 10 from the fracturing fluid. A groove in an inner surface of the fracturing spool 24 receives an annular seal for sealing between the isolation sleeve 52 and fracturing spool 24. Injecting a viscous fluid into the groove energizes the seal, and blocks high pressure fracturing fluid from flowing between the isolation sleeve 52 and fracturing spool 24.
Described herein is a modular, adjustable system (10) for distributing fluids to one or more wellbores (18). The system (10) is readily configured and assembled at a well site, and allows for one portion of the system (10) to be isolated for service or repair while the remainder of the system (10) continues to operate. The system includes a plurality of pump skids (32, 232) having both a distribution junction (30) in fluid communication with inlets (35) to of plurality of pump trucks (16) and an exit junction (40) in fluid communication with outlets (37) of the plurality of pump trucks (16).
A gate valve seat for a gate valve includes a seat (101) having a stepped outer wall surface, with a spring (102), spacer ring (103), front facing lip seal (104), and a rear facing lip seal (105) disposed about the stepped outer surface of the seat. The spring (102) may be releasably locked into a compressed configuration for installation of the gate of the gate valve.
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
F16K 3/20 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor with special arrangements for separating the sealing faces or for pressing them together by movement of the seats
A dual barrier plug system (100) includes a frac spool (110), having a dual barrier plug (130) disposed within the interior of the frac spool; a valve selector member (180) disposed within the interior of the dual barrier plug; and the plurality of seals (45, 46) are used to seal fluid flow from below the frac spool, and the seals provide two barriers to each fluid flow.
