391 results about "Tubing hanger" patented technology

A tubing assembly including a tubing string and tubing hanger provides a fluid passage with backpressure threads for securing a backpressure plug in a fluid-tight seal below the tubing hanger, so that the tubing hanger can be removed from the tubing string. The back pressure threads are preferably incorporated in a backpressure adapter pin connected between the tubing string and the tubing hanger. The adapter pin may also incorporate external weight-bearing shoulders for snubbing and / or suspending the tubing assembly. The backpressure plug is inserted or removed using a backpressure plug tool that slides through a packing in a pressurized casement that maintains pressure in an axial passage through a control stack of the wellhead.

A subterranean oil or gas well apparatus is provided. The apparatus includes a single-bore production tubing hanger arranged concentric with a wellhead. The tubing hanger includes a plurality of ports and channels arranged about the tubing hanger to give operators access to the production tubing annulus and provide chemical injection capability. The ports are closable by a sliding valve. The apparatus also includes annulus and production radial-bore stab assemblies between a christmas tree and an internal crossover assembly. The stab assemblies are extendable and retractable between the chirstmas tree and the crossover assembly to allow the retrieval and installation of each independently.

A running string for a subsea completion comprises an upper section (70) which may be a coiled tubing (CT) injector unit as shown, or a wireline lubricator (FIG. 8). A lower section (60) provides wireline / CT access to production / annulus bores of a tubing hanger (not shown) attached to tubing hanger running tool (62). A flow package (64) in the lower section (60), together with BOP pipe rams (86) and annular seal (88), directs production and annulus fluid flows / pressures to the BOP choke / kill lines (78 / 76). The upper and lower sections allow installation and pressure / circulation testing of, and wireline / CT access to, a subsea completion, without the use of a high pressure riser.

Subsea wells are drilled and completed with an offshore floating platform in a manner that allows simultaneous work on more than one well. A first well is drilled and cased. Then a tubing hanger is run through a drilling riser and landed in the wellhead housing. Then, with the same floating platform, the drilling riser is disconnected and moved to a second well. While performing operations on the second well, the operator lowers a production tree from the floating platform on a lift line, and connects it to the first wellhead housing. An ROV assisted subsea plug removal tool is used for plug removal and setting operations. Seabed separation is configured upstream of a production choke valve.

A subsea wellhead assembly has a tubing hanger with a tubing annulus passage and a production passage. A metal-sealing shuttle valve is mounted in the tubing hanger for blocking upward flow through the tubing annulus passage. The shuttle valve has a retention mechanism that prevents the shuttle from moving to the open position when fluid pressure is applied from above. The retention mechanism is released by the running tool after testing has been completed, causing the shuttle to close. The tree has an engaging member that can be stroked downward into the tubing hanger annulus passage to move the shuttle valve to the open position for communicating with the annulus.

The present invention includes a tubing hanger suspension assembly for an oil and gas well completion system and a method of installing same. The tubing hanger suspension assembly includes a tubing hanger housing which is positioned in the wellhead housing. The tubing hanger assembly includes a sealing and lockdown mechanism capable of providing sealing and load support of the production tubing in the production casing string. A stab sub assembly connected to the upper end of the tubing hanger suspension assembly and lower end of the Christmas tree assembly provides downhole hydraulic and electric functionality and annulus access to the production tubing.

A method and system of operating a landing string utilized on a floating platform. The landing string is disposed within a marine riser, with the marine riser being connected to a subsea production tree, and wherein the subsea production tree contains internal conduits communicating controls through a series of stab passageways. The method comprises providing a tubing hanger operatively connected to the landing string, delivering hydraulic or electrical controls from the floating platform through a control system umbilical to a junction plate operatively attached to the subsea production tree. The method further comprises landing the tubing hanger into the subsea production tree, establishing control of the tubing hanger by providing the hydraulic controls to the tubing hanger with the series of stab passageways through the subsea production tree, and establishing control of the completion bottom hole assembly with the stab passageways. In the preferred embodiment, the landing string has attached thereto a completion bottom hole assembly that will be placed in the well.

The wellhead assembly has a production tree with multiple safety barriers. A tubing hanger lands and seals in the bore of the tree. The tubing hanger has a lateral production flow passage that registers with a lateral passage in the tree. A tubing annulus passage extends upward from the tubing annulus to an exterior port. A second portion of the tubing annulus passage extends upward from the exterior port into the bore above the tubing hanger seal. The external port may be used for gas injection. If so, two closure members are located in the upper portion of the tubing annulus above the seal. The upper closure member may be either a check valve or a removable plug.

A system for providing power to elements down-hole in a subsea well includes a control pod having at least one shuttle valve, a down-hole hydraulically-actuated device having at least one internal porting mechanism in fluid communication with the at least one shuttle valve, a blowout preventer stack connected to the down-hole device, the blowout preventer stack including a first ram and a second ram, and a choke line in fluid communication with an area between the first ram and the second ram. The at least one shuttle valve controls distribution of hydraulic pressure applied through the choke line to the internal porting mechanism for selective distribution of power to the hydraulically-actuated device.

A flow completion apparatus comprises a wellhead housing installed at an upper end of a well bore and a tubing spool connected over the wellhead housing. The tubing spool includes a central bore extending axially therethrough, a production outlet communicating with the central bore and an annulus passageway communicating with the tubing annulus. A tubing hanger is supported in the central bore and includes a production bore extending axially therethrough and a production passageway communicating between the production bore and the production outlet. The tubing spool comprises a workover passageway extending between the annulus passageway and a portion of the central bore located below the top of the tubing hanger. Furthermore, the tubing hanger comprises an annulus bore extending between the workover passageway and the top of the tubing hanger.

A method of completing a well having a casing hanger set in a subsea wellhead housing includes attaching a running tool to a tubular bridging hanger. A metal-to-metal inner seal is attached to a lower exterior portion of the bridging hanger and a metal-to-metal outer seal is located on an upper exterior portion of the bridging hanger. The assembly is lowered into the well and the lower exterior portion of the bridging hanger is inserted into the casing hanger. The inner seal is wedged between the casing hanger and the bridging hanger in response to weight of the running string. The running tool is actuated to set the outer seal between the upper exterior portion of the bridging hanger and the wellhead housing. Then, a tubing hanger is landed and sealed in the interior of the bridging hanger.

A completion system, and a corresponding method, for completing a subsea well, where the well includes a wellhead and a tubing hanger disposed in the wellhead and supports a string of production tubing, allows for angular alignment-free assembly of the subsea well. The completion system includes a series of circumferential channels formed in a well completion device at a boundary between the tubing hanger and the well completion device. The circumferential channels provide complete circular fluid paths with respect to the tubing hanger and the well completion device. At least one supply bore is in communication with each circumferential channel and is and oriented to supply a fluid to the circumferential channel, and at least one drain bore in communication with each circumferential channel and is oriented to remove fluid from the circumferential channel. Finally a circumferential electrical connector couples the tubing hanger and the completion device. The circumferential channels and bores provide fluid services between the completion device and the tubing hanger and the electrical connector provides electrical services to the tubing hanger. The completion system allows the fluid and electrical services to be provided without requiring any angular alignment between the tubing hanger and the completion device.

A system, apparatus, and method to apply tension to completion tubing in a wellbore. The system, apparatus, and method comprises an inner and outer tubing hanger, with the string of tubing attached to the inner tubing hanger. A running tool lands the outer tubing hanger on a landing shoulder and continues to lower the inner tubing hanger into the wellbore until the lower end of the inner tubing hanger latches into a retaining device. The running tool then sets a seal which holds the outer tubing hanger in position and causes a ratcheting mechanism to move to an engaged position. The running tool then withdraws the inner tubing hanger a predetermined distance until the inner tubing hanger engages the ratcheting mechanism.

The invention relates to a mechanical recovery horizontal well preset produced fluid profile testing method and a special wellhead testing device thereof, mainly aiming at solving the problem of the downhole testing of a mechanical recovery horizontal well. The invention is characterized in that: the special wellhead testing device comprises an eccentric type tubing hanger body connected with a tubing string, wherein, the side wall of the tubing hanger body is divided into a body and splits which are completely matched with each other, and the splits are fixed on a locking arm which is fixed on the body though bolts; and a corresponding matched cable penetrating a channel is arranged at the splitting seam of the body and the splits, the channel is internally provided with a cable gasket, a spacer and a pressing cap. By being matched with a special wellhead support, under the condition that a testing cable and a tester are pre-arranged in the horizontal well to test a target layer, an oil pipe does not touch the cable during the up and down process of the oil pipe. The method and the special wellhead testing device can realize the produced fluid profile testing of the mechanical recovery horizontal well, and ensure the accuracy of normal testing and data of the mechanical recovery horizontal well with simple and reliable operation method.

A completion system comprises a christmas tree (10) mounted on a wellhead housing (11), a tubing hanger (12) landed in the tree or wellhead housing, the wellhead housing (11) being mounted on a casing string (100) and a tubing string (14) being suspended from the tubing hanger within the casing string; wherein, in use, the annulus defined between the tubing (14) and the casing (100) serves as a production bore. A second tubing string (98) is expanded into sealing engagement with the casing string (100) over at least a portion of their lengths. The annulus normally used to provide well service functions is thus eliminated. Well servicing is instead provided via the tubing string (14), which may be coiled tubing.

The invention relates to an underwater cable connector. An insertion head part is installed in an oil tube suspender, a piston A is arranged in an insertion head chamber in the oil tube suspender, the axle center of the piston A is sleeved on an insertion head conducting ring, two ends of the insertion head conducting ring are respectively provided with insertion head non-conductive parts, a spring A is sleeved at the periphery of a rear insertion head non-conductive part, and a cable A is connected with the insertion head conducting ring; a socket part is fixed on an underwater Christmas tree body and in a socket chamber of a socket shell, a socket body is sleeved in an internal guiding sleeve of the socket shell, a guiding column is arranged at the axle center of the socket body, and a socket conducting ring is arranged on the contact surface of the guiding column and the socket body; a spring B is arranged in a spring chamber of the socket body, and the bottom of the spring chamber is connected with a hydraulic pressure compensated cavity; a compensation liquid flow channel is additionally formed in the socket body; the socket conducting ring is connected with outside by the cable B; and the inner cavity of the compensated cavity shell is sequentially provided with the hydraulic pressure compensated cavity, and the piston B and a second spring chamber. The device realizes the underwater reliable insertion and pulling connection.

A subsea wellhead assembly has a tubing hanger landed in a wellhead housing. A spool lands on the wellhead housing and has a bore with a laterally extending production flow outlet. A tree cap having an axially extending flow passage and a laterally extending production flow outlet lands within the bore of the spool. Upper and lower seals on the tree cap seal between the tree cap and the bore of the spool above and below the production flow outlet of the spool. An isolation tube on a lower end of the tree cap sealingly engages the production flow passage of the tubing hanger. The tree cap may be ran with the spool as an assembly and retrieved from the spool for workover operations.

A method of completing a well having a casing hanger set in a subsea wellhead housing includes attaching a running tool to a tubular bridging hanger. A metal-to-metal inner seal is attached to a lower exterior portion of the bridging hanger and a metal-to-metal outer seal is located on an upper exterior portion of the bridging hanger. The assembly is lowered into the well and the lower exterior portion of the bridging hanger is inserted into the casing hanger. The inner seal is wedged between the casing hanger and the bridging hanger in response to weight of the running string. The running tool is actuated to set the outer seal between the upper exterior portion of the bridging hanger and the wellhead housing. Then, a tubing hanger is landed and sealed in the interior of the bridging hanger.

A subsea wellhead assembly provided over a wellbore, the assembly having a wellhead housing, a tubing hanger in the housing, a production tree on the wellhead housing above the tubing hanger, and a control circuit that passes axially downward from the production tree and through the tubing hanger. A tree stab assembly may be included that is set between the tubing hanger and production tree. The wellhead assembly can also include a casing hanger landed in the housing, casing attached to the casing hanger, and tubing attached to the tubing hanger.

A subsea wellhead assembly allows communication between a production tubing annulus and a conduit in fluid communication with a platform above. The wellhead assembly has a tubing hanger that is held relative to a tubular wellhead member of a subsea well by a tubing hanger support. A string of tubing extends from the tubing hanger into the well, defining an annulus around the tubing. The conduit communicates with the tubing annulus through a tubing annulus passage. The tubing annulus passage has a portion extending through the tubing hanger support. The wellhead member supports a valve block located between the tubing hanger support and the riser. The tubing annulus passage has another portion that registers with the portion of the passage in the tubing hanger support. The conduit stabs into valve block portion of the tubing annulus passage when the riser connects to the upper end of the valve block.

A tubing hanger and wellhead have features for controlling and monitoring fluid pressure to downhole equipment. The tubing hanger has an internal vertical passage. A hydraulic line connects to the lower end of the vertical passage and runs downhole. The vertical passage communicates with a lateral passage through the outer wall of the hanger. A lateral passage through the wellhead housing is generally aligned with the lateral passage of the hanger when the hanger is installed in the wellhead housing. A pressure shaft is installed in the wellhead passage and has a passage therethrough. A seal member having spherical ends is inserted between spherical receptacles located on the inner end of the pressure shaft passage and on the outer end of the lateral passage of the hanger. The seal member has an internal passage having a flared inner end. The seal member is allowed to rotate to sealingly connect the lateral passages if some misalignment of the lateral passages exists. A gage or other pressure monitoring device or a source of hydraulic pressure can be attached to the outer end of the pressure shaft to communicate with the shaft passage.