Abstract: The present application pertains to a coiled tubing injector system. The system comprises a coiled tubing injector; an injector tilt configured to be mounted to a trailer wherein the injector tilt is configured to receive the coiled tubing injector; a securing mechanism to secure the coiled tubing injector to the injector tilt; and a sensor configured to detect whether the securing mechanism is positioned to substantially secure the coiled tubing injector to the injector tilt. Advantageously, the system is configured such that the injector can only be tilted if the sensor detects that securing mechanism is positioned to substantially secure the coiled tubing injector to the injector tilt.

Abstract: A conductor assembly comprising a conductor of an offshore platform and a guide surrounding the conductor. The guide extending from an upper end to a lower end and having a main portion therebetween, a stabilising body defining a bore extending therethrough, the conductor extending through the bore of the stabilising body, the stabilising body provided between the conductor and the guide optionally the stabilising body comprising an inner body and an outer body. In this way, the conductor is allowed to move vertically within the guide with the only moving surfaces in contact being an outer surface of the inner body and the inner surface of the outer body, thus mitigating or eliminating abrasion of the conductor and/or guide.

Abstract: Some embodiments may include a coil tubing injector, which may include: a cylinder-rod assembly including at least one cylinder rod operably coupled to a first load beam and a second load beam, the at least one cylinder rod to change a separation distance between the first load beam and the second load beam; opposing grippers; and at least one additional beam, at least one link, a set of gears, or control valves to maintain a parallel orientation of the load beams relative to each other during operation of the at least one cylinder rod, the at least one additional beam, the at least one link, or the set of gears operably coupled to at least one of the load beams or the control valves coupled to hydraulic piping to hydraulically operate the cylinder-rod assemblies independently. Other embodiments may be disclosed and/or claimed.

Abstract: A method of building and operating a land-based drilling rig with a high-capacity mast include providing a platform collapsed on a substructure over a proposed well drilling location and building the high-capacity mast in a horizontal condition by attaching a lower portion of the high-capacity mast to the platform. The high-capacity mast having an opening formed therein sized to accommodate four Range 2 pipes or three Range 3 pipes. The high-capacity mast may be raised from the horizontal condition to a vertical condition by pushing the side of the high-capacity mast to pivot the high-capacity mast about a pivot point on the platform. The platform may be raised from a collapsed condition to a raised condition over the substructure. Some implementations include dual racking boards on the high-capacity mast.

Abstract: A pivoting guide arch is provided. The guide arch includes a guide having a curved portion to receive a coiled tube and to guide the tube as the tube traverses between a reel and a wellbore. The guide arch also includes a support structure extending from a first end of the guide that is configured to mechanically support the guide, and a swivel mount that is rotatably coupled to a wellhead to enable the guide and support structure to pivot about an axis of the wellhead.

Abstract: A method of assembling an optical fiber cable on production casing includes positioning the optical fiber cable against a production casing at a hole of a well site, and affixing the optical fiber cable against the production casing by applying an adhesive to the production casing to secure the optical fiber cable against the production casing. The method further includes applying pressure to the adhesive to adhesively bond the optical fiber cable to the production casing along a length of the production casing while the production casing is being run-in-hole.

Abstract: A trigger mechanism is provided for a passive rotating jointed tubing injector having gripper blocks for moving connected, segmented oilfield tubulars axially into or out of horizontal, extended-reach oil and natural gas wells that may contain pressurized fluid or gas to complete for production, work over and service the wells, utilizing an operation commonly known as snubbing. The trigger mechanism can open the gripper blocks when a tapered upset section of increasing diameter on the tubulars is encountered that would not otherwise fully open and operate the gripper blocks.

Abstract: A method of building and operating a land-based drilling rig with a high-capacity mast include providing a platform collapsed on a substructure over a proposed well drilling location and building the high-capacity mast in a horizontal condition by attaching a lower portion of the high-capacity mast to the platform. The high-capacity mast having an opening formed therein sized to accommodate four Range 2 pipes or three Range 3 pipes. The high-capacity mast may be raised from the horizontal condition to a vertical condition by pushing the side of the high-capacity mast to pivot the high-capacity mast about a pivot point on the platform. The platform may be raised from a collapsed condition to a raised condition over the substructure. Some implementations include dual racking boards on the high-capacity mast.

Abstract: A drilling rig includes a base section, a first section, a second section, a third section and a fourth section. For the base section upper region, a fixed pulley block and a guide pulley are installed. Except for the fourth section-crown block section, each section lower region is installed with a lifting lug for a movable pulley block installation for substantially vertical lifting. The crown block section is installed substantially vertical; the subsequent section is located substantially horizontal with the section front pillar upper region connecting to the previous section front pillar lower region. The previous section is substantially vertical lifted to draw the next section skidding into the base section and lifting substantially vertical with the previous section pillar lower region connected to the next section pillar upper region.

Abstract: A mobile well service unit has a structural frame with a front end and a rear end, and defining an axis between the front end and the rear end; a platform mounted at the front end or the rear end of the structural frame and configured to move up and down relative to the structural frame; and ground engaging members mounted to the structural frame and configured to permit the mobile well service unit to move laterally, relative to the axis, across a ground surface. A method of use involves translating the unit laterally.

Abstract: A device includes a base configured to be coupled to a storage segment of a pipe support assembly. The device also includes an arm configured to be coupled to the base. The arm is configured to provide lateral support to a pipe when the pipe is disposed in a storage area adjacent to a first portion of the storage segment. The arm is also configured to move in a horizontal direction from a first location in which an end of the arm is disposed at a first horizontal distance from the storage segment to a second location in which the end of the arm is disposed at second horizontal distance from the storage segment when a force greater than or equal to a predetermined level is applied to the arm.

Abstract: A wellhead assembly includes an annulus access valve (AAV) disposed in a wellhead hanger. Upper and lower annulus access bores intersect the bore at upper and lower ports. The AAV includes a body that reciprocates within the bore between open and closed positions. Hydraulic fluid moves the body between the open and closed positions. Axially spaced apart upper and lower apertures are formed through the body outer surface allow communication to a chamber within the body. When in the open position, the upper and lower apertures respectively register with the inlet and outlet ports so that the upper and lower annulus access bores are in communication through the AAV. When in the closed position, a solid portion of the body registers with one of the inlet or outlet ports, thereby blocking communication through the AAV between the upper and lower annulus access bores.

Abstract: The present invention provides an apparatus for retaining rig slips gripping a drill pipe through a bore of a flow control device. The apparatus includes a plate and a support means. The plate has an aperture that constricts the rig slips against passing trough the aperture. The support means attaches the plate to the flow control device, such that the axis of the drill pipe and the bore are substantially parallel with each other.

Abstract: A wellhead system includes a bypass sleeve for temporarily isolating portions of a wellhead assembly from pressurized fracing fluid. The bypass sleeve may include a generally tubular body having a tool interface, a lock ring disposed at least partially around the body, and an anti-rotation device coupled to the body. The anti-rotation device includes a resilient member disposed in a cavity in the body, and an anti-rotation member biased away from the body by the resilient member. The anti-rotation member extends radially outward from the body.

Abstract: A stabilizer to suppress unwanted pivotal movement in pipe handling equipment suspended from bails. The stabilizer can contain either or both adjustable contacting members and non-adjustable contacting members which are rigidly connected to a portion of the pipe handling equipment. The adjustable contacting members contact the bails on one or both sides of the bail(s) to suppress motion of the elevator relative to the bail.

Abstract: The Free Mandrel System, Protected Casing is to be applied in the petroleum industry for selective injection of fluids, liquids or gases, in different formations while keeping the casing isolated from fluid pressure. As it is hydraulically driven by the injection fluid, an operator can handle the provided surface valves. The system includes five assemblies: Surface, Transport, Free Mandrel, Fixed Bottom Hole and Complementary. The Free Mandrel Assembly is the dynamic main device that carries all the Injection valves together, one for each formation, from the Fixed Bottom Hole to the surface in 30? and vice versa. As this operation is performed many times in the well lifetime, it allows a cumulative time and money saving. Workover equipment is only used for installing the system and for fixing the required packers. Formation Pressure is kept at any time when the system is either operated, set up, or pulled up.

Abstract: An excavator is provided, in which the excavator includes a head that is slidably mounted on a leader, and a position fixture assembly slidable along the leader via the head. The position fixture includes a support plate including a groove in it top surface, with a first rod slidable within the groove. The position fixture also including a locking unit that serves to engage a base member, allowing the base member to be elevated when the head is elevated.

Abstract: The articulated wireline hole finder is a modular device which attaches to the bottom of a wireline logging tool-string to aid conveyance down irregular shaped and/or deviated boreholes which possess features such as ledges, washouts, and contractions, that might otherwise terminate full descent of the tool-string to the bottom of the borehole and thereby compromise the wireline data acquisition objectives. Elements of the articulated wireline hole finder may include a low friction roller nose assembly and spacer sub, an articulated spring joint, that transfers tool-string weight and directs lateral movement of the roller nose towards hole center, and a pair of five arm centralizers that possess a wide dynamic range.

Abstract: A blade assembly of a blowout preventer for shearing a tubular of a wellbore penetrating a subterranean formation is provided. The blowout preventer has a housing with a hole therethrough for receiving the tubular. The blade assembly includes a ram block movable between a non-engagement position and an engagement position about the tubular, a blade carried by the ram block for cuttingly engaging the tubular, a retractable guide carried by the ram block and slidably movable therealong, and a release mechanism for selectively releasing the guide to move between a guide position for guiding engagement with the tubular and a cutting position a distance behind the blade for permitting the blade to cuttingly engage the tubular.

Abstract: The invention concerns a tool for a tool for connecting an end of a first pipeline (22) to an end of a second pipeline (3) supported by a subsea structure (1) and being provided by at least two guide elements (11, 12). The tool comprising means for connecting the pipelines, and it comprises a receiving portion (32) provided to accommodate the end of the first pipeline in a slideable manner, and guiding means comprising at least two guiding sections (34, 35) extending from receiving portion (32). Each guiding section has an end arranged with an attachment portion (36, 37) interfacing with the guide elements (11, 12).

Abstract: A rotating breech lock rotates tubing to distribute wear caused by a rotating or reciprocating rod of an artificial lift system. The rotating breech lock has a spool that disposes on a wellhead. A bowl element disposes in the spool's bore, and a hanger fits into the spool and lands on the bowl element with a thrust bearing. Above the hanger, a load ring fits against the hanger with a bearing, and a hold-down sleeve and locking pins hold the load ring against the hanger. The spool has a worm that mates with a wheel defined about the hanger so turning the worm by a ratchet or other mechanism rotates the hanger. Internally, the hanger has a bore with opposing shoulders separated by gaps. A mandrel couples to the tubing and disposes up into the hanger. Protrusions or keys on the hanger can selectively align with the gaps and the shoulders depending on how the mandrel is rotated in the hanger bore.

Abstract: A tubular gripping assembly for use with a top drive to handle a tubular includes a tubular gripping tool having a mandrel and gripping elements operatively coupled to the mandrel; and a link assembly attached to the mandrel, wherein a load of the link assembly is transferred to the mandrel. The tubular gripping assembly may also include one or more of a swivel having selectively actuatable seals, a thread compensator to facilitate tubular make-up, or a wedge lock release apparatus to facilitate the release of gripping elements from the tubular.

Abstract: One embodiment provides an adjustable guide 10a to steer the end 90 of a pipe string 88 into position to be engaged and supported by a pipe gripping apparatus such as, for example, an externally gripping elevator assembly 10. The adjustable guide 10a may comprise a plurality of angularly distributed guide inserts 30, each having a sloped surface 30A to engage a pipe end 90. Another embodiment provides an adjustable guide 60a to steer a pipe connection into position to pass through a spider 60. The guide inserts 30, 80 of an adjustable guide may be controllably positionable to together form a guide that is concentric with the bore of the tapered bowl of an elevator assembly or a spider. One embodiment comprises a guide insert retainer 11 having a plurality of channels 28, each slidably receiving a guide insert 30 and positionable by rotation of a threaded shaft 40.

Abstract: The present disclosure provides a well service rig for tripping rods and tubulars. The well service rig includes a service rig base unit, a mast coupled to the well service rig base unit movable between a folded position and an upright position, a vertical guide mounted to the mast, and a traveling block system coupled to the vertical guide at a first end and configured to travel up and down at least a portion of a length of the vertical guide. The traveling block system is couplable to a rod, a tubular, or both at a second end.

Abstract: A production flow base (1) for possible future branched connection onto a production manifold (10) in order to provide for the connection of at least two production jumpers extending from respective subsea Xmas trees onto the production manifold (10), is shown. The production flow base (1) is arranged as a retrofit module connectable to a single inboard hub (11) prearranged on the production manifold (10). The production flow base (1) includes a frame structure (2), piping (3), at least one connector (4) and guiding means (9). The frame structure (2) is arranged for landing on a supporting arrangement (12) projecting from a manifold structure (10). The piping (3) forms a branch terminating in a connector (4) and at least two outboard hubs (6).

Abstract: An orientation joint for a subsea landing string equipped to maintain both unitary and telescoping configurations. For example, the joint may maintain a unitary configuration to provide continuous orientation definition while lowering a landing string within a blowout preventer (BOP). Additionally, the orientation joint may be configured to telescope and provide an appropriately sized uniform outer diameter surface to enable a sealing engagement with an aligned ram of the BOP.

Abstract: An outer wellhead member has a bore with a first profile portion and an annular recess. A tubular inner wellhead member with a centralizer/overpull ring is lowered into the outer wellhead member. The centralizer/overpull ring is biased to expand outward to engage the bore of the outer wellhead member to center the inner wellhead member within the bore as the inner wellhead member is lowered through the bore. The recess of the outer wellhead member is adapted to receive the centralizer/overpull ring and oppose axial movement of the centralizer/overpull ring to enable an upward test pull of the inner wellhead member.

Abstract: A magnetic-latch stabbing guide apparatus is presented enabling a first drill pipe to connect with a second drill pipe. The magnetic-latch stabbing guide easily attached to the first drill pipe and facilitates connection between the first drill pipe and the second drill pipe. During the connection process, the magnetic-latch stabbing guide easily detaches from the two drill pipes without physical manipulation of the magnetic-latch stabbing guide.

Abstract: A coiled tubing guide-in device is applied to oil field coiled tubing operation and used for guiding a coiled tubing into injector head gripper blocks. The coiled tubing guide-in device mainly consists of a slip connecting head, a locking sleeve, a floating sleeve, a guide head, and a traction steel rope. In the structure of the slip connecting head, a cone of an expansion plug is arranged in a slip sleeve. A lower end of a tightening nut is a convex spherical body. At a lower end of the tightening nut, an end of a traction steel rope is fixed in a rectangular groove at the lower end of the tightening nut through a threaded pin. In the structure of the locking sleeve, an upper end surface of a spherical support body is a concave spherical surface. An inner conical sleeve and an outer conical clamping sleeve are arranged in a cylindrical space. A spherical head is fixed on inner screw threads of the spherical support body. The number of combined locking bodies ranges from 4 to 15.

Abstract: A Drill-To-The-Limit (DTTL) drilling method variant to Managed Pressure Drilling (MPD) applies constant surface backpressure, whether the mud is circulating (choke valve open) or not (choke valve closed). Because of the constant application of surface backpressure, the DTTL method can use lighter mud weight that still has the cutting carrying ability to keep the borehole clean. The DTTL method identifies the weakest component of the pressure containment system, such as the fracture pressure of the formation or the casing shoe leak off test (LOT). With a higher pressure rated RCD, such as 5,000 psi (34,474 kPa) dynamic or working pressure and 10,000 psi (68,948 kPa) static pressure, the limitation will generally be the fracture pressure of the formation or the LOT. In the DTTL method, since surface backpressure is constantly applied, the pore pressure limitation of the conventional drilling window can be disregarded in developing the fluid and drilling programs.

Abstract: A mobile rig for use in lowering a string comprising joints of a conduit into a well is provided with a rig transporter comprising a motorized unit, a mast assembly, a pivotal connection on the mast assembly with respect to the rig transporter. At least one hydraulic arm is pivotally mounted to the rig transporter and the mast assembly operable to move the mast to an upright position and for lowering the mast to a substantially horizontal position for transportation. In one embodiment, a top drive is mounted in the mast which is raised and lowered with the mast whereby the top drive is transported in the mast in the substantially horizontal position.

Abstract: An upper mast fixture for positioning a tubular received from a pipe handling system for use with a top drive having a rotor utilized to connect with pipe. The upper mast fixture is utilized to assist and/or provide alignment of a threaded connection on a top of said pipe with said top drive rotor.

Abstract: A method and apparatus for aligning a wellhead or BOP stack with a mast assembly comprising a sensor which provides an initial alignment between a mast and a wellhead or BOP stack. A mast assembly is transported to a well site by a rig carrier which positions the mast assembly adjacent a wellhead, or BOP stack. The mast assembly is raised to an upright position whereby a rear portion of the mast extends over the wellhead. Sensors mounted to the top drive, crow, well head, or mast can be used to align the mast with the wellhead.

Abstract: A pressure control apparatus and methodology related to a drilling operation has a housing such as, for example, a bearing assembly configured to engage an item of oilfield equipment being delivered through the oilfield pressure control apparatus. The housing has an upper and/or a lower portion with a seal element coupled to the upper and/or lower portion and configured to seal around the item of oilfield equipment. A guide is coupled proximate the seal element. The guide is configured to support and/or limit lateral deflection of the seal element during the lateral deflection of the seal element created by movement of the item of oilfield equipment.

Abstract: An apparatus including a base, and a drilling tower pivotally coupled to the base to pivot the drilling tower between first and second pivot positions. The drilling tower includes a first portion, and a second portion pivotally coupled to the first portion to pivot the second portion between third and fourth pivot positions when the drilling tower is in the first pivot position. According to another aspect, a method includes pivotally coupling a drilling tower to a base, which includes providing a first portion of the drilling tower, pivotally coupling a second portion of the drilling tower to the first portion of the drilling tower, and pivotally coupling the first portion of the drilling tower to the base.

Abstract: A connector (1) for connecting components of a subsea system, the connector comprising male and female components (3, 2), guide means (11) for assisting preliminary orientation of the male component within the female component and means (18; 20; 21) for drawing the male component into the female component and latch means (22) for securing the male component within the female component.

Abstract: An apparatus for centering a first tubular with respect to a second tubular at a wellhead in which the apparatus has a frame, a gripping member extending outwardly of the frame and suitable for gripping the first tubular, and a guide member connected to the frame and extending outwardly therefrom. The guide member is positioned below the gripping member. The guide member has a slot therein suitable for receiving a portion of the second tubular therein. The slot of the guide member has a center vertically aligned with a center of the gripping member. The guide member is pivotally connected to the frame.

Abstract: A retrievable flow module (RFM) apparatus is provided. In one embodiment, the RFM apparatus is a standalone assembly configured to mate with a subsea device, such as a production tree. The RFM apparatus may include a frame within which various flow control and monitoring elements are disposed. The frame may have an alignment system that enables the RFM apparatus to horizontally mate with the tree. Because the RFM apparatus provides for the collocation of flow control and monitoring elements within a standalone assembly, deployment or retrieval of the flow control and monitoring elements may be accomplished in single operation. Additional systems, devices, and methods are also disclosed.

Abstract: A system, in certain embodiments, includes a casing head and a tubing hanger disposed within the casing head and supported by a first retaining feature of the casing head. The tubing hanger is configured to support a tubing string. The system also includes a guide string hanger disposed within the casing head and supported by a second retaining feature of the casing head independent of the first retaining feature. The guide string hanger is configured to support a guide string.

Abstract: An apparatus to attach a control line to a tubular member, in which the apparatus includes a control line arm having a first control line guide coupled thereto, and a base having a second control line guide coupled thereto, with the control line arm coupled to the base and movable with respect to the base. The control line arm may be movable between a raised position and a collapsed position with respect to the base, and the control line arm may be at least one of slidably coupled and rotatably coupled to the base.

Abstract: The present disclosure relates to a system and a method to grip a tubular member and sense wear for a pipe handling apparatus. The system includes a pipe handling apparatus having a bore formed therein with an axis defined therethrough, a pipe guide disposed adjacent to an opening of the bore of the pipe handling apparatus, and a wear sensor coupled to the pipe guide.

Abstract: A travel joint (100) for space out operations in a wellbore. The travel joint (100) includes a generally tubular mandrel assembly (112) and a generally tubular housing assembly (102) slidably disposed about the mandrel assembly (112). The mandrel assembly (112) included an infinite slot (118) and at least one axial slot (120). A lock assembly (128) is positioned between the mandrel assembly (112) and the housing assembly (102). The lock assembly (128) is operable to selectively prevent and allow relative axial movement between the mandrel assembly (112) and the housing assembly (102). A floating lug ring (140) is positioned between the mandrel assembly (112) and the housing assembly (102). The floating lug ring (140) includes at least one lug (142) and is operable to rotate relative to the mandrel assembly (112) and the housing assembly (102) when the lug (142) travels in the infinite slot (118).

Abstract: A system for removably mounting a drum to a winch assembly comprises a drum assembly, a frame defining at least a portion of a mounting base for the drum, at least one connector for connecting the drum assembly to the mounting base, a lifting apparatus releasably attached to the drum assembly, and at least one guide member releasably attached to the frame and engaging with the lifting apparatus for directing the drum assembly away from the frame when the drum assembly is removed therefrom.

Abstract: A break-out assembly includes a slide wrench assembly, and a slide wrench rotator assembly which rotates the slide wrench assembly in response to actuating first and second rotator assembly cylinders. The first and second rotator assembly cylinders are actuated in opposed directions. The break-out assembly includes a clamp assembly having opposed arm assemblies which are rotatable about separate pivot points.

Abstract: A system for setting and retrieving a tool including a tubular having a first profile and a tool haing a second profile, the first and second profiles complementarily formed and engagable together for enabling the tool to be located in a borehole with respect to the tubular, the first profile or the second profile at least partially formed from a degradable material, the degradable material degradable upon exposure to a downhole fluid.

Abstract: A method and vessel for installing an expandable tubular in a subsea wellbore, wherein said expandable tubular is assembled from expandable tubular segments, said expandable tubular being adapted to be expanded diametrically when positioned in said wellbore by means of expansion tooling, wherein a multitude of expandable tubular segments are provided, and wherein use is made of a surface vessel, said vessel comprising: at least one assembly station adapted for the assembly of at least one intermediate tubular assembly by interconnection of multiple expandable tubular segments, an intermediate tubular assembly suspension storage device adapted for storage of one or more intermediate tubular assemblies, said intermediate tubular assemblies being suspended from the vessel into the water by said storage device, a guide and handling system for intermediate tubular assemblies, said guide and handling system having an entry and an exit, said entry being spaced from said exit, the entry being arranged and adapted t

Abstract: In one embodiment, a tubular gripping assembly for use with a top drive to handle a tubular includes a tubular gripping tool having a mandrel and gripping elements operatively coupled to the mandrel; and a link assembly attached to the mandrel, wherein a load of the link assembly is transferred to the mandrel. In another embodiment, the tubular gripping assembly includes a swivel having selectively actuatable seals. In yet another embodiment, the tubular gripping assembly includes a thread compensator to facilitate tubular make-up. In yet another embodiment, the tubular gripping assembly includes a wedge lock release apparatus to facilitate the release of gripping elements from the tubular.

Abstract: A rotating control device has a bowl including a central passage configured for having a bearing assembly positioned therein. A bowl sleeve ledge is integral the bowl within the central passage. The bowl sleeve is removably disposed within the central passage. Movement of the bowl sleeve along a length of the central passage is constrained by the bowl sleeve ledge and movement of the bowl sleeve radially with respect to the length of the central passage is constrained by a central passage surface. A sealing device of a first configuration is engaged between an exterior surface of the bowl sleeve and the central passage surface. The bearing assembly has an exterior surface of its outer barrel engaged with the interior surface of the bowl sleeve. A sealing device of a second configuration is engaged between the interior surface of the bowl sleeve and the exterior surface of the outer barrel.

Abstract: The present application is directed to an assembly for controlling an annulus between tubulars. The assembly comprising a first annular member securable to the outer tubular; a second annular member securable to the first annular member; wherein each of the first and second annular members have eccentric bores therethrough.

Abstract: The current invention relates to an improved gripper for use within a coiled tubing injector unit. The improved gripper comprises a carrier for securing the gripper to the chain drive mechanism of the coiled tubing injector unit and a gripping shoe carried by the carrier. The improved gripper provides a carrier and a gripping shoe designed to permit quick and easy removal and replacement of the gripping shoe in the field during operation of the coiled tubing injector unit.