Abstract: A locking mechanism for a ladder tray is disclosed. The locking mechanism includes two locking points on the frame or handle of the ladder while allowing single-handed operation.

Abstract: A down the hole rock drilling machine and a method of drilling rock. The drilling machine comprises a casing (15) inside which is a control sleeve (20). A reciprocating piston (19) is arranged to move inside the control sleeve and control feeding and discharging of working chambers (20, 21). Between the control sleeve and an inner surface of the casing are all the fluid passages (28, 29, 30, 31) needed for fluid routing. The piston opens and closes transverse openings and controls the work cycle.

Abstract: A method of horizontal directional drilling is provided. The proposed method utilizes directional drilling in which boreholes are arranged in a pattern such that the surface area of extraction is maximized. The pattern can be achieved using a vertical borehole, multiple lateral boreholes and multiple subsidiary portions of the lateral boreholes. A lateral borehole is drilled extending beyond a vertical borehole towards the orebody, from which a subsidiary borehole is drilled into the orebody. Once the extraction is complete, the subsidiary borehole is back filled. A new subsidiary borehole is drilled extending beyond the lateral borehole and adjacent to the first subsidiary borehole. The subsidiary boreholes are planned to form a honeycomb or direct stacked pattern. Once all extraction is complete from a lateral borehole and its subsidiary boreholes, a new lateral borehole is drilled from the vertical borehole and the process is repeated.

Abstract: Methods and apparatus for releasing a downhole tool of a BHA from a whipstock in a wellbore include a latch release mechanism disposed on a whipstock. The latch release mechanism has a latch actuator and a latch member. The latch actuator has a switch and an actuator piston disposed in housing having an inlet. The inlet is in fluid communication with the actuator piston. The switch has first, intermediate, and second configurations. Fluid communication between the inlet and the actuator piston is blocked when the switch is in the first and intermediate configurations, and the fluid communication is unblocked when the switch is in the second configuration. The actuator piston is coupled to the latch member and configured to move the latch member out of engagement with a lock mechanism of the downhole tool in response to fluid communication from the inlet when the switch is in the second configuration.

Abstract: A rotary guiding device comprises a rotating shaft, the rotating shaft is used to drive a tool head to rotate, and the rotating shaft includes at least one steerable portion; a first non-rotating body and a second non-rotating body, the first non-rotating body and the second non-rotating body are substantially in a non-rotating state in a circumferential direction thereof relative to the rotating shaft when the rotating shaft drives the tool head to rotate; a guide driving mechanism, the guide driving mechanism is configured to connect the first non-rotating body and the second non-rotating body, the guide driving mechanism is adapted to generate a substantially axial driving force to change the relative direction between the first non-rotating body and the second non-rotating body, thereby changing the orientation of the tool head.

Abstract: The present disclosure relates to roller cone drill bit journals with asymmetric ball races and extended friction races. The disclosure also relates to methods of forming such journals, and methods of finishing these journals to produce finished journals with symmetric ball races.

Abstract: Disclosed are a drill bit for drilling and a method for manufacturing same, in which the hardness of a body part of a shank can be selectively improved by performing rapid cooling in a forced cooling method after performing rapid heating selectively only on the body part of the shank in a high-frequency induction heating method after completing infiltration.

Abstract: The invention relates to a device (10) for transporting, in particular skidding or jacking, a heavy object (4) supported on at least one guide (2), comprising an actuator (7) for effecting transport, in particular at least one hydraulic cylinder, one end of which is configured for connection to the object (4) or a foundation and the other end is connected to a shoe (8) configured for connection to the guide (2). The shoe (8) comprises at least two pins (11) configured to be inserted into openings (9) in the guide (2) to provide, at least in the direction of the guide (2) a positive connection between the shoe (8) and the guide (2).

Abstract: An offshore installation comprising a riser pipe and a bend stiffener. The riser pipe comprises a flexible pipe body having a pipe length and an end fitting and the riser has a longitudinal pipe axis. The bend stiffener comprises a helically shaped body arranged to surround a stiffened length section of the flexible pipe body. The bend stiffener has a root end and a far end, wherein the root end is closer to the end fitting than the far end and the root end is locked at an axial distance to the end fitting, determined along the longitudinal pipe axis.

Abstract: A dissolvable connector allows a wireline or similar conveyance to be detached from a downhole tool or device based on conditions in a downhole environment instead of an external action, such as application of tension or an electrical pulse. The dissolvable connector can be strategically positioned to allow retrieval of expensive tools and equipment that are located above the connector. A protective sheath may be provided around the dissolvable connector that opens or unsheathes based on conditions in the downhole environment (e.g., pressure, temperature), a telemetry signal (e.g., from the surface or from a tool string), or tension, to provide greater control over the timing of the release of the dissolvable connector. Such a dissolvable connector allows the device to be detached from the conveyance without the need for wire-cutting operations or weak-point breaking operations.

Abstract: A guiding sleeve for aligning downhole tubulars includes a body having a first end portion, a second end portion and an intermediate portion extending therebetween. The first end portion is receptive of a terminal end of a first tubular and the second end portion includes a guiding feature that promotes axial alignment of the first tubular with a second tubular.

Abstract: A spin-through drive rod centralizer consisting of a stator constructed of plastic, or other appropriate material, which is mounted on a rotor attached to the body of the drive rod, which provides the bearing surface for rotation of the rotor within the stator. The stator is equipped with multiple vanes which extend to the full internal diameter of the production tubing. In one configuration, the radially oriented vanes have cut-outs which allow the tip of the vane to compress inward, allowing passage through tight spots in the tubing, then rebounding to the full ID of the tubing. In another configuration, the vanes are tangentially attached to the stator body, such that they bend in a circumferential direction to allow passage through tubing tight spots, then rebound to full tubing ID.

Abstract: A float shoe for a downhole tubular or casing includes a housing, a nose, a support, and a valve. The housing is attached to the casing, and the nose having a shell of a millable material (e.g., composite, aluminum, etc.) extends from the housing. A support of cement, fills an internal cavity of the nose's shell and support a valve in the housing. The shell for the nose defines a flow passage communicating with the valve and can have a conical or eccentric shape to facilitate passage of the float shoe in a borehole during run-in. The shell for the nose can also have a port or jet that communicate the flow passage out the side of the nose.

Abstract: A system, includes a movable platform slidingly coupled to one or more supports and configured to be selectively moved towards a drill floor and away from the drill floor. The system also includes a roughneck disposed on the movable platform and configured to make up or break out a threaded joint between a first tubular segment and a second tubular segment. The system additionally includes a support member disposed on the movable platform and configured to support one of the first tubular segment or the second tubular segment as the movable platform is selectively moved towards a drill floor or away from the drill floor.

Abstract: A drill rod handler (30) for use on a drilling rig (10). In at least one embodiment, the drill rod handler (30) comprises a boom (32) having jaws (38) for releasably grasping a drill rod (14) in at least two spaced apart positions along the length of the drill rod, and a boom positioning means for positioning the boom so that the jaws may grasp a drill rod (14) from a rod storage (18) on the drilling rig or from another rod storage at a different location (16). In another embodiment, a drill rod handler comprising a boom having jaws for releasably grasping a drill rod in at least two spaced apart positions along the length of the drill rod, a boom tilt mechanism for raising or lowering an end of the boom and a drill rod when the drill rod is grasped by the jaws; and an interconnect for connection to the end of the boom for stabilising the end of the boom with respect to the a mast (20) of the drilling rig (10) when the boom (32) is in a rod presentation position.

Abstract: A high trip rate drilling rig has first handling equipment to transport stands in/out of setback, second handling equipment to deliver stands to/from well center, and a hand-off position to set down stands for exchange between first/second equipment. Second equipment can include a top drive and a delivery arm translatable along the mast past each other, and a clasp on the arm slidable on the stand for constraint below the upper end, which can allow the top drive to engage/disengage the constrained stand above the arm. A high trip rate method transports stands in/out of setback, delivers stands to/from well center, and sets down and hands off stands at hand-off position between the setback transportation and well center delivery. The delivery can include engaging/dis-engaging the top drive and a stand constrained by the clasp.

Abstract: A guiding sleeve for aligning downhole tubulars includes a body having a first end portion, a second end portion and an intermediate portion extending therebetween. The first end portion is receptive of a terminal end of a first tubular and the second end portion includes a guiding feature that promotes axial alignment of the first tubular with a second tubular.

Abstract: A conduit forming part of a drilling fluid return path from a wellbore has at least one flow restrictor disposed on an interior surface of the conduit. A drill string is disposed through the interior of the conduit and has at least one flow restrictor disposed on an exterior surface of the drill string. The drill string is longitudinally movable through the conduit to enable placing the flow restrictor in the conduit, and the flow restrictor on the drill string at a selected longitudinal distance from each other.

Abstract: Methods and apparatus for managing fluid flow in pipes. An exemplary method includes initializing models of at least two fluid pads and one or more pipe elements, the models of the fluid pads comprising material points; for each of the material points, determining: an integration weight; and a material state; (a) for each of the fluid pads, discretizing governing fluid flow equations on a numerical grid, wherein the numerical grid is constrained within the pipe elements; (b) solving the discretized equations to generate nodal solutions; (c) constructing material point solutions from the nodal solutions; and until end criteria are met: updating the models of the fluid pads with the material point solutions; and repeating (a)-(c). An exemplary fluid flow data analysis system includes a processor and a display configured to display graphical representations of a fluid flow model, wherein the system is configured to manage fluid flow in pipes.

Abstract: A method and apparatus for controlling pressure in a drilling system that includes a drilling fluid return flow path. Steps include providing a choke system comprising a first flowline having an inlet and an outlet each connected to the drilling fluid return flow path, wherein the outlet connects to the return flow path downstream of the inlet connection, a first choke positioned on the flowline, a second choke positioned on the flowline downstream of the first choke, and a control module for controlling the first and second chokes; flowing drilling fluid through the first flowline while at least one of the first and second choke is partially closed so as to cause a pressure drop; in response to an input, opening the partially closed choke and partially closing the other choke so as to substantially maintain the pressure drop; returning the chokes to the original flow status.

Abstract: An open-hole drilling method and process is embodied in creation of a closed cycle and system for extracting gas from shale and other impermeable and natural vertical fracture dominated reservoirs. The closed cycle system enables gas from reservoir to be used as a drilling fluid, with any excess gas produced as the wellbore is extended, to be sold in real time through a gas pipeline. Since only natural gas exists throughout the closed system, no risk exists for downhole explosions, and no wellbore damages occur from foreign fluids, such as mud, cement, and water. Limits of wellbore length due to gas produced while drilling, and risks during gas flaring are eliminated. All products produced from wellbore are captured so no venting of any liquids, gases, or solids. All hydraulic fracturing issues are avoided. Gas flow rate measurements while drilling enables technical, financial, reserve estimate models development in real time.

Abstract: A setting tool for setting frac plugs and the like can include a mandrel having a chamber for housing expandable gas and a gas port in fluid communication with the chamber; a firing head secured to the mandrel for igniting a power charge to generate pressurized gas within the chamber; a barrel piston housing the mandrel and connected to a sleeve for setting the frac plug; and an expansion region defined between the mandrel and the barrel piston and receiving the pressurized gas which exerts force to cause a stroke of the barrel piston over the mandrel as the expansion region expands axially. The setting tool can include various features, such as certain gas bleed systems, an enhanced shear screw assembly, a bleed port and plug assembly, a scribe line, a particular gas port configuration, a liquid escape conduit, no-shoulder barrel configuration, and/or a low-force design for frac plugs.

Abstract: A setting tool for setting frac plugs and the like can include a mandrel having a chamber for housing expandable gas and a gas port in fluid communication with the chamber; a firing head secured to the mandrel for igniting a power charge to generate pressurized gas within the chamber; a barrel piston housing the mandrel and connected to a sleeve for setting the frac plug; and an expansion region defined between the mandrel and the barrel piston and receiving the pressurized gas which exerts force to cause a stroke of the barrel piston over the mandrel as the expansion region expands axially. The setting tool can include various features, such as certain gas bleed systems, an enhanced shear screw assembly, a bleed port and plug assembly, a scribe line, a particular gas port configuration, a liquid escape conduit, no-shoulder barrel configuration, and/or a low-force design for frac plugs.

Abstract: A rescue dart for deployment down a wellbore to dislodge a pre-set frac plug having a plug mandrel from within the wellbore is provided. The rescue dart includes a dart body adapted to be conveyed down the wellbore via fluid flow and a mandrel defeater connected to the dart body and operable to reduce structural integrity of a portion of the plug mandrel until structural failure of the plug mandrel occurs and the frac plug is unset and dislodged. A corresponding system is also provided. The system includes the rescue dart and a pump for pumping fluids down the wellbore. A method of dislodging a pre-set frac plug using the rescue dart is also provided.

Abstract: Provided, in one embodiment, is a pulling prong. The pulling prong, in one example, includes an outer housing, and a nose assembly slidably located within the outer housing. In this example, the nose assembly and outer housing form an activation chamber. The pulling prong, in this example, may further include activation means located within the activation chamber, the activation means configured to move the nose assembly from a first running configuration to a second retrieving configuration.

Abstract: A method and apparatus for single-trip casing cutting and pulling for well abandonment and slot recovery. Perforations (28) are made in the casing (12) at a maximum depth using a punch tool (18) and a pulsed fluid circulated through the perforations (28) to determine a return at surface. In the event of a return at surface being detected, the casing (12) is cut and then pulled with assisted vibratory action. When no return is detected, perforations (28) are made at increasingly shallower depths until a return is detected and the casing (12) is then cut and pulled. This ensures the maximum length of casing (12) is cut and pulled on a single trip in the well bore.

Abstract: Example embodiments presented herein are directed towards a subsea control system for transmitting subsea related data to and from a topside control system with the use of Subsea Electronic Modules (SEMs) connected in a network in a multidrop configuration.

Abstract: A drone conveyance system for deploying drones into an oil or gas wellbore is described. The system includes a platform, a drone magazine, a platform receiver, a conveyance, and a wellhead receiver. A drone magazine contains a plurality of the drones and selectively releases/feeds the drones into the platform receiver. More than one drone magazine, each containing different drone types, may supply drones to the platform receiver such that different drones may be ordered for disposal into the wellbore. The platform receiver prepared the drones to be moved from the platform to the wellhead by the conveyance. The wellhead receiver accepts the drones from the conveyance and prepares each received drone for dropping into the wellbore via the wellhead.

Abstract: Apparatus and methods for launching objects into a wellbore. The apparatus generally includes a first object container and a container actuator. The first object container includes first compartments. The container actuator is adapted to displace the first object container so that respective ones of the first compartments are sequentially aligned with an opening. When the respective ones of the first compartments are sequentially aligned with the opening, objects loaded into the respective ones of the first compartments are sequentially launchable through the opening and into the wellbore. In some embodiments, the apparatus further includes a second object container including second compartments and being positionable above the first object container so that the respective second compartments are aligned with the respective first compartments.

Abstract: Apparatus, systems, and methods according to which a launcher defines a central passageway and is adapted to launch an object into the central passageway so that the object enters an oil and gas wellbore. The launcher includes a cylinder rotatable about an axis between first and second angular positions, the cylinder defining a chamber into which the object is loadable when the cylinder is in the first angular position, and from which the loaded object is launchable when the cylinder is in the second angular position. A lubricator is extendable through, and retractable from, the central passageway of the launcher.

Abstract: A plug which does not cause an adverse effect such as failure of a member constituting the plug when a wellbore is plugged. The downhole plug (10) includes a mandrel (1) having a hollow structure, a sealing member (2) attached to an outer circumferential surface of the mandrel (1) and being deformable by exerted pressure, and a socket (3) attached, adjacent to the sealing member (2), onto the outer circumferential surface of the mandrel (1), downstream of where the pressure is exerted on the sealing member (2).

Abstract: An example method includes pumping fluid into a wellbore to fill, at least partly, a region in a lost circulation zone, with the fluid having a first density; and after pumping the fluid, pumping cement slurry into the wellbore. The cement slurry has a second density. The first density is greater than, or equal to, the second density, which causes the fluid to prevent, at least partly, the cement slurry from mixing with other fluid in the lost circulation zone for at least a period of time.

Abstract: A method for recompleting a well is applied to a well such that the recompleted well can thermally transfer geothermal energy to surface. The recompleting method can comprise steps to enhance the thermal conductivity of a wellbore of a hydrocarbon well, by inserting a thermal material into the wellbore that displaces a reservoir fluid having a lower thermal conductivity than the thermal material. The recompleting method can also comprise steps to enhance the thermal conductivity of a reservoir in which the wellbore is located by inserting a thermal material into the reservoir that displaces a reservoir fluid having a lower thermal conductivity than the thermal material, or in which the reservoir is fractured, and a thermal material is inserted into created fractures.

Abstract: An assembly for a valve includes an inner cylinder, an outer cylinder circumferentially surrounding the inner cylinder, and a first bar comprising a first end portion coupled to the inner cylinder and a second end portion coupled to the inner cylinder. The second end portion extends radially outwardly through a groove extending circumferentially about a curved wall of the outer cylinder to enable the inner cylinder and the first bar to rotate relative to the outer cylinder.

Abstract: A fault-tolerant system relieves pressure of fluid flow in a drilling system. Redundant pressure relief valves can open to relieve fluid flow from a discharge outlet of a manifold when over pressurization is detected. A hydraulic arrangement operably connected to the redundant relief valves provides hydraulic motive force in redundant hydraulic circuits respectively to the redundant relief valves. The redundant circuits are cross-connected to one another. Pressure transducers distributed in the hydraulic arrangement measures operational pressures of the hydraulic arrangement. Redundant controllers can both control the hydraulic motive force provided in the redundant circuits respectively to the redundant relief valves to open and close the relief valves in response to the pressure level measurement.

Abstract: A toe sleeve that is configured to allow communication between an inner diameter of the tool and an annulus outside of the tool during a bleed off cycle, which occurs after testing the casing. To test the casing, pressure within the inner diameter of the tool may be increased, and during a bleed off cycle the pressure within the inner diameter of the tool may be reduced.

Abstract: A downhole tool having a flapper valve assembly for controlling the backflow of fluid into a tubing string that includes at least one flapper. The downhole tool also includes a deformable element that maintains the at least one flapper in an open position after the deformable portion is deformed. A downhole tool having a flapper valve assembly for controlling the backflow of fluid into a tubing string that includes at least one flapper. The downhole tool also includes a sleeve slidably disposed within at least a portion of the flapper valve assembly and the downhole tool. The downhole tool includes a deformable and dissolvable seat disposed uphole and adjacent to the sleeve and a dissolvable fluid blocking member to engage with the seat to shift the sleeve from first position to a second position within the downhole tool. Methods of using these downhole tools are provided.

Abstract: A flow control apparatus comprising: a housing, a housing passage disposed within the housing, a subterranean formation flow communicator for effecting flow communication between the subterranean formation and the housing passage, a flow control member, displaceable, relative to the subterranean formation flow communicator, for effecting at least opening of the subterranean formation flow communicator There is further provided a first actuation system for actuating displacement of the flow control member relative to the subterranean flow communicator. There is also provided a second actuation system for actuating displacement of the flow control member relative to the subterranean flow communicator. Relative to the central longitudinal axis of the housing passage, the first actuation system is angularly spaced from the second actuation system.

Abstract: A technique provides a desired control over incremental actuation of hydraulic devices. A hydraulically actuated tool is combined with a control module. The hydraulically actuated tool has an actuator piston positioned in a piston chamber and movable between operating positions. The control module comprises a hydraulic indexing circuit arranged to enable incremental movement of the actuator piston in a first direction and full stroke movement in a second direction based on hydraulic input delivered via control lines. The hydraulic indexing circuit comprises an indexing piston system and at least one check valve working in cooperation with the indexing piston system to enable the incremental and full stroke movements.

Abstract: A surface-controlled wireline-retrievable safety valve includes a seat housing having a plurality of flow ports that is configured to house a hard seat. A closure device has a plurality of equalization ports, is disposed within the seat housing, and is configured to controllably move off the hard seat and expose the plurality of flow ports to a central lumen of the safety valve under hydraulic actuation. A power piston having a shoulder portion includes a top end that is attached to the closure device and the shoulder portion is disposed within a hydraulic chamber housing forming a differential area. A hydraulic actuation port may be configured to receive hydraulic actuation fluid from a surface pump. A hydraulic passage may be configured to convey the hydraulic actuation fluid from the hydraulic actuation port to the differential area via a hydraulic access port.

Abstract: A valve assembly (1) for use particularly in a deviated wellbore of an oil, gas or water well comprises a body (50) with an axis and first and second resiliently deformable seats (20, 25) to seat a valve closure member (10a) such as a ball, the seats being deformable to allow passage of the ball at different first and second fluid pressures acting on the seated valve closure member. The first and second seats are axially spaced from one another on a control sleeve (60) on opposite sides of an inner end of a selectively operable fluid outlet conduit connecting the bore with an external surface of the valve assembly, and operation of the valve assembly at pressures between the first and second pressures opens and closes the outlet while maintaining the ball between the first and second seats.

Abstract: An insulating fluid system includes an acidic nanosilica dispersion and an alkaline activator. The acidic nanosilica dispersion includes silica nanoparticles and a stabilizer, such as a carboxylic acid. The alkaline activator includes an alkanolamine, such as a monoalkanolamine. A mixture of the acidic nanosilica dispersion and the alkaline activator forms an insulating fluid having a pH greater than 7 and less than or equal to 12, and the insulating fluid forms an insulating gel when heated to a temperature in a range between 100° F. and 300° F. The insulating gel may be formed in an annulus between an inner conduit and an outer conduit. The inner and outer conduits may be positioned in a subterranean formation. Forming an insulating gel may include combining the acidic nanosilica dispersion with the alkaline activator to yield the insulating fluid, and heating the insulating fluid to form the insulating gel.

Abstract: Provided is a wellbore scraper assembly for use with a wireline. The wellbore scraper assembly, in one example, includes a tubular housing, a plurality of hydraulically deployable scraper features associated with the tubular housing, the plurality of hydraulically deployable scraper features configured to move from a first retracted state to a second radially extended state, and a hydraulic deployment system coupled to the plurality of hydraulically deployable scraper features, the hydraulic deployment system configured to move the plurality of hydraulically deployable scraper features from the first state to the second state.

Abstract: A pressure rated well annulus fluid expansion storage device that is capable of managing pressure variation within a well annulus by removing or adding fluid to the well annulus. The well annulus fluid expansion storage device includes an annulus fluid expansion unit containing a well annulus fluid and a working fluid, the annulus fluid expansion unit further includes a moveable partition maintaining the working fluid and the well annulus fluid in separate chambers, a working fluid storage tank that stores the working fluid, an adjustable pressure control valve that maintains a pressure of the working fluid, a working fluid pump that feeds and pressurizes working fluid from the working fluid storage tank into the annulus fluid expansion unit, a check valve that allows flow of working fluid from the working fluid storage tank to the annulus fluid expansion unit, and a flow line for receiving and discharging well annulus fluid.

Abstract: This disclosure provides a dissolvable sealing joint system that can be used in an improved method of sealing a multi-lateral well junction. The sealing joint system is comprised of a dissolvable junction subassembly that can be easily removed after a sealing operation is conducted. A tapered end of the dissolvable junction subassembly is inserted in a liner of a secondary wellbore, and a seal located about the tapered end is sealed against the top of the liner and a no-go shoulder of dissolvable junction subassembly. Once a seal is established, an isolation fluid is pumped into the junction area via a fluid port located in the dissolvable junction subassembly. A method of isolating a wellbore junction is also presented.

Abstract: Methods of exploiting a formation containing a reservoir of hydrocarbons utilize a gas-liquid drift-flux (DF) model for a multi-segmented wellbore (MSW). The DF model is provided for use in conjunction with a reservoir simulator. The DF model is configured to account for pipe inclinations of the MSW between ?90° and +90° including horizontal or near-horizontal wellbores in addition to vertical and slanted wellbores. The DF model is based on mixture velocity as opposed to superficial velocities, thereby permitting the DF model to be integrated with reservoir models that utilize mixture velocity. The DF model can also be continuous and differentiable over all primary variables.

Abstract: A downhole puncher tool may include a pump system configured to produce a force. The downhole puncher tool may include a plurality of arm systems. Each arm system may have one or more arms that are configured to extend radially outward from the downhole puncher tool upon receiving the force from the pump system. In some embodiments, at least one arm system of the plurality of arm systems comprises a punching insert that is coupled to an arm of the one or more arms, and the punching insert may have a projecting surface.

Abstract: The present invention relates to the injection of water and gas, either simultaneously or alternately, into subsea wells in order to enhance production and the oil recovery level. Thus, the present invention provides a subsea system for pressurizing a subsea oil reservoir injecting at least one of water and gas, comprising (i) at least two subsea injection wells (4, 4?), each subsea injection well (4, 4?) being connected to a production unit (5) by means of a single subsea line (1, 2) which is connected to the respective subsea injection well (4, 4?) by a main injection mandrel (6, 6?), and (ii) at least one jumper (3), each jumper (3) hydraulically connecting two of the at least two adjacent subsea injection wells (4, 4?) through annular mandrels (7, 7?). The present invention further provides a subsea reservoir pressurization method associated with the above-described system.

Abstract: A system for heating a hydrocarbon resource in a subterranean formation having a wellbore extending therein may include a radio frequency (RF) source, and a casing within the wellbore including electrically conductive pipes with a dielectric heel isolator coupled between adjacent electrically conductive pipes. Electrically conductive pipes from among the plurality thereof and downstream from the dielectric heel isolator define an RF antenna. The system may further include an RF transmission line extending within the casing and coupled between the RF source and RF antenna, a seal between the RF transmission line and adjacent portions of the casing adjacent the dielectric heel isolator to define an internal choke fluid chamber upstream of the seal, and an electrically conductive choke fluid contained within the internal choke fluid chamber.

Abstract: There is provided a downhole flow control apparatus comprising: a housing; a port extending through the housing; a passage disposed within the housing for conducting material to and from the port; a flow control member displaceable relative to the port; and a flow control member actuator configured for producing a pressurized fluid for urging the displacement of the flow control member.