Abstract: A system includes a cable with a core material, an intermediate layer surrounding the core material, a retention assembly located around the core material and configured to compress the core material and restrict the core material from moving in the cable, and an outer metallic tubular surrounding the intermediate layer. Further an electrical device is coupleable to the cable.

Abstract: Disclosed is an apparatus for connecting to a tube or a rod in a longitudinal axial direction of the tube or rod. The tube or rod is used in the assembly of a tube or rod string. The apparatus comprises an engagement member adapted to engage with an engagement 5 portion located at an end of the tube or rod. The apparatus also comprises an abutment member associated with the engagement member. The abutment member is adapted to abut an abutment portion of the tube or rod. The apparatus is adapted such that, when the engagement member is engaged with the engagement portion and the abutment member abuts the abutment portion, the abutment member can apply a locking force to the abutment 0 portion in the axial direction of the tube or rod, being a force that secures the engagement member to the engagement portion such that the tube or rod can be lifted and moved.

Abstract: An apparatus for lifting, lowering and positioning well servicing apparatus relative to an oil or gas well is disclosed. A tubular main body is mounted in an operative position relative to a wellbore, by a bolted flange, clamp or other means. A lift arm having a vertical arm section and a horizontal arm section is slidably disposed in said main body and movable vertically and rotationally. A hydraulic cylinder, preferably positioned within the main body, moves the lift arm vertically up and down. Desired rotation is achieved by the interaction of a guide pin or cam follower, disposed in the main body and extending into a slot pattern on the outer surface of the vertical arm section, as the lift arm is moved vertically by the hydraulic cylinder. The apparatus can be used to position a safety “night cap,” a ball drop mechanism, or other tools on a well.

Abstract: An apparatus for slip monitor and control includes a body; a plurality of slips; a transmitter for each slip; at least one receiver coupled to the body; and an actuator for each slip configured to move the respective slip vertically relative to the body. A method for slip monitor and control includes obtaining slip positional information for a plurality of slips; determining whether the slip positional information for each of the slips matches criteria; and sending one or more control signals to one or more actuators, each actuator configured to move one of the slips vertically relative to a body. A method for handling a tubular includes actuating a plurality of slips to move vertically relative to a body; engaging the tubular with at least one of the slips; measuring positional data of the plurality of slips; and identifying an offset pipe condition.

Abstract: A vertical pipe handling system comprising a bellyboard with at least one automated guide for leading tubulars between the fingers of the bellyboard. A method to move a tubular on or above a rig floor comprising automatically moving the tubular with a racking system comprising a bellyboard with at least one automated guide for leading tubulars between the fingers of the bellyboard.

Abstract: A core tube handling device can be used with exploratory drilling rigs. The device can include a slew arm mounted on the rig's mast and a pivot arm mounted on the slew arm. When the slew arm is adjacent to the mast, clamping devices on the pivot arm can grasp and hold a core tube from the drill string. The slew arm can pivot away from the mast and align the pivot arm with a tray that receives and holds the tubes. The pivot arm can pivot to a position proximate the tray and release the tube. The tray can be rotatable and translatable to facilitate transfer of the tube from the pivot arm to the tray.

Abstract: An attachment that is configured for attachment to an arm of a piece of heavy construction equipment. The attachment is configured to rotate a section of pipe during break-out (i.e. disconnection or disassembly) from another section of pipe and/or make-up (i.e. connection or assembly) with another section of pipe. The attachment is configured to break the joint or torque the joint, unthread or thread pipe, and lift the pipe under the power of the heavy construction equipment.

Abstract: Lost circulation material (LCM) and method including LCM objects each having a centrally-disposed solid core and tentacles extending from the solid core to entangle with tentacles of neighboring LCM objects to treat loss circulation in a wellbore in a subterranean formation. The LCM as solid cores and entangled tentacles at the loss circulation zone collects solids from wellbore fluid to form a barrier to treat the loss circulation.

Abstract: Provided are systems and methods that are related to a fluid processing unit. A method for separating a drilling waste fluid, the method comprising: introducing drilling waste fluid into a thermal extraction chamber; allowing drilling waste fluid to flow longitudinally along two screws disposed within thermal extraction chamber, wherein each screw comprises a shaft, an orifice, and an internal heating element; allowing internal heating element to provide heat to thermal extraction chamber; allowing at least a portion of the drilling waste fluid to evaporate; removing evaporated fluid through a first outlet; removing solids through a second outlet. A thermal extraction chamber for separating drilling waste fluids, wherein thermal extraction chamber comprises: a barrel; a first screw; a second screw, wherein first screw and the second screw comprise a shaft, an orifice, a an internal heating element; an inlet port; a first outlet port; and a second outlet port.

Abstract: A flow diverter for connecting a central bore to an outer conduit. The flow diverter defines a portion of the central bore and angled flow passages connecting the portion of the central bore to the outer conduit. Rounded edges between the central bore and angled flow passages reduce cavitation and/or turbulence. The rounded edges and an adjacent portion of the central bore may be defined by an insert. The insert may define walls extending fully around portions of the angled flow passages.

Abstract: A safety drilling system for preventing collapse of water-sensitive formation in the upper part of a high-pressure saltwater layer, which includes a wellhead equipment, a downhole drilling tool, a first injection pipeline, a second injection pipeline, a first return pipeline and a second return pipeline. Upon encountering a high-pressure saltwater layer while drilling, the system injects heavy mud into the annulus of a wellhead through the first injection pipeline to form a heavy mud cap, such that a fluid column pressure in the annulus balances the pressure of the high-pressure saltwater layer. In this case, a fluid column pressure in a drill string is lower than the pressure of the high-pressure saltwater layer.

Abstract: An autonomous tool includes a tool body and turbine wheels coupled to the tool body. Each turbine wheel is retractable into the tool body and extendable out of the tool body. When the turbine wheels are extended out of the tool body, the axial axes of the turbine wheels can be positioned parallel to the axial axis of the tool body, allowing generation of mechanical energy from a fluid stream moving along the tool body, or positioned perpendicular to the axial axis of tool body, allowing the turbine wheels to roll along a tubular wall. Electrical generators are mechanically coupled to the turbine wheels to convert the mechanical energy produced by the turbine wheels into electrical energy. An energy storage stores the electrical energy for use by components of the tool.

Abstract: A setting mechanism for a liner hanger to be secured within the casing of an oil/gas well includes an expandable hydraulic chamber a portion of which is connected to a setting collar positioned around the liner hanger. Expansion of the chamber will cause the setting collar to radially move one or more slips having a gripping surface into contact with an inner surface of the casing.

Abstract: A setting tool and bridge plug that are run-in-hole on wireline through a core bit while drill rods are in place can be used to plug a borehole. A setting tool can be sized to have a same or smaller diameter as a drill rod. A bridge plug can have a run-in configuration of a diameter that is smaller than an inner diameter of a core bit. The bridge plug can have a set configuration that can respond to the setting tool pulling uphole. The bridge plug can be positioned below a drill bit of the drill rod in the set configuration, and the diameter of the bridge plug in the set configuration can be greater than the diameter of the drill rod.

Abstract: A collecting device for displacement in a tubing. The collecting device is extended in shape with a longitudinal axis and forms a leading portion with an entrance and an end portion. The device includes a wall extending from the leading portion to the end portion, a collecting chamber formed inside a portion of the wall, a filter positioned with the collecting chamber, a motor, a pump, and an outlet at the end portion, where the filter stocking provided with an open first end portion and a closed second end portion, and the open first end portion faces the leading portion, a and the filter stocking forms a receptacle. A method for emptying the collecting device is described.

Abstract: A tool for use in a borehole to perform a milling, under reaming, or other cutting operation includes a tool body configured for rotation about its longitudinal axis, within the borehole, and a set of cutters, the set including two or more cutters which, at least in a deployed configuration, extend outwardly from the tool body and are fixedly coupled together whilst being pivotally coupled to the tool body substantially on said axis so that the cutters rotate with the tool body whilst being pivotable together relative to the tool body during cutting.

Abstract: A powered articulated magnetic fishing tool having one or more knuckle or ball joints and a magnet to retrieve fish from a subterranean well and methods of retrieving the metallic object using the fishing tool. The fishing tool includes a magnet and one or more powered joints. The powered joints may each include or be coupled to a multi-axis position sensor that indicates the orientation of the joint and associated section downhole from the joint. The fishing tool may include a camera and a light located at the magnet end of the fishing tool. A system may include a human interface console located at the surface to control the fishing tool.

Abstract: An apparatus for use with a device used in a well with a wellhead housing includes a sleeve comprising an interior profile that is configured to be coupled to the wellhead housing and an engagement assembly comprising an exterior profile that is configured to engage with the interior profile of the sleeve to prevent axial movement between the engagement assembly and the sleeve. The apparatus further includes a latch assembly coupled to the engagement assembly and configured to latch to the device.

Abstract: A control line assembly for coupling with a tubing or casing hanger of a wellhead assembly includes a support ring configured to couple with the tubing or casing hanger, and a tubular member configured to extend through a first bore disposed in the support ring, wherein a first end of the tubular member is configured to be stabbed into a passage disposed in a wellhead component of the wellhead assembly, and a second end of the tubular member is configured to be stabbed into a first receptacle disposed in the tubing or casing hanger, wherein, when the control line assembly is coupled with the tubing or casing hanger and the wellhead component is landed over the tubing or casing hanger, a passage disposed in the tubular member is configured to provide communication between the passage of the wellhead component and the first receptacle of the tubing or casing hanger.

Abstract: A wellhead port plug assembly having a sensor unit, a plug, a transmitter unit arranged in the sensor unit and comprising a wireless signal transmitter, and a receiver unit arranged on the spool unit and comprising a wireless signal receiver. There is also disclosed a method for installing, removing or replacing a sensor unit located in a port of a wellhead.

Abstract: A lead impression system having a downhole tool and a lead impression assembly assembled radially around the downhole tool is landed on a previously installed host casing hanger or a casing hanger being installed in the current/same trip to obtain a lead impression from the bore of the wellhead housing and indicate where the host casing hanger is located axially within the wellhead housing with respect to a feature on the bore of the wellhead housing from which the lead impression is obtained. Lead impression modules in the assembly have a lead pad that protrudes radially outward through a window on an outer sleeve according to a pressure differential between an internal and an external pressure of the lead impression assembly. The lead pad retracts to its pre-set position when the pressure differential exceeds a preset burst pressure.

Abstract: System for displacing a blowout prevention safety valve, which has an overhead crane mounted on a suspended rail and provided with a winch for lifting and transporting the safety valve from a parking zone to a drilling area, where a crane is placed on which the safety valve is hung. A coupling device is mounted on the overhead crane, such that the overhead crane can be moved between the parking zone and the drilling area, having both the winch and the coupling device connected to the safety valve. In the drilling area, the coupling device are disengaged from the safety valve, while the crane and the winch are maintained connected to the safety valve in order to lower it to an operating position.

Abstract: A subsea assist snubbing jack comprises bi-directional slip bowls and can hold light or heavy pipe loads, create clamping load internally without relying on pipe weight or the force of the subsea assist snubbing jack to develop clamping force; do not require pipe motion to unseat the clamp on the pipe; utilize smooth faced inserts that do not mark the pipe; and are suitable for subsea control by wire operation. In embodiments, it is also instrumented to directly measure the pipe weight being held by one or both slip bowls.

Abstract: The disclosure relates to a rotating control device used in a drilling system having a non-rotating tubular RCD housing enclosing an elongate passage. A mandrel rotatably extends along the passage about an axis. A seal assembly seals the RCD housing to the mandrel and provides first and second seals against the mandrel's exterior surface. The first and second seals are spaced parallel to the mandrel's axis to create space between the mandrel and the first and second seals. The first seal has a first side exposed to fluid pressure in the RCD housing and a second side exposed to fluid in the space between the seals. The second seal has a first side exposed to fluid pressure in the space between the seals and a second side exposed to fluid pressure at the exterior of the RCD housing. A pressure stepping mechanism supplies fluid to the space between the two seals.

Abstract: A downhole isolation tool for sealing a casing in a well, the downhole isolation including plural parts made of a composite material, each part having a preset functionality with regard to sealing the casing; and a sealing element configured to seal the casing. At least two parts of the plural parts have a single, combined body.

Abstract: A wellbore isolation tool, e.g., a bridge plug, provides the ability to seal portions of a well from production or to temporarily seal zones of a well from treatment. A bridge plug may include a sealing element supported by one or more segmented barrier devices that operate to prohibit extrusion of the sealing element as the sealing element is subjected to an axial force. The segmented barrier device may operate passively as segments are driven radially outward by the radial expansion of the sealing element when subject to the axial force and driven radially inward by leaf springs when the axial force is removed. Segments of the segmented barrier device may circumferentially overlap and form a generally flat shoulder supporting the sealing element. The segmented barrier device may include a jacket covering the segments, and a sealing element may be supported by a segmented barrier device on each axial end.

Abstract: A well barrier can include an annular seal element, an anti-extrusion backup having radially inward and radially outward portions, and a biasing device that exerts a biasing force against the radially outward portion of the anti-extrusion backup. A method of operating a well barrier can include setting the well barrier by decreasing a longitudinal distance between abutments of the well barrier, thereby compressing a seal element between the abutments, and unsetting the well barrier by increasing the longitudinal distance between the abutments and radially inwardly retracting an anti-extrusion backup positioned longitudinally between the seal element and one of the abutments. Another well barrier can include an annular seal element, an anti-extrusion backup, an abutment displaceable relative to the seal element to compress the seal element, a sleeve reciprocable relative to the abutment, and a biasing device that biases the sleeve toward the anti-extrusion backup.

Abstract: A method for improving oil recovery within a subterranean formation that includes forming a barrier within the formation to isolate at least a portion of a first region from a proximate second region. The barrier is formed by introducing a first solution including an ammonium containing compound and a second solution including a nitrite containing compound into the formation. The first solution, the second solution, or both, further include a foaming agent. The compounds react to generate nitrogen gas in the presence of the foaming agent to generate a foam within a first region. The foam provides the barrier. Water is introduced into the formation. The barrier diverts the water away from the first region and into the second region. The water operates to displace at least a portion of a hydrocarbon present in the second region and discharge the hydrocarbon from the formation.

Abstract: An example method of forming a well includes identifying a lost circulation zone in a wellbore, where the lost circulation zone includes a fracture in a formation adjacent to the wellbore; arranging an inflatable in a vicinity of the lost circulation zone; forcing slurry into the inflatable to cause at least part of the inflatable containing the slurry to expand into the fracture; allowing the slurry to set for a period of time to produce a solid; and drilling through the solid in the inflatable in the wellbore, leaving the solid in the fracture.

Abstract: Capsules with a cement additive covered by a polymeric outer shell are added to wellbore cement. The additive is released from the shells by osmosis or shell ruptures. Capillary forces draw the additive into micro-annuli or cracks present in the cement, where the additive seals the micro-annuli and cracks to define a self-sealing material. The empty shells remain in the cement and act as an additive that modifies cement elasticity. The capsules are formed by combining immiscible liquids, where one of the liquids contains a signaling substance, and each of the liquids contains a reagent. When combined, the liquids segregate into a dispersed phase and a continuous phase, with the dispersed phase having the signaling agent. The reagents react at interfaces between dispersed and continuous phases and form polymer layers encapsulating the signaling agent to form the capsules. Adjusting relative concentrations of the reagents varies membrane strength and permeability.

Abstract: A drill string steering system includes a motor and a rotary valve body disposed in a tool body. The motor includes a motor shaft coupled to the motor and extending within a central bore of the tool body. The motor shaft has a downhole engagement portion that includes a first splined surface. The rotary valve body includes a disk-shaped component and a valve shaft coupled to the disk-shaped component and extending uphole of the disk-shaped component. The valve shaft includes a second splined surface engageable with the first splined surface for rotation of the motor shaft to be imparted to the rotary valve body.

Abstract: The invention discloses a circulating system and a method for continuous downhole cooling of high-temperature drilling fluid. The circulating system includes a cooling water tank, a cooling water injection pump, a plurality of U-shaped pipes, a liquid nitrogen cooling tank, a spiral pipe, a cooling water return pump and a return pipeline. The U-shaped pipe is fixed in an unsealed bond cement gap between outer and inner casings, and two ends are respectively connected with output end of the cooling water injection pump and the spiral pipe. The spiral pipe is disposed in the liquid nitrogen cooling tank; input and output ends of the cooling water return pump are respectively connected with the spiral pipe and the return pipeline; one end of the return pipeline is disposed in the cooling water tank; input end of the cooling water injection pump is connected with the cooling water tank by a pipe.

Abstract: Systems and methods for collecting debris in a subterranean well include a wellbore cleanout tool having a tool housing with a tool bore. The wellbore cleanout tool further includes a power source, a wire in electrical communication with the power source, and a core member located within the tool bore. The wire is wound around the core member with a first end and a second end of the wire in electrical connection with a positive terminal and a negative terminal of the power source, respectively. A plurality of magnetic bars are spaced around the core member. A sleeve member is moveable between an uphole position where the sleeve member circumscribes the plurality of magnetic bars, and a downhole position where the sleeve member is located downhole of a portion of the plurality of magnetic bars and can be a collection basket. The wellbore cleanout tool further has a permanent magnet.

Abstract: Downhole electrical energy harvesting and communication in systems for well installations having metallic structure carrying electric current, for example CP current. In some instances there is a harvesting module (4) electrically connected to the metallic structure (2) at a first location and to a second location spaced from the first location, the first and second locations being chosen such that, in use, there is a potential difference therebetween due to the electric current flowing in the structure (2); and the harvesting module (4) being arranged to harvest electrical energy from the electric current. In addition or alternatively, there may be communication apparatus (4, 5, 6) for communication by modulation of the current, for example CP current, in the metallic structure (2).

Abstract: A turbine assembly is provided for downhole components of a well system. The turbine assembly includes a translational component which translates when a fluid is passed through the turbine assembly. The turbine assembly also includes a braking system which includes one or more magnets in magnetic communication with a conductive component. The braking system enacts a braking force onto the translational component due to the relative translation of the one or more magnets with the conductive component. The braking force from the braking system is proportional to the rate of translation of the translational component.

Abstract: The present invention relates to a method for verifying a well model, comprising the steps of receiving stored well data of an existing well, forming a model based on the received well data, submerging a tool for performing a work task into the existing well, wherein the tool is arranged to sense present well characteristics when submerged, receiving tool data corresponding to the presently sensed well characteristics from the tool, said tool data representing downhole properties relevant to downhole operation and performance of the tool, and performing a confirmation check by comparing the well data of the model with the tool data. Furthermore, the present invention relates to a well model verifying apparatus, to a well model verifying system and to a computer readable storage medium.

Abstract: Subsea system (100) and method of installing the subsea system (100), the method comprising the steps of: —preparing a first foundation (1?) comprising at least a first dedicated position for receiving a first subsea station (3?, 13?), —providing the first foundation (1?) with at least a first guide system (4?), —installing the first foundation (1?) at a subsea location, —preparing at least a first subsea station (3?, 13?) comprising a first flow module (5?) for connection with a pipeline (6), —installing the at least first subsea station (3?, 13?) with the first flow module (5?) in the first dedicated position on the first foundation (1?), —preparing a pipeline (6) and providing the pipeline (6) with at least a first T-connection (7?) at a determined calculated position corresponding to the first dedicated position on the first foundation (1?), —installing the pipeline (6) and allowing the pipeline (6) to rest on the first guide system (4?) on the first foundation (1?) such that the first T-connection (7?) i

Abstract: A device for perforating, packing, and fracturing and a tubing string comprising the device are disclosed, wherein the device comprises an upper connector, a nozzle sleeve, a mandrel, a packer, a lower connector, a first inner sleeve provided inside the upper connector, and a second inner sleeve provided inside the nozzle sleeve, further wherein the upper connector is provided with a fracturing hole, and a nozzle is provided at the nozzle sleeve.

Abstract: A method including (a) lowering a first tool string into a first wellbore, the tool string including a first perforating gun and a gun switch configured to detonate the first perforating gun, (b) detonating the first perforating gun in response to transmitting a first gun firing signal from a control system to the gun switch, (c) retrieving the tool string from the first wellbore following (c), (d) lowering a second tool string including the gun switch used in the first tool string and a second perforating gun into at least one of the first wellbore and a second wellbore that is different from the first wellbore following (d), and (e) detonating the second perforating gun of the second tool string in response to transmitting a second gun firing signal from the control system to the gun switch.

Abstract: A valve system for use in a wellbore, comprising a side pocket mandrel having a main bore for alignment with a wellbore tubular and a laterally offset side pocket bore separated from the main bore by an internal wall, the laterally offset side pocket bore comprising a first receptacle for a first device and a second receptacle for a second device, the internal wall having an opening through which each of the first device and the second device is independently retrievable. There is also provided a side pocket mandrel, a hydrocarbon well and a method of operating a hydrocarbon well.

Abstract: A method of extracting oil from a subsurface reservoir includes the steps of accessing the subsurface reservoir by means of a well, injecting a waterflooding composition comprising water and a functional molecule, into the subsurface reservoir through the well, altering the interfacial viscoelasticity, and extracting the oil through the well.

Abstract: A process for in situ thermal recovery of hydrocarbons from a reservoir is provided. The process includes: providing an oxygen-enriched mixture, fuel, feedwater and an additive including at least one of ammonia, urea and a volatile amine to a Direct-Contact Steam Generator (DCSG); operating the DCSG, including contacting the feedwater and the additive with hot combustion gas to obtain a steam-based mixture including steam, CO2 and the additive; injecting the steam-based mixture or a stream derived from the steam-based mixture into the reservoir to mobilize the hydrocarbons therein; and producing a produced fluid including the hydrocarbons.

Abstract: Ether amine additives are used in oil recovery such as steam-assisted gravity drainage and cyclic steam stimulation, as well as surface mining of bitumen. Methods of oil recovery using the ether amine additives are described. The ether amine additives are injected with steam into a subterranean oil reservoir such as oil tar sands to improve recovery of oils such as bitumen and/or heavy oil, or used to wash surface-mined rock to assist in oil extraction therefrom. The ether amine additives may be added to steam in steam-assisted oil recovery methods such as cyclic steam stimulation and steam-assisted gravity drainage. Condensates of the additives in steam exhibit very low advancing and receding contact angles and low interfacial tensions at low concentrations of the additives.

Abstract: System and methods of controlling fluid diversion during stimulation treatments are provided. Real-time measurements are obtained from a plurality of fiber-optic data sources at a well site during a stimulation treatment being performed along a portion of a wellbore within a subsurface formation. Fracture growth and stress within the subsurface formation surrounding the portion of the wellbore are determined as the stimulation treatment is performed, based on the real-time measurements and a fully-coupled diversion model. An amount of diverter for a diversion phase of the stimulation treatment to be performed along the portion of the wellbore is determined, based on the fracture growth and the stress within the subsurface formation. The diversion phase of the stimulation treatment is performed by injecting the amount of diverter into the subsurface formation via at least one injection point located along the portion of the wellbore.

Abstract: System and methods for customizing fracturing fluids downhole for real-time optimization of micro-fracturing operations are provided. Downhole operating conditions are monitored during a micro-fracturing operation along a portion of a wellbore within a subterranean formation, based on downhole measurements collected by sensors of a downhole formation tester. Injection parameters for a fracturing fluid to be injected from a bulk storage chamber of the downhole formation tester into the subterranean formation are determined based on the downhole operating conditions. Signals for customizing the fracturing fluid using one or more fluid additives stored within corresponding fluid storage chambers of the downhole formation tester are transmitted to a controller of the downhole formation tester, based on the injection parameters.

Abstract: A system and method of enhancing operation of hydraulic fracturing equipment at a hydraulic fracturing wellsite may include determining if a hydraulic fracturing stage profiles are available for use for hydraulic fracturing equipment at a wellsite. The method may include prompting an acceptance or amendment of one of the hydraulic fracturing stage profiles for a hydraulic fracturing pumping stage. The method may include, in response to an amendment of one of the hydraulic fracturing stage profiles, prompting acceptance of the amended hydraulic fracturing stage profile as the current hydraulic fracturing stage profile for use in association with the controller. The method may include, when a hydraulic fracturing stage profile is not available, prompting configuration of hydraulic fracturing pumping stage parameters for the current hydraulic fracturing stage profile.

Abstract: The disclosure provides a method comprising of determining an injection flow rate for each one of a plurality of wells, determining a total injection flow rate for the plurality of wells, introducing sequentially a series of treatment fluids into a well bore of each one of the plurality of wells, wherein each of the well bores penetrates at least a portion of a subterranean formation, the series of treatment fluids comprising: a first treatment fluid that comprises a base fluid and a reactive agent; and a second treatment fluid that comprises a microproppant slurry, allowing the first treatment fluid to form one or more fractures in the subterranean formation, and depositing at least a portion of a microproppant in the microproppant slurry in at least a portion of the one or more fractures in the subterranean formation.

Abstract: Method for control of an inner tube of an inclined tubular separator, wherein the inner tube is provided with an outlet adapted the viscosity of oil introduced into the inner tube.

Abstract: A system and method of automating a slide drilling operation comprising a plurality of tasks is described, in particular, reducing stored torque within a drill string that extends within a wellbore that includes storing, using a computing system, a first predetermined workflow to reduce stored torque within the drill string, and a second predetermined workflow to reduce stored torque within the drill string, wherein the first predetermined workflow comprises instructions to vertically move the drill string in first and opposing second directions; and wherein the second predetermined workflow comprises instructions to rotate the drill string in a first direction.

Abstract: Methods, systems, and computer-readable medium to perform operations including determining, in real-time, values of drilling parameters of a drilling system drilling a wellbore. The operations further include calculating, based on the values of the drilling parameters, a cuttings concentration in an annulus of the wellbore (CCA). Further, the operations include calculating, based on the calculated CCA and a mud weight (MW) of a drilling fluid, an effective mud weight (MWeff) of the drilling fluid. Yet further, the operations include calculating, based on the effective mud weight, a slip velocity of the cuttings. In addition, the operations include calculating, based on the slip velocity, a transport ratio (TR) of the cuttings.