Abstract: A drilling boom and rock drilling rig. The drilling boom includes a basic boom part, a distal end of which is provided with a front joint assembly of a wrist. The wrist connects a feed beam assembly to the basic boom part. The wrist has three joints, which are a roll-over joint, a feed tilt joint and a feed swing joint. The order of the joints of the wrist is optimized when the joints are in the mentioned order. The rock drilling rig is provided with one or more such drilling booms provided with face drilling units or bolting heads.

Abstract: A drilling system includes a rotatable string for connecting with a bit for drilling a borehole, and an active stabilizer which includes a body having an outer surface for contacting a wall of the borehole, and a plurality of actuators connecting the body and the string and capable of driving the string to deviate away from a center of the borehole with a displacement to change a drilling direction. The drilling system further includes a module for measuring direction parameters including at least one of a declination angle and an azimuth angle of the borehole, a module for measuring imbalance parameters including at least one of a lateral force, a bending moment and a torque near the drill dit, and a controller including a calculator for calculating an adjustment needed for the displacement, based on the measured parameters and expected values of these parameters.

Abstract: An earth-boring tool includes a body, at least one blade, and at least one rotatable cutting structure. The blade extends axially from the body and extends radially outward from a center longitudinal axis of the earth-boring tool to less than an outer diameter of the earth-boring tool. The blade defines a first cutting profile. The at least one rotatable cutting structure assembly is coupled to the body and includes a leg extending axially from the body and a rotatable cutting structure rotatably coupled to the leg. The rotatable cutting structure defines a second cutting profile extending to the outer diameter of the earth-boring tool. The first cutting profile overlaps with the second cutting profile in a radial direction in an amount that is less than 20% of the outer diameter of the earth-boring tool. A method of making an earth-boring tool.

Abstract: A hybrid earth-boring bit comprising a bit body having a central axis, at least one, preferably three fixed blades, depending downwardly from the bit body, each fixed blade having a leading edge, and at least one rolling cutter, preferably three rolling cutters, mounted for rotation on the bit body. A rolling cutter is located between two fixed blades.

Abstract: Reamer for earth-boring applications may include a body having a longitudinal axis and a blade carried by the body. The blade may include at least one cutting element located at a first radial distance from the longitudinal axis and a gage pad located at a second, smaller radial distance from the longitudinal axis. Methods of enlarging pilot holes in earth formations utilizing reamers may involve removing earth material from a sidewall of the pilot hole utilizing at least one cutting element located at a first radial distance from a longitudinal axis of a body of the reamer on a blade of a reamer.

Abstract: An example drill bit is configured to operate within a wellbore of a hydrocarbon-bearing rock formation. The drill bit includes a drill bit body including at least one leg. The drill bit may include at least one roller cone rotatably mounted on the drill bit body. The roller cone includes a plurality of cutting elements for abrading or crushing rock. The drill bit includes at least one bearing mounted between a surface of the drill bit body and the at least one roller cone to facilitate rotation of the at least one roller cone. The drill bit system includes a lubrication system to reduce friction between moving parts of the drill bit. The drill bit system includes at least one wear sensor associated with the drill bit to sense physical wear on the drill bit.

Abstract: A condition of a flexible pipeline may be monitored by scanning a section of the flexible pipeline with an ultrasonic scanner and using the ultrasonic scanner to produce a first ultrasonic signal that penetrates the section of the flexible pipeline and is used to create a set of condition data indicative of a condition present near or within an annulus of the flexible pipeline, the condition comprising pressure on or within the flexible pipeline.

Abstract: A pipe assembly has a hollow inner member nested within a hollow outer member. A series of pipe assemblies are connected end-to-end to form a dual-member drill string useful in horizontal directional drilling operations. The drill string has mutually exclusive first and second fluid paths. Fluid seals, interposed between adjacent inner members of the string, isolate the first fluid path from the second fluid path. Compressed air is delivered into the first fluid path from above ground level, and routed to an underground boring tool. The expelled air and spoils are returned to above ground level by way of the second fluid path. One or more baffle elements are supported on the drill string adjacent the boring tool. The baffle elements are configured to prevent compressed air and spoils from flowing between the walls of the borehole and the drill string.

Abstract: Embodiments of the invention generally provide a tube centralizer. The tube centralizer generally includes a base structure, and at least one rubber fin formed on the base structure, wherein the at least one rubber fin is configured to separate an inner pipe to which the tube centralizer is attached from an outer pipe.

Abstract: A load transfer system includes a load transfer bushing having a first and second arcuate segments configured to engage a load surface of a tubular or of a collar connected to the tubular, and an elevator configured to receive the load transfer bushing. Moving the elevator from its closed position to its open position while the elevator engages the load transfer bushing moves the first and second arcuate segments apart, permitting the elevator and the load transfer bushing to be received around the tubular. Moving the elevator from the opened position to the closed position with the load transfer bushing and elevator surrounding the tubular forms an axial engagement load surface for the load surface of the tubular or the collar. The load transfer bushing is disengageable from the elevator.

Abstract: An actuator assembly with integrated torque turn monitoring is described. Embodiments include a rotationally fixed outer hydraulic section and a rotationally independent inner hydraulic section which incorporates torque load sensors and rotational speed sensors directly into the inner hydraulic section. The inner hydraulic section is coupled to an outer cage using by a cage ring and is axially movable relative to the inner mandrel. Upper and lower fluid chambers are disposed between the outer housing assembly and the inner mandrel. Fluid pumped through a lower pressure port into the lower chamber moves the housing assembly in a first direction, and fluid pumped through an upper pressure port into the upper fluid chamber moves the housing assembly in a second direction.

Abstract: A system for moving a bridge crane includes a first drive and a second drive coupled to a support structure, a first sheave and a second sheave coupled to the support structure, and third sheaves coupled to a beam movable in a first axis. The system includes a first line coupled to the first drive, the first sheave, the second sheave, and one or more of the third sheaves. The first line is coupled to a gripping assembly that is coupled to the beam and movable in a second axis. The system includes a second line coupled to the second drive, the first sheave, the second sheave, and the third sheaves. The second line is coupled to the gripping assembly. Rotating the first and second drives causes the beam and the gripping assembly to move in the first axis and/or the gripping assembly to move in the second axis.

Abstract: A rod positioning device for aligning a drilling rod with a rod string having complementary mating threads, comprising a base, an arm mounted to the base about a first rotation axis, and a rod-gripping device mounted on the arm. The arm is for displacement about the first rotation axis between a rod loading position and a rod alignment position. The rod-gripping device is for operating between a rod-gripping configuration and a rod-releasing configuration. The rod-gripping device comprises jaws for gripping the drilling rod while the rod-gripping device is in the rod-gripping configuration and the arm is in the rod loading position, and guiding elements mounted on the jaws, the guiding elements aligning the drilling rod with the rod string and enabling longitudinal displacement of the drilling rod to contact the rod string.

Abstract: This invention relates to a drilling rig or a drill ship having a first activity centre with a main well, a second activity centre with an auxiliary well and a third activity centre with offline casing and drill pipe stand-building capabilities. The offline casing and drill pipe stand-building facility is a standalone feature and can be located in the forward or aft side of a drilling rig or drill ship depending on the choice of the builder or operator.

Abstract: A pipe-handling apparatus for moving a pipe relative to a drilling floor of a drilling rig, the pipe-handling apparatus having a main support structure; a pipe delivery mechanism for delivering pipe between a pipe load/unload position and a drilling floor position; and at least one walking unit comprising: a jack capable of lifting the main support structure in a substantially vertical direction; and a foot capable of moving the main support structure in a substantially horizontal direction.

Abstract: Embodiments of methods for reducing lost circulation in a wellbore comprise inserting a conduit comprising a first and second end and an outer diameter and an inner diameter into the wellbore, and pumping a thixotropic cement slurry, wherein the thixotropic cement slurry will increase in viscosity with no shear and decrease in viscosity with shear, and have a power law exponent value of less than or equal to 0.3 when the thixotropic cement slurry has a density of greater than 12.69 pounds per gallon, through the conduit into the wellbore, in which the thixotropic cement slurry comprises at least one cement, at least one viscosifier, mix water, and one or more than one strength accelerating additives. The method further comprises allowing the thixotropic cement slurry to harden in the wellbore to create a plug, removing the conduit from the wellbore, and reducing lost circulation via the plug in the wellbore.

Abstract: An example mobile drilling fluid plant includes a plurality of intermodal containers each exhibiting a length, a width, and a height compliant with universal shipping container dimensions and configurations dictated by the International Organization for Standardization, wherein the plurality of intermodal containers include a plurality of fluid storage containers and one or more fluid mixing containers, one or more pumps in fluid communication with the plurality of fluid storage containers and the one or more fluid mixing containers, and one or more flexible hoses fluidly coupled to the one or more pumps and placing the plurality of fluid storage containers in fluid communication with the one or more fluid mixing containers.

Abstract: A system for use in the drilling of oil or gas wells in conjunction with a mud injection device, said mud injection device adapted to maintain fluid pressure control within the borehole of a well bore when operating a drillstring therethrough, the system comprising: a gas reservoir containing gas; adapted for injection to control borehole pressure; compression system fluidly connected to the gas reservoir and the borehole; a pressure regulation system operatively connected to the gas reservoir and the borehole and adapted to measure the pressure within the annulus and relay such to a computer; wherein, when a drilling operation is halted to add a new stand to the drillstring and the mud injection device is stopped, the gas is injected to maintain the borehole pressure within the annulus of the borehole at a near constant value.

Abstract: A method for operating a drilling system that has a mud pump disposed on an earth surface and a drill string with a bottom hole assembly (BHA) in a borehole. The method involves turning the mud pump ON or OFF according to a pre-determined sequence so that the mud flow in the borehole fluctuates between high and low. The mud pulser in the bottom hole assembly senses the fluctuation in the mud flow and generates a binary signal accordingly. The mud pulser further sends the binary signal to a measurement-while-drilling (MWD) tool in the bottom hole assembly. The binary signal executes one or more firmware in the MWD tool.

Abstract: A modular force multiplier converts a pull-up force applied to a work string from the surface into a multiplied opposite linear force that can be used to operate downhole tools to perform tasks requiring the application of linear force.

Abstract: The invention provides an expanding and collapsing ring apparatus (171) and method of use. The expanding and collapsing ring comprises a plurality of elements (177) assembled together to form a ring structure (172, 173a, 173b) oriented in a plane around a longitudinal axis. The ring structure is operable to be moved between a collapsed condition and a first expanded condition by movement of the plurality of elements on actuation by an axial force. The apparatus further comprises a secondary expanding and collapsing mechanism operable to move the ring structure between its collapsed condition or its first expanded conditions to a second expanded condition on actuation by an axial force. Applications of the invention include oilfield devices, including anti-extrusion rings, plugs, packers, locks, patching tools, connection systems, and variable diameter tools run in a wellbore.

Abstract: This system invention relates to the use of short hop communications to transfer data between two modules inside a well. A system deployed in a well permanently or semi-permanently collects data from downhole parameters such as pressure, temperature, vibration, flow and fluid identification and stores the information in the system memory. The receiver module is deployed in the well via slick line, electric line or coil tubing with the purpose of retrieving the data from the system memory by interfacing with the downhole module via wireless short hop communications. The receiver module can also send commands into the downhole module to change its data collection parameters. Upon completion of the data transfer, the collector is returned to the surface where the data is again wirelessly transferred to a processing system such as a Personal Computer.

Abstract: A system and method to actuate a downhole tool, where the tool can include a body, a closure member and a degradable actuation ring. A profile of the actuation ring can be configured to engage an actuation tool (e.g. shifting tool, ball drop, dart, plug, etc.) used to displace the activation ring via the engagement and thereby displacing the closure member to a different position. The degradable actuation ring can be degraded by an agent downhole to degrade and/or remove the actuation ring from the downhole tool thereby providing an increased clearance through the tool.

Abstract: A settable device including a radially enlargeable portion, a force retention pathway (between 20 and 42 or between 20 and 160) operably connected to the radially enlargeable portion to maintain a setting force to the radially enlargeable portion, a material disposed within the force retention pathway (between 20 and 42 or between 20 and 160) of the device, the material retaining force when in solid form and disengaging force retention when in fluid form.

Abstract: A technique enables maintenance of sufficient clearance between a wellhead and, for example, a mobile rig. The technique facilitates support of a cable, e.g. an antenna suspension cable, at the wellhead without detrimentally affecting the desired clearance. According to an embodiment, a flange system is used in combination with a cable clamp assembly at a wellhead. The flange system may comprise a flange having a connector portion configured for coupling with the wellhead. The flange also comprises a cylinder portion coupled to the connector portion such that the cylinder portion extends into a corresponding bore of the wellhead. The cable clamp assembly is configured to clamp around and support a cable extending down through the wellhead. The cable clamp assembly is supported within the cylinder portion of the flange such that the cable clamp assembly is at least partially disposed within the wellhead.

Abstract: An umbilical termination head (1) for connection of a multi-bore flying lead or umbilical (2) to a structure (10), the flying lead or umbilical comprising multiple conduits (7) leading to couplers (4) being arranged on a connector part (3), the umbilical (2) being provided with an end fitting (9) onto which a bracket arrangement (8, 19, 20) is mounted, the connector part (3) being mounted to a bracket (8) of the bracket arrangement. A guide means (11) is arranged on the bracket (8) in such a way that an interacting guide means (12) on the structure (10) lead the umbilical termination head (1) onto the structure (10) for connection of the couplers (4) to corresponding couplers (6) on the structure (10).

Abstract: In one embodiment, a sealing device includes a tubular body having a bore; a collet seat having a plurality of collets; a frangible sealing element disposed in the collet seat and blocking fluid communication through the bore; and a releasable sleeve releasably attached to the tubular body and retaining the collet seat against the tubular body.

Abstract: A sealing device includes a tubular body having a bore; a collet seat having a plurality of collets; a frangible sealing element disposed in the collet seat and blocking fluid communication through the bore; and a releasable sleeve releasably attached to the tubular body and retaining the collet seat against the tubular body. In one embodiment, the plurality of the collets includes threads mated with threads on the tubular body. In another embodiment, the plurality of the collets is attached to the sleeve.

Abstract: A female undersea hydraulic coupling member is equipped with a plurality of pressure-energized metal seals configured to seal between the body of the female member and the probe of a corresponding male hydraulic coupling member in response to ambient hydrostatic pressure and/or hydraulic fluid pressure. Pressure-energized metal seals may also be provided to seal between the body of the female coupling member and a removable seal retainer or seal cartridge. In one particular preferred embodiment, the pressure-energized seals are back-to-back metal C-seals separated by annular seal supports having a generally T-shaped cross section and retained on one or more shoulders in the body of the female member by a removable seal cartridge.

Abstract: The invention provides an expanding and/or collapsing apparatus (10) and a method of use. The apparatus comprises a plurality of elements (12) assembled together to form a ring structure oriented in a plane around a longitudinal axis. The ring structure is operable to be moved between an expanded condition and a collapsed condition by movement of the plurality of elements. The plurality of elements is operable to be moved between the expanded and collapsed conditions by sliding with respect to one another in the plane of the ring structure, in a direction tangential to a circle concentric with the ring structure. Applications of the invention include oilfield devices, including anti-extrusion rings, plugs, packers, locks, patching tools, connection systems, and variable diameter tools run in a wellbore.

Abstract: Plug assemblies for plugging a wellbore tubular and methods relating thereto are disclosed. In an embodiment, the plug assembly includes a central axis and a seal sub including a plurality of axially extending fingers and a tapered outer surface. In addition, the plug assembly includes a sealing element coupled to the axially extending fingers of the seal sub. Further, the plug assembly includes a slip sub including a tapered inner surface, and a plurality of axially extending fingers. The fingers of the slip sub each include one or more teeth. The seal sub is configured to be at least partially inserted within the slip sub so that the tapered outer surface engages with the tapered inner surface, and axial advance of the tapered inner surface within the tapered outer surface is to radially expand the fingers of the slip sub to engage with an inner surface of the tubular.

Abstract: A filament-reinforced composite material having with load-aligned filament windings enables improvement of mechanical properties for specific loading of parts made from the material. The orientation of the winding within the part may be changed depending on an orientation of an external load to the part. In one example, the part may be a slip in a frac plug or a bridge plug in a downhole application.

Abstract: A wellbore tool includes a rotatable elongate pipe that includes a first elongate portion extending along a longitudinal axis of the elongate pipe. A first bending portion with a first end attaches to a downhole end of the first elongate portion. The first bending portion deviates from a longitudinal axis of the first elongate portion in a first direction. A second bending portion has a first end attached to a second end of the first bending portion. The second bending portion is positioned downhole of the first bending portion. The second bending portion deviates towards the longitudinal axis in a second direction different from the first direction. The first bending portion and the second bending are eccentric relative to the first elongate portion. The wellbore tool is rotated a set amount and stabbed in a downhole direction until the wellbore tool enters the parted casing.

Abstract: A wellbore tool includes a rotatable elongate pipe that includes a first elongate portion extending along a longitudinal axis of the elongate pipe. A first bending portion with a first end attaches to a downhole end of the first elongate portion. The first bending portion deviates from a longitudinal axis of the first elongate portion in a first direction. A second bending portion has a first end attached to a second end of the first bending portion. The second bending portion is positioned downhole of the first bending portion. The second bending portion deviates towards the longitudinal axis in a second direction different from the first direction. The first bending portion and the second bending are eccentric relative to the first elongate portion. The wellbore tool is rotated a set amount and stabbed in a downhole direction until the wellbore tool enters the parted casing.

Abstract: A frac valve can include an outer housing with at least one port which provides for fluid communication between an interior and an exterior of the outer housing, and a sleeve releasably secured against displacement between a closed position in which the sleeve blocks flow through the port and an open position in which flow through the port is permitted. The sleeve may be press-fit in the outer housing as a result of the displacement. A method of operating a frac valve can include connecting the frac valve in a tubular string, and displacing a sleeve of the frac valve between closed and open positions. The displacing step can include deforming the sleeve and/or an outer housing of the frac valve, thereby preventing relative rotation between the sleeve and the outer housing.

Abstract: A downhole pump used for a reciprocating pump system includes a barrel coupling to a tubing string and having a standing valve and includes a plunger coupling to a rod string and having a traveling valve. One or both of the valves can include an assembly comprising a housing, an insert, a ball, and a seat. The insert allowing for flow therethrough defines a ball stop at one end has a ball passage at the other end. The insert positions in flow passage of the housing, and one of the ends engages a shoulder in the passage. The insert is secured in the flow passage with metallic material metallurgically affixed between at least a portion of the insert and the flow passage. For example, brazing material can be brazed at the end of the insert to metallurgically affix the insert in the passage. The ball is positioned in the insert, and the seat is positioned adjacent an end of the insert. The assembly is then incorporated into components of the pump.

Abstract: A choke controlling fluid flow in a well has a conduit with an inlet and an outlet, and a flow restrictor comprising first and second choke members, one of which rotates relative to the other to choke or promote flow. The first and second choke members are axially spaced from one another, and have mating faces that are optionally planar, and are axially stacked in the choke. The choke is operated by a shifting tool, which grips the inner surface of the rotating choke member, and rotates it relative to the other, in order to vary the flow.

Abstract: A fracturing system includes a fracturing sleeve having an opening sleeve and a closing sleeve. The closing sleeve has a collapsible seat. The system also includes a sand screen spaced from the fracturing sleeve and disposed in a same zone as the frac sleeve. The screen includes a screen sleeve having a collapsible seat, the screen seat being complementary to a plug that is complementary to the closing sleeve collapsible seat.

Abstract: A ported tubular is provided for use in casing a wellbore, to permit selective access to the adjacent formation during completion operations. A system and method for completing a wellbore using the ported tubular are also provided. Ports within the wellbore casing may be opened, isolated, or otherwise accessed to deliver treatment to the formation through the ports. A tool assembly and method for completing a well are also provided. The tool includes debris relief features that enable use in solids-laden environments, for example in the presence of sand. Forward and reverse circulation pathways to the isolated interval are present to allow clearing of debris from the wellbore annulus while the sealing device remains set against the wellbore.

Abstract: A method of pumping fluids down a wellbore. The method first comprises providing a wellbore. The wellbore has been completed with a pumping system comprising a string of production tubing, a polished rod, and a sucker rod string extending down into the production tubing. A traveling valve is connected at a lower end of the sucker rod string. The method also includes adjusting a position of the polished rod relative to the pumping system to enable the traveling valve to tag a standing valve. The method further comprises compressing the traveling valve to cause the traveling valve to open. The method additionally includes pumping a fluid down the production tubing. The fluid is further pumped across the traveling valve and the standing valve, optionally while the standing valve remains seated.

Abstract: A method of manufacturing a safety valve chamber housing can include depositing a chamber housing material, and thereby gradually building up the chamber housing and forming a chamber in the chamber housing enclosed by the chamber housing material, the chamber being bounded by only a single solid structure of the chamber housing. A safety valve can include a piston, and a chamber housing having a piston bore and a chamber formed therein, the piston bore being in communication with the chamber, the chamber being enclosed by only a single chamber housing material. A well system can include a safety valve connected in a tubular string, the safety valve including a chamber housing with a chamber in communication with a control line, inner and outer walls of the chamber housing being made of a continuous chamber housing material.

Abstract: A drilling tool with power generation includes an outer housing and a driveshaft located at least partially within the outer housing and configured to rotate with respect to the outer housing via bearings located between the driveshaft and the outer housing. The drilling tool also includes an electromagnetic power generation device. The electromagnetic power generation device includes a coil and a magnet located within the housing. One of the coil and the magnet is coupled to the housing and the other is coupled to the driveshaft. Relative movement of the driveshaft with respect to the coil generates electrical power.

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: 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: Raw, real-time drilling data is pulled from a centralized database for processing. The raw, real-time drilling data is re-formatted into a format required for processing by one or more predictive models. Real-time processing is performed with respect to one or more drilling parameters associated with the re-formatted data using the one or more predictive models to generate output data. The output data received from the one or more predictive models is re-formatted for storage in the centralized database. The reformatted output data is retrieved from the centralized database for analysis with respect to visualization, generating alerts, or generating recommendations.

Abstract: A method and apparatus for containing one or more shaped charges in a single plane, arrayed about the center axis of a gun body, and detonated from a single initiator in a shaped charge cluster assembly.

Abstract: A signal transfer assembly includes a signal transfer propellant assembly and a signal transfer connector tube in hydraulic communication with a signal transfer firing head. The signal transfer propellant assembly has a piston and a gas generating energetic material. The signal transfer connector tube has a bore and a first opening allowing fluid communication between a borehole fluid surrounding the connector tube and the bore. The piston generates a pressure pulse when propelled through the bore by the generated gas. The signal transfer firing head assembly includes a housing having a second opening allowing fluid communication between the housing bore and the borehole fluid. A related method includes forming a well tool by operatively connecting a signal transfer assembly as described above to a primary downhole tool and a secondary downhole tool; conveying the well tool into a wellbore using a work string; and activating the secondary downhole tool by initiating the primary downhole tool.

Abstract: A firing head assembly for a well tool includes a shaft, a piston head, a biasing member, and a housing. The shaft has a nose and a terminal end. The shaft also includes a first shoulder and a second shoulder formed between the nose and the terminal end. The piston head slides along the shaft and is positioned between the retaining element and the first shoulder. The biasing member is mounted on the shaft and positioned between the piston head and the second shoulder. The housing has a bore in which the shaft, the piston head, and biasing member are disposed. The housing includes an opening allowing fluid communication between the housing bore and the borehole fluid external to the housing.

Abstract: A system, method and process (utility) is presented to control a gas injection setpoint of a production well utilizing gas lift. The utility may control a flow valve and/or source of injection gas (e.g., gas injection compressor) to increase or decrease a gas injection flow rate (e.g., setpoint) into the well during a gas injection interval. The utility monitors bottom hole pressure related values for multiple gas injection intervals with each have different gas injection setpoints (e.g., flow volumes). Bottom Hole Pressures (e.g., averages). The differences between the Bottom Hole Pressures are compared to calculate Bottom Hole Pressure Drawdown (BHPD) rates between intervals. A subsequent gas injection setpoint (e.g., direction and/or magnitude of change) is selected based on a comparison of a current BHPD and a previous BHPD.

Abstract: According to one aspect, a system is adapted to actively control one or more operating parameters associated with: a wellbore extending in a subterranean formation, and/or wellbore fluid flowing out of the wellbore via a wellhead. The system includes one or more sensors; an electronic controller adapted to receive from the one or more sensors measurement data; and a valve through which the wellbore fluid is adapted to flow. The valve is adapted to be in communication with the electronic controller. The active control of the at least one of the one or more operating parameters is adapted to facilitate: maintenance of the integrity of the wellbore, and/or enhancement of oil and/or gas production out of the wellbore. In one embodiment, the wellbore fluid flow is frac flow-back. In another aspect, a system is adapted to monitor vent gas separated from wellbore fluid flowing out a wellhead.