Abstract: Systems and methods for managing power at a wellsite. A system includes well construction equipment, power equipment, a power manager, power equipment sensors operable to output power equipment sensor data indicative of operational status of the power equipment, and a human-machine interface usable by a human user to enter power management settings. The power manager is operable to receive the power equipment sensor data and receive the power management settings, wherein each power management setting is associated with a corresponding mode of operation of the power manager. The power manager is further operable to, for each power management setting, change the mode of operation of the power manager to the mode of operation associated with that power management setting, and for each mode of operation, cause the power equipment to supply electrical power to the well construction equipment in a predetermined manner with respect to that mode of operation.

Abstract: Methods of mapping a subterranean formation using imploding particles are described. In some cases, the particles contain a material that generated a gas which passes through a water-insoluble coating to create a void within the particle. In some aspects, the implosive particles have a coating that dissolves in the subterranean formation.

Abstract: The present disclosure provides a valve assembly comprising a valve section, a power section, and an electronics section. The valve assembly is configured to mate with a tubing sub (and/or mandrel) inserted in-line with a tubing string inserted into a wellbore. The valve allows for injection into or production from the tubing string. The valve assembly comprises an electric motor and a motor controller permitting fine control over the valve, as well as sensors which measure various parameters, such as fluid flow, valve position, pressure, temperature, and/or water cut. A cable connects the valve assembly to the surface and provides power and data telemetry and allows control of the valve assembly with a remote electronic signal. Multiple valve assemblies may be provided at spaced intervals along the tubing string and individually monitored and/or controlled by a remote location. Also disclosed is a method for operation of such valve assemblies.

Abstract: An electric submersible pump assembly with integral heat exchanger, high speed gas separator, high-speed self-aligning bearings, and dual bearing thrust chamber is described. The described gas separator may be used for operating an electric submersible pump at high speeds as well as over a wide range of speeds and flowrates without replacing downhole equipment.

Abstract: Methods and compositions for introducing a treatment fluid into a wellbore penetrating a subterranean formation wherein the treatment fluid comprises: a base fluid; and composite diverting particulates, wherein the composite diverting particulates each comprise a degradable polymer and an oil-soluble material, wherein the composite diverting particulate at least partially plugs a zone in the subterranean formation; and diverting at least a portion of the treatment fluid and/or a subsequently introduced fluid away from the zone.

Abstract: A system includes a first tubing arranged within a second tubing. A first flow path is formed within the second tubing, and a second flow path is formed between the first tubing and the second tubing. A pump is disposed within the first tubing and has a discharge end that is fluidly connected to the first flow path. A seal fitting coupled to a distal end of the first tubing includes a third flow path and a sealing arrangement to isolate the second flow path from a portion of an external environment of the first tubing. A gas separator is positioned to receive a fluid mixture stream from the third flow path and separate the fluid mixture stream into a gas stream that is directed into the second flow path and a liquid-rich fluid stream that is directed into the pump.

Abstract: A multi-functional well completion apparatus and method of operation thereof that offers the ability, in a single trip and with limited running tool manipulation, to perform downhole completion operations, such as gravel pack operations or sand control frac or other fluid stimulation operations is described. The well completion tool has multiple functions or operational positions by using a self-closing time delay valve without the need of service tools, thereby saving rig time, reducing operating costs and operational risks associated with tripping service tools into and out of a wellbore.

Abstract: A junction for use in a multilateral completion system is presented. The junction comprises a metal sealant applicable to a lateral component of the multilateral completion system. The metal sealant is expanding in response to hydrolysis and after activation forms a seal and an anchor with a well casing or tubing of the multilateral completion system. The metal sealant is expanding in response to one of an alkaline earth metal hydrolysis and a transition metal hydrolysis. More specifically, the metal sealant is expanding in response to one of magnesium hydrolysis, aluminum hydrolysis, calcium hydrolysis, and calcium oxide hydrolysis.

Abstract: The present disclosure provides a valve assembly comprising a valve section, a power section, and an electronics section. The valve assembly is configured to mate with a tubing sub (and/or mandrel) inserted in-line with a tubing string inserted into a wellbore. The valve allows for injection into or production from the tubing string. The valve assembly comprises an electric motor and a motor controller permitting fine control over the valve, as well as sensors which measure various parameters, such as fluid flow, valve position, pressure, temperature, and/or water cut. A cable connects the valve assembly to the surface and provides power and data telemetry and allows control of the valve assembly with a remote electronic signal. Multiple valve assemblies may be provided at spaced intervals along the tubing string and individually monitored and/or controlled by a remote location. Also disclosed is a method for operation of such valve assemblies.

Abstract: The present disclosure provides a valve assembly comprising a valve section, a power section, and an electronics section. The valve assembly is configured to mate with a tubing sub (and/or mandrel) inserted in-line with a tubing string inserted into a wellbore. The valve allows for injection into or production from the tubing string. The valve assembly comprises an electric motor and a motor controller permitting fine control over the valve, as well as sensors which measure various parameters, such as fluid flow, valve position, pressure, temperature, and/or water cut. A cable connects the valve assembly to the surface and provides power and data telemetry and allows control of the valve assembly with a remote electronic signal. Multiple valve assemblies may be provided at spaced intervals along the tubing string and individually monitored and/or controlled by a remote location. Also disclosed is a method for operation of such valve assemblies.

Abstract: A main well bore is drilled. The main well bore is completed and stimulated. The main well bore is sealed. A lateral well bore is drilled off the main well bore. A junction that allows communication with the lateral well bore and that connects the main well bore is inserted. The lateral well bore is stimulated through the junction. The main well bore is unsealed, allowing comingled flow from the main bore and the lateral bore.

Abstract: A downhole tool and method of use. The downhole tool includes a stimulation sleeve receptive to a stimulation insert, and a production sleeve receptive to a production insert. A formation parameter of the reservoir is obtained. The tool is assembled to include the stimulation sleeve and the production sleeve, which are configured based on the formation parameter. The tool is run downhole into a wellbore to perform a stimulation operation via the stimulation sleeve and a production operation via the production sleeve.

Abstract: Aspects of the subject technology relate to systems and methods for pumping multiple wellbores from a common pumping source. A fluid pump of known operating pump capacity can be selected. The pump can be fluidly connected to a common pumping source that is fluidly connected with each of a plurality of cased wellbores in a subterranean formation for providing pumped fracturing fluid to each of the wellbores. Each of the plurality of wellbores can have at least one perforation through a casing of the wellbore with a known rate range within which fracturing fluid is required to be provided to the perforation to successfully fracture the subterranean formation outside the perforation, through the perforation. Further, the wellbores can be configured so that the common pumping source provides fracturing fluid to each of the perforations within the known rate range of the respective perforation to successfully fracture the subterranean formation.

Abstract: A method and system for enhancing petroleum production are provided, in which a fracturing operation can be conducted in a formation through a string and then petroleum is displaced from the fractured formation by selectively injecting fluid into selected fractures in the formation while other non-selected fractures remain without fluid injection. The injected fluid flows out into the fractured formation and enhances recovery from the non-selected fractures. Petroleum is selectively collected from the non-selected fractures.

Abstract: A deflector assembly for an object in a well. The deflector assembly may include a tubular housing and a core plug. The tubular housing may include a window through a wall of the tubular housing, a deflector below the window. The deflector may include a cavity extending through an axial length of the deflector and a deflector angled surface that is shaped to direct the object toward the window. The core plug may be removably coupleable within the cavity and include a receptacle and a second angled surface that is shaped to direct the object toward the window. The second angled surface is aligned with the deflector angled surface. The core plug may be coupleable with the deflector so as to rotate with the deflector.

Abstract: A flow control device including a housing sized to be disposed within a wellbore; a valve portion disposed within the housing and operable to control the flow of fluid therethrough, the valve portion having at least one valve having a first configuration and a second configuration; an actuator operable to adjust the at least one valve between the first configuration and the second configuration; and a conduit coupled with an exterior surface of the housing and in fluidic communication with the at least one valve.

Abstract: Provided, in one aspect, is a windowed deflector assembly. The windowed deflector assembly according to this aspect includes a tubular housing, the tubular housing having a window there through, a wrap covering the window, and a deflector coupled to or formed integrally as part of the tubular housing.

Abstract: A cementing tool has an outer housing defining a central flow passage and a plurality of housing flow ports through a wall thereof. An opening sleeve has first and second opening sleeve faces exposed to housing pressure. The first opening sleeve face has a greater surface area than the second opening sleeve face. The pressure differential created is such that the sleeve will move from a first position to a second position in which flow through the plurality of housing flow ports is permitted. The cementing tool has an opening seat defined on the opening sleeve. The opening sleeve may also be moved from the first to the second position as a result of the engagement of the opening plug with the opening seat and an application of pressure thereabove.

Abstract: A system includes a string disposed in a wellbore, a first valve coupled to the string, the first valve including a sleeve having an engagement profile with a first coded sequence, a second valve coupled to the string, the second valve including a sleeve having an engagement profile with a second coded sequence that differs from the first coded sequence of the first valve, and a first dart flow transportable through the string, the first dart including a collet finger having a first coded sequence configured to restrict the collet finger from matingly engaging the engagement profile of the first valve while permitting the collet finger to engage the engagement profile of the second valve, wherein the first dart actuates the sleeve of the second valve between first and second positions in response to the collet finger of the first dart matingly engaging the engagement profile of the second valve.

Abstract: A unitary multilateral junction for deployment in a wellbore, wherein the multilateral junction permits electrical power and communications signals to be established in both a lateral wellbore and a main wellbore utilizing. The unitary junction assembly generally includes a conduit with a first upper aperture, a first lower aperture and a second lower aperture where the first lower aperture is defined at the distal end of a primary passageway extending from a conduit junction and a second lower aperture defined at the distal end of a lateral passageway extending from the conduit junction. A lower wireless energy transfer mechanism is positioned along at least one of the passageways between the distal end of the passageway and the junction. The lower wireless energy transfer mechanism is in wired communication an upper energy transfer mechanism permitting electrical communication to be established across the intersection of wellbore branches utilizing the unitary junction.

Abstract: A method for securing a downhole assembly to a casing string disposed within a wellbore includes moving, in a first direction, at least a portion of the downhole assembly within a passageway of a landing nipple that forms a portion of the casing string; exchanging a wireless signal between a first communication device that is coupled to the downhole assembly and a second communication device that forms a portion of the nipple; and preventing further movement of the downhole assembly, relative to the nipple, in the first direction in response to the exchange of the wireless signal and when the first communication device is spaced from the second communication device in the first direction.

Abstract: An apparatus, system, and method are disclosed herein. In one embodiment, the apparatus includes a plurality of valves. Each valve of the plurality of valves is associated with a respective production zone of a well. Each valve includes a valve body having a passage and an inflow fluid input through which a formation fluid from the respective production zone associated with the valve is to enter the passage of the valve body. Each valve further includes a sensor located within the valve body to detect a density of the formation fluid. The apparatus further includes a processor programmed to determine a fraction of a subject fluid in the formation fluid based on the density of the formation fluid and a density of the subject fluid.

Abstract: Aspects of the subject technology relate to systems and methods for pumping multiple wellbores to form and stabilize fractures during a fracturing job. A fluid pump of known operating pump capacity measurable in barrels per minute is selected. The pump is fluidly connected with each of a plurality of cased wellbores in a subterranean formation for providing fracturing fluid to each of the wellbores. The plurality of wellbores each have at least one perforation through a casing of the wellbore that has a known rate range within which fracturing fluid is required to successfully fracture the subterranean formation outside the perforation through the perforation. The pump is configured to provide fracturing fluid to each of the perforations within the known rate range of the respective perforation to successfully fracture the subterranean formation outside of the perforation.

Abstract: Electrical submersible pump (ESP) completion in a lateral wellbore includes an ESP installed in a wellbore that includes a vertical wellbore portion and a lateral wellbore portion that is connected to the vertical wellbore portion at a junction. The ESP is installed in the vertical wellbore portion downhole of the junction. The lateral wellbore portion extends to a subsurface hydrocarbon reservoir carrying hydrocarbons. Using the ESP, at least a portion of the hydrocarbons is produced through the lateral wellbore portion.

Abstract: A downhole indicating device includes a collet body and a slidable collet comprising a protrusion and surrounding and slidable along a length of the collet body between a low snap position and a high snap position. In the low snap position, the protrusion is depressible under a low snap force, and in the high snap position, the protrusion is depressible under a high snap force with the low snap force being less than the high snap force.

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: A tool, system, and method for reentry access into a lateral wellbore. The tool, utilized in the system and the method, can include a body with an internal flow passage, an inflatable bladder disposed along an exterior portion of the body, and a flow restrictor that can partially restrict fluid flow through the internal flow passage and create a pressure differential across the tool when fluid pressure rises at an inlet of the internal flow passage. The pressure differential can cause inflation of the inflatable bladder and a surface of the inflatable bladder can be extended radially outward from the body in response to the inflation, where the extended surface can push the tool away from a wall of a main wellbore toward an opposite wall of the main wellbore and divert the tool into a lateral wellbore.

Abstract: A multilateral deflection system is configured to exit a main bore and enter an offset lateral. The multilateral deflection system includes a hole arranged in a ground surface having a main bore and an offset lateral. A latch in coupling is arranged in the main bore. A deflector assembly further includes a deflector body joined to deflector rails and deflector threads. A latch in sub is made up to the deflector body. A deflector profile is arranged in the main bore. A seal assembly is joined to a bottom side of the deflector body.

Abstract: A tubular goods connection for releasably coupling tubular members includes: a coupling having a first internal wedge dove-tail thread formed within a longitudinal bore of the coupling and a second internal dove-tail wedge thread; a first tubular member having a first mating external vanishing dove-tail wedge thread extending from a first proximal pin end face; and a second tubular member substantially identical to the first tubular member; wherein when the first and second tubular members are made-up into the coupling using a predetermined recommended optimum torque, a distance D between the first pin end face and the second pin end face is in the range of 0 to 10 millimeters and when the distance D is equal to 0 there is contact between the first pin end face and a second pin end face of the second tubular good but there is no axial interference.

Abstract: A method of reducing erosional peak velocity includes arranging a sand control screen assembly in an open hole section of a wellbore, the sand control screen assembly including a base pipe defining a plurality of flow ports, a sand screen arranged about the base pipe, and a wellbore isolation device deployed within an annulus defined between the sand control screen assembly and an inner wall of the wellbore. A fluid from a surrounding subterranean formation is circulated within the annulus, and the fluid within the annulus is diverted through the sand screen and into the base pipe upon approaching the wellbore isolation device. A peak velocity of the fluid flowing through the sand screen is reduced with a peak flux reducing assembly arranged axially adjacent the wellbore isolation device.

Abstract: Systems and methods for multi-lateral wellbore construction and stimulation from cased parent wellbores. Methods and apparatus are provided to facilitate the creation of casing exit openings in the casing of parent wellbores. Methods and systems are provided for azimuthally and longitudinally aligning drilling assemblies through openings in a parent wellbore casing are provided to allow for drilling multiple lateral wellbores extending outwardly from a parent wellbore. A method of stimulating one or more subterranean zones intersected by multiple lateral wellbores extending outwardly from one or more patent wellbores includes the steps of: simultaneously injecting a stimulation fluid into the lateral wellbores; and stimulating the zones intersected by the lateral wellbores in response to the stimulation fluid injecting step.

Abstract: The present disclosure provides a valve assembly comprising a valve section, a power section, and an electronics section. The valve assembly is configured to mate with a tubing sub (and/or mandrel) inserted in-line with a tubing string inserted into a wellbore. The valve allows for injection into or production from the tubing string. The valve assembly comprises an electric motor and a motor controller permitting fine control over the valve, as well as sensors which measure various parameters, such as fluid flow, valve position, pressure, temperature, and/or water cut. A cable connects the valve assembly to the surface and provides power and data telemetry and allows control of the valve assembly with a remote electronic signal. Multiple valve assemblies may be provided at spaced intervals along the tubing string and individually monitored and/or controlled by a remote location. Also disclosed is a method for operation of such valve assemblies.

Abstract: Downhole tool assembly comprises a whipstock engageable with a flow control device. The whipstock comprises a channel. A core is removably mounted in the channel. The flow control device comprises a valve with a shiftable sleeve for selectively directing fluid flow. In a process of drilling and operating a branched well, the whipstock is anchored at a junction in a first well. A second well is drilled from the junction in a direction defined by the work face of the whipstock. After drilling, the core is removed to open the channel in the whipstock. The valve can be set to direct fluid flow to the second well so a fluid pressure can be applied to the second well. The valve can also be set to direct fluid flow through the channel to the first well, so a fluid pressure can be applied to the first well.

Abstract: Systems and methods are described for drilling a new secondary wellbore from a primary wellbore in which a production string is already deployed. The production string is severed below a desired kick-off location for the new secondary wellbore and the upstream portion of the production string is withdrawn from the primary wellbore, thereby exposing an end of the remaining production string. A lateral orientation device (LOD) is mounted on the exposed end of the production string. The LOD includes a shoulder for seating on the exposed end, anchoring mechanism(s) to secure the LOD to adjacent tubular(s), and seals to sealingly engage adjacent tubulars. The LOD may include a contoured surface for orientation of a tool, such as a whipstock, which may be utilized to drill a new wellbore. Alternatively, a work string may be coupled with the LOD to perform pumping operations in the wellbore below the LOD.

Abstract: A method to reduce fluid production in a well includes performing a production simulation of a reservoir model comprising a production tool with an inflow control device, and determining a parameter for the inflow control device to reduce fluid production through the inflow control device based upon the production simulation.

Abstract: To perform an aligned operation downhole, a tubular disposed downhole has an internal bore with a first inner circumference and has a target at a first radial orientation. A locator profile is defined about the internal bore at a first location, and an internal nipple is defined about the internal bore at a second location. The internal nipple has a second inner circumference less than the first of the internal bore. An orientation slot is defined longitudinally across the internal nipple and is disposed at a second radial orientation configured relative to the first radial orientation of the target. A tool is deployable into the internal bore. The tool has a locator to engage in the locator profile and has an orientation key to engage in the slot and align an operational component for the aligned operation with the target.

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 subsea wellhead assembly provides a positive indication of landing of a wellhead member and locking of a wellhead member to a wellhead. The subsea wellhead assembly includes at least one positive indicator assembly disposed within a wellhead member, and a communication line extending down a running string from a platform to a running tool disposed in a subsea wellhead. The at least one positive indicator assembly provides confirmation of setting of the wellhead member, and the communication line is in communication with the positive indicator assembly to communicate the confirmation of setting with the platform following setting of the wellhead member.

Abstract: A system for distributing pressurized fluid during wellbore operations can include a pressure vessel having a fluid inlet and a fluid outlet. The system can also include a conduit rotatably connected to the fluid outlet of the pressure vessel for coupling to one or more wellbores. Also, a method for distributing pressurized fluid during wellbore operations can include receiving pressurized fluid in a pressure vessel. The method can also include distributing to one or more wellbores the pressurized fluid from the pressure vessel through a conduit rotatably connected to the pressure vessel.

Abstract: Embodiments of systems and methods for advanced inflow control valve systems is provided. Multiple micro-computer integrated downhole inflow control valves can be configured as part of an inflow control valve control system. Inflow control valves of the described system can be configured to include a micro-computer system configured with a micro-computer circuit board comprising a processor, memory, nonvolatile memory, networking capability, wireless communications channels, and software. The software can include an operating system, a communications interface program, and a program for inflow control valve control and monitoring functions. In an embodiment, each inflow control valve can be assigned an internet IP address.

Abstract: The present invention relates to a downhole system for unloading a liquid of a well in an annulus between an intermediate casing and a production tubular metal structure.

Abstract: A method of completing or stimulating a portion of a wellbore comprising: introducing a treatment fluid into the wellbore, wherein the treatment fluid comprises a base fluid and an insoluble particulate, wherein the treatment fluid flows through a first tube or set of tubes of a multi-tube system during introduction, wherein the multi-tube system comprises multiple tubular members rigidly attached to each other along the axial lengths of the members, and wherein the attached tubular members complimentarily create a cross-sectional shape of a generally D- or wedge-shaped portion of a circle; possibly creating one or more fractures in a subterranean formation; depositing at least a portion of the particulate within the wellbore; and returning at least a portion of the base fluid to a wellhead of the wellbore, wherein the treatment fluid flows through a second tube or set of tubes of the multi-tube system during return.

Abstract: The present invention relates to a liquid evacuation device for an extraction well. The device comprises a tank presenting a liquid accumulation area. The tank is connected to a gas evacuation tubing. An insulant limits a flow of fluid between a wall of the tank and a wall of the well, from a first space formed between the insulant and the well bottom to a second space formed between the insulant and the well head. A first opening on the tank enables circulation of a gas-liquid mixture from said first space to a third space formed in the gas evacuation tubing. A second opening on the tank enables circulation of fluid from said second space to the liquid accumulation area. The first opening is made between the liquid accumulation area and the connection to the evacuation tubing.

Abstract: A well integrity monitoring system may include one or more sensing elements that are configured to generate feedback indicative of an integrity of a well. The one or more sensing elements may be disposed in at least one annulus of wellhead assembly. Additionally, the well integrity monitoring system may include a controller coupled to the wellhead assembly. The controller may be configured to wirelessly determine the feedback from the one or more sensing elements.

Abstract: A wellbore assembly including an actuation dart for actuating a target tool in tubing string. The dart is activatable downhole, such that it can be moved past tools similar to the target tool without actuating them. The target tool may include a release mechanism that releases the actuation dart after being actuate by it. Such a target tool may be useful with a second tool that retains the actuation dart against further movement down the tubing string.

Abstract: An apparatus includes a string that extends into a well and a tool that is disposed in the string. The tool is adapted to form a seat to catch an object communicated to the tool via a passageway of the string in response to the tool being perforated.

Abstract: A collapsible baffle sub installable within a casing string of a hydrocarbon well. The collapsible baffle sub includes a movable sleeve and a collapsible baffle. By moving the sleeve from a first to a second position using a setting tool, the collapsible baffle is permitted to collapse within the collapsible baffle sub. Once collapsed, the collapsible baffle may receive an untethered object, such as a ball, forming a seal between the untethered object and the collapsible baffle and isolating sections of the wellbore for treatment.

Abstract: A technique facilitates selection of optimum flow control valve settings to improve a desired objective function in a multizone well having zonal isolation. A network of flow control valves is provided in a completion network disposed along isolated well zones of at least one lateral bore of the multizone well. Data is acquired from downhole in the multizone well and processed on processor system modules which may be used in selected combinations. Examples of such modules comprise completion network modules, deconvolution modules, optimization modules, and/or inflow-outflow modules. The modules are designed to process the collected data in a manner which facilitates adjustment of the flow control valve settings in the network of flow control valves to improve the desired objective function.

Abstract: The present invention relates to a completion method for completing a uniform inner bore downhole completion system in a reservoir in a formation, comprising the steps of drilling a hole in the formation, inserting a surface casing having an inner surface casing diameter, cementing an outer face of the surface casing to the hole, inserting a drilling head in the surface casing, drilling a main bore extending from the surface casing, the main bore having a first part and a second part, the second part comprising an end of the main bore, and the main bore having an inner main bore diameter which is substantially the same as the inner surface casing diameter of the surface casing, retracting the drilling head from the main bore and the surface casing, inserting a lower production casing in the second part of the main bore, the lower production casing having annular barriers and an inner diameter, setting at least one of the annular barriers of the lower production casing, inserting the drilling head into the fir

Abstract: There is provided a plurality of injection stations, wherein each one of the injection stations, independently, comprising: a housing; a port extending through the housing; a flow control member configured for displacement for effecting at least opening of the port such that, when the injection station is integrated within a wellbore string that is disposed within a wellbore of a subterranean formation, and treatment fluid is being supplied through a wellbore string passage of the wellbore string, injection of the supplied treatment fluid into the subterranean formation is effected through the port; and a deployable seat, mounted to the housing, and including an aperture, and configured such that, when the seat is deployed in a deployed position, the seat is configured for receiving a respective plug for seating of the respective plug over the aperture of the seat; such that a plurality of plugs are respective to the injection stations, wherein each one of the plugs is respective to a deployable seat of a one