Abstract: A method of drilling a wellbore includes drilling the wellbore through a formation by injecting drilling fluid through a drill string and rotating a drill bit. The drill string includes a shifting tool, a receiver in communication with the shifting tool, and the drill bit. The method further includes retrieving the drill string from the wellbore through a casing string until the shifting tool reaches an actuator. The casing string includes an isolation valve in an open position and the actuator. The method further includes sending a wireless instruction signal to the receiver. The shifting tool engages the actuator in response to the receiver receiving the instruction signal. The method further includes operating the actuator using the engaged shifting tool, thereby closing the isolation valve and isolating the formation from an upper portion of the wellbore.

Abstract: A tool bus spans multiple segments of a bottom hole assembly (BHA) is implemented as a transmission line with only a single electrical contact (SEC) across joints of adjacent segments. A common mode (CM) choke on the transmission line promotes return currents to pass through the transmission line as opposed to through parallel return paths and stabilizes the characteristic impedance on the transmission line. The tool bus uses a two-layer bus with a first layer that is used to communicate across segments and a second layer that is used to communicated among nodes within one segment. A primary node is used to link the primary bus and the secondary bus. A CM choke may be used at the connection between the primary node and the primary bus, at the connection between the primary node and the secondary bus, and/or at the connection between the secondary bus and a secondary node.

Abstract: The invention relates to the decommissioning of hydrocarbon wells. It concerns the artificial promoting or inducing of creep in the overburden formation 3 surrounding an oil well 1, so that the formation rock 3 encroaches against the casing 5 to form a seal. This avoids the need to plug the annulus between the casing 5 and formation 3 with cement. The overburden may be caused to creep by reducing the pressure in the annulus, by applying heat to the overburden rock or by stressing the rock repeatedly to cause fatigue in the rock 3.

Abstract: A method for enhancing production from multiple-fractured underground “tight” formations. Spaced upwardly-extending injection fissures are created along a horizontal injection wellbore, and upwardly-extending collection fissures, alternately spaced with the injection fissures, are created along the horizontal injection wellbore or another adjacent production wellbore. The injection wellbore is supplied with fluid under pressure, which flows into such created fissures and drives reservoir fluids within the formation to the remaining (alternately) spaced adjacent fissures along such wellbore or another parallel adjacent (production) wellbore, thereby allowing reservoir fluids to flow downwardly along such alternately spaced production fissures for collection.

Abstract: A downhole tool for creation of an annular seal in a well and a method of cementing a casing in a well, wherein tool and method make use of an expansion cone. The expansion cone is driven through a portion of the tool having a sealing element on the wellbore side so that the portion is expanded and the sealing element brought into contact with the wellbore. A force multiplier is used to increase the force exerted on the expansion cone by fluid pressure.

Abstract: A composition includes a continuous phase of water, alcohol, or a mixture of water and alcohol; hexagonal boron nitride nanoparticles dispersed in the continuous phase; and a compound having a formula (I) or a salt thereof, wherein n is an integer between 50 and 200 and y is an integer between 20 and 200.

Abstract: Example methods and systems are described for evaluating an effectiveness of ceramic particles to recover heavy oil from a subterranean region. In some aspects, a heavy oil recovery evaluation system includes a vessel containing a mixture of heavy oil and sand, the vessel including a chamber to receive a plurality of ceramic particles and water, a probe connected to the vessel to transfer energy from an energy source for energizing the plurality of ceramic particles, wherein the energized ceramic particles convert the water into steam to recover the heavy oil from the mixture, and a computer system connected to the vessel to evaluate an effectiveness of the plurality of ceramic particles to recover heavy oil from the mixture.

Abstract: The invention is a method for determining an amount of hydrogen sulfide produced by aquathermolysis induced by a thermal process, such as steam injection. The hydrocarbons are described with a compositional representation using H2S and the fractions saturated compounds, aromatics, resins and asphaltenes. A kinetic model is constructed based on the compositional representation using an elementary model obtained by mass balance for sulfur distributed within the fractions. A thermodynamic model is constructed based on the same compositional representation. The amount of produced H2S is determined by performing a compositional reservoir simulation using a compositional and reactive thermal simulator using the kinetic and thermodynamic models.

Abstract: Aspects of a flow balanced frac tank farm are described herein. In one embodiment, the flow balanced frac tank farm includes at least one battery of frac tanks comprising a plurality of frac tank trailers, a header pipe arrangement, and at least one valve between one or more of the frac tank trailers and the header system. The header pipe arrangement may include a header supply pipe to supply water to individual ones of the plurality of frac tank trailers and a header discharge pipe to discharge water from individual ones of the plurality of frac tank trailers. The header pipe arrangement may be relied upon to help balance the flow of heated fluids among the frac tank trailers in frac tank farm.

Abstract: A method for recovering hydrocarbons from an underground formation having a first exploited or partially exploited region and a second less exploited region in at least partial fluid communication with said first region. Electrical heating means is provided in the first region, and electrical energy supplied to the first region to raise or sustain its pressure to mitigate the loss of fluids and pressure from the second region due to hydraulic interaction with the first region. The electric heating affects the pressure by thermal expansion of the liquids and vapors present in or added to the first region and/or flashing of those liquids to vapors. The use of electric means is advantageous over the prior art by allowing for the redirection of injection fluids to more active regions of exploitation, and allows for more timely reclamation of the equipment and surface area above the first region.

Abstract: A reaction apparatus for providing reactants from a surface to a wellbore to create a generated gas when the reactants undergo a reaction in situ to affect the density of a fluid in the wellbore, the reaction apparatus comprises a reaction housing, the reaction housing comprises a first reactant cell configured to contain a first reactant, a second reactant cell configured to contain a second reactant, a mixing chamber, configured to allow the first reactant and the second reactant to mix, a first passage configured to allow the first reactant to pass from the first reactant cell to the mixing chamber, a second passage configured to allow the second reactant to pass from the second reactant cell to the mixing chamber, an outlet configured to allow the generated gas from the reaction to escape the mixing chamber, a line comprising a plurality of electric cables, and a reel.

Abstract: The present invention generally relates to an apparatus and method for expanding an anchoring device in a borehole. In one aspect, an anchoring device is provided. The anchoring device includes an expandable tubular. The anchoring device further includes a plurality of bands disposed on an outer surface of the expandable tubular. Each band is attached to the tubular at a first connection point and a second connection point, wherein each band is configured to bow radially outward as the expandable tubular shortens in length in response to the expansion of the tubular. In a further aspect, a method of attaching an anchoring device in a borehole is provided.

Abstract: A system for heating a hydrocarbon resource in a subterranean formation having a wellbore extending therein may include a radio frequency (RF) source, a choke fluid source, and an elongate RF antenna configured to be positioned within the wellbore and coupled to the RF source. The elongate RF antenna may have a proximal end and a distal end separated from the proximal end. The system may further include a first choke fluid dispenser coupled to the choke fluid source and positioned to selectively dispense choke fluid into adjacent portions of the subterranean formation at the proximal end of the RF antenna, and a second choke fluid dispenser coupled to the choke fluid source and positioned to selectively dispense choke fluid into adjacent portions of the subterranean formation at the distal end of the RF antenna.

Abstract: A system for heating a hydrocarbon resource in a subterranean formation having a wellbore extending therein may include a radio frequency (RF) source, a choke fluid source, and an elongate RF antenna configured to be positioned within the wellbore and coupled to the RF source, with the elongate RF antenna having a proximal end and a distal end separated from the proximal end. The system may also include a choke fluid dispenser coupled to the choke fluid source and positioned to selectively dispense choke fluid into adjacent portions of the subterranean formation at the proximal end of the RF antenna to define a common mode current choke at the proximal end of the RF antenna.

Abstract: Disclosed is a system and method for integrating power distribution for subsea boosting and direct electrical heating (DEH) of at least one subsea flowline. A subsea power cable located in a subsea environment is electrically connected to at least one power generator at a topsides location and delivers power to a subsea switchgear module which connects to subsea adjustable speed drives (ASD). At least one pump motor is electrically connected to at least one of the ASD, and at least one capacitor bank is electrically connected to at least one of the subsea ASD. A subsea pressure boosting pump is driven by the pump motor. At least one capacitor bank is electrically connected to at least one of the subsea ASD. At least one DEH is electrically connected to at least one of the subsea ASD in series with the at least one capacitor bank and in contact with the at least one subsea flowline. Power is distributed to the boosting and DEH equipment more efficiently and cost effectively.

Abstract: The invention provide a manufacturing method for producing conductive adhesive with spherical graphene, and the steps comprise as following: step 1: preparing monomer, initiator, a dispersing agent and solvent to manufacture a monomer compound, and use the monomer compound to produce polymer micro ball; step 2: heating pre-treatment or plasma etching pre-treatment to the said polymer micro ball; step 3: by chemical vapor deposition, the polymer micro ball after pre-treatment from step 2 to grow graphene outside surfaces or inside polymer micro ball, and then obtain the spherical graphene; step 4: producing epoxy gel system made by epoxy, hardener and accelerant with a certain ratio mixing homogeneously; step 5: dispersing the spherical graphene from step 3 into the epoxy gel system to produce pre-material of conductive adhesive of spherical graphene; Step 6: deforming the pre-material of conductive adhesive of spherical graphene, and then obtain conductive adhesive of spherical graphene.

Abstract: A method of fracking carbonate-rich reservoirs, comprising injecting a cryogenic or chilled fluid followed by an acid into the reservoir, allowing the acid to etch the reservoir, and thereby increasing production of a fluid, such as water, oil or gas, from the reservoir. Further, injecting a preflush into the reservoir and later injecting a postflush into the reservoir to displace the acid from the tubulars into the reservoir.

Abstract: A device to be deployed downhole. The device includes a member including a metallic foam and a sealing material coupled to the metallic foam. The member attains a compressed shape when compressed to restrict fluid flow between regions downhole. The sealing material may be in, on or coated on the metallic foam member.

Abstract: Systems and methods for positioning horizontal wells within a limited-pre-defined boundary. The systems and methods include an automated process for creating jointed target pairs or horizontal laterals to be utilized for planning horizontal wells in order to position the horizontal laterals within limited pre-defined boundary(ies).

Abstract: A control system for controlling the operation of a Downhole Steam Generator (DHSG) system includes a cascade control strategy for control of individual final control elements in communication with a local well master controller. The final control elements may control fuel, oxidant, feedwater, and/or carbon dioxide flow to the downhole steam generator. The local well master controller may monitor and adjust the flows to the DHSG to control the operating performance of the DHSG.

Abstract: Methods, systems, devices, and products for taking a downhole measurement are presented. The method may include cooling a sensor in a borehole intersecting an earth formation using an electrocaloric material associated with the sensor, wherein the sensor is responsive to a downhole parameter. The method may further include applying an electric field to the electrocaloric material to generate a giant electrocaloric effect. The method may include selecting dimensions, composition, and Curie temperature of the electrocaloric material and characteristics of the electric field sufficient to reduce the nominal temperature of the sensor by at least 20 degrees Celsius, which may result in the sensor being proximate to a target temperature within the nominal operational temperature range of the sensor.

Abstract: Methods and systems relate to the in-situ removal of heavy metals such as mercury, arsenic, etc., from produced fluids such as gases and crudes from a subterranean hydrocarbon-bearing formation. A sufficient amount of a fixing agent is injected into formation with a dilution fluid. The fixing agent reacts with the heavy metals forming precipitate, or is extracted heavy metals into the dilution fluid as soluble complexes. In one embodiment, the heavy metal precipitates remain in the formation. After the recovery of the produced fluid, the dilution fluid containing the heavy metal complexes is separated from the produced fluid, generating a treated produced fluid having a reduced concentration of heavy metals. In one embodiment, the dilution fluid is water, and the wastewater containing the heavy metal complexes after recovery can be recycled by injection into a reservoir.

Abstract: Operators manufacture a wellscreen by forming a wire-wrapped screen on a base pipe. Rather than stopping and restarting winding, the desired length of screen is completed along the base pipe, and then the wire screen is segmented into a plurality of screen sections as required for the various zones and details of the implementation. Operators arrange the screen sections relative to one another on the base pipe, which can have different lengths with and without perforations. On the free ends of these separate screen sections, mating split ring components fit around the free ends and the base pipes. Male edges of one split ring component mate to complementary female edges of another to form the end ring around the screen section and base pipe, and longitudinal welds made in seams along the mating edges affix the split ring components together.

Abstract: Disclosed is a chemical system of gas evolving oil viscosity diminishing compositions (GEOVDC) for stimulating the productive layer of an oil reservoir, that is to chemical compositions for a thermochemical treatment of an oil reservoir, more specifically for initiating a chemical reaction in the productive layer zone of the oil reservoir to produce heat and evolve gases so that the extraction of oil (petroleum) is improved. Further disclosed is a method of thermochemically treating an oil reservoir by means of this chemical system, and an apparatus for performing thermochemical treatment of an oil reservoir.

Abstract: An apparatus for cooling a downhole device is provided that in one embodiment includes a refrigerant having a saturation vapor pressure and stored in a chamber, an outlet configured to allow the refrigerant to discharge from the chamber and vaporize to cool the downhole device, and a force application device configured to apply pressure on the refrigerant in the chamber to maintain the refrigerant in the chamber at or above the saturation vapor pressure of the refrigerant. In another aspect, a method of cooling a device is provided that in one embodiment includes providing a chamber containing a refrigerant therein, the refrigerant having a saturation vapor pressure, discharging the refrigerant from the chamber to cause the refrigerant to evaporate to cause a cooling effect proximate the device to be cooled, and maintaining the refrigerant at or above the saturation vapor pressure of the refrigerant.

Abstract: A method for assembly of a well heater including injecting a length of coiled tubing into a well, supporting the coiled tubing in the well and cutting the coiled tubing above the well head; injecting one or more resistive heating cables into the into the coiled tubing; constructing a cable support structure at the cut end of the coiled tubing for supporting the weight of the cables against the inner sidewall of the coiled tubing; cutting the cables and configuring the cut ends of the cables for connection to an electrical source, thereby defining the structure of the well heater; and withdrawing the well heater from the well.

Abstract: The invention concerns a subsea system transporting fluid, wherein the subsea system comprises a first part having a flow path carrying a flow of fluid and at least a second part having a flow path provided for carrying fluid. The second part is temporarily being closed off from the flow path of the first part of the subsea system. The heat from the fluid transported in the first part of the subsea system is transferred to the second part by a heat conducting structure establishing a contact between the first and second part of the subsea system, to prevent the formation of hydrates in the second part of the subsea system.

Abstract: In a subsea system where subsea devices are operated using a pressurized fluid from one or more accumulators, the method of providing flow of pressurized fluid to operate a device which is greater than the flow from an accumulator providing the flow, comprising discharging the accumulator to drive one or more motors, driving one or more pumps by the one or more motors, the one or more pumps having a larger displacement than the one or more motors such that the one or more pump outputs a greater volume of fluid than the motor consumes, and delivering the output of the one or more pumps to operated the subsea device.

Abstract: Systems and methods for positioning horizontal wells within a limited-pre-defined boundary. The systems and methods include an automated process for creating jointed target pairs or horizontal laterals to be utilized for planning horizontal wells in order to position the horizontal laterals within limited pre-defined boundary(ies).

Abstract: Methods for heating a material within a wellbore using nano-particles such as carbon nano-tubes. The material may be a flowable material such as cement, drilling mud, an acidizing fluid, or other material. Generally the methods comprise placing the flowable material in proximity to a radial wall of a wellbore. The methods also include running an energy generator into the wellbore. In one aspect, energizing the nano-particles in the filter cake causes the nano-particles to be activated, and increases a temperature within the flowable material to a temperature that is greater than an initial circulation temperature of the flowable material. Activating the energy generator may also assist in curing the flowable material in situ.

Abstract: A method and system for initiating hydrocarbon production from a reservoir are provided. This method and system utilize thermosyphons. The system and method utilize one or more sealed, elongated, hollow tubular containers supported in earth in a geothermal heat zone below the reservoir and extending upwardly therefrom into the reservoir. The containers comprise (a) a bottom portion in the geothermal heat zone below the reservoir; (b) a top portion within the reservoir; and (c) being partially filled with a liquid that evaporates in the bottom portion forming a vapor and transferring heat via convective flow of the vapor to the top portion, the heat being dissipated at the top portion into the surrounding reservoir as the vapor condenses back into liquid and flows downward to the bottom portion. The reservoir can be a clathrate reservoir.

Abstract: A method for fracturing a downhole formation, includes: preparing an energized fracturing fluid including mixing gaseous natural gas and a fracturing base fluid in a mixer; injecting the energized fracturing fluid through a wellhead and into a well; and continuing to inject the energized fracturing fluid until the formation is fractured. An apparatus for generating an energized fracturing fluid for use to fracture a downhole formation, the apparatus includes: a fracturing base fluid source; a natural gas source; and a mixer for accepting natural gas from the natural gas source and fracturing base fluid from the fracturing base fluid source and mixing the natural gas and the fracturing base fluid to generate the energized fracturing fluid.

Abstract: Trace amount levels of non-volatile mercury in crude oil are reduced by contacting the crude oil with a water stream containing at least a monatomic water-soluble sulfur species such as sulfides and hydrosulfides. The non-volatile mercury is extracted into the water phase forming a mercury rich wastewater, yielding a treated crude oil having at less than 50% of the original non-volatile mercury level. The wastewater can disposed or recycled by injection into a reservoir. In one embodiment, the water stream consists essentially of produced water.

Abstract: Downhole tools for use in wellbores in subterranean formations comprise a body comprising at least one anomalous strengthening material. Methods of forming downhole tools for use in wellbores in subterranean formations comprise forming a body comprising at least one anomalous strengthening material. Methods of using downhole tools in wellbores in subterranean formations comprise disposing a body comprising at least one anomalous strengthening material in a wellbore in a subterranean formation. The at least one anomalous strengthening material may be exposed to a temperature within the wellbore higher than a temperature at a surface of the subterranean formation and a yield strength of the at least one anomalous strengthening material may increase.

Abstract: A release mechanism for use in setting a downhole tool comprises two connectors releasably connected to one other. One of the connectors includes a material having a coefficient of thermal expansion that is different from a material included in the second connector. The difference in the coefficients of thermal expansion causes one of the connectors to expand greater than the other connector when heat is applied to one or both of the connectors. As a result of the greater expansion of one of the connectors, the connectors release from each other. Upon release, an actuator within the downhole tool is permitted to move and cause actuation or setting of the downhole tool.

Abstract: A method of producing heated water from a reservoir having a hot bitumen-depleted zone adjacent to an aqueous mobile zone. The method includes generating fluid communication between the aqueous mobile zone and the hot bitumen-depleted zone. The method further includes driving water from the aqueous mobile zone through a portion of the hot bitumen-depleted zone to heat the water to produce heated water from a heated water production well.

Abstract: A method of extracting hydrocarbons from a subterranean formation comprises forming a suspension comprising reactive particles and a carrier fluid. The suspension is introduced into a subterranean formation containing a hydrocarbon material. At least a portion of the reactive particles are exothermically reacted with at least one other material within the subterranean formation to form a treated hydrocarbon material from the hydrocarbon material. The treated hydrocarbon material is extracted from the subterranean formation. An additional method of extracting hydrocarbons from a subterranean formation, and a method of treating a hydrocarbon material within a subterranean formation are also described.

Abstract: Described herein is a method of producing heated water from a hydrocarbon reservoir. The method includes injecting water into at least a portion of the hot bitumen-depleted zone to heat the water; and producing the heated water from a heated water production well. The method can includes generating the hot bitumen-depleted zone using steam-assisted gravity drainage, in situ combustion, steam flooding, cyclic steam stimulation, a solvent aided thermal recovery process, electric heating, electromagnetic heating, or any combination thereof.

Abstract: Method to enhance the recovery of oil from an oil field, comprising: applying heat to a colloidal hydrocarbonic medium that comprises hydrocarbon chains; and applying pressure waves having a predetermined frequency and intensity to hydrocarbon chains, in order to crack hydrocarbon chains into relatively shorter hydrocarbon chains. Optionally: applying heat may comprise applying steam; the pressure waves may be applied directly or indirectly to hydrocarbon chains to be cracked; applying pressure waves may be performed within the oil field, by use of an Activator within or outside of the oil field; applying pressure waves may be performed within the oil field; applying pressure waves may be performed by use of a rotor situated in a housing pervaded by the colloidal hydrocarbonic medium.

Abstract: Methods and systems for treating a subsurface hydrocarbon formation are described herein. A method for treating a subsurface hydrocarbon formation includes applying electrical current to a one or more heating elements positioned in a first tubular located in an opening in the subsurface hydrocarbon formation; providing fluid through a second tubular positioned in the first tubular in the subsurface hydrocarbon formation such that a portion of the fluid flows between the first tubular and second tubular and along a length of the tubulars; allowing the fluid to flow into a hydrocarbon layer in the subsurface hydrocarbon formation; and allowing heat to transfer from at least one of the heating elements and the fluid to a portion of the hydrocarbon layer in the subsurface hydrocarbon formation.

Abstract: Systems and methods used in treating a subsurface formation are described herein. Some embodiments also generally relate to barriers and/or methods to seal barriers. A method used to treat a subsurface formation may include heating a portion of a formation adjacent to a plurality of wellbores to raise a temperature of the formation adjacent to the wellbores above a mobilization temperature of bitumen and below a pyrolysis temperature of hydrocarbons in the formation; and allowing the bitumen to move outwards from the wellbores towards a portion of the formation comprising water cooler than the mobilization temperature of the bitumen so that the bitumen solidifies in the formation to form a barrier.

Abstract: A device for heating hydrocarbon resources in a subterranean formation having a wellbore therein may include a tubular radio frequency (RF) antenna within the wellbore and a tool slidably positioned within the tubular RF antenna. The tool may include an RF transmission line and at least one RF contact coupled to a distal end of the RF transmission line and biased in contact with the tubular RF antenna. The tool may also include a dielectric grease injector configured to inject dielectric grease around the at least one RF contact.

Abstract: A device for heating hydrocarbon resources in a subterranean formation having a wellbore therein may include a tubular radio frequency (RF) antenna within the wellbore, and a tool slidably positioned within the tubular RF antenna. The tool may include an RF transmission line and at least one RF contact coupled to a distal end of the RF transmission line and biased in contact with the tubular RF antenna. The tool may also include an anchoring device configured to selectively anchor the RF transmission line and the at least one RF contact within the tubular RF antenna.

Abstract: A device for heating hydrocarbon resources in a subterranean formation having a wellbore therein may include a tubular radio frequency (RF) antenna within the wellbore and a tool slidably positioned within said tubular RF antenna. The tool may include an RF transmission line and at least one RF contact coupled to a distal end of said RF transmission line and biased in contact with said tubular RF antenna. The tool may also include a guide member extending longitudinally outwardly from the distal end of said RF transmission line.

Abstract: In one aspect, a method of extracting heat from a downhole device is disclosed, which method, in one non-limiting embodiment, may include: providing a heat exchange fluid that includes a base fluid and core-shell nanoparticles therein; circulating the heat exchange fluid in the downhole device proximate to a heat-generating element of the downhole to cause the core of the core-shell nanoparticles to melt to extract heat from the downhole device and then enabling the heat exchange fluid to cool down to cause the core of the core shell nanoparticles to solidify for recirculation of the heat exchange fluid proximate to the heat-generating element.

Abstract: A dual-purpose tool can be used for steam injection and production in a wellbore. A mandrel deploys in the wellbore to communicate steam in a steam injection operation and to communicate production fluid from the wellbore during production operations. A distributor on the mandrel has nozzles for injecting steam into the wellbore and has production valves for producing fluids from the wellbore. A screen can be used to screen production fluids as they are produced through the production valves. The nozzles can also allows produced fluids to flow into the mandrel, or backflow valves can be used to restrict flow of produced fluids through the nozzles while permitting the flow of steam out of the nozzles.

Abstract: A method for pyrolyzing organic matter in a subterranean formation includes powering a first generation in situ resistive heating element within an aggregate electrically conductive zone at least partially in a first region of the subterranean formation by transmitting an electrical current between a first electrode pair in electrical contact with the first generation in situ resistive heating element to pyrolyze a second region of the subterranean formation, adjacent the first region, to expand the aggregate electrically conductive zone into the second region, wherein the expanding creates a second generation in situ resistive heating element within the second region and powering the second generation in situ resistive heating element by transmitting an electrical current between a second electrode pair in electrical contact with the second generation in situ resistive heating element to generate heat with the second generation in situ resistive heating element within the second region.

Abstract: A method of downhole steam generation comprising determining a desired level of electrical conductivity for water to be converted to steam in a downhole location, acquiring a main feedwater supply, wherein water of the main feedwater supply has an electrical conductivity lower or higher than the desired level, mixing water of the main feedwater supply with water from one or more sidestreams to generate a resultant stream with an electrical conductivity of about the desired level, pumping the resultant stream to the downhole location, and passing an electrical current through the resultant stream in the downhole location to generate steam.

Abstract: Systems and methods for controlling in situ resistive heating elements may be utilized to enhance hydrocarbon production within a subterranean formation. An in situ resistive heating element may be controlled by heating a controlled region associated with the in situ resistive heating element, injecting a control gas into the controlled region, and adjusting the electrical conductivity of the controlled region with the control gas. The controlled region may be located such that the heating and injecting may change the shape of the in situ resistive heating element and/or guide the in situ resistive heating element towards subterranean regions of potentially higher productivity and/or of higher organic matter.

Abstract: A heater includes a conduit and three insulated electrical conductors located in the conduit. At least one of the three insulated conductors includes an electrical conductor at least partially surrounded by an insulation layer and an electrically conductive sheath at least partially surrounding the insulation layer. One or more layers of electrical insulation at least partially surround the three insulated electrical conductors in the conduit. The one or more layers of electrical insulation electrically isolate the insulated electrical conductors from the conduit.