Abstract: A mobile fire protection system comprises a first radiation detector for detecting radiation emitted by a flame in a monitoring region. A container holds fire suppression agent, the container being in selective fluid flow communication via a passage with an outlet for discharging the fire suppression agent. A mobile support structure carries the container. A valve is selectively movable between a closed state, wherein the fire suppression agent remains captive within the container, and an open state, wherein flow of the fire suppression agent from the container towards the outlet is enabled. A controller is configured, responsive to the first radiation detector detecting radiation emitted by the flame in the monitoring region, to cause the valve to move to the open state to discharge the fire suppression agent via the passage and the outlet towards the flame.

Abstract: A mobile fire protection system comprises a first radiation detector for detecting radiation emitted by a flame in a monitoring region. A container holds fire suppression agent, the container being in selective fluid flow communication via a passage with an outlet for discharging the fire suppression agent. A mobile support structure carries the container. A valve is selectively movable between a closed state, wherein the fire suppression agent remains captive within the container, and an open state, wherein flow of the fire suppression agent from the container towards the outlet is enabled. A controller is configured, responsive to the first radiation detector detecting radiation emitted by the flame in the monitoring region, to cause the valve to move to the open state to discharge the fire suppression agent via the passage and the outlet towards the flame.

Abstract: A system for deploying and powering an electric submersible pump within a subterranean well. The system includes a tubing string having a wall forming a hollow interior, one end of the tubing string connected to the electric submersible pump; a flowable conductive material at least partially filling the hollow interior of the tubing string, the flowable conductive material forming a first conductive path; and a second conductive path, wherein the first conductive path and the second conductive path form a circuit for supplying power to the electric submersible pump. A method for deploying and powering an electric submersible pump within a subterranean well is also provided.

Abstract: Systems and methods for mitigating the effects of subsurface shunts during bulk heating of a subsurface formation are disclosed. The methods may include electrically connecting, and concurrently applying, first, second, and third alternating voltages to respective first, second, and third electrode assemblies within the subsurface formation. The first, second, and third alternating voltages may have the same frequency and respective first, second, and third phase angles. The second phase angle may be different than the first phase angle, and the third phase angle may be different than the second phase angle. The methods may include, upon determining a presence of a subsurface shunt between the first electrode assembly and the second electrode assembly, electrically connecting the first electrode assembly to the second alternating voltage and applying the second alternating voltage to the first and second electrode assemblies while applying the third alternating voltage to the third electrode assembly.

Abstract: A method of recovering hydrocarbons includes forming a first electrode by creating a first hydraulic fracture within the subsurface formation and pumping a first electrically conductive material into the first hydraulic fracture; forming a second electrode by creating a second hydraulic fracture within the subsurface formation and pumping a second electrically conductive material into the second hydraulic fracture; electrically connecting a first power transmitting mechanism to the first electrode; electrically connecting a second power transmitting mechanism to the second electrode; and heating the subsurface formation between the first electrode and the second electrode by transmitting an electrical current via the first power transmitting mechanism to the first electrode and via the second power transmitting mechanism to the second electrode and by flowing the electrical current from the first electrode to the second electrode.

Abstract: A system for deploying and powering an electric submersible pump within a subterranean well. The system includes a tubing string having a wall forming a hollow interior, one end of the tubing string connected to the electric submersible pump; a flowable conductive material at least partially filling the hollow interior of the tubing string, the flowable conductive material forming a first conductive path; and a second conductive path, wherein the first conductive path and the second conductive path form a circuit for supplying power to the electric submersible pump. A method for deploying and powering an electric submersible pump within a subterranean well is also provided.

Abstract: A system for deploying and powering an electric submersible pump within a subterranean well. The system includes a tubing string having a wall forming a first conductive path, one end of which is connected to the electric submersible pump; and a second conductive path, wherein the first conductive path and the second conductive path form a circuit for supplying power to the electric submersible pump. A method for deploying and powering an electric submersible pump within a subterranean well is also provided.

Abstract: Systems and methods for bulk heating of a subsurface formation with at least a pair of electrode assemblies in the subsurface formation are disclosed. The method may include electrically powering the pair of electrode assemblies to resistively heat a subsurface region between the pair of electrode assemblies with electrical current flowing through the subsurface region between the pair of electrode assemblies; flowing a shunt mitigator into at least one of the pair of electrode assemblies; and mitigating a subsurface shunt between the pair of electrode assemblies with the shunt mitigator. Mitigating may be responsive to a shunt indicator that indicates a presence of the subsurface shunt.

Abstract: A method of recovering hydrocarbons includes forming a first electrode by creating a first hydraulic fracture within the subsurface formation and pumping a first electrically conductive material into the first hydraulic fracture; forming a second electrode by creating a second hydraulic fracture within the subsurface formation and pumping a second electrically conductive material into the second hydraulic fracture; electrically connecting a first power transmitting mechanism to the first electrode; electrically connecting a second power transmitting mechanism to the second electrode; and heating the subsurface formation between the first electrode and the second electrode by transmitting an electrical current via the first power transmitting mechanism to the first electrode and via the second power transmitting mechanism to the second electrode and by flowing the electrical current from the first electrode to the second electrode.

Abstract: Systems and methods for mitigating the effects of subsurface shunts during bulk heating of a subsurface formation are disclosed. The methods may include electrically connecting, and concurrently applying, first, second, and third alternating voltages to respective first, second, and third electrode assemblies within the subsurface formation. The first, second, and third alternating voltages may have the same frequency and respective first, second, and third phase angles. The second phase angle may be different than the first phase angle, and the third phase angle may be different than the second phase angle. The methods may include, upon determining a presence of a subsurface shunt between the first electrode assembly and the second electrode assembly, electrically connecting the first electrode assembly to the second alternating voltage and applying the second alternating voltage to the first and second electrode assemblies while applying the third alternating voltage to the third electrode assembly.

Abstract: An in situ method of producing hydrocarbon fluids from an organic-rich rock formation may include heating an organic-rich rock formation, for example an oil shale formation, in situ to pyrolyze formation hydrocarbons, for example kerogen, to form a production fluid containing hydrocarbon fluids. The method may include separating the production fluid into at least a gas stream and a liquid stream, where the gas stream is a low BTU gas stream. The low BTU gas stream is then fed to a gas turbine where it is combusted and is used to generate electricity.

Abstract: A method of producing hydrocarbon fluids from a subsurface organic-rich rock formation, for example an oil shale formation, in which the oil shale formation contains water-soluble minerals, for example nahcolite, is provided. In one embodiment, the method includes the step of heating the organic-rich rock formation in situ. Optionally, this heating step may be performed prior to any substantial removal of water-soluble minerals from the organic-rich rock formation. In accordance with the method, the heating of the organic-rich rock formation both pyrolyzes at least a portion of the formation hydrocarbons, for example kerogen, to create hydrocarbon fluids, and converts at least a portion of the water-soluble minerals, for example, converts nahcolite to soda ash. Thereafter, the hydrocarbon fluids are produced from the formation.

Abstract: A method of producing hydrocarbon fluids from a subsurface organic-rich rock formation, for example an oil shale formation, in which the oil shale formation contains water-soluble minerals, for example nahcolite, is provided. In one embodiment, the method includes the step of heating the organic-rich rock formation in situ. Optionally, this heating step may be performed prior to any substantial removal of water-soluble minerals from the organic-rich rock formation. In accordance with the method, the heating of the organic-rich rock formation both pyrolyzes at least a portion of the formation hydrocarbons, for example kerogen, to create hydrocarbon fluids, and converts at least a portion of the water-soluble minerals, for example, converts nahcolite to soda ash. Thereafter, the hydrocarbon fluids are produced from the formation.

Abstract: A method for treating water at a water treatment facility is provided. In one aspect, the water has been circulated through a subsurface formation in a shale oil development area. The subsurface formation may comprise shale that has been spent due to pyrolysis of formation hydrocarbons. The method in one embodiment includes receiving the water at the water treatment facility, and treating the water at the water treatment facility in order to (i) substantially separate oil from the water, (ii) substantially remove organic materials from the water, (iii) substantially reduce hardness and alkalinity of the water, (iv) substantially remove dissolved inorganic solids from the water, and/or (v) substantially remove suspended solids from the water. The method may further includes delivering the water that has been treated at the water treatment facility re-injecting the treated water into the subsurface formation to continue leaching out contaminants from the spent shale.

Abstract: A method for spacing heater wells for an in situ conversion process includes the steps of determining a direction along which thermal energy will travel most efficiently through a subsurface formation, and completing a plurality of heater wells in the subsurface formation, with the heater wells being spaced farther apart in the determined direction than in a direction transverse to the determined direction. In one aspect, the step of determining a direction along which thermal energy will travel most efficiently is performed based upon a review of geological data pertaining to the subsurface formation. The geological data may comprise the direction of least horizontal principal stress in the subsurface formation. Alternatively, the geological data may comprise the direction of bedding in the subsurface formation, the tilt of the subsurface formation relative to the surface topography, the organic carbon content of the kerogen, the initial formation permeability, and other factors.

Abstract: A method for predicting petroleum production is provided. An exemplary embodiment of The computer-implemented comprises computing a first approximation of an amount of generated petroleum that is retained with a complex organic product using a Threshold and a Maximum Retention value. The exemplary method also comprises revising the first approximation by approximating a process of chemical fractionation using at least one partition factor to create a revised approximation and predicting petroleum production based on the revised approximation.

Abstract: A method and system for heating a subsurface formation using electrical resistance heating includes providing a wellbore which has a production portion that penetrates an interval of organic-rich rock within the subsurface formation. The method includes forming a fracture in the organic-rich rock along a plane that is generally parallel with the production portion of the wellbore. A first electrically conductive proppant is placed into the fracture. Second and third electrically conductive proppants are placed within the wellbore and in electrical communication with the first electrically conductive proppant. The second and third proppants are spaced apart, and have a bulk resistivity that is less than the bulk resistivity of the first proppant. The method then includes passing an electric current through the fracture such that heat is generated by electrical resistivity within the first proppant sufficient to pyrolyze at least a portion of the organic-rich rock into hydrocarbon fluids.

Abstract: A method of producing hydrocarbon fluids with improved hydrocarbon compound properties from a subsurface organic-rich rock formation, such as an oil shale formation, is provided. The method may include the step of heating the organic-rich rock formation in situ. In accordance with the method, the heating of the organic-rich rock formation may pyrolyze at least a portion of the formation hydrocarbons, for example kerogen, to create hydrocarbon fluids. Thereafter, the hydrocarbon fluids may be produced from the formation. Hydrocarbon fluids with improved hydrocarbon compound properties are also provided.

Abstract: A method for producing hydrocarbon fluids from an organic-rich rock formation to a surface facility is provided. The method may include heating the formation in situ to cause pyrolysis of formation hydrocarbons, and producing production fluids from the formation via two or more wells. The produced fluids have been at least partially generated as a result of pyrolysis of the formation hydrocarbons. In addition, the produced fluids comprise non-condensable fluids, or gases, which taken together have an averaged Wobbe Index which varies at a rate of more than 5% over a period of time. The method also includes controlling production from one or more of the wells such that a combination of the production fluids from the wells results in a combined gas stream that's averaged Wobbe Index varies at a rate of less than 5% over the period of time. The combined stream comprises combustible hydrocarbon fluids.

Abstract: A method for producing hydrocarbons from subsurface formations at different depths is first provided. In one aspect, the method includes the step of heating organic-rich rock, in situ, within a subsurface formation at a first depth. The result of the heating step is that at least a portion of the organic-rich rock is pyrolyzed into hydrocarbon fluids. Preferably, the organic-rich rock of the subsurface formation of the first depth is oil shale. The method also includes providing at least one substantially unheated zone within the formation of the first depth. In this way, the organic-rich rock in that zone is left substantially unpyrolyzed. The method further includes drilling at least one production well through the unheated zone, and completing the at least one production well in a subsurface formation at a second depth that is deeper than the first depth. Thereafter, hydrocarbon fluids are produced through the at least one production well.