Abstract: The present invention provides a method of repairing one or more fractures in a wellbore cement by an electric field to move micelles from crude oil to the area to be repaired.

Abstract: Particulate additives that may be useful in mitigating fluid loss and/or as bridging agents or diverting agents in subterranean treatment fluids such as drilling fluids. In some embodiments, the particulate additives include a polymeric material and calcium carbonate disposed on at least a portion of the outer surface of the polymer core wherein the particulates have a particle size (d50) of from about 2 ?m to about 1600 ?m in diameter. In some embodiments, the methods include providing a treatment fluid that includes the base fluid and the particulate additives and introducing the treatment fluid into at least a portion of a subterranean formation.

Abstract: Halite scales in an oilfield brine that has a potential for halite scaling can have halite scale formation inhibited or prevented by adding an effective amount of an additive, where the additive contains at least one non-water-soluble quaternary ammonium compound and at least one organic solvent. The quaternary ammonium compound may be benzyl-alkyldimethyl ammonium chloride, where the alkyl group has from 2 to 30 carbon atoms. The organic solvent may be one or more alcohol or glycol.

Abstract: The thickness of subsurface layers if they had remained as they were prior to compaction may be estimated by restoring the volume of void space lost during compaction. Decompacted depths below seafloor, the depths the layers would be if compaction had not occurred, may be determined for the layers. A surrogate decompaction velocity may then be determined by dividing the decompacted depths by the travel times of acoustic waves that reflect off layers within the subsurface region. The decompaction velocity may be used in post-processing of acoustic data to produce a decompacted digital representation of the subsurface region. The decompacted digital representation may be used to directly interpret the thickness of layers prior to compaction, sedimentation rates over time, fault offsets, and other phenomena distorted by compaction.

Abstract: A downhole pumping system includes a downhole pump that includes a motor and is configured to circulate a downhole fluid from a subterranean reservoir to a terranean surface; a production tubing string positioned in the wellbore from the terranean surface to the subterranean reservoir and fluidly coupled to the downhole pump; a wellbore seal positioned in the wellbore and configured to fluidly isolate a first portion of an annulus that is uphole of the downhole pump from a second portion of the annulus in which the downhole pump is positionable; and a pump power cable electrically connected to the motor and to a power source cable in the first portion of the annulus with a power connector, where each of the pump power cable and the power source cable includes a metal jacket that encapsulates the respective cable.

Abstract: Provided is an invert emulsion oil-based drilling fluid composition that may include an invert emulsion of an oil phase and an aqueous phase. The oil phase may include an oleaginous fluid. The composition may include a low-end rheology modifier that is a C-36 dimer diamine dihydrochloride salt. Further provided is a method that may include introducing the invert emulsion oil-based drilling fluid composition into a wellbore.

Abstract: A method and a system for recovering oil from currently inaccessible oil containing geological units by activating the deep biosphere microbial seed bank. Nutrient and thermal enhancement of microorganisms in oil containing geological units allows for stimulation of inactive and/or dormant microorganisms such that they proliferate and produce gas. The oil viscosity that is decreased by heat, along with the gas pressure produced by activated microbes which allows previously inaccessible oil to flow toward production wells.

Abstract: The present disclosure relates to biocide compositions, formulations and methods for using formulations. In particular the present disclosure relates to biocide compositions and their use in effecting biocidal activity in subterranean oil and gas wells being drilled, completed, worked over or produced.

Abstract: A ternary water control and gas recovery method suitable for an unconsolidated siltstone gas reservoir is provided. It includes the following steps: first, running a silt control screen pipe manufactured by an interface hydrophobic modification into a wellbore to realize wellbore water control and silt control; second, filling a surface hydrophobic modified gravel in an annular space between the silt control screen pipe and the wellbore to form a hydrophobic gravel packing layer for water control and silt control; third, injecting a wetting agent aqueous solution into a stratum, and performing a hydrophobic modification on a gas reservoir seepage channel surface to realize in-situ waterblocking and silt migration of the unconsolidated siltstone gas reservoir, and then closing a well for a preset time before exploitation.

Abstract: A method for providing a well injection program in which an evaluation of plugging of the sandface over time is included to more accurately determine the water treatment facility specifications and well injection parameters for a produced water re-injection well. An artificial produced water is provided which includes both water wet solids and oil wet solids being representative of the treated produced water to be injected, at solids and oil content concentrations magnitudes of order greater than the treated produced water. This allows filtration testing on small injected volumes suitable for standard laboratory equipment. The areal spurt loss and Carter's Leak-Off coefficient are then determinable for use in evaluating the plugging of the sandface over time.

Abstract: A process for generating power from a warm saline steam (1) obtained from geothermal sources. The process involves converting latent osmotic energy present in the stream (1) into an increase in the total pressure of said stream by passing through an osmotic pump unit (7). The stream is passed over a semi-permeable membrane (8) and a lower salinity steam (14) is passed over the other side of said membrane (8), such that the need for mechanical pumping in subsequent process steps is reduced.

Abstract: An earth-boring rotary tool includes a body comprising a pin, a roller cone mounted on the pin, and a seal assembly disposed between the pin and the roller cone. The seal assembly includes a seal ring to form a seal between the seal ring and the roller cone. The seal assembly includes a first polymer ring, while compressed, applies a first force on the seal ring that biases the seal ring towards the roller cone. The seal assembly includes a second polymer ring proximate the first polymer ring. The second polymer ring, while compressed, applies a second force on the seal ring to further bias the seal ring towards the roller cone. The second force is greater than the first force.

Abstract: A water treatment system that removes calcium and magnesium using coagulants and pH controls, aqueous phase organic materials from water using a biological removal system that includes microorganisms and a physical separation system that includes sparging equipment for sparging the water to remove non-aqueous phase liquid organic materials, volatile phase organic materials. An apparatus, system and method for pretreating oilfield produced water to completely remove or significantly reduce concentrations of substances that are known to interfere with downstream recovery of metals including lithium. This technology facilitates a more efficient and cost-effective extraction method from alternate sources to meet the increasing global demand.

Abstract: Produced water from a crude oil or natural gas production process is purified using a membrane purification system for petroleum production, agricultural, commercial and domestic uses. The produced water is pretreated to remove, at least, particulates and oil from the produced water. The minimally pretreated water is then purified in a membrane purification system, that is operated at conditions such that membrane scaling is reduced or prevented. In particular, the membrane purification system is operated to maintain the turbidity of clarified water feed to the system or intermediate aqueous streams that are cascading through the membrane purification system. Ensuring that the turbidity of the reject streams generated in the membrane system are useful in achieving long membrane operating life.

Abstract: A method and apparatus for extracting and providing heavy crude oil from subterranean oil fields. The method utilizes a specially designed mixing mandrel to facilitate the combination and mixing of a high AP gravity diluent with heavy crude oil from a subterranean oil reservoir, such that the resulting heavy oil mixture can be efficiently pumped to the surface.

Abstract: A method of conditioning source water is comprised of: (a) acidifying source water by aluminum or iron chloride to prevent carboxylate from forming scale and emulsion and/or convert bicarbonate to carbon dioxide, and separating oil and/or carbon dioxide by hydrophobic membranes to produce a de-oiled and/or de-carbonated source water; (b) adding a hydrated lime or a hydrated lime with an amine solvent to separate magnesium hardness in the form of brucite and sulfate in the form calcium sulfoaluminate or calcium sulfoferrate to produce a de-brucited and de-sulfated source water; (c) if desired, reacting the excess amounts of the hydrated lime or the hydrated lime and amine solvent within the de-brucited and de-sulfated source water with carbon dioxide from step (a) to separate at least most of calcium hardness and produce a de-calcited source water; and (d) de-oxygenating the treated source water in step (b) or (c) by hydrophobic membranes.

Abstract: A method for treating liquid effluents and recovering metals is described, which comprises the steps of: a) liquid effluent equalization; b) sulphide addition and precipitation of metals in the form of metal sulphides; c) solid/liquid separation of the metal sulphides produced in step (b) and formation of a metal-free liquid phase; d) addition of a 50 to 250 g/L amine solution to the liquid phase precipitating magnesium in the form of magnesium hydroxide (Mg(OH)2); and e) recovery of amine by stripping and rectification.

Abstract: An isolation tool and related methods for protecting a wellhead to which a casing string is operably coupled. In an exemplary embodiment, the isolation tool includes an anchor assembly adapted to be connected to the wellhead; a mandrel adapted to sealingly engage an interior portion of at least one of the wellhead and the casing string; and a lock assembly including a mandrel head connected to the mandrel and adapted to be displaced, relative to the anchor assembly and the wellhead, to sealingly engage the mandrel with the interior portion; a landing sleeve connected to the mandrel head and adapted to be displaced, relative to the mandrel head, the mandrel, the anchor assembly, and the wellhead, to engage the anchor assembly; and a connector adapted to secure the landing sleeve to the anchor assembly when the mandrel sealingly engages the interior portion and the landing sleeve engages the anchor assembly.

Abstract: A material to be used for hydraulic fracturing, comprising argon maintained as a supercritical fluid, and a proppant. The material may also include any one of a variety of gels, foaming agents, and/or gases. The material may be used in a system to recover resources from bedrock, the system comprising the fracturing material, at least one mixer, a pump to inject the material into a bore well, and a recovery unit to recover the resource from the well. The material and system may be used in a variety of methods for extracting resources from bedrock, the method including mixing the proppant with the supercritical argon to form a mixture, pumping the mixture into a bore well, and recovering the resource from the bore well. Additionally, the material and bore well may comprise a structure used in the extraction of resources from bedrock.

Abstract: Disclosed herein are methods for isolating heavy saturated hydrocarbons from a subsurface shale formation comprising kerogen and an extractible organics component. These methods can be used to provide a bright stock product. The process comprises extracting an extractible organics component from subsurface shale formations comprising kerogen and the extractible organics component in an inorganic matrix and isolating a heavy hydrocarbon fraction comprising saturated beta-carotene. The methods utilize a hydrocarbon solvent to at least partially solubilize the extractible organics component. Among other factors, these processes are based on the discovery that the extractible organics is composed of a heavy hydrocarbon component containing saturated beta-carotene. The saturated beta-carotene product is a valuable commercial product. The presently disclosed processes are more environmentally benign, more economical, and more efficient in producing commercial products and in providing access to kerogen.

Abstract: A multistage process for producing mineral oil from mineral oil deposits by injecting aqueous flooding media into a mineral oil formation through injection boreholes and withdrawing the mineral oil through production boreholes, in which the mineral oil yield is increased by the use of microorganisms in combination with measures for blocking highly permeable zones of the mineral oil formation.

Abstract: The invention provides formulations for facilitating the removal of oil from a surface using a chisel composition, wherein the chisel composition includes a polymer having one or more binding points with a high affinity for the surface, and one or more hydrophilic segments that form a hydrophilic coating on the surface, rendering the surface water-wet and thereby facilitating the removal of oil from the surface. The invention also provides for methods of use of such formulations.

Abstract: This invention presents innovative methods to treat saline streams such as produced water, seawater, and the like. The invention can be used to: (1) de-NORM produced water; or (2) de-NORM and partially de-salt produced water; or (3) de-NORM and partially de-salt and de-ionize produced water; or (4) de-oil, de-NORM, de-salt and de-ionize produced water. The invention can also be used to de-sulfate seawater and the like in conjunction with desalting plants.

Abstract: Inhibiting gas hydrate formation while transporting hydrocarbon fluids may include providing a kinetic gas hydrate inhibitor, adding the kinetic gas hydrate inhibitor to a fluid capable of producing gas hydrates, and transporting the fluid that comprises the kinetic gas hydrate inhibitor. Generally a kinetic gas hydrate inhibitor may include a heterocyclic compound comprising nitrogen, e.g., poly(vinyl pyrrolidone).

Abstract: New classes of temporary and/or permanent clay stabilization compositions including at least one quaternary salt of polyamines or a reaction product of at least one polyamine having an NH moiety with an aldehyde, and to methods for making and using same, where the quaternary salts of polyamines have reduced toxicity.

Abstract: A process for producing mineral oil from mineral oil deposits by injecting aqueous flooding media into a mineral oil formation through injection boreholes and withdrawing the mineral oil through production boreholes, wherein the process comprises several cycles of process steps in which oil-mobilizing microorganisms and flooding water are injected alternately into the deposit. Processes in which highly permeable regions of the mineral oil formation are additionally blocked.

Abstract: A method of increasing biogenic production of a combustible gas from a subterranean geologic formation is described. The method may include extracting formation water from the geologic formation, where the extracted formation water includes at least a first species and a second species of microorganism. The method may also include analyzing the extracted formation water to identify the first species of microorganism that promotes the biogenic production of the combustible gas. An amendment may be introduced to the formation water to promote the growth of the first species of microorganism, and the biological characteristics of the formation water may be altered to decrease a population of the second species in the geologic formation.

Abstract: A method includes introducing a treatment fluid including a first polymer gel into a subterranean formation to generate a production fluid having an aqueous portion and a hydrocarbon portion, treating the aqueous portion of the production fluid with chlorine dioxide to separate additional hydrocarbons from the aqueous portion, and adjusting the viscosity of the treated aqueous portion prior to introducing the treated aqueous portion back into the subterranean formation.

Abstract: A gas hydrate is produced by injecting guest molecules into voids in a layer of which temperature and pressure condition allows the guest molecules to cause to form hydrate, in a form of emulsion where liquid of the guest molecules is dispersed in water as minute particles having a size of less than a size of voids, and thereby dispersing the guest molecules uniformly into the voids in the layer.

Abstract: Recovering oil and gas from subterranean oil and gas reservoirs using gas injection can serve an additional purpose of capturing and sequestering carbon dioxide. This can be accomplished where the feed gas for the gas injection is, at least in part, carbon dioxide from a carbon dioxide capture and sequestration process. Corrosion of steel in a gas transportation system due to the presence of carbon dioxide and water and oxygen may be prevented or at least mitigated by employing a corrosion inhibitor effective at preventing or mitigating steel corrosion in the presence of oxygen and carbon dioxide. The corrosion inhibitors may incorporate alkyl succinic acids, alkyl succinic anhydrides, and trimer acids.

Abstract: A process for the production of hydrogen in a subterranean hydrocarbon reservoir, is provided. The process may comprise the steps of introducing a metal-based catalyst into a hydrocarbon-containing zone in said reservoir, raising the temperature in said zone to a temperature at which catalyzed conversion of hydrocarbon to hydrogen occurs, and, optionally but preferably, recovering hydrogen from an extraction section of a production well located above said zone.

Abstract: An environment is moderated against microbial buildup, and especially bacterial buildup in an area where residual liquid wastes are collected or retained or added into natural ground formations. Water wastes are created, collected in storage areas or retained in natural land formations after the use of fluids to extract hydrocarbons contained in oil sand or oil shale or other hydrocarbon rich formations. The residual water wastes are of the type that generate or provide or promote in or above the fluid at least one waste selected from the group consisting of bacteria, carbon dioxide, hydrogen sulfide, ammonia, mercaptans and organic acids. A combination is provided of at least one of i) a friction reducing polymer for oil extraction and/or a polymer capable of absorbing at least ten times its weight in water (preferably a super-absorbing polymer) and ii) a combination of salts that react to liberate I2.

Abstract: A process for mineral oil production, in which an aqueous formulation comprising at least one water-soluble, hydrophobically associating copolymer (A) and at least one nonionic and/or anionic surfactant (B) is injected through at least one injection borehole into a mineral oil deposit, and crude oil is withdrawn from the deposit through at least one production borehole, wherein the water-soluble, hydrophobically associating copolymer comprises at least acrylamide or derivatives thereof, a monomer having anionic groups and a monomer which can bring about the association of the copolymer, and aqueous formulation, which is suitable for execution of the process.

Abstract: A post cold heavy oil production with sand (“CHOPS”) microbial enhanced oil recovery method comprises selecting a well having at least one wormhole and that has completed primary CHOPS production. When the reservoir does not contain enough of a gas producing indigenous microbe, an injectant is prepared comprising a gas-producing microbe, a nutrient suitable for the microbe, and a fluid base. The injectant is injected through the well and into the at least one wormhole in the reservoir; the well is shut in until pressure in the well reaches the target pressure; and then the well is produced.

Abstract: A method of foaming a fluid for recovering gas from a gas well and enhancing oil production from a gas-lifted oil well penetrating a subterranean oil-bearing formation is disclosed and claimed. The method includes introducing into the fluid a foam-forming amount of a composition comprising at least one compound having the general formula: R1 is selected from a saturated linear or branched alkyl, an unsaturated linear or branched alkyl, a substituted naphthalene, a substituted benzene, a natural oil, and a natural oil derivative. R2 is a C2-C8 alkyl. R3, R4, and R5 are independently selected from trimethyl, triethyl, diethyl, monoethyl, benzyl dimethyl, and benzyl diethyl. X is selected from hydrogen, methyl, and ethyl. Z? is a negatively charged counterion.

Abstract: A remediation process that a employs improved quantitative method(s) of estimating of the volume and/or mass of contaminant in the subsurface, removal and or in situ degradation of the contamination using subsurface pulsing treatment (“SPT”) technology, and evaluation of the degree of remediation by re-applying the quantitative contaminant evaluation methods. The process uses SPT technology with the addition of a vacuum or sub-atmospheric pressure to an extraction well in order to create a push-pull effect to remove free contaminant or residual in conjunction with the pressure wave driving force created in the excitation or excitation well. The process can quantitatively measure the amount of residual contaminant, which up until now has not been possible or tractable using in situ methods, as well as measure the amount of residual that can be removed by SPT.

Abstract: A process for utilizing microwaves to heat H2O within a subterranean region wherein the heated H2O contacts heavy oil in the subterranean region to lower the viscosity of the heavy oil and improve production of the heavy oil.

Abstract: Method of improving performance or efficiency of a wellbore pump associated with a wellbore and/or for increasing the rate of production of reservoir fluid from a reservoir, in which a wellbore pump is arranged to pump wellbore fluid within the wellbore to a surface. The method includes (a) selecting a wellbore which includes an associated wellbore pump associated with a production tube and arranged within a casing. An annulus is defined between the casing and the pump/production tube, the annulus including reservoir fluid which has a hydrostatic head which is at least 15 m above the level of an inlet of the wellbore pump, and (b) contacting a reservoir fluid in the annulus upstream of an inlet of the wellbore pump with a treatment formulation. The treatment formulation has a first polymeric material which includes —O— moieties pendent from a polymeric backbone thereof, and the first polymeric material is optionally cross-linked.

Abstract: The uncontrolled flow of fluid from an oil or gas well may be reduced or stopped by injecting a composition including 2-cyanoacrylate ester monomer into the fluid stream. Injection of the monomer results in a rapid, perhaps instantaneous, polymerization of the monomer within the flow stream of the fluid. This polymerization results in formation of a solid plug that reduces or stops the flow of additional fluid from the well.

Abstract: A method of storing CO2 in a porous and permeable hydrocarbon reservoir having at least one injection well and at least one production well penetrating the reservoir, by recovering a produced fluid stream including produced hydrocarbons, produced water, and produced CO2 from the production well; passing the produced fluid stream to a production facility where a produced vapor stream of carbon dioxide and volatile hydrocarbons is separated from the produced fluid stream; compressing the produced vapor stream to above the cricondenbar for the produced vapor stream; cooling the compressed stream to form a cooled stream that in a dense phase state; importing a CO2 stream to an injection facility wherein the imported CO2 is either in a liquid state or a supercritical state; mixing the cooled stream with the imported CO2 stream thereby forming a co-injection stream; and injecting the co-injection stream into the hydrocarbon bearing reservoir from said injection well.

Abstract: Viscoelastic surfactant (VES) gelled aqueous fluids containing water, a VES in an amount effective to increase the viscosity of the water, and an internal breaker may be useful in removing a residual polymer from a hydraulic fracture. Optionally, a pseudo-crosslinker may be present to further improve the properties related to treatment fluid placement and polymer clean-up. A plurality of aliquots of VES gelled fluid may be injected into a subterranean formation. A stop-start interval may exist between the injection of each aliquot. The VES gelled fluid may contact at least some of the residual polymer in the hydraulic fracture, and a broken fluid is formed once the viscosity of the VES gelled fluid is reduced with the internal breaker. At least a portion of the residual polymer and a majority of the broken fluid may be removed.

Abstract: The invention relates to a process for mineral oil extraction by means of Winsor Type III microemulsion flooding, in which an aqueous surfactant formulation comprising at least one ionic surfactant of the general formula R1—O-(D)n-(B)m-(A)l-XY?M+ is injected through injection boreholes into a mineral oil deposit, and crude oil is withdrawn from the deposit through production boreholes. The invention further relates to ionic surfactants of the general formula.

Abstract: The invention relates to a method for extracting methane from methane hydrates, comprising the following steps: feeding carbon dioxide to the methane hydrate deposits; allowing the carbon dioxide to take effect on the methane hydrate to release methane and store the carbon dioxide as carbon dioxide hydrate; and removing the released methane, characterized in that the fed carbon dioxide is supercritical carbon dioxide.

Abstract: The invention relates to methods and compositions for producing or recovering an aqueous-based fluid to be utilized or injected in a wellbore or surrounding subterranean formation. The method comprises the step of contacting an aqueous-based fluid with an aqueous-soluble breaker composition comprising an oxidizing agent and a catalyst for a time sufficient to reduce or eliminate one or more deleterious substances in the aqueous-based fluid to produce a treated aqueous-based fluid suitable for use or injection in a wellbore or surrounding subterranean formation.

Abstract: A method and apparatus for hydrocarbon recovery and/or treatment of frac water includes introducing a volume of water into a formation, recovering the introduced water, with the recovered introduced water further comprising suspended hydrocarbon product. The recovered liquid is treated to remove substantial amounts of the suspended hydrocarbon product, provide the treated recovered liquid with a ORP in a range of 150 mv to 1000 mv, and partially desalinated, and is either re-introduced as treated recovered liquid with the ORP into a formation to assist in recovery of additional hydrocarbon deposits in the formation, or is stored to reduce the ORP and then subsequently discharged into surface waters.

Abstract: A technique facilitates monitoring of conditions which are prone to cause scale precipitation around downhole equipment. The technique also enables a local, downhole reaction to the potential for precipitation of scale. A downhole scale monitoring and inhibition system may be provided with a measurement module and injection module. The measurement module monitors at least one downhole parameter indicative of the potential for scale formation. In response to data output from the measurement module, the injection module is operated to provide downhole, local injections of an inhibitor chemical.

Abstract: The present invention is directed to a method and system for treating a well having a wellbore extending from a ground surface or subsea surface downhole to an oil producing formation. Oil producing formations are capable of generating formation fluids into a wellbore. Formation fluids are comprised of at least an oil fraction and an aqueous fraction. Emulsions may form during oil production, and such emulsions may be comprised of oil and water. Inhibitor compositions may be employed to break such emulsions.

Abstract: A method for enhanced oil recovery contacts a gas and an alkylene carbonate with a subterranean formation. The gas may be selected from any gas that is suitable for injection into a subterranean formation and has properties that allow for enhanced recovery of petroleum from a subterranean formation. The alkylene carbonate may be cyclic, straight chained, or combinations thereof.

Abstract: A process for recovering oil from an oil-bearing formation comprises introducing into said formation an aqueous composition comprising at least one sulfonated derivative of one or more internal olefins, said internal olefins being characterized by having low amounts of tri-substitution on the olefin bond, said sulfonated derivative being obtained by sulfonating a composition comprising internal olefins of the formula: R1R2C?CR3R4 wherein R1, R2, R3 and R4 are the same or different and are hydrogen or straight- or branched-chain, saturated hydrocarbyl groups and the total number of carbon atoms of R1, R2, R3 and R4 is 6 to 44 with the proviso that at least about 96 mole percent of R1 and R3 are straight- or branched-chain, saturated hydrocarbyl groups and at least about 96 mole percent of R2 and R4 are hydrogen.

Abstract: Embodiments include methods for recovering petroleum products from a formation containing heavy crude oil. In one embodiment, a method includes positioning a steam generator within the petroleum-bearing formation, flowing a fuel source and an oxidizing agent into the steam generator, generating and releasing steam from the steam generator to heat the heavy crude oil, flowing a catalytic material containing a nanocatalyst into the petroleum-bearing formation, and exposing the catalytic material to the heavy crude oil. The method further provides forming lighter oil products from the heavy crude oil within the petroleum-bearing formation and extracting the lighter oil products from the petroleum-bearing formation. In some examples, the fuel source contains methane, syngas, or hydrogen gas, and the oxidizing agent contains oxygen gas, air, or oxygen enriched air. The nanocatalyst may contain cobalt, iron, nickel, molybdenum, chromium, tungsten, titanium, alloys thereof, or combinations thereof.