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: Provided are apparatus, systems, and methods for generating a non-plugging hydrate slurry. The apparatus, systems, and methods for generating a hydrate slurry are useful for transport and/or production of wellstream hydrocarbons in subsea and arctic environments. The present invention provides methods of seeded or unseeded methods of making dry hydrates. Dry hydrates are made with or without the aid of chemicals and, preferably, with minimum use of rotating or other energized equipment.

Abstract: The present invention relates to a method and apparatus for reducing the occurrences of lateral wellbores being occluded by fines such as sand and silt. More specifically, the invention relates to discharging a portion of the output of an electrical submersible pump through nozzles that pass through the sidewalls of tubing, the tubing being located in the lateral wellbore.

Abstract: In some embodiments, apparatus useful for providing fluids or equipment into a subterranean well through a production tubing and associated dead string includes an injection system that is movable into and out of the well without removing the production tubing. The injection system includes a stopper that forms the seal that creates the dead string.

Abstract: Systems for enhanced in-situ or perhaps even ex-situ biogenic methane production from hydrocarbon-bearing formations (1) including coal seam, oil shale, coal, coal derivates and the like are presented in embodiments such as but not limited to: increasing and perhaps even selection of microbial populations (2), amending CBM water and other microbe-containing media, diminishing sulfate reduction competition, enhancing organic matter concentrations and generation of biogenic methane (10), universally treating hydrocarbon-bearing formations, and introducing amendments (3) to hydrocarbon-bearing formations.

Abstract: The methods described herein generally relate to preparing and delivering a fluid mixture to a confined volume, specifically an annular volume located between two concentrically oriented casing strings within a hydrocarbon fluid producing well. The fluid mixtures disclosed herein are useful in controlling pressure in localized volumes. The fluid mixtures comprise at least one polymerizable monomer and at least one inhibitor. The processes and methods disclosed herein allow the fluid mixture to be stored, shipped and/or injected into localized volumes, for example, an annular volume defined by concentric well casing strings.

Abstract: A method for stimulating methane production from a carbonaceous material is described. The methods may include the step of contacting the material with cells of a methanogenic consortium under anaerobic conditions to form a reaction mixture. The method may also include maintaining anaerobic conditions for a time sufficient to permit methanogenesis, and collecting methane from anaerobic water or head space of the reaction mixture.

Abstract: An oil recovery process utilizes one or more membranes to remove silica and/or oil from produced water. In one method, the process includes separating oil from produced water and precipitating silica. The produced water having the precipitated silica is directed to a membrane, such as a ceramic membrane, which removes the precipitated silica from the produced water. In some cases, residual oil is present and is also removed by the membrane.

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: An enhanced oil recovery method and apparatus for thermal processing of polymer-based waste to produce organic and inorganic processed materials. The organic and inorganic processed materials are injected as an injection stream into the ground to liberate ground oil. The liberated ground oil is withdrawn from the ground. The injection stream interacts with the ground oil to form a new oil and the new oil including the ground oil is withdrawn from the ground. Thermal processing is done with pyrolysis of waste tires.

Abstract: A method to remove hydrate plugs in a production system by passing a non-hydrate-forming or a hydrate-forming gas, which forms hydrates at a higher pressure than the existing hydrate, through the flow-restricting hydrate.

Abstract: A method of treating a subterranean formation penetrated by a wellbore to mitigate the production of unwanted fluids from the wellbore is carried out by forming a treatment fluid containing at least one of an oil-wetting or water-repelling surfactant and a carrier fluid. The treatment fluid is then introduced into the wellbore. The treatment or treatments may be performed remedially or prophylacticaly. The treatment may include the completion and production of zones containing the undesirable fluid(s) and the deliberate formation of cones therein.

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: Methods are disclosed to treat produced water from hydrocarbons production facilities. The disclosed methods can be used to either: (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.

Abstract: A process is described for replacing at least a portion of the liquid within the annular volume of a casing system within a wellbore with a second liquid. The second liquid is preselected to provide a measure of control of the pressure within the annular volume as the fluid within the volume is being heated.

Abstract: A process is described for replacing at least a portion of the liquid within the annular volume of a casing system within a wellbore with a second liquid. The second liquid is preselected to provide a measure of control of the pressure within the annular volume as the fluid within the volume is being heated.

Abstract: A plume of combined gases are infused into hydrocarbon-bearing formations, “inert” as the major gas and “reactive” as the minor gas, where the minor gas reacts with hydrocarbons to fully saturate hydrocarbons with supercritical fluid, which migrate hydrocarbons out of formations, even at great distances from the regulated fuel cell source. Coal, tar sands, petroleum-contaminated soil, and/or oil wells that have lost gas pressure can also be desorbed by this in-situ method.

Abstract: A process for injecting water into a subterranean petroleum-bearing formation for petroleum recovery, said method comprising: a) positioning a selective membrane (14) between an aqueous solution (18) and formation water (20) having a higher solute concentration than the aqueous solution (18), such that water passes across the membrane (14) by osmosis to dilute the formation water (20), b) injecting the diluted formation water (22) into the petroleum-bearing formation, c) recovering formation water from the petroleum-bearing formation, and d) using at least a portion of the recovered formation water in step a).

Abstract: This invention presents innovative and off the beaten path methods to mainly produce suitable saline streams for oil-fields water injection operations. The production of such suitable saline streams can: (1) be achieved economically; and (2) meet the actual stringent requirements for injection operations to steadily enhance oil production from depleted and plugged wells.

Abstract: An oil recovery process utilizes one or more membranes to remove silica and/or oil from produced water. In one method, the process includes separating oil from produced water and precipitating silica. The produced water having the precipitated silica is directed to a membrane, such as a ceramic membrane, which removes the precipitated silica from the produced water. In some cases, residual oil is present and is also removed by the membrane.

Abstract: A well liner segment for use in hydrocarbon recovery processes. An elongate, typically cylindrical outer liner member, and an inner elongate liner member concentrically located therewithin is provided. Hydrocarbon upgrading catalyst is provided in the interstitial space between the two members. The outer liner members may be threadably coupled together. A slidable seal is provided between the outer liner and the inner liner to accommodated differential thermal growth between the two liners. A process for use of well liner segments having hydrocarbon upgrader catalyst pre-installed therein, is also provided, as is a method for manufacture of a well liner segment.

Abstract: A process for recovery oil includes recovering an oil/water mixture from an oil well. Thereafter, the method includes separating oil from the oil/water mixture to produce an oil product and produced water having dissolved silica therein. The produced water is directed to an evaporator and produces steam and a concentrated brine. The method or process entails mixing a precipitant or crystallizing reagent with the produced water or the concentrated brine and causing the silica to precipitate from the produced water or the concentrated brine. Steam produced by the evaporator is condensed to form a distillate which is directed to steam generator. At the steam generator the distillate is heated to produce steam which is injected into an injection well, giving rise to the formation of the oil/water mixture.

Abstract: A method of conditioning well bores and reducing the deleterious effects of water production in a subterranean formation by placing an aqueous phase polymer and/or resin, which at a designated set up time, solidifies and blocks water conduits and establishes post treatment gas and oil permeability. Novel polymers and/or resins for use as a water barrier are typified by phenolformaldehyde containing 1-2 weight % of at least one of sodium bisulphite, sodium metabisulphite or mixtures thereof. The method includes selecting a well having sizable hydrocarbon reserves with a production history of decrease of oil or gas production with concurrent increase of water production.

Abstract: A process is described for replacing at least a portion of the liquid within the annular volume of a casing system within a wellbore with a second liquid. The second liquid is preselected to provide a measure of control of the pressure within the annular volume as the fluid within the volume is being heated.

Abstract: A method for recovering hydrocarbons from a reservoir includes separating air into a nitrogen-rich gas and an oxygen-rich gas, oxidizing a hydrocarbon fuel with at least part of the oxygen-rich gas to produce steam and a CO2-rich gas, injecting at least part of the steam through an injection well into the reservoir to heat the hydrocarbons, purging the injection well with at least part of the nitrogen-rich gas, and injecting at least part of the CO2-rich gas into the reservoir containing the heated hydrocarbons.

Abstract: A wellbore tubular including: an inner tubular wall; an opening through the inner tubular wall; an outer tubular wall positioned about the inner tubular, the outer tubular wall including an opening therethrough; a chamber between the inner tubular wall and the outer tubular wall; and a chemical treatment material in the chamber and positioned between the opening of the inner tubular wall and the opening of the outer tubular wall. The wellbore tubular may be used in downhole fluid treatment process.

Abstract: An economic method for in situ maturing and production of oil shale or other deep-lying, impermeable resources containing immobile hydrocarbons. Vertical fractures are created using horizontal or vertical wells. The same or other wells are used to inject pressurized fluids heated to less than approximately 370° C., and to return the cooled fluid for reheating and recycling. The heat transferred to the oil shale gradually matures the kerogen to oil and gas as the temperature in the shale is brought up, and also promotes permeability within the shale in the form of small fractures sufficient to allow the shale to flow into the well fractures where the product is collected commingled with the heating fluid and separated out before the heating fluid is recycled.

Abstract: A modified method for in situ recovery of hydrocarbon from an underground hydrocarbon-containing formation. An “L” shaped production well, having a vertical section, and a lower horizontal leg positioned low in the formation, is provided. The horizontal leg connects to the vertical section at a heel portion, and has a toe portion at an opposite end thereof. Oxidizing gas is injected into the formation in or proximate the vertical section. A combustion front sweeps outwardly from the vertical section and laterally within the formation above the horizontal leg, from the heel to the toe, causing hydrocarbons in the formation above the horizontal leg to drain downwardly into the horizontal leg, which are then delivered to surface via production tubing. A non-oxidizing gas is injected into at least the heel portion and preferably additional portions of the horizontal leg via injection tubing contained within the vertical section of the production well.

Abstract: A method of treating a subterranean formation penetrated by a wellbore to mitigate the production of unwanted air from the wellbore is carried out by forming a treatment fluid containing a water-wetting surfactant and a carrier fluid. The treatment fluid is then introduced into the wellbore. The treatment or treatments may be performed remedially or prophylacticaly. The treatment may include the completion and production of zones containing the undesirable air and the deliberate formation of cones therein.

Abstract: Systems for enhanced in-situ or perhaps even ex-situ biogenic methane production from hydrocarbon-bearing formations (1) including coal seam, oil shale, coal, coal derivates and the like are presented in embodiments such as but not limited to: increasing and perhaps even selection of microbial populations (2), amending CBM water and other microbe-containing media, diminishing sulfate reduction competition, enhancing organic matter concentrations and generation of biogenic methane (10), universally treating hydrocarbon-bearing formations, and introducing amendments (3) to hydrocarbon-bearing formations.

Abstract: An aqueous fluid useful for the recovery of crude oil from a subterranean formation, which includes a composition including a mixture of water, a water soluble block copolymer, an inorganic salt and at least one member of the group of a nonionic surfactant having an HLB of less than 12, and methods for using same.

Abstract: Methods are disclosed to de-sulfate saline streams such as seawater, brine from seawater desalination plants, and the like. The disclosed methods can also co-produce de-ionized water and inorganic materials from such de-sulfated saline streams.

Abstract: A process for emulsifying and burning a portion of heavy oil extracted from an underground reservoir, wherein the emulsified heavy oil is burned to generate steam and a caustic is used to aid in emulsifying the heavy oil.

Abstract: A process is described for replacing at least a portion of the liquid within the annular volume of a casing system within a wellbore with a second liquid. The second liquid is preselected to provide a measure of control of the pressure within the annular volume as the fluid within the volume is being heated.

Abstract: This invention teaches methods and compositions to enhance oil and gas recovery from reservoirs. The methods and compositions disclosed enhance hydrocarbon recovery and fluid disposal in subterranean reservoirs by injecting microemulsion fluids with supercritical fluids, water, or an alternating injection phase of each fluid.

Abstract: Embodiments include methods for recovering petroleum products from a formation containing heavy crude oil. In one embodiment, a method includes flowing a catalytic material containing the nanocatalyst into the formation containing the heavy crude oil and exposing the heavy crude oil and the catalytic material to a reducing agent (e.g., H2). The method further includes positioning a steam generator within the formation, generating and releasing steam from the steam generator to heat the heavy crude oil containing the catalytic material, forming lighter oil products within the formation, and extracting the lighter oil products from the formation. In another embodiment, a method includes exposing the heavy crude oil and the catalytic material to an oxidizing agent (e.g., O2). The nanocatalyst may contain cobalt, iron, nickel, molybdenum, chromium, tungsten, titanium, oxides thereof, alloys thereof, or combinations thereof.

Abstract: A method for removing silica from evaporator concentrate to facilitate disposal of the concentrate. An alkaline earth compound is mixed with the concentrate in a crystallizer. Silica in the concentrate reacts with the alkaline earth compound and precipitates from the concentrate as alkaline silicate complexes. The concentrate having the alkaline earth silicate complexes is directed to a separator where the alkaline earth silicate complexes are separated from the concentrate, producing an aqueous solution and slurry. The slurry is directed to a filter where solids are separated from a filtrate. Both the aqueous solution and the filtrate can be disposed of by deep well injection.

Abstract: A process to increase the area of microbial stimulation in a process of methane gas recovery in a multi seamed coal bed/methane dewatering and depressurizing production system by first utilizing an underbalanced multilateral drilling technique. At this point in the process one could introduce the microorganisms into the horizontal well bore to achieve a greater area of stimulation of the coal bed than would a vertical well. An even more preferred method would to first drill a series of lateral wells off of the horizontally drilled well bore, so as to increase or maximize the area of coal bed which is being covered. At that point, one would take the steps of what is known in the art of introducing a particular type of microorganism, which would then be injected via the plurality of lateral bores into the coal bed formation, to maximize the area of penetration, which would include, most, if not all, of the area of the coal bed through the series of lateral wells.

Abstract: A method of extraction of fuels, organic pollutants, and elements from Methane hydrate deposits, shale seams and the soil is described which freezes the zone and heats the center carrying the fuel, chemicals and water in these deposits and seams from where they are found, be it deep in the sea or on land, and carries them into the condensing unit in inert Nitrogen gas. Required drilling on the surface or sea bottom includes a main shaft and with auxiliary narrow drillings widely spaced from the shaft. The extraction zone, which is first cooled to brittle cold using the evaporation of Liquid Nitrogen and fractured with vibrations, is heated to the highest temperature of the hydrocarbon fraction desired to be extracted. The evaporating hydrocarbons are extracted in a Nitrogen gas carrier, a recognized fire suppressant (NFPA Code 2000).

Abstract: The invention provides a method of protecting a hydrocarbon conduit during a period of reduced hydrocarbon flow, said method comprising introducing nitrogen into said conduit during a said period at a pressure p of 1 to 350 bar g and at a rate of (1.5 to 35). A kg/sec (where A is the internal cross sectional area of the conduit in square metres) for a period of t hours where t=p.d/n where d is the length in km of the conduit from the nitrogen introduction location and n is 10 to 400.

Abstract: Corrosive effects arising during oilfield treatment applications are inhibited and/or prevented by introducing into an oil or gas well at least one compound of formula I: wherein: R1 is independently H, —[—CnH2nO—]a—H, or an alkyl group having from 1 to about 24 carbon atoms; R2 is independently H or —[—CnH2nO—]b—H, R3 is independently —[—CH2]c—, or —CdH2d—[—OCnH2n—]e—, R4 is independently H or —[—CnH2nO—]f—H, R5 is independently H or —[—CnH2nO—]g—H, a is from about 1 to about 8; b+f+g is between 0 to about 30; c is from about 1 to 6; d is from about 1 to 6; e is from about 1 to about 8; and n is 2 or 3. Such corrosive effects are especially inhibited in the treatment of sour wells where H2S corrosion is a potential problem as well as conduits used during the treatment of subterranean formations.

Abstract: Methods of producing a sour hydrocarbon gas via production tubing intersecting a reservoir, are described, one method including contacting an underground reservoir with an aqueous composition optionally comprising an additive, the reservoir comprising hydrocarbons and sulfur compounds; displacing the composition into the reservoir by forcing a fluid (which may be a non-hydrocarbon gas, or inert gas, or nitrogen, or argon, or mixture thereof), into the reservoir, or into the production tubing; and producing at least some of the hydrocarbons and sulfur compounds from the reservoir through the production tubing, the composition wetting the production tubing and preventing substantial deposition of elemental sulfur thereon.

Abstract: An oil recovery process utilizes one or more membranes to remove silica and/or oil from produced water. In one method, the process includes separating oil from produced water and precipitating silica. The produced water having the precipitated silica is directed to a membrane, such as a ceramic membrane, which removes the precipitated silica from the produced water. In some cases, residual oil is present and is also removed by the membrane.

Abstract: In some embodiments, apparatus useful for providing fluids or equipment into a subterranean well through a production tubing and associated dead string includes an injection system that is movable into and out of the well without removing the production tubing. The injection system includes a stopper that forms the seal that creates the dead string.

Abstract: A method for recovering oil includes recovering an oil-water mixture from a well and separating oil from the oil-water mixture to produce an oil product and produced water. The produced water is directed to an evaporator which produces steam that is condensed to form a distillate. Thereafter the distillate is directed to a steam generator and is heated to form steam and water. At least a portion of the water is recirculated through the steam generator. Another portion of the water is mixed with the steam to form a steam-water mixture that is injected into an injection well.

Abstract: A method for recovering heavy oil including recovering an oil-water mixture from a well and separating oil from the oil-water mixture to produce an oil product and produced water. The produced water is separated into a series of produced water streams. Each produced water stream is directed into each of a plurality of interconnected evaporators in a multiple effect evaporator. A first produced water stream is heated and vaporized to form a first vapor stream. The first vapor stream then heats and vaporizes a second produced water stream to form a second vapor stream. This process may continue wherein the second vapor stream heats and vaporizes a third produced water stream. The vapor streams are condensed to form a distillate that is directed to a steam generator. The steam generator then heats the distillate and produces steam to inject into an oil injection well.

Abstract: A down hole apparatus includes a first expandable packer and a second expandable packer, where the first expandable packer longitudinally spaced from the second expandable packer. The apparatus further includes an optional expandable bladder disposed at a longitudinal location between the first expandable packer and the second expandable packer. The expandable bladder inflates to displace drilling fluid between the first and second bladder elements. The down hole apparatus can optionally displace drilling fluid between the first and second bladder elements with another fluid. Fluids and/or slurry can be selectively removed using ports between the first and second expandable packers, and optionally placed in sample chambers, or expelled to the bore hole.

Abstract: Provided embodiments relate to introducing a water-drainage-rate-enhancing agent into a subterranean formation to enhance gas production following a relative-permeability-modifier treatment to decrease undesired water production. An exemplary embodiment provides a method of treating a subterranean formation such that initiation of gas production is enhanced following the treatment, the method comprising: introducing a relative-permeability modifier into at least a portion of the subterranean formation such that the relative-permeability modifier reduces permeability of the portion to aqueous fluids; and introducing a water-drainage-rate-enhancing agent into at least a portion of the subterranean formation. Another exemplary embodiment provides a treatment fluid comprising a carrier fluid, a relative-permeability modifier, and a water-drainage-rate-enhancing agent.

Abstract: A method of increasing the production of a formation gas from a well bore penetrating a gas producing formation wherein the formation gas has a water content that results in the formation of condensate water from the formation gas as the formation gas passes up the well bore to the surface so as cause the condensate water to accumulate at the bottom of the well bore and impede the flow of formation gas into the well bore from the gas producing formation. The method includes injecting a volume of a diluent gas having a water content less than the water content of the formation gas into the well bore at a pressure sufficient to cause the diluent gas to mix with the formation gas in the well bore and dilute the formation gas but at a pressure insufficient to cause the diluent gas to invade the gas producing subterranean zone to produce a production gas which has a water content that substantially prevents the formation and deposition of condensate water as the production gas passes to the surface.

Abstract: A method and system for the production of a gas hydrate including the steps of drilling into a subterranean gas hydrate formation and at least partially depressurizing the gas hydrate formation to permit separation of gas and water from the hydrate form. The gas and water is then pumped from the formation and recovered from the well. At least a portion of water pumped from the well is water that is introduced into the well from the surface or reintroduced by a feed back loop from the production operation.