Abstract: A method of drilling multiple boreholes within a single caisson, for recovery of methane gas from a coal bed, including the steps of drilling first and second vertical boreholes from a single location within a single caisson; drilling at least one or more horizontal wells from the several vertical bore hole, the horizontal wells drilled substantially parallel to a face cleat in the coal bed; drilling at least one or more lateral wells from the one or more horizontal wells, the lateral wells drilled substantially perpendicular to one or more face cleats in the coal bed; continuously circulating water through the drilled vertical, horizontal and lateral wells to recover the water and entrained methane gas from the coal bed; applying friction or choke manifold to the water circulating down the well bores so that the water appears to have a hydrostatic pressure within the well sufficient to maintain an equilibrium with the hydrostatic pressure in the coal bed formation; and drilling at least a third vertical bore

Abstract: The fracturing methods can provide an advantage over the current fracturing methods. The disclosed fracturing methods can change the fracture gradient of the downhole subterranean formation. For example, one or more of the fracture gradients of the low and high stress zones of the downhole subterranean formation can be changed. Furthermore, the methods of present disclosure, in relation to current practices, can decrease the extent and/or degree of fracturing within low stress downhole formations and increase the degree of fracturing within high stress formations.

Abstract: Methods and compositions are provided that relate to sealant compositions comprising cement kiln dust, tire-rubber particles, and water. An embodiment discloses a method comprising: providing a sealant composition comprising cement kiln dust, tire-rubber particles, and water; and allowing the sealant composition to set to form a hardened mass.

Abstract: Loss of wellbore fluids (such as drilling fluids, completion fluids and workover fluids) into the flow passages of a subterranean formation may be reduced or eliminated by introducing into the wellbore in communication with the formation a composition containing a composite of a deformable core having a hardened coating which contains a viscosifying agent and, optionally, a crosslinking agent. The viscosity of the composition increases in-situ as the viscosifying agent, and optional crosslinking agent, disassociate from the deformable core and react. A fluid-impermeable barrier is thereby formed. The composites may also be used in spacers, well cements, workover and completion fluids as their need arises.

Abstract: A vapor hood for a proppant blending system, with a proppant entrance port to receive proppant, the proppant entrance port having a one way valve to allow the flow of proppant but prevent the backflow of vapor when the proppant is not entering the vapor hood.

Abstract: Improved hydraulic fracturing compositions are disclosed which help reduce potential negative environmental impact by hydraulic fracturing. The disclosed compositions have flammability and toxicity and are relatively safe for the environment. The compositions may also contain biodegradable components.

Abstract: Downhole tools for use in oil and gas production which degrade into non-toxic materials, a method of making them and methods of using them. A frac ball and a bridge plug comprised of polyglycolic acid which can be used in fracking a well and then left in the well bore to predictably, quickly, and safely disintegrate into environmentally friendly products without needing to be milled out or retrieved.

Abstract: A method of use of single component resins to strengthen structural features in subterranean formations includes providing particulates, a carrier fluid, a curable resin and a latent curing agent. The curable resin is not cured by the latent curing agent at room temperature, standard pressure or neutral pH. The particulates are coated with the curable resin and the latent curing agent to create resin-coated particulates. A slurry of resin-coated particulates is created in the carrier fluid, and placed into a portion of a subterranean formation and allowing the latent curing agent to cure the curable resin to form cured, resin-coated particulates.

Abstract: The present invention relates to carbon-based fluorescent nano-agent tracers for analysis of oil reservoirs. The carbon-based fluorescent nano-agents may be used in the analysis of the porosity of a formation. The nanoagents are suitable for injection into a petroleum reservoir and may be recovered from the reservoir for the determination of hydrocarbon flow rates and retention times.

Abstract: An electrophilic acid gas-reactive fracturing and recovery fluid, proppant, and process are detailed. The fluid expands in volume to provide rapid and controlled increases in pressure that enhances fracturing in subterranean bedrock for recovery of energy-producing materials. Proppants stabilize openings in fractures and fissures following fracturing.

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: Methods of treating a subterranean formation including providing a subterranean formation comprising at least one fracture; providing proppant particulates coated with a binding agent and having a gas-generating chemical and a delayed encapsulated activator attached thereto so as to form coated proppant particulates; suspending the coated proppant particulates in a treatment fluid; placing the treatment fluid into the at least one fracture; and reacting the gas-generating chemical and the delayed encapsulated activator so as to produce a gas within the at least one fracture and form a proppant pack therein.

Abstract: Diverting compositions for treating a subterranean zone substantially distanced from a wellbore, comprising: a carrier fluid; and a particulate, partially dehydrated or anhydrous borate source material that does not substantially swell when placed in contact with the carrier fluid. The carrier fluid is capable of carrying and placing the borate source material into a stimulation network substantially distanced from a wellbore, and wherein the borate source material is dissolvable through sufficient contact with an aqueous fluid. The carrier fluid is a water-miscible non-aqueous fluid selected from the group consisting of ethylene glycol, propylene glycol, N,N- dimethylformamide, tetrahydrofuran, dichloromethane, 1,4-dioxane, dimethylsulfoxide, tetramethylenesulfone, acetonitrile, hexamethylphosphoramide, 1,3-methyl-3,4,5,6-tetrahydro- 2(1H)-pyrimidinone, propylene carbonate, ethylene carbonate, and combinations thereof.

Abstract: The present invention relates to lightweight high strength microsphere containing ceramic particles having controlled microsphere placement and/or size and microsphere morphology, which produces an improved balance of specific gravity and crush strength such that they can be used in applications such as proppants to prop open subterranean formation fractions. Proppant formulations are further disclosed which use one or more microsphere containing ceramic particles of the present invention. Methods to prop open subterranean formation fractions are further disclosed. In addition, other uses for the microsphere containing ceramic particles of the present invention are further disclosed, as well as methods of making the microsphere containing ceramic particles.

Abstract: A method includes preparing a hydraulic fracturing fluid that includes a proppant mixture; adjusting the hydraulic fracturing fluid to a flow pattern operable to distribute a substantially equal distribution of an amount of proppant from the proppant mixture into a plurality of fracture clusters formed in a subterranean zone; and distributing the hydraulic fracturing fluid in the substantially equal distribution of the amount of proppant from the proppant mixture into the plurality of fracture clusters, each of the plurality of fracture clusters formed in the subterranean zone at a unique depth from the terranean surface.

Abstract: A method for hydraulically fracturing subterranean formations in a manner resulting in improved propping of fractures, particularly in ductile rock formations such as gas-containing shales having a high clay content. The method allows for improved hydrocarbon production. The method involves injecting a first fluid having a first proppant concentration into the subsurface formation to form a fracture, reducing the pressure in the fracture and allowing the fracture to substantially close, and injecting a second fluid having a second proppant concentration into the fracture to re-open the fracture. The second proppant concentration is greater than the first proppant concentration. A portion of the proppant is effectively retained in the reopened fracture.

Abstract: Methods of treating a subterranean formation penetrated by a well bore, by providing a treatment fluid comprising a blend including a first amount of particulates having a first average particle size between about 3 mm and 2 cm and a second amount of particulates having a second average size between about 1.6 and 20 times smaller than the first average particle size or a second amount of flakes having a second average size up to 10 times smaller than the first average particle size; by introducing the treatment fluid into the well bore; and by creating a plug with the treatment fluid.

Abstract: Methods and systems of fracturing subterranean formations are provided comprising pumping metacritical phase natural gas into a subterranean formation to create or extend one or more fissures in the formation. Methods and systems may further comprise maintaining or increasing pressure of the metacritical phase natural gas in the formation by pumping more metacritical phase natural gas into the fissures to hold the fissures open. Methods and systems may further comprise delivering a proppant into the subterranean formation. Disclosed methods and systems may be used to extract hydrocarbons from subterranean formations without the use of liquids.

Abstract: A method using a propping fluid comprising a first carrier fluid and a plurality of propping agents and a spacer fluid comprising a second carrier fluid and an expandable filler material. The method introduces the propping fluid into a fracture in a subterranean formation and introduces the spacer fluid into the fracture. Then the expandable filler material is exposed to an expanding agent that causes the expandable filler material to expand and press against the adjacent propping agents.

Abstract: An angular abrasive proppant comprises angular sintered particles of a material selected from bauxite, clay-minerals, and mixtures thereof, with particle sizes varying from 30 mesh to 150 mesh. A process for the production of an angular abrasive proppant comprising sintered particles of a material selected from bauxite, clay-minerals, and mixtures thereof comprises the steps of drying, grinding, pelletizing, and sintering a bauxite starting material, grinding the sintered pellets, and sizing said particles to a particle size varying from 35 to 150 mesh. A hydraulic fracturing process uses as proppant the angular abrasive proppant as the described above.

Abstract: A tool having a high-molecular weight Polyglycolides such as polyglycolic acid (PGA) may be used in downhole hydrocarbon recovery applications. Advantageously, PGA tools do not need to be drilled out but will naturally break down into environmentally-compatible natural compounds.

Abstract: An apparatus and method for delivering a thickened fluid mixture, including a CO2 recapture system. The apparatus including a proppant storage vessel and a fracturing fluid storage vessel providing a continuos supply of a proppant material and a fracturing fluid to a mixing apparatus. The mixing apparatus configured to output and deliver a thickened fluid mixture of the proppant, the fracturing fluid and a thickener agent at or above the fracturing fluid blending pressure to a high pressure pump assembly. The high pressure pump assembly configured to deliver a high pressure thickened fluid mixture to one or more downstream components at an injection pressure. The apparatus including a CO2 recapture system configured to recapture an exhaust stream from the one or more downstream components and/or other CO2 output sources, and provide a purified and liquefied CO2 fluid stream to the fracturing fluid storage vessel. The apparatus configured for continual operation.

Abstract: A borehole is drilled from the surface to an underground shale matrix. A pipe is inserted into the borehole. Openings are created in the pipe in fluid communication with fractures in the shale matrix. The interior surface of at least one section of pipe is coated with a contaminant-capturing substance. Fracturing fluid including water, proppants and chemicals is pumped through the pipe and into the fractures in the shale matrix. The fluid re-enters the pipe from the shale matrix and moves toward the surface through the coated pipe section where contaminants are sequestered by the coating. Natural gas or oil from the fractured shale then enters the pipe and moves to the surface to be collected. The coated pipe section remains in the ground permanently such that the necessity of disposing of the captured contaminants is eliminated.

Abstract: A system and method of operation are shown where the system includes a plurality of geothermal wells, each well having a heat exchanger therein including closed cycle system piping to and from the surface, each well having plurality of appendages drilled in multiple directions in relation to the central borehole of the well and filled with heat conductive material in order to conduct heat from the appendages to the heat exchanger. At least one upstream working fluid manifold is connected at manifold inlets to piping conveying hot working fluid pumped from the closed cycle system piping of more than one of the plurality of geothermal heat extraction borehole wells and connected by manifold outlets to piping conveying the pumped hot working fluid to at least one heat engine.

Abstract: Solid proppants are coated with a coating that exhibits the handling characteristics of a precured coating while also exhibiting the ability to form particle-to-particle bonds at the elevated temperatures and pressures within a wellbore. The coating includes a substantially homogeneous mixture of (i) at least one isocyanate component having at least 2 isocyanate groups, and (ii) a curing agent. The coating process can be performed with short cycle times, e.g., less than about 4 minutes, and still produce a dry, free-flowing, coated proppant that exhibits low dust characteristics during pneumatic handling but also proppant consolidation downhole for reduced washout and good conductivity.

Abstract: Methods of treating a wellbore in a subterranean formation including providing an oil-external treatment fluid, wherein the oil-external treatment fluid is a 3D-network comprising a chemical interaction between a hydrocarbon fluid, an aqueous fluid, and a surface modification agent; providing proppant particulates; suspending the proppant particulates in the oil-external treatment fluid; and introducing the oil-external treatment fluid comprising the proppant particulates into the wellbore in the subterranean formation.

Abstract: Systems and methods for cooling process equipment are provided. The system includes a process fluid source, and a heat exchanger fluidly coupled with the process equipment and the process fluid source. The heat exchanger is configured to receive a process fluid from the process fluid source and transfer heat from the process equipment to the process fluid. The system also includes a control system fluidly coupled with the heat exchanger. The control system is configured to vary a temperature of the process fluid heated in the heat exchanger. Further, at least a portion of the process fluid heated in the heat exchanger is delivered into a wellbore at a temperature below a boiling point of the process fluid.

Abstract: A method is provided for treating at least a portion of a subterranean formation. The method includes introducing a treatment fluid including a composite particle, which includes proppant incorporated into or attached to a swellable material and/or swellable materials, into a subterranean formation via a wellbore; and increasing the buoyancy of the composite particle including proppant by either mixing it with a treatment fluid or mixing it with a treatment fluid and triggering the swellable material and/or swellable materials to swell.

Abstract: There are provided high power laser perforation, hydraulic fracturing systems, tools and methods for the stimulation and recovery of energy sources, such as hydrocarbons, from a formation. These systems, tools and methods provide predetermined laser beam energy patterns, to provide for the down hole volumetric removal of custom geometries of materials, sealing of perforations, reperorations, refractures and other downhole actives.

Abstract: The invention relates to a method of generating an enhanced fracture network in a rock formation by the sequential stages of: i) injecting a non-slurry aqueous solution into a well extending into the formation at a rate and pressure which is close to the minimum hydraulic fracture initiation pressure and rate of the formation, until the maximum possible stimulated volume of the formation has been substantially attained to generate an outer zone of self-propping fractures; ii) injecting a first slurry of relatively fine grains of proppant to prop fractures generated in stage i within an intermediate zone located within and surrounded by the outer zone generated in stage i; and iii) injecting a second slurry comprising relatively coarse grains of to generate large fractures within an inner zone surrounded by and within the intermediate zone, in communication with the fractures generated in stages i and ii.

Abstract: A method for underdisplacing fracture proppant in a well bore. The method can include providing a set retainer having a passage configured to receive a wiper plug. The method may also include installing the set retainer in the well bore and injecting a proppant-laden fluid into the well bore, through the passage of the set retainer and through a perforation to create the fracture. The method may include providing a wiper plug configured to be received in the passage of the set retainer. The method may also include inserting the wiper plug into the well bore and allowing the wiper plug to wipe a portion of the proppant-laden fluid past the set retainer and into the fracture. Additionally, the method may include allowing the set retainer to receive the wiper plug.

Abstract: A polyamide-poly(phenylene ether) composition includes, based on the total weight of the composition, 35 to 80 weight percent of polyamide, and 20 to 65 weight percent of a poly(phenylene ether). The polyamide-poly(phenylene ether) composition is utilized in a variety of methods, including methods applicable to the oil and gas industry.

Abstract: The disclosed compositions and methods provide a system that is effective for hydraulic fracturing, which can be used to extract natural gas and oil from subterranean formations, such as deep shale and coal bed type rack formations. In a first aspect, the invention features a composition for hydraulic fracturing, which includes a low pH product, a surfactant, and a thickening agent, all in an aqueous composition. The composition includes i) from about 0.01 wt % to about 20.0 wt % of a low pH product that includes an ammonium salt (e.g., ammonium bicarbonate, ammonium carbonate, or ammonium hydroxide) and hydrogen chloride (and optionally a carborane).

Abstract: Re-treatment of a formation having a wellbore, which can be an open hole or a cased hole lined with casing, involves deploying a tubing string in the casing having tools disposed at intervals thereon. The tools position on the tubing string, and the tubing string with the tools thereon is inserted into the casing. Biasing rings of the tools passively engage with the casing. The annulus is accessed between the tubing string and the casing at the intervals between the tools. For example, sliding sleeves on the tubing string can be opened (selectively), or new plug and perforation operations can be used to create perforations in the tubing string at desired intervals between the tools. With access achieved, retreatment is pumped down the tubing string, out the access to the annulus, and at least partially sealed by the engaged rings in the intervals between the tools.

Abstract: In one aspect, a method for completing a wellbore in a formation is disclosed, that in one non-limiting embodiment includes placing a casing in the wellbore, cementing an annulus between the casing and the wellbore, and forming an annular cavity of a selected length in the cement between the casing and the wellbore. In one aspect, the forming the annular space includes placing a dissolvable material on an outside of the casing before placing the casing in the wellbore, and dissolving the dissolvable material after cementing to form the annular space.

Abstract: The methods described are for determining distribution, orientation and dimensions of networks of hydraulically-induced fractures within a subterranean formation containing fluids. Micro-seismic events are generated by particles introduced into the fractures which are capable of explosive or chemical reaction. In one method, treated proppant having a reactive coating is positioned in the formation during fracturing and reactive particles are introduced. In another method, reactive particles having a reactive core and a non-reactive coating are positioned in the fractures and react upon removal of the non-reactive coating, such as by dissolving, and reaction with a reactive particle. The waves generated by the micro-seismic events are used to map fracture space.

Abstract: Well treatment with shapeshifting particles. Methods, treatment fluids and systems utilizing shapeshifting particles are disclosed. One method relates to the injection of the shapeshifting particles into a fracture, and changing a conformation of the shapeshifting particles to improve conductivity. A treatment fluid comprises the shapeshifting particles dispersed in a carrier fluid, and a system comprises a unit to supply the treatment fluid, a pump system to inject the treatment fluid into the fracture and a triggering system to change the conformation of the shapeshifting particles.

Abstract: A method of creating a step-change in proppant concentration in a fracturing fluid at a desired location within the conduit or wellbore of an oil or gas well includes the steps of connecting an in-line mixer at an end of a conveyance, placing the in-line mixer within a conduit proximate to the desired location, providing a flow of a clean fluid from an upper portion of the conduit past the in-line mixer and into a lower portion of the conduit, introducing a proppant slurry into the conveyance, and injecting the proppant slurry into the clean fluid from the in-line mixer to generate a first step-change from the clean fluid to a flow of a mixture of the proppant slurry and the clean fluid within the desired location.

Abstract: The invention pertains to a process for fracturing a subterranean formation using a mixture of methane (natural gas) and propane/butane (liquefied petroleum gas). The process comprises: a)providing a first fluid (in a gas or liquefied form) comprising at least 50 wt. % of methane: b)providing a second fluid (in a gas or liquefied form) comprising at least 50 wt. % of the combination of propane and butane: c)mixing and, in case of a gas mixture, liquefying said first fluid and said second fluid to obtain a liquefied fluid mixture comprising 15-80 wt. % of methane and 15-80 wt. % of the combination of propane and butane, said liquefied mixture having a temperature and a pressure such that the liquefied fluid stays above the bubble point of the mixture; d)blending a proppant and/or a gellant into the liquefied fluid mixture to produce a 1 fracturing fluid; e)injecting the fracturing fluid into the subterranean formation.

Abstract: A borehole is drilled from the surface to an underground shale matrix. A pipe is inserted into the borehole. Openings are created in the pipe in fluid communication with fractures in the shale matrix. The interior surface of at least one section of pipe is coated with a contaminant-capturing substance. Fracturing fluid including water, proppants and chemicals is pumped through the pipe and into the fractures in the shale matrix. The fluid re-enters the pipe from the shale matrix and moves toward the surface through the coated pipe section where contaminants are sequestered by the coating. Natural gas or oil from the fractured shale then enters the pipe and moves to the surface to be collected. The coated pipe section remains in the ground permanently such that the necessity of disposing of the captured contaminants is eliminated.

Abstract: Solid proppants are coated with a phenol-urethane coating in one or more layers by a method comprising coating a proppant solid and then curing the coated proppant under conditions sufficient to substantially cure said proppant, wherein said coating comprises a substantially homogeneous mixture of (i) an isocyanate component having at least 2 isocyanate groups, (ii) an amine reactant, and optionally (iii) an amine that is a latent curing agent for said isocyanate.

Abstract: A fracturing valve comprising a tubular mandrel having a through bore continuous with a tubing string, and a frac window through the side of the tubular mandrel. An outer sleeve is radially disposed around the tubular mandrel. The outer sleeve includes a sleeve port in a sidewall. The tubular mandrel slides relative to the sleeve by application and release of set down weight on a coiled tubing string. When the valve is closed, there is no fluid communication from the tubing string out of the frac window. When the valve is open, fluid communication from the tubing string is enabled. The valve may be installed in a downhole tool having a perforation device. The tool string can be used with one sealing element as the tool is pulled up the hole isolating lower perforations, or with two sealing elements to allow pin-point treatments isolating perforations both up and downhole.

Abstract: A well stimulation method includes using a well formation containing fractures and placing proppant in the fractures. A plurality of individual particles of the proppant includes a core containing a swellable material. The method includes swelling the core and increasing a size of the fractures using the swelling core. A proppant particle includes a core containing a swellable material and a dissolvable layer encapsulating the core.

Abstract: A method of distributing proppant in a spatial arrangement throughout a created or enlarged fracture by pumping into a subterranean formation penetrated by a well multiple stages of fracturing fluid wherein a fluid laden with proppant is pumped into the well and a fluid substantially free of proppant is then pumped into the well; the fluid of the fluid laden with proppant and the fluid substantially free of proppant being the same. Vertically extending pillars are created within the formation. Fluid produced from the hydrocarbon-bearing reservoir is then flowed at least partially through channels between the vertically extending pillars.

Abstract: A subterranean zone surrounding a well bore is fractured with a fracturing fluid. Micro proppant of 200 mesh or smaller is pumped into far field fractures of the subterranean zone and props the far field fractures open.

Abstract: The invention relates to a method of generating a network of fractures in a rock formation for extraction of hydrocarbon or other resource from the formation. The method includes the steps of i) enhancing a network of natural fractures and incipient fractures within the formation by injecting a non-slurry aqueous solution into the well under conditions suitable for promoting dilation, shearing and/or hydraulic communication of the natural fractures, and subsequently ii) inducing a large-fracture network that is in hydraulic communication with the enhanced natural fracture network by injecting a plurality of slurries comprising a carrying fluid and sequentially larger-grained granular proppants into said well in a series of injection episodes.

Abstract: A method and apparatus for making up fracturing fluid with coated proppant applies opposed electrical charges to the proppant and its coating to create a uniform coating without extensive mechanical mixing, and additionally, the method applies opposed electrical charges to the coated proppant and fracturing fluid to enhance mixing.

Abstract: A well fracturing fluid is shown which includes an aqueous base fluid, a hydratable polymer, such as a guar gum, and a suitable crosslinking agent for crosslinking the hydratable polymer to form a polymer gel. The hydratable polymer has a higher molecular weight which is achieved by improvements in the processing of the guar split. The higher molecular weight polymer provides improved performance in well fracturing operations.

Abstract: This invention relates to oil and gas production, more specifically, to the methods of producing polymer emulsion for downhole operations and mixing degradable (hydrolysable) polymer emulsion with the treatment fluid.

Abstract: Well treatment with an untethered and/or autonomous device. In situ channelization treatment fluids used in multistage well treatment with an untethered and/or autonomous device is also disclosed. Also disclosed are methods and/or systems for treating a subterranean formation penetrated by a wellbore, relating to in situ channelization treatment fluids, which may optionally be energized, and untethered and/or autonomous devices.