Abstract: A method of fracturing a tight subterranean formation comprising: introducing a cement composition comprising cement and water into the tight subterranean formation thereby creating or enhancing a fracture in the tight subterranean formation, wherein the tight subterranean formation comprises at least one formation zone with a permeability of less than 1 millidarcy; allowing the cement composition to set within the fracture; and creating a permeable flow path within the set cement composition using pressure pulses. Another method comprises introducing a treatment fluid into the tight subterranean formation at or above the fracture gradient of the set cement composition to create or enhance a permeable flow path within the set cement composition.

Abstract: Methods including introducing a treatment fluid comprising a solvent-base fluid and a consolidation composition into a wellbore in a subterranean formation, the consolidation comprising, a crosslinking diverting agent, a hardening agent, and a multi-functional epoxy resin, the multi-functional epoxy resin comprising at least three epoxy groups; coating a face of the subterranean formation with the consolidation composition; and at least partially curing the consolidation composition in the wellbore, to reduce production of unconsolidated particulates from the subterranean formation into the wellbore.

Abstract: A method of controlling flow in a subterranean well can include a device introduced into the well being conveyed by flow in the well, the device comprising a material selected from poly-vinyl alcohol, poly-vinyl acetate and/or poly-methacrylic acid. The material may degrade in the well. A system for use with a well can include a flow conveyed device conveyed through a tubular string by flow in the tubular string, and the flow conveyed device including a material selected from poly-vinyl alcohol, poly-vinyl acetate and/or poly-methacrylic acid. A flow conveyed device for use in a subterranean well can include a body and a degradable material extending outwardly from the body, the degradable material being formed as a film, tube or filament.

Abstract: A collet system is disabled from gaining profile support when moved between profiles that will be used ultimately to support an inner string at a desired plurality of locations. It is when the collet reaches a desired location that it is unlocked by virtue of inner string movement so that a profile on the outer assembly is engaged by a sleeve to induce relative rotation of the sleeve with respect to the mandrel that supports the sleeve. The relative rotation moves a tab into alignment with a slot to permit relative axial movement between the mandrel and the tool so that the tool can function as intended. The sleeve is engaged by another profile for further relative rotation to misalign the tab and the slot to lock the tool. The tool is preferably a support collet for a crossover in a multi-zone gravel pack.

Abstract: Energy is stored by injecting fluid into a hydraulic fracture in the earth and producing the fluid back while recovering power and/or desalinating water. The method is particularly adapted to storage of large amounts of energy such as in grid-scale electric energy systems. The hydraulic fracture may be formed and treated with resin so as to limit fluid loss and to increase propagation pressure. The fluid may be water containing a dissolved salt or fresh water and a portion or all of the water may be desalinated using pressure in the water when it is produced.

Abstract: A method of fracturing a formation surrounding a wellbore comprises the steps of: (i) providing a tubular including at least two portions, each portion comprising an annulus isolation means, a selective flow path between the interior and the exterior of the tubular and a throughbore isolation means; (ii) running the tubular into the wellbore; (iii) isolating an annulus between the exterior of the tubular and the wellbore to thereby create at least two isolated zones; (iv) selecting any zone to be fractured; (v) remotely opening the flow path in the portion of tubular corresponding to the selected zone; (vi) remotely isolating the throughbore of the tubular by closing the throughbore isolation means in the portion of tubular corresponding to the selected zone; and (vii) fracturing at least part of the formation surrounding the well.

Abstract: Stabilizers that include hydrophobically modified amine-containing polymers may be utilized as compositions or in methods for controlling particulate migration in a subterranean formation. For example, a method may include providing a treatment fluid that comprises a base fluid and a hydrophobically modified amine-containing polymer (HMAP), the HMAP comprising a plurality of hydrophobic modifications on an amine-containing polymer; introducing the treatment fluid into a wellbore penetrating a subterranean formation, the subterranean formation comprising a plurality of particulates; and allowing the HMAP to coat at least some of the particulates.

Abstract: Methods of treating a subterranean formation comprising placing a treatment fluid comprising a base fluid, proppant particulates, a consolidating agent, a thermoplastic material, and a degradable polyester material into the subterranean formation; coating the proppant particulates and the consolidating agent with the thermoplastic material and the degradable polyester material together so as to form proppant pillars; and degrading the degradable polyester material.

Abstract: A method of cementing in a subterranean formation comprising the steps of: (A) introducing a cement composition into the subterranean formation, the cement composition comprising: (i) cement; (ii) water; and (iii) a high-density additive selected from the group consisting of silicon carbide, sintered bauxite, and any combination thereof, wherein the cement composition has a density of at least 16 pounds per gallon; and (B) allowing the cement composition to set. According to an embodiment, the high-density additive is in a concentration of at least 30% by weight of the cement. A cement composition for use in an oil or gas well comprises: (A) cement; (B) water; and (C) a high-density additive selected from the group consisting of silicon carbide, sintered bauxite, and a combination thereof, wherein the high-density additive is in a concentration of at least 30% by weight of the cement, and wherein the cement composition has a density of at least 16 pounds per gallon.

Abstract: The invention relates to compositions and method for construction of an underground coal gasification (UCG) well liner assembly. In particular, a well liner segment for use in the construction of a UCG well liner assembly for conveying product gas to a production well is disclosed. Also disclosed are a system and method for UCG product gas production.

Abstract: A method of increasing the fracture resistance of a low permeability formation that includes emplacing a wellbore fluid in a wellbore through the low permeability formation, the wellbore fluid comprising: a settable carrier fluid; and a solid particulate bridging material; increasing the pressure in the wellbore such that fractures are formed in the formation; allowing the settable carrier fluid to enter the fractures; bridging and sealing the mouths of the fractures to form a substantially impermeable bridge proximate the mouth of the fractures thereby strengthening the formation; and holding the increased pressure for an amount of time sufficient for setting of the carrier fluid in the fractures is disclosed.

Abstract: A wellbore screen including: an apertured base pipe; an intermediate filtering layer including a plurality of metal fibers wrapped helically around the apertured base pipe and a fluid tracing filament wrapped helically about the apertured base pipe, the fluid tracing filament including a filament structure and a tracer carried by the filament structure, the tracer being entrainable in produced fluids in a wellbore environment; and an outer apertured shell over the intermediate layer. A method for producing a wellbore screen, the method comprising: forming a filter tube by wrapping an intermediate layer, including a metal wool fiber strip and a fluid tracing filament, about an apertured base pipe in a helical arrangement under tension; positioning the filter tube within the long bore of an outer apertured sleeve; and securing the outer apertured sleeve and the filter tube together.

Abstract: According to one aspect of the inventions, emulsion compositions are provided. Emulsions according to this aspect include: (a) a water-insoluble resinous material; (b) water; and (c) an emulsifier, wherein the emulsifier comprises a non-ionic, a cationic, or a zwitterionic emulsifier; wherein the continuous phase of the emulsion comprises the water; wherein a dispersed phase of the emulsion comprises the resinous material; wherein the dispersed phase is in the form of droplets having a size distribution range such that at least 50% of the droplets have a size of 0.5 micrometers-500 micrometers; wherein the resinous material of the droplets is in a concentration of at least 5% by weight of the water; and wherein the composition of the droplets has a viscosity of less than 2,000 Poise measured at 20° F. According to another aspect of the inventions, methods are provided for treating a portion of a subterranean formation.

Abstract: Anti-channeling pack-off particles used in a production section of an oil-gas well, a completion method, and a production method are provided. The anti-channeling pack-off particles are macromolecule polymer particles having an average particle diameter of 0.05-1.0 mm and a real density of 0.8-1.4 g/cm3. The particles are compactly filled into a space of the oil-gas well, which is required to be filled and packed off so that there is no channeling path after filling, thus effectively pack-off or sectioning the oil-gas well into multiple, relatively independent regions for production from the oil-gas well, and thus improving the production efficiency of the oil-gas well.

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: A well screen for use in a subterranean well can include a filter with a nano-particle reinforcement. A method of constructing a well screen can include treating a filter with a nano-particle reinforcement.

Abstract: A chopper mechanism for providing a fiber to a fluid at an oilfield. The chopper mechanism may be employed to process the fiber from an uncut form to a cut form in order to provide a mixture of the fluid and the fiber with flowback inhibiting character. Techniques of employing the chopper mechanism may be utilized at the site of an oilfield for applications such as fracturing, cementing, and drilling. Additionally, the chopper mechanism itself may be made available as a large high capacity chopper assembly, or a smaller handheld chopper gun for slower rate fiber supply operations.

Abstract: The invention provides a method and system for sealing an annulus enclosing a tubular element in a wellbore. The method comprises the steps of: i) introducing a first drilling fluid in the wellbore; ii) drilling an open hole section of the wellbore using a drilling tool suspended at the end of a tool string; iii) pumping a second drilling fluid comprising particles into the wellbore; iv) filtering the particles out of the second drilling fluid near a downhole end of the tubular element; v) extending the tubular element into the open hole section of the wellbore while directing at least part of the filtered particles to an annulus between the tubular element and a wellbore wall. Steps i) to v) may be repeated as often as required.

Abstract: A composite having a solid particulate and a surface modifying treatment agent on the solid particulate wherein the surface modifying treatment agent has a hydrophobic tail and an anchor for adhering the hydrophobic tail onto the solid particulate. The anchor may be metal and the hydrophobic tail may be an organo-silicon material, a fluorinated hydrocarbon or both an organo-silicon material and a fluorinated hydrocarbon. The composite may be used as a proppant in a hydraulic fracturing operation as well as a sand control particulate in a gravel packing operation. The presence of the surface modifying treatment agent on the surface of the solid particulate reduces the generation of fines and dust as well as the migration of sand during a hydraulic fracturing operation or a sand control operation. The presence of the surface modifying treatment agent on the surface of the solid particulate further enhances the crush resistance of the solid particulate.

Abstract: A composite having a solid particulate and a surface modifying treatment agent on the solid particulate wherein the surface modifying treatment agent has a hydrophobic tail and an anchor for adhering the hydrophobic tail onto the solid particulate. The anchor is an organophosphorus acid derivative. The composite may be used as a proppant in a hydraulic fracturing operation as well as a sand control particulate in a gravel packing operation. The presence of the surface modifying treatment agent on the surface of the solid particulate reduces the generation of fines and dust as well as the migration of sand during a hydraulic fracturing operation or a sand control operation. The presence of the surface modifying treatment agent on the surface of the solid particulate further enhances the crush resistance of the solid particulate.

Abstract: In a completion for producing methane the bottom hole assembly has a base pipe with porous media surrounding it for equalizing flow along the base pipe. A shape memory polymer foam surrounds the porous media. The borehole can be reamed to reduce produced methane velocities. Surrounding the shape memory polymer is an exterior layer of consolidated proppant or sand that can self-adhere and/or stick to the polymer foam. The proppant or sand can be circulated or squeezed into position although, circulation is preferred. The borehole may enlarge due to shifting sands in an unconsolidated formation as the methane is produced. The bottom hole assembly helps in fluid flow equalization and protects the foam and layers below from high fluid velocities during production.

Abstract: In one aspect, a method of forming a shape conforming material is disclosed that in one non-limiting embodiment may include: providing a base shape memory material having a glass transition temperature; and adding a selected amount of heat transfer nanoparticles to the base shape conforming material to provide the shape conforming material. In one aspect, the heat transfer nanoparticles include a core and a shell, wherein the core has a melting point below the glass transition temperature of the base shape memory material and the melting point of the shell.

Abstract: A downhole tool includes an outer tubular member and an inner tubular member. The outer tubular member may have one or more screens coupled thereto, a packer coupled thereto, and a shunt tube isolation valve coupled thereto. A first sleeve may be coupled to the packer and move from a first position to a second position. The packer may actuate into a set state when the first sleeve is moved to the second position, and the packer may isolate first and second portions of an annulus from one another when in the set state. A shunt tube may be coupled to the packer and provide a path of fluid communication from the first portion of the annulus, through the packer, and to the second portion of the annulus when the packer is in the set state.

Abstract: Disclosed are coated particles, such as proppants, processes for their preparation and methods for using such particles, such as in a hydraulic fracturing process. The coated particles include a coating that includes a crystalline or semicrystalline polyester/polyurethane having a decrystallization temperature of at least 35° C.

Abstract: Composition and methods using the compositions are disclosed, where the compositions include heterocyclic aromatic amines, substituted heterocyclic aromatic amines, poly vinyl heterocyclic aromatic amines, co-polymers of vinyl heterocyclic aromatic amine and non amine polymerizable monomers (ethylenically unsaturated mononers and diene monomers), or mixtures or combinations thereof in the absence of phosphate esters, optionally ethoxylated alcohols, and optionally, which form alter self-aggregating properties and/or aggregation propensities of the particles, surfaces, and/or materials.

Abstract: Energized slurries (including foams) comprising an Apollonian particle mixture and at least one additive selected from the group consisting of viscosifiers, gelling agents and rheological agents. Also, methods, fluids, equipment and/or systems for treating a subterranean formation penetrated by a wellbore, relating to treatment fluids based on the energized slurries.

Abstract: A flow control device is disclosed. The device includes a tubular member having a plurality adjacent wraps, wherein each wrap has an outer surface and an inner surface. Some of the wraps include one or more flow control paths, wherein each such flow control path includes a tortuous path to control flow of a fluid from the outer surface to the inner surface.

Abstract: In one aspect, a flow control device is disclosed that in one embodiment may include a sand screen that includes adjacent wraps of a longitudinal member, wherein the longitudinal member has a width, a first axial side and a second axial side, the longitudinal member further including spaced apart standoffs along the first axial side and spaced apart channels that provide fluid paths from the second axial side to the first axial side.

Abstract: Methods of treating a portion of a well include the steps of: (A) depositing a solid particulate into the portion of the well, wherein the solid particulate comprises an aliphatic polyester, preferably a polylactide; and (B) contacting the particulate deposited in the portion of the well with a treatment fluid comprising: (i) water; (ii) a source of a strong alkali; and (iii) a source of a strong oxidizer. The steps of depositing and contacting can be with a single treatment fluid or separate treatment fluids.

Abstract: The flow of a fluid may be diverted from a high permeability zone to a low permeability portion of a subterranean formation by use of particulates comprising a mixture of (i) at least one aliphatic polyester having the general formula of repeating units: where n is an integer between 75 and 10,000 and R is selected from the group consisting of hydrogen, alkyl, aryl, alkylaryl, acetyl, heteroatoms, and mixtures thereof; and (ii) at least one compound of the formula: or an anhydride thereof wherein: R1 is —COO—(R5O)y—R4 or —H; R2 and R3 are selected from the group consisting of —H and —COO—(R5O)y—R4; provided both R2 or R3 are —COO—(R5O)y—R4 when R1 is —H and further provided only one of R2 or R3 is —COO—(R5O)y—R4 when R1 is —COO—(R5O)y—R4 R4 is —H or a C1-C6 alkyl group; R5 is a C1-C6 alkylene group; and each y is 0 to 5.

Abstract: A method of wellbore strengthening may include providing a wellbore strengthening fluid comprising a drilling fluid, a particulate, and a fiber; introducing the wellbore strengthening fluid into a wellbore penetrating a subterranean formation; and forming a plug comprising the particulate and the fiber in a void near the wellbore, the plug being capable of maintaining integrity at about 1000 psi or greater overbalance pressure.

Abstract: Fluids with high carrying capacity for particulates in high pressure environments that may also be high temperature environments may include a viscosified base fluid having a density of about 14 ppg to about 20 ppg and comprises an aqueous fluid, a salt, a gelling agent, and an oxygen scavenger. Such fluids may be utilized in methods that involve providing a sand control screen assembly disposed within a wellbore penetrating a subterranean formation; and forming a gravel pack proximal to the sand control screen assembly with a treatment fluid, wherein the treatment fluid comprises the viscosified base fluid and a plurality of particulates.

Abstract: The present invention relates to methods for hydraulically fracturing a subterranean formation to improve the production rates and ultimate recovery by contacting unconsolidated resin-coated proppant particulates residing in a propped fracture with a reactive crosslinker in order to form a consolidated proppant pack. The present invention also relates to methods for use in water injection wells to consolidate the resin-coated proppant particulates in a gravel packed or frac packed region of a wellbore.

Abstract: A method for treating a zone of a subterranean formation penetrated by a wellbore, the method including the steps of: (A) introducing a treatment fluid through the wellbore into the zone of the subterranean formation, wherein the treatment fluid comprises an alkoxysilane having at least two alkoxy groups; (B) shutting in the zone to allow the alkoxysilane to hydrolyze in the formation under the design conditions; and (C) before or after introducing the treatment fluid into the zone, installing a mechanical sand control device in the wellbore of the zone.

Abstract: Treatments and compounds can be useful in subterranean formations where particulates and/or surfaces may be subject to silica scale build-up. Certain embodiments pertain to utilizing silica scale control additives with particulate packs. Of these, certain methods may treat particulate packs in a subterranean formation with silica scale control additives, certain methods may combine silica scale control additives with particulates prior to formation of a particulate pack, and certain compounds may provide the features of both silica scale control additives and particulates.

Abstract: A borehole completion method treats a formation surrounding a borehole with a chemical treatment that alters how formation particulates interact. A standalone screen deploys downhole in the borehole (either before or after the treatment) on a downhole string. When fluid is produced, formation particulates treated with the chemical treatment agglomerate in the annulus surrounding the screen in permeable structures. This can be especially when the standalone screen is useful in a cased hole having perforations. The chemical treatment includes an inner salt adapted to neutralize the zeta potential (i.e., electrokinetic potential) of the formation particulates so they aggregate into one or more permeable structures in the annulus.

Abstract: A cascading liquid air removal filter system is disclosed. Said system comprising a filter system having a bristles element. Said bristle element comprises a plurality of bristles each having a first end and a second end. Said bristles element comprises a plurality of fluid passages between said bristles. Said filter system is attached to a column of a well having one or more sections, between said column and a casing of said well. Said filter system comprises a filter outside diameter. Said casing comprises a casing internal diameter. Said filter outside diameter is equal to or larger than said casing internal diameter. Said fluid passages comprise a plurality of non-linear paths through said bristles element for a liquid passing through said filter system. Said filter system provides only said non-linear paths for said liquid to travel from a first end to a second end of said filter system.

Abstract: A permeable material compacting method includes, positioning a portion of at least one elongated member within the interior of a tubular, moving a portion of the at least one elongated member through the interior of the tubular, moving a permeable material through the interior of the tubular with the portion of the at least one elongated member, and radially compacting the permeable material as the permeable material passes through the interior of the tubular.

Abstract: Methods for reducing fines migration in a porous subterranean reservoir are disclosed. In certain aspects, the methods include introducing a composition comprising a water-soluble or dispersible branched polyhydroxyetheramine into the porous subterranean reservoir, maintaining a sufficient temperature in the porous subterranean reservoir for a period of time, adsorbing the composition onto a surface of the porous subterranean reservoir, and stabilizing at least a portion of the fines present in the porous subterranean reservoir. Methods for enhancing an effective permeability of a porous subterranean reservoir are also disclosed. In connection with the disclosed methods, a treatment composition can be used and in certain aspects, the treatment composition can be a reaction product of bisphenol A, an ethanol amine, diethanol amine, and a monofunctionalized polyoxyalkyleneamine.

Abstract: The present invention provides a method for the treatment of a subterranean formation which contains sand particles, said method comprising contacting said formation with a material capable of increasing the residual matrix strength of said particulate fine whereby to reduce or prevent their migration whilst minimizing any decrease in their permeability. Preferred materials include organosilanes and enzyme systems.

Abstract: A borehole completion method treats a formation surrounding a borehole with a chemical treatment that alters how formation particulates interact. A standalone screen deploys downhole in the borehole (either before or after the treatment) on a downhole string. When fluid is produced, formation particulates treated with the chemical treatment agglomerate in the annulus surrounding the screen in permeable structures. This can be especially when the standalone screen is useful in a cased hole having perforations. The chemical treatment includes an inner salt adapted to neutralize the zeta potential (i.e., electrokinetic potential) of the formation particulates so they aggregate into one or more permeable structures in the annulus.

Abstract: A filter (13) is provided at a tip portion of an injection well (9). A pumping apparatus (5) pumps carbon dioxide stored in a carbon dioxide tank (3). The pumping apparatus (5) feeds carbon dioxide from the carbon dioxide tank (3) into the injection well (9) by means of a pump. In the pumping apparatus, the pressure and temperature of carbon dioxide are maintained at respective predetermined levels or higher by means of a pressure regulation valve, a temperature regulator, etc., whereby carbon dioxide enters a supercritical state. The carbon dioxide having entered a supercritical state is fed in the direction of arrow A through the injection well (9), passes through the filter (13) provided at an end portion of the injection well (9), and is injected into a brine aquifer (11). Carbon dioxide injected into the brine aquifer (11) assumes the form of microbubbles.

Abstract: Of the methods provided herein, one example of a method that is disclosed includes the steps of placing a stand-alone-screen that does not comprise a concentric washpipe in a well bore, and forming an in situ coated stand-alone-screen in the well bore by placing a screen-plugging filter cake on the interior surface of the stand-alone-screen, the screen-plugging filter cake comprising particulate plugging agents deposited by a packing slurry.

Abstract: A completion joint 100 has a sand control jacket 120 and an inflow control device 130. The jacket 120 communicates screened fluid with a housing of the inflow control device 130. The basepipe's flow openings 118 are isolated in the housing from the screened fluid by flow devices 170. The flow devices 170 are externally accessible on the device's housing to selectively configure the flow devices 170 open or closed.

Abstract: The present invention provides a method for the treatment of a subterranean formation which contains sand particles, said method comprising contacting said formation with a material capable of increasing the residual matrix strength of said particulate fine whereby to reduce or prevent their migration while minimizing any decrease in their permeability. Preferred materials include organosilanes and enzyme systems.

Abstract: Delayed-tackifier coated particulates and treatment fluids comprising delayed-tackifier coated particulates wherein the tackifier is associated with a surfactant. The treatment fluids may be used in methods that include providing a treatment fluid that comprises an aqueous base fluid and a delayed-tackifier coated particulate and introducing that treatment fluid into a wellbore penetrating a subterranean formation. Once within the formation, forming a particulate pack, wherein the particulate pack is a gravel pack along a portion of the wellbore, a proppant pack within a portion of the subterranean formation, or both.

Abstract: The present invention involves methods of using particulates coated with a tackifying agent that need not be used immediately once they are prepared and that provide increased viscosity when placed into an aqueous fluid. The described methods include the steps of contacting particulates with a tackifying agent to create tackified particulates; contacting the tackified particulates with a partitioning agent to form coated particulates that are capable of being stored for a time period, wherein the partitioning agent comprises a hydratable polymeric material; and, placing the coated particulates in an aqueous treatment fluid whereby the partitioning agent hydrates and increases the viscosity of the treatment fluid.

Abstract: Generally, a consolidating treatment fluid includes at least an aqueous base fluid and an ultra-dilute water-based curable resin. The consolidating treatment fluid may be used in a plurality of subterranean operations to consolidate the unconsolidated particles within the subterranean formation.

Abstract: A method of forming a gelled liquid hydrocarbon treatment fluid is disclosed. The method comprises combining a liquid hydrocarbon, a phosphoric acid ester and a pre-mixed solution comprising water, ferrous ion (Fe2+) and an amine; and forming the gelled liquid hydrocarbon treatment fluid. A method of treating a portion of a subterranean formation is also disclosed and comprises: providing a gelled liquid hydrocarbon treatment fluid, by combining a liquid hydrocarbon, a phosphoric acid ester and a pre-mixed solution comprising water, ferrous ion and an amine, and treating the portion of the subterranean formation with the gelled liquid hydrocarbon treatment fluid.

Abstract: An embodiment of an apparatus may include a permeable member made by combining a particulate additive to one or more materials, which materials when processed without the particulate additive form a substantially impermeable mass, wherein the permeable member inhibits flow of solid particles above a particular size through the permeable member.