Abstract: A composition for lost circulation material (LCM) usable in subsurface well intervention includes particles of a hydrated superabsorbent polymer (SAP) mixed with an aqueous solution of a salt tolerant osmotic barrier polymer. A method for stopping fluid loss from a well into a formation penetrated by the well includes pumping a selected volume of the composition into the well until the selected volume is adjacent to the formation.

Abstract: Coated proppants include a proppant particle, a surface copolymer layer surrounding the proppant particle, and a resin layer surrounding the surface copolymer layer. The surface copolymer layer includes a copolymer of at least two monomers chosen from styrene, methyl methacrylate, ethylene, propylene, butylene, imides, urethanes, sulfones, carbonates, and acrylamides, where the copolymer is crosslinked by divinyl benzene. The resin layer includes a cured resin.

Abstract: Hydrophobic particles such as coal and hydrophobized mineral fines can be readily separated from hydrophilic impurities by forming agglomerates in water using a hydrophobic liquids such as oil. The agglomerates of hydrophobic particles usually entrap large amounts of water, causing the moisture of the recovered hydrophobic particles to be excessively high. This problem can be overcome by dispersing the hydrophobic agglomerates in a hydrophobic liquid that can be readily recycled. The dispersion can be achieved using specially designed apparatus and methods that can create a turbulence that can help destabilize the agglomerates in a recyclable hydrophobic liquid and facilitate the dispersion.

Abstract: A method of fracturing multiple productive zones of a subterranean formation penetrated by a wellbore is disclosed. The method comprises injecting a fracturing fluid into each of the multiple production zones at a pressure sufficient to enlarge or create fractures in the multiple productive zones, wherein the fracturing fluid comprises an upconverting nanoparticle that has a host material, a dopant, and a surface modification such that the upconverting nanoparticle is soluble or dispersible in water, a hydrocarbon oil, or a combination thereof; recovering a fluid from one or more of the multiple production zones; detecting the upconverting nanoparticle in the recovered fluid by exposing the recovered fluid to an excitation radiation having a monochromatic wavelength; and identifying the zone that produces the recovered fluid or monitoring an amount of water or oil in the produced fluid by measuring an optical property of the upconverting nanoparticle in the recovered fluid.

Abstract: The present invention discloses a method for proppant suspension and suspension parameter optimization based on bubble bridge effect, comprising: select a proppant and hydrophobically modify its surface to obtain a hydrophobically surface-modified proppant; prepare a bubbly fracturing base fluid; make the first optimization of the base fluids according to the average radius of the proppant and the average radius of the bubbles of the base fluids; optimally select the base fluids selected for the second time according to the interaction energy between the proppant particle and the bubble after the hydrophobically surface-modified proppant mixed with the base fluid; the basic parameters of the bubbly fracturing base fluid selected at the third time were used for the perfect selection for proppant suspension. The present invention establishes a procedure on experimental evaluation and parameter calculation optimization by suspending fracturing proppant with the bubble bridge effect on the hydrophobic surface.

Abstract: Compositions and methods for treating kerogen in a subterranean formation by generating bromine and other halogens in situ in a subterranean formation. In some implementations, the generation of the bromine or halogen is delayed. This can occur, for example, by the decomposition of precursors, a chemical reaction, the encapsulation of precursors or reactants, or a combination of these approaches.

Abstract: A polymeric scale inhibitor composition and a method for inhibiting metal sulfide scale formation in a well are provided. The composition includes 80-82 mol % of a first monomeric unit, where the first monomeric unit is 2-acrylamido-2-methylpropane sulfonic acid (AMPS). The composition also includes 2-18 mol % of a second monomeric unit selected from N-vinyl formamide, N-vinyl pyrrolidone, and diallyl dimethyl ammonium chloride. The composition further includes 2-18 mol % of a third monomeric unit selected from acrylic acid, methacrylic acid, esters of acrylic acid or methacrylic acid with an alcohol having 1 to 4 carbon atoms, and carboxyethyl acrylate. The polymeric scale inhibitors show superior adsorption characteristics on rocks and their subsequent release behavior allows for scale inhibition over extended time periods respectively at a significant volume of coreflood fluids. They are especially suited for downhole application via field scale squeeze treatments.

Abstract: Provided are a hydrocarbon production method and a hydrocarbon production apparatus that, in a mining process, can transport proppant efficiently even if the viscosity is low and can prevent microbial contamination, and, in a desulfurization process, can improve the efficiency of desulfurization. This hydrocarbon production method comprises a hydrocarbon well mining step in which hydraulic fracture fluid is used to break up bedrock by hydraulic pressure and mine the hydrocarbon embedded in the interior of the bedrock, and a desulfurization step in which sulfur contained in the hydrocarbon mined in the mining step is removed, wherein: the hydraulic fracture fluid contains a base fluid, a proppant that supports a fracture 110, and a thickener; and air bubbles less than 100 ?m in size (diameter) under normal pressure are caused to be jointly present in the hydraulic fracture fluid.

Abstract: Disclosed are compositions and methods for the pressure protection of existing wells during infill drilling operations. The methods can include injecting a gas into the existing wellbore in fluid communication with an unconventional subterranean formation prior to and/or during fracturing of the new wellbore in fluid communication with the unconventional subterranean formation.

Abstract: Disclosed are compositions and methods for the pressure protection of existing wells during infill drilling operations. The methods can include injecting a foamed pressure protection composition into the existing wellbore in fluid communication with an unconventional subterranean formation prior to and/or during fracturing of the new wellbore in fluid communication with the unconventional subterranean formation.

Abstract: Methods and compositions for treating aqueous fluids that may be included in treatment fluids that are used for treating a subterranean formation. In some embodiments, the methods include: providing a water-based friction reducing additive that includes an aqueous base fluid, a salt, a first friction reducing polymer, and a suspension agent; introducing the water-based friction reducing additive into a treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation at a pressure sufficient to create or enhance one or more fractures within the subterranean formation.

Abstract: Disclosed herein are compositions and methods for increasing recovery, or flowback, of hydrocarbon compounds from hydrocarbon-containing subterranean reservoirs. The flowback compositions include an anionic sulfonated surfactant, an amphoteric surfactant, water, and a coupling agent. The flowback compositions convert oil-wet rocks to water-wet, yet exhibit a low tendency of composition components to sorb to the rock. The flowback compositions do not cause formation of emulsions with hydrocarbon compounds within the subterranean environment. The flowback compositions are particularly useful for increasing the yield of hydrocarbons recovered from tight shale reservoirs.

Abstract: A method of fracturing multiple productive zones of a subterranean formation penetrated by a wellbore is disclosed. The method comprises injecting a fracturing fluid into each of the multiple production zones at a pressure sufficient to enlarge or create fractures in the multiple productive zones, wherein the fracturing fluid comprises an upconverting nanoparticle that has a host material, a dopant, and a surface modification such that the upconverting nanoparticle is soluble or dispersible in water, a hydrocarbon oil, or a combination thereof; recovering a fluid from one or more of the multiple production zones; detecting the upconverting nanoparticle in the recovered fluid by exposing the recovered fluid to an excitation radiation having a monochromatic wavelength; and identifying the zone that produces the recovered fluid or monitoring an amount of water or oil in the produced fluid by measuring an optical property of the upconverting nanoparticle in the recovered fluid.

Abstract: Methods and compositions for suppressing fugitive dust are provided herein. To suppress fugitive dust, particulate materials, dust and or substrates can be treated with a mixture having a hydrophobizing agent and an oil. The hydrophobizing agent can be an organo- or halosilane, a tallow alkylamine, an amine-functionalized polysiloxane, or an amine-functionalized hydrophobic polymer.

Abstract: Methods for treating subterranean formations are provided. In one embodiment, the methods comprise providing a treatment fluid comprising an aqueous base fluid and a surfactant comprising an ethoxylated amine or derivative thereof; introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation; and producing fluids from the wellbore during or subsequent to introducing the treatment fluid into the wellbore.

Abstract: An ultra-high temperature fracturing fluid, including the following components in mass percentages: 0.4 wt %-0.8 wt % of a polymer thickener, 0.015 wt %-0.02 wt % of a non-metallic crosslinking agent, 0.04 wt %-0.06 wt % of a gel breaker and the rest is water. The polymer thickener is obtained by a polymerization of acrylamide, acrylic acid, 2-acrylamido-2-methylpropanesulfonic acid, rigid monomer and cationic hydrophobic monomer in a weight ratio of 55-70:15-20:15-20:0.5-3:0.1-1.0, the polymerization temperature is 30-40° C. and the polymerization time is 8-10 hours. The fracturing fluid of the present invention can effectively solve the technical problems that traditional fracturing fluids are easily decomposed at high temperatures and affect performance.

Abstract: The present invention relates to a method for reducing solvent retention in ES-SAGD process so as to increase process economics wherein an anti-retention agent is injected into the reservoir to decrease solvent retention in the reservoir. The anti-retention agent can be made pre-injection or can form in situ, and comprises an agent in which the solvent is readily soluble, such that the solvent partitions into the foam, colloidal dispersion, or gel, and out of the condensed water or steam, and away from the reservoir rock.

Abstract: The present technology relates to compositions and related methods for stabilizing surfactants capable of increasing liquid hydrocarbon production from subterranean reservoirs. In some embodiments, the technology relates to the stabilization of sulfonate based surfactants for enhanced oil recovery (“EOR”) operations. In certain embodiments, the sulfonate based surfactants are characterized by increased thermal and chemical stability under crude oil recovery conditions.

Abstract: The present invention relates to the field of oilfield chemistry, and discloses a composition for fracturing and displacement and a method for fracturing and displacement of a tight oil reservoir. The composition contains a pyrrolic compound represented by formula (1) and a laurate; in the formula (1), M? is halide ion, R1 is C1-C5 linear or branched alkyl, and R2 is C15-C20 linear or branched alkyl. The composition for fracturing and displacement provided in the present invention has functions of fracturing, solid carrying, imbibition, drainage and oil displacement, so as to maximize the recovery efficiency of tight oil, and attain economic and social benefits by implementing multiple functions with a single composition, saving resources, and reducing cost.

Abstract: An oil-phase-free triple-play slick water concentration system, is characterized by first synthesizing a water-soluble dispersion polymer drag reducer A; and then preparing an inorganic salt solution B, under mechanical agitation, of high-performance water-soluble fluorocarbon surfactant and a water-soluble of high-performance small molecule or macromolecule clay stabilizer containing quaternary ammonium ions; and finally, the aqueous inorganic salt solution B is slowly added to the drag reducer dispersion A, wherein the ratio of the aqueous inorganic salt solution B and the dispersion A is 20-80:80-20.

Abstract: A multifunctional slick water concentrate, is obtained by “W/W” dispersion polymerization at elevated temperature, wherein water-soluble monomer A1, water-soluble fluorocarbon surfactant A2, water-soluble quaternary ammonium clay stabilizer A3, water-soluble dispersant A4, water-soluble free radical initiator A5, inorganic salt A6 and water A7, is first formed a homogeneous system under mechanical agitation; wherein, the percentage of the weight of each respective component, relative to the total weight of the reaction system, is as the following: water-soluble monomer A1: 5.0-20.0%; water-soluble fluorocarbon surfactant agent A2: 0.1-5.0%; water-soluble quaternary ammonium clay stabilizer A3: 0.1-20.0%; water-soluble dispersant A4: 0.1-10.0%; water-soluble radical initiator A5: 0.000001-0.100%; inorganic salt A6: 15.0-40.0%; water A7: remainder.

Abstract: A process is disclosed which includes separating selected solids from a process stream with a selected solids mechanical processor containing a filter to produce a filtrate substantially free of selected solids and a retentate containing recovered selected solids. In one embodiment, the process stream contains an increased amount of liquid is provided to a downstream mechanical processor as compared to a process stream having no selected solids mechanical processor upstream. The selected solids mechanical processor can be a dynamic filtration device or a static separation device. Bio-oil recovery efficiency, quantity, and quality can be improved as a result.

Abstract: Methods for reducing the amount of water produced from a subterranean formation can include the use of a gellable treatment fluid that comprises a quaternary ammonium salt as a gel-time modifier. The gellable treatment fluids can comprise an aqueous base fluid, a base polymer comprising an acrylamide monomer unit, an organic crosslinking agent, and a gel-time modifier comprising a quaternary ammonium salt.

Abstract: The disclosure relates to liquid nitrogen pump equipment load testing and experimenting apparatus, and testing and experimenting method thereof, used for oil-gas fields or coalbed methane nitrogen foam fracturing equipment testing. A hydraulic damping apparatus unit and a pressure regulation unit are provided; the hydro-mechanical damping apparatus unit comprises a water tank, a pump unit apparatus, and a pipe manifold system connected in sequence.

Abstract: Methods for reducing the amount of water produced from a subterranean formation can include the use of a gellable treatment fluid that comprises a gel-time modifier comprising at least one amino group. The gellable treatment fluids can comprise an aqueous base fluid, a base polymer comprising an acrylamide monomer unit, an organic crosslinking agent, and a get-time modifier comprising at least one amino group.

Abstract: This invention relates generally to novel foamer compositions for treatment of oil and gas wells to enhance production. The invention provides a method of foaming a fluid. The method includes introducing into the fluid a foam-forming amount of a composition comprising at least one long chain fatty acid and at least one organic solvent. An example of the long chain fatty acid is tall oil fatty acid and an example of the organic solvent is ethyleneglycol monobutyl ether.

Abstract: A treatment fluid comprises: a liquid fluorinated compound; and at least one additive, wherein the additive: (A) comprises carbon and at least one fluorine functional group; and (B) is soluble or dispersible in the liquid fluorinated compound. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

Abstract: Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus.

Abstract: Provided herein are inter alia novel compositions and methods having application in a variety of fields including the field of enhanced oil recovery, the cleaning industry as well as groundwater remediation. In particular, the alkoxy carboxylate compounds and mixtures thereof presented herein can be used, inter alia, for the recovery of a large range of crude oil compositions from challenging reservoirs.

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: The present invention generally provides systems, methods, and compositions comprising an emulsion or a microemulsion and chlorine dioxide for use in oil and/or gas wells. In some embodiments, the systems, methods, and/or compositions comprise reducing the viscosity a fluid comprising a polymer, wherein the fluid was utilized in the recovery of oil and/or gas from the oil and/or gas well.

Abstract: Provided herein is a composition comprising carbon dioxide, an aqueous phase, and reverse micelles, wherein the reverse micelles comprise a metal cation-chelating agent, and a metal cation; and methods of using said composition for sequestering carbon dioxide and/or recovering hydrocarbons from a hydrocarbon reservoir.

Abstract: A polymer solution is mechanically mixed with at least one surfactant solution under conditions preventing air access. The produced polymer-surfactant solution is saturated with a gas by increasing pressure to a value ensuring complete gas dissolution and exceeding an expected pressure of use of aphrons. Then, the pressure is rapidly reduced to a value corresponding to the expected pressure of use of the aphrons and narrow size distribution aphrons are produced.

Abstract: Propping compositions comprising: a hardenable, liquid external phase comprising an element selected from the group consisting of: a cement, a cement foam, a polymer, a resin, an aluminum, a flowable carrier fluid, and any combination thereof; and an internal phase that is either gas or liquid and that is immiscible with the external phase; wherein the internal phase exits the propping composition as the hardenable external phase hardens, leaving behind an hardened, interconnected porous network. Some propping compositions may require contact with a treatment for removal from the hardenable external phase and the treatment for removal may comprise at least one material selected from the group consisting of: an acid, a base, a chelant, an oxidizer, a solvent, and any combination thereof.

Abstract: Phosphate brine compositions reduce hydrate formation in flowlines under conditions conducive for hydrate formation in the absence of the phosphate, where the phosphate brines include a compatible anti-corrosion system and may include nitrate brines.

Abstract: Nitrate brine compositions reduce hydrate formation in flowlines under conditions conducive for hydrate formation in the absence of the nitrate brines, where the nitrate brines include compatible anti-corrosion system.

Abstract: Sulfate and sulfonate derivatives of unsaturated fatty alcohols, processes for making them, and methods of using them are disclosed. In one aspect, a monounsaturated fatty alcohol composition is made by reducing a metathesis-derived monounsaturated alkyl ester. The fatty alcohol composition is then converted to a sulfate or sulfonate derivative by one or more of alkoxylation, sulfation, sulfonation, and sulfitation. Of particular interest are the sulfate and ether sulfate derivatives.

Abstract: Polyglycolic acid resin short fibers for a well treatment fluid, the fibers having the following characteristics of (a) to (e): (a) an outside diameter of 5 to 300 ?m; (b) a fiber length of 1 to 30 mm; (c) fineness of 0.1 to 25 D; (d) strength of 1 to 20 gf/D; and (e) a ratio of an area of the polyglycolic acid resin with respect to an area of a circle circumscribing a cross section of the fibers being from 10 to 95%; and a well treatment fluid containing the polyglycolic acid resin short fibers for a well treatment fluid.

Abstract: A process for producing a purified synthesis gas stream from a feed synthesis gas stream comprising besides the main constituents carbon monoxide and hydrogen also hydrogen sulphide, HCN and/or COS, the process comprising the steps of: (a) removing HCN and/or COS by contacting the feed synthesis gas stream with a catalyst in a HCN/COS reactor in the presence of steam/water, to obtain a synthesis gas stream depleted in HCN and/or in COS; (b) converting hydrogen sulphide in the synthesis gas stream depleted in HCN and/or in COS to elemental sulphur, by contacting the synthesis gas stream with an aqueous reactant solution containing solubilized Fe(III) chelate of an organic acid, at a temperature below the melting point of sulphur, and at a sufficient solution to gas ratio and conditions effective to convert H2S to sulphur and inhibit sulphur deposition, to obtain a synthesis gas stream depleted in hydrogen sulphide; (c) removing carbon dioxide from the synthesis gas stream depleted in hydrogen sulphide, to obta

Abstract: The present invention relates to a foam containing water, between 5 and 30 wt % on total weight of the foam of a chelating agent selected from the group of glutamic aid N,N-diacetic acid or a salt thereof (GLDA), aspartic acid N,N-diacetic acid or a salt thereof (ASDA), methylglycine N,N-diacetic acid or a salt thereof (MGDA), N-hydroxyethyl ethylenediamine-N,N?,N?-triacetic acid or a salt thereof (HEDTA), a foaming agent, and at least 25 vol % on total volume of the foam of a gas, and having a pH of between 2 and 5, to a viscosified composition containing water, between 5 and 30 wt % on total volume of the composition of a chelating agent selected from the group of glutamic aid N,N-diacetic acid or a salt thereof (GLDA), aspartic acid N,N-diacetic acid or a salt thereof (ASDA), methylglycine N,N-diacetic acid or a salt thereof (MGDA), N-hydroxyethyl ethylenediamine-N,N?,N?-triacetic acid or a salt thereof (HEDTA), and at least 0.

Abstract: A well treatment additive includes a siloxane surfactant, a solvent and an aqueous phase. The solvent, in some embodiments, is a terpene hydrocarbon. Also disclosed is a method for using the well treatment additive to form and enhance the properties of foams useful for the treatment of oil and gas wells. Methods of using the novel well treatment foams include using the additives in a variety of well treatment processes including, but not limited to, acidizing operations, hydraulic fracturing operations, well remediation operations and water removal operations.

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: 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: Foamable epoxy-based zonal isolation sealing compositions include epoxy resin and a blowing agent and methods for isolating zones in borehole of oil and gas wells using the compositions, where the foam nature of the cured seals provide sufficient compressibility and resiliency to be used with expandable tubing without substantial loss in sealant integrity and in squeeze operations.

Abstract: A wellbore treatment fluid is formed from an aqueous medium, a gas component, a viscosifying agent, and a surfactant. The surfactant is represented by the chemical formula: [R—(OCH2CH2)m—Oq—YOn]pX wherein R is a linear alkyl, branched alkyl, alkyl cycloaliphatic, or alkyl aryl group; O is an oxygen atom; Y is either a sulfur or phosphorus atom; m is 1 or more; n is a integer ranging from 1 to 3; p is a integer ranging from 1 to 4; q is a integer ranging from 0 to 1; and X is a cation. The fluid may be used in treating a subterranean formation penetrating by a wellbore by introducing the fluid into the wellbore. The fluid may be used in fracturing a subterranean formation penetrated by a wellbore by introducing the fluid into the formation at a pressure equal to or greater than the fracture initiation pressure.

Abstract: A method of servicing a wellbore comprising providing a flowable component comprising syntactic foam, and communicating the flowable component into a wellbore.

Abstract: A treatment fluid comprising: water; a formate; and a corrosion inhibitor, wherein the corrosion inhibitor is capable of providing: (A) a pH of at least 10; and (B) a corrosion rate equal to or less than 4 mils per year wherein carbon dioxide accounts for at least 100 psi (0.7 MPa) of the total pressure, for a test fluid consisting essentially of: the water; the formate; and the corrosion inhibitor, and in the same proportions as in the treatment fluid, whereas a substantially identical test fluid without the corrosion inhibitor has a pH of less than 10 and a corrosion rate of greater than 4 mils per year under the testing conditions. The treatment fluid can further comprise a scale inhibitor. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

Abstract: A treatment fluid comprising: water; a formate; and a corrosion inhibitor, wherein the corrosion inhibitor is capable of providing: (A) a pH of at least 10; and (B) a corrosion rate equal to or less than 4 mils per year wherein carbon dioxide accounts for at least 100 psi (0.7 MPa) of the total pressure, for a test fluid consisting essentially of: the water; the formate; and the corrosion inhibitor, and in the same proportions as in the treatment fluid, whereas a substantially identical test fluid without the corrosion inhibitor has a pH of less than 10 and a corrosion rate of greater than 4 mils per year under the testing conditions. The treatment fluid can further comprise a scale inhibitor. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

Abstract: A hydraulic fracturing composition includes: a superabsorbent polymer in an expanded state; a plurality of proppant particles disposed in the superabsorbent polymer; an additive comprising a surfactant, a viscose polymer, or a combination thereof, and a fluid to expand the superabsorbent polymer into the expanded state. A process for disposing a plurality of proppant particles in a fracture comprises: disposing a hydraulic fracturing composition in a downhole environment; forming a fracture; disposing the hydraulic fracturing composition in the fracture; breaking the superabsorbent polymer after forming the fracture; and releasing the plurality of proppant particles from superabsorbent polymer. The process also comprises injecting a proppant-free fluid and a proppant-containing fluid in an alternating order into a subterranean formation.

Abstract: This invention discloses articles, in the form of particles to small granules to macro sized objects, capable of the controlled release of active ingredients (AI) from a mixture as a solid solution, a matrix or an encapsulated system containing AI and one or more of polymers, additives and/or carriers. The invention also covers additional surface coatings on those articles to further reduce the rate of release of AI. Finally, methods for producing these articles and treating the oil field well and other segments of the oil industry, for example piping, storage tank, and refinery locations, are introduced. The claimed articles can be used as is or mixed with other oil filed components or system, for example proppant fluid, in oil field applications.