Abstract: This disclosure relates to compositions including a poly-alkene maleic anhydride copolymer, a PEG, and a crosslinker selected from an ethyleneamine, a benzenetricarboxylic acid, a benzimidazole, and combinations thereof. The poly-alkene maleic anhydride copolymer includes repeat units I and II: where R1, R1?, R2, and R2? are each independently selected from —H and —(C1-C5)alkyl. The disclosure also provides methods of treating a subterranean formation or cement construction using the compositions.

Abstract: A composition for efficient metal chelation includes (i) a primary chelant; (ii) a coordination enhancing additive; and (iii) a solvent. A wellbore servicing fluid includes (i) a primary chelant; (ii) a coordination enhancing additive; and (iii) a solvent.

Abstract: Disclosed are alkyl lactone-derived hydroxyamides and alkyl lactone-derived hydroxyesters used in compositions and methods for inhibiting natural gas hydrate agglomerates. The alkyl lactone-derived hydroxyamides and alkyl lactone-derived hydroxyesters are reaction products of an alkyl lactone and an amine, and an alkyl lactone and an alcohol, respectively.

Abstract: Embodiments relate to use of graphite nanoplatelets (GnP) to enhance the mechanical and durability characteristics of cement that may be used as cement sheaths in wellbores of oil and gas wells. Generally, undesired permeability of cement is caused by diffusion of trapped oil and/or natural gas through the cementitious matrix of the cement, leading to material degradation of the cement. Methods disclosed involve using modified GnPs (having physically modified surfaces or chemically modified surfaces energies) to generate a cementitious nanocomposite with uniformly dispersed GnPs, which can effectively arrest the undesired diffusion mechanism. Modified GnPs can also increase the strength of interfacial adhesion (e.g., interfacial bonds and interfacial energies) between the GnP and the cement matrix (e.g., hydrations of the cement). Physical modification of GnP can involve non-covalent treatment techniques. Chemical modification of GnP can involve covalent treatment techniques.

Abstract: A composition is for making a drilling fluid a non-invasive drilling fluid. The composition has a first component comprising particles having a scratch hardness above 2 Mohs and a second component comprising particles selected from the group of fragmented seeds of Tamarindus indica, comminuted bark from Litsea glutinosa, or comminuted Ocimum tenuiflorum. Also disclosed is a non-invasive drilling fluid having the composition, and a method for drilling a wellbore.

Abstract: The disclosure belongs to the technical field of well completion engineering in oil and gas engineering, and particularly relates to a high-flow-conductivity proppant and its preparation method. The high-flow-conductivity proppant includes dumbbell-shaped framework granules and an oil-soluble film coating layer coated on the surfaces of the framework granules; the oil-soluble film coating layer melts when meeting oil at the temperature of 30-120° C. The high-flow-conductivity proppant prepared by the method has low bulk density, and the problems that the traditional proppant cannot be transported to the far end of a crack, has poor flow conductivity and the like can be effectively solved.

Abstract: A fluid for controlling the permeability of a subterranean formation having an aqueous solution of at least one thermo-responsive polymer with block structure A-B-A?, wherein A and A?, the same as or different from one another, each represent a thermo-responsive oligomer group, and B is an oligomer group having n repeat units, the same as or different from one another. At least one of the repeat units has a solubility of the corresponding monomer, in water at 20° C., equal to or greater than 120 g/l, and n is a whole number within the range 30-1000. The fluid is also used in a method for controlling the permeability of a subterranean formation.

Abstract: Described herein are methods for treating a subterranean formation penetrated by a wellbore with a retarded acidizing fluid containing an acid and an acid retarding agent, the concentrations of which are adjusted based on measured parameter values of the formation. Also described is a method for treating a subterranean formation by introducing an acid to the formation following the introduction of an acid retarding agent to the formation. Also described is a method for acid fracturing a subterranean formation including reducing the concentration of an acid retarding agent contained in a retarded acidizing fluid over the course of the acid fracturing operation.

Abstract: Methods for making and using an invert-emulsion drilling fluid, and the invert-emulsion drilling fluid are provided. An exemplary invert-emulsion drilling fluid includes a C-36 dimer diamine dihydrochloride salt (CDDH), an aqueous solvent, a non-aqueous solvent, an emulsifier, and calcium chloride.

Abstract: A method, system, and drilling fluid for treating a wellbore for filter cake removal, including providing the drilling fluid having thermochemical reagents that are encapsulated and acid-generating material that is encapsulated into a wellbore in a subterranean formation to attack filter cake in the wellbore, and attacking the filter cake via the drilling fluid.

Abstract: The solid electrolyte material of the present disclosure includes Li, M, O, X, and F. M is at least one element selected from the group consisting of Ta and Nb. X is at least one element selected from the group consisting of Cl, Br, and I.

Abstract: An oil soluble invert emulsifier and a process for preparation thereof, including invert emulsion drilling fluid compositions and their use, are described. The oil soluble invert emulsifier is synthesized from fatty acid reaction with polyalkylene polyamines and unsaturated mono carboxylic acids. The emulsifier is further modified with multivalent alkali metal salts. The emulsifier stabilizes the invert emulsion drilling fluid at temperatures exceeding 400° F. and imparts improved fluid properties.

Abstract: Provided is a lithium secondary battery including a positive electrode layer composed of a cobalt-containing lithium composite oxide sintered body, a negative electrode layer composed of a titanium-containing sintered body, a ceramic separator interposed between the positive electrode layer and the negative electrode layer, an electrolyte impregnating at least the ceramic separator, and an exterior body having a closed space and accommodating the positive electrode layer, the negative electrode layer, the ceramic separator, and the electrolyte within the closed space. The positive electrode layer, the ceramic separator, and the negative electrode layer are bonded together. The lithium composite oxide sintered body contains, as an auxiliary agent, 0.05 to 2.0 mol % of boron with respect to the content of cobalt in the lithium composite oxide sintered body or 0.05 to 1.2 mol % of strontium with respect to the aforementioned cobalt content.

Abstract: A lubricant composition containing a vegetable oil, a degreasing agent, and a non-ionic surfactant. The vegetable oil may be soybean oil, the degreasing agent may be ethyl lactate, and the non-ionic surfactant may comprise sorbitan esters, polyethoxylated sorbitan esters, or a combination thereof. Also provided is a wellbore servicing fluid containing a base fluid and the lubricant composition containing vegetable oil, degreasing agent, and non-ionic surfactant. Methods of introducing the lubricant composition and wellbore servicing fluids containing the lubricant composition into a subterranean zone (e.g., into a wellbore disposed in a subterranean formation) are also provided.

Abstract: Provided are water-soluble polymers that may include a water-soluble bipolymer, a water-soluble anionic terpolymer, and a water-soluble cationic terpolymer. The water-soluble polymers may include a reaction product of a first monomer that has a vinyl-containing group linked to a pendant carbohydrate moiety; a second monomer that has a vinyl group, a carbonyl group and a nitrogen; an anionic monomer in a water-soluble anionic terpolymer; and a cationic monomer in a water-soluble cationic terpolymer. Further provided are aqueous solutions that may include a water-soluble bipolymer, a water-soluble anionic terpolymer, and a water-soluble cationic terpolymer. Further provided are methods of use that may include introducing an aqueous solution into a formation such that the formation fractures, where the aqueous solution may include a water-soluble bipolymer, a water-soluble anionic terpolymer, and a water-soluble cationic terpolymer.

Abstract: The present invention pertains to the field of oilfield stimulation technologies for oil and gas field development, in particular to an instant soluble temperature and salt resistant polyacrylamide and the preparation method and application thereof, and the polyacrylamide is modified by adding rigid temperature and salt resistant monomer containing benzene ring and cationic fluorinated hydrophobic monomer on the basis of acrylamide monomer and sodium acrylate monomer, and then polymerized to obtain instant soluble temperature and salt resistant polyacrylamide. The temperature and salt resistant monomer containing benzene ring can improve the thermal stability and temperature and salt resistance of polyacrylamide, while the long-chain cationic fluorinated hydrophobic monomer can enhance the hydrophobicity of polymer. The comprehensive properties of polymer is improved by appropriate intermolecular association.

Abstract: This invention relates to compositions and methods of microbial enhanced oil recovery using biochemical-producing microbes. In specific embodiments, the methods of the subject invention comprise applying a biosurfactant-producing bacteria and/or a growth by-product thereof to an oil-producing site. In preferred embodiments, the bacteria is a strain of Bacillus in spore form. In some embodiments, the methods further comprise applying the bacteria with a yeast fermentation product, an alkaline compound, a polymer, a non-biological surfactant, and/or one or more chelating agents. Advantageously, the subject invention can be useful for stimulating the flow of oil from a well, as well as dissolving scale present in an oil-bearing formation.

Abstract: A wellbore fluid comprising an aqueous base fluid and a plurality of nanoparticles suspended in the aqueous base fluid. The nanoparticles are present in the wellbore fluid in an amount effective to have an effect of increasing the density by at least 0.2 lb/gal.

Abstract: According to a storage battery of an embodiment includes a first battery module and a second battery module connected in parallel with the first battery module. The number of first cells connected in series in the first battery module is M, and the number of second cells connected in series in the second battery module is N. When an open circuit voltage at SOC=X % of the first cells and the second cells are Va1 (X) and Va2 (X), respectively, the voltages of the battery modules are M×Va1 (X)<N×Va2 (X) in the range where the SOC of the cell is 0% to 30%, and M×Va1 (X)>N×Va2 (X) in the range where the SOC of the cell is 70% to 100%.

Abstract: Macroparticulates may be formed through at least partial self-assembly by reacting an epoxide-containing (meth)acrylic polymer or copolymer with a compound bearing a nitrogen nucleophile. An internal cavity may be formed when functionalizing the (meth)acrylic polymer or copolymer in the presence of a hindered amine base. When appropriately functionalized, the macroparticulates may be used to sequester a contaminant from a substance in need of contaminant remediation, such as produced water or flowback water from a wellbore job site. Reclaimed water obtained from the macroparticulates may be utilized to form a treatment fluid. The macroparticulates may be located within a continuous flow line, particularly within a removable cartridge, to promote removal of at least one contaminant from a substance in need of contaminant remediation.