Abstract: A method for administering a composition for exploiting natural gas hydrates. The method includes the following steps: injecting the reagent A into the tube A; injecting the reagent B into the tube B; stretching the tube A and the tube B into a hydrate reservoir by using a reagent injection instrument; regulating a flow rate according to a proportion of each component; allowing the reagents to react at a preset reservoir position; and allowing water in the reservoir to participate in the reaction at the same time, wherein a reaction product is used for supporting the reservoir.

Abstract: A composition of an invert emulsion oil-based drilling fluid is provided. The composition may include an oil phase and an aqueous phase. The oil phase may include an oleaginous fluid, an organophilic clay-based solid viscosifier, and a liquid viscosifier including a POSS. Further provided is a method of introducing the composition including the POSS into a wellbore. After introduction of the composition into the wellbore, the method includes maintaining wellbore conditions to provide a stable rheological property for a period up to about 96 hours in an HPHT section of a wellbore.

Abstract: Described herein is a multi-phase aqueous composition containing a surfactant; a first phase comprising water, an acid, and a water-soluble acid retarding agent; and a second phase selected from the group consisting of an immiscible organic phase, a gas, and combinations thereof. Further described are methods of making and using such compositions.

Abstract: The present invention belongs to the technical field of rock and soil reinforcement, and specifically relates to a plant urease-containing soil solidification agent and a zero-waste production process thereof. A crudely-purified plant urease solution includes a large amount of irrelevant proteins, which seriously affects the treatment effect of the soil solidification agent, makes it impossible to achieve an expected construction purpose, and also causes serious waste and environmental pollution. In the present invention, a common plant urease extraction method on the market is optimized to significantly reduce a protein concentration in a plant urease solution, greatly improve the infiltration performance of a plant urease-containing soil solidification agent, and broaden an application range of such a soil solidification agent.

Abstract: The present invention relates to a reagent for exploiting natural gas hydrates, which includes a regent A and a regent B. The reagent A is PEG400-polyurethane prepolymer; the reagent B includes PEG400 and an initiator; and a volume ratio of the PEG400-polyurethane prepolymer, the PEG400 and the initiator is (1-3000):(1-1000):(1-2000). The reagent of the present invention has excellent performance and high stability, and can effectively “replace” the “water” of the natural gas hydrate; and moreover, the reaction is exothermic reaction to effectively increase the reaction rate, which reduces the energy loss on the one hand, and reduces the blockage of a gas passage caused by the secondary generation of the natural gas hydrates in a low-temperature high-pressure pipeline during transferring on the other hand.

Abstract: Proppants for use in fractured or gravel packed/frac packed oil and gas wells are provided with a contaminant removal component to remove one or more of the contaminants found in subterranean water/hydrocarbon from a production well. The water/hydrocarbon cleaning proppant solids may be used as discrete particles in a proppant formulation, as a coating on proppant solids in pores of a porous proppant solid or as part of the proppant's internal structure. The contaminant removal component removes contaminants, especially dissolved contaminants, in the subterranean water or hydrocarbon before the water/hydrocarbon leaves the well. For those contaminant removal components that can be regenerated, such as ion exchange resins, a measured quantity of an acidic regeneration solution can be injected into the fractured stratum for regeneration and recovered when the well resumes production.

Abstract: A method is provided for swelling hydrocarbon-swellable elements located in a portion of a well. The method comprises the steps of: (A) introducing a water-in-oil emulsion into the portion of the well, wherein the water-in-oil emulsion comprises: (i) a hydrocarbon liquid, wherein the hydrocarbon liquid is the external phase of the water-in-oil emulsion; (ii) an aqueous liquid, wherein the aqueous liquid is an internal phase of the water-in-oil emulsion and wherein the aqueous liquid is adjacent to the external phase of the water-in-oil emulsion; and (iii) a surfactant; and (B) allowing the water-in-oil emulsion to contact the hydrocarbon-swellable element for a sufficient length of time to cause the thickness of the hydrocarbon-swellable element to expand by a desired percentage, wherein the desired percentage is at least 5%.

Abstract: A method is provided for swelling water-swellable elements located in a portion of a well. The method comprises the steps of: (A) introducing an oil-in-water emulsion into the portion of the well, wherein the oil-in-water emulsion comprises: (i) an aqueous liquid, wherein the aqueous liquid is the external phase of the oil-in-water emulsion; (ii) a hydrocarbon liquid, wherein the hydrocarbon liquid is an internal phase of the oil-in-water emulsion, and wherein the hydrocarbon liquid is adjacent to the external phase of the oil-in-water emulsion; and (iii) a surfactant; and (B) allowing the oil-in-water emulsion to contact the water-swellable element for a sufficient length of time to cause the thickness of the water-swellable element to expand by a desired percentage, wherein the desired percentage is at least 5%.

Abstract: Degradable polylactic or polyhydroxyalkanoate polymers may be used to viscosify aqueous fluids for use in wells. Sand control screen or liner can be coated with a solid degradable polymer during placement in a well. Mechanical changes or flow changes in a well can be caused by solid degradable polymer that changes physical properties after it is placed in a well. Parts of devices or entire devices can be made of solid degradable polymer that converts to a fluid after selected times in an aqueous environment in a well.

Abstract: A thermal insulating fluid contains microspheres of hollow spherical particulates. The presence of the hollow spherical particles improves the thermal insulating properties of the fluid by imparting to the thermal insulating fluid a low heat transfer coefficient. The hollow particulates may be inorganic or organic in nature and include hollow spheres of glass, ceramics and plastics. The thermal insulating fluid is capable of controlling the heat transfer from a production tubing or transfer pipe to one or more surrounding annuli and the environment. In addition to reducing heat transfer in the producing well, heat transfer in the fluid produced from the well is also minimized.

Abstract: A well treating composition containing a polysaccharide-based water-superabsorbent material has particularly applicability as a thermal insulating, fracturing or acid stimulation fluid. The water-superabsorbent material is capable of absorbing, at a minimum, its own weight. Particularly effective are biodegradable materials containing guar gum and carrageenan. The composition may further contain a crosslinking agent, brine and/or a viscosifying polymer or a gelling agent. As an oil-based fluid, the crosslinking agent is absorbed onto the water-superabsorbent material and serves to effectively delay crosslinking.

Abstract: A thermal insulating packer fluid contains water and/or brine, a crosslinkable viscosifying polymer, a crosslinking agent and an optional set retarder. The composition is capable of inhibiting unwanted heat loss from production tubing or uncontrolled heat transfer to outer annuli. The viscosity of the composition is such as to reduce the convection flow velocity within the annulus.

Abstract: The present invention relates to viscoelastic fluids that contain nanotube structures that may be used advantageously as oilfield stimulation fluids in many different applications, most particularly as a fracturing fluid. Viscoelastic fluid compositions of the present invention include an aqueous medium, a viscoelastic surfactant, an organic or inorganic acids, or salt thereof, organic acid salts, inorganic salts, and a nanotube component. The invention is also called to a methods of treating a subterranean well bores in which the viscoelastic fluid is injected into the wellbore to perform operations such as fracturing, drilling, acid fracturing, gravel placement, removing scale, matrix acidizing, and removing mud cake. Further, a method of preparing a nanotube viscoelastic fluid comprising the steps of effectively mixing a carbon nanotube component into a viscoelastic fluid, and sonicating the mixture in order to incorporate the carbon nanotube component is claimed.

Abstract: A method for producing a precursor polymer dispersion for addition to a brine for use in drilling and completion operations comprising providing a precursor brine having a first salt content, and mixing a water-soluble polymer with the precursor brine at a sufficient concentration and under conditions sufficient to produce a precursor polymer dispersion effective at a sufficient concentration in a final brine having a second salt content to improve the rheology and/or fluid loss control properties of the final brine.

Abstract: A well service fluid and method using same for brine-sensitive formations is disclosed. The fluid is an invert oil emulsion comprising heavy, solids-free brine, an oil or synthetic, and sufficient emulsifier to create the emulsion. The fluid has particular applicability in gravel packing a horizontal well.

Abstract: Hydrosoluble copolymers made of hydrophilic monomers, e.g., acrylamide, and of silane or siloxane derivative-based hydrophobic monomers, e.g., a silane or or siloxane acrylate, is obtained by micellar or heterogeneous radical copolymerization, and such copolymers can be used as rheology control agents in, e.g., a well bore.

Abstract: Elastic solids having reversible stress-induced fluidity are prepared, e.g., by combining liquid formulations with a crystalline mixed metal hydroxide conforming substantially to the formulaLi.sub.m D.sub.d T(OH).sub.(m+2d+3+n.multidot.a) (A.sup.n).sub.a .multidot.xH.sub.2 Owhere m is amount of Li, d is amount of divalent metal D, T is a trivalent metal, A represents at least one anion or negative-valence radical of valence n and a is the amount of A, and xH.sub.2 O represents excess waters of hydration, if any. These make useful coatings.The instantly reversible fluidization of these unique elastic solids may be expressed as:.sigma.=k.sub..alpha. .epsilon. when .epsilon.<F, for the solid phase; and.sigma.=f(d.epsilon.'/dt) when .epsilon.'>F, (this equation represents a generalized form for the usual theological equations); for a cycle of .epsilon., -xF <.epsilon.<xF, and when .epsilon.' equals 0 the liquid phase changes back to the solid phase, andwhere the symbol .sigma. represents stress; k.

Abstract: A thixotropic thermal insulating fluid includes a heavy hydrocarbon, water and oleophilic clay, wherein said heavy hydrocarbon is present in an amount of between about 75% to about 92% by volume of the fluid, said water is present in an amount of between about 5% to about 15% by volume of the fluid, and said oleophilic clay is present in an amount of between about 3% to about 10% by volume of the fluid. The fluid may be prepared by mixing water in an amount of between about 5% to about 15% by total volume of the fluid with oleophilic clay in an amount of between about 3% to about 10% by total volume of the fluid so as to provide a substantially homogeneous first gel product; and mixing said first gel product with a heavy hydrocarbon in an amount of between about 75% to about 92% by total volume of the fluid under agitation for a time sufficient to provide a second thixotropic gel product.

Abstract: The present invention provides nonionic alkanolamides which may be added to drilling fluids in order to minimize hydration and prevent erosion loss of water-sensitive shale substrates. Preferred alkanolamides are acetamide mono- and diethanolamines.

Abstract: In one embodiment, an epoxy resin composition is provided comprising: an epoxy resin and a partially reduced aromatic amine hardening agent. In another embodiment, a well treating composition is provided comprising: an epoxy resin; a partially reduced aromatic amine hardening agent; a solid particulate material; and a carrier fluid. In yet another embodiment, a method of treating a subterranean formation is provided. The inventive method comprises the step of placing the inventive well treating composition into the formation.

Abstract: A composition, especially suitable for use as a mud sweep and a spacer. The composition includes a petroleum-based hydrocarbon, a biopolymer, a thickening agent, a surfactant and potassium chloride. Other optional ingredients in embodiments of the present invention include a lower alkanol, sodium salts and aluminum stearate.