Abstract: A method of reducing a density of a density of a stable emulsion drilling fluid may comprise providing a stable emulsion drilling fluid comprising: an aqueous liquid; a biopolymer; an emulsifier; solid particulates; and an oil; wherein the stable emulsion drilling fluid is capable of remaining in quiescent storage at approximately 70° F. and atmospheric pressure without phase separation for about 8 hours or longer; circulating the stable emulsion drilling fluid though a drill string and annulus; adding additional oil to the stable emulsion drilling fluid to decrease the density of the stable emulsion drilling fluid and produce a reduced density stable emulsion drilling fluid; and circulating the reduced density stable emulsion drilling fluid though the drill string and the annulus.

Abstract: This document relates to energetic salts that contain an organic cation and an oxidizing anion and methods of using the energetic salt compositions, including methods of hydraulic fracturing, pressure pulse fracturing, formation damage removal, and lowering the viscosity of heavy oil.

Abstract: An oil-based drilling fluid composition, includes a base fluid and a treating agent. The base fluid comprises a base oil and an inhibitor; the treating agent comprises an organic soil, a main emulsifier, an auxiliary emulsifier, a plugging agent, a weighting agent, a humectant, an alkaline regulator and a filtrate reducer. 5-25 parts by weight of the inhibitor, 5-12 parts by weight of the organic soil, 1-6 parts by weight of the main emulsifier, 2-8 parts by weight of the auxiliary emulsifier, 3-18 parts by weight of the plugging agent, 5-30 parts by weight of the weighting agent, 2-6 parts by weight of the humectant, 2-7 parts by weight of the alkaline regulator and 2-10 parts by weight of the filtrate reducer are used, based on 100 parts by weight of base oil.

Abstract: Methods for reducing zinc in fluids for use in subterranean formations are provided. In one or more embodiments, the methods include providing a fluid comprising an aqueous base fluid and zinc; and adding a precipitant comprising polyvinylpyrrolidone or any derivative thereof to the fluid to form a precipitate with at least a portion of the zinc.

Abstract: A method of drilling a subterranean geological formation is described. The method includes driving a drill bit to form a wellbore into the subterranean geological formation thereby producing a formation fluid including hydrogen sulfide (H2S). The method includes injecting a drilling fluid into the subterranean geological formation through the wellbore. The drilling fluid composition includes 0.25 to 2 wt. % of a primary H2S scavenger which is potassium permanganate. The drilling fluid composition includes an invert emulsion which includes a continuous phase including mineral oil and a dispersive phase including water. The potassium permanganate present in the drilling fluid composition reacts with the H2S present in the formation fluid to produce a dispersion of manganese-containing particles which are at least one selected from the group consisting of manganese sulfide and manganese sulfate.

Abstract: The present disclosure relates to a profile control and oil displacement agent for an oil reservoir and a preparation method thereof. The profile control and oil displacement agent is prepared by uniformly dispersing polymer microspheres, an activator and a solvent. The polymer microspheres are micron-sized dry-powdered microspheres, which are prepared by stirring and polymerizing a first monomer, a second monomer, an initiator, a hydrophobic nano-powder and water in a specific proportion. The profile control and oil displacement agent of the present disclosure can reduce the oil-water interfacial tension, has good long-term stability, simple preparation and low cost, avoids solvent waste, and can be applied to the deep profile control and oil displacement system of oil fields.

Abstract: A method of dissolving a gas hydrate in a pipeline includes introducing a gas hydrate dissolving solution into the pipeline and allowing the gas hydrate dissolving solution to at least partially dissolve the gas hydrate in the pipeline. The gas hydrate dissolving solution includes a glycol, dimethylformamide, or both, and has a boiling point of greater than 80° C. A method of dissolving a gas hydrate in a pipeline may also include introducing a gas hydrate dissolving solution into the pipeline and allowing the gas hydrate dissolving solution to at least partially dissolve the gas hydrate in the pipeline. The gas hydrate dissolving solution includes comprises a glycol, dimethylformamide, cesium formate, potassium formate, or combinations thereof, and has a flash point of greater than 50° C.

Abstract: The invention relates to the field of drilling fluid, in particular to a saturated salt water drilling fluid of salt response type intelligent polymer and preparation method thereof. The drilling fluid contains two or more of the following components stored in admixture or separately: bentonite, NaOH, KCl, calcium carbonate, barite, NaCl, supramolecular fluid loss additive, supramolecular shear-enhancing agent, plugging agent, coating agent and water. The drilling fluid provided by the invention has the characteristics of salt response and self-assembly, can keep rheological properties such as rapid recovery of the sheared structure, low extreme high shear rate viscosity, good shear dilution property and the like in a high-salt environment, has good fluid loss reduction performance, reservoir protection performance and debris dispersion inhibition performance, and has good temperature resistance and pollution resistance performance.

Abstract: A main chain of a temperature-resistant and anti-collapse multi-branched polymer fluid loss reducer is composed of the following repeating unit (I): In the repeating unit (I): x:y:z=(20˜80):(20˜80):(2˜30); the R1 and R2 groups are alkylamines having a multi-branched structure. The beneficial effect of the multi-branched polymer fluid loss reducer is: introducing cheap acrylamide branch monomer into the polymer monomer system of acrylamide and 2-acrylamido-2-methylpropanesulfonic acid, the preparation process is simple, the reaction conditions are mild, and the production cost is significantly reduced.

Abstract: Methods of controlling clay swelling and stabilizing subterranean geological formations containing swellable clays (e.g., montmorillonite, bentonite) are described. The methods involve treating the swellable clays with a composition containing an amidoamine-based gemini surfactant. The gemini surfactant has dual chains connected via an alkylene linker, whereby each chain contains a quaternary ammonium head group and an ethoxylated alkyl tail. As examined by linear swelling and free swelling tests, use of the gemini surfactant is effective in reducing swelling of the clays.

Abstract: A method of preparing a fracturing fluid comprising: preparing or providing an aqueous fluid containing iron ions; screening a plurality of friction reducers against the aqueous fluid wherein the plurality of friction reducers are anionic, cationic, nonionic, amphoteric, or combinations thereof; selecting at least one friction reducer from the plurality of friction reducers based at least in part on the step of screening; and preparing a fracturing fluid including the at least one friction reducer.

Abstract: An invert emulsion drilling fluids having a combination of fatty acids derived from waste vegetable oil (WVO) and a fatty alcohol as a rheology modifier. An invert emulsion drilling fluid may include a water in oil emulsion, an invert emulsifier, a fatty alcohol having six to thirty carbon atoms, and a fatty acid having six to eighteen carbon atoms. The fatty acid is provided by esterifying a waste vegetable oil to produce a methyl ester of the waste vegetable oil and cleaving an ester group from the methyl ester of the waste vegetable oil. The invert emulsion drilling fluid may be formulated free of organoclay. Methods of drilling a wellbore using an invert emulsion drilling fluid are also provided.

Abstract: Corrosion inhibitor compositions and methods for inhibiting corrosion on a metal surface exposed to a hydrocarbon fluid are provided. The corrosion inhibition composition can comprise tetrafluoroterephthalic acid, dimethyl sulfoxide, and heavy aromatic naphtha. The corrosion inhibitor composition can be phosphate-free and can inhibit naphthenic acid corrosion. In the methods, the corrosion inhibitor composition is added to the hydrocarbon fluid exposed to the metal surface to prevent or inhibit corrosion on the metal surface, including naphthenic acid corrosion.

Abstract: An aqueous injection fluid including: a polymer comprising hydrophilic moieties and a plurality of hydrophobic groups; and a surfactant that changes shape based on salinity and/or temperature.

Abstract: In accordance with one or more embodiments of the present disclosure, a method of inhibiting shale formation during water-based drilling of subterranean formations includes introducing a shale inhibitor to the subterranean formation during the water-based drilling, the shale inhibitor comprising a cationic polymer comprising repeating units of [A-B]. A is a substituted benzene or a substituted triazine of formula (2). B is a N-containing heterocycle. The cationic polymer and a method of making the cationic polymer are also described.

Abstract: A method and system for removing wax deposits from a wellbore and other oil production and processing equipment using a wax removal surfactant having at least 1% alkyl polyglycoside (APG), at least 0.5% ethoxylated alcohol (AE) or alcohol ethoxysulfates (AES), and at least 1% saturated alcohol, and optionally comprising D-Limonene, wherein the wax removal surfactant solution forms a Winsor Type III or Type IV microemulsion with water and wax.

Abstract: A high-temperature resistant, high-strength, and thixotropic gel plugging agent is composed of 8-20% of acrylamide monomer, 0.05-0.5% of reactive polymer, 0.1-1.0% of organic polymer cross-linker, 3.0-8.0% of resin toughening agent, 1.0-5.0% of flow pattern regulator, 0.01-0.5% of cross-linking regulator by the weight in the water. The gel solution shows a low apparent viscosity during the shear flow and is easy to be pumped into the wellbore and then into the formation leakage layer; after the pumping stops, the gel solution shows rapidly increased viscosity and strong adhesive force, and form a high-strength barrier between the wellbore and the formation, preventing the drilling fluid from further leaking.

Abstract: A polymer composite hydrogel includes a polymer composite, water, an organic crosslinker, and a salt. The polymer composite includes a nanosheet filler dispersed throughout a polymerized polyacrylamide. The nanosheet filler includes one or more of zirconium hydroxide, zirconium oxide, titanium oxide, graphene oxide, non-functionalized graphene, and hexagonal boron nitride. Further, a weight ratio of the nanosheet filler to the polymerized polyacrylamide is between 1:99 and 1:9. The polymer composite hydrogel includes 0.5 to 6 weight percent of the polymer composite and 0.25 to 5 weight percent of the salt, the salt being a monovalent salt, a divalent salt, or a combination of monovalent and divalent salts. A method of preparing a polymer composite, a method of preparing a polymer composite hydrogel for water shutoff applications, and the associated method of forming a barrier to shut off or reduce unwanted production of water in a subterranean formation is also provided.

Abstract: A hydrocarbon formation treatment micellar solution fluid and its use in treating underperforming hydrocarbon formations is described and claimed. A hydrocarbon formation treatment micellar solution fluid wherein the micellar solution fluid comprises water, a non-terpene oil-based moiety, a brine resistant aqueous colloidal silica sol; and optionally a terpene or a terpenoid, wherein the brine resistant aqueous colloidal silica sol has silica particles with a surface that is functionalized with at least one moiety selected from the group consisting of a hydrophilic organosilane, a mixture of hydrophilic and hydrophobic organosilanes, or a polysiloxane oligomer, wherein the brine resistant aqueous colloidal silica sol passes at least two of three of these brine resistant tests: API Brine Visual, 24 Hour Seawater Visual and API Turbidity Meter, and wherein, when a terpene or terpenoid is present, the ratio of total water to terpene or terpenoid is at least about 15 to 1.

Abstract: The instant application relates to nanogels or compositions that hold multivalent metal ions until some level of nanogel degradation has occurred, then slowly release the multivalent metal ions for gelation with carboxylate containing polymers. Compositions comprising such nanogels, together with polymers that can be crosslinked with multivalent metal ions, allow the deployment of such mixtures in various applications, and greatly increased gelation times.