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, and an invert emulsion, which includes a continuous phase including a vegetable oil which is at least one selected from the group consisting of corn oil, soybean oil, rapeseed oil, canola oil, sunflower oil, safflower oil, peanut oil, and cottonseed oil and a dispersive phase including water.

Abstract: A modeling method is provided. The modeling method includes: extracting multiple pieces of logging data corresponding to a plurality of logging characteristic parameters at different drilling depths of a sample well, based on a logging information of the sample well; marking the different drilling depths based on a lost circulation information of the sample well to distinguish lost circulation points and non-lost circulation points; and classifying the lost circulation points and the non-lost circulation points by adopting a random forest algorithm, based on the plurality of logging characteristic parameters and the multiple pieces of marked logging data at the different drilling depths, to establish a plurality of corresponding relations between the logging characteristic parameters and a lost circulation or non-lost circulation result, so as to obtain a diagnosis model.

Abstract: A stabilized composition for use as a well fluid is provided. The stabilized composition includes a brine, a polyol, the polyol in an amount operable to inhibit solid formation, the polyol further operable to dissolve within the brine; and a stabilization compound, the stabilization compound operable to stabilize the polyol, such that the polyol does not degrade at a bottom hole temperature.

Abstract: A method for adjusting temperature and/or pressure of fuel in a pressured container system of a vehicle to a respective temperature setpoint and/or a respective pressure setpoint before a process of filling the pressurized containers includes extracting fuel from a first pressurized container having a first temperature and a first pressure, to bring the first temperature and/or the first pressure of the fuel closer to the temperature setpoint and/or to the pressure setpoint of the first pressurized container. The method also includes supplying the extracted fuel to either a fuel conversion device to power the vehicle or into a second pressurized container, where fuel in the second pressurized container has a second temperature and a second pressure, to bring the second temperature and/or the second pressure of the fuel closer to the temperature setpoint and/or to the pressure setpoint of the second pressurized container.

Abstract: A stabilized composition for use as a well fluid is provided. The stabilized composition includes a brine, a polyol, the polyol in an amount operable to inhibit solid formation, the polyol further operable to dissolve within the brine; and a stabilization compound, the stabilization compound operable to stabilize the polyol, such that the polyol does not degrade at a bottom hole temperature.

Abstract: Provided here are polyethylene glycol-based drilling fluid compositions and methods of making and using such compositions during drilling operations for recovery of hydrocarbons. Various other embodiments may be disclosed and claimed.

Abstract: The present invention relates to glycerol based drilling fluids. In particular, the invention relates to drilling fluids comprising a 95-20 volume % glycerol/water solution capable of stabilizing water-sensitive formations during drilling and the use of such solutions for drilling a well having water-sensitive formations.

Abstract: Aqueous and substantially anhydrous fluids having particularly low thermal conductivities and variable densities are disclosed. The fluids include: one or more organic and/or inorganic salts and at least one aprotic polar organic solvent, a mixture of aprotic and protic polar organic solvents, and/or a polar organic solvent having both protic and aprotic polar functional group linkages. The fluids optionally include one or more viscosifying agents and are free of cross-linking agents. Methods for formulating and using the fluids are also disclosed.

Abstract: Esters of alkanolamines with unsaturated, polyunsaturated or saturated C8-C36 monocarboxylic acids are additives for reducing accretion on drilling equipment (anti-accretion agents) to be used in drilling muds during drilling and completion of oil and gas wells.

Abstract: Nanomaterial compositions are useful for applications in drilling and completion fluids as enhancers of electrical and thermal conductivity, emulsion stabilizers, wellbore strength improvers, drag reduction agents, wettability changers, corrosion coating compositions and the like These nanomaterials may be dispersed in the liquid phase in low volumetric fraction, particularly as compared to corresponding agents of larger size. Nanofluids (fluids containing nano-sized particles) may be used to drill at least part of the wellbore. Nanofluids for drilling and completion applications may be designed including nanoparticles such as carbon nanotubes. These fluids containing nanomaterials, such as carbon nanotubes, meet the required rheological and filtration properties for application in challenging HPHT drilling and completions operations.

Abstract: A drilling fluid comprising: a non-ionic surfactant including: a branched alcohol ethoxylate and/or a capped alcohol ethoxylate; and a detergent builder.

Abstract: Coacervate gels having excellent shear viscosities and other properties are made with anionic or cationic polymers, a smaller amount of a surfactant having a charge opposite that of the polymer, and a hydrophobic alcohol and an effective amount of a phosphorus-containing compound sufficient to increase the viscosity of coacervate gels up to 3 times as compared to the gels in the absence of the phosphorus-containing compound. The Zeta Potential of the gel is maintained at an absolute value of at least 20. Optional gel promoting additives include betaines and amine oxides. A preferred gel comprises poly diallyl dimethyl ammonium chloride, a lesser amount of sodium lauryl sulfonate, and lauryl alcohol. The gels are particularly useful in well drilling fluids and well fracturing fluids.

Abstract: The present invention generally relates to emulsifiers for oil-based drilling fluids and muds comprising an emulsifier based on the polyamides derived from fatty acid/carboxylic acid and optionally alkoxylated polyamines. The invention also relates to oil or synthetic based drilling fluids comprising the emulsifiers of the invention and to drilling methods utilizing same.

Abstract: A method of servicing a wellbore in a subterranean formation having one or more lost circulation zones comprising placing a wellbore servicing fluid comprising a sealing composition into the wellbore, wherein the sealing composition comprises a latex and an accelerator and wherein the latex, the accelerator or both are encapsulated with an encapsulation material. A wellbore servicing fluid comprising a latex and an accelerator wherein the latex, the accelerator, or both are encapsulated.

Abstract: A drilling fluid comprising: a non-ionic surfactant including: a branched alcohol ethoxylate and/or a capped alcohol ethoxylate; and a detergent builder.

Abstract: According to one aspect of the invention, a method of converting an oxy halide salt into a halide dioxide in a reaction zone under certain conditions is provided. More specifically, the method includes generating chlorine dioxide from a stable composition comprising an oxy halide salt by introducing said composition to a reducing agent and minimum temperature within the reaction zone. According to another aspect of the invention, a composition for a stable chlorine dioxide precursor comprising an oxy halide salt is provided.

Abstract: Methods and fluids are provided that include, but are not limited to, a drilling fluid comprising an aqueous base fluid and a fluid loss control additive that comprises at least one polymeric micro gel and a method comprising: providing an aqueous based treatment fluid comprising a fluid loss control additive that comprises at least one polymeric micro gel; placing the aqueous based treatment fluid in a subterranean formation via a well bore penetrating the subterranean formation; allowing the fluid loss control additive to become incorporated into a filter cake located on a surface within the subterranean formation; allowing the filter cake to be degraded; and producing hydrocarbons from the formation. Additional methods are also provided.

Abstract: A method for enhancing the rheology of drilling fluids that is effective for any mud weight “clay-free” invert emulsion drilling fluid, even when drilling at high temperatures. The improved rheology is effected with addition of a silicon oil to the drilling fluid. A nonlimiting example of such a rheology additive comprises polydimethylsiloxane.

Abstract: According to an embodiment, an invert emulsion drilling fluid comprises: an external phase, wherein the external phase of the drilling fluid comprises a hydrocarbon liquid; an internal phase, wherein the internal phase of the drilling fluid comprises water; and a surfactant, wherein the surfactant: (A) comprises a hydrophobic tail group having a carbon chain length greater than or equal to 16; (B) has a boiling point greater than or equal to 400° F. (204.4° C.); and (C) is in at least a sufficient concentration such that the surfactant spontaneously forms reverse-micelles. According to another embodiment, a method of using the invert emulsion drilling fluid comprises: introducing the drilling fluid into a well.

Abstract: The invention provides a method of manufacturing a solid phase barite containing material for use in a wellbore. The method includes the steps of providing the barite containing material having relatively small particles with a particle size distribution of at least 50 vol % particles having a diameter in the range of 1 ?m to 10 ?m and at least 90 vol % particles having a diameter in the range of 4 ?m to 20 ?m; and contacting the barite containing material with a liquid in order to form relatively large particles having a particle size distribution with at least 90 vol % of the particles having a diameter of at least 30 ?m. There is also described a method of treating a wellbore with a fluid including the barite containing material.

Abstract: A oil field production fluid, namely a drilling mud composition, comprising a mixture of: (a) at least one base oil component; and (b) an additive component comprising a blend of dibasic esters. The functional fluid can optionally comprise additional additive components. The blend of dibasic esters comprises two or more of dialkyl methylglutarate, dialkyl adipate, dialkyl ethylsuccinate, dialkyl succinate, dialkyl glutarate.

Abstract: According to one aspect of the invention, a method of converting an oxy halide salt into a halide dioxide in a reaction zone under certain conditions is provided. More specifically, the method includes generating chlorine dioxide from a stable composition comprising an oxy halide salt by introducing said composition to a reducing agent and minimum temperature within the reaction zone. According to another aspect of the invention, a composition for a stable chlorine dioxide precursor comprising an oxy halide salt is provided.

Abstract: An environmentally responsible iron chelating additive and method for removing hydrogen sulfide or sulfide ions from drilling and packer fluids and preventing settling of precipitates. Iron chelating agents selected from the group consisting of ferrous lactate, ferrous gluconate, ferrous bis glycinate, ferrous citrate, ferrous acetate, ferrous fumarate, ferrous succinate, ferrous sacchrate, ferrous tartarate, ferrous glycine sulfate, ferrous glutamate, ferrous ascorbate, ferrous polymaltose, or a combination thereof, may be used. When the fluids are oil based, the iron chelating agents are added to the water phase of an emulsion, and the emulsion is added to the fluid. Viscosifiers may also be added to the drilling fluid with the emulsion.

Abstract: A method of cleaning a wellbore prior to the production of oil or gas, wherein the wellbore has been drilled with an invert emulsion drilling mud that forms an invert emulsion filter cake is disclosed. The method may include circulating a breaker fluid into the wellbore, where the breaker fluid includes a non-oleaginous internal phase and an oleaginous external phase, where the non-oleaginous phase includes a water soluble polar organic solvent, a hydrolysable ester of a carboxylic acid, and a weighting agent, and the oleaginous external phase includes an oleaginous fluid and an emulsifier, and where the hydrolysable ester is selected so that upon hydrolysis an organic acid is released and the invert emulsion of the filter cake breaks.

Abstract: Various salt crystal and agglomeration settling inhibiting agents may aid the ability to keep salt crystals of a desired particle size undissolved and dissolved in an aqueous drilling fluid, including, whey, wine-making residues, “steepwater solubles” or an organic liquid formed from the residue of wet processing of grains, sugar cane, sugar beets, and similar plants for the food and beverage industries for consumption by human or animals, and combinations thereof. A fluid so treated has more uniform properties and a reduced tendency for the salt therein to settle out as compared to an otherwise identical fluid absent an effective proportion or amount of the salt crystal agglomeration and settling inhibiting agent, even for saturated salt fluids. The salt crystal agglomeration and settling inhibiting agents are also believed to be useful in inhibiting or preventing the formation of gas hydrates under gas hydrate forming conditions of low temperature and high pressure.

Abstract: The present invention relates to bridging agents for use in subterranean formations, to well drill-in and servicing fluids comprising such bridging agents, and to methods of using such bridging agents and well drill-in and servicing fluids in subterranean drilling operations. An example of a well drill-in and servicing fluid of the present invention comprises a viscosified fluid, a fluid loss control additive, and a bridging agent comprising a degradable material.

Abstract: Methods and compositions for use in drilling a wellbore into an earthen formation that includes the use of a graphene-based material, where the graphene-based material may be at least one of graphene, graphene oxide, chemically converted graphene, and derivatized graphite oxide are shown and described. In certain examples, the methods and compositions reduce permeability damage and/or stabilize shales.

Abstract: A fluid may contain nanoparticles and a base fluid where the base fluid may be a non-aqueous fluid. The base fluid may be, but is not limited to a drilling fluid, a completion fluid, a production fluid, and/or a stimulation fluid. The fluid may have at least one property, such as but not limited to a dielectric constant ranging from about 5 to about 10,000, an electrical conductivity ranging from about 1×10?6 S/m to about 1 S/m, and combinations thereof. The non-aqueous fluid may be a brine-in-oil emulsion, or a water-in-oil emulsion, and combinations thereof. The addition of nanoparticles to the base fluid may modify the electrical properties of the fluid.

Abstract: The present invention relates to processes employing industrial streams, including glycerol-containing by-products of triglyceride processing as well as waste glycol streams recovered from several sources, to produce oil well drilling, completion and hydrofracturing fluids.

Abstract: The present invention relates to bridging agents for use in subterranean formations, to well drill-in and servicing fluids comprising such bridging agents, and to methods of using such bridging agents and well drill-in and servicing fluids in subterranean drilling operations. An example of a well drill-in and servicing fluid of the present invention comprises a viscosified fluid, a fluid loss control additive, and a bridging agent comprising a degradable material.

Abstract: The addition of a non-aqueous, non-oleaginous component into an aqueous-based drilling fluid may reduce the amount of salt necessary for the aqueous-based drilling fluid to reach saturation. The amount of the non-aqueous, non-oleaginous component within the aqueous-based drilling fluid may range from about 5 vol % to about 95 vol %. The component may be, but is not limited to glycol, glycerin, polyol, alcohol, and combinations thereof. The aqueous-based drilling fluid may then be used for drilling a wellbore into a subterranean reservoir that contains salt and thereby prevent or inhibit the salt from being leached from the subterranean reservoir.

Abstract: An amphiphilic nanoparticle comprises a nanoparticle having a hydrophilic region comprising a hydrophilic functional group bonded to a first portion of a surface of the nanoparticle, and a hydrophobic region of a surface of the nanoparticle. A downhole fluid comprises the amphiphilic nanoparticle, and a method of controlling an oil spill using the downhole fluid are also disclosed.

Abstract: The present invention relates to a process for the preparation of an ester in a reactor, a device, a process for the preparation of a thermoplastic composition comprising the ester prepared according to the invention, a process for the production of a shaped article comprising the ester according to the invention or the thermoplastic composition according to the invention, a process for the production of a packed product, a process for the production of an at least partly coated object, and uses of the esters according to the invention as an additive in various compositions.

Abstract: A drilling fluid comprising: a non-ionic surfactant including at least one of a branched alcohol ethoxylate and a capped alcohol ethoxylate, a detergent builder and a viscosifier.

Abstract: Systems and methods for processing glycerol into one or more products are provided. In at least one specific embodiment, the method can include decreasing a pH of a mixture comprising glycerol and fatty acids to produce an emulsion comprising a glycerol-rich portion and a fatty acids-rich portion. At least a portion of the glycerol-rich portion can be reacted with an acid comprising phosphorus at conditions sufficient to produce a reacted product comprising glycerophosphoric acid, glycerol, and a portion of the acid.

Abstract: Drilling fluids comprising a carrier fluid; a weighting agent that comprises sub-micron precipitated barite; a particle having a specific gravity of greater than about 2.6; and, a bridging agent that is not the submicron-precipitated barite or the particle. The weighting agent has a particle size distribution such that at least 10% of particles in the sub-micron precipitated barite have a diameter below about 0.2 microns, at least 50% of the particles in the sub-micron precipitated barite have a diameter below about 0.3 microns and at least 90% of the particles in the sub-micron precipitated barite have a diameter below about 0.5 microns. The particle has a specific gravity of greater than about 2.6 is not sub-micron precipitated barite. The ratio of the sub-micron precipitated barite to the particle is about 10:90 to about 99:1. The bridging agent comprises a degradable material.

Abstract: Drilling fluids comprising a carrier fluid; a weighting agent that comprises sub-micron precipitated barite; a particle having a specific gravity of greater than about 2.6; and, a bridging agent that is not the submicron-precipitated barite or the particle. The weighting agent has a particle size distribution such that at least 10% of particles in the sub-micron precipitated barite have a diameter below about 0.2 microns, at least 50% of the particles in the sub-micron precipitated barite have a diameter below about 0.3 microns and at least 90% of the particles in the sub-micron precipitated barite have a diameter below about 0.5 microns. The particle has a specific gravity of greater than about 2.6 is not sub-micron precipitated barite. The ratio of the sub-micron precipitated barite to the particle is about 10:90 to about 99:1. The bridging agent comprises a degradable material.

Abstract: A subterranean treatment fluid comprising a degradable gemini surfactant composition described by the following formula: A and A? are spacers that may be a hydrophobic group or a hydrophilic group. B is an ion and may contain a quaternary nitrogen, a sulfonate, or a phosphate. A, A?, B, B?, C, C, E and E? may be an alkyl, an aryl, a sugar, an ester, an ether, and any combination thereof. D and D? may be an aryl, a sugar, an ester, an ether, and any combination thereof. In some cases, A?, D?, and E? may be optional.

Abstract: A water-based polymer drilling fluid, containing effective quantities of surfactants having HLB numbers equal to or greater than approximately 7, emulsifies oil and bitumen contained in oil sand cuttings, resulting in the oil and bitumen being dispersed into the mud as an emulsion. This eliminates or significantly reduces the ability of the oil, bitumen, and cuttings to clog the well or stick to drill string components when drilling a well through oil-bearing sands, particularly sands containing highly viscous oil or bitumen. The emulsification process separates the sand particles from the oil and bitumen, such that the sand particles can be removed when the mud is run through a conventional shale shaker or other suitable apparatus.

Abstract: Of the many compositions and methods provided here, one method includes providing a drilling fluid comprising a lost circulation material and a base drilling fluid, wherein the base drilling fluid comprises an oleaginous continuous phase and a polar organic molecule, wherein the base drilling fluid has a first normal stress difference magnitude (|N1|) greater than about 100 Pa; and drilling a portion of a wellbore in a subterranean formation using the drilling fluid.

Abstract: Coacervate gels having excellent shear viscosities and other properties are made with anionic or cationic polymers, a smaller amount of a surfactant having a charge opposite that of the polymer, and a hydrophobic alcohol and an effective amount of a phosphorus-containing compound sufficient to increase the viscosity of coacervate gels up to 3 times as compared to the gels in the absence of the phosphorus-containing compound. The Zeta Potential of the gel is maintained at an absolute value of at least 20. Optional gel promoting additives include betaines and amine oxides. A preferred gel comprises poly diallyl dimethyl ammonium chloride, a lesser amount of sodium lauryl sulfonate, and lauryl alcohol. The gels are particularly useful in well drilling fluids and well fracturing fluids.

Abstract: Drilling fluids comprising polymers containing hydroxylated structural units are useful as accretion inhibiting agents, and/or as fluid rheology controlling agents, and/or as filtrate reducing agents, and/or as lubricating agents.

Abstract: Methods and compositions utilizing a drilling fluid comprising sub-micron precipitated barite having a weight average particle diameter below about 1 micron. Methods include a method comprising circulating a drilling fluid in a well bore, wherein the drilling fluid comprises: a carrier fluid; and a weighting agent that comprises sub-micron precipitated barite having a weight average particle diameter below about 1 micron are disclosed. In some embodiments, the drilling fluid may comprise an invert emulsion. In some embodiments, the sub-micron precipitated barite has a particle size distribution such that at least 10% of particles in the sub-micron precipitated barite have a diameter below about 0.2 micron, at least 50% of the particles in the of the sub-micron precipitated barite have a diameter below about 0.3 micron and at least 90% of the particles in the sub-micron precipitated barite have a diameter below about 0.5 micron.

Abstract: A well treatment composition comprises: a water-soluble, organic liquid, wherein the organic liquid: (A) comprises the continuous phase of the well treatment composition; and (B) comprises a polyglycol or a derivative of polyglycol; a fluid loss additive, wherein the fluid loss additive: (A) is insoluble in the organic liquid; and (B) comprises a high molecular weight, water-swellable polymer; and a suspending agent, wherein the suspending agent comprises an organophilic clay, wherein the well treatment composition has an activity of at least 15%. A method of cementing in a subterranean formation comprises: introducing a cement composition into the subterranean formation, the cement composition comprising: (i) cement; (ii) water; and (iii) the well treatment composition; and allowing the cement composition to set after introduction into the subterranean formation.

Abstract: A method of formulating a wellbore fluid that includes precipitating a weighting agent from a solution; and adding the precipitated weighting agent to a base fluid to form a wellbore fluid is disclosed. Fluids and methods of formulating wellbore fluids that contain dispersant coated precipitated weighting agents are also disclosed.

Abstract: Deicing compositions comprised of glycerol-containing by-products of triglyceride processing processes are disclosed.

Abstract: A method comprises providing a drilling fluid comprising: an aqueous fluid; and a microemulsion surfactant; and drilling a well bore in a subterranean formation comprising an oleaginous fluid using the drilling fluid, wherein the microemulsion surfactant forms a microemulsion with the oleaginous fluid within the well bore. In accordance with the method, the subterranean formation has a retained producibility greater than about 50%.

Abstract: The present invention relates to glycerol based drilling fluids. In particular, the invention relates to drilling fluids comprising a 95-20 volume % glycerol/water solution capable of stabilizing water-sensitive formations during drilling and the use of such solutions for drilling a well having water-sensitive formations.

Abstract: The lubricity of a drilling fluid or a completion fluid may be increased by incorporating into the fluid a water-soluble or water-dispersible salt of a sulfonated (sulfated) vegetable oil or a derivative thereof, such as a sulfonated (sulfated) castor oil. Suitable derivatives include the sodium, potassium, calcium, magnesium or ammonium salt. A non-ionic or anionic surfactant which is capable of enhancing the solubility of the salt may further be incorporated into the drilling fluid or completion fluid.

Abstract: The present invention relates to glycerol based drilling fluids. In particular, the invention relates to drilling fluids comprising a 95-20 volume % glycerol/water solution capable of stabilizing water-sensitive formations during drilling and the use of such solutions for drilling a well having water-sensitive formations.