Abstract: A process and apparatus for removing hydrocarbons from hydrocarbon containing drilling waste. The process includes introducing hydrocarbon contaminated drill cuttings into one or more centripetal cuttings separators to create two distinct phases, thereafter discarding the bulk solids containing less hydrocarbons and treating the concentrated liquids phase in a solvent wash apparatus, resulting in improved efficiency of the facility throughput, while not substantially impacting the capital cost or operating cost of a solvent wash process facility. Apparatus for performing the process is also described.

Abstract: A fracturing fluid viscosity-controlling agent maintains the high viscosity of the fracturing fluid during fracture formation in hydraulic fracturing and reduces the viscosity during recovery of the fracturing fluid. A fracturing fluid which includes the viscosity-controlling agent is provided as well as a crude oil or natural gas drilling method using the fracturing fluid with the viscosity-controlling agent. This viscosity-controlling agent contains polyalkylene oxide and a viscosity-reducing agent and is in the form of a tablet.

Abstract: A method of manufacturing particulate material. The method can include manufacturing particulate material during an operation at a well, injecting the particulate material into the well during the manufacturing, and changing a dimension of the particulate material during the injecting. Another method of manufacturing particulate material can include manufacturing particulate material during an operation at a well, injecting the particulate material and a proppant into the well during the manufacturing, and then the particulate material degrading in the well. Another method of manufacturing particulate material can include manufacturing particulate material during an operation at a well, fixing a shape of the particulate material by cooling the particulate material, and then injecting the particulate material into the well.

Abstract: The present invention provides methods for increasing the viscosity of the drive fluid for displacing oil from a subterranean formation by the use of microorganisms selected or modified for the ability to produce cell free polymers without the formation of any significant bioplugging biofilm or capsule.

Abstract: Fibers are employed to improve proppant transport in low viscosity treatment fluids. The treatment fluids employ fibers to inhibit proppant settling without an unacceptable bridging tendency. The fibers are preferably crimped staple fibers having 1-10 crimps/cm of fiber length, a crimp angle between 45 and 160 degrees and a mean diameter between 8 and 40 microns.

Abstract: Chelating agents and silica scale control additives are often employed separately in conjunction with performing a dissolution process in a subterranean formation containing a siliceous material. Carminic acid and related compounds may be used to perform similar functions dually in various subterranean treatment operations. Methods for treating a subterranean formation can comprise: providing a treatment fluid comprising a carrier fluid and an ortho-dihydroxylated aromatic compound comprising a substance selected from the group consisting of carminic acid, kermesic acid, any salt thereof, any derivative thereof, and any combination thereof; and introducing the treatment fluid into a subterranean formation.

Abstract: Polymer-modified asphalt is used in drilling fluids for filtration control, lost circulation control, drill string differential sticking prevention, or wellbore stabilization. The latex modified asphalt provides a mixture of latex-asphalt complex, asphalt, and latex particles that help maintain wellbore stability while drilling into shale formations. The polymer-modified latex is effective for controlling laminated and microfractured shale. Polymers may be functionalized to react with the asphalt to create copolymer modifications of the asphalt for improved performance as drilling fluid additives. The drilling fluids may be water-based or oil-based, or based on an emulsion of oil and water.

Abstract: A method for consolidating a proppant in a formation comprises injecting in the formation a composition comprising an enzyme and a substrate. The enzyme and the substrate may react, optionally in the presence of a precipitating compound, to form a solid precipitate on the surface of proppant particles to consolidate the proppant in situ, e.g., in one or more fractures of the formation.

Abstract: A method of treating a subterranean formation includes introducing a viscosified treatment fluid into a subterranean formation, the treatment fluid including an aqueous fluid, a gelling agent, and a crosslinker including a copolymer with an interpenetrating monomer and organic bound metal ions. A composition includes an aqueous fluid, a gelling agent; and a crosslinker including a copolymer with an interpenetrating monomer and organic bound metal ions.

Abstract: A method for abandonment of a subsea well includes: setting a packer of a lower cementing tool against a bore of an inner casing hung from a subsea wellhead; fastening a pressure control assembly (PCA) to the subsea wellhead; hanging an upper cementing tool from the PCA and stabbing the upper cementing tool into a polished bore receptacle of the lower cementing tool; perforating a wall of the inner casing below the packer; perforating the inner casing wall above the packer by operating a perforator of the upper cementing tool; mixing a resin and a hardener to form a sealant; and pumping a fluid train through bores of the cementing tools and into an inner annulus formed between the inner casing and an outer casing hung from the subsea wellhead. The fluid train includes the sealant followed by a cement slurry.

Abstract: A method of sealing a formation that includes drilling a wellbore through the formation while pumping a non-aqueous based wellbore fluid comprising an encapsulated first component into the wellbore, the non-aqueous based wellbore fluid forming a filter cake on the walls of the wellbore; and adding a second component to the wellbore fluid when fluid losses are registered during drilling, whereby the first and second components react to form a chemical sealing layer in the filter cake is disclosed.

Abstract: An expansive additive composition for use in Portland cements and a method of using such an additive composition is provided. The additive composition can include a calcium aluminate cement additive and a lithium compound. The additive composition is capable of producing expansion in set cements when the temperature is at or below room temperature and minimizes the amount of calcium aluminate cement additive needed.

Abstract: Precipitated particles may be formed under conditions that provide a particle morphology suitable for conveying a desired set of properties to a wellbore circulation fluid. Methods for using precipitated particles in a wellbore may comprise: selecting precipitation conditions for producing precipitated particles that are substantially non-spherical in shape, are about 1 micron or under in size, or any combination thereof; forming the precipitated particles from a reaction mixture under the precipitation conditions without using a polymeric dispersant; and introducing a wellbore circulation fluid comprising a plurality of the precipitated particles into a wellbore penetrating a subterranean formation. The precipitation conditions may include one or more of modulating various reaction conditions, applying an electric field to the reaction mixture, or including a carbohydrate-based material in the reaction mixture.

Abstract: Metal-organic frame-works (MOFs) and its compositions for use as proppants in a method of treating subterranean formations. A method comprising contacting the formation with a fluid composition comprising a metal-organic framework comprised of at least one metal ion and an organic ligand that is at least bidentate and that is bonded to the metal ion.

Abstract: A wellbore (1) surrounded by a formation has a horizontal section provided with a non-cemented perforated liner (3), thereby forming an annular space (4) between the liner and the formation. The annular space is divided into zones (zone 1, zone 2, zone 3) isolated from each other by means of respective external packers (6, 7, 8) arranged externally on the liner. Selective access to the zones is provided by means of an internal pipe (9) arranged inside the liner and provided with internal packers (10, 11, 12) corresponding to the respective external packers. For each of the zones, the internal pipe is provided with a valve (14, 15, 16) providing access between the inside of the internal pipe and the corresponding zone. Stimulation of the near-wellbore is performed by pumping acid or the like reactive fluid through the internal pipe into the wellbore and is performed simultaneously in adjacent zones of the annular space.

Abstract: A diverter fluid having a carbon-containing particulate dispersed therein for controlling fluid flow within subterranean formations. The diverter fluid can be injected into a wellbore for formation of a filter cake by the carbon-containing particulate, and which disperses in hydrocarbons for return to the surface.

Abstract: A method and system for dehydration of a gas phase and hydrate inhibition of a liquid hydrocarbon phase in a multiphase hydrocarbon fluid stream containing water. The method may include (i) separating the hydrocarbon fluid stream into a liquid phase and a first gas phase, (ii) adding hydrate inhibitor to the first gas phase, and (iii) separating off condensed liquids and a second gas phase. The first gas phase has a water dew point that is lower than the initial multiphase hydrocarbon fluid stream and the second gas phase has a lower water dew point than the first gas phase. The hydrate inhibitor has a water content that is low enough to enable it to dry the first gas phase, the hydrate inhibitor being separated off with the condensed liquids and mixed with a part or all of the liquid phase from the separation to inhibit the liquid phase.

Abstract: Mesophase surfactant solutions and/or micellar solutions, pre-formed single phase microemulsions (SPMEs), and in situ-formed fluids may be used to clean up and remove hydrocarbons and synthetic oils such as oil-based mud filter cake and near wellbore damage in oil and gas wells. Removal occurs by solubilization of the hydrocarbons and synthetic oils into the micellar solutions, SPME, in situ-formed fluids, etc. when the fluid formulation contacts the hydrocarbons and synthetic oils. An in situ-formed fluid (e.g. microemulsion), may be formed when one or more surfactant, an optional linker, optional co-surfactant, optional acid, optional co-solvent and a polar high-density brine phase, and eventually some amount of organic phase, contacts the subterranean location and solubilizes the hydrocarbons and synthetic oils encountered, such as in the near wellbore of a subterranean formation. The micellar solutions, microemulsions, in situ-formed fluids, etc.

Abstract: A treatment fluid that comprises a carrier fluid and a degradable material in the form of particles, fibers or both is provided or prepared. The treatment fluid is placed in a borehole such that the treatment fluid contacts a liner, a downhole filter, perforations, natural fractures, induced fractures, or a subterranean formation or combinations thereof. The treatment fluid is allowed to flow into the liner, downhole filter, perforation, natural or induced fracture or subterranean formation such that the degradable material forms at least one plug or filter cake (or both), preventing or reducing further fluid movement between the wellbore and the subterranean formation. The degradable material is then allowed to dissolve after a period of time, causing the plug or filter cake (or both) to weaken, thereby allowing removal of the plug or filter cake (or both) and reestablishing fluid movement between formation and the wellbore.

Abstract: Fluids containing surfactants and hydrophobic particles are effective media for cleaning non-aqueous fluids (NAFs) out of a subterranean wellbore. The fibers and surfactants are preferably added to a drilling fluid, a spacer fluid, a chemical wash, a cement slurry or combinations thereof. NAFs, such as an oil-base mud or a water-in-oil emulsion mud, are attracted to the fibers as the treatment fluid circulates in the wellbore.