Abstract: A method of treating a subterranean formation comprises pumping into a well penetrating the formation a surface modifying treatment agent having a metallic anchor and at least one hydrophobic tail attached to the metal of the anchor. The surface modifying treatment agent is covalently bound to the surface of the subterranean formation through the metal of the anchor.

Abstract: A well treatment fluid comprising a 2-oxo-aldehyde having 3 or more carbon atoms is disclosed herein. Methods to prepare and to utilize the fluid, and to inhibit biological degradation of a well treatment fluid, are also disclosed.

Abstract: A method of treating a treatment zone in a well is provided. The method includes the step of introducing into the treatment zone: (a) a hydrated sheet silicate mineral; and (b) a chemical activator for expanding the hydrated sheet silicate mineral. According to an embodiment, a method of treating a treatment zone in a well, where the method includes the steps of, in any order: (a) introducing into the treatment zone a first treatment fluid, wherein the first treatment fluid includes: (i) a hydrated sheet silicate mineral; and (ii) water; and (b) introducing into the zone a second treatment fluid including a chemical activator for expanding the hydrated sheet silicate mineral in the treatment zone.

Abstract: Embodiments including methods comprising providing a treatment fluid comprising a first aqueous base fluid and a polymeric gelling agent, wherein the treatment fluid comprises a first surface tension; introducing a fluid mobility modifier into the treatment fluid, wherein the fluid mobility modifier comprises: a first surfactant selected from the group consisting of a non-ionic surfactant; a cationic surfactant; and any combination thereof, and a solvent-surfactant blend comprising a second aqueous base fluid, a second surfactant, a solvent, and a co-solvent, wherein the ratio of the first surfactant to the solvent-surfactant blend is in the range of between about 1:5 to about 5:1, wherein the fluid mobility modifier causes the treatment fluid to adopt a second surface tension that is less than the first surface tension; and introducing the treatment fluid into a subterranean formation.

Abstract: Scales are prevented or inhibited from forming in a well or in a formation penetrated by a well by pumping into the well a fluid comprising a hydratable polymer, a crosslinking agent, such as an organometallic crosslinking agent containing a polyvalent metal and a scale inhibitor selected from the group consisting of polyvinyl sulfonates, a polyacrylamidomethylpropane sulfonic acid, carboxymethyl inulin and sulfonated polyacrylates and mixtures thereof.

Abstract: Using in situ channelization treatment fluids in multistage well treatment is disclosed. Also disclosed are methods, fluids, equipment and/or systems for treating a subterranean formation penetrated by a wellbore, relating to in situ channelization treatment fluids.

Abstract: Methods of treating a subterranean formation are disclosed that include contacting a paste including a liquid chemical and a lightweight fiber having a high aspect ratio with a treatment fluid, and placing the treatment fluid into a subterranean formation. Also disclosed is an additive for treating a subterranean formation comprising a paste including a liquid chemical and a lightweight fiber having a high aspect ratio.

Abstract: In an embodiment, a method is provided including the steps of: (A) introducing a well fluid comprising an electron-poor orthoester into a well; and (B) allowing or causing the electron-poor orthoester to hydrolyze to produce an acid and an alcohol in the well. In another embodiment, a water-based well fluid is provided, the well fluid including: (A) a continuous aqueous phase having a pH of a least 6; (B) an electron-poor orthoester; and (C) a viscosity-increasing agent.

Abstract: Gellable treatment fluids containing a terpolymer that comprises 2-acrylamido-2-methylpropanesulfonic acid, acrylamide, acrylic acid monomer units can be used in various subterranean operations where it is necessary for the treatment fluid to remain in a gelled state for extended periods of time at high formation temperatures. Methods for treating a subterranean formation can comprise providing a treatment fluid comprising an aqueous carrier fluid, a crosslinking agent, a gel stabilizer, and a terpolymer that comprises 2-acrylamido-2-methylpropanesulfonic acid, acrylamide, and acrylic acid monomer units, or any salt thereof; introducing the treatment fluid into a subterranean formation; allowing the treatment fluid to form a gel in the subterranean formation; and breaking the gel after it has been in the subterranean formation for at least about one day.

Abstract: Ferrous Nanoparticle Oil Extraction is the process of introducing ferrous nanoparticles coated in an oleophilic surfactant into oil reservoirs and implementing a magnetic force within the oil to supplement the traditional suctioning forces to extract oil. The nanoparticles, once in the oil, are allowed to disperse by Brownian motion and bind to the oil particles. The oil-nanoparticle solution is then magnetized and drawn out of the well. The magnetic force, originating at the mouth of the extraction pipe, supplements the traditional suctioning forces. Once collected, the oil-nanoparticle solution is passed through a high gradient magnetic separator, separating the oil from the nanoparticles. The nanoparticles are ready for reuse in the process of ferrous nanoparticle oil extraction.

Abstract: Methods, fluids, and compositions are provided for treating subterranean formations. The fluids can be servicing or drilling fluids including a base fluid and a particulate agent or biocide precursor particulate agent. The particulate agent can seal flow paths in the subterranean formation and subsequently can be degraded to allow flow to resume. The particulate agent may be a reaction product of a urea containing compound and an aldehyde containing compound. An example of such a reaction product is a methylene urea.

Abstract: A method of well treatment that includes providing a well treatment composition containing a non-functionalized cellulose material and a halide salt composition containing at least zinc halide, calcium halide or a mixture thereof, and placing the well treatment composition within a wellbore or a subterranean formation, and wherein the halide salt composition dissolves at least a portion of the non-functionalized cellulose material.

Abstract: Methods of treating a subterranean formation are disclosed that include placing a treatment fluid into a subterranean formation, the treatment fluid containing a one or more polymers capable of consolidating to form a polymeric structure at a downhole location. Also disclosed are treatment fluids including a polymeric structure for treating a subterranean formation.

Abstract: A method of treating a very high salinity high temperature hydrocarbon containing formation is described. The method includes (a) providing a hydrocarbon recovery composition to at least a portion of a hydrocarbon containing formation having a brine salinity of above about 13 wt % and a temperature of above about 7° C., wherein the composition comprises a C15-18 internal olefin sulfonate; and (b) allowing the composition to interact with hydrocarbons in the hydrocarbon containing formation.

Abstract: Systems and methods for improving reservoir fluid recovery from fractured subterranean formations. The methods may include injecting a pressurizing fluid into an injection fracture that extends within a subterranean formation and producing a produced fluid from a production fracture that extends within the subterranean formation. The production fracture is spaced apart from the injection fracture and is in indirect fluid communication with the injection fracture via a portion of the subterranean formation that extends therebetween and the pressurizing fluid injection provides a motive force for the production of the produced fluid. The methods further include injecting a foaming agent into the production fracture to limit production of the pressurizing fluid from the production fracture. The systems may include hydrocarbon production systems that may be utilized to perform the methods and/or that may be created while performing the methods.

Abstract: Viscoselastic surfactant systems including at least one viscoelastic surfactant and at least one divalent metal compound, where the systems are useable for enhancing oil production in oil wells that coproduce high volumes of gas and/or water and for enhancing gas injection uniformity into injection formations and methods including treating producing or injecting formations with the systems to enhance oil production in treated producing zones or enhance injection efficiency in injection zones.

Abstract: A continuous process for upgrading a heavy hydrocarbon includes the steps of: obtaining a heavy hydrocarbon; heating the heavy hydrocarbon; contacting the heavy hydrocarbon with a solvent at upgrading conditions so as to produce a first product comprising a mixture of upgraded hydrocarbon and solvent and a second product comprising asphaltene waste and water; continuously feeding the first product and the second product to a first separator; heating the first product; and continuously feeding the first product to a second separator to separate the upgraded hydrocarbon from the solvent. A system is also provided.

Abstract: Dimethyl sulfide is produced from sour gas. The dimethyl sulfide is utilized in an oil recovery formulation introduced into a petroleum-bearing formation to enhance recovery of petroleum from the formation.

Abstract: This invention presents innovative methods to treat saline streams such as produced water, seawater, and the like. The invention can be used to: (1) de-NORM produced water; or (2) de-NORM and partially de-salt produced water; or (3) de-NORM and partially de-salt and de-ionize produced water; or (4) de-oil, de-NORM, de-salt and de-ionize produced water. The invention can also be used to de-sulfate seawater and the like in conjunction with desalting plants.

Abstract: A method for producing oil from a fractured oil bearing formation is provided in which an oil recovery formulation comprising water and dimethyl ether is introduced into a fracture in the formation to mobilize oil, the mobilized oil is contacted with water or brine, and the mobilized oil is produced from the formation at a location positioned upwards from the fracture.

Abstract: The flow of a fluid may be diverted from a high permeability zone to a low permeability portion of a subterranean formation by use of particulates comprising a mixture of (i) at least one aliphatic polyester having the general formula of repeating units: where n is an integer between 75 and 10,000 and R is selected from the group consisting of hydrogen, alkyl, aryl, alkylaryl, acetyl, heteroatoms, and mixtures thereof; and (ii) at least one compound of the formula: or an anhydride thereof wherein: R1 is —COO—(R5O)y—R4 or —H; R2 and R3 are selected from the group consisting of —H and —COO—(R5O)y—R4; provided both R2 or R3 are —COO—(R5O)y—R4 when R1 is —H and further provided only one of R2 or R3 is —COO—(R5O)y—R4 when R1 is —COO—(R5O)y—R4 R4 is —H or a C1-C6 alkyl group; R5 is a C1-C6 alkylene group; and each y is 0 to 5.

Abstract: A method of treating a subterranean formation. The method may include providing a well treatment including a treatment complex formed of a treatment agent encapsulated, entrapped, or embedded in a polysaccharide, introducing the treatment complex into a wellbore through a subterranean formation, and allowing the treatment complex to release the treatment agent over a release time period. The method may include allowing the treatment complex to release the treatment agent after a delay time period from the introduction of the treatment complex into the wellbore.

Abstract: A system is provided for removing dimethyl ether (DME) from oil, water or brine and gas that includes a gas-oil-water separation module, a DME absorber, a water stripper, a liquid-liquid extractor, a water source, and an oil stripper, and a process is provided for separating DME from a mixture of DME, crude oil, water or brine, and a gas containing alkane hydrocarbons. A DME lean oil containing at most 1 ppmwt may be produced by the process.

Abstract: The method for enhanced oil recovery by in situ carbon dioxide generation utilizes a chelating fluid injected into an oil reservoir through a fluid injection system. The chelating fluid is a low pH solution of a polyamino carboxylic acid chelating agent. The polyamino carboxylic acid chelating agent may have a concentration of about 5 wt %. The polyamino carboxylic acid chelating agent is preferably either an aqueous solution of H2Na2-ethylenediaminetetraacetic acid (pH 4.5), H3-hydroxyethyl ethylenediamine triacetic acid (pH 2.5), or an aqueous solution of H2NaHEDTA (pH 4). The injection of the chelating fluid may be preceded by flooding the core with seawater, and is followed by injection of either to seawater, a high pH chelating agent, or low salinity water to ensure maximal extraction of oil from the reservoir. The method is particularly for use in formations where the core of the reservoir has a carbonate rock matrix.

Abstract: Inhibiting gas hydrate formation while transporting hydrocarbon fluids may include providing a kinetic gas hydrate inhibitor, adding the kinetic gas hydrate inhibitor to a fluid capable of producing gas hydrates, and transporting the fluid that comprises the kinetic gas hydrate inhibitor. Generally a kinetic gas hydrate inhibitor may include a heterocyclic compound comprising nitrogen, e.g., poly(vinyl pyrrolidone).

Abstract: Trivalent-ion chelating agents may be useful in mitigating the formation aluminum and ferric precipitates in subterranean formations during acidizing operations. An acidizing operation may include introducing an acidizing fluid into a wellbore penetrating a subterranean formation, the acidizing fluid comprising an aqueous fluid, an acid source, and a trivalent-ion chelating agent, e.g., hydroxamates, 6,7-dihydroxyquinoline, 3-hydroxy-4-pyridinones, and any combination thereof. In some instances, trivalent-ion chelating agents with a pKa of less than about 7 may be particularly useful in acidizing operations.

Abstract: Treatment fluid compositions may comprise transient polymer networks for use in methods related to subterranean applications. In one aspect, a method may include providing a treatment fluid comprising an aqueous base fluid and a transient polymer network, and placing the treatment fluid in a subterranean formation. In another aspect, a subterranean treatment fluid may include an aqueous-base fluid and a transient polymer network.

Abstract: Compositions of and methods of using a fluid formulation for increasing flow, production, and/or recovery of oil and gas hydrocarbons from a subterranean formation.

Abstract: Treatments and compounds for use in subterranean formations where surfaces may be subject to silica scale build-up. Certain embodiments pertain to utilizing silica scale control additives with remediation and stimulation treatments. One example of a suitable method of treatment includes providing an acidic treatment fluid comprising: a base fluid, an acid, and a silica scale control additive; contacting at least a portion of a subterranean formation with the acidic treatment fluid; and allowing the acidic treatment fluid to interact with silica scale buildup in the subterranean formation so that at least a portion of the silica scale buildup is removed.

Abstract: Methods of preventing or reducing migration of particulates in injection wells. Some embodiments of the present invention describe methods of introducing a tackifying treatment fluid through an injection well and into a portion of a subterranean formation surrounding the injection well, wherein the tackifying treatment fluid comprises a base fluid and a tackifying agent. Other embodiments include a step of introducing a resin treatment fluid to the injection well before the tackifying treatment fluid.

Abstract: Compositions and methods for their use are disclosed, where the compositions comprise an amine component, an amine/phosphate ester component and optionally a solvent component. The compositions are adapted to coat solid materials, substrates and/or surfaces of producing reservoirs and formations and methods for making and using same, where the coating agents modify surface properties of the solid materials, substrates and/or surfaces of producing formations decreasing residual oil saturation.

Abstract: A method includes introducing a treatment fluid including a first polymer gel into a subterranean formation to generate a production fluid having an aqueous portion and a hydrocarbon portion, treating the aqueous portion of the production fluid with chlorine dioxide to separate additional hydrocarbons from the aqueous portion, and adjusting the viscosity of the treated aqueous portion prior to introducing the treated aqueous portion back into the subterranean formation.

Abstract: Methods and compositions comprising an emulsion or a microemulsion for use in various aspects of the life cycle of an oil and/or gas well are provided. In some embodiments, the emulsion or the microemulsion comprises water, a solvent, and a surfactant, and optionally, one or more additives.

Abstract: A method involving exposing a substance to a promoter, the promoter being made from a liquid carrier and a metal salt component, the metal salt component, having at least (i) a magnetic susceptibility above 1000 or (ii) an ionization potential below about 500 volts, or (iii) both (i) and (ii), and applying electromagnetic wave energy to the substance while the substance is in the presence of the promoter, for a period of time and at a frequency and amplification sufficient to promote the modification of at least one physical property of the substance. A related method of treating a well in a subterranean formation, a tank or a pipeline, and the well treatment promoter composition, are also described.

Abstract: Methods and compositions for stimulating of the production of hydrocarbons (e.g., formation crude oil and/or formation gas) from subterranean formations are provided. In some embodiments, the compositions are emulsions or microemulsions, which may include water, a terpene, and a surfactant. In some embodiments, methods of selecting a composition for treating an oil or gas well are provided.

Abstract: Method of treating a carbonate hydrocarbon-bearing formation. The method includes contacting the hydrocarbon-bearing formation with a composition comprising solvent and a fluorinated amphoteric compound. Carbonate hydrocarbon-bearing formations treated according to the method are also disclosed.

Abstract: The present invention relates to nitrogen-containing hydroxyethyl substituted compounds to be used as corrosion inhibitors for metal surfaces, for example in aqueous systems and in particular in oil-field applications, e.g. in oil or gas wells, and which could be used under sweet-well conditions as well as under sour-well conditions. It may also be used in oil-field acidizing and fracture-acidizing well stimulation treatment. The compounds belong to the group of partly ethoxylated fatty alkylamines, partly ethoxylated alkyletheramines and partly or fully hydroxyethyl substituted alkylamidopropylamines.

Abstract: A method includes treating a first formation intersecting a wellbore, preparing a diversion fluid including an inactivated viscosifier and an inactivated thinning agent, and positioning an amount of the diversion fluid to isolate the first formation. An activator is then delivered to the diversion fluid, thereby activating the inactivated viscosifier and triggering a thinning agent activation process.

Abstract: A plurality of solid particles including a thermoplastic composition having a softening temperature in a range from 50° C. to 180° C. and a blocked isocyanate resin; optionally at least some of the particles in the plurality of solid particles comprise both the thermoplastic composition and the blocked isocyanate resin. A composition comprising the plurality of particles dispersed in a fluid is also disclosed. A method of modifying a wellbore within a geological formation is also disclosed. The method includes introducing the fluid composition into the wellbore. A method of making a plurality of particles, for example, to use in the fluid composition, is also disclosed.

Abstract: A method for treating a zone of subterranean formation is provided. The method includes the steps of: (a) forming a treatment fluid including: (i) water; (ii) a viscosity-increasing agent selected from the group consisting of water-soluble polysaccharides, water-soluble derivatives thereof, and any combination of the foregoing; (iii) a crosslinker for the viscosity-increasing agent; (iv) a hydrophobically modified water-soluble polymer; wherein the viscosity-increasing agent is not a hydrophobically modified polymer; and (b) introducing the treatment fluid into a zone of a subterranean formation, wherein the zone has a design temperature of equal to or greater than 350° F.

Abstract: Methods and apparatus for running a completion string with sand screen assemblies through multiple zones are presented allowing sequential stimulation of zones, and production without multiple trips. An exemplary method includes running a completion string and isolating target zones. If desired, the formation can be produced prior to stimulation. To stimulate the zones, a first tubing valve is closed, for example by ball-drop, forcing fluid through the first screen assembly. After stimulating the zone is complete, a first screen valve is closed by increased tubing pressure. The first work string valve is re-opened by further increasing tubing pressure. A subsequent tubing valve is then closed, for example, by flowing the ball to the next ball seat. The process is repeated until all zones are stimulated. Valves are then opened at each screen assembly to allow production flow through the screen assemblies.

Abstract: This invention relates to oil and gas production, more specifically, to the methods of producing polymer emulsion for downhole operations and mixing degradable (hydrolysable) polymer emulsion with the treatment fluid.

Abstract: Treatments and compounds can be useful in subterranean formations where particulates and/or surfaces may be subject to silica scale build-up. Certain embodiments pertain to utilizing silica scale control additives with particulate packs. Of these, certain methods may treat particulate packs in a subterranean formation with silica scale control additives, certain methods may combine silica scale control additives with particulates prior to formation of a particulate pack, and certain compounds may provide the features of both silica scale control additives and particulates.

Abstract: A wellbore treatment tool for setting against a constraining wall in which the wellbore treatment tool is positionable, the wellbore treatment tool including: a tool body including a first end formed for connection to a tubular string and an opposite end; a no-go key assembly including a tubular housing and a no-go key, the tubular housing defining an inner bore extending along the length of the tubular housing and an outer facing surface carrying the no-go key, the no-go key configured for locking the no-go key and tubular housing in a fixed position relative to the constraining wall, the tubular housing sleeved over the tool body with the tool body installed in the inner bore of the tubular housing; and a sealing element encircling the tool body and positioned between a first compression ring on the tool body and a second compression ring on the tubular housing, the sealing element being expandable to form an annular seal about the tool body by compression between the first compression ring and the second c

Abstract: Compositions and methods are given for delayed breaking of viscoelastic surfactant gels inside formation pores, particularly for use in hydraulic fracturing. Breaking inside formation pores is accomplished without mechanical intervention or use of a second fluid. Bromate oxidizing agents are used along with selected breaking activators for the bromate breaking compounds. Useful bromate breaking activators include acid-generating breaking activators, oxidizing sulfur containing breaking activators, and reducing agent breaking activators.

Abstract: Production-treating chemicals, such as paraffin inhibitors, corrosion inhibitors and scale inhibitors are provided along with water-soluble polymers in a base oil phase to be used in a well treatment. The mixture may be provided as a separate product or mixed at a well site when performing a well treatment, such as hydraulic fracturing, acidizing or gravel packing.

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: Functionalized alpha-hydroxy alkyl ethers have been found to perform as non (or anti-) scaling hydrogen sulfide scavengers. A method of scavenging hydrogen sulfide includes contacting a fluid containing hydrogen sulfide with a treatment fluid including a functionalized alpha-hydroxy alkyl ether. Accordingly, the alpha-hydroxy alkyl ether reacts with the hydrogen sulfide to reduce the amount of hydrogen sulfide in the fluid. The functionalized alpha-hydroxy alkyl ether is functionalized with a phosphate group, phosphonate group, sulfate group, or sulfonate group. A broad range of alpha-hydroxy alkyl ethers are disclosed.

Abstract: Of the many compositions and methods provided herein, one method includes contacting tar resident in a well bore with a tar stabilizer comprising an acrylonitrile-butadiene copolymer; and allowing the tar stabilizer to interact with the tar to at least partially reduce the tendency of the tar to adhere to a surface.

Abstract: A well treatment method includes drawing a solvent to a first pump, drawing a wetting liquid to a second pump, pumping the wetting liquid through a polymer mixer using the second pump, combining polymer with the wetting liquid to produce a slurry containing undissolved polymer, and combining the slurry with the solvent upstream from the first pump. Another well treatment method includes increasing dissolution time of the polymer by providing a buffering agent in the wetting liquid before combining the wetting liquid and the polymer. A well treatment system includes a polymer mixing subsystem with a mix loop having a mix loop inlet line from a first pump feed line and a mix loop outlet line back to the first pump feed line, the mix loop outlet line containing a polymer mixer.