Abstract: Provided are extraction methods and systems to remove contaminants in a subterranean formation. The method of contaminant removal comprises introducing one or more organic acids and one or more organic acid surfactant boosters into a hydrocarbon-containing stream, recovering the hydrocarbon-containing stream from a subterranean formation, and separating at least a portion of the contaminants from the hydrocarbon-containing stream. The organic acids and the organic acid surfactant boosters have a synergistic effect that improves the contaminant removal efficacy of the organic acid.

Abstract: Hydraulic fracturing fluids include an aqueous fluid, an acrylamide-based polymers, and a hyperbranched crosslinker that crosslinks the acrylamide-based polymer to form a crosslinked gel. The hyperbranched crosslinker includes a hyperbranched polyethyleneimine polyoxiranylalkanol having a weight-average molecular weight from 10 kDa to 1500 kDa. The hyperbranched crosslinker may be a product of reacting a hyperbranched polyethyleneimine with an oxiranylalkanol to obtain the hyperbranched polyethyleneimine polyoxiranylalkanol. In examples, the oxiranylalkanol is glycidol. Methods for preparing the hydraulic fracturing fluids and methods for treating subterranean formations with the hydraulic fracturing fluids are disclosed.

Abstract: The invention relates to a composition C which comprises, in an aqueous medium M: surfactants suitable for creating a foam in the presence of a gas; and polymers P based on acrylamide or acrylamido units, having a molecular mass of 1,000,000 to 20,000,000 g/mol; or: composition C has a viscosity of less than 6 mPa·s; and the content of polymer P is greater than the concentration limit beyond which the apparent viscosity of a foam obtained from composition C is greater by at least 10% than the apparent viscosity of a foam obtained from the same composition but deprived of polymers. The invention further relates to the use of these compositions as foaming compositions for EOR.

Abstract: An acid mixture includes hydrochloric acid, a monoamine corrosion inhibitor, and at least one of a diamine corrosion inhibitor and an acid additive. A method for inhibiting corrosion in an acid treatment operation includes introducing an acid mixture comprising hydrochloric acid and a monoamine corrosion inhibitor into at least one of a subterranean formation and subterranean wellbore. The method also includes maintaining the amount of the monoamine corrosion inhibitor in the acid mixture in the subterranean formation and/or the subterranean wellbore in a range of 10 ppm to 400 ppm for the duration of the acid treatment operation. The corrosion rate of steel parts of an acidic fluid circulation system in the acid mixture may be within an acceptable corrosion rate in a temperature range of 20° C. to 135° C.

Abstract: Provided is a method of introducing a scavenger composition into a fluid contaminated with a sulfur contaminant, mixing the scavenger composition with the fluid in a vessel, and recovering the fluid containing a reduced amount of sulfur contaminant from the effluent. The scavenger composition comprises a hydrogen sulfide scavenger and a linear anionic polymer. The linear anionic polymer is present in an amount of about 0.1% to about 50% by weight of the scavenger composition and has a number average molecular weight of about 1.0×103 to about 2.0×104 Daltons.

Abstract: Methods including generating heat and/or gas in subterranean operations, pipelines, and other related applications. In some embodiments, the methods include providing treatment composition including a carrier fluid, a catalyst, a first reactant, a second reactant, a solvent, an emulsifier, and a foaming agent, wherein the first and second reactants are capable of reacting in an exothermic chemical reaction; and introducing the treatment composition into at least a portion of a conduit or container having a temperature of less than 30° C.

Abstract: Provided are methods, compositions, and systems embodying cement compositions and the synergistic effect of lost circulation materials (LCMs) and fluid loss control additives (FLCAs) thereupon for cementing subterranean zones. A method of subterranean well cementing, comprising providing a cement composition comprising a hydraulic cement, a first FLCA, a LCM, and water, wherein the first FLCA comprises a water-soluble polymer with repeating units comprising a 5- to 6-membered cyclic amide; introducing the cement composition into a wellbore penetrating a subterranean formation, wherein inclusion of the first FLCA and the LCM in the cement composition fluid reduces fluid loss into the subterranean formation, wherein the subterranean formation has fractures with a width of from about 1 micron to about 800 microns, and wherein the subterranean formation has a permeability of about 1 millidarcy to about 300 Darcy; and allowing the cement composition to set in the subterranean formation.

Abstract: The subject invention provides multi-functional biochemical compositions, as well as their use in enhancing oil recovery by, for example, enhancing traditional acid treatments. Advantageously, the compositions and methods of the subject invention are operationally-friendly, cost-effective, and environmentally-friendly approaches to enhancing oil recovery. More specifically, in preferred embodiments, the subject invention provides a multi-functional composition for enhanced oil recovery (EOR) comprising one or more concentrated acids that work in synergy with a combination of one or more surfactants, one or more chelating agents, and one or more solvents to stimulate the flow of oil from a formation.

Abstract: Methods for initiating chemical reactions in a wellbore include delivering one or more reactive components via a carrier fluid to the wellbore. The one or more reactive components delivered to the wellbore are configured to enable one or more chemical reactions to occur. The one or more chemical reactions are carried out until a threshold volume of the one or more reactive components is delivered to the wellbore.

Abstract: Disclosed are compositions and methods for the pressure protection of existing wells during infill drilling operations.

Abstract: A process for preparing a well for use in subsequent recovery of hydrocarbons from a hydrocarbon-bearing formation wherein (i) mobilizing fluid is injected into the formation and emulsion fluids are produced to surface and directed to a high-pressure produced emulsion line, reducing pressure in the well, (ii) mobilizing fluid injection is terminated while emulsion production continues at reduced pressure, (iii) redirecting a portion of the reduced-pressure emulsion fluids to an additional low-pressure line instead of the produced emulsion line, and (iv) pumping the portion of the emulsion fluids at an elevated pressure from the additional line into the produced emulsion line.

Abstract: A method of inhibiting corrosion of metal during acid stimulation of an oil and gas well is provided. According to the method the oil and gas well is treated with an acidic treatment fluid which is an oil-in-water emulsion containing 10 to 28 wt. % of an acid, from 10 to 30 vol. % of a solvent selected from the group consisting of dimethyl formamide, dimethyl acetamide, acetone, methyl ethyl ketone, phenol, cresol, and benzyl alcohol; and 0.001 to 0.045 wt.

Abstract: Well stimulating fluids and methods may use a first and a second chelating agent, e.g., diethylene triamine pentaacetic acid (DTPA), glutamic diacetic acid (GLDA), and/or hydroxyethyl ethylene diamine triacetic acid (HEDTA), particularly in amounts of from 1 to 10 wt. %, to control iron precipitation during the stimulation process. Such fluids can stabilize iron ions without precipitation to manage the efficiency and performance of the stimulation fluid. Such stimulation fluids can be used with for highly concentrated HCl solutions, e.g., more than 20 up to 28 wt. % or more, that are useful in emulsified acid formulations in acid fracturing or acidizing of carbonate formations.

Abstract: A method for manipulating hydraulic fracture geometry. In one embodiment, the method comprises injecting a fracturing fluid into a well to generate one or more hydraulic fractures in a subsurface rock formation and then substantially draining any fluids from the one or more hydraulic fractures. The method may further comprise injecting a hydrophilic polymer and one or more crosslinking agents into the well to subsequently form low-density hydrogels which may then screen out only each tip of the one or more hydraulic fractures. A working fluid may then be injected into the well to increase fracture width of the one or more hydraulic fractures without substantially increasing fracture length. In an alternative embodiment, the hydrophilic polymer may be fully crosslinked by the one or more crosslinking agents and injected as pre-formed particle gels (PPGs) which may also screen out only each tip of the one or more hydraulic fractures.

Abstract: A method for mitigating gas override in an hydrocarbon reservoir by increasing sweep efficiency and consequently improving incremental oil recovery is provided with at least one injection well, at least one production well, and an hydrocarbon reservoir. The injection well and the production well are in fluid communication with the hydrocarbon reservoir. An injection blend produced by mixing a displacement fluid with an organic solvent is transferred into the hydrocarbon reservoir through the injection well. Preferably, the displacement fluid is supercritical carbon dioxide and the organic solvent is triethyl citrate. The higher density and the viscosity of the injection blend are vital in reducing gravity override and improving sweep efficiency. A resulting injection blend is extracted from the production well and the organic solvent is separated. Since the organic solvent can be reused, the method of mitigating gas override can be financially and operationally beneficial.

Abstract: Portable/transportable apparatuses, methods, and systems for generating and delivering sulfur trioxide on-site or near an item to be treated is provided. A method for extracting hydrocarbons from deposits containing a clathrate hydrate such as methane hydrates includes a step of delivering sulfur trioxide to an ice deposit containing a clathrate hydrate and subsequently extracting linear or branched hydrocarbons.

Abstract: The present disclosure relates to material for use in oil and gas well completion activities. More particularly, the present disclosure relates to diversion particles, along with methods for making and using the diversion particles. In an embodiment, a composite diversion material includes a non-degradable component comprising two or more non-degradable particulates, wherein the non-degradable particulates have a long term permeability at 7,500 psi of at least about 20 D. The composite diversion material includes a degradable component surrounding at least a portion of the non-degradable component. In another embodiment, a method of making a composite diversion material includes mixing non-degradable proppant particles with an aqueous solution containing a first degradable material to provide a mixture having a proppant concentration of at least about 20 volume percent. The method includes drying the mixture at a temperature of from about 25° C. to about 200° C. to provide the composite diversion material.

Abstract: A method for the controlled delivery of a fracturing fluid to a well bore comprises formulating an aqueous base fluid such that it meets or exhibits desired physical and chemical characteristics for an optimal fracturing fluid. The formulation of the aqueous base fluid max involve commingling one or more sources of waste water with a source of fresh water followed by controlled injection of one or more additives. This process is substantially completed prior to delivering the aqueous base fluid to the well site. This allows the delivery of an optimal volume of the aqueous base fluid with homogeneously blended additives to the well bore.

Abstract: A method for performing an acid stimulation operation using a downhole tool includes conveying the downhole tool in a borehole that is formed in a subsurface formation. The downhole tool includes a chamber to store stimulation fluid comprising a stimulation acid. The downhole tool includes a fluid injector that is fluidly coupled to an output of the chamber via a flow line of the downhole tool. The method includes coating the flow line with an acid resistant fluid. The method includes injecting, from the fluid injector via the flow line, the stimulation fluid into the subsurface formation that is released through the output of the chamber.

Abstract: A method of inhibiting corrosion of metal during acid stimulation of an oil and gas well is provided. The method includes treating the oil and gas well with an acidic treatment fluid containing an acid, a corrosion inhibitor of formula I, wherein R1 to R5 are hydrogen, and a secondary corrosion inhibitor of formula (II) wherein R1 to R5 are independently hydrogen, an alkyl, an aryl, or an alkoxy, The treatment fluid is substantially free of an intensifier, a surfactant, an organic solvent and a dimeric reaction product obtained by a double condensation reaction between thiocarbohydrazide (H2N—NH—C(S)—NH—NH2) and two cinnamaldehyde compounds.