Abstract: Disclosed herein are extended- and multimodal-release compositions for inhibiting scale in an industrial water system. In an example, an extended-release composition for inhibiting scale in an industrial water system includes a solid, particulate scale inhibitor. The solid, particular scale inhibitor may include a phosphonate, a carboxylate, or a combination thereof; and a divalent cation, a trivalent cation, or a combination thereof.

Abstract: The flow of a fluid may be diverted from a high permeability zone to a low permeability zone of a subterranean formation or well sections may be temporarily isolated by use of particles comprising a mixture of (i) at least one bi-phenyl compound of Compound I, (ii) one mellitic derivative of Compound II, (iii) one chelating agent of Compound III, (iv) one polymer of Compound IV, and (v) an internal breaker for the diverting agents and other additives like gels, foams, acids, brines and various other treatment chemicals.

Abstract: A method of non-mechanically remediating damage to a wellbore comprising a plurality of fracture stages is disclosed. A total treatment volume is calculated based on the plurality of fracture stages, the wellbore space, and either the production tubing or the annulus of the wellbore. The fracture stages of the wellbore are then divided into a plurality of chemical stages. The wellbore is pre-flushed, and each chemical stage is treated and isolated in order of depth by a volume of remediation chemical and volume of diverter. A post-treatment flush completes the remediation process and after a shut-in period, the well's production is substantially improved.

Abstract: A method of non-mechanically remediating damage to a wellbore comprising a plurality of fracture stages is disclosed. A total treatment volume is calculated based on the plurality of fracture stages, the wellbore space, and either the production tubing or the annulus of the wellbore. The fracture stages of the wellbore are then divided into a plurality of chemical stages. The wellbore is pre-flushed, and each chemical stage is treated and isolated in order of depth by a volume of remediation chemicals and a volume of diverter. A post-treatment flush completes the remediation process and after a shut-in period, the well's production is substantially improved.

Abstract: A synergistic fluid solution for breaking gelled fracturing fluid comprises an oxidizer, a transition metal, and an alkali compound at a total composition of between 100 and 150,000 ppm, wherein the gelled fracturing fluid is capable of significantly reducing viscosity of a gelled fracturing fluid within a time period between 30 minutes and 240 minutes after introduction at a temperature between 100° F. and 300° F.

Abstract: Embodiments of the invention comprise compositions and methods for inhibiting the formation of scales in wellbore environments with high levels of dissolved iron. The composition comprises compounds made with sugar acids, such as aldonic acids, ulosonic acids, uronic acids, and/or aldaric acids, and/or salts, esters, and ethers thereof. These sugar acids can be used in conjunction with conventional threshold scale inhibitors, comprising phosphonates, phosphates, aminocarboxylates, amino acids, and polymers containing carboxylic acids, sulfonic acids, phosphonates, phosphates. The resulting scale inhibition mixture minimizes scale formation from various cations while simultaneously acting as a chelating agent.

Abstract: A method of non-mechanically remediating damage to a wellbore comprising a plurality of fracture stages is disclosed. A total treatment volume is calculated based on the plurality of fracture stages, the wellbore space, and either the production tubing or the annulus of the wellbore. The fracture stages of the wellbore are then divided into a plurality of chemical stages. The wellbore is pre-flushed, and each chemical stage is treated and isolated in order of depth by a volume of remediation chemicals and a volume of diverter. A post-treatment flush completes the remediation process and after a shut-in period, the well's production is substantially improved.

Abstract: A wood treatment method for reducing fungal growth utilizes a treatment solution comprising an aldehyde, a carrier solvent, an organic co-solvent, at least one surfactant, and at least one acid, base, or salt. In embodiments, the carrier solvent may comprise water and the organic co-solvent may comprise an alcohol or acetone. The aldehyde is impregnated into the wood, where it reacts with thiamine and other amino acids to promote cross-linking, reducing the porosity of the wood and thereby reducing the ability of various microbes and fungi to access the interior of the wood as a nutrient source.

Abstract: A method for treating a zone of a well is provided, wherein the fluid is adapted to break in the zone of the well. The method includes the steps of: (A) introducing a well treatment fluid into a desired zone of the well, wherein the well fluid includes: (i) a water phase; (ii) a water-soluble polymer, such as derivatized polyacrylamide, soluble in the water phase; and (iii) an aldehyde or ketone or a source compound that releases the aldehyde or ketone; and (B) allowing the viscosity of the well fluid to break in the zone or proppant pack, and/or, increasing the solubility of the polyacrylamide polymer and reduce formation damage.

Abstract: The flow of a fluid may be diverted from a high permeability zone to a low permeability zone of a subterranean formation or well sections may be temporarily isolated by use of particles comprising a mixture of (i) at least one bi-phenyl compound of Compound I, (ii) one mellitic derivative of Compound II, (iii) one chelating agent of Compound III, (iv) one polymer of Compound IV, and (v) an internal breaker for the diverting agents and other additives like gels, foams, acids, brines and various other treatment chemicals.

Abstract: During “fracking” operations, proppants are used to keep open the fissures that are created, and stimulation fluids are often injected into the subterranean hydrocarbon-bearing geological formations to assist in capturing released hydrocarbons. However, because fissure surfaces formed in subterranean hydrocarbon-bearing geological formations from fracking tend to be hydrophobic, both introduced stimulation fluids and the hydrocarbons from the subterranean hydrocarbon-bearing geological formations tend to adhere to the fissure surfaces. The addition of a gemini surfactant appears to reduce the hydrophobic nature of the geological structure's fissure surfaces, thereby wetting surfaces of indigenous rock and/or introduced proppant surfaces. The addition of the gemini surfactant results in an increase of the fluid flow through the subterranean hydrocarbon-bearing geological formations, thereby enhancing of recovery of hydrocarbons and introduced stimulation fluids.

Abstract: It is common to require oil-well treating chemicals to be introduced into subterranean geological formations over the well's drilling, stabilization and extraction phases. The timely controlled and uniform release of such chemicals throughout the fluid bed vastly enhances their effectiveness. A method is disclosed for introducing such oil-well treating chemicals throughout the subterranean formation by encapsulating the chemicals within engineered composites, which are introduced into the subterranean formations along with the other fluids. These engineered composites are formed to slowly release the oil-well treating chemicals once they are in the subterranean formations as the engineered composites slowly dissolve.

Abstract: During “fracking” operations, proppants are used to keep open the fissures that are created, and stimulation fluids are often injected into the subterranean hydrocarbon-bearing geological formations to assist in capturing released hydrocarbons. However, because fissure surfaces formed in subterranean hydrocarbon-bearing geological formations from fracking tend to be hydrophobic, both introduced stimulation fluids and the hydrocarbons from the subterranean hydrocarbon-bearing geological formations tend to adhere to the fissure surfaces. The addition of a gemini surfactant appears to reduce the hydrophobic nature of the geological structure's fissure surfaces, thereby wetting surfaces of indigenous rock and/or introduced proppant surfaces. The addition of the gemini surfactant results in an increase of the fluid flow through the subterranean hydrocarbon-bearing geological formations, thereby enhancing of recovery of hydrocarbons and introduced stimulation fluids.

Abstract: Fracturing (or fracking fluids) used to enhance hydrocarbon extraction for subterranean rock formations may impede the recovery of the targeted hydrocarbons. Thus, it is common practice to inject a breaker into the subterranean rock formation to reduce the viscosity of the fracking fluids. The chemicals used to reduce the viscosity, called breakers, need to act after the tracking fluids have opened the pores in the subterranean rock formations, but before hydrocarbon extraction is hindered. A novel method for controlling the release of the breakers is disclosed. This method comprises encapsulating the breakers within a capsule comprised of water-soluble polymers and water-insoluble polymers. The water-soluble polymers are dissolved controllably by fluids within the well, allowing the breakers to react with the fracking fluids.

Abstract: Fracturing fluids (or fracking fluids) used to enhance hydrocarbon extraction for subterranean rock formations may impede the recovery of the targeted hydrocarbons. Thus, it is common practice to inject a breaker into the subterranean rock formation to reduce the viscosity of the fracking fluids. The chemicals used to reduce the viscosity, called breakers, need to act after the fracking fluids have opened the pores in the subterranean rock formations, but before hydrocarbon extraction is hindered. A novel method for controlling the release of the breakers is disclosed. This method comprises encapsulating the breakers within a capsule consisting essentially of water-soluble polymer components and water-insoluble polymer components. The water-soluble polymer component dissolves controllably by fluids within the well, allowing the breakers to react with the fracking fluids.

Abstract: A novel method for a controlled release of oil well treating compositions is revealed. The “engineered composite” are formed by mixing well treatment agents with an impervious substrate that exhibit low solubility in water and oil. The engineered composite is introduced in to subterranean wells along with a carrier, fluid to release well, treatment agents over extended periods of time.

Abstract: Acids, such as hydrochloric acid, are pumped down in to the formation in acidizing treatments of oil & gas wells, thru metal pipes/tubing. Corrosion Inhibition of these metal surfaces (pipes, tubing, etc) has been extensively studied. Most known acid corrosion inhibitors (ACI) and acid corrosion inhibitors currently used in the oilfield contain ingredients that are an environmental concern or have poor Health, Safety and Environmental (HSE) characteristics. This invention relates to the discovery of a Novel Acid Corrosion Inhibitor. Aromatic Nitriles, especially Cinnamyl Nitrile, when added to the acid in effective amounts, offers acceptable rates of corrosion inhibition. Cinnamyl Nitrile can be substituted in place of ingredients that have poor HSE characteristics, to improve the HSE characteristics of acid corrosion inhibitors, without sacrificing corrosion inhibition performance.