Abstract: A method of using a gas control additive to provide gas migration control in a wellbore includes the steps of mixing the gas control additive with a cement to form a cement slurry, where the gas control additive includes a semi-permeable membrane and a scrubbing agent, such that the semi-permeable membrane forms a shell around a core such that the scrubbing agent is in the core, introducing the cement slurry to the wellbore, and reacting the scrubbing agent with an antagonistic gas to produce a helper byproduct, where the antagonistic gas migrates from a hydrocarbon-bearing formation into the wellbore and permeates through the semi-permeable membrane to the core of the gas control additive.

Abstract: A method for artificially recharging a target reservoir in a geological formation using powered water injection from a local source aquifer in the geological formation. The method comprises detecting chemical properties of water in the source aquifer, determining whether the water in the source aquifer is compatible with water in the target reservoir based on the chemical properties, activating an electrical submersible pump (ESP) positioned between target reservoir and the source aquifer to inject water from the source aquifer into the target reservoir, detecting downhole pressure, temperature and water flow rate conditions at the ESP, and controlling a rate at which the ESP injects water using the downhole pressure, temperature and water flow rate conditions.

Abstract: Methods for treating subterranean formations are provided. In one embodiment, the methods comprise providing a treatment fluid comprising an aqueous base fluid and a surfactant comprising an ethoxylated amine or derivative thereof; introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation; and producing fluids from the wellbore during or subsequent to introducing the treatment fluid into the wellbore.

Abstract: Methods and systems employing a flocculation polymer and microparticulates. The flocculation polymer flocculates the microparticulates to form micro-aggregates for use in forming complex fracture networks. Additionally, the flocculation causes the flocculation polymer to be removed from a treatment fluid due to its interaction with the microparticulates, thereby effectively cleaning the flocculation polymer from a subterranean formation. Individual microparticulates are synergistically used alone or in the presence of a de-aggregating agent to enhance complex fracture networks.

Abstract: A composition for an environmentally friendly hydrofracturing friction reducer product can be synthesized. A method for synthesis of a friction reducer emulsion can include using gas-to-liquid synthesized oil as a continuous phase in invert emulsion polymerization. The composition can be optimized by using a suitable amount of salt tolerant monomer for the best performance with salt tolerant features. Various inverting agents can be utilized for the self-inverting in brine with good product stability. The optimized friction reducer can be used in weighted brine hydrofracturing.

Abstract: A method for treating a subterranean formation with a foamed acid system is disclosed. The method includes introducing a treatment fluid into the formation. The treatment fluid includes a first solution and a second solution. The first solution includes an ammonium containing compound and an acid. The second solution includes a nitrite containing compound. One or both of the solutions further include a foaming agent. The solutions are mixed within the formation to generate a nitrogen gas. The method further includes, allowing the compounds to generate nitrogen in the presence of the foaming agent to form a foam and generate the foamed acid system within the formation. The acid present in the foamed acid system reacts with soluble substances in the subterranean formation to increase permeability of the subterranean formation and enable enhanced production of reservoir fluids.

Abstract: The technology extends hyperbolic-lipophilic difference and net average curvature (HLD-NAC) to a robust algorithm for predicting the phase behavior of microemulsions at different conditions away from experimental results. The HLD-NAC equations are modified to ensure consistency over the entire composition space including type II? and II+ regions. The algorithm converges and provides continuous estimates with any formation variable of tie lines and triangles for all Winsor types. The algorithm is configured such that discontinuities are eliminated and limiting tie lines near critical points are determined analytically. The algorithm is tuned using several sets of experimental data and provides for predictability of tie lines and tie triangles, and solubilization ratios.

Abstract: The present disclosure discloses a waterless foam generator for fracturing shale oil and gas reservoirs and use thereof. The structure of the waterless foam generator includes: a top of the proppant storage tank is provided with a proppant inlet, a second feed port of liquid CO2 and a safety valve, and a bottom of the proppant storage tank is connected to the high-pressure gas-liquid-solid mixer, a side wall of the high-pressure gas-liquid-solid mixer is provided with a first feed port of liquid CO2, an feed port of N2 and an feed port of waterless foam foaming agent, and the high-pressure gas-liquid-solid mixer is connected to the first shaker of waterless foam fracturing fluid, the first shaker of waterless foam fracturing fluid, the second shaker of waterless foam fracturing fluid and the third shaker of waterless foam fracturing fluid are connected in sequence.

Abstract: Certain foamed gel treatment fluids and methods of using the treatment fluids in wellbores penetrating subterranean formations are provided. In one embodiment, the treatment fluids comprise: an aqueous base fluid, a gas, a plurality of particulates, and a plurality of swellable particles each comprising a material having a first monomer, a second monomer, and a third monomer comprising a foamable surfactant. In one embodiment, the methods comprise: preparing a treatment fluid comprising an aqueous base fluid and a swellable particle that comprises a material having a first monomer, a second monomer, and a third monomer comprising a foamable surfactant; blending the treatment fluid with a gas to form a foamed gel; and introducing the foamed gel into a wellbore penetrating at least a portion of a subterranean formation.

Abstract: Methods and compositions for the use of thermally responsive lost circulation materials in subterranean formations are provided. In one embodiment, the methods include introducing a treatment fluid including a base fluid and a thermally responsive lost circulation material including a thermally responsive hydrogel that includes at least one thermoresponsive polymer into a wellbore penetrating at least a portion of a subterranean formation including a loss zone; allowing the thermally responsive lost circulation material to reach a thickening transition temperature; and allowing the treatment fluid to at least partially set in the subterranean formation.

Abstract: Methods and systems for treating a subterra-nean formation. An example method comprises pumping an aerosol comprising a vaporized carrier fluid and a dispersed polyhydroxyetheramine in a wellbore penetrating the sub-terranean formation; depositing the polyhydroxyetheramine on a surface of the subterranean formation; and producing hydrocarbons from the treated subterranean formation.

Abstract: Methods for temporary fracture isolation are provided. An existing fracture is treated with a chemical diverter. The chemical diverter is exposed to conditions causing it to expand, plugging the fracture. A new fracture can be created through the application of pressure and fluid, without disrupting the plugged fracture. The chemical diverter can then be removed through biodegradation or the application of a solvent to reopen the first fracture.

Abstract: A system for forming an upper plug in a well, the system, comprising lower tool segment that is adapted to land within a wellhead housing under open water conditions, a well control package that is adapted to be positioned above the lower segment and coupled to the wellhead housing, the well control package comprising at least one seal ram, an upper tool segment that is adapted to be positioned through the well control package (i.e., after the well control package has been attached to the wellhead) and operatively coupled to the lower tool segment, wherein at least one seal ram of the well control package is adapted to engage an outer surface of the upper tool segment, and at least one cutting means that is coupled to the lower segment and adapted to be actuated to cut at least one opening in at least one section of casing within the well.

Abstract: A tool for manipulating a tubular, such as casing or production tubing, in a downhole environment, includes a housing defining a chamber, the chamber having at least one outlet, a propellant source located within the chamber and an ignition mechanism for igniting the propellant source. Upon ignition of the propellant source, the propellant deflagrates, creating at least one stream of combustion products, the chamber directing the stream of combustion products through the/each outlet, towards the tubular to be manipulated, the/each stream of combustion products combining with at least one modifying agent to manipulate the tubular.

Abstract: Methods for producing proppants with block copolymer proppant coating include coating proppant particles with the block copolymer proppant coating to produce coated proppants with block copolymer proppant coating. The block copolymer proppant coating is a block copolymer composition having at least one copolymer backbone. Each copolymer backbone comprises at least two hard segments and a soft segment disposed between the at least two hard segments. Additionally, a proppant comprising a proppant particle and a block copolymer proppant coating is provided. The block copolymer proppant coating is a block copolymer composition having at least one copolymer backbone, in which each copolymer backbone comprises at least two hard segments. A soft segment is disposed between the at least two hard segments. The copolymer backbone has at least one anhydride group grafted onto the soft segment. Furthermore, the anhydride group is crosslinked by an amine-containing crosslinker.

Abstract: The invention provides environmentally-friendly compositions and methods for reducing the viscosity of crude oil using microorganisms and/or biosurfactants produced by microorganisms.

Abstract: Formulations for fracturing fluids are prepared by mixing a granulated water-soluble friction reducing polymer with an invert polymer emulsion friction reducing formulation optionally in the presence of an organophilic clay, without the need for specialized field equipment. The mixture can be dosed into water to produce a fracturing fluid which is found to be technically highly advantageous and cost-effective.

Abstract: A method of a bandoning a well in a reservoir. The method including the step of forming a scale in the reservoir by introducing into the reservoir a first solution comprising a first scale precursor and a second solution comprising a second scale precursor and a scale inhibitor. The first solution and second solution are able to react together to form the scale. The method further includes the step of at least partially filling the well with cement.

Abstract: Embodiments relate to a polymeric scale inhibitor that is a polycarboxylic acid copolymer comprising acrylic acid, methacrylic acid, and styrene sulfonic acid. The polymeric scale inhibitor compositions are particularly suitable for high pressure/high temperature scale inhibition treatment of oil, gas, geothermal production wells and/or subterranean formations.

Abstract: Provided herein are methods of increasing production from a hydrocarbon containing formation by adding a proppant to the formation, wherein a treatment fluid comprising a colloidal silica nanoparticle is added to the formation before, during or after the time the proppant is added to the formation.