Abstract: A method and a sealing fluid for setting a packer in an annulus between a well bore and a well tubular is provided, which by adjusting i.a. the density, viscosity and setting time of the sealing fluid is able to provide among other things a full radial seal with an acceptable axial dispersion, in particular in highly deviated wells and/or in wells having eccentric annuli.

Abstract: Controlled fracturing in geologic formations is carried out in a method employing a combination of alternating and impulsive current waveforms, applied in succession to achieve extensive fracturing and disintegration of rock materials for liquid and gas recovery. In a pre-conditioning step, high voltage discharges and optionally with highly ionizable gas injections are applied to a system of borehole electrodes, causing the formation to fracture with disintegration in multiple directions but confined between the locations of electrode pairs of opposite polarity. After pre-conditioning, intense current waveform of pulse energy is then applied to the system of borehole electrodes to create waves of ionization or shock waves with bubbles of heated gas that propagate inside and outside the high conductivity channels, resulting in rock disintegration with attendant large scale multiple fracturing.

Abstract: In one aspect, a method of extracting heat from a downhole device is disclosed, which method, in one non-limiting embodiment, may include: providing a heat exchange fluid that includes a base fluid and core-shell nanoparticles therein; circulating the heat exchange fluid in the downhole device proximate to a heat-generating element of the downhole to cause the core of the core-shell nanoparticles to melt to extract heat from the downhole device and then enabling the heat exchange fluid to cool down to cause the core of the core shell nanoparticles to solidify for recirculation of the heat exchange fluid proximate to the heat-generating element.

Abstract: An in situ method to deploy and/or plasticize a shape-memory material in order to change the material's physical dimensions and/or mechanical properties, includes a method for deploying a shape memory polymer having a deformed or compressed shape in an environment at a first temperature, the shape memory polymer having a first glass transition temperature which is greater than the first temperature. The method also includes contacting the shape memory polymer with an activation fluid in an amount effective to decrease the glass transition temperature of the shape memory polymer from the first glass transition temperature to a second glass transition temperature which is less than or equal to the first temperature, where the activation fluid comprises a sugar present in an amount effective to raise a flash point of the activation fluid.

Abstract: Pumpable process-fluid compositions comprise polyacrylamide, a non-metallic crosslinker and a pH-adjustment material. Such compositions have utility in the context of controlling lost circulation in subterranean wells. Upon entering at least one lost circulation zone, the compositions crosslink, thereby forming a barrier that minimizes or stops fluid flow from the wellbore into the lost circulation zone.

Abstract: Disclosed are treating fluid compositions for use in subterranean workover and hydrocarbon recovery operations, as well as methods of treating subterranean formations penetrated by a wellbore utilizing the treating fluid. The treating fluid compositions contain a first, aqueous liquid, and a crosslinkable organic polymer that is at least partly soluble in the liquid. The treating fluid further contains a borate crosslinking agent solution containing a primary, un-refined borate and a secondary, refined borate, the borate solution being present as a crosslinking agent upon addition to the first fluid admixture so as to crosslink the organic polymer and increase the viscosity and/or accelerate the crosslink time of the treating fluid.

Abstract: Ampholyte polymeric compound that comprises at least one nonionic monomer, at least one sulfonic acid-containing monomer, and at least one cationic monomer may be useful in viscosifying treatment fluids for use in subterranean operations at a concentration of about 0.5 v/v % to about 30 v/v % of the treatment fluid. Such operations may involve introducing the treatment fluid into a wellbore penetrating a subterranean formation optionally at a pressure sufficient to create or extend at least one fracture in the subterranean formation.

Abstract: Described are a method and composition which use microorganisms for downhole applications, in particular for the maintenance or restoration of the integrity of a cement sheath in a wellbore. The method of cementing a wellbore comprises preparing a cement composition comprising a pumpable slurry of cement, water and a healing agent that comprises one or more microorganisms, delivering the cement composition into the wellbore and allowing the cement composition to set. The method of restoring the integrity of a set cement composition in a wellbore comprises preparing a pumpable slurry that comprises water, a healing agent that comprises one or more microorganisms and optionally cement, pumping the slurry into the wellbore in and around the set cement composition, and allowing the one or more microorganisms to grow and replicate to thereby restore the integrity of the set cement composition. Compositions for carrying out the methods are also described.

Abstract: A concentrated solar power (CSP) deliquification system for discouraging the accumulation of liquids in a wellbore includes a CSP heating subsystem, and an injection and recirculation subsystem. A working fluid is heated by the CSP heating subsystem and conveyed down-hole into the wellbore by the injection and recirculation subsystem. Heat is transferred from the working fluid to a production fluid within the wellbore, which facilitates maintenance of the production fluid in a gaseous or phase while in the wellbore.

Abstract: A wellbore servicing composition comprising a base fluid, the base fluid comprising a substantially aqueous fluid, a brine, an emulsion, an invert emulsion, an oleaginous fluid, or combinations thereof, a quantity of template assisted crystallization beads, and a wellbore servicing fluid component, the wellbore servicing fluid component comprising a quantity of proppant, a quantity of gravel, or combinations thereof. A wellbore servicing system comprising a flowpath, the flowpath comprising at least one component of wellbore servicing equipment, and a conduit extending from the at least one component of wellbore servicing equipment to a wellbore, and a wellbore servicing fluid disposed within the flowpath, wherein the wellbore servicing fluid comprises a plurality of template assisted crystallization beads.

Abstract: A process for recovering oil from a carbonate reservoir of high salinity, wherein supercritical CO2 floodings are combined with a fluorosurfactant in the tertiary recovery. Embodiments include alternating injection and co-injection schemes of the supercritical CO2 and the fluorosurfactant. A stable fluorosurfactant-CO2 foam that is not susceptible to the harsh conditions of the reservoir (temperature, pressure and salinity) can be successfully generated, leading to a reduction in the mobility of CO2, an increase in the mobility of the reservoir oil, higher contact between the injected fluid with the oil and a better sweep efficiency of the oil.

Abstract: Ampholyte polymeric compounds that comprise at least one nonionic monomer, at least one sulfonic acid-containing monomer, and at least one cationic monomer may be useful as friction reducing agents in treatment fluids for use in subterranean operations at a concentration of about 0.001 v/v % to about 0.5 v/v % of the treatment fluid. Such operations may involve introducing the treatment fluid into a wellbore penetrating a subterranean formation optionally at a rate and/or a pressure sufficient to create or extend at least one fracture in the subterranean formation.

Abstract: Boronated biopolymer crosslinking agents useful in producing viscosified treatment fluids that include an aqueous fluid, a base polymer, and the boronated biopolymer crosslinking agent, wherein the boronated biopolymer crosslinking agent comprises a biopolymer derivatized with a boronic acid, a boronate ester, or both. Such viscosified treatment fluids may be useful in fracturing operations, gravel packing operations, drilling operations, and the like.

Abstract: A self-adaptive cement formulation includes cement, water and thermoplastic block-polymer particles. The set cement demonstrates self-healing properties when exposed to methane, and is particularly suited for well-cementing applications. After placement and curing, the self healing properties help maintain zonal isolation should bonding be disrupted between the set cement and the formation or a casing string, should cracks or defects appear in the set-cement matrix, or both.

Abstract: The present invention provides a method of isolating a selected reservoir zone in a subterranean reservoir comprising at least the step of squeezing a treatment fluid into the selected reservoir zone, the treatment fluid comprising: a viscosifying agent; a fluid loss control agent; and a particulate material. The invention further provides a treatment fluid comprising a base fluid; a viscosifying agent; at least 20 kg/m3 of a fluid loss control agent; and a particulate material.

Abstract: A method of treating a geologic formation including injecting into a wellbore a high viscosity composition which comprises a base fluid wherein the base fluid has an initial viscosity of 100 cP or greater and which exhibits a decrease in viscosity upon exposure to a viscosity reducing agent, and fibers wherein the fibers exhibit flocking upon a decrease in the viscosity of the base fluid, and injecting into the wellbore a viscosity reducing agent wherein the viscosity reducing agent is injected into the wellbore with or separately from the high viscosity composition is provided.

Abstract: A transition fluid comprises: a hydrocarbon liquid, wherein the hydrocarbon liquid is the external phase of the transition fluid; an aqueous liquid, wherein the aqueous liquid is the internal phase of the transition fluid and wherein the aqueous liquid comprises a water-soluble salt; and a calcium aluminate cement. A method of cementing in a subterranean formation comprises: introducing the transition fluid into the subterranean formation; and introducing a cement composition into the subterranean formation, wherein the step of introducing the cement composition is performed after the step of introducing the transition fluid and wherein the cement composition comprises cement and water.

Abstract: One or more specific embodiments herein includes a method for hydraulically re-fracturing a shale formation comprising injecting oxidizer through a horizontal wellbore into a fracture in the shale formation comprising pores containing hydrocarbon gas or liquid, and recovering some of the hydrocarbon gas or liquid from the shale formation. Some of the injected oxidizer combusts and increases the temperature of a portion of the shale formation and of the hydrocarbon gas or liquid contained in some of the pores in the shale formation, at least some of the hydrocarbon liquid is heated and turns to hydrocarbon gas, the pressure of some of the hydrocarbon gas increases to a point sufficient to cause formation of new fractures, and some of the hydrocarbon gas passes from the pores through some of the new fractures and can be thereafter recovered.

Abstract: A drilling fluid system using retarded acid systems such as gelled acid (VES or polymer) and/or emulsified acid to drill carbonate formations (calcite and dolomite). Foamed acid may be used in low abnormal pressure carbonate reservoirs. The drilling fluid system permits drilling a target hydrocarbon-producing formation with zero-invasion of the drilling fluid system. A method for using the drilling fluid system for fluid loss control during drilling operations.

Abstract: The invention provides methods for treating a portion or treatment zone of a well that include introducing one or more treatment fluids into the well, wherein the one or more treatment fluids include: (i) a first reactant and a second reactant, wherein the first reactant and second reactant are selected for being capable of reacting together in an exothermic chemical reaction, and wherein the first and second reactant are in at least sufficient concentrations in the carrier fluid to generate a theoretical heat of reaction of at least 500 kJ/liter of at least one of the treatment fluids; and (ii) a treatment chemical in at least one of the treatment fluids, wherein the treatment chemical is selected for chemically reacting with a substance of a material in the portion or treatment zone of the well. The exothermic reactants and the treatment chemical can be introduced in a single treatment fluid or in separate treatment fluids.