Abstract: Bentonite-based grout fluids and methods of using the grout fluids are provided. A method of using a grout fluid includes placing a geothermal conduit in at least one hole in the earth, providing a grout fluid consisting essentially of water and a bentonite-based grout, wherein the bentonite-based grout consists essentially of calcium carbonate, a bentonite, one or more grout-setting modifiers, and one or more thermally conductive materials, introducing the grout fluid into a space between the geothermal conduit and sidewalls of the at least one hole so that the grout fluid is in contact with the geothermal conduit, and after introducing the grout fluid, allowing the grout fluid to set to fix the geothermal conduit to the at least one hole, wherein after setting, the grout fluid has a hydraulic conductivity of between about 1×10?7 cm/s and about 1×10?9 cm/s.

Abstract: Methods of natural gas production and carbon sequestration are provided. The method includes delivering a feedstock downhole to a coal reservoir, generating biogas within the coal reservoir, and harvesting the biogas. Another method for tracing the migration of biogas in a coal reservoir includes delivering a feedstock downhole to a coal reservoir, generating biogas that is isotopically differentiable from a background gas within the coal reservoir through microbial action, harvesting the biogas, analyzing the biogas from the coal reservoir at the injection well and at one or more offset wells within the same coal reservoir, detecting the biogas at the offset wells using isotopic differentiation, and mapping the migration of the biogas from the injection well to the offset wells using the biogas as an isotopic tracer.

Abstract: A method for inhibiting water permeation in an extraction well of a hydrocarbon fluid from an underground reservoir may include: supplying a water-in-oil emulsion including an oily continuous phase and an aqueous discontinuous phase containing a plurality of particles of at least one hydrogel containing a cationic polymer; and positioning the water-in-oil emulsion in contact with the underground reservoir. A treatment fluid for hydrocarbon fluid extraction wells may contain a water-in-oil emulsion including an oily continuous phase and an aqueous discontinuous phase containing a plurality of particles of at least one hydrogel containing a cationic polymer.

Abstract: A method including entraining carbon dioxide (CO2) in a cement slurry composition and subjecting the cement slurry composition to conditions under which the CO2 achieves and maintains a supercritical state; and allowing the cement slurry composition to harden to form a hardened cement having CO2 sequestered therein.

Abstract: A flow conveyed plugging device for use in a well, the device can include a body, and one or more lines extending outwardly from the body, each of the lines having a lateral dimension that is substantially smaller than a size of the body. A method of plugging an opening in a well can include deploying at least one flow conveyed plugging device into the well, the flow conveyed plugging device including a body and, extending outwardly from the body, at least one of the group consisting of: a) one or more fibers and b) one or more lines, the flow conveyed plugging device being conveyed by flow in the well into sealing engagement with the opening. Another flow conveyed plugging device can include a body, and fibers extending outwardly from the body. The flow conveyed plugging device degrades and thereby permits flow through an opening in the well.

Abstract: A structural stabilizer for a fiber and proppant complex to enhance proppant migration and placement in a fractured well during propping and a preparation method thereof are provided. The structural stabilizer consists of: water, inorganic salt, kaolinite, nitrogen-doped modified graphene oxide, anionic surfactant, non-ionic alkyl polyglucoside, and polyacrylamide. The structural stabilizer improves bonding between a proppant and a fiber when slick water is used in stimulated reservoir volume (SRV) fracturing, prevents separation of the fiber and the proppant during migration, thereby reducing escape rate of the fiber from the fiber and proppant complex.

Abstract: Methods and compositions comprising one or more degraded in situ gelable polymers are provided. Use of such compositions and methods comprising one or more degraded in situ gelable polymers during enhanced oil recovery may result in an increase in oil production relative to methods and/or compositions which do not comprise one or more degraded in situ gelable polymers.

Abstract: An aqueous sol used in CO2 foam flooding, one of EOR flooding methods for recovering crude oil by injection into the oil reservoir of an onshore or offshore oil field, the aqueous sol increasing foam stability even over a substantial period of time, at high temperatures and pressures, and in salt water, thus improving crude oil recovery rate. The aqueous sol for increasing stability of froth or emulsion in a mixture containing carbon dioxide, water, and oil in CO2 foam flooding of EOR, the sol including silica particles having an average particle diameter of 1 to 100 nm as measured by dynamic light scattering and having surfaces at least partially coated with a silane compound having a hydrolyzable group, the silica particles serving as a dispersoid and dispersed in an aqueous solvent having a pH of 1.0 to 6.0 serving as a dispersion medium.

Abstract: Aqueous well treatment fluids especially suited for use in far field diversion in low viscosity carrier fluids comprise water, a friction reducer, and a diverter. The diverter comprises dissolvable particulates and proppants. The dissolvable particulates have a specific gravity of from about 0.9 to about 1.6 and a particle size of about 50 mesh or less. The proppants have a specific gravity of from about 0.9 to about 1.4 and a particle size of from about 20 to about 100 mesh. The dissolvable particulates have a higher specific gravity and a smaller particle size than the proppant.

Abstract: Methods are provided for producing hydrocarbons and recovering solvent from a subterranean reservoir that is penetrated by an injection well and a production well, in which a production phase involves injecting solvent (and optionally steam) to mobilize viscous hydrocarbons and a solvent-recovery phase involves non-condensable gas injection. The production phase and the solvent-recovery phase are each defined by an injection profile. The solvent-recovery-phase injection profile is selected: (i) based on the production-phase injection profile, and (ii) to ensure the pressure/temperature conditions in proximity to the production well favor gas-phase solvent recovery.

Abstract: A method of attenuating annular pressure buildup within a wellbore. The method includes accessing a wellbore, with the wellbore having an annulus disposed between first and second strings of casing. The method also includes placing a column of cement around the second string of casing generally below the first string of casing. The method further includes pumping a fluid mixture into the annulus, forming a fluid column. The fluid mixture comprises a carrier fluid, and a plurality of compressible particles dispersed in the carrier fluid. Each of the compressible particles is fabricated to partially collapse in response to thermal expansion of the fluid mixture. The method also includes placing a wellhead over the wellbore, thereby forming a trapped annulus in the wellbore. The method additionally includes at least partially sealing the annular region along at least one depth above the column of cement to inhibit vertical migration of the compressible particles.

Abstract: A wellbore isolation assembly includes an outer component and an inner component. The outer component is disposed at a first location in a wellbore. The inner component is disposed at a second location in the wellbore. The inner component is moved from the second location into engagement with the outer component at the first location to form a barrier within the wellbore. When deployed in the wellbore, the barrier inhibits passage of fluids. The wellbore isolation assembly is then retrieved from the wellbore.

Abstract: A method to incorporate calcined Saudi calcium bentonite as a low-density cement admixture in oil and gas well applications. Low-density cement systems were designed using the calcined Saudi calcium bentonite in an amount of from 10 to 30 weight % of the admixture to form a low-density cement slurry at a density of from 10 pounds per gallon (ppg) to 15 ppg; and injecting the low-density cement slurry into the well to seal the well from the geological formation; and curing the low-density cement slurry in the well to seal the well from the geological formation.

Abstract: Methods of fracturing a subterranean formation include introducing a fracturing fluid containing an aqueous medium, a viscosifying agent and a polyethylene oxide alkyl ether through a wellbore and into the subterranean formation, pressurizing the fracturing fluid to fracture the subterranean formation, and allowing the fracturing fluid to flow back into the wellbore from the subterranean formation. The polyethylene oxide alkyl ether useful in some embodiments is defined according to the formula: where R1 and R2 are independently selected from linear or branched alkyl groups having from 2 to 16 carbon atoms, and ‘n’ may be a value selected from within a range of from 1 to 100.

Abstract: A method of recovering crude oil from a reservoir by: determining a depletion pressure for providing a lights-depleted crude oil comprising a reduced amount of light ends including methane, nitrogen, carbon dioxide (CO2), or a combination thereof and having a CO2 multi contact Minimum Miscibility Pressure (CO2-MMP) below a CO2-MMP of a native crude oil, wherein the native crude oil is crude oil extracted from the reservoir prior to primary oil recovery therefrom; depleting the pressure of the reservoir from an initial reservoir pressure to the determined depletion pressure, thus providing the lights-depleted crude oil; repressurizing the reservoir to an operating pressure for recovering the lights-depleted crude oil from the reservoir via carbon dioxide (CO2) injection; injecting CO2 into the reservoir via at least one injection well; and recovering at least a portion of the lights-depleted crude oil from the reservoir via at least one production well.

Abstract: Provided are compositions and methods of using a liquid suspension of hollow particles comprising a plurality of hollow particles, water, a suspending aid, and a stabilizer selected from the group consisting of a non-ionic surfactant, a latex, an oleaginous fluid, porous silica, and combinations thereof. The liquid suspension is homogenous. An example method includes statically storing the liquid suspension in a container for at least one week; wherein the liquid suspension maintains a difference in density from the top of the container to the bottom of the container of less than one pound per gallon while stored. The method further includes adding the liquid suspension to a treatment fluid; wherein the liquid suspension reduces the density of the treatment fluid; and introducing the treatment fluid into a wellbore penetrating a subterranean formation.

Abstract: A slurry for treating a wellbore, comprising a base fluid and a plurality of pre-processed fiber flocks dispersed in the base fluid.

Abstract: A method of stimulating a subterranean carbonate formation includes delivering a composition comprising a hydrophobically modified polymer, a phosphorylated alkyl amino polycarboxylic acid, and a base treatment acid into the subterranean formation; and contacting the subterranean carbonate formation with the composition to form conductive flowpaths in the subterranean carbonate formation. The method may further include producing hydrocarbons from the subterranean carbonate formation. A composition for stimulating a subterranean formation includes a hydrophobically modified polymer; a phosphorylated alkyl amino polycarboxylic acid; and a base treatment acid.

Abstract: Stimulation treatments are designed and performed in a manner that takes into account radial acid flow into the formation. A reservoir core plug is selected and a liner core flow test is performed. The core flow test comprises measuring a flowing fraction, injecting into the core plug a treatment volume of at least one candidate stimulation fluid at an injection rate at reservoir conditions, and measuring an effective reaction rate constant. The linear flow data are then scaled to radial flow. A skin, an acid concentration at a wormhole tip and a fluid velocity at a wormhole tip are calculated. A stimulation treatment is then performed. The method can also be performed on analog cores. The stimulation treatment may be matrix acidizing, fracture acidizing or acidizing natural fractures.

Abstract: A method includes placing a fluid in a treatment zone of a wellbore, the fluid in fluid communication with a near wellbore region of a subterranean formation. At least one energetic event generating material is placed in the wellbore, and positioned adjacent and up hole from the fluid. An energetic event is generated from the at least one energetic event generating material, and at least one fracture is formed in the near wellbore region from the at least one energetic event applying a pressure pulse onto the fluid. In some aspects, the fluid is a viscous pill.