Abstract: A system for generating hydrogen and enhancing wellbore injectivity and hydrocarbon recovery includes at least one wellbore having hydrocarbons, an injector for injecting an enriched aqueous fluid into the wellbore, a fluid sensor located at a target zone of the wellbore, an ignition source located at the target zone, and a hydrogen-permeable membrane located at the target zone. A method for generating hydrogen and enhancing wellbore injectivity and hydrocarbon recovery includes dissolving oxygen into an aqueous fluid to produce an enriched aqueous fluid, injecting the enriched aqueous fluid into a wellbore comprising hydrocarbons, and measuring the concentration of oxygen of the enriched aqueous fluid. The method further includes introducing a catalyst to the target zone, adjusting a concentration of the catalyst of the enriched aqueous fluid, igniting oxygen in the enriched aqueous fluid at the target zone, and separating the produced hydrogen from the gas mixture.

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: A method for storing CO2 includes identifying a depleted or partially depleted gas, gas condensate or oil reservoir having a plurality of injection wells and a plurality of production wells. The reservoir is then depleted. Once the reservoir is depleted or partially depleted, enhanced oil recovery and/or enhanced gas recovery is then performed on the reservoir where a first quantity of carbon dioxide is injected into the plurality of injection wells to displace the remaining oil and gas. Heat mining is then performed on the reservoir, where the second quantity of carbon dioxide is injected into the reservoir and the first and second quantities of carbon dioxide are subsequently produced to the surface for capture and conversion of geothermal heat of the first and second quantities of carbon dioxide into electricity. A third quantity of carbon dioxide is then injected and stored in the reservoir permanently.

Abstract: A drilling fluid comprising an alkaline earth metal mineral carrier, a process for producing a drilling fluid and the use of a loaded mineral carrier for the delivery of a surfactant to a drilling fluid.

Abstract: A diverter acid fluid composition for use in the stimulation of oil wells during exploration thereof, named Quovadis is disclosed. The diverter acid fluid may be used for stimulating oil wells during matrix acidification. The role thereof is to improve the efficiency of processes of stimulation of wells by acid treatment allowing the fluid to come into contact with regions of low permeability of the carbonate rock matrix, i.e., regions of difficult access. The diverter acid fluid also removes permanent formation damage around the well, allowing for greater coverage of the treatment and, consequently, better use of the treatment.

Abstract: A method for stimulating hydrogen production from an injection formation. This method includes the steps of providing a well traversing a subsurface into an injection formation containing hydrocarbons. Carbon dioxide, water, steam, and combustion gas are introduced into the injection formation via the well. Further, the injection formation is stimulated using one or more of infrasonic, sonic, and ultrasonic stimulation. The injection formation is monitored via one or more sensors located in the injection formation to determine one or more properties of reactions in the injection formation and the flow back effluent. Flowback operations are conducted to retrieve flowback effluent.

Abstract: One or more embodiments relates to a productive consolidated sand pack product. The sand pack product may be a cured resin that is bound to sand particles and has a porous structure. The sand pack product is obtained from curing a resin composition which may include a resin, a curing agent, a chemical blowing agent, a surfactant, a carrier fluid, a pH agent, and a salt. The porous volume may include one or more of trapped gas, bubbles, and open or connected pore space.

Abstract: A treatment fluid may be suitable for a hydrocarbon fluid extraction well. Such a treatment fluid may include a water-in-oil emulsion. The water-in-oil emulsion may include: an oily continuous phase; and an aqueous discontinuous phase comprising water and a plurality of particles comprising a hydrogel comprising a cationic polymer. The cationic polymer may include, in polymerized form, a monomer with one or more cationic groups. The cationic group may be a —N+—R1R2R3 group, wherein R1, R2, and R3, are independently H or a C1 to C4 alkyl group.

Abstract: The effervescent tablet for enhanced oil recovery is made of multi-walled carbon nanotubes (MWCNTs), sodium dodecyl sulfate (SDS), sodium phosphate monobasic (NaH2PO4), and sodium carbonate (Na2CO3). To perform enhanced oil recovery, a suspension is first prepared by adding the effervescent tablet to water. This preparation may be performed at room temperature. Steam is then injected into the oil well, followed by flooding the oil well with the suspension. One-third of the pore volume of an oil reservoir of the oil well may be injected with the steam, and two-thirds of the pore volume of the oil reservoir may be flooded with the suspension.

Abstract: A method of removing hydrogen sulfide from a subterranean geological formation includes mixing a cobalt-imidazolate material with an organic liquid containing one or more unsaturated oil to form a drilling fluid suspension with a pH of 10 or more. The cobalt-imidazolate material is a ZIF-67 and is present in an amount of 0.1 to 2.5 percent by weight of the drilling fluid suspension. The method further includes injecting the drilling fluid suspension in the subterranean geological formation and circulating the drilling fluid suspension in the subterranean geological formation and forming an oil-based mud to scavenge hydrogen sulfide from the subterranean geological formation.

Abstract: Methods include pumping a fracturing pad fluid into a subterranean formation under conditions of sufficient rate and pressure to create at least one fracture in the subterranean formation, the fracturing pad fluid including a carrier fluid and a plurality of bridging particles, the bridging particles forming a bridge in a fracture tip of a far field region of the formation. Methods further include forming a first plurality of fibers in situ into the subterranean formation to form a low permeability plug with the bridging particles, and pumping a proppant fluid comprising a plurality of proppant particles.

Abstract: An oil-based treatment fluid for use in subterranean operations may comprise an invert emulsion including an aqueous internal phase and an oil external phase. The aqueous internal phase is solids free and comprises a two-salt brine and a true crystallization temperature reduction additive. The two-salt brine comprises a bromide and a nitrate, wherein the bromide brine has a density of about 14.2 lbs/gal to about 17 lbs/gal. There are no additional salts in the aqueous internal phase; The bromide brine has a first true crystallization temperature without inclusion of a true crystallization temperature reduction additive and a second true crystallization temperature with a true crystallization temperature reduction additive that is lower than the first true crystallization temperature reduction additive.

Abstract: Described herein are methods of treating fluid including hydrocarbons, water, and polymer being produced from a hydrocarbon-bearing formation. The methods include adding a concentration of a viscosity reducer to the fluid to degrade the polymer present in the fluid and adding a concentration of a neutralizer to the fluid to neutralize the viscosity reducer in the fluid. The viscosity reducer is buffered at a pH of 7 or less. The addition of the concentration of the viscosity reducer is in a sufficient quantity to allow for complete chemical degradation of the polymer prior to the addition of the concentration of the neutralizer in the fluid such that excess viscosity reducer is present in the fluid.

Abstract: Methods and systems including a composition of a hydratable polymer slurry comprising a hydrocarbon-based solvent. The hydrocarbon-based solvent includes a hydratable polymer powder and at least one of a polar surfactant, a hydrocarbon-soluble polymer, and/or an organophilic clay, wherein the polymer slurry is prepared at a temperature greater than 22° C. by mixing.

Abstract: Methods and compositions for servicing a wellbore and, in certain embodiments, to the use of compositions in a wellbore to mitigate lost circulation. In some embodiments, the methods include providing a treatment fluid that includes an aqueous base fluid, a lost circulation material, and a rheology modifier that includes a nanocellulose material; introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation including a loss zone; and allowing the treatment fluid to rapidly defluidize in the loss zone.

Abstract: A method for preventing stratal water from breaking into bottom holes of gas, gas-condensate, or gas-hydrate wells includes performing an injection of a shielding agent into a bottomhole formation zone, for which an emulsion-suspension system (ESS) is used. The ESS system includes: 5-12 vol % of diesel fuel, 2-3 vol % of emulsifier, and 1.0-1.5 vol % of colloidal nano-particles of silicon dioxide, with the remainder being an aqueous solution of calcium chloride or potassium chloride. The emulsifier used is a composition comprising: 40-42 vol % of esters of linoleic or oleic acids and resin acids, 0.7-1 vol % of amine oxide, 0.5-1 vol % of lime-in-diesel fuel suspension or bentonite-in-diesel fuel suspension, with the remainder being diesel fuel.

Abstract: A coated article comprises an article, and one or more amide based coatings on an outer surface of the proppant particle, the amide based coating include the reaction product of an isocyanate component that includes at least one isocyanate and a carboxylic acid component that includes one or more poly-carboxylic acids.

Abstract: A method, system, and taggants (tracers) for quantifying zonal flow in a multi-lateral well having a wellbore with a first lateral and second lateral. The technique includes flowing first produced fluid from a formation via the first lateral into production tubing providing a first taggant through a first dosing tubing to the first lateral, and flowing second produced fluid from the formation via the second lateral into the production tubing and providing a second taggant through a second dosing tubing to the second lateral. A produced stream having the first produced fluid and the second produced fluid flows uphole through the production tubing and discharges from the wellbore. The produced stream may be analyzed to measure an amount of the first taggant in the produced stream and an amount of the second taggant in the produced stream.

Abstract: A tool for use in a wellbore includes an annular body having an inner flow passage extending axially therethrough, at least one gripping member positioned around an outer perimeter of a retainer section of the annular body, and a gate member positioned in the inner flow passage. When the gate member is in a closed configuration, an upstream portion of the inner flow passage is sealed from a downstream portion of the inner flow passage by the gate member. When the gate member is in an open configuration, the upstream portion of the inner flow passage is fluidly connected to the downstream portion of the inner flow passage. At least one static mixing blade extends through the downstream portion of the inner flow passage to mix fluid when it flows through the open gate member.

Abstract: A method for the fracking or stimulation of a hydrocarbon-bearing formation, said method comprising the steps of: providing a wellbore in need of stimulation; inserting a plug in the wellbore at a predetermined location; inserting a perforating tool and a spearhead or breakdown acid into the wellbore; positioning the tool at said predetermined location; perforating the wellbore with the tool thereby creating a perforated area; allowing the spearhead acid to come into contact with the perforated area for a predetermined period of time sufficient to prepare the formation for fracking or stimulation; removing the tool form the wellbore; and initiating the fracking of the perforated area using a fracking fluid. Also disclosed is a corrosion inhibiting composition for us with the acid composition.