Abstract: A tool (1), for example, a tool for use downhole in a tubular oil or gas well, and a method of deploying and operating the tool (1), are disclosed herein. The tool (1) includes a generally cylindrical body (4), which includes a chamber (6). A fuel source (8) is also included. The fuel source (8) is a pressurised fuel and oxidant mixture (9) which is released into the chamber by an injector device through injector nozzles (16). The fuel and oxidant mixture (9) is ignited to form a combustion jet (20). The combustion jet (20) exits the nozzle outlet (28) as directed combustion jets, which perforate the walls of the tubular oil or gas well 30, wherein the walls of the tubular oil or gas well represent a material to be manipulated.

Abstract: A multicomponent nanocapsule composition comprising a core particle, an oil phase encapsulating the core particle, and an aqueous phase in which the encapsulated core particle is suspended is provided. The porous particle includes a cationic surfactant encapsulated in a porous particle. The oil phase includes an anionic surfactant and a zwitterionic surfactant. A method of making a multicomponent nanocapsule composition is also provided. A method of treating a hydrocarbon-bearing formation with the multicomponent nanocapsule composition is provided. The method may include providing a multicomponent nanocapsule composition, introducing the multicomponent nanocapsule composition into the hydrocarbon-bearing formation, displacing hydrocarbons from the hydrocarbon-bearing formation by contacting the multicomponent nanocapsule composition with the hydrocarbons, and recovering the hydrocarbons.

Abstract: Compositions and methods for providing water shut off within a water producing zone of a wellbore. The composition includes alkaline nanosilica particles and hydrolysable ester-based 3D engineered non-convex particles. The method includes dissolving the hydrolysable ester-based 3D engineered non-convex particles to release an acid, which reacts with the alkaline nanosilica particles to form a solid.

Abstract: The present disclosure relates to a composition and a method to use it for releasing the oil trapped in tight oil reservoirs.

Abstract: A composition and methods are provided for stimulating a well with nanobubbles. An exemplary method includes obtaining a stimulation fluid and generating a nanobubbles solution, wherein the nanobubbles solution includes nano-sized bubbles in the stimulation fluid. The nanobubbles solution is injected into the oil well.

Abstract: A hydraulic fracture fluid is provided. The fluid can include a liquid solvent, one or more surfactants, a proppant-forming compound, and one or more curing agents. The liquid reacts to form proppant in-situ under downhole conditions.

Abstract: A foamed composition includes a base fluid, a graphene particle, one or more surfactants, a gas, and an inorganic acid. The foamed composition has a foam quality in a range from 50 to 90 vol/vol % at a temperature in a range from 120° C. to 165° C. A method of stimulating a hydrocarbon-bearing formation includes introducing the foaming composition into the hydrocarbon-bearing formation under a pressure greater than fracturing pressure of the hydrocarbon-bearing formation to generate fractures in the hydrocarbon-bearing formation and generating a foam from the foaming composition inside the hydrocarbon-bearing formation using a gas. The foam has a half-life of 130 to 260 min at 200° F.

Abstract: Described is a system for targeted waterflooding in an oil field. The system includes a mobile reverse osmosis unit connected with source water. The mobile reverse osmosis unit generates low salinity fresh water from the source water. An injection manifold is connected with the mobile reverse osmosis unit. The injection manifold distributes the low salinity fresh water into injection wells within the oil field. The low salinity fresh water is stored underground prior to its use in production wells.

Abstract: Systems and methods presented herein relate to processing produced oilfield brine by deconstructing it into two useful components: (1) desalinated water and (2) a suspension of solid-state salt (e.g., crystallized salt) slurried in a salt-saturated brine, which may be formulated and injected into hydrocarbon-producing formations above hydraulic fracturing pressure to intentionally create regions of localized high stress within the respective formations. In addition, systems and methods presented herein relate to processing oilfield brine received from hydrocarbon-producing wells by: (1) coupling high-pressure desalination technologies with saltwater disposal (SWD) operations, (2) active management of SWD water composition at the rock face through dual stream (e.g., split-stream) injection, and/or (3) coupled SWD injection, flow assurance, and stimulation to minimize SWD formation damage and injection pressures.

Abstract: A method including reacting carbon dioxide from exhaust gas produced at a wellsite to produce a solid metal carbonate, and microwaving the solid metal carbonate to produce recovered carbon dioxide and solid metal alkaline. A system for carrying out the method is also provided.

Abstract: The present disclosure provides a self-generating heat process for in-situ converting medium-low mature and organic-rich shale, and relates to the field of in-situ mining of medium-low mature shale rich in organic matter, the self-generating heat process mainly comprises the following steps: locally preheating the vincinity of an injection well of medium-low mature and organic-rich shale formation with well-reformed reservoir and injecting ambient temperature air into the preheated formation to excite and establish a chemical reaction zone composed of a residue zone, an autogenous heat zone, a thermal cracking zone and a preheating zone. Heat is released by oxidation reaction of residues generated after kerogen thermal cracking, so as to realize convection heating of medium-low mature and organic-rich shale formation. Oil and gas products generated from kerogen thermal cracking enter production wells through fractures and are lifted to the ground surface.

Abstract: The disclosure relates to catalysts that include a fibrous silica support and a plurality of metal oxide nanoparticles including iron oxide and nickel oxide, and methods of making and using such catalysts. The fibrous silica support is a particle with radially extending fibers. The catalyst can used to convert methane into hydrogen gas. The catalysts can be introduced into an underground formation, such as with a fracking fluid, for in-situ methane conversion.

Abstract: Embodiments herein are directed to a method for forming a solidified fluid barrier in a wellhead including: injecting a wellhead sealing composition into a first flow line, a second flow line, a crown valve, or combinations thereof of the wellhead, the wellhead including at least a wellbore casing, a master valve, a fluid chamber, a first wing valve, a second wing valve, and a crown valve; pumping the wellhead sealing composition including a cyclodextrin, water, and an azaarene into the fluid chamber of the wellhead; and heating the wellhead sealing composition to solidify the wellhead sealing composition in the fluid chamber. Further embodiments herein are directed to a wellhead for a subsurface well including a wellbore casing, a master valve, a fluid chamber including a solidified fluid barrier including alpha-cyclodextrin, water, and 4-methylpyridine, a first wing valve, a second wing valve, and a crown valve.

Abstract: Methods and systems including introducing a treatment fluid into a subterranean formation wellbore. The treatment fluid includes an aqueous base fluid; nitrogen-containing waste plastic; and carbon dioxide. The nitrogen-containing waste plastic is hydrolyzed in the aqueous base fluid under conditions in the subterranean formation wellbore, thereby forming hydrolysis reaction products. The hydrolysis reaction products and the carbon dioxide are reacted in the subterranean formation wellbore.

Abstract: A method of stimulating a geological formation and sequestering CO2 in the geological formation may include positioning an acidic fracturing fluid comprising dissolved CO2 and CO2 microbubbles and/or CO2 nanobubbles in the geological formation, hydraulic fracturing the geological formation, acidizing the geological formation with the acidic fracturing fluid, thereby increasing a permeability of the geological formation, and sequestering CO2 by reacting the CO2 in the acidic fracturing fluid with reactive rock in the geological formation to form carbonates.

Abstract: Systems and techniques may include enhancing production of a natural resource from a reservoir in the earth. By pumping and circulating a material through a reservoir, where the material interacts with proppant or formation material in fracture zones, the interaction reduces permeability in an overproductive fracture zone and redirects flow to an underproductive fracture zone. Through this self-correcting feedback mechanism, flow redistributes more uniformly across multiple fracture zones over time, resulting in more even permeability distribution and improved reservoir performance. The systems and techniques enable passive treatment using chemical solutions that create self-correcting permeability changes, leading to more controlled and efficient resource recovery from subsurface reservoirs.

Abstract: Methods of cleanup for hydraulic fracturing operations using a polymeric thickening agent may include use of exothermically reactive salts. For example, a method of cleanup may include use of a first fluid including a first exothermically reactive salt and a second fluid including a second exothermically reactive salt. Upon introduction into a subterranean reservoir, exothermically reactive salts may undergo an exothermic reaction to generate heat, and such heat generated from the exothermic reaction may break a polymeric thickening agent and decrease viscosity thereof.

Abstract: Wellbore treatment fluids are provided that include an aqueous component and an amphiphilic hyperbranched copolymer comprising the polymerized reaction product of at least a first monomer and a second monomer, where the first monomer comprises at least one surface reactive end group chosen from the group consisting of carboxylates, phosphonates, sulfonates, and zwitterions. Also provided are methods of modifying subsurface energy of a carbonate formation using the wellbore treatment fluids.

Abstract: Methods for initiating chemical reactions in a wellbore include delivering one or more reactive components via a carrier fluid to the wellbore. The one or more reactive components delivered to the wellbore are configured to enable one or more chemical reactions to occur. The one or more chemical reactions are carried out until a threshold volume of the one or more reactive components is delivered to the wellbore.

Abstract: Methods and apparatus are provided for disposal of Fat, Oil and Grease (FOG) wastes in subterranean formations, and for disposal of low-density organic wastes in subterranean, brine-filled caverns.