Abstract: Method is provided for preventing fluid from entering a well, such as a producing well, during a hydraulic fracturing treatment in another well completed in the same reservoir. Degradable ball sealers or degradable particulate material is injected into the well and pressure is maintained in the well during the fracturing treatment to prevent influx of fluid.

Abstract: A process for providing steam from a steam source to a well located remote from the steam source, includes heating a first portion of a first pipe by directing steam along the first portion of the first pipe that extends along a first segment of a path between the steam source and the well, across a first cross-over pipe, and back to the steam source, along a first portion of a second pipe that extends along the first segment of the path. The process also includes heating a second portion of the first pipe by directing steam along the first portion and the second portion of the first pipe, across a second cross-over pipe, and back to the steam source along a second portion of the second pipe. The first pipe and the second pipe are utilized to transport steam to the well.

Abstract: Some implementations include an apparatus for washing a downhole tubular. The apparatus may include a head coupled to a rotatable shaft, the head including one or more jets configured to emit fluid to cause the head to rotate on the rotatable shaft and wash the downhole tubular. The apparatus may include one or more brakes coupled with the rotatable shaft and configured to control rotation of the head.

Abstract: A system includes a control system disposed on a well surface and a pipe component disposed in a wellbore to form an annulus that is in fluid communication with a reservoir. The system includes a valve in fluid communication with the annulus. The system includes a recorder configured to detect data of the annulus. The system includes a fluid conduit configured to flow annular fluid from one or more annuli disposed in the wellbore. The fluid conduit is in fluid communication with the annulus, the valve, and a relief tank. The system includes a communication cable coupled to the control system, the valve, and the recorder. The recorder is configured to transmit the data to the control system.

Abstract: A method of producing a cementitious material includes combining a reaction mixture to form a slurry and curing the slurry to form the cementitious material. The reaction mixture may include a mineral mixture, an organic compound, and CO2. The mineral mixture may include calcium and the organic compound may be 3,4-dihydroxyphenethylamine, methyl salicylate, or both.

Abstract: The subject invention provides microbe-based products, as well as their use to improve oil production and refining efficiency by, for example, remediating the disposable layers in oil tanks and other oil storage units. In preferred embodiments, the microbe-based products comprise biochemical-producing yeast and growth by-products thereof, such as, e.g., biosurfactants. The subject invention can be used to remediate rag layer and/or other dissolved solid layers that form in water-oil emulsions. Furthermore, the subject invention can be used for remediating solid impurities, such as sand, scale, rust and clay, in produced water, flow-back, brine, and/or fracking fluids.

Abstract: A method for designing a cement composition may include: providing a target compressive strength and a target composition density; selecting at least one cementitious material from a plurality of cementitious materials; calculating a required amount of water to produce a cement composition with the target composition density, the cement composition comprising the water and the at least one cementitious material; calculating a compressive strength of the cement composition based at least in part on a model of compressive strength; comparing the calculated compressive strength to the target compressive strength; and preparing the cement composition with the calculated compressive strength.

Abstract: Nano- and micro-particles (NMP) can be formed from an oil/water emulsion. The emulsion is made by mixing a liquid solvent, at least one surfactant, a particle-forming compound, and at least curing agent. If desired, pH control agents and viscosity enhancers can be added to the liquid solvent. The particle-forming compound and the curing agents are mixed together and form the oil phase in the emulsion and after curing, the particles are formed. The nano- and micro-particles can be used as proppant to enhance the conductivity of nano- and microfractures and fluid-loss-control additive for hydraulic fracturing operations.

Abstract: An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section coupled to the electric motor; a fluid intake coupled to an uphole end of the seal section, wherein the fluid intake defines a plurality of inlet ports; a gas separator comprising a plurality of gas phase discharge ports, and at least one liquid phase discharge port, wherein the gas separator is located uphole of the fluid intake; a centrifugal pump comprising a fluid inlet at a downhole end, wherein the at least one liquid phase discharge port of the gas separator is fluidically coupled to the fluid inlet of the centrifugal pump; and an inverted shroud assembly, wherein a downhole end of the inverted shroud assembly is coupled to an outside of the gas separator downhole of the gas phase discharge ports of the gas separator and uphole of the fluid intake.

Abstract: The present invention disclosed a method for underground separation of components in sulfur-containing flue gas and sequestration of carbon dioxide and sulfides, comprising: injecting sulfur-containing flue gas into injection well which is arranged in a well pattern of a sequestrated aquifer in advance; transiting and injecting formation water into the formation at a first preset injection speed by injection well of the well pattern after injecting the sulfur-containing flue gas for a first preset time, maintaining the first formation pressure, and conducting water drainage and gas production by a production well of the well pattern in a mode of a fixed bottom hole flowing pressure; and determining the well shut-in time according to the nitrogen molar concentration of the production well and conducting well shut-in. The separated N2 is produced, while the separated CO2 and sulfides are sequestered in aquifer, achieving effective underground separation of the flue gas components.

Abstract: A microwave drill bit capable of achieving fracturing of a borehole wall and end of a deep hard rock while drilling and a use method thereof are provided. The microwave drill bit comprises a microwave drill bit body, wherein a support frame front plate, a metal sleeve and a water inlet ring sequentially sleeve on the microwave drill bit body, the metal sleeve is connected with a rotary drive I mounted on the support frame front plate, the microwave drill body is connected with a microwave mode converter and a microwave splitter II respectively, the microwave mode converter and the microwave splitter II are connected with a microwave splitter I by a rectangular waveguide, the microwave splitter I is sequentially connected with a microwave rotating joint, a fixed waveguide and a microwave generator, and the microwave rotating joint is connected with a rotary drive II mounted on the support frame rear plate.

Abstract: A selective scraper tool configured to clean an inner surface of a downhole tubular comprising a scraper actuator configured to generate an activation force to deploy one or more scraper blades from corresponding windows on a blade assembly to contact the inner surface of the downhole tubular. A control device located between the scraper actuator and the blade assembly comprises a lug located within a control pattern with a first position and a second position. The first position configures the blade assembly in a retracted position. The second position deploys the scraper blades from the blade assembly. A pumping operation can direct the lug within the control pattern to travel from the first position to the second position.

Abstract: A method and a system for recovering oil from currently inaccessible oil containing geological units by activating the deep biosphere microbial seed bank. Nutrient and thermal enhancement of microorganisms in oil containing geological units allows for stimulation of inactive and/or dormant microorganisms such that they proliferate and produce gas. The oil viscosity that is decreased by heat, along with the gas pressure produced by activated microbes which allows previously inaccessible oil to flow toward production wells.

Abstract: A well system includes a wellhead arranged atop a wellbore, production tubing extending from the wellhead into the wellbore and thereby defining an annulus between the production tubing and an inner wall of a wellbore, and a plurality of fixed injection ports defined in the production tubing. The well system further includes a chemical injection system that includes one or more chemical conduits extending from the wellhead within the annulus and communicably coupled to the plurality of fixed injection ports and thereby placing the one or more chemical conduits in fluid communication with an interior of the production tubing, a chemical injection line in fluid communication with the one or more chemical conduits via the wellhead, and a pump arranged in the chemical injection line to convey one or more chemicals from the chemical storage tank to the production tubing via the one or more chemical conduits.

Abstract: A composition of an invert emulsion oil-based drilling fluid is provided. The composition may include an oil phase and an aqueous phase. The oil phase may include an oleaginous fluid, an organophilic clay-based solid viscosifier, and a liquid viscosifier including a POSS. Further provided is a method of introducing the composition including the POSS into a wellbore. After introduction of the composition into the wellbore, the method includes maintaining wellbore conditions to provide a stable rheological property for a period up to about 96 hours in an HPHT section of a wellbore.

Abstract: A displacement system designed for robust heterogeneous oil reservoirs and its application within the oil exploitation field. System comprises a polymer-enhanced foam plugging agent and an active polymer flooding agent. Plugging agent consists of 0.12% bio-polysaccharide polymer diutan gum foam stabilizer and 0.4% ?-olefin sulfonate foaming agent by mass. The active polymer flooding agent is formulated through free radical polymerization, with components comprising a total monomer concentration of 27.5%, wherein monomer A to monomer B ratio is 7.5:2.5, monomer C constitutes 5.5% of the total monomer concentration, and water comprises the remaining. Monomer A is acrylamide, monomer B is 2-acrylamide-2-methyl propane sulfonic acid, and monomer C is a quaternary ammonium salt type active monomer. Demonstrated through parallel core displacement experiments, this displacement system exhibits effective displacement in heterogeneous oil reservoirs with a permeability gradation of 30 at 65° C.

Abstract: A desander assembly retrievably positionable in a tubing string including a fishing neck, a bypass tool, a stop assembly configured to retrievably mate with a portion of the tubing string, an outer tubular member, and an inner tubular member. The outer tubular member has at least one aperture extending. The inner tubular member is positioned in the outer tubular member to form an annulus and so a bore of the inner tubular member is in fluid communication with the bypass tool. The inner tubular member has at least one spiral protrusion extending outwardly from the sidewall to cooperate with an interior side of the outer tubular member to form a spiral channel. The bore of the inner tubular member receives reservoir fluid that passes into the annulus formed between the inner tubular member and the outer tubular member via the apertures of the outer tubular member.

Abstract: This disclosure relates to thermal stimuli-responsive surfactant mixtures useful for reducing water/oil interfacial tension at high temperatures and increasing water/oil interfacial tension at low temperatures. The disclosure also relates to methods of using the surfactant mixtures for enhanced oil recovery applications.

Abstract: The method includes gathering field data of a formation, preparing samples of brine consistent with the composition of the formation brine and the injection brine, dead crude oil, and live crude oil, and characterizing the properties of crude oil samples. The method includes preparing samples of reservoir rock and characterizing the properties of the rock samples of the formation. The method includes measuring the contact angle of surfactant/formation brine/formation rock/formation crude oil samples at ambient and reservoir conditions and measuring the interfacial tension of the sample. The method includes characterizing the HLD properties of each surfactant. In addition, the method includes performing formulation targeting HLD=0 for a mixture of surfactants, performing laboratory evaluation of the HLD=0 formulation of the mixture of the surfactants to obtain values of oil recovery number, and testing the HLD=0 formulation of the mixture of the first and second selected surfactants in the formation.

Abstract: Systems, methods, and apparatus for producing wellbore fluids using drill cuttings, geopolymers, and/or mine tailings, and compositions relating to the same are disclosed. The drill cuttings, geopolymers, and/or mine tailings may be used to create appropriate wellbore fluids to be used in wellbore fluid supply systems, such as spacer fluids, lead barrier fluids, tail barrier fluids. In one embodiment, the wellbore fluids result in one or more substantially impermeable barrier sheaths within the wellbore, which barrier sheaths may be cementitious or non-cementitious.