Abstract: Provided herein are liquid polymer (LP) compositions comprising a synthetic (co)polymer (e.g., an acrylamide (co)polymer), as well as methods for preparing inverted polymer solutions by inverting these LP compositions in an aqueous fluid. The resulting inverted polymer solutions can have a concentration of a synthetic (co)polymer (e.g., an acrylamide (co)polymer) of from 50 to 15,000 ppm, and a filter ratio of 1.5 or less at 15 psi using a 1.2 ?m filter. Also provided are methods of using these inverted polymer solutions in oil and gas operations, including enhanced oil recovery.

Abstract: A composition includes a continuous phase, a silica nanoparticle, methyl groups, and a quantum dot. The continuous phase includes ethanol or water. The silica nanoparticle has a diameter of less than 100 nanometers. The methyl groups are disposed on a surface of the silica nanoparticle. The quantum dot includes zinc oxide. The quantum dot is embedded in the silica nanoparticle.

Abstract: A method of forming a fluid loss material for a wellbore fluid includes mixing tannin at least one modifier to form a mixture, heating the mixture to a temperature greater than about 100° C. to react the tannin with the at least one modifier to form a modified tannin, and reacting the modified tannin with an amine to form an organophilic fluid loss material comprising the amine bonded to the modified tannin. Related organophilic fluid loss materials and methods of operating a wellbore are also disclosed.

Abstract: A pump includes a drive chamber with a drive piston and a production chamber with a production piston. The drive piston is coupled to the production piston. The pump further includes a passage in fluidic communication with the drive piston and a port fluidically coupling the passage with the production chamber. In operation, a first pressure is applied to fluid in the passage, thereby moving the drive piston. Then a second higher pressure is applied to fluid in the passage, thereby opening a valve associated with the port. In an example operation, fluid flows from the passage into the production chamber, and flushes gas out of the production chamber, thereby alleviating gas-locking. In another example operation, fluid including a treatment chemical flows from the passage into the production chamber. A surface equipment package includes a controller configured to monitor and control operation of the pump.

Abstract: Techniques for controlling an amount of an acid gas in a production fluid includes operating a completion assembly that includes a production tubular, a first zone completion assembly, and a second zone completion assembly. The techniques include circulating a first formation fluid into the production tubular with a first flow control valve; circulating a second formation fluid into the production tubular with a second flow control valve; determining an amount or percentage of an acid gas in a production fluid that includes a mixture of the first and second formation fluids; comparing the determined amount of percentage to a threshold value; and modulating at least one of the first or second flow control valves in response to the comparison so that the production fluid meets the threshold value of the amount or percentage of the acid gas.

Abstract: Methods are provided herein for an end-of-life recovery of mobilized hydrocarbons from a stranded hydrocarbon pay zone within a subterranean reservoir by way of a recovery well. In some embodiments, the stranded pay zone is located between mobilized hydrocarbon zones of thermal recovery operations. In some embodiments, the stranded pay zone is an upper stranded pay zone located above a mobilized hydrocarbon zone of a thermal recovery operation. In some embodiments, the stranded pay zone is a lower stranded pay zone located below a mobilized hydrocarbon zone of a thermal recovery operation. The methods herein involve commencing end-of-life recovery at an end-of-life stage after a production threshold is achieved for thermal recovery operations.

Abstract: A method of cementing an annular space between a pipe string and a well bore, the method comprising the steps of (a) providing a cement composition including a calcium-deficient calcium silicate; (b) mixing the cement composition with water to form a cement slurry; (c) mixing the cement slurry composition with carbon dioxide form a foamed cement; and (d) placing the foamed cement in the annular space between the pipe string and the wellbore.

Abstract: Rotating a casing during a cementing operation to ensure efficient displacement of cement slurry. More specifically, embodiments are directed towards a sub and rotating tool that are positioned above a first cement operation, wherein the rotating tool is positioned in a kickoff point or build section of a horizontal well.

Abstract: A cement slurry includes a set retarder comprising graphene, a cementitious material, and water; the graphene comprises bioderived renewable graphene (BRG). The cement slurry has from about 0.01 to about 20, from about 0.1 to about 15, or from about 0.5 to about 5 percent graphene by weight of cementitious material (% graphene bwoc). The cement slurry has an increased thickening time relative to a same cement slurry absent the graphene.

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: Surfactants for use in formulations and processes suitable for hydrocarbon recovery. These formulations, include formulations suitable for fracking, enhancing oil and or gas recovery, and the recovery and or production of bio-based oils.

Abstract: The present disclosure provides a system, method and apparatus for the removal of natural gas/methane from in situ loci within shale reservoirs to (i) provide fully de-carbonized surplus electricity, and (ii) power re-injection of the resulting carbon formed (CO.sub.2) upon combustion in an electric generator along with large volumes of atmospheric CO.sub.2, such as for large scale removal of CO.sub.2 from the Earth's surface/atmosphere.

Abstract: The present invention includes a cost effective custom-designed blend of organic chemicals to stimulate oil production. The invention includes a chemical composition for use in drilling operations for oil recovery and the method of using the chemical composition. The chemical composition includes an ammonia compound, an alcohol or polar organic compound, and aqueous carrier solution. The aqueous carrier solution is of sufficient volume such that it is operable to fully dissolve the ammonia compound and alcohol (or polar organic compound) in the aqueous carrier solution. Heating of the solution may be provide by encapsulated Polonium.

Abstract: A grout composition includes a grout binder comprising calcium sulfate, the grout binder constituting from about 25.0 weight percent to about 99.0 weight percent of the grout composition, and at least one thermal conductivity additive comprising graphite. A grout formed from the grout composition has a thermal conductivity greater than about 1.0 W/m·K. Related grout slurries formed from the grout composition, grouts, and methods of grouting a wellbore are also disclosed.

Abstract: Described are compositions and methods for use in oil and gas operations. The methods can decrease pressure drop along a lateral segment of a wellbore in an unconventional subterranean formation.

Abstract: The present disclosure relates to a multi-stage temporary plugging fracturing method based on a stress cage effect, a device thereof and a storage medium, which are applied to the technical field of oil and gas exploitation. The method includes: determining a plugging point by acquiring a weak stress position on a major fracture; determining the consumption of temporary plugging deflection fluid by calculating a net pressure in a fracture that needs to be increased to generate a branch deflection fracture at the position where a principal stress is minimum; plugging a weakest stress position in the major fracture to form an artificial shielding layer, preventing subsequent fluid pressure from passing forward, thereby changing a geostress field near this position, thus forming an additional induced stress field near the weak position, generating a stress cage effect, and realizing formation of a multi-stage temporary plugging branch fracture in vertical wells.

Abstract: The present invention discloses a supercritical CO2 thickener for shale gas reservoir based on hollow mesoporous silica nanoparticles and a preparation method thereof, and relates to the technical field of oil and gas field development. The preparation method of the thickener includes: reacting a monomer consisting of fluoroacrylate, styrene and vinyl acetate in a molar ratio of 3-5:1-2:1-2 with 2%-5% of a total weight of hollow mesoporous silica nanoparticles with carbon-carbon double bonds under the action of an initiator to obtain the thickener. The preparation method of the present invention does not involve the addition of organic solvents during the reaction process and thus does not cause harm to the human body. The thickener of the present invention has good CO2 viscosity-increasing effect and good sand carrying performance, and can effectively improve the fracturing effect.

Abstract: A wellbore debris removal apparatus comprises a crossover sub having a first sub end and a second sub end, wherein the crossover sub includes at least one slotted mechanism and includes a fluid passageway extending from the first sub end to the second sub end. The wellbore debris removal apparatus comprises a debris removal tube having at least one lug and a tube end to be placed in the crossover sub such that the debris removal tube is engaged with the at least one slotted mechanism of the crossover sub via the at least one lug.

Abstract: Drilling fluids and methods for drilling a wellbore. An example drilling fluid is a divalent brine aqueous base fluid having at least one dissolved divalent zinc salt and also a polymeric additive that is a cross-linked copolymer comprising a first comonomer of 2-acrylamido-2-methylpropanesulfonic acid in a first comonomer concentration of at least 50 mol % of the copolymer; wherein the polymeric additive additionally comprises a second comonomer comprising a N-vinyl amine-containing monomer, a terminal double bound-containing monomer, or a combination of a N-vinyl amine-containing monomer and a terminal double bound-containing monomer; wherein the second comonomer is present in a total second comonomer concentration of 50 mol % or less of the copolymer. The drilling fluid further includes a zinc solid.

Abstract: Disclosed herein is a composition comprising a cementitious material, a pozzolanic material, aplite, and an aqueous fluid. Also disclosed herein is a method of servicing a wellbore penetrating a subterranean formation, comprising: placing the composition into the wellbore; and allowing the composition to form a set cement. The composition can develop suitable mechanical properties and permeability after setting in a wellbore and be expansive.