Abstract: Breaker fluids for removing polyolefin agglomerations from wellbore equipment and subterranean formations. An example breaker fluid includes an acid, at least one oxidizer, a corrosion inhibitor, a surfactant, an asphaltene remover, a sludging inhibitor, and an aqueous base fluid. The breaker fluid is introduced to wellbore equipment and subterranean formations and breaks down polyolefin agglomerations present therein.

Abstract: A foam composition includes a foam stabilizer, a foaming agent, a brine, and an inert gas. The foam stabilizer includes graphene. The foaming agent includes a viscoelastic surfactant. The inert gas is in the form of gas bubbles dispersed through a mixture of the foam stabilizer, the foaming agent, and the brine. The foam composition is configured to convert to a gel that is substantially impermeable to fluid flow in response to exposure to downhole conditions of a subterranean zone.

Abstract: A method for consolidating a subterranean geologic formation is provided. The method includes injecting a first composition, a second composition, and a third composition into the subterranean geologic formation. The first composition includes CaO, the second composition includes MgO, and the third composition includes NH4HF2. The method includes injecting at least one thermochemical fluid into the subterranean geologic formation to raise a temperature of the subterranean geologic formation to at least 120° C. The method includes reacting the third composition respectively with the first composition and the second composition to form CaF2 and MgF2 in the subterranean geologic formation. The method includes precipitating the CaF2 and the MgF2 on sand grains of the subterranean geologic formation to bind the sand grains together into a consolidated matrix in the subterranean geologic formation.

Abstract: A method for consolidating a subterranean geologic formation is provided. The method includes injecting a first composition, a second composition, and a third composition into the subterranean geologic formation. The first composition includes CaO, the second composition includes MgO, and the third composition includes NH4HF2. The method includes injecting at least one thermochemical fluid into the subterranean geologic formation to raise a temperature of the subterranean geologic formation to at least 120° C. The method includes reacting the third composition respectively with the first composition and the second composition to form CaF2 and MgF2 in the subterranean geologic formation. The method includes precipitating the CaF2 and the MgF2 on sand grains of the subterranean geologic formation to bind the sand grains together into a consolidated matrix in the subterranean geologic formation.

Abstract: A method for consolidating a subterranean geologic formation is provided. The method includes injecting a first composition, a second composition, and a third composition into the subterranean geologic formation. The first composition includes CaO, the second composition includes MgO, and the third composition includes NH4HF2. The method includes injecting at least one thermochemical fluid into the subterranean geologic formation to raise a temperature of the subterranean geologic formation to at least 120° C. The method includes reacting the third composition respectively with the first composition and the second composition to form CaF2 and MgF2 in the subterranean geologic formation. The method includes precipitating the CaF2 and the MgF2 on sand grains of the subterranean geologic formation to bind the sand grains together into a consolidated matrix in the subterranean geologic formation.

Abstract: An encapsulated lost circulation material includes: a particulate having a core including a compressed shape-memory polymer foam, and a disintegrating agent, the disintegrating agent including at least one of a phase change material or a gas-producing material; and a shell encapsulating the core. A method of reducing lost circulation includes: introducing into a subsurface a wellbore fluid including the encapsulated lost circulation material; heating the disintegrating agent to cause the phase change material to expand, or to cause the gas-producing material to produce a gas, or a combination thereof to break the shell; and releasing the compressed shape-memory polymer foam from the encapsulated lost circulation material; expanding the released shape-memory polymer foam; and filling a void or fracture of the subsurface with the expanded compressed shape-memory polymer foam to reduce fluid loss.

Abstract: A method of reducing water production in a wellbore may include introducing an alkaline nanosilica dispersion to the wellbore such that it contacts a water producing zone of the wellbore, introducing a sodium bicarbonate activator to the wellbore such that it contacts the alkaline nanosilica dispersion in the water producing zone, and forming a gelled solid from the water shutoff material in the water producing zone, thereby reducing water production in the wellbore.

Abstract: A hardened cement produced by setting a cement slurry including graphene comprising bioderived renewable graphene (BRG), a cement, and water. The graphene of the cement slurry comprises, consists essentially of, or consists of BRG, and the cement slurry comprises at least 0.2 (e.g., from about 0.2 to about 20) percent graphene comprising BRG by weight of cement (% graphene bwoc). The hardened cement produced by allowing the cement slurry to set has one or more enhanced mechanical properties (e.g., increased Young's modulus (YM), increased compressive strength (CS), or increased resiliency as indicated by an increased reduction in a ratio of YM/CS) relative to a same hardened cement produced by allowing to set a same cement slurry comprising a same total amount of graphene, with synthetic graphene (SG) in place of at least a portion of the BRG. Methods of cementing with the cement slurry are also provided.

Abstract: A resin slurry for a fractured-vuggy formation and the preparation and use thereof, which belong to the field of drilling fluid lost circulation control. The resin slurry plugging system is composed of the following raw materials in mass percentage: 20%-40% of composite resin plugging agent, 0.5%-5.0% of consolidating agent, 0.5%-5.0% of flow pattern regulator, 0.3%-1.2% of cross-linking agent, 0.3%-1.2% of retarder, 3%-12% of filling agent, and the balance of water. The plugging system has a certain fluidity under low-temperature conditions, is easy to be injected into the formation, and can fill a lose channel of a fractured-vuggy reservoir. The consolidating time of the plugging system is controllable, and the construction conditions are safe. The plugging system forms a three-dimensional cross-linked network structure consolidation after cross-linking and consolidating under high-temperature conditions of the formation.

Abstract: A method of removing hydrogen sulfide from a subterranean geological formation includes injecting a drilling fluid suspension in the subterranean geological formation. The drilling fluid suspension has a pH of 10 or more and includes a layered triple hydroxide material, including manganese, copper, and aluminum, in an amount of 0.01 to 1.5 percent by weight of the drilling fluid suspension. The method further includes circulating the drilling fluid suspension in the subterranean geological formation and forming a water-based mud and scavenging the hydrogen sulfide from the subterranean geological formation by reacting the hydrogen sulfide with the layered triple hydroxide material in the water-based mud.

Abstract: A plug for Plug and Abandonment (P&A) operations. The plug is a two-part plug of bismuth-based alloy and resin, allowing for sealing of an oil well using two different mechanisms with a shorter plug. The sealing can be rock-to-rock and/or cast-in-place.

Abstract: A method of fracturing a subsurface formation includes super-cooling liquid carbon dioxide to a temperature between ?60° F. to ?70° F. using liquid nitrogen having a temperature in a range of ?100° F. to ?200° F., pumping the lipid carbon dioxide down a wellbore to create fractures in the subsurface formation, and pumping fracturing fluid containing a proppant down the wellbore after pumping the liquid carbon dioxide down the wellbore.

Abstract: A method for consolidating a subterranean geologic formation is provided. The method includes injecting a first composition, a second composition, and a third composition into the subterranean geologic formation. The first composition includes CaO, the second composition includes MgO, and the third composition includes NH4HF2. The method includes injecting at least one thermochemical fluid into the subterranean geologic formation to raise a temperature of the subterranean geologic formation to at least 120° C. The method includes reacting the third composition respectively with the first composition and the second composition to form CaF2 and MgF2 in the subterranean geologic formation. The method includes precipitating the CaF2 and the MgF2 on sand grains of the subterranean geologic formation to bind the sand grains together into a consolidated matrix in the subterranean geologic formation.

Abstract: A method of non-mechanically remediating damage to a wellbore comprising a plurality of fracture stages is disclosed. A total treatment volume is calculated based on the plurality of fracture stages, the wellbore space, and either the production tubing or the annulus of the wellbore. The fracture stages of the wellbore are then divided into a plurality of chemical stages. The wellbore is pre-flushed, and each chemical stage is treated and isolated in order of depth by a volume of remediation chemicals and a volume of diverter. A post-treatment flush completes the remediation process and after a shut-in period, the well's production is substantially improved.

Abstract: Methods for storing carbon dioxide in a subsurface formation include identifying a plurality of negative geologic closures in the subsurface formation. The dimensions of the plurality of negative geologic closures are characterized. Layers of subsurface formation in the vicinity the negative geologic closures are characterized. One of the negative geologic closures is selected for bottom-up storage of carbon dioxide based on the characterized dimensions and layers.

Abstract: A method includes deploying a solid epoxy material into a target region of a pipe and delivering a liquid epoxy formulation into the target region of the pipe so that the liquid epoxy formulation fills voids around the solid epoxy material and inside the pipe within the target region, wherein the liquid epoxy formulation cures within the voids to form a solid epoxy plug with the solid epoxy material within the target region of the pipe.

Abstract: In a system for producing power and capturing carbon dioxide (CO2) at an offshore site, separator units separate a fluid produced from an offshore vessel in fluid communication with a reservoir into water, oil, and gas. The gas is sent to oxy-firing gas turbine generator units. Air separation units separate an air into nitrogen and oxygen. The oxygen is sent to the oxy-firing gas turbine generator units. Gas compression units compress an exhaust gas from the oxy-firing gas turbine generator units. Dehydration units dehydrate the compressed exhaust gas, and a portion of the dehydrated compressed exhaust gas is recycled back to the oxy-firing gas turbine generator units. Gas pumps inject a remaining portion of the dehydrated compressed exhaust gas into the reservoir. Additionally, the oxy-firing gas turbine generator units generates electricity with the oxygen, the gas, and the portion of the dehydrated compressed exhaust gas.

Abstract: Bismuth-based alloys comprising at least about 50% by weight bismuth, about 30 to about 35% by weight tin, and about 1.8 to about 2.8% by weight antimony; and an alloy of bismuth and silver comprising about 90 to about 97% by weight bismuth and about 3 to about 9% by weight silver. A plug comprising an alloy of bismuth, tin, and antimony; and a plug comprising an alloy of bismuth and silver. A method of using a plug made from a bismuth-based alloy to seal a well, wherein a length of a well is filled with the molten alloy and the molten alloy is allowed to solidify.

Abstract: Methods for hydraulically fracturing a subterranean formation to improve the production rates and ultimate recovery by contacting unconsolidated resin-coated proppant particulates residing in a propped fracture with a reactive crosslinker in order to form a consolidated proppant pack are described. Additionally, methods for use in water injection wells to consolidate the resin-coated proppant particulates in a gravel packed or frac packed region of a wellbore are also described.

Abstract: The effectiveness of expansive cement systems may be diluted when, during a well cementing operation, commingling takes place between the cement slurry and a spacer fluid, a drilling fluid, or both. Incorporating expansive agents in the spacer fluid or drilling fluid may reduce or negate the loss of expansion at the cement slurry/spacer interface or the cement slurry/drilling fluid interface, thereby promoting zonal isolation throughout the cemented interval.