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.

Abstract: A method, wellbore, and pill for treating a region of a subterranean formation adjacent a wellbore zone of the wellbore, including injecting a gellable treatment composition (e.g., as the pill) through the wellbore zone into the region of the subterranean formation adjacent the wellbore zone, allowing the gellable treatment composition to form nanoparticles in-situ in the region and gel in the region via heat provided by the region to prevent or reduce flow of an unwanted fluid from the region into the wellbore zone. The gellable treatment composition may include a zwitterionic gemini surfactant (ZGS).

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: Cementing in a subterranean formation may include, activating an extended-life cement composition by mixing at least the extended-life cement composition with a liquid activated pozzolan additive comprising a carrier fluid and an activated pozzolan, wherein the extended-life cement composition comprises water, pumice, hydrated lime, and a set retarder; introducing the extended-life cement composition into a subterranean formation; and allowing the extended-life cement composition to set to form a hardened mass in the subterranean 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.

Abstract: The present invention relates to artificially reducing the porosity of any potential flow paths in the near-wellbore region of a well or in permeable zones within or surrounding a well. In doing so, the permeability in this the targeted region will be significantly reduced, thus, preventing unwanted flow of subsurface fluids. The present invention concerns a method comprising applying a first and second solution comprising scale precursors to the porous media, wherein following this application, at least a portion of the scale precursors form at least two insoluble salts. Additionally, the present invention concerns a kit of parts comprising the first and second solutions.

Abstract: A well tool device includes a housing; a through bore provided axially through the well tool device; and a frangible disc supported in the through bore by a first supporting device and a second supporting device. The through bore is defined with a bore wall. The second supporting device is axially displaceable in relation to the first supporting device. The well tool includes a shear element for preventing axial displacement of the second supporting device; a sealing element arranged radially outside of the frangible disc and radially inside of the bore wall when the well tool device is in a first state, in which the sealing element together with the frangible disc is configured to prevent axial fluid flow between a first side of the frangible disc and a second side of the frangible disc; and a disintegration device.

Abstract: A well system includes a well extending from a surface into a formation, a Y-tool provided at an end of a tubing string extending through the well, a concentric coiled tubing string extending through the tubing string and through a bypass line of the Y-tool, and a plurality of treatment solutions provided at the surface of the well. The plurality of treatment solutions includes at least one component of a dissolvable gel, a gel dissolving solution, and at least one component of a non-dissolvable gel. A method for plugging a water zone in a hydrocarbon bearing formation and a method for reducing a concentration of produced water from a hydrocarbon bearing formation are also described.

Abstract: A method and compounds for enhanced oil recovery (EOR) including flooding of a mixture of water and one or more of the compounds in a geological formation. The compounds have a fluoroalkyl group.

Abstract: A method, and related apparatus, involves providing one or more drill pipe segments and disposing a quantity of lost circulation material objects within the one or more drill pipe segments. A retention element is provided to retain the lost circulation material objects within the one or more drill pipe segments. The one or more drill pipe segments are connected to a drill string at a wellbore, and drilling fluid is flowed through the drill string. The flowing of drilling fluid through the drill string causes the retention element to release the lost circulation material objects to propagate further.

Abstract: The present disclosure provides a method and system for acquiring an elastic modulus of a rock containing sedimentary rhythms, including: acquiring a rock sample containing sedimentary rhythms; measuring contents of rock elements in the rock sample at test points with an X-ray fluorescence (XRF) spectrometer, the test points being provided on different rhythms of the rock sample; determining a lithology of the rock sample according to the contents of the rock elements; determining an element-mineral relation equation according to the lithology; determining mineral components of the rock sample with the lithology and the element-mineral relation equation; determining a modulus coefficient of each of minerals according to the mineral components; and determining an elastic modulus of the rock sample according to the mineral components and the modulus coefficient of each of the minerals. The present disclosure can implement nondestructive testing on mechanical properties of rock samples.

Abstract: A swellable packer assembly that includes a mandrel, a sealing element disposed about a least a portion of the mandrel, and a degradable metal coating disposed about at least a portion of an outer surface of the sealing element. The degradable metal coating fluidly isolates the portion of an outer surface of the sealing element from an exterior of the coating and the sealing element is formed of a material responsive to exposure to a fluid in a wellbore to radially expand from the mandrel. The degradable metal coating is selectively removable from the mandrel downhole so as to expose the sealing element to the fluid in the wellbore.

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.

Abstract: Cement slurries are prepared that comprise water, a hydraulic cement, particles of an oil-absorbent particles and non-swellable hydrophobic particles. The particles are present in an amount sufficient to alter a property of a non-aqueous drilling fluid. The cement slurry is placed in a subterranean well, whereupon the slurry contacts residual drilling fluid on casing and formation surfaces. The oil-absorbent particles and hydrophobic particles in the cement slurry may reduce the mobility of the drilling fluid, thereby improving zonal isolation.

Abstract: Methods and compositions for modified well fluids. One method including combining an amount of a synthetic functionalized additive with an intermediate well fluid composition to form a synthetic functionalized additive-containing well fluid composition; the synthetic functionalized additive comprising a synthetic layered magnesium silicate that is covalently bonded to a functional group, and the intermediate well fluid composition comprising a water-based continuous phase with solid particles, wherein the synthetic functionalized additive increases suspension stability of the solid particles versus a well fluid composition comprising the solid particles without the synthetic functionalized additive.

Abstract: Cement slurries are prepared that comprise water, a hydraulic cement and particles of an oil-absorbent material. The particles are present in an amount sufficient to alter a property of a non-aqueous drilling fluid. The cement slurry is placed in a subterranean well, whereupon the slurry contacts residual drilling fluid on casing and formation surfaces. The oil-absorbent material in the cement slurry may reduce the mobility of the drilling fluid, thereby improving zonal isolation.

Abstract: A method for the subterranean regeneration of CO2-philic solvents and the sequestration of carbon dioxide may include exposing the CO2-philic solvent to a carbon dioxide-containing gas in an absorber to allow the CO2-philic solvent to absorb at least a portion of the carbon dioxide in the carbon dioxide-containing gas, thereby producing a CO2-containing solution. The CO2-containing solution may be supplied to one or more porous rock fractures via one or more injection conduits in fluid communication with the one or more porous rock fractures. The CO2-containing solution may be heated via heat provided by one or more rock fractures in order to release at least a portion of the absorbed carbon dioxide into the one or more rock fractures and thereby regenerate the CO2-philic solvent.

Abstract: Suspensions of elastomer particles for cement compositions and associated methods of cementing. An example method includes providing a suspension of elastomer particles. The suspension of elastomer particles includes elastomer particles, an aqueous fluid, a viscosifier, a surfactant, and a clay-based stabilizer. The suspension may be combined with a cement slurry to form a cement composition. The cement slurry includes a cement and a base fluid. The cement composition may be introduced into a wellbore penetrating a subterranean formation. The cement composition may be allowed to set in the wellbore.

Abstract: Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries have, among other attributes, an extended thickening time, leading to improved retardation, flowability, and pumpability and may be used, for instance, in the oil and gas drilling industry. The cement slurry includes water, microfine cement material, and bisphenol-F diglycidyl ether resin.

Abstract: Disclosed are a room temperature curable quick-setting high-strength alkali-activated fly ash (AAFA) cementitious material and a preparation method thereof, belonging to the technical field of building materials. The raw materials include: in parts by mass, 30-50 parts of undisturbed fly ash, 50-70 parts of highly reactive ultra-fine fly ash, and 12-18 parts of sodium hydroxide. Specifically, the AAFA with fast setting and high strength for room temperature curing is prepared by pretreatment of fly ash with sodium hydroxide exciter, based on a premise that the raw material system and preparation process are simplified and feasible.

Abstract: A geopolymer cementing fluid with controllable thickening time includes the following components in parts by weight: 100 parts of a cementitious material, 10 parts-30 parts of an activator, 0.2 parts-5 parts of a retarder, 0.4 parts-4 parts of an anti-settling agent, and 30 parts-70 parts of water. The geopolymer cementing fluid of the present invention has the advantages of controllable thickening time, excellent compressive strength, good settlement stability, good rheological properties, green and eco-friendly, and the like. The geopolymer cementing fluid can be better suited for the operations of oil and gas well cementing and ensure cementing safety.

Abstract: A method of setting a wellbore fluid includes injecting a drilling fluid including water, cementitious material, a phosphonic acid derivative, a sulfonate acrylic acid copolymer, and zinc oxide into a wellbore; introducing sodium hexametaphosphate to the drilling fluid to form the wellbore fluid; allowing the sodium hexametaphosphate to dissolve phosphonate-calcium complexes between the phosphonic acid derivative and the cementitious material, thereby reducing the hydration time; and allowing the water and cementitious material to react, thereby curing the wellbore fluid and forming a cement.

Abstract: Provided are methods, compositions, and systems embodying cement compositions and the synergistic effect of lost circulation materials (LCMs) and fluid loss control additives (FLCAs) thereupon for cementing subterranean zones. A method of subterranean well cementing, comprising providing a cement composition comprising a hydraulic cement, a first FLCA, a LCM, and water, wherein the first FLCA comprises a water-soluble polymer with repeating units comprising a 5- to 6-membered cyclic amide; introducing the cement composition into a wellbore penetrating a subterranean formation, wherein inclusion of the first FLCA and the LCM in the cement composition fluid reduces fluid loss into the subterranean formation, wherein the subterranean formation has fractures with a width of from about 1 micron to about 800 microns, and wherein the subterranean formation has a permeability of about 1 millidarcy to about 300 Darcy; and allowing the cement composition to set in the subterranean formation.

Abstract: A shearable sleeve supports a disintegrable plug element in a pipe string, and may include a first portion including a first circumferential end surface, a seat for supporting the disintegrable plug element, a second portion including a second circumferential end surface, and a surface extending axially between the first and second circumferential end surfaces and formed with one or more radial protrusions adapted to shear off from the rest of the sleeve when being exposed to a predefined axial force, and one or more recesses for receiving one or more loading devices for initiating disintegration of the disintegrable plug element upon contact with the plug, wherein one or more radial protrusions is/are axially offset relative to the first circumferential end surface. A plug device, as well as a plug assembly in a pipe string, may include the shearable sleeve.

Abstract: A wellbore is plugged using a bismuth alloy. The wellbore is arranged so that a liquid bismuth alloy sets with an excess pressure of the plug relative to the borehole fluid pressure along a desired seal height distance.

Abstract: A system for utilizing oolitic aragonite as a proppant in hydraulic fracking is provided. The system includes a proppant storage tank including a stockpile of the oolitic aragonite. The system further includes a proppant pumping unit operable to pump the oolitic aragonite from the proppant storage tank, through an underground shaft, and into an underground fracture proximate to the underground shaft.

Abstract: A rupture disc assembly and a float tool incorporating the rupture disc assembly is disclosed. The rupture disc assembly may include a rupture disc assembly comprising a rupture disc, an upper tubular portion and a lower tubular portion, and a securing mechanism for holding the rupture disc between the upper and lower tubular portions. A float tool for creating a buoyant chamber in a casing string may include the rupture disc assembly and a sealing device for sealing the lower end of the casing string, the buoyant, sealed chamber may be created there between. In operation, applied fluid pressure causes the rupture disc to move downward. The rupture disc may be shattered by contact with a surface on the lower tubular portion. Full casing internal diameter may be restored in the region where the rupture disc formerly sealed the casing.

Abstract: Methods for more reliably cementing and remediating oil and gas wells by plastically expanding the diameter of the wellbore casing at select locations along the wellbore to control fluid flow in the micro-annular leak paths formed in the casing annulus between the casing and cement sheath, or between the casing and wellbore. Such methods do not require pre-placement of casing packers or prediction of potential leak points of the casing annulus. In cementing operations, casing expansion can be performed at strategic locations along the wellbore to eliminate annular leak paths that permit detrimental flow, direct the flow of cement to the desired portions of the wellbore, and prevent the flow of cement to oil producing formations. In instances of inter-zonal communication between subterranean formations, casing expansion can be performed at location(s) between the formations to mitigate or prevent inter-zonal communication via annular leak paths in the casing annulus.

Abstract: A method for zonal isolation in a subterranean formation includes identifying a zone of interest within the subterranean formation, determining a static temperature of the zone of interest, determining a time duration for gelation of a treatment fluid, determining a concentration of an accelerator in the treatment fluid, determining a volume of the treatment fluid to be delivered to the zone of interest, determining a correlation between cooling of a wellbore near the zone of interest and a delivery rate of the treatment fluid, determining a target wellbore temperature, delivering a cooling stage until the target wellbore temperature is reached, and delivering a treatment stage. Delivering the cooling stage and the treatment stage results in forming, within the zone of interest, a gel that is impermeable to fluid flow.

Abstract: A method for strengthening a subterranean formation is disclosed herein. A method of strengthening a subterranean formation includes: introducing a first fluid into the subterranean formation, wherein the first fluid includes polyvalent cations; and introducing a second fluid into the subterranean formation, wherein the second fluid includes a dissolved silicate in an aqueous-base fluid; wherein the dissolved silicate reacts with the polyvalent cations in the subterranean formation to form a reaction product including precipitated silicate in the subterranean formation.

Abstract: A method of controlling lost circulation includes introducing into a wellbore a lost circulation fluid comprising: an external oil phase, an internal aqueous phase, an emulsifier, a wetting agent, a magnesia sealant, and a; retarder; contacting the lost circulation fluid with a lost circulation zone; and forming a plug adjacent the lost circulation zone by reacting the magnesia sealant with water at a wellbore temperature, thereby reducing fluid loss into the lost circulation zone.

Abstract: A casing segment comprising a cylinder, a downhole tool, a first channel in the cylinder, a degradable plug wherein the plug degrades when exposed to a degrading fluid, said degrading fluid concurrently not degrading to the cylinder or the downhole tool, and a fluid reservoir that stores the degrading fluid, wherein the fluid reservoir is in fluid communication with the plug. A method comprising obtaining a casing segment having a cylinder, a downhole tool, and a fluid reservoir with degrading fluid, said degrading fluid concurrently not degrading to the cylinder or the downhole tool, wherein the cylinder includes a first channel, installing a degradable plug within the first channel, deploying the casing segment downhole, and exposing the degradable plug to the degrading fluid to cause the downhole tool to be in fluid communication with the interior surface of the cylinder.

Abstract: A sealing method for a drilled hole in three zones of overburden comprises: blocking the fissure zone and the caving zone with at least one filling bag; and transporting prepared cement slurry to the drilled hole through a hollow drill pipe, so as to block the curved subsidence zone. The three zones of overburden comprise a fissure zone, a caving zone and a curved subsidence zone.

Abstract: An exemplary dissolvable assembly is provided. The dissolvable assembly includes a skeleton made from a first material, and a body made from a second material, wherein the first material and the second material dissolve at different rates.

Abstract: Compositions and methods for inhibiting dissolution of carbonates in a subterranean formation are provided. In some embodiments, the methods comprise: providing a treatment fluid that comprises a base fluid and a carbonate dissolution inhibiting additive; contacting a portion of a carbonate-bearing subterranean formation with the treatment fluid; and allowing the carbonate dissolution inhibiting additive to chemically interact with the portion of the carbonate-bearing subterranean formation to inhibit dissolution of one or more carbonate minerals in the formation, whereby the susceptibility of at least a portion of the carbonate-bearing subterranean formation to fluid-induced damage is decreased.

Abstract: A method for producing a nanocomposite sorbent comprising carbon nanotube-grafted acrylic acid/acrylamide copolymer which involves copolymerization of acrylic acid and acrylamide in the presence of an aqueous dispersion of carbon nanotubes. The method yields a nanocomposite sorbent material having a reversible adsorption capacity phenol of 5 to 2500 ?g of phenol per mg of nanocomposite sorbent. Also disclosed is a method for removing organic pollutants from water using the nanocomposite sorbent.

Abstract: A hydrocarbon wellbore production apparatus includes a tailpipe and a control valve connected with the tailpipe. The tailpipe has a fluid inlet receiving well fluids entering the casing from a formation, and a fluid outlet above the fluid inlet to deliver well liquid to a connected pump inlet. The control valve is operable to (i) open when a lower fluid pressure below the flow control valve exceeds an upper fluid pressure above the flow control valve to allow upward flow through the flow control valve, (ii) close when the upper fluid pressure exceeds the lower fluid pressure by an amount which does not exceed a prescribed pressure limit value to hold fluid in the apparatus above the flow control valve, and (iii) open when the upper fluid pressure exceeds the lower fluid pressure by an amount which exceeds the pressure limit value to release excess fluid back down the tailpipe.

Abstract: A lost circulation material (LCM) is provided having an alkaline nanosilica dispersion and an ester activator. The alkaline nanosilica dispersion and the ester activator may form a gelled solid after interaction over a contact period. Methods of lost circulation control using the LCM are also provided.

Abstract: A method for mitigating a fluid flow from a target wellbore using a relief wellbore includes receiving wellbore geometry information of the target wellbore, receiving an initial interception point of the target wellbore, simulating a change in a three-dimensional flow characteristic of a kill fluid flow from a simulated relief wellbore and a target fluid flow from a simulated target wellbore resulting from an interaction between the kill fluid flow and the target fluid flow at the initial interception point, the simulated target wellbore designed using the received wellbore geometry information, and determining a final interception point of the target wellbore based on the simulation.

Abstract: Examples of the present disclosure relate to a temporary seal within a wellbore. More specifically, embodiments include a temporary seal within casing that limits the flow of fluid through the casing until the temporary seal is released.

Abstract: Compositions of nanoparticle-based stimulation fluids and methods of use for acid diversion from high permeability zones into low permeability zones to achieve deep penetration of wormholes in subterranean formations, such as carbonate formations. Certain embodiments include a gel precursor composition comprising metal oxide nanoparticles, such as silicon dioxide nanoparticles as a gelling agent, and magnesium chloride.

Abstract: Provided is a lost circulation material that may consist essentially of an alkaline nanosilica dispersion and a sodium bicarbonate activator. Further provided are methods that may control lost circulation in a lost circulation zone in a wellbore by introducing the lost circulation material such that it contacts the lost circulation zone and forms a gelled solid in the lost circulation zone.

Abstract: The present invention relates to a well tool device (1) comprising a housing (10) having an axial through bore (11). A sleeve section (20) is releasably connected to the housing (10) in the through bore (11). The sleeve section (20) comprises an axial bore (21) and a frangible disc (30) provided in the bore (21) of the sleeve section (20) in sealing engagement with the sleeve section (20). The sleeve section (20) is axially displaceable within the bore (11) between a first position (P1) and a second position (P2). The housing (10) comprises an axial bypass fluid passage (12) provided axially between a first location (L1) above the sleeve section (20) to a second location (L2) below the sleeve section (20) when the sleeve section (20) is in the first position (P1). The axial bypass fluid passage (12) is provided radially between the sleeve section (20) and the housing (10) when the sleeve section (20) is in the first position (P1).

Abstract: Systems, methods, and apparatuses of the present disclosure generally relate to dissolvable plugs for separating fluids in a wellbore. A dissolvable plug includes a first end comprising a first fluid barrier. The first fluid barrier includes a polymer film. The dissolvable plug also includes a second end opposite to the first end. The second end comprises a second fluid barrier. The second fluid barrier comprises a polymer film. The dissolvable plug includes a solid structure made of a sand and salt mixture.

Abstract: A downhole tool includes a casing string with a fluid barrier connected therein defining a lower end of a buoyancy chamber. A plug assembly connected in the casing string defines an upper end of the buoyancy chamber. The plug assembly has an outer case with a rupture disc positioned therein configured to block flow and to burst at a predetermined pressure. The rupture disk is removable from a flow path through the outer case upon the flow of fluid therethrough.

Abstract: Provided is a method for preparing a solution B comprising at least one catalyst in at least one second solvent, comprising at least the following steps of (A) providing a solution A comprising the at least one catalyst in at least one first solvent, (B) treating the solution A from step (A) with activated carbon, (C) removing the activated carbon from the solution A, and (D) exchanging the at least one first solvent in solution A for at least one second solvent in order to obtain the solution B comprising the at least one catalyst in at least one second solvent, to a solution of at least one catalyst in at least one second solvent, obtainable by the method according to the invention, to the use of this solution for preparing a composition comprising the at least one catalyst, the at least one second solvent, at least one polyisocyanate and at least one NCO-reactive compound, to the use of this composition for producing a single-layered or multi-layered coating system and a corresponding process.

Abstract: A well treatment fluid comprising an aqueous base fluid and a sugar-based surfactant is provided. The sugar-based surfactant includes at least one betaine functionalized alkyl polyglucoside. Also provided is a method of treating an oil and gas well.

Abstract: A lost-circulation material including a mixture of an aqueous colloidal dispersion and fatty acid. The aqueous colloidal dispersion includes silica nanoparticles and has a pH of at least 8. Combining the colloidal dispersion and the fatty acid initiates gelation of the lost-circulation material when the pH of the lost-circulation material is less than 8 and a temperature of the lost-circulation material is in a range of 5° C. to 300° C. Sealing an opening in a portion of a wellbore or a portion of a subterranean formation in which the wellbore is formed may include providing the aqueous colloidal dispersion and the fatty acid to the wellbore, mixing the colloidal dispersion and the fatty acid to yield the lost-circulation material, initiating gelation of the lost-circulation material, and solidifying the lost-circulation material in the wellbore to yield a set gel.

Abstract: A rupture disc assembly and a float tool incorporating the rupture disc assembly is disclosed. The rupture disc assembly may include a rupture disc assembly comprising a rupture disc, an upper tubular portion and a lower tubular portion, and a securing mechanism for holding the rupture disc between the upper and lower tubular portions. A float tool for creating a buoyant chamber in a casing string may include the rupture disc assembly and a sealing device for sealing the lower end of the casing string, the buoyant, sealed chamber may be created there between. In operation, applied fluid pressure causes the rupture disc to move downward. The rupture disc may be shattered by contact with a surface on the lower tubular portion. Full casing internal diameter may be restored in the region where the rupture disc formerly sealed the casing.

Abstract: A cement composition is disclosed that includes a cement slurry and an epoxy resin system that includes at least one epoxy resin and a curing agent. The cement slurry has a density in a range of from 65 pcf to 180 pcf and includes a cement precursor material, silica sand, silica flour, a weighting agent, and manganese tetraoxide. The epoxy resin system includes at least one of 2,3-epoxypropyl o-tolyl ether, alkyl glycidyl ethers having from 12 to 14 carbon atoms, bisphenol-A-epichlorohydrin epoxy resin, or a compound having formula (I): (OC2H3)—CH2—O—R1—O—CH2—(C2H3O) where R1 is a linear or branched hydrocarbyl having from 4 to 24 carbon atoms; and a curing agent.