Abstract: A method of drilling a wellbore may include drilling the wellbore using a wellbore fluid that has rheological property values for 6 rpm, 10 minute gel, Yield Point, and/or 10 minute-to-10 second gel ratio that are +/20% of the mean values across a temperature range from 40° F. to 300° F.; and conditioning the wellbore with less than 2 hole volumes. The wellbore fluid may include an oleaginous external phase; a non-oleaginous internal phase; an amidoamine emulsifier stabilizing the non-oleaginous internal phase within the oleaginous external phase; at least two oil wetting agents; a rheology modifier; and a weighting agent having a d50 ranging from 5 to 10 ?m.

Abstract: The present disclosure discloses methods for preparing an in-situ nano emulsifier. The preparation method may include obtaining a solution by dissolving hydrated ferric chloride (or ferric chloride) and hydrated ferrous sulfate (or ferrous sulfate) into deionized water at a first temperature; obtaining an ethanol solution dissolved with an oil-soluble surfactant by dissolving an oil-soluble surfactant into ethanol at a second temperature; and adding a certain volume of ammonia water and the ethanol solution dissolved with the oil-soluble surfactant in the solution to obtain an in-situ nano emulsifier. The in-situ nano emulsifier may be applied to development of the oil reservoir through an application process. The application process may include preparing a nano emulsifier solution and a surfactant solution; sequentially injecting the surfactant solution and the nano emulsifier solution into a formation; and injecting a spacer liquid slug into the formation for replacement.

Abstract: Disclosed herein are methods and compositions for cementing. An example method may comprise providing a cement composition. The cement composition may comprise a composite cementitious material comprising a micronized particulate solid and a monophase amorphous hydraulic binder. The micronized particulate solid may have a mean particle size of about 500 microns or less. The cement composition may further comprise water. The method may further comprise introducing the cement composition into a subterranean formation; and allowing the cement composition to set.

Abstract: Systems and methods for controlling geysering in mining operations.

Abstract: A hybrid nanosurfactant composition may include a core phase including a sulfonate surfactant and a first aqueous fluid, a zwitterionic surfactant encapsulating the core phase, a plurality of magnetic particles disposed in the core phase, and a second aqueous fluid in which the encapsulated core phase is suspended. The plurality of magnetic particles may be disposed in the first aqueous fluid.

Abstract: Various embodiments provide methods and systems for providing fluid lighteners for use in downhole wells. The fluid lighteners may include one or more viscosifiers, one or more aphron generators, and a location-specific non-emulsifying surfactant.

Abstract: Provided is a composition that may include an aqueous phase, and extremophilic bacteria having signal transduction chemotaxis machinery and nanoemulsion oil droplets including metal-silica nanoparticles attached to a surface thereof. Further provided is a method for treating an oil reservoir, that may include introducing into the oil reservoir an extremophilic bacteria having signal transduction chemotaxis machinery and nanoemulsion oil droplets including metal-silica nanoparticles attached to a surface thereof. Further provided is method for bacteria mediated enhanced oil recovery that may include introducing extremophilic bacteria downhole to an oil reservoir. The method may further include triggering cell lysis of the extremophilic bacteria, mobilizing the oil trapped by the biosurfactants released from lysed extremophilic bacteria, and producing the oil trapped by the biosurfactants from the oil reservoir.

Abstract: The present disclosure to a cementitious plugging wall solidifier for water-based drilling fluid and a preparation method thereof and a water-based drilling fluid.

Abstract: A method of clearing well casing (3) or tubing from a target region of an oil/gas well (1) borehole is provided. The clearance of the oil/gas well bore hole being achieved by employing chemical agents (9) that consume, weaken or melt the well casing/tubing. In some aspects of the method the well casing is cleared to expose the rock formation within which the well borehole is formed so that the rock formation can be accessed from within the well casing/tubing. In other aspects of the method the removal of inner tubing structures is used to facilitate the unimpaired deployment of repair tools down the well borehole.

Abstract: The invention relates to a method for recovery of hydrocarbons present in an underground formation by injection of a saline aqueous solution comprising at least one surfactant, by means of a numerical flow simulator including a model of the evolution of the interfacial tension between the saline aqueous solution and the hydrocarbons as a function at least of salinity, wherein the interfacial tension evolution model is calibrated as follows: i) carrying out interfacial tension measurements for a plurality of emulsions having distinct salinity values corresponding at least to the optimum salinity, to two salinities bounding the optimum salinity in a 5-10% limit, to the zero salinity and to the solubility limit of the salts; ii) determining the constants of the interfacial tension evolution model by minimizing a difference between the model and the interfacial tension measurements.

Abstract: A method for characterizing complexity of rock fracture based on fractal dimension and a device thereof are provided. The method includes steps of: collecting rock fracture samples of a rock, and collecting basic parameters of the rock; determining a fractal dimension of a rock fracture morphology of the rock; calculating the fractal dimension of the rock; calculating a complexity coefficient Fc of rock fracture of the rock; and characterizing a complexity of rock fracture of the rock based on the complexity coefficient Fc of rock fracture of the rock. In the present invention, combined with the fractal geometry theory, fracture complexity coefficient of shale rocks is redefined and calculated to accurately characterize rock fracture morphology, so that characteristics of rock fracture morphology is correctly understood and affecting factors of fracture morphology is analyzed.

Abstract: Recovering heavy oil from a subterraneous formation penetrated by at least one injection well and one production well, by injecting into the injection well a mixture of steam and an alkyl alkoxylated carboxylate salt, increasing the apparent viscosity of the steam while at the same time lowering the steam mobility, and recovering oil from the subterranean formation.

Abstract: A liner string includes a liner hanger assembly and a liner hanger deployment assembly. The liner hanger assembly includes a liner hanger. The liner hanger includes a plurality of slips and a liner hanger actuation assembly configured to set the plurality of slips. The liner hanger deployment assembly is disposed within the liner hanger assembly. The liner hanger deployment assembly includes a setting tool configured to selectively allow fluid communication between a central bore of the setting tool and the liner hanger actuation assembly.

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: An apparatus for producing steam in-situ, the apparatus comprising an activated carbon container configured to hold activated carbon; a water supply fluidly connected to the activated carbon container, the water supply configured to provide water directly to the activated carbon container; an inter-container valve fluidly connected to the activated carbon container, the inter-container valve configured to let steam flow from the activated carbon container to a steam container; the steam container fluidly connected to the inter-container valve, the steam container configured to hold the steam that flows from the activated carbon container; and one or more release valves fluidly connected to the steam container, the one or more release valves configured to release steam from the steam container.

Abstract: The systems and method described in this specification relate to a method for determining a residual oil saturation of a reservoir. The method includes obtaining a plurality of rock samples from the reservoir; determining a permeability of each of the rock samples; measuring a fluid viscosity of oil in the reservoir; estimating a location-specific permeability of the reservoir across the reservoir based on the permeability of each of the rock samples; determining a location-specific displacing velocity of the reservoir based on a function of the location-specific permeability and the fluid viscosity of the oil; determining the residual oil saturation of the reservoir based on the location-specific displacing velocity using Franklin's equation; and predicting a recovery of the oil from the reservoir using the residual oil saturation in a computational model of the reservoir.

Abstract: The present invention provides compositions and methods for enhancing oil recovery from low permeability subterranean formation using three mechanisms: repressurization; reduction of interfacial tension; and increased permeability. The subject compositions comprise a chelating agent, a biosurfactant, a carbonate or bicarbonate salt, water, and a pH adjusting substance, which when applied to an oil-bearing formation according to the methods of the subject invention, allow for controlled release of carbon dioxide within the formation without complicated machinery or gas-producing microorganisms.

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: Various embodiments disclosed relate to compatibilized resin-cement composite compositions and methods of using the same. In various embodiments, the present invention provides a method of treating a subterranean formation that includes placing in the subterranean formation a resin-cement composite composition. The resin-cement composite composition includes a resin, a cement, and a substituted or unsubstituted poly(alkylamine) compatibilizer.

Abstract: Various embodiments provide methods and systems for providing fluid lighteners for use in downhole wells. The fluid lighteners may include one or more viscosifiers, one or more aphron generators, and a location-specific non-emulsifying surfactant.