Abstract: A diverting agent of the present invention contains a polyvinyl alcohol-based resin, wherein when the diverting agent is added to a 0.48 mass % aqueous solution of guar gum to prepare a mixed solution having a concentration of 12 mass %, a dispersion liquid obtained by dispersing the mixed solution at 30° C.

Abstract: Described is a method for treating hydrocarbons in a reservoir. A foaming surfactant solution and a foaming gas are introduced into the upper portion of a reservoir such that barrier foam bubbles form. Then, super/critical carbon dioxide is introduced such that a CO2 cap forms. The CO2 cap is formed above a foam barrier of aggregated barrier foam bubbles positioned at an interface between hydrocarbons to be treated in the reservoir and the CO2 cap. The super/critical carbon dioxide is introduced into the reservoir at an injection rate that is greater than a pre-treatment critical gas injection rate. Hydrocarbons are recovered from a lower portion of the reservoir.

Abstract: Provided is a method for mitigating a lost circulation zone. The method may include providing a lost circulation treatment composition that may include an acid responsive polymer that may include at least one monomer, at least one comonomer, and at least one crosslinker; a carbonate-based solvent; and a carrier fluid that may include water. The method may also include introducing the lost circulation treatment composition into a wellbore within a subterranean formation, wherein the subterranean formation may include the lost circulation zone; placing the lost circulation treatment composition into the lost circulation zone, hydrolyzing the carbonate-based solvent to generate carbon dioxide, and causing the swelling (change of shape) of acid responsive polymer to mitigate the losses.

Abstract: Methods for drilling in higher temperature rock formations such as geothermal formations with phase change material augmented drilling fluid include observing flow rate of the augmented fluid. Heat exchange between the annulus returning fluid and tubular fluid can be minimized thereby facilitating a cooler fluid for contact with a rock face being drilled. The cooling assists in pre-fracturing the rock face prior to destruction by the drill bit.

Abstract: A method for steering a well based on rock properties and obtaining natural fracture information includes inducing tube waves in the well during drilling the well. Acoustic energy is measured in the well. The energy comprises tube wave reflections from formations adjacent to the well. The measured acoustic energy is inverted to determine at least one of a rock property, a near wellbore hydraulic conductivity, and natural fracture occurrence. A trajectory of the well is adjusted to maintain the at least one of a rock property, near wellbore hydraulic conductivity and natural fracture occurrence. An n optimized, well-customized hydraulic fracturing design may be created based on the measured natural fracture properties. A method to optimize hydraulic fracturing treatment based on measured natural fracture properties during drilling.

Abstract: A system that separates the wellhead fluid into four streams consisting of water, crude, residue gas and an NGL injectant fluid stream. The natural gas liquids injectant fluid stream has characteristics that are desirable for enhanced oil recovery namely, unfractionated natural gas liquids mix with high concentration of methane and ethane while still remaining at liquid phase when leaving the system.

Abstract: Distributed acoustic sensing (DAS) measurements may be acquired at an observation wellbore during a current stage of a stimulation treatment along a treatment wellbore within a reservoir formation. A cumulative strain trace for the current stage of the stimulation treatment may be determined based on the DAS measurements. Based on the cumulative strain trace, whether or not to adjust a spacing of perforation clusters and/or a stage length used at the treatment wellbore for a subsequent stage of the stimulation treatment may be determined. Responsive to determining to adjust the spacing of the perforation dusters or to adjust the stage length, at least one treatment parameter for the subsequent stage may be adjusted. The subsequent stage may be performed based on the adjusted at least one treatment parameter.

Abstract: A method of increasing hydrocarbon recovery from a wellbore in a tight formation with greater breakdown pressures, the method including using hydro-jetting to effect a plurality of oriented cavities or discoidal grooves in the horizontal portion of the wellbore to overcome near-wellbore stresses, injecting a thermally controlled fluid into the wellbore to alter the temperature of the formation and lower stresses, and then fracturing the formation to generate a series of fractures that can be formed in a planar formation.

Abstract: A method of treating a well, comprising introducing a well treatment fluid into the well. The well treatment fluid includes an aqueous base fluid and a dewatering agent. The dewatering agent includes water, a demulsifying surfactant, and a polyamine polyether.

Abstract: Forming a hydrogel in-situ downhole by pumping multiple polymers together that synergistically work together to reduce the flow of water through a proppant pack

Abstract: A system and method using a subterranean biological reactor can include a pre-reactor storage unit configured to receive a feedstock including a slurry of biologically derived material and at least one pump configured to pump the effluent from the pre-reactor storage unit. The system may include at least one wellbore containing a subterranean biological reactor configured to receive the effluent from the pre-reactor storage unit. At least a portion of the subterranean biological reactor may be configured to perform anaerobic digestion upon the effluent to generate a biogas.

Abstract: An acid-generating fluid includes a thermally activated strong acid precursor. The thermally activated strong acid precursor can include a component selected from aldehydes, ketones, and combinations thereof, in combination with a precursor of a compound adapted to react to liberate sulfur dioxide; or it can include sulfur dioxide in combination with a precursor of a compound adapted to react to liberate a component selected from aldehydes, ketones, and combinations thereof.

Abstract: A method and reactive treatment fluid for treating a wellbore for filter cake removal, including providing the reactive treatment fluid having a viscoelastic surfactant (VES) into a wellbore in a subterranean formation and attacking the filter cake via the reactive treatment fluid.

Abstract: Construction and use of an instrument test fixture for capturing performance data for stimulation or fracturing treatments. The test fixture includes a target material, such as concrete, which includes embedded sensors surrounding a casing. An energetic stimulation treatment, such as a dynamic pulse fracturing technique, is applied through the casing to the target material to simulate a treatment that would be performed in a wellbore. During application of the treatment, the sensors capture measurements which are recorded for analysis by a data collection system. The sensors allow for the measurement of key performance indicators including static and dynamic pressure, generated temperature, and resulting strain energy. The captured data can be analyzed and used to design and optimize stimulation treatments for field applications.

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: A method includes wrapping a packer bag around a deployment tool, providing at least one canister in fluid communication with the packer bag, sending the packer bag around the downhole tool to a downhole location in a well, and injecting a polymer filler material from the at least one canister into the packer bag until the packer bag expands to seal the downhole location.

Abstract: A method for fracking a hydrocarbon formation. An actuating member, flowable along a production string, is provided. A unique key portion thereon engages a desired sliding sleeve covering an associated port in the production string. Applying uphole fluid pressure causes the sliding sleeve and actuating member to move so as to uncover the associated port. After fracking and cessation of supply of pressurized fracturing fluid, a compressed spring on the actuating member decompresses so as to reposition a sand screen immediately beneath the port so as to prevent sand from flowing into the production string. Flowable insertion of additional “keyed” actuating members allows similar opening of additional successive uphole ports and fracking in the regions of such additional opened ports, with similar location of sand screens at each opened port. Plug members on each actuating member thereafter dissolve or are successively burst to thereby allow production.

Abstract: An actuation member for use in fracking operations, which immediately prior to fracking locates a sand screen at a desired location along a tubing liner and eliminates having to trip out the frac string prior to commencing production. The actuation member comprises a cylindrical hollow collet sleeve, with one or more radially-outwardly biased protuberances forming a unique profile which further matingly engages a corresponding mating profile on one of a plurality of sliding sleeve members in the tubular liner. A longitudinally-extending sand screen is provided, longitudinally slidable on the actuation member. A spring member, adapted to be forcibly compressed by the sand screen member when pressurized fluid is applied, and decompressed upon removal of pressurized fluid, is further provided on the actuation member.

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 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.