Abstract: A system and method for water shutoff, including providing a treatment fluid including a polymer and a nitrogen-generating compound through a wellbore into a water zone in a subterranean formation, generating nitrogen gas in the water zone by a reaction of the nitrogen-generating compound, generating foam from the nitrogen gas and the treatment fluid in the water zone to give foamed polymer in the water zone, and sealing the water zone with the foamed polymer.

Abstract: Methods and systems for delivering well stimulation materials to a wellbore using a high-pressure delivery manifold are provided. In some embodiments, the methods of the present disclosure include: providing a pressurizable delivery manifold at a well site, wherein the pressurizable delivery manifold is continuously equalized with a piping system; providing a pressurized treatment fluid to the pressurizable delivery manifold; releasing one or more well stimulation materials into the pressurized treatment fluid to create a payload delivery treatment fluid; and injecting the payload delivery treatment fluid into at least a portion of a subterranean formation.

Abstract: Method for characterizing subterranean formation is described. One method involves injecting a fluid into an active well of the subterranean formation at a pressure sufficient to induce one or more hydraulic fractures. Measuring, via a pressure sensor, a poroelastic pressure response caused by inducing of the one or more hydraulic fractures. The pressure sensor is in at least partial hydraulic isolation with the one or more hydraulic fractures.

Abstract: An encapsulated polymer flooding method and system for enhancing oil recovery includes: (1) determining reservoir parameters, a well deployment, and a development dynamic state of a target oil reservoir; (2) determining a near-wellbore targeted profile control area and a far-wellbore targeted viscosification area; (3) designing and synthesizing an encapsulated polymer according to conditions of the target oil reservoir; (4) evaluating and determining whether the anti-shearing performance, the sustained release and viscosification performance, the injection performance, and the profile control performance of the encapsulated polymer meet expected performance requirements based on laboratory tests; (5) formulating an injection scheme for an encapsulated polymer flooding field; and (6) monitoring the development dynamic state of the oil reservoir; according to the present disclosure, the polymer is wrapped with a shell layer, which greatly reduces the shear degradation during injection of the polymer and effecti

Abstract: A dispersion of capsules in critical or supercritical carbon dioxide is provided. The capsules include an aqueous solution encapsulated by covalent organic framework particles. Also provided is a method of making a dispersion of aqueous solution capsules. The method includes providing a medium of critical or supercritical carbon dioxide, introducing the aqueous solution into the critical or supercritical carbon dioxide medium, and introducing a covalent organic framework particle into the critical or supercritical carbon dioxide medium. Associated methods of using the disclosed dispersions in hydrocarbon-bearing formations are also provided.

Abstract: Techniques for treating a hydrocarbon reservoir include delivering a composition to the hydrocarbon reservoir. The composition includes at least one acid, and liquid or supercritical carbon dioxide (CO2). The method further includes exposing the delivered composition to water to activate the composition; and treating a rock formation of the hydrocarbon reservoir with the activated composition.

Abstract: The present invention discloses a novel aqueous composition for use in removing petroleum-contaminated barium sulfate scale from a surface contaminated with such, said composition comprising: a chelating agent and a counterion component selected from the group consisting of: Li5DTPA; Na5DTPA; K5DTPA; Cs5DTPA; Na4EDTA; K4EDTA; TEAH4DTPA; and TBAH5DTPA; a scale removal enhancer; a non-ionic surfactant; and a hydrotrope. There is also disclosed methods to use such compositions.

Abstract: Methods and compositions for performing a sealing operation in a wellbore. An example method introduces a sealant composition into the wellbore while the sealant composition is under shear. The sealant composition comprises a thixotropic material, a conformance gel system, and an aqueous base fluid. The sealant composition is placed into a target location, and applied shear is reduced to the sealant composition when in the target location thereby allowing the sealant composition to thicken in the target location. Fluid flow across the target location is reduced by a fluid seal formed by the thickened sealant composition.

Abstract: A corrosion inhibition package for use with an aqueous acid composition, said package comprising: a terpene; a cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant; and a solvent. Also disclosed are compositions comprising said corrosion inhibitor package. Preferably, the corrosion inhibition package meets the environmental requirements for classification as yellow according to the Norwegian North Sea offshore drilling regulatory requirements.

Abstract: The present invention refers to a method for removing fouling in carbonate reservoirs and/or depleted reservoirs by adding carbon dioxide to industrial or desulphated water to produce carbonic acid, in producing well stimulation operations, to be used as a weak acid for removing fouling in remote operation aiming at keeping the productivity of producing wells and lessening the need for remote operations with stimulation vessel, and therefore reducing operating costs.

Abstract: The present invention relates to the use of a process fluid with an environmentally compatible biostabilizer in a geothermal borehole. The biostabilizer is characterized in that it comprises at least one organic acid, or a salt, alcohol or aldehyde thereof, wherein the at least one organic acid is selected from the group consisting of hop acids, resin acids, fatty acids and mixtures thereof. The biostabilizer is preferably a mixture of hop extract, rosin and myristic acid. The invention further relates to related process fluids and methods for producing the same.

Abstract: A composition of matter including a mono-facial polymer-grafted graphene particle and an aqueous-based drilling fluid is provided. In the composition, a first side of the graphene particle has a grafted polymer. A method of lubricating a tool surface using the composition of matter is also provided. The method includes providing an aqueous-based drilling fluid, the aqueous-based drilling fluid having a mono-facial polymer-grafted graphene particle, and introducing the aqueous-based drilling fluid into a wellbore such that it contacts a tool surface to form a coated tool. A drilling tool having a mono-facial polymer-grafted graphene particle adhered to its surface is also provided.

Abstract: A system includes upstream process equipment and downstream process equipment. The upstream process equipment is configured to transmit a predetermined fluid to the downstream process equipment. A manually operated valve fluidly couples the upstream process equipment to the downstream process equipment. A removable ultrasonic wireless flow meter is coupled to piping downstream from the manually operated valve. A control system is coupled to the manually operated valve and the removable ultrasonic wireless flow meter. The control system determines an optimum time and speed to actuate the manually operated valve using a predictive model based on a valve size of the manually operated valve, a valve age of the manually operated valve, fluid type, a criticality index of the manually operated valve, a measured flow rate from the removable ultrasonic wireless flow meter, and corresponding coefficients.

Abstract: A fluid loss pill containing a brine and a crosslinked polymer of underivatized guar or a derivatized guar and puffed boron or ulexite crosslinking agent. The brine may be a heavy brine having a density greater than 11.0 ppg.

Abstract: Fiber additives that may be useful as lost circulation materials for mitigating fluid loss and/or as bridging agents or diverting agents in subterranean treatment fluids such as drilling fluids. In some embodiments, the fiber additives include a fiber and calcium carbonate disposed on at least a portion of the outer surface of the fiber. In some embodiments, the methods include providing a treatment fluid that includes the base fluid and the fiber additives, and introducing the treatment fluid into at least a portion of a subterranean formation.

Abstract: A method may include monitoring, for two or more well heads of a hydraulic fracturing system, an operation or a state of one or more subsystems of the hydraulic fracturing system. The hydraulic fracturing system may include one or more fracturing rigs, one or more blending equipment, one or more power sources electrically connected to a first subset of the one or more fracturing rigs, or one or more fuel sources fluidly connected to a second subset of the one or more fracturing rigs, and one or more missile valves. The hydraulic fracturing system may further include one or more zipper valves, one or more well head valves, and multiple well heads. The method may further include controlling, based on an operation schedule for the hydraulic fracturing system and based on monitoring the operation or the state, fluid pressures at the two or more well heads for continuous pumping.

Abstract: System and method for the optimized production of hydrocarbons from shale oil reservoirs via cyclic injection to achieve an improved and optimal recovery of oil. The method can determine and optimize the composition of injected fluids to be injected, the rate, pressure and duration of injection, the production rate and pressure of produced fluids; can determine and utilize the optimum number of injection and production cycles; can determine the amount of soaking time (if any); and can determine the equipment design and operating characteristics to provide for the optimized injection of injection fluids, and the separation of produced fluids for both reinjection and delivery to sales or storage.

Abstract: Method for production of hydrocarbons from shale oil reservoirs via a cyclic injection and production process. The method determines the composition of injected hydrocarbon-containing composition to be injected, performing injection and production steps, and then re-determines the composition of the injected hydrocarbon-containing composition to be injected.

Abstract: An apparatus and method for deploying an elongate medium in a bore is described. The apparatus includes a housing defining an internal spool cavity, and the housing is configured to be deployed in the bore. A spool of elongate medium is mounted within the spool cavity. The housing defines an outlet to permit the elongate medium to be deployed from the spool cavity, and an inlet to permit bore fluid to enter the housing during deployment of the elongate medium from the spool cavity. In use, the housing includes an isolating fluid to isolate the elongate medium from the bore fluid entering the housing. Also described is a kit for deploying elongate medium in a bore and a method of preparing an apparatus for deployment of an elongate medium in a bore.

Abstract: Methods of stimulating a hydrocarbon well are disclosed herein. The hydrocarbon well includes a wellbore that extends within a subterranean formation and a tubular that extends within the wellbore and defines a tubular conduit. The methods include retaining a sealing structure within the tubular conduit and, during the retaining, stimulating a zone of the subterranean formation. Subsequent to the stimulating, the methods include fluidly isolating the zone of the subterranean formation from the uphole region by at least partially sealing the plurality of perforations. Subsequent to the fluidly isolating, the methods include moving the sealing structure in a downhole direction within the tubular conduit. The methods also include repeating the retaining, the stimulating, the fluidly isolating, and the moving a plurality of times to stimulate a plurality of corresponding zones of the subterranean formation.

Abstract: The present disclosure belongs to the technical field of clean and efficient mining of deep unconventional or conventional resources, and discloses a pilot-scale supercritical water oxidation oil and hydrogen production system capable of realizing multi-stage heating of organic rock. The system comprises a supercritical water generator, a supercritical water pyrolysis reaction system for organic rock, an oxygen injection system and an oil-gas condensation and collection system, wherein the supercritical water generator mainly comprises a water injection system, a front-section preheating system, a second-stage heating system and a third-stage heating system. The reaction system can carry out a pilot-scale simulation process of supercritical water pyrolysis for organic rock, a multi-stage heating function is realized, the maximum reaction distance is 8 m or more, and the release characteristics of oil-gas products under different reaction distances are explained.

Abstract: Embodiments of treating fluid comprising hydrocarbons, water, and polymer being produced from a hydrocarbon-bearing formation are provided. One embodiment comprises adding a concentration of a viscosity reducer to the fluid to degrade the polymer present in the fluid and adding a concentration of a neutralizer to the fluid to neutralize the viscosity reducer in the fluid. The addition of the concentration of the viscosity reducer is in a sufficient quantity to allow for complete chemical degradation of the polymer prior to the addition of the concentration of the neutralizer in the fluid such that excess viscosity reducer is present in the fluid. The addition of the concentration of the neutralizer is sufficiently upstream of any surface fluid processing equipment to allow for complete neutralization of the excess viscosity reducer such that excess neutralizer is present in the fluid prior to the fluid reaching any of the surface fluid processing equipment.

Abstract: A system and method of testing diverting agents may include injecting a diverting agent into a testing device. The system may be configured to inject a diverting agent into a testing device configured to receive a fluid through a flow channel and, change the flow channel in a transverse direction relative to the direction of the fluid flow.

Abstract: An aqueous wellbore fluid may include a surface active agent package in an amount ranging from 1 to 20 gpt, a thickener in an amount ranging from 0.01 to 0.3 wt. %, and an aqueous base fluid. The surface active agent package may include an ?-olefin sulfonate, a terpenoid, and isopropyl alcohol. The thickener may include a biopolymer.

Abstract: The present application provides expandable chemical diverting agents, such as flexible polyurethanes and swellable hydrogels, or chemical precursors thereof. Methods of using these expandable diverting agents for treating a subterranean formation are also provided. An example of subterranean formation treatment process described in the present application is wellbore stimulation, such as hydraulic fracturing or matrix acid treatment.

Abstract: An acid mixture includes hydrochloric acid, a monoamine corrosion inhibitor, and at least one of a diamine corrosion inhibitor and an acid additive. A method for inhibiting corrosion in an acid treatment operation includes introducing an acid mixture comprising hydrochloric acid and a monoamine corrosion inhibitor into at least one of a subterranean formation and subterranean wellbore. The method also includes maintaining the amount of the monoamine corrosion inhibitor in the acid mixture in the subterranean formation and/or the subterranean wellbore in a range of 10 ppm to 400 ppm for the duration of the acid treatment operation. The corrosion rate of steel parts of an acidic fluid circulation system in the acid mixture may be within an acceptable corrosion rate in a temperature range of 20° C. to 135° C.

Abstract: The subject invention provides multi-functional biochemical compositions, as well as their use in enhancing oil recovery by, for example, enhancing traditional acid treatments. Advantageously, the compositions and methods of the subject invention are operationally-friendly, cost-effective, and environmentally-friendly approaches to enhancing oil recovery. More specifically, in preferred embodiments, the subject invention provides a multi-functional composition for enhanced oil recovery (EOR) comprising one or more concentrated acids that work in synergy with a combination of one or more surfactants, one or more chelating agents, and one or more solvents to stimulate the flow of oil from a formation.

Abstract: In one aspect, a method for plugging a bore includes pumping a slurry composition comprising a swellable phyllosilicate clay in an amount of 70 wt % or less into the bore, and permitting compaction of the phyllosilicate clay in the slurry to plug the bore.

Abstract: A permeability-enhancing flooding system for tight oil reservoirs and preparation and use thereof are disclosed. The permeability-enhancing flooding system is present in a state of oil-in-water droplet and composed of a surfactant, an oil-soluble substance and water, and has an outer phase that is an aqueous solution containing the surfactant, and an inner phase that is the oil-soluble substance; and the surfactant comprises one of nonionic gemini surfactants and anionic gemini surfactants, or a combination of two or more thereof. The preparation process for the permeability-enhancing flooding system is simple to operate, suitable for industrialized production, and low in overall cost, and has obvious application prospects in the field of tight oil reservoirs for an enhanced oil recovery.

Abstract: The present invention relates to a method for removing hydrocarbons from produced water, comprising: (i) separating produced water from a hydrocarbon and water mixture extracted from a subterranean formation: (ii) contacting said produced water with multivalent metal cations to produce a mixture of produced water and multivalent metal cations; and (iii) removing hydrocarbons from said mixture in a hydrocyclone and/or a compact flotation unit to give treated produced water, wherein the concentration of hydrocarbons in said produced water is less than 10% wt.

Abstract: A downhole injection system in selective communication with a wellhead assembly and a wellbore, the downhole injection system including a pumping chamber in selective communication with the wellhead assembly, the pumping chamber defining a wellhead pressure portion defining a wellhead pressure inlet in selective communication with the wellhead assembly and a wellhead pressure outlet in selective communication with the wellhead assembly, where the wellhead pressure portion is maintained at a wellhead pressure, and a chemical portion in selective communication with the wellbore, and a movable plate positioned within the pumping chamber, where the chemical portion is separated from the wellhead pressure portion by the movable plate.

Abstract: The present invention relates to a bionics-based efficiently transported and packed proppant and preparation method thereof, comprising enhanced fracturing fluid and biomimetic dandelion proppant; the mass ratio of the enhanced fracturing fluid and the biomimetic dandelion is: 1-2:100-400; the 100 pbw of enhanced fracturing fluid includes 0.1-1 pbw of drag reducing agent, 0.01-0.1 pbw of cleanup additive, 0.2-0.8 pbw of clay stabilizer, 0.01-0.05 pbw of bactericide, 0.01-0.2 pbw of nanoparticle enhancer, and water; the biomimetic dandelion proppant consists of modified proppant and modified fiber, and the mass ratio between the modified proppant and the modified fiber is 99-99.9:0.1-1.

Abstract: A method for the controlled delivery of a fracturing fluid to a well bore comprises formulating an aqueous base fluid such that it meets or exhibits desired physical and chemical characteristics for an optimal fracturing fluid. The formulation of the aqueous base fluid max involve commingling one or more sources of waste water with a source of fresh water followed by controlled injection of one or more additives. This process is substantially completed prior to delivering the aqueous base fluid to the well site. This allows the delivery of an optimal volume of the aqueous base fluid with homogeneously blended additives to the well bore.

Abstract: Emulsions, treatment fluids and methods for treating subterranean formations are provided, wherein the emulsions comprise water, a water-immiscible liquid, one or more polymers, one or more ethoxylated amine compounds and optionally, one or more organic or inorganic salts. The emulsions are particularly suitable for use in harsh brine conditions.

Abstract: In general, in various embodiments, the present disclosure is directed systems and methods for producing a porous surface from a solid piece of polymer. In particular, the present disclosure is directed to systems that include a track assembly, mold assembly, press assembly, and methods for using the same for producing a porous surface from a solid piece of polymer. In some embodiments, the present systems and methods are directed to processing a polymer at a temperature below a melting point of the polymer to produce a solid piece of polymer with an integrated a porous surface.

Abstract: A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I): where Y1, Y2, Y3, Y4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III): where R2 is a C15-C27 hydrocarbon group or a C15-C29 substituted hydrocarbon group, R3 is a C1-C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. A method of using the wellbore fluid for treating a hydrocarbon-containing formation is also provided.

Abstract: A method of recycling a direct emulsion wellbore fluid may include disrupting a direct emulsion comprising an aqueous external phase and an oleaginous internal phase, wherein the direct emulsion is stabilized by a surfactant composition; and separating the aqueous phase and the oleaginous phase.

Abstract: A method of preventive well maintenance with pumping equipment in the well for well rehabilitation using CO2 with varying lengths of producing intervals utilizing varying methods to deliver cleaning energy and varying porosity of aquifers to determine varying quantities of energy over the entire well structure.

Abstract: Hydraulic fracturing fluids and methods to hydraulically fracture a subterranean formation and oxidize organic material in the subterranean formation. The hydraulic fracturing fluid includes water, another fluid, and a surfactant. An inorganic oxidizer is included in the water.

Abstract: The present invention discloses a method for realizing uniform stimulation for the oil and gas well by low-cost multi-stage fracturing, comprising the following steps: first calculate and predict the inlet widths of the fracture created in the planned hydraulic fracturing; then design the plugging scheme for blocking the fracture inlet after each fracturing treatment; the selected plugging particles are composed of filling particles and skeleton particles, with designed plugging scheme; after complete the design of plugging scheme, perform the fracturing treatment to create hydraulic fracturing in the reservoir; skeleton particles and filling particles are added into the fractures successively according to plan. The present invention provides a multi-stage single-cluster fracturing method, with the advantages of controllable fracture sizes and low cost. The present invention can realize a good uniformity of stimulation for the oil and gas wells.

Abstract: The present invention relates to modified proppants and methods of using the modified proppants that use metal ligand tracers to characterize subterranean fluid flow. The metal and ligands are best chosen to be a strongly-coordinating, chelating ligand with a functional group for the chosen flow environment.

Abstract: Aspects of the subject technology relate to systems and methods for determining positions of cementing plugs during a cementing process. Systems and methods are provided for determining a length of an optical fiber line deployed into a wellbore for a cementing process, measuring signal intensity data as a function of distance from the optical fiber line, the optical fiber line being attached to a lower cementing plug and an upper cementing plug, the upper cementing plug being attached to the optical fiber line by an attenuation assembly, generating signal intensity profiles based on the signal intensity data as a function of a round trip delay of a light signal in the optical fiber line, and determining positions of the lower cementing plug and the upper cementing plug based on the signal intensity profiles of the optical fiber line.

Abstract: A method of evaluating a surfactant is provided. The method includes preparing a first emulsion comprising an aqueous phase, an oleaginous phase, and a first surfactant. Then the method includes determining an average droplet size of oleaginous phase droplets in the first emulsion. The method then includes preparing a second emulsion comprising the aqueous phase, the oleaginous phase, and a second surfactant, and then determining an average droplet size of oleaginous phase droplets in the second emulsion. After determining droplet sizes of both emulsions, the method includes comparing the average droplet size of the of the oleaginous phase droplets in the first emulsion to the average droplet size of the oleaginous phase droplets in the second emulsion, and based on the comparing of the average droplet sizes, determining a relative interfacial tension of the first surfactant as compared to the second surfactant.

Abstract: One illustrative valve disclosed herein includes a body, a first flow bore in the body that includes a fluid flow gallery, a first fluid flow port and a second fluid flow port, wherein the fluid flow gallery is in fluid communication with the first and second fluid flow ports. In this example, the valve also includes a second flow bore in the body and at least one sliding sleeve positioned in the body, wherein the at least one sliding sleeve is adapted to be moved from a first closed position to a second open position, and vice-versa, wherein, in the first closed position, fluid communication between the first flow bore and the second flow bore is blocked and wherein, in the second open position, fluid communication between the first flow bore and the second flow bore is established.

Abstract: A wellbore fluid comprising a first aqueous base fluid and a plurality of silica nanoparticles suspended in the first aqueous base fluid. The nanoparticles are present in the fluid in an amount to have an effect of decreasing a crystallization temperature by at least 4 to 55° F. as compared to a second aqueous base fluid without the silica nanoparticles.

Abstract: A system for fracturing multiple wellbores on a multi-well pad can include a missile that receives high-pressure fracturing fluid from a plurality of pump truck. The system can also include a main manifold that receives the high-pressure fracturing fluid from the missile, where the main manifold includes multiple valves and multiple output channels, where each of the valves are operated between an open position and a closed position. The system can further include multiple wellbores including a first wellbore, a second wellbore, and a third wellbore, where the wellbores are connected to the output channels of the main manifold. The valves of the main manifold can be operated to enable simultaneous flow of the high-pressure fracturing fluid to the first wellbore, the second wellbore, and the third wellbore so that the first wellbore, the second wellbore, and the third wellbore are fractured simultaneously.

Abstract: A method and system for enhancing petroleum production are provided, in which petroleum is displaced from a fractured formation by selectively injecting fluid into selected fractures in the formation without injecting into the other non-selected fractures. The injected fluid flows out into the fractured formation and enhances recovery from the non-selected fractures. Petroleum is selectively collected from the non-selected fractures.

Abstract: Exemplary embodiments seek to eliminate or reduce fouling enabled by atmospheric oxygen entering the airspace of the well column. An inerting gas is used to flush atmospheric oxygen out of the well airspace. Once atmospheric air in the well gas-column has been replaced with an inerting gas, the well is sealed and pressurized with the inerting gas. The introduction of atmospheric oxygen back into the system through leaks is overcome by keeping a small, positive pressure-differential between the well-column gas pressure and the atmosphere. Results, as described herein, have shown the removal of atmospheric oxygen from the system can greatly reduce, or eliminate, both chemical and biological fouling as well as reduce or eliminate the need for well cleaning treatments.

Abstract: A method of pumping a non-Newtonian fluid includes pumping the non-Newtonian fluid into an interior of a tubular string, and autonomously controlling a flow resistance to the non-Newtonian fluid flowing from the interior of the tubular string to an exterior of the tubular string with an autonomous flow control device.

Abstract: The invention includes methods for stimulating a hydrocarbon-bearing formation by perforating a wellbore and introducing an acidic composition in the wellbore. A preferred embodiment includes inserting an isolation plug in the wellbore at a predetermined location followed by inserting a perforating tool and a breakdown acid into the wellbore. The wellbore is perforated by the tool to create a perforated area. The breakdown acid is allowed to come into contact with the perforated area for a predetermined period of time sufficient to prepare the formation for stimulation. The tool is then removed from the wellbore wherein stimulation of the perforated area is thereby initiated. Also disclosed is a corrosion inhibiting composition for use with the acidic composition.