Abstract: The invention provides a wellbore fluid which comprises an aqueous continuous phase and, dissolved in said aqueous continuous phase, at least one salt which exists in a liquid state at a temperature below 150° C. and which has an ammonium, phosphonium or sulfonium cation containing at least 5 carbon atoms, or a quaternised nitrogen-containing heterocyclic cation containing at least 6 carbon atoms; provided that said salt is not 2-hydroxy-N,N,N-trimethyl ethanaminium acetate; and a method of carrying out a wellbore operation, which comprises introducing into a wellbore in a clay-containing formation, a wellbore fluid according to the invention. The described salts are effective shale inhibitors.

Abstract: A downhole tool assembly including a bridge plug and a cement retainer in tandem to be deployed into a wellbore on the same run or trip for remedial cementing of the wellbore.

Abstract: Provided is a process for limiting or preventing the formation and/or agglomeration of gas hydrates, comprising combining (1) a production fluid comprising an aqueous phase and one or more gasses and (2) at least one compound represented by formula (I) or a salt thereof as defined herein.

Abstract: The present invention provides a method and system for providing on-site electrical power to a fracturing operation, and an electrically powered fracturing system. Natural gas can be used to drive a turbine generator in the production of electrical power. A scalable, electrically powered fracturing fleet is provided to pump fluids for the fracturing operation, obviating the need for a constant supply of diesel fuel to the site and reducing the site footprint and infrastructure required for the fracturing operation, when compared with conventional systems.

Abstract: A hybrid particle mix lost circulation material (LCM) is provided. The hybrid particle mix LCM includes date palm seed particles produced from date palm seeds and scrap tire particles produced from scrap tires. The LCM may include date palm seed particles in the range of about 50 wt % to about 80% and scrap tire particles in the range of about 50 wt % to about 20 wt %. Methods of lost circulation control and manufacture of a hybrid particle mix LCM are also provided.

Abstract: The present invention is concerned with the treatment of produced water, obtained from a chemically enhanced oil recovery process using viscosity-increasing polymeric compounds. Said treatment comprises particularly the steps of obtaining a produced water, from an oil-water mixture recovered from an oil-bearing formation, wherein the produced water comprises the viscosity-increasing polymeric compounds; and, of directing the produced water to a specific filtration device, and subjecting the produced water to filtration, for obtaining a retentate stream and a permeate stream. Said process allows particularly obtaining a permeate comprising the viscosity-increasing polymeric compounds, said permeate being substantially free of suspended solids, free oil and emulsified oil.

Abstract: Compounds are identified that act as crystallization suppressants when added to clear brine fluids, significantly lowering the true crystallization temperatures of the brines, and allowing for higher salt content in clear brine fluids. The crystallization suppressants of the invention also allow for the preparation of higher density zinc free brines. Crystallization suppressant blends are also identified that allow for the preparation of high density clear brine fluids with lower viscosities.

Abstract: A hybrid particle mix lost circulation material (LCM) is provided. The hybrid particle mix LCM includes date palm seed particles produced from date palm seeds and scrap tire particles produced from scrap tires. The LCM may include date palm seed particles in the range of about 50 wt % to about 80% and scrap tire particles in the range of about 50 wt % to about 20 wt %. Methods of lost circulation control and manufacture of a hybrid particle mix LCM are also provided.

Abstract: The present invention relates to a method of providing a barrier in a fracture-containing system, comprising: i) Providing a treatment fluid comprising: a) a base fluid; b) an elastomeric material, wherein said elastomeric material comprises at least one polymer capable of crosslinking into an elastomer, and c) at least one crosslinking agent; ii) Placing the treatment fluid in a fracture-containing system; iii) Allowing the elastomeric material to crosslink with itself to form a barrier in said fracture-containing system; wherein the elastomeric material and/or the crosslinking agent are of neutral buoyancy with regard to the base fluid. The invention is contemplated to having utility not only in the oil-drilling industry but also in the plugging of fractures in sewer drains, pipelines etc.

Abstract: Various embodiments disclosed relate to guanidine- or guanidinium-containing clay or shale stabilizers for treatment of subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation that can include placing a composition including a clay or shale stabilizer including at least one of a substituted guanidine group and a substituted guanidinium group in a subterranean formation.

Abstract: Provided herein are liquid polymer (LP) compositions comprising a synthetic (co)polymer (e.g., an acrylamide (co)polymer), as well as methods for preparing inverted polymer solutions by inverting these LP compositions in an aqueous fluid. The resulting inverted polymer solutions can have a concentration of a synthetic (co)polymer (e.g., an acrylamide (co)polymer) of from 50 to 15,000 ppm, and a filter ratio of 1.5 or less at 15 psi using a 1.2 ?m filter. Also provided are methods of using these inverted polymer solutions in oil and gas operations, including enhanced oil recovery.

Abstract: Embodiments of the present disclosure are directed to double emulsified acids, specifically water in oil in water (W/O/W) double emulsions with an acidic interior water phase. The double emulsified acid may include two or more emulsifying agents. In addition to improving the stability of the emulsions, the emulsifying agents may help slow the acid reaction rate. The first emulsifying agent may have an HLB greater than 7 and the second emulsifying agent may have an HLB less than or equal to 7. Other embodiments are directed to methods for producing a double emulsified acid and methods for acidizing a carbonate formation including a double emulsified acid.

Abstract: A well treatment composition for use in a hydrocarbon-bearing reservoir comprising a reversible aminal gel composition. The reversible aminal gel composition includes a liquid precursor composition. The liquid precursor composition is operable to remain in a liquid state at about room temperature. The liquid precursor composition comprises an organic amine composition; an aldehyde composition; a polar aprotic organic solvent; and a metal salt composition with valence 3, 4, or 5. The liquid precursor composition transitions from the liquid state to a gel state responsive to an increase in temperature in the hydrocarbon-bearing reservoir.

Abstract: A low-cost, portable, destructive sanitization method for solid state drives (SSDs) is provided. Preferably, an SSD is destroyed by disintegration within a given time period (approximately 30 minutes or less) using a blending device operating at a given peak power, e.g., greater than 450 W. A pulverizing agent may be admixed with pieces of an SSD printed circuit board prior to initiating the disintegration process to increase the number of particle collisions in a processing/blending chamber. The pulverizing agent may also contain moisture that mitigates suspension of processed SDD particles in the surrounding air (when the mixing chamber is opened). The overall process may be video-recorded for compliance purposes.

Abstract: Flowline components are assembled into high-pressure fluid transportation systems by a flange union. The flowline component comprises a body defining a substantially cylindrical central conduit. The conduit extends between first and second flat union faces and is adapted to conduct fluids through the body. The union faces are adapted to provide a mating surface for a flange union between the component and another flowline component. Accordingly, the union faces have a plurality of holes adapted to accommodate threaded connectors for forming the flange union. The holes are arranged in a defined array extending angularly around the conduit. Importantly, the array of holes on the first union face and the array of holes on the second union face are offset angularly relative to each other by an angle ?. It will be appreciated that such components may allow changes in the direction of a flow line.

Abstract: An apparatus according to which a subterranean formation in which a wellbore extends is hydraulically fractured, the apparatus comprising first and second manifolds, the first manifold including first and second flow lines adapted to be in fluid communication with first and second pumps, respectively, the first pump being adapted to pressurize fluid received from the first flow line, and the second pump being adapted to pressurize fluid received from the second flow line, and the second manifold including a third flow line adapted to convey pressurized fluid from the first and second pumps to the wellbore to hydraulically fracture the subterranean formation in which the wellbore extends. The apparatus is adapted to be connected to another apparatus used to hydraulically fracture the subterranean formation in which the wellbore extends by moving one, or both, of the first and second flow lines relative to the third flow line.

Abstract: Method of selecting an optimum formation stabilization treatment for subterranean formations is described. The methods include obtaining formation material, adding a test fluid to the formation material to form a first mixture, adding the test fluid to the formation material to form a second mixture, agitating the first and second mixtures, measuring capillary suction time of the first mixture, and measuring turbidity of the second mixture.

Abstract: Systems and methods for stabilizing portions of a subterranean formation, including portions of a subterranean formation having unconsolidated particulates, using a consolidating agent comprising polyamino-functionalized nanoparticles are provided. Certain of the methods include the steps of providing a treatment fluid comprising a base liquid and polyamino-functionalized nanoparticles; and introducing the treatment fluid into a portion of a subterranean formation. Treatment fluids comprising polyamino-functionalized nanoparticles include gravel packing fluids, consolidation fluids, and hydraulic fracturing fluids are also provided.

Abstract: The invention provides a method, composition, and system for inhibiting corrosion where the composition forms an acid-in-oil emulsion comprising hexamethylenetetramine, a corrosion inhibitor; and at least one emulsifier.

Abstract: Methods for fracking, particularly dry fracking, comprising the use of surfactants for preparation of substantially water-free carbon dioxide in oil foams are presented.

Abstract: A composition for use in a polymer flooding operation in a viscous oil containing carbonate reservoir formation with in situ rock is provided. The composition includes a polymer, the polymer operable to increase the viscosity of the composition; and a smart water, the smart water operable to alter a wettability of the in situ rock, wherein the smart water has a total dissolved solids of between 5,000 ppm and 7,000 ppm, wherein the total dissolved solids comprises one or more salts; wherein the composition has a viscosity between 4 cP and 100 cP.

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: Methods and apparatus of adjusting matrix acidizing procedures are disclosed. An example method includes determining parameters of a wellbore fluid during a matrix acidizing procedure using at least a first sensor and a second sensor. The parameters include velocity of the wellbore fluid and a temperature difference between the first sensor and the second sensor. The method also includes, based on the parameters, determining a characteristic relative to an invasion length of a reactive fluid within the formation, the reactive fluid used in association with the matrix acidizing procedure.

Abstract: A system and process for defining, blending and monitoring fresh water with subterranean produced formation fluids, with particular constituents of the blended waters being controlled for proper use in gel-type hydraulic fracturing operations. On-site measurements and calculations of clay stabilization replacement, through a Potassium Chloride (KCl) Equivalency calculation, provide feedback on water constituent adjustments that may be needed just prior to the gel-based hydraulic fracturing process. This assures adequate gel cross-linking times, delayed gel cross-linking times, and clay stabilization in the formation to be fractured.

Abstract: Certain metal surfaces are often unable to be contacted effectively with fluids containing hydrofluoric acid due to significant corrosion issues. Steel surfaces represent but one example. Corrosion inhibitor compositions comprising an N-(phosphonoalkyl)iminodiacetic acid or any salt thereof can be used to suppress corrosion of steel surfaces, including those that contain multiple types or grades of steel. Methods for suppressing corrosion of a steel surface can comprise: contacting a steel surface with a corrosive environment, the corrosive environment comprising hydrofluoric acid; exposing the steel surface to a corrosion inhibitor composition, the corrosion inhibitor composition comprising an N-(phosphonoalkyl)iminodiacetic acid or any salt thereof; and suppressing corrosion of the steel surface being contacted with the corrosive environment through exposure to the corrosion inhibitor composition.

Abstract: Corrosion inhibiting compositions and methods of inhibiting corrosion on a metal surface commonly used in the petroleum industry is disclosed. The corrosion inhibitor includes at least one azole, at least one polypeptide derived from amino acid, at least one intensifier preferably from metal halides, and at least one surfactant. The methods include combining effective amounts of the corrosion inhibitor composition and contacting a metal surface in aqueous environment commonly found in oil and gas industry. The composition is very effective against corrosion of metals in contact with aqueous media when used in a dosage as low as 50 ppm.

Abstract: A hybrid particle mix lost circulation material (LCM) is provided. The hybrid particle mix LCM includes date palm seed particles produced from date palm seeds and scrap tire particles produced from scrap tires. The LCM may include date palm seed particles in the range of about 50 wt % to about 80% and scrap tire particles in the range of about 50 wt % to about 20 wt %. Methods of lost circulation control and manufacture of a hybrid particle mix LCM are also provided.

Abstract: Disclosed herein are water-soluble polymers comprising hydrolyzable cross-linked monomer units, and methods for recovering hydrocarbon fluids from a subterranean formation using the water-soluble polymers.

Abstract: The present invention relates to energetic cocrystals, and to methods for using the same for treatment of a subterranean formation. In various embodiments, the present invention provides a method of treating a subterranean formation, the method including obtaining or providing a composition including energetic cocrystals. Each energetic cocrystal independently includes an energetic compound and a secondary material. The method also includes placing the composition in a subterranean formation.

Abstract: Fracturing systems and methods for increasing the conductivity of a flow path between a reservoir formation and a wellbore are presented that include varying a proppant concentration of a fracturing fluid in response to a measured characteristic from the wellbore during the fracturing process. During the injection of proppant pulses into the wellbore, one or more of a pulse length, pulse height, pulse shape, or duty cycle of the proppant concentration is varied. Other systems and methods are disclosed.

Abstract: The present invention relates to cocrystals including a scale-inhibiting compound, and methods of using the cocrystals for treating a subterranean formation. In various embodiments, the present invention provides a method of treating a subterranean formation including obtaining or providing a composition including cocrystals. Each cocrystal independently includes a scale-inhibiting compound and a secondary material. The method also includes placing the composition in a subterranean formation.

Abstract: A breaker fluid for breaking a filtercake in a wellbore. The fluid including a hydrolysable ester of carboxylic acid, and a chelant, an alkyl glycoside, or a combination thereof. The breaker fluid may be pre-mixed and include an amount of water less than required to completely hydrolyze the ester.

Abstract: The present disclosure describes methods and systems, including computer-implemented methods, computer program products, and computer systems, for diagnosing reservoir health. One computer-implemented method includes receiving, from a client, a plurality of reservoir diagnostic data associated with a reservoir; computing, at a server, a plurality of reservoir health sub-indices based on the plurality of the reservoir diagnostic data; computing a reservoir health diagnostic index based on the plurality of reservoir health sub-indices and a predetermined category weighting factor; determining that a reservoir health sub-index is below a predetermined threshold; in response to the determining, generating an alert; and sending, to the client, the alert and a cause, wherein the cause indicates a reason that contributes to the reservoir health sub-index being below the predetermined threshold.

Abstract: A pumping system for use in hydraulic fracturing or fracing of wells. The pumping system is generally self-contained on a transportable system, such as a trailer. The weight and configuration of the trailer must be sized to be hauled legally on United States roadways. The system components include a diesel generator with cooling radiator, a variable-frequency drive (VFD) with cooling system, an A/C induction motor and a high capacity pump. The system may also include a second generator to power other items, such as cooling fans, cooling pumps, lube pumps, lighting and electrical outlets and air conditioning units for cooling equipment. In some embodiments, the system includes single components, while other embodiments include redundant components.

Abstract: A fracturing tool features spaced releasable packers with an outlet in between. The housing has relatively moving components for opening the frac port between the packers with weight set on the lower packer. Once the frac port is opened the upper packer is set and the pumping begins. The upper packer can be released so that tension can be pulled on the lower packer to close the frac port and open a through passage in the housing. In one embodiment the through passage can be located above the lower packer to a sand jet perforator to clean debris away from the lower packer if it is difficult to release the lower packer or to abrasively perforate through a tubular. The housing outlet can be below bottom packer to perform a treatment further downhole or to operate another tool. The straddle tool can be run in on coiled tubing.

Abstract: Methods for treating an oil well having a wellbore. The methods involve injecting a microemulsion into the wellbore to increase formation crude oil production by the well. The microemulsion comprises water, a first type of solvent and a first type of surfactant. The microemulsion includes a continuous water phase.

Abstract: A portion of a drilling fluid waste is injected into a well. A cross-sectional dimension of solids in a slurry is reduced. The slurry includes the drilling fluid waste. A property of the slurry, of the well, or both is measured. A model is obtained based at least partially upon the property. The model represents an interaction of the slurry with the well. An additive is introduced into the slurry in response to measuring the property, generating the model, or both. The slurry is injected into the well after the additive is introduced.

Abstract: A downhole tool deployable within a wellbore for controlling the supply of treatment to fluid to a reservoir is disclosed. The downhole tool includes a housing defining a passage and a port extending through the housing. The housing includes a seat that is configured for deployment to a plug-receiving position for receiving a plug that is deployed through the passage. A key profile for effecting actuation of the seat to the plug-receiving position in response to registration of the key profile with a matching key on the plug being deployed through the passage is provided. The downhole tool further includes a flow control member configured for displacement relative to the port in response to application of a sufficient net force effected by a fluid pressure differential that is created by supplying pressurized fluid to the passage while the plug is deployed on the seat.

Abstract: A method of treating particles of a particle pack located in a subterranean formation comprising: introducing an additive into the subterranean formation, wherein the additive: (i) comes in contact with the particles of the particle pack; (ii) has a chemical attraction to the particles of the particle pack; and (iii) comprises a first functional group, wherein the first functional group is a water-control agent.

Abstract: Novel fracturing fluid compositions including a polymers system including a major portion of one synthetic hydratable polymer or a plurality of synthetic hydratable polymers, and a minor portion of one natural hydratable polymer or a plurality natural hydratable polymers, and an effective amount of a viscosifying system including one guanidine salt or a plurality of guanidine salts, where the effective amount is sufficient to increase the viscosity of the synthetic polymer system by 20% or more compared to fracturing fluids including only the synthetic polymer system and methods for making and using the compositions.

Abstract: A method for injecting a portion of a drilling fluid waste into a well includes separating solids from the drilling fluid waste to produce a filtered drilling fluid waste. A cross-sectional dimension of at least a portion of the solids is reduced. The filtered drilling fluid waste is combined with the at least a portion of the solids that were reduced in dimension to produce a slurry. A property of the slurry is measured. The property is adjusted in response to measuring the property. The slurry is injected into the well.

Abstract: Methods and compositions for stimulating of the production of hydrocarbons (e.g., formation crude oil and/or formation gas) from subterranean formations, and methods of selecting a composition for treating an oil or gas well. In some embodiments, the compositions are emulsions or microemulsions, which may include water, a terpene, and a surfactant.

Abstract: An apparatus for selectably isolating a subterranean formation from a production string comprises a radially expandable ring located between upper and lower sleeves and retained at a position to intrude into a central passage extending therethrough. The expandable ring is permitted to radially expand into a recess upon displacement of the lower sleeve to permit a body retained thereon to move therepast. The apparatus includes a pair of inner and outer indexing rings which cooperate to permit the inner and outer indexing rings to move towards a bottom end thereof only to a fixed endwall whereafter further movement of the inner and outer indexing rings and lower sleeve is prevented.

Abstract: Methods for reducing loss of wellbore fluid to formation may include pumping an oil-based wellbore fluid into the wellbore, where the wellbore includes an oleaginous continuous phase and a plurality of modified brine phases dispersed in the oleaginous continuous phase.

Abstract: A method of servicing a wellbore comprising providing a degradable polymer and a delayed action construct within a portion of a wellbore, a subterranean formation or both; wherein the delayed action construct comprises (i) a degradation accelerator comprising an alkanolamine, an oligomer of aziridine, a polymer of azridine, a diamine, or combinations thereof, (ii) a solid support, and (iii) an encapsulating material; and placing the wellbore servicing fluid comprising the degradable polymer and delayed action construct into the wellbore, the subterranean formation or both.

Abstract: Methods for acidizing subterranean formations may include introducing into a wellbore penetrating the subterranean formation having a temperature of about 275° F. or greater a treatment fluid comprising an aqueous fluid, a Lewis acid catalyst and a precursor; wherein the precursor is selected from the group consisting of a saccharide, a saccharide derivative, and a combination thereof; and reacting the precursor and the Lewis acid catalyst to yield an organic acid in a portion of the subterranean formation, a portion of the wellbore, or both.

Abstract: A method of treating a treatment zone of a subterranean formation penetrated by a wellbore of a well, the method including the steps of: (A) forming a treatment fluid comprising: (i) an aqueous phase comprising water having at least 1,000 ppm total dissolved inorganic salts; (ii) a carboxymethyl hydroxyethyl cellulose, wherein: (a) the carboxymethyl hydroxyethyl cellulose has a carboxymethyl degree of substitution is in the range of about 0.3 to about 0.45 per glucopyranose unit in the polymer; and (b) the carboxymethyl hydroxyethyl cellulose has a hydroxyethyl molecular substitution is in the range of about 2.1 to about 2.8 per glucopyranose unit in the polymer; and (iii) a breaker for the carboxymethyl hydroxyethyl cellulose; and (B) introducing the treatment fluid into the treatment zone. In embodiments, the carboxymethyl hydroxyethyl cellulose may or may not be crosslinked.

Abstract: Methods and compositions for stimulating of the production of hydrocarbons (e.g., formation crude oil and/or formation gas) from subterranean formations are provided. In some embodiments, the compositions are emulsions or microemulsions, which may include water, a terpene, and a surfactant. In some embodiments, methods of selecting a composition for treating an oil or gas well are provided.

Abstract: Provided herein are cementitious compositions comprising a non-aqueous fluid and an alkali-activated material. The non-aqueous fluid can include a natural oil, a synthetically derived oil, one or more surfactants, or a combination thereof. In some embodiments, the non-aqueous fluid can include an oil based mud, a synthetic based mud, or a mixture thereof. The alkali-activated material in the cementitious composition can be derived from an aluminosilicate material and an alkaline activator. In some embodiments, the aluminosilicate material includes fly ash. The alkaline activator can be selected from an alkali-hydroxide, an alkali-silicate, an alkali carbonate, an alkali bicarbonate, an alkali sulfate, and a mixture thereof. Provided herein are also wellbore servicing composition, such as compositions to reduce lost circulation of drilling fluids or cement a casing into the borehole, comprising the cementitious compositions and methods for preparing and using the cementitious compositions.

Abstract: A method of conducting multiple stage treatments. The method includes running a string into a borehole. The string having at least a first sleeve assembly and a second sleeve assembly. The first sleeve assembly in a position closing a port in the string; communicating from a radial exterior of the string or from a location downhole of the first and second sleeve assemblies to a first electronic trigger of the first sleeve assembly to trigger the first sleeve assembly into moving longitudinally relative to the string to open the port. Performing a treatment operation through the port; communicating from the radial exterior of the string or from a location downhole of the first and second sleeve assemblies to a second electronic trigger of the second sleeve assembly to trigger the second sleeve assembly into moving longitudinally relative to the string to close the port.