Abstract: The present invention includes a method of treating a hydrocarbon-bearing clastic formation having non-connate water, the method includes contacting the hydrocarbon-bearing clastic formation with a composition that includes a solvent and a surfactant wherein the solvent at least partially displaces or solubilizes the water in the formation.

Abstract: Spherical and rod-shaped proppants and anti-flowback agents made from sillimanite minerals possess high strength and high conductivity. The sillimanite minerals may be selected from the group consisting of kyanite, sillimanite, and andalusite and may be used alone or in combination with other materials, such as bauxite, kaolin, meta-kaolin, pure or technical grade alumina (about 98%-99.9% alumina by weight), alumina-containing slag, zirconia, silica, iron, alkali elements (such as calcium, magnesium, and sodium), and virtually any other mineral containing alumina. The starting material may optionally be milled to achieve better compacity and crush resistance in the final proppant or anti-flowback agent. A fracturing fluid may comprise the rods or spheres alone, or in combination with each other or other proppants or anti-flowback agents of different shapes.

Abstract: A wellbore servicing composition comprising a metal oxide, a soluble salt and a viscosifier wherein the viscosifier comprises a quaternary amide, a quaternary amide ester, or combinations thereof. A wellbore servicing composition comprising magnesium oxide, a chloride or phosphate salt and a quaternary material. A wellbore servicing composition comprising magnesium oxide, magnesium chloride, and a quaternary material wherein the quaternary material comprises a quaternary amide, a quaternary amide ester or combinations thereof and wherein the quaternary material is present in an amount of from about 0.05 wt. % to about 5 wt. % and a plot of the composition's plastic viscosity as a function of the amount of quaternary material is about linear.

Abstract: Methods and compositions for forming a hydraulic fracture are disclosed herein. The methods and compositions make use of novel amphiphobic proppants. The amphiphobic properties of the disclosed proppant compositions provide several advantages over existing solutions. The hydrophobic nature of the proppant enhances recovery of fracture fluid from the fracture as well as prevents liquid build-up with the fracture. Additionally, the lipophobic nature of the proppant may enhance production of hydrocarbons from the fracture.

Abstract: A treatment of a subterranean formation which contains a hydrocarbon-bearing zone, is carried out using a hydrocarbon-responsive fluid thickened with an oligomeric surfactant consisting of from 2 to 8_linked surfactant monomer subunits. The process of treatment comprises (i) mixing a thickening amount of oligomeric surfactant with an aqueous liquid to make a viscoelastic treatment fluid, (ii) pumping said viscoelastic treatment fluid through a wellbore and into the subterranean formation, where (iii) contact with hydrocarbons within the formation dissipates the viscosity of the treatment fluid.

Abstract: A reservoir cleaning, treating and/or stimulation system allows the operator to control the speed and pressure of delivery of the treating fluid into the reservoir and remove or dissolve sediment particles settled in the reservoir or the reservoir formation. The system uses a thermal heater capable of heating the treating fluid from ambient temperature to about 400 degrees Fahrenheit. A charge pump mounted on an intake side of the heater forces the treating fluid through the heater, while the treating fluid passes through the tubing of the heater. The heated treating fluid is channeled to a discharge pump on an outlet side of the heater, where the treating fluid is pressurized to a value sufficient to overcome the pressure existing within the reservoir and cause displacement or dissolution of the sediment in the reservoir. A flow meter mounted between the heater and the charge pump regulates the volume of the treating fluid being admitted into the heater.

Abstract: An engineered composition for reducing lost circulation in a well includes a mixture of coarse, medium and optional fine particles, and a blend of long fibers and short fibers. The long fibers are rigid and the short fibers are flexible. The long fibers form a tridimensional mat or net in the lost-circulation pathway that traps the mixture of particles and short flexible fibers to form a mudcake. The mixture of particles and blend of fibers may be added to water-based and oil-based drilling fluids. The composition, size, and concentration of each component of the mixture of particles and blend of fibers may be fine-tuned for each application.

Abstract: Spherical and rod-shaped proppants and anti-flowback agents made from sillimanite minerals possess high strength and high conductivity. The sillimanite minerals may be selected from the group consisting of kyanite, sillimanite, and andalusite and may be used alone or in combination with other materials, such as bauxite, kaolin, meta-kaolin, pure or technical grade alumina (about 98%-99.9% alumina by weight), alumina-containing slag, zirconia, silica, iron, alkali elements (such as calcium, magnesium, and sodium), and virtually any other mineral containing alumina. The starting material may optionally be milled to achieve better compacity and crush resistance in the final proppant or anti-flowback agent. A fracturing fluid may comprise the rods or spheres alone, or in combination with each other or other proppants or anti-flowback agents of different shapes.

Abstract: A method of absorbing gases into a liquid comprising providing a stream of at least one desirable gas and at least one undesirable gas, exposing the gas stream to a liquid, so that the liquid absorbs more of the desirable gas than the undesirable gas, and releasing the liquid and gas mixture into an underground formation.

Abstract: A fluid loss control method uses a fluid loss control pill in a well in advance of a completion operation. An embodiment of the fluid loss control pill comprises polyester solids that are hydrolysable and can exhibit plastic deformation at formation conditions. An embodiment of the method comprises spotting the fluid loss control pill in the well adjacent to a formation to form a filtercake to inhibit fluid entry from the well into the formation, performing a completion operation comprising contacting the filtercake with overbalanced wellbore fluid, and degrading the filtercake wherein the polyester particles are hydrolyzed to remove formation damage.

Abstract: Of the many compositions and methods provided herein, an example method includes a method of treating a subterranean formation that comprises combining components comprising water and a density-matched suspension to prepare a treatment fluid, wherein the density-matched suspension comprises a suspending liquid and a solid particle suspended in the suspending liquid, and introducing the treatment fluid into a well bore. An example composition includes a suspension that comprises a suspending liquid comprising a hydrophobic liquid, wherein the hydrophobic liquid hydrolyzes when placed in contact with an aqueous fluid to form hydrophilic products, and a solid particle suspended in the suspending liquid, wherein the suspension is a density-matched suspension.

Abstract: A method of treating a wastewater is provided and can be used, for example, to treat a gas well hydrofracture wastewater. The method can involve precipitating barium as barium sulfate, precipitating calcium and strontium as calcium carbonate and strontium carbonate, precipitating magnesium hydroxide, and filtering out the metal compounds to form a recycle water. The recycle water produced from the method is also provided, as is a method for using the recycle water as a gas well hydrofracture water. In some embodiments, discharge water from a coal mine, and/or water from an abandoned coal mine, is used as a source of sulfate ions to precipitate barium as barium sulfate.

Abstract: The concept involves placing within the annulus, hollow particles that possess material and geometric properties such that the hollow particles buckle at or near a defined pressure. Buckling of the particles increases the available volume within the annulus, thereby decreasing the annular pressure. The elastic hollow particles are designed such that they buckle in a sufficiently elastic manner to allow them to rebound towards their original shape as the pressure decreases. The rebounded particles then remain available to mitigate subsequent instances of APB.

Abstract: Controlling microbial growth and activity during Microbial Enhanced Oil Recovery processes is disclosed. Specific control of microbial growth and activity in this process results in prevention of nutrient loss in transit and allows better targeting of microbial activity to the desired subsurface location(s).

Abstract: The present invention relates to methods and compositions for carrier fluids comprising water-absorbent fibers. One embodiment of the present invention provides a method of treating a portion of a subterranean formation, comprising providing a slurry wherein the slurry comprises a servicing fluid, particulates, and a degradable, water-absorbent material wherein the degradable, water-absorbent material acts to help keep the particulates from settling out of the slurry; and, introducing the slurry into the portion of the subterranean formation. Another embodiment of the present invention provides a slurry suitable for use in subterranean operations comprising a servicing fluid, particulates, and a degradable, water-absorbent material wherein the degradable, water-absorbent material acts to help keep the particulates from settling out of the slurry.

Abstract: The present disclosure relates to systems and methods for producing a fracturing gel using a preheated hydration fluid. The hydration fluid can be preheated using heat energy recycled from a different part of the operation. Recycling the heat energy can, in certain instances, reduce gel production costs and gel hydration times while improving gel yield.

Abstract: A hydrocarbon industry servicing fluid comprises an irradiated fluid that is biologically inert. The fluid may be irradiated with ultraviolet light. A method comprises performing a hydrocarbon industry service operation with an irradiated fluid that is biologically inert. The method may comprise disposing of the irradiated fluid to the environment or capturing the irradiated fluid when the service operation is complete. The method may further comprise re-irradiating the captured irradiated fluid to produce a remediated fluid, and performing a service operation with the remediated fluid.

Abstract: This invention relates to methods for stimulating oil production from well by pumping reactive stimulation fluids from the well into the formation. The methods are particularly relevant to cold heavy oil production. This invention provides methods of stimulating production from a formation surrounding a well, comprising pumping a fluid from the well into the formation so as to create a hydraulic fracture, wherein the fluid contains one or more reactive species that destabilise cohesive forces in the formation matrix, and allowing the fluid to leak of into the formation and react with the formation matrix so as to produce a destabilised zone in the formation around the location of the fracture such that formation fluids and sand particles can be produced from the formation through the zone and into the well. The methods preferably comprise selecting the fluid so as to produce an at least partially unconsolidated formation matrix in the destabilised zone.

Abstract: A composition comprising: (i) a chelating aminocarboxylic acid-C8-C22 amine complex; (ii) a C15-C21 bis(2-hydroxyethyl)amide; and (iii) a C15-C44 imidazoline compound.

Abstract: The present invention relates generally to a method for treating hydrogen sulfide-containing fluids, more specifically to a method of treating hydrogen sulfide associated with petroleum and/or natural gas production.

Abstract: A polyelectrolyte complex for the controlled release of an oil and gas field chemical selected from the group consisting of (a) a gel-forming or cross-linking agent, (b) a scale inhibitor, (c) a corrosion inhibitor, (d) an inhibitor of asphaltene or wax deposition, (e) a hydrogen sulfide scavenger, (f) a hydrate inhibitor, (g) a breaking agent, and a surfactant.

Abstract: Fluids viscosified with viscoelastic surfactants (VESS) may have their fluid loss properties improved with at least one mineral oil which has a viscosity greater than 20 cps at ambient temperature. The mineral oil may initially be dispersed oil droplets in an internal, discontinuous phase of the fluid. In one non-limiting embodiment, the mineral oil is added to the fluid after it has been substantially gelled in an amount between about 0.2 to about 10% by volume.

Abstract: Compositions and methods are given for delayed breaking of viscoelastic surfactant gels inside formation pores, particularly for use in hydraulic fracturing. Breaking inside formation pores is accomplished without mechanical intervention or use of a second fluid. Acidic internal breakers such as sulfuric acid and nitric acid are used. The break may be accelerated, for example with a free radical propagating species, or retarded, for example with an oxygen scavenger.

Abstract: The invention describes improved environmentally friendly, non-toxic, CBM friendly, green fracturing compositions, methods of preparing fracturing compositions and methods of use. Importantly, the subject invention overcomes problems in the use of water-based mists as an effective fracturing composition particularly having regard to the ability of a mist to transport an effective volume of proppant into a formation. As a result, the subject technologies provide an effective economic solution to using high ratio gas fracturing compositions that can be produced in a continuous (i.e. non-batch) process without the attendant capital and operating costs of current pure gas fracturing equipment.

Abstract: The invention describes improved environmentally friendly, non-toxic, green fracturing compositions, methods of preparing fracturing compositions and methods of use. Importantly, the subject invention overcomes problems in the use of water-based mists as an effective fracturing composition particularly having regard to the ability of a mist to transport an effective volume of proppant into a formation. As a result, the subject technologies provide an effective economic solution to using high ratio gas fracturing compositions that can be produced in a continuous (i.e. non-batch) process without the attendant capital and operating costs of current pure gas fracturing equipment.

Abstract: A surfactant blend of a low molecular weight surfactant and a high molecular weight surfactant to be used in an aqueous flooding. The surfactant blend may be neutralized with an alkali or alkaline agent. The surfactant blend may be mixed with a polymer. Surfactant blends of the present invention increase oil recoveries from oil reservoirs.

Abstract: The present invention is directed to methods of extracting a hydrocarbon-based product from subsurface (oil) shale formations, wherein such methods rely on the use of an extraction fluid comprising pentane for facilitating the production of a mobile hydrocarbon-based product when the pentane contacts hydrocarbons in subsurface shale. The contacting process, and the subsequent process of recovering the mobile hydrocarbon-based product, is further enhanced by the methods of fracturing and/or rubblizing portions of the shale formation, so as to enhance their fluid permeability.

Abstract: Clean-up additive compositions may be used to enhance the clean-up of VES-gelled aqueous fluids in a wide range of applications and VES fluid compositions, including use of an internal breaker system. The compositions are microemulsions that may include, but not necessarily be limited to, at least one viscosity reducing agent, at least one solubilizing agent, at least one desorption agent and at least one water wetting agent. One non-limiting embodiment of a specific microemulsion includes an unsaturated fatty acid oil, a glycol, a sorbitan ester/ethoxylated sorbitan ester mixture, and an alkyl sulfonate. Microemulsions may perform one or more of the following functions: keeping the reservoir water wet; keeping surface tension reduction low; demulsifying reservoir crude oils and aqueous VES fluids; dispersing and solubilizing the by-products generated when breaking the VES gel; and/or limiting the amount of VES residue on reservoir minerals.

Abstract: The invention discloses a well treatment composition for use in a subterranean formation comprising: a carrier fluid; and a viscoelastic surfactant being present in a concentration of less than about 1.5% by weight. Optionally, the fluid comprises a crosslinked polymer in a thickening amount in the carrier fluid. The invention also discloses a method to increase the viscosity of a fluid, the method comprising: providing a fluid comprising a thickening amount of a crosslinked polymer; adding a viscoelastic surfactant at a given concentration to the fluid; taking the fluid to a given temperature; defining a viscosity profile of the fluid depending of the concentration and the temperature; comparing said viscosity profile to a viscosity profile of the crosslinked polymer fluid alone; and defining an optimum concentration of the viscoelastic surfactant for each temperature.

Abstract: Single-phase microemulsions (SPMES) and in situ-formed microemulsions in water-wetting pills may be used to reverse the wettability of subterranean rock previously drilled with an oil-based mud or synthetic-based mud before pumping a high fluid loss squeeze pill or crosslink pill or other water-based pill. This wettability reversal occurs by solubilization of the non-polar material into the microemulsion when the water-wetting pill contacts the non-polar material. An in situ microemulsion may be formed when one or more surfactant and a polar phase (e.g. water or brine), and eventually some amount of organic phase, contacts the reservoir formation and reverses the wettability encountered in the porous media. The microemulsions are effective for reversing the wettability that occurs from non-polar materials which include, but are not necessarily limited to, oil-based mud, synthetic-based mud, paraffins, asphaltenes, emulsions, slugs, and combinations thereof.

Abstract: A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant (16) and proppant-spacing filler material called a channelant (18) through a wellbore (10) into the fracture (20), heterogeneously placing the proppant in the fracture in a plurality of proppant clusters or islands (22) spaced apart by the channelant (24), and removing the channelant filler material (24) to form open channels (26) around the pillars (28) for fluid flow from the formation (14) through the fracture (20) toward the wellbore (10). The proppant and channelant can be segregated within the well treatment fluid, or segregated during placement in the fracture. The channelant can be dissolvable particles, initially acting as a filler material during placement of the proppant in the fracture, and later dissolving to leave the flow channels between the proppant pillars.

Abstract: The invention discloses a method of for changing the water permeability of a subterranean formation of a well, the method comprising: providing a fluid comprising a liquid carrier and a viscoelastic surfactant; introducing the fluid into the well; and contacting the fluid and the subterranean formation wherein the action of the liquid carrier and the viscoelastic surfactant is able to change the water permeability of the subterranean formation. The fluid may further comprise methanol, or a salt which can be embodied within the carrier fluid. Advantageously, no further RPM polymer is used. In a first aspect the method is used for reducing the amount of water produced, in as second aspect for improving the oil recovery.

Abstract: A method of solubilizing/removing cellulose or chemically-modified cellulosic polymers utilized in subterranean drilling operations such as fracturing. The method involves introducing a deep eutectic solvent (DES) into a subterranean region. Deep eutectic solvents useful as cellulose solvents include quaternary ammonium compounds, including choline chloride and chlorcholine chloride, reacted with a compound selected from amides, amines, carboxylic acids alcohols, and metal halides. The DES material can be pumped downhole after fracturing operations to remove cellulosic material used, for example, to thicken fracturing fluid which is left behind in the created fractures, on the face of the formation, along the wellbore, or elsewhere within the subterranean region. The DES can be used alone or in a sequential treatment protocol, whereby the DES is introduced into the subterranean region, followed by post-treatment introduction of water, caustic, acid or anhydride into the subterranean as a flush.

Abstract: A mixture of proppant particles and conductivity enhancing structures is disclosed. The spherically shaped proppant particles have convex surfaces. The conductivity enhancing structures include concave surfaces. The proppant particles' convex surfaces abut the conductivity enhancing structures concave surfaces.

Abstract: A method of treating a subterranean formation penetrated by a wellbore to mitigate the production of unwanted fluids from the wellbore is carried out by forming a treatment fluid containing at least one of an oil-wetting or water-repelling surfactant and a carrier fluid. The treatment fluid is then introduced into the wellbore. The treatment or treatments may be performed remedially or prophylacticaly. The treatment may include the completion and production of zones containing the undesirable fluid(s) and the deliberate formation of cones therein.

Abstract: A method for increasing drilling rates by reducing torque and drag in hostile environments such as high pressure, high temperature, and horizontal wells is provided by adding chemically and thermally inert spherical carbon beads to the drilling fluid.

Abstract: A composition and method are given for self-destructive fluid loss additives and filter cakes in wellbores and subterranean formations. The fluid loss additives and filter cakes are formed from a mixture of particulate solid acid-precursors, such as a polylactic acid or a polyglycolic acid, and particulate solid acid-reactive materials, such as magnesium oxide or calcium carbonate. In the presence of water, the solid acid-precursors hydrolyze and dissolve, generating acids that then dissolve the solid acid-reactive materials. The composition is used in oilfield treatments such as drilling, completion and stimulation where it disappears when it is no longer needed without the use of mechanical means or injection of additional fluids.

Abstract: The present application relates to granules of powdery mineral particles produced by spray granulation of a liquid slurry comprising powdery minerals particles having particle size below 10 m, at least one water-reducing agent and/or at least one binder agent and/or at least one dispersing agent. The application further relates to a method for producing such granules.

Abstract: Nano-sized clay minerals enhance the viscosity of aqueous fluids that have increased viscosity due to the presence of viscoelastic surfactants (VESs). In one non-limiting theory, the nano-sized clay mineral viscosity enhancers associate, link, connect, or relate the VES micelles thereby increasing the viscosity of the fluid, possibly by mechanisms involving chemisorption or surface charge attractions. The nano-sized clay particles may have irregular surface charges. The higher fluid viscosity is beneficial to crack the formation rock during a fracturing operation, to reduce fluid leakoff, and to carry high loading proppants to maintain the high conductivity of fractures.

Abstract: Method of modeling the biodegradation of hydrocarbons trapped in an oil reservoir or trap through the action of the bacterial population in an underlying aquifer.

Abstract: A fluid injection system is used in a well. Fluid stages are arranged in repeating series within a tubing of the fluid injection system to facilitate control over effects of injection. A sensor system can be used to detect one or more parameters related to the fluids moved downhole through the tubing to further enhance injection procedures.

Abstract: A method of controlling the pressure of a casing annulus in a subterranean well that includes injecting into the casing annulus a composition including a base fluid and a polymer coated colloidal solid material. The polymer coated colloidal solid material includes: a solid particle having an weight average particle diameter (d50) of less than two microns, and a polymeric dispersing agent coated onto the surface of the solid particle during the comminution (i.e. grinding) process utilized to make the colloidal particles. The polymeric dispersing agent may be a water soluble polymer having a molecular weight of at least 2000 Daltons. The solid particulate material may be selected from materials having of specific gravity of at least 2.68 and preferably the solid particulate material may be selected from barium sulfate (barite), calcium carbonate, dolomite, ilmenite, hematite, olivine, siderite, strontium sulfate, combinations and mixtures of these-and other similar solids.

Abstract: Oil wells may be fracture treated on-site in order to stimulate production. Such fracture treatment may be performed using a portable blender tub to mix fracturing fluid, proppant, and dry chemical additive into an injection slurry. A mechanical conveyance device may be adjustably attached to the portable blender tub, so that in its first position it is stowed for transport, while in its second position it is deployed for operation. When deployed, the mechanical conveyance device may mechanically convey and meter dry chemical additive into the blender tub, allowing a handler to feed and meter dry chemical additive while standing on the ground. This allows for improved safety and efficiency in fracture treating a wellbore.

Abstract: A method comprising placing a sealant composition comprising one or more MEMS sensors in a wellbore and allowing the sealant composition to set. A method of servicing a wellbore comprising placing a MEMS interrogator tool in the wellbore, beginning placement of a sealant composition comprising one or more MEMS sensors into the wellbore, and terminating placement of the sealant composition into the wellbore upon the interrogator tool coming into close proximity with the one or more MEMS sensors. A method comprising placing a plurality of MEMS sensors in a wellbore servicing fluid. A wellbore composition comprising one or more MEMS sensors, wherein the wellbore composition is a drilling fluid, a spacer fluid, a sealant, or combinations thereof.

Abstract: One embodiment of the present invention relates to spherical ceramic elements, such as proppants, for maintaining permeability in subterranean formations to facilitate extraction of oil and gas therefrom. The strength of the ceramic element may be enhanced by combining materials having different coefficients of thermal expansion. Methods of making the ceramic elements are also disclosed.

Abstract: A proppant composition comprises a non-radioactive, detectable tracer at least partially embedded in a ceramic composition. The composition may be prepared by agglomerating granules of the ceramic material and granules of the non-radioactive, detectable material to produce the particle by compression. Backflow of proppants in a fractured subterranean formation into which a plurality of particles of the proppant composition have been introducted may be tracked by analyzing a sample of the backflow by detecting for presence of the tracer in the sample.

Abstract: Viscoelastic surfactant (VES) gelled aqueous fluids containing water, a VES, an internal breaker, a VES stabilizer, a fluid loss control agent and a viscosity enhancer are useful as treating fluids and particularly as fracturing fluids for subterranean formations. These VES-based fluids have faster and more complete clean-up than polymer-based fracturing fluids. The use of an internal breaker permits ready removal of the unique VES micelle based pseudo-filter cake with several advantages including reducing the typical VES loading and total fluid volume since more VES fluid stays within the fracture, generating a more optimum fracture geometry for enhanced reservoir productivity, and treating reservoirs with permeability above the present VES limit of approximately 400 md to at least 2000 md.

Abstract: Treatment fluids are provided that include a treatment fluid comprising a base fluid and a gelling agent that comprises clarified diutan. In some embodiments, the treatment fluid is a subterranean treatment fluid. In some embodiments, the treatment fluid is a subterranean treatment fluid comprising a base fluid, a gelling agent that comprises clarified diutan, and at least a plurality of particulates. Additional treatment fluids are also provided.

Abstract: Methods are provided that include a method comprising providing a treatment fluid comprising a base fluid and a gelling agent that comprises a clarified diutan; and introducing the treatment fluid into at least a portion of a subterranean formation. In some embodiments, the treatment fluid may be placed into at least a portion of a subterranean formation at a pressure sufficient to create or enhance at least one fracture in the subterranean formation. In some embodiments, the treatment fluid may be introduced into a pipeline. Additional methods are also provided.

Abstract: A method of enhancing hydration of a hydratable material is described, including providing an aqueous composition including a hydratable material, and supplying energy to the aqueous composition using a cavitation device.