Abstract: Methods and system involving well control. In some embodiments, the system includes an injection spool coupled to a subsea wellhead including an inlet, a manifold in fluid communication with the inlet of the injection spool for mixing one or more components of a well control treatment composition, a first container for storing natural gas in fluid communication with the manifold, and a second container for storing nitrogen in fluid communication with the manifold.

Abstract: Disclosed are foam precursor compositions, foamed compositions, and methods of using these foamed compositions for the stimulation of unconventional reservoirs.

Abstract: A method of consolidating a subterranean formation which comprises particles is provided. The method includes selecting a subterranean formation in need of consolidation, contacting the particles with a cationic polymer and then an anionic or non-ionic polymer, thereby agglomerating the particles and consolidating the formation, wherein the agglomeration increases the uniformity of the size of the particles. Methods of producing hydrocarbon wherein the formation is consolidated by the method herein described are also provided. Use of kits comprising cationic polymer and anionic polymer and/or non-ionic polymer to consolidate subterranean formations is further provided. Kits comprising the polymers used in the method are also provided.

Abstract: The present invention discloses a method for enhancing the recovery factor of heavy oil by in-situ oil-water emulsion with high phase inversion point, and the method is aimed at the development of heavy oil reservoir by water injection under the condition that the performance parameters of crude oil emulsion meet the following three specific requirements: (A) The viscosity of the crude oil is less than 6,000 mPa·s; (B) At the reservoir temperature, the phase inversion point of the crude oil emulsion is greater than or equal to 70%, and the emulsion viscosity corresponding to the phase inversion point is 2-6 times of the crude oil viscosity; (C) At the reservoir temperature, when the water cut is less than or equal to the phase inversion point, the flow rate ratio of crude oil emulsion to crude oil is 0.2 to 0.9.

Abstract: The present disclosure generally relates to systems and methods for horizontal well completions, including dual monobore completions, without certain well intervention operations. More specifically, the embodiments described herein generally eliminate certain well intervention operations, such as cleaning of cementing-related equipment and accessories (e.g., plugs, balls, and so forth), performing logging operations, running and cementing intermediate casings, and so forth. In certain embodiments, a production casing may be run into a wellbore and cemented into place within the wellbore directly adjacent a surface casing of the well. In certain embodiments, the production casing comprises first and second tubular sections longitudinally separated by an intermediate tapered section.

Abstract: The present invention provides environmentally-friendly compositions and methods for degrading polymers used in fracking operations to enhance the recovery of oil and gas. Specifically, the compositions and methods utilized microorganisms and/or their growth by-products to degrade polymers, such as PGA, PLA and PAM, used in fracking wells.

Abstract: A packaging structure, where the packaging structure includes: a first radiation plate, a second radiation plate, and a feeding part, where the second radiation plate is disposed below the first radiation plate, where a slot is disposed on the second radiation plate, where the slot is in a ring shape, where the feeding part is disposed below the second radiation plate, and where the feeding part includes a first feeding stub and a second feeding stub that are disposed independently of each other. Additionally, the first feeding stub and the second feeding stub are perpendicular to each other and disposed on a substrate below the slot, and the first feeding stub and the second feeding stub feed the first radiation plate using the slot.

Abstract: A planar antenna clamp system comprising: a base; a connector mounted to the base; a clamp arm mounted to the base such that, when in an open configuration, an air gap exists between the top surface of the base and the bottom surface of the clamp arm's distal end, and wherein the clamp arm and the base are oriented with respect to one another such that conductors of a planar antenna may be positioned in the air gap when in the open configuration; a matching circuit disposed on the top surface of the base and electrically connected to the connector; and a clamp configured to compress the conductors of the planar antenna between the top surface of the base and the bottom surface of the clamp arm such that the conductors of the planar antenna are operatively coupled with the matching circuit, when in a closed configuration.

Abstract: The invention relates to a process for mineral oil production, in which an aqueous saline surfactant formulation comprising a surfactant mixture of at least one anionic surfactant of the general formula R1—O—(CH2C(CH3)HO)x—(CH2CH2O)y—SO3M and at least one anionic surfactant of the general formula R2—O—(CH2CH2O)z—SO3M and a base is injected through injection boreholes into a mineral oil deposit, and crude oil is withdrawn from the deposit through production boreholes. The invention further relates to the surfactant mixture, a concentrate comprising the surfactant mixture and a manufacturing process as well as the use of the surfactant mixture and the con- centrate in the production of mineral oil from underground mineral oil deposits.

Abstract: A method for selecting a surfactant solution for use in an enhanced oil recovery process may include contacting a surfactant solution with crude oil to produce a crude/surfactant mixture, compressing the interface between the crude oil and the surfactant solution in a Langmuir trough to obtain an interface pressure versus surface area isotherm, calculating an interface compression energy of the interface between the crude oil and the surfactant solution by integrating the interface pressure versus surface area isotherm, and selecting the surfactant solution for use in an enhanced oil recovery process if the interface compression energy of the interface between the crude oil and the surfactant solution is at most 100 Ergs.

Abstract: A method for injecting non-condensable gas or application of in-situ combustion to recover remaining oil in a heavy oil reservoir with bottom water includes: drilling a new horizontal well in an oil layer between the existing horizontal production well location and the bottom water layer; preheating the new horizontal well; after the horizontal section of the horizontal well is in thermal communication with the upper steam/gas chamber, performing gas injection in existing wells to maintain pressure slightly higher or similar to the pressure of the bottom water layer, and converting the horizontal well into a continuous production well; drilling a vertical well in the unswept reservoir area; establishing a fluid communication in the oil layer between the vertical well and the horizontal well, injecting air or oxygen into the vertical well; and in the later stage of the horizontal well, stopping gas injection and gradually reducing the pressure in the steam/gas chamber.

Abstract: This invention relates to a surfactant composition, production and use thereof in tertiary oil recovery. The present surfactant composition comprises a cationic-nonionic surfactant and an anionic surfactant, and exhibits significantly improved interfacial activity and stability as compared with the prior art. With the present surfactant composition, a flooding fluid composition for tertiary oil recovery with improved oil displacement efficiency and oil washing capability as compared with the prior art could be produced.

Abstract: Drilling fluid compositions and methods for using drilling fluid compositions are provided with enhanced anti-bit balling properties that includes an aqueous base fluid, one or more drilling fluid additives, and an anti-bit balling additive where the anti-bit balling additive comprises a C15-C18 alkene or a mixture of two or more C15-C18 alkenes. Methods for using the drilling fluid compositions may further include mixing the mixing an aqueous base fluid with one or more drilling fluid additives and an anti-bit balling additive, wherein the anti-bit balling additive includes a C15-C18 alkene or a mixture of two or more C15-C18 alkenes, and introducing the drilling fluid to a subterranean formation.

Abstract: An oil recovery method may include injecting 0.05 to 0.25 pore volumes of low-salinity water having 4,000-8,000 ppm of total dissolved solids into a reservoir, and then applying seismic stimulation to the reservoir for a predetermined duration. The steps of injecting low-salinity water and applying seismic stimulation are repeated until 0.25 to 1.0 pore volumes of the low-salinity water has been added to the reservoir. Then, high-salinity water having 35,000 to 57,000 ppm of total dissolved solids is introduced to the reservoir.

Abstract: A method for improving oil recovery within a subterranean formation that includes forming a barrier within the formation to isolate at least a portion of a first region from a proximate second region. The barrier is formed by introducing a first solution including an ammonium containing compound and a second solution including a nitrite containing compound into the formation. The first solution, the second solution, or both, further include a foaming agent. The compounds react to generate nitrogen gas in the presence of the foaming agent to generate a foam within a first region. The foam provides the barrier. Water is introduced into the formation. The barrier diverts the water away from the first region and into the second region. The water operates to displace at least a portion of a hydrocarbon present in the second region and discharge the hydrocarbon from the formation.

Abstract: A method of extracting oil from a subsurface reservoir includes the steps of accessing the subsurface reservoir by means of a well, injecting a waterflooding composition comprising water and a functional molecule, into the subsurface reservoir through the well, altering the interfacial viscoelasticity, and extracting the oil through the well.

Abstract: Methods and systems produce petroleum products by insulating a thermal hydrocarbon recovery process from heat loss to surrounding areas of a formation utilizing an insulating composition including a non-gaseous phase component introduced into the reservoir that is different from water and insoluble in the hydrocarbons. The insulating composition may be disposed in the reservoir adjacent to where the heat loss is desired to be limited. In addition, the insulating composition may be disposed in a thief zone and may also be from an agent activated to form the composition at such desired locations by selecting activation dependent on at least one of temperature, time delay and oil saturation.

Abstract: The present invention relates to a method for the production of crude oil from subterranean, oil-bearing formations comprising at least the following steps of providing an aqueous surfactant composition comprising water and a surfactant mixture, injecting said surfactant composition into the subterranean, oil-bearing formation through at least one injection well, thereby reducing the crude oil-water interfacial tension to less than 0.1 mN/m, and withdrawing crude oil from the formation through at least one production well, wherein the surfactant mixture comprises at least a surfactant (A) having the general formula R1—O—(CH2CH(R2)O)a—(CH2CH(CH3)O)b—(CH2CH2O)c—R3—Y?M+ (I) and a solubility enhancer (B) having the general formula R4—O—(CH2CH(CH3)O)x—(CH2CH2O)y—R3—Y?M+ (II), wherein R1 to R4, a, b, c, x, y, Y and M have the meaning as defined the the description and claims.

Abstract: The proposed method is an improved chemical flooding of an oil reservoir, especially one containing heavy oil or bitumen, that is cheaper than traditional chemical flooding techniques. This is obtained by viscosifying the displacing phase with a polyol, such as glycerol and/or its derivatives. Glycerol and its derivatives are an excellent additive because they are cheaper than the more commonly used chemicals, work only as a viscosifying agent, do not alter the reservoir properties, and have a wide range of viscosity facilitating the displacement of a wider range of heavy oils. This improved chemical flooding can be used with any other enhanced oil recovery technique, including thermal means, solvent assisted and polymer floodings.

Abstract: The invention relates to a process for producing at least one alkoxylated polyphenol comprising the following successive steps: (a) reacting at least one polyphenol, at least one alkoxylating agent, at least one catalyst, in the presence of at least one alkoxylated polyphenol as a solvent, the polyphenol/polyphenol alkoxylated weight ratio as a solvent being less than 2, preferably less than or equal to 1.5, more preferably less than or equal to 1, even more preferably less than or equal to 0.5; and (b) removing the residual alkoxylating agent.

Abstract: Emulsion or microemulsion for treating an oil or gas well having a wellbore are provided, and related methods. In some embodiments, the emulsion or microemulsion comprises an aqueous phase; a surfactant; and a non-aqueous phase comprising a first type of solvent and a second type of solvent. In some embodiments, the first type of solvent is a long chain hydrocarbon. In some embodiments, the second type of solvent is an oxygenated solvent. The emulsion or microemulsion may comprise additional components (e.g., at least one type of co-solvent).

Abstract: A composition for use in surfactant polymer flooding processes in a carbonate reservoir, the composition comprising a surfactant, the surfactant operable to reduce interfacial tension, a polymer, the polymer operable to increase the viscosity of the composition, and a tailored water, the tailored water operable to alter a wettability of the in-situ rock, where the tailored water has a total dissolved solids of between 5,000 wt ppm and 7,000 wt ppm, where the total dissolved solids comprises a salt, where the composition has a viscosity between 3 cP and 100 cP.

Abstract: A method for recovering hydrocarbons in a carbonate reservoir by introducing a saline solution injection containing a saline soluble surfactant and a saline soluble polymer. The method provides for increased hydrocarbon recovery as compared to conventional waterflooding techniques.

Abstract: A method of fracturing a subterranean formation to produce fluid from a reservoir through a wellbore includes flowing a treating fluid into the wellbore to create fractures in the formation, selectively flowing a flow constraint material (FCM) into the wellbore simultaneously with the treating fluid, pausing the flow of the FCM while maintaining the flow of the treating fluid, monitoring a parameter of the formation to determine whether the parameter is within a range, resuming the flow of the FCM when the parameter of the formation is out of the range, ceasing the flow of the FCM when the parameter of the formation is in the range, where a system strain increase is about 0.0003 or less when the parameter of the formation is in range, and where the flow of the flow constraint material partially constrains the treating fluid from entering at least one of the fractures.

Abstract: An aqueous caustic composition comprising: a caustic component; an additive adapted to provide an extended buffering effect to the caustic composition when such is exposed to an acid; and water. Methods of using such compositions are also disclosed.

Abstract: An imbibition gel composition that induces spontaneous imbibition of a water phase into a reservoir matrix is provided. The imbibition gel composition including a surfactant, the surfactant operable to alter the wettability of a surface of a reservoir matrix from oil-wet toward water-wet and the surfactant further operable to diffuse through the water phase. The imbibition gel composition further including a gel system, the gel system operable to retain the surfactant and the gel system further operable to release the surfactant in the presence of the water phase, where altering the wettability of the surface of the reservoir matrix toward water-wet induces the spontaneous imbibition of the water phase into the reservoir matrix.

Abstract: The present invention provides a method for in-depth profile control and displacement of low-permeability oil reservoirs, comprising: sequentially injecting a flexible and elastic particle-containing pre-slug, a polymer microsphere-containing main slug and a flexible and elastic particle-containing protective slug into an oil layer, and the three slugs have a volume ratio of total injection amount of 1-2:6-8:1-2. The invention provides a method for in-depth profile control and displacement by using styrene-based flexible and elastic particles in combination with the polyacrylamide polymer microsphere, wherein the flexible elastic particles can block cracks and large pore channels of the oil layer, and the polymer microsphere can displace the remaining oil in the oil layer. In the present invention, different slugs of profile control and displacement system are combined to achieve the objective of blocking cracks and large pore channels, displacing crude oil, and improving oil well recovery.

Abstract: A hydrocarbon field including thief zones can be modeled based on production history data and supplemental data constraining a thief-zone distribution across the field. In various embodiments, a numerical optimization approach involves creating a plurality of model thief-zone distributions with varying parameter values, parameterizing permeability maps obtained for the thief-zone distributions and aggregating across the thief-zone distributions to obtain distributions of coefficients associated with the parameterization, and then iteratively sampling the coefficient distributions, determining a permeability map of the model based on the selected coefficients, and measuring a deviation between the measured production history data and simulated production history data derived from the computational model until a match is achieved.

Abstract: Injectates and method that use surface blocking agents for enhancing subterranean oil recovery are disclosed. The surface blocking agents reduce the adhesion of oil to rock surfaces thereby increasing oil recovery. The surface blocking agents attach to or are attracted to the oils positive nitrogen sites and have an opposing negative charge that is repulsed by the negative rock surface charge.

Abstract: Viscous aqueous injections fluids including polymers having hydrophilic moieties and hydrophobic groups and at least one of crude oil emulsions and amphiphilic diblock copolymers are provided herein. Methods of making the aqueous injection fluids, and methods of using the aqueous injection fluids for oil recovery are also provided.

Abstract: Provided herein are compounds, compositions, and methods having application in the field of enhanced oil recovery (EOR). In particular, the short hydrophobe anionic surfactants as well as aqueous compositions comprising these surfactants are provided that can be used for the recovery of a large range of crude oil compositions from challenging reservoirs.

Abstract: Additional oil recovery is obtained from a reservoir with a composition comprising at least a coupling solvent typically employed in waterborne coating compositions. Provided herein are embodiments of methods of recovering hydrocarbons using at least one coupling solvent, such as an oxygenated coupling solvent. The coupling solvent increases the mutual solubility with water at the injection temperature to facilitate the mixing and injection, particularly with an optional co-solvent. The coupling solvent helps mitigate formation plugging and improve performance when injected into a formation, as the solvent mixture moves from being miscible in the injection field water to being miscible in the reservoir oil, mobilizing the reservoir oil to increase oil recovery.

Abstract: The present disclosure relates to a method for oil displacement using a dispersed particle gel-strengthened polymer ternary composite displacement system.

Abstract: The present disclosure provides compositions comprising anisotropic chain-like silica nanoparticles functionalized with hydrophilic groups. The anisotropic chain-like silica nanoparticles comprise linked arrays of charged silica nanoparticles, each linked array have at least one linear dimension of from about 100 nm to about 1200 nm and the anisotropic chain-like silica nanoparticles each in have a diameter of from about 10 nm to about 500 nm. These compositions are superoleophobic in the presence of water, e.g., when submerged in water. Also provided are layered coatings comprising these compositions, substrates comprising the layered coatings, articles comprising the layered coatings, methods of filtering a mixture of water and an oil using the compositions described herein, and methods of preparing a superoleophobic coating on a substrate using the compositions described herein.

Abstract: A well treatment fluid comprising an aqueous base fluid and a sugar-based surfactant is provided. The sugar-based surfactant includes at least one betaine functionalized alkyl polyglucoside. Also provided is a method of treating an oil and gas well.

Abstract: A method for developing a hydrocarbon reservoir by injecting a gas in the form of foam, comprising a step of determining a foam displacement model, which is a function of an optimal gas mobility reduction factor and of at least one water saturation-dependent interpolation function. The optimal gas mobility reduction factor is determined and constants of the water saturation-related interpolation function are calibrated from a plurality of apparent viscosity measurements for various foam quality values, and by use of a lamella model allowing which relates the lamella density as a function of the water saturation. The invention has an application to petroleum exploration and development.

Abstract: Methods and systems are provided for recovery of oil from a subterranean reservoir employing nanofluid injection at a controlled flow rate. The method comprises the step of injecting nanofluid through at least one well that traverses the subterranean reservoir and into the subterranean reservoir at a controlled flow rate. And, the system comprises: at least one well that traverses the subterranean reservoir; and injection means for injecting nanofluid through the well and into the subterranean reservoir at a controlled flow rate.

Abstract: Systems and methods for selecting surfactants for use in subterranean formations are provided. In one embodiment, the methods comprise: providing a sample of oil from at least a portion of a subterranean formation; measuring at least one of the total acid number (TAN) and the total base number (TBN) of the oil sample; and selecting a set of surfactants to evaluate for a treatment in at least a portion of the subterranean formation based on at least one of the TAN and the TBN of the oil sample, the set of surfactants selected from the group consisting of: a set of cationic surfactants, a set of anionic surfactants, and a set of zwitterionic surfactants.

Abstract: A coated proppant includes a solid core proppant particle and a heavy metal recovery coating, including heavy metal recovery crystals embedded within a polymer resin matrix. A process for the manufacture of a coated proppant includes providing a solid core proppant particle, and forming on the solid core proppant particle, a heavy metal recovery coating including heavy metal recovery crystals embedded within a polymer resin matrix.

Abstract: This invention relates to a surfactant composition, production and use thereof in tertiary oil recovery. The present surfactant composition comprises a cationic surfactant and an anionic-nonionic surfactant, and exhibits significantly improved interfacial activity and stability as compared with the prior art. With the present surfactant composition, a flooding fluid composition for tertiary oil recovery with improved oil displacement efficiency and oil washing capability as compared with the prior art could be produced.

Abstract: A composition and method for controlling heavy hydrocarbons in down-hole environments and with associated equipment used in oil and gas well operations. The composition and method comprising an ether and optionally an ester, an alkoxylated alcohol or a hydrocarbon co-solvent. The compositions and methods are useful in controlling heavy hydrocarbons such as paraffins and asphaltenes by dissolving paraffins, suspending paraffins and asphaltenes and dissolving heavy oils, both down-hole and with associated equipment.

Abstract: Water-in-oil lattices of water soluble or dispersible polymers and methods of using the same are presented. The lattices include phosphorus functional inversion agents that provide rapid and complete inversion of the lattices under conditions wherein the water source used to invert the latex is provided at high temperature, or includes a high level of total dissolved solids, or is both high temperature and high total dissolved solids.

Abstract: Provided here are compositions and improved methods for recovering portion of irreducible water saturation in a porous rock sample. Compositions used here contain a displacement fluid and a surfactant, and lead to an increased recovery of the irreducible water from the porous rock sample.

Abstract: An oil recovery composition of an aqueous solution of one or more salts and dilute polymer and processes for enhanced oil recovery using the oil recovery composition are provided. An oil recovery composition may include an aqueous solution of one or more salts having a salinity of about 5000 parts-per-million (ppm) to about 6000 ppm and a polymer having a concentration of 250 ppm to 500 ppm. The one or more salts may include sodium sulfate (Na2SO4). The polymer may include a copolymer of acrylamide and acrylamido tertiary butyl sulfonate (ATBS). The oil recovery compositions provided may be suited for enhancing oil recovery in carbonate reservoirs having in situ oil viscosities less than 3 centipoise (cP).

Abstract: An oil recovery composition of an aqueous solution of one or more salts and dilute polymer and processes for enhanced oil recovery using the oil recovery composition are provided. An oil recovery composition may include an aqueous solution of one or more salts having a salinity of about 5000 parts-per-million (ppm) to about 6000 ppm and a polymer having a concentration of 250 ppm to 500 ppm. The one or more salts may include sodium sulfate (Na2SO4). The polymer may include a copolymer of acrylamide and acrylamido tertiary butyl sulfonate (ATBS). The oil recovery compositions provided may be suited for enhancing oil recovery in carbonate reservoirs having in situ oil viscosities less than 3 centipoise (cP).

Abstract: The invention relates to the use of at least one compound corresponding to the formula below: R—O—(—CH2—CH(—CH3)—O—)m—(—CH2—CH2—O—)n—H in which: R is a hydrocarbon-based group comprising from 6 to 40 carbon atoms; m is a number ranging from 0 to 20; n is a number greater than 20; for inhibiting the anionic-surfactant retention phenomena in an oil reservoir, especially in a carbonate-based or argillaceous reservoir.

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: A sparingly soluble sulfonate-metal salt particle includes the metal ion salt of an alkyl aryl sulfonate, the metal ion salt of a petroleum sulfonate and a hydrophobically modified hydrophilic polymer, and has an average particle size diameter in a range of from about 50 nm to about 450 nm and is sparingly soluble in water at room temperature. A method of producing a sparingly soluble sulfonate-metal salt particle includes the steps of introducing an aqueous solution containing a metal ion salt into a reactor, introducing an aqueous solution containing a sulfonate surfactant and a polymer into the reactor, and operating the reactor such that the sparingly soluble sulfonate-metal salt particle forms from the interaction of the metal ion from the salt, the sulfonate surfactant and the polymer.

Abstract: A method for recovering hydrocarbons in a carbonate reservoir by introducing a saline solution injection containing a saline soluble surfactant and a saline soluble polymer. The method provides for increased hydrocarbon recovery as compared to conventional waterflooding techniques.

Abstract: The present invention relates to a method which allows quick and effective hydration of associative polymers, in particular those intended for use in the field of oil drilling. This method uses a specific solid formulation, which can be easily hydrated, including, in a pre-mixture, said associative polymers and surfactants capable of improving the hydration of these polymers.