Abstract: A ported tubular is provided for use in casing a wellbore, to permit selective access to the adjacent formation during completion operations. A system and method for completing a wellbore using the ported tubular are also provided. Ports within the wellbore casing may be opened, isolated, or otherwise accessed to deliver treatment to the formation through the ports.

Abstract: Systems and methods for creating and/or using multi-functional surfactant complexes that may enhance surfactant treatments in subterranean formations are provided. In some embodiments, the methods comprise: providing a treatment fluid comprising an aqueous base fluid and one or more multi-functional surfactant complexes that comprise at least one surfactant and at least one polymeric additive, wherein the surfactant and the polymeric additive carry opposite charges; and introducing the treatment fluid into a well bore at a well site penetrating at least a portion of a subterranean formation.

Abstract: Described herein are compositions for use in treating subterranean formations where the compositions include a water soluble polymer and an ionic surfactant. In preferred compositions, the polymer and surfactant are oppositely charged. Methods of using the compositions also are disclosed.

Abstract: An aqueous slurry composition for use in industries such as the petroleum and pipeline industries includes a particulate, an aqueous liquid and a chemical compound that renders the particulate surface extremely hydrophobic. The slurry is produced by rendering the surface of the particulate extremely hydrophobic during or before making the slurry.

Abstract: The present invention relates to the petroleum drilling field and discloses a reservoir protecting agent composition comprising a structured nanometer film reservoir protecting agent and a water block preventing agent, a drilling fluid containing the same and use thereof for drilling in low-permeability reservoirs. The reservoir protecting agent composition comprises a structured nanometer film reservoir protecting agent and a water block preventing agent, wherein the structured nanometer film reservoir protecting agent comprises montmorillonite laminas, structural units represented by formula (1) and structural units represented by formula (2), wherein each of R1, R2, R3, R4 and R5 is independently selected from H, C1-C4 alkyl and C1-C4 alkoxy, R6 is C1-C6 alkylene. The present invention further provides a drilling fluid that contains the reservoir protecting agent composition according to the present invention.

Abstract: Systems and methods of treating a zone of a subterranean formation penetrated by a wellbore are described. A composition may include a first solution including at least one amine containing resin; and citraconic anhydride. The composition may also include a second solution mixed with the first solution, where the second solution includes at least one epoxide containing resin. Methods may include providing the treatment fluid to a subterranean formation.

Abstract: A liquid treatment method includes mixing a liquid with an agent to form a mixture, aging the mixture to obtain to a predetermined condition in at least one of the liquid and the agent, and dispensing the aged mixture. An interaction between the liquid and the agent causes the predetermined condition to occur. Also, a majority of the aging occurs while the mixture is in a dynamic state. A related system includes a mixer receiving a liquid and a drag reducing agent and an aging module connected to the mixer. The mixer disperses the drag reducing agent in the liquid to form a mixture and the aging module has a flow path along which the mixture flows. The flow path has a distance sufficient for a majority of the aging to occur while the mixture is in a dynamic state, wherein the aging changes the drag reducing agent to a predetermined condition.

Abstract: A method of completing a well includes, pumping treating fluid into a tool string in the well, displacing drilling mud within the tool string with the treating fluid, and treating an earth formation with the treating fluid.

Abstract: The present invention relates to a polymer including at least one monomer comprising a switchable-amphiphilic functional group. Various embodiments provide a methods of treating a subterranean formation with the polymer, compositions including the polymer, and methods of making compositions including the polymer.

Abstract: Air and ammonia gas are introduced into a subterranean formation during the in-situ combustion to increase the mobility of hydrocarbons in a subterranean formation and facilitate recovery of the hydrocarbons from the subterranean formation. The air supports in-situ combustion of a portion of the hydrocarbon within the subterranean formation to form water and establish a combustion front. The ammonia gas contacts the hydrocarbons ahead of the combustion front and reacts in-situ with naphthenic acid in the hydrocarbon to form a surfactant. The hydrocarbons, water and surfactant then form an oil-in-water emulsion that drains more freely through the formation. A production well, in fluid communication with the hydrocarbons ahead of the combustion front, may be used to remove the oil-in-water emulsion from the subterranean formation.

Abstract: The present disclosure relates generally to devices and methods useable during well drilling operation. More particularly, the present disclosure pertains to a drilling rig incorporating a dual top drive apparatus useable for decreasing connection time of pipe segments useable during well drilling or other well operations, and methods of connecting pipe segments useable during well drilling or other operations.

Abstract: The invention relates to the storage of contaminated material under a water layer, in particular the storage of bottom ash. The invention provides for this purpose a method for storing a contaminated material under a water layer, comprising the processing steps of supplying the contaminated material, supplying ground material, mixing the contaminated material with the ground material and arranging the mixture of contaminated material and ground material in or under a retention layer situated under a water layer, and wherein the mixture is not in contact with the water layer, and the retention layer comprises ground material. The invention also provides an installation for storing contaminated material and a composition comprising the contaminated material.

Abstract: A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising an amino multicarboxylic acid chelating agent, a pH adjusting compound, and an aqueous base fluid, and contacting the wellbore servicing fluid with scale deposits on a surface in fluid communication with the wellbore and/or subterranean formation.

Abstract: Enhanced oil recovery becomes increasingly important in satisfying the growing demand for fossil fuel. The efficiency of secondary recovery processes like water flooding is however largely influenced by the rock characteristics, fluid characteristics, chemistry and physics. For development of the full potential of secondary oil recovery, it remains a challenge to obtain sufficient knowledge about the reservoir conditions. The present invention provides a novel water-dispersed, nano-sensor composition based on. InP/ZnS quantum dots (“QDs”) and atomic silver clusters, which exhibit a bright visible fluorescence combined with dedicated sensor functionalities. The QD and silver nano-sensors were tested in simulated reservoir conditions to determine their selected functionality to these reservoir conditions. The developed nano-sensors showed improved sensor functionalities towards pH, temperature, and subterranean reservoir rock, such, as clay or limestone.

Abstract: Downhole nuclear magnetic resonance (NMR) methods that utilize oleophilic nanoparticle may allow for differentiation of light oil and oil-based filtrates. For example, a method may involve drilling a wellbore penetrating a subterranean formation using an oil-based drilling fluid that comprises an oil base fluid and a plurality of oleophilic nanoparticles; performing a plurality of NMR measurements at a plurality of depths of investigation (DOI) of a near-wellbore portion of the subterranean formation; and producing an invasion profile of an oil-based drilling fluid filtrate into the near-wellbore portion of the subterranean formation based on the plurality of NMR measurements.

Abstract: Gelled barrier fluids preventing the ingress of undesired fluids from subsurface environments into subsurface apparatus have a specific gravity which is within ±0.05 of the specific gravity of the undesired fluid.

Abstract: Compaction aid compositions and methods for compacting soils, sands, and other aggregates are described herein. In particular, the compaction aid compositions can comprise at least one synthetic fluid that was previously derived from a Gas-to-Liquids process. The compactions aids can be used to efficiently and effectively compact various soils, sands, and other aggregates at temperatures below the freezing point of water, thereby making such compaction aids highly useful in arctic and subarctic environments.

Abstract: A method and system for removing solids or displacing a fluid from a wellbore wherein a plurality of resilient rubber-like flexible reticulated open cell foam elements are dispersed in a fluid and pumped through drill pipe and into the annulus between the wellbore and the drill pipe. In the annulus, the foam elements impact and dislodge solids such as proppants, gravels, drilled cuttings and other solids or a fluid to be displaced and the proppants, etc. or the fluid are carried by the fluid containing the foam elements back to the surface or a different location in the wellbore. At the surface, the fluid containing the foam elements and the proppants, etc., is carried to a shale shaker where the solids and the foam elements are separated from the fluid. The separated solids and foam are collected for disposal and, after adding new foam elements, the fluid can be recirculated down hole.

Abstract: A wellbore treatment apparatus includes: a tubing string including a wall defining an inner diameter and a port extending through the wall, the port closed by a closure including a plug-actuated sliding sleeve; and a port opening apparatus including a wireline deployable through the inner diameter of the tubing string to extend to a position adjacent the plug-actuated sliding sleeve and an actuator plug carried on and axially slideable along the wireline, the actuator plug sized to land in the plug-actuated sliding sleeve to actuate the plug-actuated sliding sleeve, while remaining on the wireline. The apparatus can be employed in a method by running the tubing string into a well, placing the slickline in the string and running the actuator plug along the wireline to land on and actuate a sleeve in the string.

Abstract: A frac sleeve system includes an outer sleeve with openings, an inner sleeve with ports, a pressure seat, a bottom locking device and a spring device. In a closed configuration of the inner sleeve, the openings and ports are not aligned for any fluid connection. In an opened configuration, at least one opening is aligned with at least one port for a fluid connection through the system. The inner sleeve shifts back and forth between configurations according to the pressure seat and the spring. The interaction of a guide pin on the outer sleeve and the guide slot on the inner sleeve controls the rotational and longitudinal movement of the inner sleeve along the common axis of the inner sleeve and outer sleeve so that there is unlimited shifting between configurations. The locking devices and spring device are also reuseable for the multiple shifting.

Abstract: A fracture plug seat assembly used in well stimulation for engaging and creating a seal when a plug, such as a ball, is dropped into a wellbore and landed on the fracture plug seat assembly for isolating fracture zones in a well. The fracture plug seat assembly has a fracture plug seat that includes elastomeric material and reinforcing material.

Abstract: A composition and method for performing a treatment of a subterranean formation. The composition includes an emulsified acid and a sulfobetaine surfactant. The emulsified acid and the sulfobetaine surfactant may be mixed to form a treatment composition, which may be injected into a subterranean formation as part of an acid fracturing or hydraulic fracturing treatment.

Abstract: Methods and apparatus for sealing a well are disclosed. The method includes introducing a plug axially into the well, with a mouth of the plug turned up and a bottom wall part turned down, the plug being positioned in the well at a desired depth. The plug is inflated by injecting a high-pressure liquid into it via its mouth so that a tubular wall part of the plug expands radially beyond its elastic limit and presses firmly and tightly against the wall of the well by a crimping effect, while its bottom wall part serves as a sealing partition, forming a tight barrier between lower and upper parts of the well that it separates. The plug has an internal axial mandrel that connects its mouth to its bottom wall, the mandrel being pierced with channels that allow injection of high-pressure liquid inside the plug via the mouth and channels.

Abstract: A tool assembly including an equalization valve allowing for continuous equalization of pressure above and below a sealing element includes a housing having a fluid passageway that is fluidically continuous across a sealing element disposed on a mandrel. The mandrel is part of a sealing assembly that contains the sealing element. The equalization valve includes a valve plug moveable from an open to a seated position wherein the valve plug is seated against the sealing mandrel. The valve plug defines a conduit that provides minimal fluid flow across the sealing element when the valve plug is seated against the sealing mandrel. The equalization valve further includes an outer port for permitting lateral flow of fluid from the tubing string to the annulus defined between the tubing string and the wellbore. The equalization valve may be part of a downhole tool assembly which includes the equalization valve and a sealing assembly.

Abstract: A well may be serviced with a fluid formulated with components comprising a friction reducer having at least one polymer unit chosen from acrylamide groups, acrylate groups, sulfo groups, and maleic acid groups; and an anionic surfactant, a cationic surfactant and an aqueous base capable of forming a viscoelastic gel.

Abstract: A method for stabilizing a carbonylation catalyst with carbon monoxide recovered from a gaseous stream derived from a carbonylation reaction. The carbon monoxide enriched stream is fed downstream of the carbonylation reactor, preferably to a flasher or light ends column, to enhance catalyst stability throughout the process.

Abstract: A wellbore servicing system comprising a casing string disposed within a wellbore, a work string at least partially disposed within the casing string and having a wellbore servicing tool incorporated therein, wherein the wellbore servicing tool is selectively transitionable between a jetting configuration and a mixing configuration, wherein the wellbore servicing tool is configured to transition between the jetting configuration and the mixing configuration via contact between the wellbore servicing tool and the casing upon movement of the work string upwardly within the casing string, upon movement of the work string downwardly within the casing string, or by combinations thereof.

Abstract: A method of obtaining a hydrocarbon material from a subterranean formation comprises forming a flooding suspension comprising degradable particles and a carrier fluid. The flooding suspension is introduced into a subterranean formation containing a hydrocarbon material to form an emulsion stabilized by the degradable particles and remove the emulsion from the subterranean formation. At least a portion of the degradable particles are degraded to destabilize the emulsion. An additional method of obtaining a hydrocarbon material from a subterranean formation, and a stabilized emulsion are also described.

Abstract: Disclosed herein is a gel comprising, polyacrylamide crosslinked with a non-metallic crosslinker, the non-metallic crosslinker comprising a polyamine. A method of making the gel and a method of using the gel are also disclosed.

Abstract: A method of predictive modeling of a treatment fluid comprises: determining the value of properties of a base fluid and insoluble particulates; providing a proposed suspending agent; performing a first calculation of the suspendability of the proposed suspending agent as determined by a yield gravity function equation; evaluating if the result from the first calculation indicates a stable treatment fluid comprising the base fluid, the insoluble particulates, and the proposed suspending agent, or if the result does not indicate a stable treatment fluid, then: modifying the value of at least one of the properties of the proposed suspending agent, base fluid, and/or insoluble particulate; and performing a second calculation, wherein the same or different property values are continued to be modified and the calculation is continued to be performed until the result indicates a stable treatment fluid; and introducing the stable treatment fluid into a wellbore.

Abstract: A method of servicing a wellbore that includes, transporting a fluid treatment system to a wellsite, accessing a water source proximate to the wellsite, introducing a water stream from the water source into the fluid treatment system, irradiating at least a portion of the water stream within the fluid treatment system, forming a wellbore servicing fluid from the irradiated water stream, and placing the wellbore servicing fluid into the wellbore. The portion of the water stream is irradiating by exposing the portion of water stream to ultraviolet light emitted from at least one pulsed ultraviolet lamp.

Abstract: A fluid separator separates a fluid flow into a plurality of fluid portions, and delivers at least a first fluid portion of the plurality of fluids to a flow conduit. An imaging-based measurement device includes a light source and an image sensor. The imaging-based measurement device measures the first fluid portion in the flow conduit. An imaging processor in the imaging-based measurement device processes the measurement data to determine a characteristic of the first fluid portion.

Abstract: Methods for treating oil-based drilling fluids with a fluid loss additive that includes one or more hydrocarbon resins. An oil-based drilling fluid and a hydrocarbon resin can be combined to produce a treated oil-based drilling fluid. The hydrocarbon resin can include a polymerized product of a reaction mixture that can include a dicyclopentadiene; at least one member selected from the group consisting of: a dimer of an aliphatic cyclic diene having five carbon atoms, a dimer of an aliphatic non-cyclic diene having five carbon atoms, a monoolefin, a diolefin, or a polyene, each having more than five carbon atoms and no aromatic rings, a C5-olefin, a debutanized aromatic concentrate, and any mixture thereof; and at least one member selected from the group consisting of: a fatty acid-containing material, a rosin acid-containing material, and a mixture thereof.

Abstract: Fluid treatment systems and compositions are provided including (a) at least one material including (1) at least one carboxylic acid functional group and (2) at least one sulfur-containing group selected from the group consisting of sulfonyl functional groups, sulfonate functional groups and mixtures thereof; and (b) at least one friction reducing agent selected from the group consisting of guar gums, polyacrylamides, hydratable cellulosic materials, viscoelastic surfactants, and mixtures thereof. The fluid treatment systems and compositions can be used to treat aqueous systems, for example as fracturing fluids for use in fracturing subterranean formations. Methods for inhibiting formation and/or precipitation of metal oxides in an aqueous composition using the fluid treatment systems or compositions also are provided.

Abstract: A method for determining wettability of a solid, such as a reservoir rock material includes disaggregating the material, for example by grinding and placing the disaggregated material on the surface of the fluid. The wettability is analyzed based on whether a portion of the material floats on or sinks into the fluid. The method is well suited for heterogeneous solid materials that have mixed wetting characteristics and/or have varying surface types. The fluid can be evaluated as a potential treatment fluid or a component thereof that can be used for treating the rock formation. For example, the potential treatment fluid can include a surfactant or an oxidizing agent. A simple observation can be made whether substantially all of the material placed on the surface of the fluid sinks into the fluid, or the portions of floating and sinking material can be weighed.

Abstract: The present disclosure provides a surfactant formulation for use in treating and recovering fossil fluid from a subterranean formation. The surfactant formulation includes a primary surfactant, a formulation stability agent and injection water.

Abstract: The invention relates to a method of treating a hydrocarbon containing formation, comprising the following steps: a) preparing an internal olefin sulfonate, comprising sulfonating an internal olefin into sulfonated internal olefin followed by contacting sulfonated internal olefin with a base containing solution resulting in the internal olefin sulfonate, wherein sulfonated internal olefin is contacted with the base containing solution in the presence of a non-ionic surfactant, and/or after step a) but before step b), the internal olefin sulfonate and said non-ionic surfactant are combined; b) transporting an aqueous solution comprising the internal olefin sulfonate and the non-ionic surfactant to the location of the hydrocarbon containing formation; c) providing the internal olefin sulfonate and the non-ionic surfactant to at least a portion of the hydrocarbon containing formation; and d) allowing the internal olefin sulfonate and the non-ionic surfactant to interact with the hydrocarbons in the hydrocarbon c

Abstract: A method of plugging an opening in a subterranean formation such as a fracture system is provided. A gel composition can be provided which includes an aqueous fluid, a cross-linkable polymer soluble in the aqueous fluid and a cross-linking agent. Inorganic fibers can be added to the gel composition. The gel composition can be injected into the opening in the subterranean formation. The gel composition can be cross-linked, and the opening can be plugged with the gel composition. In certain illustrative embodiments, the inorganic fibers can be mineral wool fibers.

Abstract: An aqueous fluid, possibly a wellbore fracturing fluid, comprises an aqueous solution or dispersion of a first polymer, which may be polysaccharide, as a thickener and a cross linking agent to enhance the viscosity of the fluid by crosslinking the first polymer, wherein the crosslinking agent is a second polymer comprising at least one polymer chain with phenyl boronate groups distributed along the polymer chain and the phenyl boronic acid groups have nitrogen attached to the phenyl group at a position which is meta relative to the boronate group.

Abstract: Produced or flowback water from an underground reservoir having been treated with a fluid containing a viscosifying polymer and a vitamin B1 and/or ylide breaker may be recycled by deactivating the vitamin B1 and/or ylide breaker with a sulfur or phosphorus containing nucleophilic agent.

Abstract: Methods of processing a fluid recovered from an oil or gas extraction operation for reuse in a hydraulic fracturing fluid are described. The methods include providing an amount of a produced fluid composition containing iron and suspended solids and controlling at least one of the conductivity, iron content, oxidative strength, and pH of the composition, such that Fenton's reagent is formed in situ. Also described are hydraulic fracturing fluids produced using fluid recovered from an oil or gas production process and treated in accordance with the methods described herein as well as systems for preparing a hydraulic fracturing fluid having, as a fluid source, fluid recovered from an oil or gas production process that has been treated in accordance with the methods described herein.

Abstract: Crosslinked gelling agents employed during subterranean operations use electronically-modified boronic acids to enable higher operating temperatures while allowing reduced gelling agent loadings; the boronic acids having Formula I: X1 and X2 are independently selected from O, CH2, CH2O, OCH2, bond, and null, Y1 and Y2 are independently N or C, Ar is a 5- or 6-membered ring aryl or heteroaryl group with a link L to monomer unit M1, m is 1 or 2, n is 0, 1, 2, or 3, and each Z is independently an electron withdrawing group selected from nitro, ester, carboxylic acids, carboxylates, halogen, cyano, amide, acyl, alkylsulfonyl, arylsulfonyl, heteroarylsulfonyl, CF3, a quaternary ammonium salt, polyhaloalkyl, and carbamate, with the proviso that when n is 0, the link L between M1 and Ar includes an electron withdrawing group attached to Ar, and introducing the treatment fluids into subterranean formations.

Abstract: A wastewater concentrator a liquid evaporator assembly, a gas-liquid separator, an exhaust assembly, and a flowback water concentrating system. The flowback water concentrating system includes a settling tank fluidly connected to the gas-liquid separator and a supernatant liquid concentration sensor for measuring a concentration of dissolved solids in the supernatant liquid in the settling tank.

Abstract: Embodiments disclosed herein include methods comprising providing a consolidation composition comprising the reaction product of a liquid curable resin and a liquid curing agent, wherein the liquid curable resin is an epoxy-functionalized alkoxysilane and wherein the liquid curing agent is selected from the group consisting of: a polyamine; a hydrophobically modified polyamine; a polyimine; a hydrophobically modified polyimine; a polyalcohol; hydrophobically modified polyacrylamide; a hydrophobically modified polyacrylate; and any combination thereof; coating proppant particulates with the consolidation composition, thereby creating coated proppant particulates; introducing the coated proppant particulates into a subterranean formation and placing the coated proppant particulates into a fracture therein; and curing the consolidation composition so as to consolidate the coated proppant particulates in the fracture and form a proppant pack therein.

Abstract: A method for treating a subterranean formation, including estimating the solubility parameter of a monomer; selecting a solvent based on the parameter; forming a fluid comprising the monomer and solvent; and introducing the fluid to the formation, wherein the formation is about 350° F. or warmer. A method for treating a subterranean formation, including forming a fluid comprising the monomer and solvent, wherein the monomer comprises poly(2-hydroxyethyl methacrylate) and/or poly(2-hydroxyethyl acrylate, and wherein the solvent comprises zinc bromide or calcium bromide or both; and introducing the fluid to the formation, wherein the formation is about 350° F. or warmer.

Abstract: Methods and apparatus for enhanced and improved viscous oil recovery are disclosed. A horizontal well is drilled through the viscous oil formation. A specially designed tubing string includes outlets that deliver steam more uniformly into the entire horizontal extent of the well borehole. Heat from the steam mobilizes and lowers the viscosity of the heavy crude wherein the crude is then produced to the surface via conventional lift arrangements.

Abstract: Apparatus, methods and systems for preparing a polymer concentrate for treating a formation with slick water systems viscous fluid or a gelled viscous fluid are disclosed. The method includes directing a powdered gel into a vortex mixing chamber, while directing a first portion of a base fluid into the vortex mixing chamber to form partially hydrated fluid concentrate. The partially hydrated fluid concentrate is then sucked or sweep into a main portion of base fluid for form the slick water systems viscous fluid or gelled viscous fluid.

Abstract: A method includes introducing a treatment fluid including a first polymer gel into a subterranean formation to generate a production fluid having an aqueous portion and a hydrocarbon portion, treating the aqueous portion of the production fluid with chlorine dioxide to separate additional hydrocarbons from the aqueous portion, and adjusting the viscosity of the treated aqueous portion prior to introducing the treated aqueous portion back into the subterranean formation.

Abstract: Aqueous compositions contain hydrochloric acid at a concentration between 8 wt % and 28 wt % inclusive. The amino acid; hydrochloric acid mole ratio may be between 0.2 and 1.5. Sufficient water is present to dissolve the hydrochloric acid and the amino acid. Such compositions have utility as retarders for acid compositions employed in the stimulation of subterranean formations. Slowing the reaction between the acid and formation helps maximize formation permeability and productivity.

Abstract: Fluids including a parylene-coated chemical entity and methods of treating a subterranean formation with such fluids are disclosed. The methods may include introducing a treatment fluid into a subterranean formation, the treatment fluid containing a parylene-coated particle having a chemical entity encapsulated therein.