Abstract: A safety valve for an effluent-production installation, the safety valve comprising a longitudinal shell in which there extends a production tube defining an inside volume for effluent flow. The tube is movable in translation inside the shell in an axial direction between an advanced position in which effluent flow is authorized from the bottom of the installation towards the surface, and a retracted position in which effluent flow is prevented. The valve includes a connection duct between a feed line for feeding at least one additive from the surface and an injection line for injecting the additive downhole, a safety plug being provided in the connection duct in order to close or open the duct depending on whether the production tube is in its retracted position or its advanced position.

Abstract: Treatments and compounds for use in subterranean formations where surfaces may be subject to silica scale build-up. Certain embodiments pertain to utilizing silica scale control additives with remediation and stimulation treatments. One example of a suitable method of treatment includes providing an acidic treatment fluid comprising: a base fluid, an acid, and a silica scale control additive; contacting at least a portion of a subterranean formation with the acidic treatment fluid; and allowing the acidic treatment fluid to interact with silica scale buildup in the subterranean formation so that at least a portion of the silica scale buildup is removed.

Abstract: Provided herein are, inter alia, heavy crude oil emulsion compositions and methods of making the same. The compositions and methods provided herein are particularly useful for the transport of heavy crude oils.

Abstract: Provided herein, inter alia, are methods and compositions useful for heavy crude oil recovery. The emulsion compositions and non-surfactant aqueous compositions provided herein may be particularly useful for the recovery of heavy crude oils under a broad range of reservoir conditions (e.g. high to low temperatures, high to low salinity, highly viscous oils).

Abstract: Apparatus and method are provided to restore contaminated groundwater based on in-situ periodic pumping and recharging. The apparatus includes a contaminated groundwater suction system, an in-situ restoration system, and a reinjection system. The suction system includes a suction well and a suction pipeline. The suction system is connected with the in-situ restoration system. The in-situ restoration system is connected with the reinjection system. The reinjection system includes a reinjection pipeline and a reinjection well. Prior to the in-situ restoration, a pumping test for suction well and an injection test for reinjection well are conducted. Through reinjecting the processed contaminated groundwater, this approach is capable of diluting contaminated water layer, reducing the pollutant concentration in the target aquifer, providing convenience for the subsequent processing, and cutting the cost.

Abstract: A sand control device is used for restricting the flow of particles from a subsurface formation into a tubular body within a wellbore during production operations. The sand control device is divided into compartments along its length that provide redundancy for particle filtration. Each compartment first comprises a base pipe. The base pipe defines an elongated tubular body having a permeable section and an impermeable section within each compartment. Each compartment also comprises a first filtering conduit and a second filtering conduit. The filtering conduits comprise filtering media and generally circumscribe the base pipe. The filtering conduits are arranged so that the first filtering conduit is adjacent to the non-permeable section of the base pipe, while the second filtering conduit is adjacent to the permeable section of the base pipe.

Abstract: A method of treating a wellbore servicing fluid includes disposing an ultraviolet treatment chamber in fluid communication with an inlet of a pump, operating the pump, and drawing a wellbore servicing fluid through the ultraviolet treatment chamber in response to operating the pump. A wellbore servicing fluid treatment system has a first ultraviolet treatment chamber and a first pump in selective fluid communication with the first ultraviolet treatment chamber. The pump is downstream relative to the first ultraviolet treatment chamber and the pump is configured to selectively draw a wellbore servicing fluid through the first ultraviolet treatment chamber. A method of servicing a wellbore includes connecting an ultraviolet fluid treatment system to a blender, operating a pump of the blender, drawing a wellbore servicing fluid through the ultraviolet treatment system in response to operating the pump of the blender, and delivering the wellbore servicing fluid into the wellbore.

Abstract: The current invention relates to the use of chitin nanocrystals and chitin nanocrystal derivatives. More specifically, the present invention relates to the use of chitin nanocrystals and chitin nanocrystals used in oil and gas operations. The chitin nanocrystals and chitin nanocrystals derivatives can be used as additives to cement and wellbore fluids and can be used to inhibit corrosion in pipelines, on downhole tools and on other oil and gas related equipment.

Abstract: Disclosed herein is a fluid flow improver comprising a branched dendritic core comprising a first quaternary carbon center bonded to four second carbon atoms, wherein at least three of the four second carbon atoms are individually bonded to one or more chain extender ligands to produce the branched dendritic core, wherein the branched dendritic core has greater than or equal to about 16 terminal hydroxyl groups, and wherein at least one of the terminal hydroxyl groups is esterified with at least one carboxylic acid moiety comprising from 6 to 30 carbon atoms. Methods of inhibiting deposition of paraffin and reducing pour point temperature of a hydrocarbon fluid are also disclosed.

Abstract: A method for reducing corrosion on the exterior or interior surface, for example coiled tubing and casing, is disclosed. The method includes mixing a selected surfactant and particles of a polymer in oil, then adding the oil to water and contacting the surfaces of the tubing with the mixture.

Abstract: A process for the enhanced recovery of oil in a deposit introduces into the deposit an alkaline aqueous solution of a water-soluble polymer containing a surfactant. The aqueous solution of water-soluble polymer introduced is prepared with an aqueous solution initially containing Ca2+ and Mg2+ ions treated with an alkaline agent and a dispersant, so as, prior to the introduction of the polymer and the surfactant into the aqueous solution, to precipitate, under the action of the alkaline agent and of CO2 optionally dissolved in the aqueous solution, the Ca2+ and Mg2+ ions. The precipitates are especially in the form of precipitates of calcium carbonate and of magnesium hydroxide and are dispersed owing to the dispersant, which is chosen in order to limit the size of the calcium carbonate and magnesium hydroxide precipitates.

Abstract: The present invention provides a valve and method for injecting a treatment fluid into a production zone of a hydrocarbon production well.

Abstract: A method of foaming a fluid for recovering gas from a gas well and enhancing oil production from a gas-lifted oil well penetrating a subterranean oil-bearing formation is disclosed and claimed. The method includes introducing into the fluid a foam-forming amount of a composition comprising at least one compound having the general formula: R1 is selected from a saturated linear or branched alkyl, an unsaturated linear or branched alkyl, a substituted naphthalene, a substituted benzene, a natural oil, and a natural oil derivative. R2 is a C2-C8 alkyl. R3, R4, and R5 are independently selected from trimethyl, triethyl, diethyl, monoethyl, benzyl dimethyl, and benzyl diethyl. X is selected from hydrogen, methyl, and ethyl. Z? is a negatively charged counterion.

Abstract: An oil well includes a wellbore (2), below ground level (4), which extends to an oil reservoir (6). The wellbore includes a casing (8) within which is arranged a progressing cavity pump (PCP) 10 which includes an inlet (12) at its lower end and is connected at its upper end to production tube (14). An annulus (16) is defined between the pump (10)/tube (14) and the casing (8). The annulus communicates with the reservoir and includes a head (20) of reservoir fluid. A water based formulation which comprises an optionally cross-linked polyvinylalcohol can be poured down the annulus (16) and pass under gravity to the reservoir (6), immediately upstream of inlet (12). The formulation may improve the performance and efficiency of the pump (10) due to its ability to increase the mobility of the oil in the reservoir immediately upstream of the pump (10) and/or enhance the ability of the oil to enter the pump inlet.

Abstract: Organo clay and activated carbon are mixed to form a particle mixture. The particle mixture is contacted with waste water having chlorides and other contaminants, such as organic materials, heavy metals, chlorides, and low level radio nuclei in solution. Acids, oxidizing chemicals, and compressed air are added to pretreat and to treat the waste water. The mixture is filtered with catalytic activated carbon filters to remove the remaining contaminants. The filters produce a clean chloride solution that is discharged or is subjected to a finishing process to produce a marketable chloride product.

Abstract: This invention relates to compositions and methods of removing an organic deposit including introducing a fluid, wherein the fluid comprises at least two non-polar organic solvents and at least two polar organic solvents; allowing the fluid to dissolve at least a portion of the organic deposit; and removing at least a portion of the fluid. This invention relates to compositions and methods of removing an organic deposit including introducing a fluid, wherein the fluid comprises at least two non-polar organic solvents and at least two polar organic solvents, wherein the non-polar organic solvents comprise aromatic naphtha, terpenes, kerosene, and combination thereof, and wherein the polar solvents comprise heavy aromatic naphtha, cyclohexanone, N-2-methyl pyrrolidone, N-ethyl-2-pyrrolidone, and combination thereof, allowing the fluid to dissolve at least a portion of the organic deposit, and removing at least a portion of the fluid.

Abstract: A method of rapidly and essentially simultaneously creating and feeding a dispersion into a hydrocarbon process stream. This method allows for the effective use of chemical additives in a hydrocarbon process line that are highly unstable or that are very difficult to disperse. This is especially helpful in hydrofracturing operations as the very rapid flow rates require very fast dispersion formations. As a result the method allows greater fracking pressures which can be obtained with lower energy inputs and by using lessor amounts of chemical additives. As a result hydrocarbon extraction can be accomplished in a manner which is both more environmentally friendly as well as less expensive.

Abstract: Method of improving performance or efficiency of a wellbore pump associated with a wellbore and/or for increasing the rate of production of reservoir fluid from a reservoir, in which a wellbore pump is arranged to pump wellbore fluid within the wellbore to a surface. The method includes (a) selecting a wellbore which includes an associated wellbore pump associated with a production tube and arranged within a casing. An annulus is defined between the casing and the pump/production tube, the annulus including reservoir fluid which has a hydrostatic head which is at least 15 m above the level of an inlet of the wellbore pump, and (b) contacting a reservoir fluid in the annulus upstream of an inlet of the wellbore pump with a treatment formulation. The treatment formulation has a first polymeric material which includes —O— moieties pendent from a polymeric backbone thereof, and the first polymeric material is optionally cross-linked.

Abstract: A method of servicing a wellbore in a subterranean formation comprising placing a wellbore servicing fluid comprising a lost-circulation composite material into a wellbore, wherein the lost-circulation composite material comprises a swellable component and a reinforcing component. A wellbore servicing fluid comprising a reinforcing component disposed within a swellable component wherein the swellable component comprises a crosslinked polymer.

Abstract: Viscoelastic surfactant (VES) gelled aqueous fluids containing water, a VES in an amount effective to increase the viscosity of the water, and an internal breaker may be useful in removing a residual polymer from a hydraulic fracture. Optionally, a pseudo-crosslinker may be present to further improve the properties related to treatment fluid placement and polymer clean-up. A plurality of aliquots of VES gelled fluid may be injected into a subterranean formation. A stop-start interval may exist between the injection of each aliquot. The VES gelled fluid may contact at least some of the residual polymer in the hydraulic fracture, and a broken fluid is formed once the viscosity of the VES gelled fluid is reduced with the internal breaker. At least a portion of the residual polymer and a majority of the broken fluid may be removed.

Abstract: Insensitive explosive compositions were prepared by reacting di-isocyanate and/or poly-isocyanate monomers with an explosive diamine monomer. Prior to a final cure, the compositions are extrudable. The di-isocyanate monomers tend to produce tough, rubbery materials while polyfunctional monomers (i.e. having more than two isocyanate groups) tend to form rigid products. The extrudable form of the composition may be used in a variety of applications including rock fracturing.

Abstract: Novel catalysts comprising nickel oxide nanoparticles supported on alumina nanoparticles, methods of their manufacture, heavy oil compositions contacted by these nanocatalysts and methods of their use are disclosed. The novel nanocatalysts are useful, inter alia, in the upgrading of heavy oil fractions or as aids in oil recovery from well reservoirs or downstream processing.

Abstract: A downhole assembly for delivering chemical treatment to a wellbore at the level of a hydrocarbon-bearing formation is provided. The chemical treatment is in solid phase, and slowly dissolves when exposed to wellbore fluids. A method of treating a wellbore using a solid chemical is also provided.

Abstract: The present invention relates generally to in situ hydrate control during hydrocarbon production when applying a recovery method utilizing cyclic injection of light hydrocarbon solvents. Hydrate formation is limited by creating an energy reserve within a hydrocarbon reservoir adjacent to the wellbore. A heated solvent is injected during an injection phase of a cyclic solvent dominated recovery process to form a heated region adjacent to the wellbore at the end of an injection cycle. The energy reserve is used to act against the evaporative cooling effect caused by subsequent production and associated depressurization to maintain reservoir conditions outside of hydrate formation conditions. In situ conditions are estimated and injected energy amounts are controlled.

Abstract: A method and apparatus for hydrocarbon recovery and/or treatment of frac water includes introducing a volume of water into a formation, recovering the introduced water, with the recovered introduced water further comprising suspended hydrocarbon product. The recovered liquid is treated to remove substantial amounts of the suspended hydrocarbon product, provide the treated recovered liquid with a ORP in a range of 150 mv to 1000 mv, and partially desalinated, and is either re-introduced as treated recovered liquid with the ORP into a formation to assist in recovery of additional hydrocarbon deposits in the formation, or is stored to reduce the ORP and then subsequently discharged into surface waters.

Abstract: Nanoparticle-treated substrates, such as screens, sand beds or proppant beds, may effectively filter and purify fluids such as waste water or fluids produced from a formation, as well as other liquids. When tiny contaminant particles in a fluid such as waste water flow contact the nanoparticle-treated substrate, the nanoparticles will capture and hold the tiny contaminant particles on the substrate due to the nanoparticles' surface forces, including, but not necessarily limited to van der Waals and electrostatic forces or other associative forces. Coating agents such as alcohols, glycols, polyols, vegetable oil, and mineral oils may help apply the nanoparticles to the surfaces of structures in the filter beds or packs.

Abstract: Oil sands and like host materials are leached with a selected leachant to render pumpable the oil (including heavy oil, bitumen or kerogen and asphaltenes) as leachate. In a preferred embodiment, natural deposits are in situ leached and the leachate recovered and removed for treatment. The leachant is separated and recycled. The leachant is selected to be biodegradable and to not precipate asphaltenes, and to comprise monoterpenes of the formula C10H16. The overall process allows environmentally acceptable resource development and contaminated site remediation.

Abstract: A process for increasing, on an existing installation, the amount of water-soluble polymer in an emulsion injected into pipelines transporting oil produced at offshore oil wells, includes before injection, diluting the emulsion with fuel oil found on the platform or Floating Production Storage & Offloading unit (FPSO).

Abstract: An automatically controlled methanol injection system for oil and gas production streams including an electric methanol injection pump and a temperature sensor and switch, the sensor and switch adapted to automatically adjust the injection of methanol as a function of sensed temperature.

Abstract: A method comprising mixing a wellbore servicing composition comprising Micro-Electro-Mechanical System (MEMS) sensors in surface wellbore operating equipment at the surface of a wellsite. An interrogator retrieves data regarding a parameter sensed by the MEMS sensor.

Abstract: Novel aminoacid alkylphosphonic acid compounds are disclosed. These compounds can be used in multiple applications, in particular in a scale inhibitor functionality in aqueous systems, including in marine oil recovery.

Abstract: An apparatus for controlling a flow of a fluid between a wellbore tubular having an opening and a formation includes a particulate control device and a flow control device positioned adjacent to the particulate control device. A flow path is formed between the opening of the wellbore tubular and the formation and that is internal to the particulate control device and the flow control device. The apparatus may include an additive supply line having an outlet positioned to dispense at least one additive into the flow path. A related method for controlling a flow of a fluid between a wellbore tubular having an opening and a formation may include positioning a flow control device adjacent to a particulate control device in the wellbore and dispensing at least one additive into a flow path internal to the particulate control device and the flow control device.

Abstract: Methods and apparatus for downhole extraction and analysis of heavy oil are disclosed. An example method includes lowering a viscosity of formation fluid in a subterranean formation and flowing the formation fluid from the subterranean formation into a downhole tool. The example method also includes controlling the viscosity of at least a portion of the formation fluid in the downhole tool.

Abstract: A method of treating a portion of a well of a well is provided. The method includes the step of forming a treatment fluid comprising: (i) a continuous aqueous phase; (ii) a viscosity-increasing agent selected from the group consisting of diutan, clarified diutan, water-soluble derivative of diutan, and any combination thereof, wherein the viscosity-increasing agent is dissolved in the aqueous phase; and (iii) a breaker comprising oxalic acid, wherein the oxalic acid is dissolved in the aqueous phase. The viscosity of the treatment fluid breaks to less than 3.0 cP in less than 72 hours when in a temperature range of 180° F. (82.2° C.) to 220° F. (104.4° C.). The method also includes the steps of introducing the treatment fluid into the portion of the well and flowing back from the portion of the well.

Abstract: A method for building a plug in a horizontal wellbore using a fluid pill containing a suspended well treatment agent. The well treatment agent contains an ultra lightweight (ULW) deformable core and a viscosifying polymer and crosslinking agent coated onto the core. The fluid pill is pumped into the wellbore at the end of a fracturing treatment. The fluid pill is displaced by a displacement fluid and the fluid pill transforms to a thickened gel. The thickened gel is formed by the in-situ reaction of the viscosifying polymer and crosslinking which become disassociated from the ULW deformable core. The gelled fluid containing the ULW deformable core assists in the bridging of the ULW deformable core and forming the bridge plug.

Abstract: An apparatus and related methods for removing hazardous trace elements from hydrocarbon reservoir effluent is implemented by placing an adsorbing volume of material designed to adsorb the hazardous trace elements into the vicinity of a producing formation face at a downhole location; and letting the reservoir effluent flow through the volume of adsorbing material.

Abstract: A technique facilitates monitoring of conditions which are prone to cause scale precipitation around downhole equipment. The technique also enables a local, downhole reaction to the potential for precipitation of scale. A downhole scale monitoring and inhibition system may be provided with a measurement module and injection module. The measurement module monitors at least one downhole parameter indicative of the potential for scale formation. In response to data output from the measurement module, the injection module is operated to provide downhole, local injections of an inhibitor chemical.

Abstract: A method can include applying a magnetic field to a well screen, thereby varying sizes of pores via which fluid flows through the well screen. A well screen can include a magnetic shape memory material having a dimension which changes in response to application of a magnetic field. Restriction to flow through the well screen can vary in response to the change in dimension of the magnetic shape memory material.

Abstract: Copolymers containing acryloylmorpholine and vinylimidazole, and optionally vinylcaprolactam and/or n-vinyl pyrrolidone, have shown superior results in hydrate inhibition tests at conditions of 7° C. subcooling dosed at 1 vol % based on the water cut of the system fluids. The copolymer product has also passed high TDS (total dissolved solids) brine compatibility tests and secondary property tests including foaming and hot injection tests which make it useful as a kinetic hydrate inhibitor in gas production systems susceptible to the formation of natural gas hydrates.

Abstract: The present invention is directed to a method and system for treating a well having a wellbore extending from a ground surface or subsea surface downhole to an oil producing formation. Oil producing formations are capable of generating formation fluids into a wellbore. Formation fluids are comprised of at least an oil fraction and an aqueous fraction. Emulsions may form during oil production, and such emulsions may be comprised of oil and water. Inhibitor compositions may be employed to break such emulsions.

Abstract: A disclosed downhole optical sensor system includes at least one optical sensor positioned in a borehole and coupled to an interface via a fiber optic cable. Each of the optical sensors includes a waveguide for conducting light, and a reagent region positioned between the waveguide and a fluid in the borehole to absorb a portion of the light from the waveguide, the portion being dependent upon a concentration of a chemical species in the fluid. A described method for operating a well includes deploying one or more downhole optical sensors in a fluid flow path in the well, probing the one or more downhole optical sensors from a surface interface to detect concentrations of one or more chemical species, and deriving a rate of scale buildup or corrosion based at least in part on the detected concentrations.

Abstract: Systems and processes are provided for removing fluid from a subterranean well and enhancing the production of oil and/or gas are herein disclosed. In one embodiment, the system includes an injection conduit, an injection valve, a relief valve, a container, a container valve, a return conduit valve, and a return conduit, all arranged within a subterranean well for removing at least one fluid from the well. The removal of at least one fluid from the well is controlled by the flow of gas into the injection conduit.

Abstract: Composition and methods using the compositions are disclosed, where the compositions include heterocyclic aromatic amines, substituted heterocyclic aromatic amines, poly vinyl heterocyclic aromatic amines, co-polymers of vinyl heterocyclic aromatic amine and non amine polymerizable monomers (ethylenically unsaturated mononers and diene monomers), or mixtures or combinations thereof in the absence of phosphate esters, optionally ethoxylated alcohols, and optionally, which form alter self-aggregating properties and/or aggregation propensities of the particles, surfaces, and/or materials.

Abstract: A method comprising placing a composition comprising a wellbore servicing fluid and a Micro-Electro-Mechanical System (MEMS) sensor in a subterranean formation, whereby the MEMS sensor is coated with an elastomer. The elastomer-coated MEMS sensor is used to detect one or more parameters, including a compression or swelling of the elastomer, an expansion of the elastomer, or a change in density of the composition.

Abstract: Methods are provided for treating production fluid in a production well in an oil reservoir to reduce the amount of sulfide in the production fluid. The production fluid is treated with nitrate and/or nitrite ions in an aqueous solution that is added to the well casing.

Abstract: Disintegrative particles having a disintegrative coating surrounding a disintegrative core may be pumped within an aqueous treatment fluid downhole to a subterranean formation. With time and/or change in wellbore or environmental condition, these particles will either disintegrate partially or completely, in non-limiting examples, by contact with downhole wellbore fluid, formation water, or a stimulation fluid (e.g. acid or brine). Once disintegrated, metals or compounds are released which raises the fluid pH and forms a structure that selectively inhibits or shuts-off the production of water from water-producing zones. The disintegrative particles may be made by compacting and/or sintering metal powder particles, for instance magnesium or other reactive metal or their alloys. Alternatively, particles coated with nanometer-sized or micrometer sized coatings may be designed where the coatings disintegrate faster or slower than the core in a changed downhole environment.

Abstract: Lipophilic fibers are effective media for cleaning non-aqueous fluids out of a subterranean wellbore. The fibers are preferably added to a drilling fluid, a spacer fluid, a chemical wash, a cement slurry or combinations thereof. Non-aqueous fluids, such as an oil-base mud or a water-in-oil emulsion mud, are attracted to the fibers as they circulate in the wellbore.

Abstract: The instant disclosure is directed to a method of enhancing adsorption of a salt inhibitor onto a wellbore region, wherein the method comprises preconditioning the wellbore region, emplacing the salt inhibitor into the wellbore region, and shutting in the wellbore region for a period of time to at least initiate adsorption of the salt inhibitor onto the wellbore region. The salt inhibitor comprises an at least partially water soluble compound comprising a Group 3 to Group 15 metal and/or an at least partially water soluble compound having any one of the formulae: wherein X is O or S; and R1, R2, R3, R4, and when present, R5 and/or R6 each independently comprise an organic or an inorganic functional group.

Abstract: A well servicing fluid is disclosed. The well servicing fluid is formulated by combining ingredients comprising: an aqueous based fluid comprising sulfate ions at a concentration greater than 50 mg/l; a chelating agent; and an acid in an amount sufficient to result in the well servicing fluid having a pH of 4.5 or less. A method of servicing a well is also disclosed.

Abstract: A method for treating a wellbore or a subterranean formation penetrated by a wellbore includes preparing a gelled oil at the surface, introducing the gelled oil into the wellbore, recovering the gelled oil at the surface, adding a base to the gelled oil to reduce the viscosity, allowing entrained solids to settle out, adding an acid to increase the viscosity, and re-injecting the gelled oil.