Abstract: Systems and methods for mud logging wherein the effectiveness of a primary gas trap is measured during operation.

Abstract: Paraffin deposits from downhole tubing, pumps and valves are removed by hot water and recycling the hot water to allow continual intermittent cleaning throughout the lifespan of the well. Heated water travels down the hollow rod annulus, entering the hollow rod string through ports at the bottom, temporarily heating both strings to melt and mobilized paraffin to enable intermittent pumping paraffin and debris to surface.

Abstract: An amount of seawater control device controls an amount of seawater supplied to a scrubber that purifies sulfur oxide contained in exhaust gas by bringing the sulfur oxide into contact with seawater. The control device includes a minimum amount of seawater converter which calculates a minimum amount of seawater necessary for an absorption reaction of the sulfur oxide by the seawater, an amount of seawater correction converter which calculates a corrected amount of seawater which is an amount of seawater at which the sulfur oxide contained in the exhaust gas discharged into atmosphere from the scrubber is equal to or less than a set variable, a summing element which calculates a set amount of seawater by summing the minimum amount of seawater and the corrected amount of seawater, and a pump control device which implements control such that seawater corresponding to the set amount is supplied to the scrubber.

Abstract: A method of producing methanol from shale gas and CO2 by the exclusive dry CO2 fracking of shale rock by injection of gaseous CO2 at a pressure between 10 and 100 atm to extract shale gas and recover it together with used CO2; combining and admixing produced shale gas containing CO2 and steam to produce a mixture of methane:carbon dioxide:water having a molar ratio of 3:1:2 for conducting the bi-reforming reaction to form a mixture of hydrogen and carbon monoxide having a molar ratio of 2:1 to 2.1:1; and converting the hydrogen and carbon monoxide under conditions sufficient to exclusively form methanol.

Abstract: A process for recovering oil from an oil-bearing formation is disclosed comprising providing a first oil recovery formulation comprising a first surfactant able to create low interfacial tension with reservoir crude oil; injecting the first oil recovery formulation into the oil-bearing formation via an injection well (201); providing a second oil recovery formulation having a second surfactant with a higher solubility in water than the first formulation; injecting the second oil recovery formulation into the oil-bearing formation via the injection well; and producing oil to a production well (203).

Abstract: Methods including producing a bulk fluid from a subterranean formation, the bulk fluid comprising at least water and a hydrocarbon, and having certain constituent parameters; sampling a portion of the bulk fluid, thereby forming at least one sampled fluid; determining constituent parameters of the sampled fluid using the hydrophilic-lipophilic deviation (HLD) model; and determining an optimal hydrate inhibitor surfactant (HIS) or HIS mixture to achieve a first oil-water separation morphological phase of the sampled fluid at temperatures above about 10° C. and a first water-in-oil morphological phase of the sampled fluid at temperatures below about 5° C.

Abstract: The invention relates to a device for extracting carbon-containing substances, in particular bitumen, from oil sands. The device comprises two separate steam circuits. The first steam circuit is a closed steam circuit, in which a steam turbine (3) is operating. The second steam circuit is an open steam circuit and is used for extracting carbon-containing substances, in particular bitumen, from oil sands. The steam turbine (3) comprises an intermediate steam removal facility (4), wherein the intermediate steam is used to evaporate the water/vapor in the second steam circuit via a heat exchanger. The invention further relates to a method for extracting carbon-containing substances by means of the previously described device.

Abstract: The present invention generally relates to one or more compositions and methods for inhibiting the formation of gas hydrate agglomerates in a fluid. The fluid may be contained, for example, in an oil or gas pipeline or refinery.

Abstract: Multiple catalytic processing stations enable a method for producing volatile gas streams from biomass decomposition at discrete increasing temperatures. These catalytic processing stations can be programmed to maximize conversion of biomass to useful renewable fuel components based on input feedstock and desired outputs.

Abstract: The present invention relates to a separation process of natural gas from gaseous compounds present at the wellhead by means of at least two adsorption columns, each containing an adsorbing solid and one operating at a higher pressure than the other, said process being characterized in that: •—the compression ratio is within the range of 1.1 to 10; •—the ratio between the characteristic convective time through the column and the characteristic diffusive time in the adsorbing solid is higher than 1.

Abstract: An improved method for the removal of non-targeted components from a non-targeted component containing gas stream, the method includes the steps of: (i) contacting the non-targeted component containing gas stream with a fluid solvent stream; (ii) passing the product of step i) through a co-current phase separation step to produce both a non-targeted component containing solvent stream and a partially purified gas stream; (iii) passing the partially purified gas stream product of step ii) through a mass transfer step to produce a wet gas product; and (iv) passing the wet gas product of step iii) through a final co-current phase separation step to produce a purified gas stream, wherein the method is performed in a subsea location.

Abstract: A system comprises an injection well in communication with an underground reservoir containing a native methane-containing solution at a first temperature, a production well in communication with the reservoir, a supply system providing a non-water based working fluid to the injection well at a second temperature lower than the first temperature, wherein exposure of the working fluid to the native fluid causes a portion of methane to come out of solution to form a production fluid of at least a portion of the working fluid and the portion of methane, and exposure to the first temperatures heats the production fluid to a third temperature higher than the second temperature, wherein the heated production fluid enters the production well, and an energy recovery apparatus in communication with the productions well for converting energy in the production fluid to electricity, heat, or a combination thereof.

Abstract: Oil-containing water is separated in a separator in an automated/continuous operation using devices that are free of moving parts in the separation container. Operation is preferably entirely controlled via adjustment of various flow rates, typically using flow control valves and/or feed pumps in response to measurement of a guided wave radar device or other IDLT.

Abstract: An arrangement for controlling and/or monitoring at least one subsea device may include: a first level node communicatively, in particular electrically and/or fiberoptically connectable to an equipment above a sea surface of a sea; at least one second level node communicatively, e.g., electrically and/or fiberoptically connected to the first level node and electrically connectable to the at least one subsea device, wherein the first level node and the at least one second level node are arrangeable at a sea bottom of the sea. A corresponding method is also disclosed.

Abstract: Described embodiments include a system and a method. A described system includes a pipeline system. The pipeline system includes a transportation conduit containing a natural gas hydrate flowing from a first geographic location to a second geographic location. The pipeline system includes a cooling conduit running parallel to the transportation conduit, and having a heat-transfer surface thermally coupled with the flowing natural gas hydrate. The cooling conduit contains a heat-transfer fluid flowing between the first geographic location and the second geographic location. The flowing heat-transfer fluid has a target temperature range predicted to maintain a selected stability of the flowing natural gas hydrate.

Abstract: A floating liquefied natural gas (“FLNG”) commissioning system and method are described.

Abstract: A new device and method for separating all phases of a three-phase fluid of the crude oil type, by means of a two-phase fluid separating device provided with a “T” joint for splitting the feed flow. The invention allows the conversion of two-phase separator into a three-phase fluid separating device, updating its functionality, increasing service life, using most of the original parts and components.

Abstract: A method is provided for producing upgraded heavy oil from a subterranean reservoir by producing a steam chamber within the reservoir by the action of steam and flowing a liquid phase additive into a near wellbore region of the steam chamber to control asphaltenes mobility within the near wellbore region. Build-up of asphaltenes, which derive from the heavy oil, in the near wellbore region has the potential of affecting heavy oil production rates from the reservoir. The additive is formulated to mobilize the asphaltenes within this region.

Abstract: The present invention regards a subsea sand handling system for limiting abrasion of specific subsea equipment (5), comprising an inlet (10) connectable to a sand separation system (2) upstream of the specific equipment (5) and an outlet (18, 22) connectable to a pipeline (6) downstream of the specific equipment (5), wherein it comprises at least two collection vessels (11,14) and means for flushing (16,17,19,21) the sand out of at least one of the collection vessels (11,14), and the vessels (11,14) and the means for flushing (16,17,19,21) the sand out of said vessels (11,14) are configured such that sand is flushed from one vessel (11,14) while sand is collected in the other vessel (14,11). The present invention also regards a method for limiting abrasion of subsea rotating equipment.

Abstract: A method for processing a flowback composition stream from a well head includes controlling a first flow rate of the flow back composition stream to a second flow rate by regulating the flowback composition stream from a first pressure to a second pressure. The method also includes separating the flowback composition stream into a first gas stream and a condensed stream. The method includes discharging the condensed stream to a degasser and degassing a carbon dioxide rich gas from the condensed stream. The method also includes mixing the carbon dioxide rich gas stream with the first gas stream to produce a second gas stream. The method includes controlling a third flow rate of the second gas stream by regulating a third pressure of the second gas stream to a fourth pressure that is different than the third pressure.

Abstract: A geothermal energy system comprising a plurality of borehole heat exchangers, each borehole heat exchanger containing a working fluid and comprising an elongate tube having a closed bottom end and first and second adjacent elongate conduits interconnected at the bottom end, a manifold for the working fluid to which the plurality of borehole heat exchangers is connected, and a plurality of valves connected between the plurality of borehole heat exchangers and the manifold, whereby the first and second conduits of the plurality of borehole heat exchangers are selectively connectable to the manifold by operation of the valves.

Abstract: Methods and compositions are described for treating water- and hydrocarbon-producing subterranean formations with a relative permeability modifier at concentrations below those conventionally used in the art, while not substantially impacting the treatment fluid's performance. Treatment fluids described herein comprise a base fluid, a relative permeability modifier comprising a hydrophobically modified hydrophilic polymer, and a companion polymer interacting synergistically with the relative permeability modifier such that the treatment fluid is operable to reduce the water permeability or to increase an aqueous fluid injection pressure of at least a portion of a subterranean formation by more than the relative permeability modifier or the companion polymer acting alone at like concentration. The water permeability reduction and/or the aqueous fluid injection pressure increase can be more than additive.

Abstract: A method for capturing dust generated during movement of sand through a sand delivery system includes positioning an inlet at a first end of each of a plurality of conduits for collecting dust in a corresponding space surrounding a corresponding point along a conveyor. A second end of each of the plurality of conduits is coupled in fluid communication with a manifold system including at least one manifold extending generally parallel to the ground. Substantially an entire length of the conveyor, including the space corresponding to the inlet of each of the plurality of conduits, is covered with a cover for containing dust generated during movement of sand along the conveyor. Air is drawn through the manifold system and the plurality of conduits to capture dust generated during the movement of sand along the conveyor through the inlet of each of the plurality of conduits.

Abstract: Disclosed is an improved water treatment cavitation reactor cone. The tank operates on a continuous flow of fluids which are subjected to ultrasonic waves in combination with a high level of injected ozone. The treatment tank includes a tangential inlet that induces a rotating flow into the tank thereby increasing the mixing of the ozone within the effluent. The effluent is further treated with DC current. The treatment tank provides a cost efficient and environmentally friendly process and apparatus for cleaning and recycling fluids as contaminated as frac water, used to stimulate gas production from shale formations, as well as other types of fluids having various levels of contaminants such as aerobic and anaerobic bacteria and suspended solids. The calcium carbonate scaling tendency is reduced to an acceptable level without the use of acids, ion exchange materials, or anti scaling chemicals which is of economical and environmental significance and benefit.

Abstract: The present invention relates to a two-step process to produce oil or gas from a subterranean formation wherein in a first step the subterranean formation is treated with an aqueous composition containing a chelating agent selected from the group of glutamic acid N,N-di-acetic acid or a salt thereof (GLDA), aspartic acid N,N-diacetic acid or a salt thereof (ASDA), methylglycine N,N-diacetic acid or a salt thereof (MGDA), and N-hydroxyethyl ethylenediamine N,N?,N?-triacetic acid or a salt thereof (HEDTA) and wherein, in a next step, in the outlet streams from the subterranean formation the aqueous phase is separated from the non-aqueous phase.

Abstract: A method of improving natural gas release from a well via an enhanced hydraulic fracturing operation. The method includes capturing or retrieving the flow back from the well following the fracturing operation. The flow back or other source water is introduced to an electrocoagulation (“EC”) treatment process. EC treatment separates the water from other fracturing fluid components in the flow back and also removes bacteria and other contaminants. Thereafter, the EC-treated fluid is recycled for subsequent fracturing operations. The process may also be used to treat all source water, including fresh water delivered to the well before it is used as a fracturing fluid.

Abstract: Disclosed is a water treatment apparatus for treating Lake Okeechobee water. The treatment apparatus operates on a continuous flow of water which is subjected to hydrodynamic waves, acoustic ultrasonic waves in combination with injected ozone and electrolysis. The treatment system provides a cost efficient and environmentally friendly process for cleaning contaminated water that is directed into estuaries, lagoons, intracoastal waterway, everglades, and the ocean. Treatment includes addressing various levels of contaminants such as aerobic bacteria, often called a green slime that produces a bio-film. The apparatus can be mounted on a vessel to permit targeting of algae blooms.

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: The present invention relates to producing oil from an oil-bearing geological formation using a selection process. The process includes selecting a treatment option such as carbon dioxide flooding for enhancing oil recovery from a geological formation in a remote location. Various characteristic properties such as a physical or chemical property of the oil or rock may be used in the selection process and the carbon dioxide may be captured from a combustion process.

Abstract: A system and method for cracking, hydrogenating and extracting oil from underground deposits includes a gasifier, an injection well and a production well. The gasifier creates high pressure, high temperature syngas. The pressurized syngas flows through an injection well into a deposit of oil under the ground to crack and hydrogenate the oil to produce upgraded oil with a reduced density and viscosity. The production well of the system receives the reduced density and viscosity oil, transports it above the ground where it may be further separated into a portion that may be sold and a portion that can be gasified in the gasifier.

Abstract: A vessel for use in settling particulate matter from a fluid stream is provided. Fluid is introduced to the vessel through an angled inlet, with flow into the vessel both disrupted and deflected by an inlet baffle, to redirect the fluid stream parallel to a horizontal axis of the vessel. The velocity of the fluid stream is reduced within the vessel, allowing the particulate matter to settle along the bottom of the vessel.

Abstract: Energy is stored by injecting fluid into a hydraulic fracture in the earth and producing the fluid back while recovering power and/or desalinating water. The method is particularly adapted to storage of large amounts of energy such as in grid-scale electric energy systems. The hydraulic fracture may be formed and treated with resin so as to limit fluid loss and to increase propagation pressure. The fluid may be water containing a dissolved salt or fresh water and a portion or all of the water may be desalinated using pressure in the water when it is produced.

Abstract: A system and methods for controlling microbial activity and growth in a mixed phase system. The method includes providing a rare-earth compound. The method also includes injecting the rare-earth compound into a mixed phase system, wherein the rare earth compound binds with a phosphate in an aqueous phase to adsorb the phosphate. The method also includes separating the rare-earth compound from the mixed phase system.

Abstract: A ball catcher for recovering balls from wellbore fluids containing sand during flow back operations. The ball catcher has a receiving chamber for receiving the wellbore fluids containing sand, a first flow outlet for discharging a portion of the wellbore fluids and sand contained therein, and a diverter for redirecting balls entrained within the wellbore fluids. The redirected balls and a balance of the wellbore fluids also containing sand are received in a ball-retaining chamber. A blocker fit to the ball-retaining chamber retains the recovered balls therein while the balance of the wellbore fluids and sand contained therein is discharged from a second flow outlet and directed to downstream equipment through an auxiliary flow line. The retaining chamber can be isolated allowing the balls to be removed from the ball catcher without disrupting the flow back operation.

Abstract: A continuous process for upgrading a heavy hydrocarbon includes the steps of: obtaining a heavy hydrocarbon; heating the heavy hydrocarbon; contacting the heavy hydrocarbon with a solvent at upgrading conditions so as to produce a first product comprising a mixture of upgraded hydrocarbon and solvent and a second product comprising asphaltene waste and water; continuously feeding the first product and the second product to a first separator; heating the first product; and continuously feeding the first product to a second separator to separate the upgraded hydrocarbon from the solvent. A system is also provided.

Abstract: Methods and systems relate to generating steam from water that contains dissolved organic compounds. The methods mix a polymerization inhibitor with the water prior to feeding the water into a steam generator. The polymerization inhibitor limits coupling of the dissolved organics under boiler conditions to mitigate fouling issues within the boiler.

Abstract: Disclosed is an improved water treatment apparatus. The treatment apparatus is pressurized and operates on a continuous flow of fluids which are subjected to hydrodynamic waves, acoustic ultrasonic waves in combination with injected ozone. The treatment tank includes a tangential inlet that induces a rotating flow into the tank thereby increasing the mixing of the ozone within the effluent. The ozonated fluid is further electro chemically treated with DC current. The treatment tank provides a cost efficient and environmentally friendly process and apparatus for cleaning and recycling fluids as contaminated as frac water, used to stimulate gas production from shale formations, as well as other types of fluids having various levels of contaminants such as aerobic and anaerobic bacteria and suspended solids.

Abstract: A surface well testing facility for dispersing separated hydrocarbon gas into separated oil from a multiphase well fluid for improved oil mobility and combustion efficiency. A multiphase fluid is produced from a well. The gas constituent and the oil constituent are separated from the multiphase fluid, the oil constituent having an undesirable viscosity. Both the gas constituent and the oil constituent are measured. Thereafter, at least a first portion of the gas constituent is injected into the oil constituent. The first portion of the gas constituent is mixed with the oil constituent such that the first portion of the gas constituent is dispersed into the oil constituent to form an oil/gas mixture having a viscosity that is lower than the undesirable viscosity of the oil constituent and a BTU content higher than the oil constituent.

Abstract: The present invention relates to a managed pressure and/or temperature drilling system (300) and method. In one embodiment, a method for drilling a wellbore into a gas hydrates formation is disclosed. The method includes drilling the wellbore into the gas hydrates formation; returning gas hydrates cuttings to a surface of the wellbore and/or a drilling rig while controlling a temperature and/or a pressure of the cuttings to prevent or control disassociation of the hydrates cuttings.

Abstract: A method and apparatus to regulate the down-hole hydrostatic pressure in a wellbore are provided which depend on regulating the resistance to the flow of wellbore returns produced by the wellbore. The resistance may be provided by the internal gas pressure in a gas/liquid separator receiving the flow of wellbore returns, where the internal gas pressure is regulated by an adjustable back pressure valve and a gas source. Alternatively or in addition, the resistance may be provided by a pump receiving the flow of wellbore returns, where the resistance of the pump is regulated by adjusting the speed of the pump.

Abstract: A method and system for processing produced fluids from a subterranean reservoir is disclosed. The system comprises: (a) a separator for separating produced fluids from a subterranean reservoir into associated gases, water and crude oil, (b) a membrane which receives at least a portion of the associated gases containing the hydrogen sulfide and separates the gas into a permeate stream enriched in hydrogen sulfide and carbon dioxide and a retentate stream depleted in hydrogen sulfide and carbon dioxide; (c) an amine unit for removing carbon dioxide and hydrogen sulfide from the retentate stream; and (d) a sour gas injection unit for injecting at the permeate stream in an underground formation.

Abstract: The present invention provides a method of generating steam for the recovery of hydrocarbon from a hydro-carbon producing system comprising: (i) generating supercritical steam from water; (ii) converting said supercritical steam to a subcritical steam; and (iii) injecting said subcritical steam into said system.

Abstract: An in situ extraction process for the recovery of hydrocarbons from a hydrocarbon bearing formation, including the steps of injecting a solvent consisting substantially of one of the group of H2S, Ammonia or COS into the formation to mobilize the hydrocarbons for extraction by forming a mobile in situ extraction fluid; and lifting the extraction fluid containing the mobilized hydrocarbons from the underground formation to the surface. In a further aspect an extraction method for a specific reservoir is provided including the steps of: establishing a minimum desired extraction rate, based on a value for the porosity, permeability and dead oil viscosity of the in situ bitumen in the specific reservoir, determining a desired minimum operating extraction temperature determining a desirable range of operating pressures identifying solvents predicted to deliver the operating extraction temperature within the range of operating pressures, and selecting a preferred solvent to use in the process.

Abstract: A subsea production and separation system comprising a subsea well drilled into a sea floor; a subsea tree located on the sea floor at a top portion of the subsea well; a manifold located on the sea floor; a well jumper connecting the subsea tree and the manifold; a first sled located on the sea floor; a second sled located on the sea floor; a separator located on the sea floor; a first flowline jumper connecting the manifold to the separator; a second flowline jumper connecting the manifold to the separator; a third flowline jumper connecting the separator to the first sled; a fourth flowline jumper connecting the separator to the second sled; a liquid export line connected to the third flowline jumper; and a gas export line connected to the fourth flowline jumper.

Abstract: A method for removing water from a wellbore fluid may include the steps of contacting a wellbore fluid with a water absorbing polymer, where the wellbore fluid includes an aqueous fluid, allowing the water absorbing polymer to interact with the wellbore fluid for a sufficient period of time so that the water absorbing polymer absorbs at least a portion of water in the aqueous fluid, and separating the water absorbing polymer containing the absorbed water from the wellbore fluid.

Abstract: A method of recovering oil from an oil well includes recovering an oil-water mixture from the oil well and separating produced water from the oil-water mixture. Thereafter, the produced water is directed through a ceramic membrane that removes free oil and emulsified oil from the produced water. The method or process further includes cleaning the ceramic membrane in online and offline modes. In the offline mode, cleaning is achieved by periodically backflushing the ceramic membrane with an aqueous media having a pH of 13 or greater and a temperature of 60° C. or greater. Further, the ceramic membrane is cleaned in the offline mode by applying the following operations. In one or more clean-in-place operations, an aqueous alkaline media at a pH of 13 or higher and a temperature of 60° C. or higher is directed through the ceramic membrane. In one or more clean-in-place operations, the ceramic membrane is also cleaned with an aqueous acidic media that contains dissolved citric acid.

Abstract: A process for recovering oil is provided. The process entails recovering an oil-water mixture from an oil-bearing formation. Next, the process entails separating oil from the oil-water mixture and producing produced water having hardness and other scale-forming compounds, suspended solids, free oil and emulsified oil. A pre-treatment process is undertaken to remove hardness and other scale-forming compounds. This entails precipitating hardness and other scale-forming compounds. After the precipitation of hardness and other scale-forming compounds, the produced water is directed to a membrane separation unit for filtering the produced water and producing a retentate having suspended solids, hardness and other scale-forming compounds, free oil and emulsified oil. The membrane separation unit also produces a permeate stream substantially free of hardness and other scale-forming compounds, suspended solids, free oil and emulsified oil.

Abstract: Described herein are systems and methods that utilize bicarbonate and acid to form carbon dioxide in a well (e.g., an oil well) to increase pressure in the well to facilitate production of oil and other resources, such as hydrocarbons, from the well. The well can be a closed system that facilitates absorption of the carbon dioxide into the oil resource. After the carbon dioxide is absorbed within the oil, the oil containing the carbon dioxide can be produced by the well. The carbon dioxide can be recycled after the resource is mined from the well to create bicarbonate that subsequently can be used with acid to facilitate the production from the well.

Abstract: Heavy crude oils having high sulfur content and viscosities are upgraded by a hydrodesulfurization (HDS) process that includes microwave irradiation of a mixture of the sour heavy crude oil with at least one catalyst and optionally, one or more sensitizers, and irradiation in the presence of hydrogen. The process is also adapted to microwave treatment of hard to break emulsions, either above ground or below ground where water-in-oil emulsions are initially formed, followed by the catalytic hydrodesulfurization promoted by application of further microwave energy to the demulsified crude oil stream.

Abstract: Produced natural gas containing carbon dioxide is dehydrated and chilled to liquefy the carbon dioxide and then fractionated to produce a waste stream of liquid carbon dioxide and hydrogen sulfide. Natural gas liquids may be first separated and removed before fractionation. After fractionation, the waste stream is pressurized and transmitted to a remote injection well for injection either for disposal of the waste stream and preferably to urge hydrocarbons toward the producing well. A hydrocarbon stream proceeds from fractionation to a methanol absorber system which removes carbon dioxide gas. The hydrocarbon stream is thereafter separated into at least hydrocarbon gas, nitrogen and helium. Some of the nitrogen is reintroduced into a fractionation tower to enhance the recovery of hydrocarbons. A methanol recovery system is provided to recover and reuse the methanol. The hydrocarbons are sold as natural gas and the helium is recovered and sold. Excess nitrogen is vented.