Abstract: A method includes receiving, by a processing device and from one or more sensors coupled to a water reservoir storing water received from a separator, fluid information. The fluid information includes a water level of the water reservoir. The separator is fluidically coupled to a wellbore string disposed within a wellbore. The method also includes determining, based on the fluid information, operation mode instructions. The method also includes transmitting, to a controller communicatively coupled to at least one flow regulation device fluidically coupled to the wellbore string, the operation mode instructions. The controller controls, based on the instructions, the at least one flow regulation device to regulate, during a production mode of the wellbore string, a flow of production fluid from the wellbore string to the separator or regulating, during a water injection mode of the wellbore string, a flow of water from the water reservoir into the wellbore string.

Abstract: A filling element has a gas valve that controls flow of gas through a gas channel that extends into or faces the container during filling thereof. The gas valve transitions between discrete states, which includes a fully-open state, a closed state, and one or more partially-open states.

Abstract: A method for controlling corrosion is described. The method includes determining a concentration of a first gas in a first formation, determining a concentration of a second gas different than the first gas in a second formation, determining a ratio between the first gas and the second gas, comparing the determined ratio to a threshold ratio of the first gas to the second gas for the wellbore which reduces a corrosion rate within the wellbore, and based on a result of comparing the determined ratio to the threshold ratio, modifying a quantity of the first formation fluid or the second formation fluid flowed into the wellbore. The first gas and the second gas mix within the wellbore.

Abstract: This disclosure relates to membrane-based systems for transporting dissolved gases to a formation and methods for increasing a mass transfer rate of gases in a formation. The membrane-based system may include an aqueous injection well, a diffusion-based membrane, a gas, and an aqueous solution.

Abstract: New formulation for pyrite scale removal from oil and gas wells and a method of pyrite scale removal are disclosed. The chemical formulation is composed of K2B4O7-4H2O, in a concentration of about 9-20 wt. % of the composition, preferably about 14 wt. % of the composition. The new formulation has the ability to dissolve pyrite without generation of the toxic H2S. Furthermore, the new formulation is cheaper and has very low corrosion rate compare to 15 wt. % HCl with corrosion inhibitor. The disclose method uses the disclosed new formulation to dissolve iron sulphide scale, performed at about 100-150° C. and about 500-2000 psi.

Abstract: Herein are provided tools and processes for extracting oil from subterranean formation. The processes can include lightening the oil in the formation prior to extraction by the addition of a nanogas solution. The tools include injectors for the formation of the nanogas solution within the subterranean formation.

Abstract: A subsea multiphase fluid separation system has a gas separator for separating gas from a well stream containing oil. A water separation stage downstream of the gas separator has at least one dual pipe separator for separating water from the oil of the wellstream. A water treatment system for cleaning oil from water is produced by the water separation stage. On an oil outlet path, downstream of the or each dual pipe separator, there is an electrocoalescer and at least one second separator in series.

Abstract: A method for pumping a liquid-gas mixture into a subsurface well includes introducing gas into a liquid at a first pressure to generate a mixture. The mixture is pumped through a first positive displacement pump to a second pressure greater than the first pressure. The mixture at the second pressure is pumped through at least a second positive displacement pump to a third pressure greater than the second pressure. The mixture is moved into the subsurface well at at least the third pressure.

Abstract: A method may include providing a humidification-dehumidification unit proximate one or more abandoned wells, circulating a water feed through the one or more abandoned wells, using geothermal heat in the one or more abandoned wells to heat the water feed, directing the heated water feed to the humidification-dehumidification unit, and treating the heated water feed in the humidification-dehumidification unit to provide purified water.

Abstract: A hydrocarbon production field layout comprising a first pipeline (1) with a first inner diameter and a second pipeline (2) with the first inner diameter. A cut off valve (20) with an inner bore with the first diameter, is arranged in a connecting arrangement between an end of the first pipeline (1) and an end of the second pipeline (2). At least one dual main header manifold (3) is in fluid connection with at least one hydrocarbon well (8, 9). A first branch pipe (16, 18) with a first valve (5, 6) is branched off from the first pipeline (1) and a second branch pipe (17, 19) with a second valve (5, 7) is branched off from the second pipeline (2). The branch pipes are connected to the at least one manifold (3, 4).

Abstract: A method of dissolving a gas hydrate in a pipeline includes introducing a gas hydrate dissolving solution into the pipeline and allowing the gas hydrate dissolving solution to at least partially dissolve the gas hydrate in the pipeline. The gas hydrate dissolving solution includes cesium formate, potassium formate, or both, and has a flash point of greater than 50° C.

Abstract: A method and system of providing source water and managing produced/flowback water during a hydraulic fracturing process in an oil and gas operation. The process is an environmentally friendly method of reducing use of fresh water and recycles frac water. The net result is that a volume of frac water is properly managed. Thus, less reliance on transportation vehicles and trucks reduces costs as well as reduction of piping systems. It further reduces a threat of seismic events from disposing of produced water and flowback.

Abstract: An oil-water fractionation system is positioned within a wellbore on a subsurface end of a production tubing proximate to a production region. The fractionation system includes a permeable hydrophobic media for preferentially conveying an oil-enriched stream (reduced water-cut presence) from the production region into the production tubing, and a permeable oleophobic media for preferentially conveying a water-enriched stream (reduced oil-cut presence) into a second flow path. The permeable hydrophobic media and the permeable oleophobic media are in simultaneous hydraulic communication with the production region. The permeable hydrophobic media is manufactured with a relatively high effective permeability to oil, allowing the oil-enriched stream to flow through the permeable hydrophobic media into the production tubing.

Abstract: A method of dissolving a gas hydrate in a pipeline includes introducing a gas hydrate dissolving solution into the pipeline and allowing the gas hydrate dissolving solution to at least partially dissolve the gas hydrate in the pipeline. The gas hydrate dissolving solution includes a glycol, dimethylformamide, or both, and has a boiling point of greater than 80° C. A method of dissolving a gas hydrate in a pipeline may also include introducing a gas hydrate dissolving solution into the pipeline and allowing the gas hydrate dissolving solution to at least partially dissolve the gas hydrate in the pipeline. The gas hydrate dissolving solution includes comprises a glycol, dimethylformamide, cesium formate, potassium formate, or combinations thereof, and has a flash point of greater than 50° C.

Abstract: Methods and systems for gasifying coal are disclosed herein. In some embodiments, a representative coal gasification system can comprise (i) an injection well extending from a ground surface to an underground coal gasification (UCG) reaction region of a coal seam; (ii) a production well spaced apart from the injection well and extending from the ground surface to the UCG reaction region, and (iii) conduits each extending from the ground surface to areas of the coal seam. End portions of the conduits within the coal can be laterally peripheral to the UCG reaction region. The conduits are configured to deliver a primary fluid from the ground surface to the primary region, the injection well is configured to deliver an oxidant gas to the UCG reaction region, and the production well is configured to deliver the product gas from the UCG reaction region to the ground surface.

Abstract: A method of removing calcium carbonate-containing oil-based filter cake from a wellbore involving contacting the calcium carbonate-containing oil-based filter cake with a biodegradable acid solution of water, hydrochloric acid, formic acid, citric acid, a surfactant, and a glycol ether mutual solvent. The method is performed at a pressure of 200 to 400 psi and a temperature of 50 to 125° C. The method removes calcium carbonate-containing oil-based filter cake made of a water-in-oil emulsion, calcium carbonate, a primary emulsifier, a secondary emulsifier, a contamination treatment agent, a viscosity control agent, a filtration control agent. The method meets industry standard steel corrosion rates of less than 0.049 lb/ft2 per day. Also disclosed is a biodegradable acid solution of water, hydrochloric acid, formic acid, citric acid, a surfactant, and a glycol ether mutual solvent that meets OECD 301B thresholds for ready biodegradability.

Abstract: The invention relates to a method for recovery of hydrocarbons in a geological reservoir by injection of a low-salinity aqueous solution. A representative model of the evolution of the flow parameters as a function of the aqueous solution salinity is calibrated by use of laboratory measurements performed on a rock sample from the reservoir for at least two salinity values. Then, by use of a flow simulator including the calibrated model, the injection of aqueous solutions into the sample is simulated, with and without capillary effects, for at least the two salinity values with a microscopic residual oil saturation being determined for each salinity value. Then, from the flow simulator including the calibrated model and the microscopic residual oil saturation values, a reservoir development scheme is determined with hydrocarbons of the reservoir being exploited according to the development scheme.

Abstract: The invention relates to the use of a non-ionic surfactant and an anionic surfactant for enhancing the injectivity of an injection well, wherein the non-ionic surfactant and the anionic surfactant are added to produced water, to form a reinjection stream which is injected into a subterranean formation by the injection well.

Abstract: Systems and methods for identifying a status of components of hydraulic fracturing units including a prime mover and a hydraulic fracturing pump to pump fracturing fluid into a wellhead via a manifold may include a diagnostic control assembly. The diagnostic control assembly may include sensors associated with the hydraulic fracturing units or the manifold, and a supervisory control unit to determine whether the sensors are generating signals outside a calibration range, determine whether a fluid parameter associated with an auxiliary system of the hydraulic fracturing units is indicative of a fluid-related problem, determine whether lubrication associated with the prime mover, the hydraulic fracturing pump, or a transmission of the hydraulic fracturing units has a lubrication fluid temperature greater than a maximum lubrication temperature, or determine an extent to which a heat exchanger assembly associated with the hydraulic fracturing units is cooling fluid passing through the heat exchanger assembly.

Abstract: Herein are provided tools and processes for extracting oil from subterranean formation. The processes can include lightening the oil in the formation prior to extraction by the addition of a nanogas solution. The tools include injectors for the formation of the nanogas solution within the subterranean formation.

Abstract: A flowback tank cleaning system and method is described. A flowback tank includes a self-cleaning system. A flowback tank cleaning method may include moving solid debris collected at a bottom of a collection section of a flowback tank towards a lift auger using a cleaning auger or a conveyer belt extending along a length of the collection section, the bottom of the collection section including an angled trough, funneling solid debris towards the cleaning auger or conveyor belt by placing the cleaning auger or conveyor belt at a base of the angled trough, spraying fluid downward through a series of fluid outlets, removing the sand so moved by the cleaning auger or conveyer belt from the flowback tank using the lift auger, and removing the fluid from the flowback tank using a drain manifold below the cleaning auger or conveyer belt.

Abstract: Disclosed is an improved vapor recovery system. The vapor recovery system includes a vapor recovery tower and a vapor recovery unit. The vapor recovery tower includes an internal heat exchanger suitable for heating crude oil processed by the vapor recovery tower. The vapor recovery unit includes a compressor suitable for compressing and thereby heating vapors and gases separated from crude oil by the vapor recovery tower. The gases heated by compression within the vapor recovery unit subsequently pass through the jacket or shell of the heat exchanger.

Abstract: A system and process for defining, blending and monitoring fresh water with subterranean produced formation fluids, with particular constituents of the blended waters being controlled for proper use in gel-type hydraulic fracturing operations. On-site measurements and calculations of clay stabilization replacement, through a Potassium Chloride (KCl) Equivalency calculation, provide feedback on water constituent adjustments that may be needed just prior to the gel-based hydraulic fracturing process. This assures adequate gel cross-linking times, delayed gel cross-linking times, and clay stabilization in the formation to be fractured.

Abstract: The present invention relates to a dry blend one-part pre-flush and spacer package for forming a water-based pre-flush and spacer on-the-fly for use in a subterranean well and a method of mixing a pre-flush and spacer on-the-fly for use in a subterranean well. The dry blend pre-flush and spacer package includes an anionic surfactant, a builder compound, and optionally, a defoamer, a dispersant calcium chelator, a density modifying agent, a viscosifying agent such as a solid, and preferably rapidly hydrating, gellant, salt and one or more lost-circulation materials. The dry blend pre-flush and spacer package is mixed on-the-fly with water at the subterranean well site to form the pre-flush and spacer at a pre-selected density and the pre-flush and spacer, when pumped into the subterranean well by a pressure pumper, converts the well from an oil-wet or substantially non-water-wet condition to a substantially water-wet condition.

Abstract: A reclaiming apparatus includes: a container in which a reclaiming process of an absorption liquid is performed; an absorption liquid supply line for supplying the container with the absorption liquid; a heat exchange device, installed inside the container, for heating a liquid inside the container; a circulation line for extracting the liquid inside the container, circulating the liquid and returning the liquid to the container; and a circulation pump installed in the circulation line.

Abstract: The invention relates to sewage treatment, and more particularly to a system for treating reverse-osmosis concentrated water with permanent hardness. The system includes a first crystallization unit, a first reverse osmosis unit, a second crystallization unit, a lime softening unit and a second reverse osmosis unit, which are connected in sequence. The system of the invention is able to eliminate the permanent hardness and the temporary hardness of the concentrated brine, and the hardness can be reduced to equal to or less than 50 mg/L.

Abstract: A method for recovering natural gas liquids from a recycle stream having natural gas is provided. In one embodiment, a carbon dioxide recycle stream that comprises carbon dioxide, natural gas, and natural gas liquids is received. The carbon dioxide recycle stream is separated into a purified carbon dioxide recycle stream and a natural gas liquids stream. The purified carbon dioxide recycle stream comprises the carbon dioxide and the natural gas, and the natural gas liquids stream comprises the natural gas liquids. In another embodiment, a system comprises piping and a separator. The piping is configured to receive a recycle stream, and the separator is coupled to the piping and is configured to separate the recycle stream into a purified recycle stream and a natural gas liquids stream.

Abstract: Systems and methods generate steam mixed with desired non-condensable gas concentrations using a direct steam generator. Injecting the steam into a reservoir may facilitate recovering hydrocarbons from the reservoir. Cooling an output of the direct steam generator produces water condensate, which is then separated from the non-condensable gas, such as carbon dioxide. Reducing pressure of the condensate subsequently heated by cross-exchange with effluent of the direct steam generator regenerates the steam with the carbon dioxide removed for the injection.

Abstract: A method to extract methane from a coal bed seam with carbon dioxide produced and recovered from a fuel cell anode exhaust stream while simultaneously sequestering the carbon dioxide on the coal. The process produces methane to supply a fuel cell to generate electricity while reducing or eliminating GHG emissions.

Abstract: Methods and systems for treating brine to produce distilled water and dried NaCl are disclosed. The brine enters a crystallization plant and is heated. Once heated, the brine is circulated to an evaporator. The evaporator increases the concentration of NaCl in the brine to a point about the super saturation level. Once above the super saturation level, NaCl crystals are formed. The larger crystals are circulated to a centrifuge for drying and the smaller crystals are recirculated through the evaporator for continued growth. The NaCl crystals are dried in the centrifuge.

Abstract: Methods of preparing an injection fluid for enhancing hydrocarbon recovery from a formation are described. A divalent salt is added to wastewater to form salinated wastewater. The salinated wastewater is tested for a shift in wettability. The salinated wastewater is tested for a change in oil recovery. The salinated wastewater is applied as an injection fluid. The shift in wettability is equal to or greater than a predetermined wettability differential value, and the change in oil recovery of the salinated wastewater is equal to or greater than a predetermined oil recovery differential value.

Abstract: A portable modular treatment system to be remotely deployed adjacent a solvent extraction bitumen well may include a portable initial separation module configured to receive a liquid emulsion from the solvent extraction bitumen well including bitumen, produced water, solvent, and at least one non-condensable gas, and liberate the at least one non-condensable gas while the solvent remains with the liquid emulsion. The system may further include a portable free water removal module configured to receive the liquid emulsion from the portable initial separation module and separate the bitumen and solvent from the produced water, a portable skimming tank module configured to receive the produced water from the portable free water removal module and remove free oil from the produced water through gravity separation, and a portable condenser module configured to receive the bitumen and solvent from the portable free water removal module and separate the bitumen and solvent.

Abstract: A shale gas extraction system includes a gas storage container configured to store gas, a heater in gaseous communication with the gas storage container, and a pump in gaseous communication with the gas storage container. The method includes extracting the shale gas from a layer of shale material, which includes the steps of heating a gas to predetermined temperature, pressurizing the gas to a predetermined pressure, driving the gas to the layer of shale material, and heating the shale gas with the gas.

Abstract: We provide a process for treatment of produced water, including but not limited to water produced by a “steam flood” process for extraction of oil from oil sands, including the removal of color from the water. This removal may be accomplished through addition of color-removal polymers and flocculents. This process may also be useful for other water treatment processes including reverse osmosis and filtration.

Abstract: Producing hydrocarbons by steam assisted gravity drainage, more particularly, utilizing conventional horizontal wellpair configuration of SAGD in conjunction of infill production well, to coinject oil-based solvents with steam initially and then switch to NCG-steam coinjection after establishing thermal communication between the thermal chamber and infill well.

Abstract: Methods for analyzing a reservoir in a formation containing hydrocarbon fluid are described. Information characterizing the formation is collected and applied to a formation simulator that is provided with a modified Darcy's law equation that accounts for at least one of gas adsorption/desorption, various modes of diffusive transport, and non-Darcy flow behavior, and the simulator is used to generate indications of the state of the reservoir and/or the state of production of hydrocarbon fluid from the reservoir. The modified Darcy's law equations are particularly useful in analyzing any type of formation containing any type of hydrocarbon fluid including shale formations containing hydrocarbon gases. According to one embodiment, a dual-porosity shape factor useful in a formation simulator is also provided.

Abstract: A method for treating produced water or a feedwater stream with an evaporator. The feedwater stream or produced water is directed to and through a deaerator located upstream of the evaporator. Steam produced by the evaporator is utilized to strip dissolved gases from the produced water or feedwater stream passing through the deaerator. To efficiently strip dissolved gases, the vapor pressure in the deaerator is maintained at below atmospheric pressure and the produced water or feedwater stream is heated to a temperature greater than the saturated vapor temperature in the deaerator.

Abstract: A system for generating high pressure steam from dirty water uses a combination of sub-merged plasma arcs and electrical resistive heating. Dirty water from steam assisted gravity drainage, or other dirty water producing process, which needs to be converted into high pressure steam, is fed directly without any pre-treatment, into a plasma fired steam generator, powered by submerged electrodes. The combination of electric arc plasma and resistive heating is created between the submerged electrodes. The heat so generated will boil the water portion of the dirty water feed to generate steam that is collected in a steam space and then removed there from. The solids and other residues (residual sludge) present in the feed water settle down at the bottom of the steam generator and are removed via a blow-down stream. The plasma arcs are used to intermittently remove any scaling or solid deposits that can accumulate on the electrodes.

Abstract: Methods for hydraulically re-fracturing a brittle shale formation section having a Young's Modulus of 20 GPa or more are disclosed involving injecting steam through a horizontal wellbore and into the brittle shale formation section; transferring heat from the injected steam through the shale matrix to pores that contain hydrocarbon gas or liquid; rupturing at least some of the pores by heating hydrocarbon gas or liquid contained in those pores and raising the pressure of hydrocarbon gas being heated in those pores to a level sufficient to rupture those pores, weaken the structure of the brittle shale matrix, and form micro-fractures in the brittle shale matrix; and injecting hydraulic fracturing fluid through the horizontal wellbore and into the primary fracture to form one or more macro-fractures in the brittle shale matrix having a weakened structure by expanding or coalescing at least some of the micro-fractures during the injecting of the hydraulic fracturing fluid.

Abstract: Improved methods and apparatus (10, 74) for the solubilization of initially solid humic acids include a large-volume mixing/agitation tank (12, 76) for water and solid humic acids, together a recirculation assembly (14, 78) for continuously recirculating the water/humic acids mixture while reducing the size of the humic acids. Properly used, the apparatus (10, 74) is capable of providing relatively stable, solubilized humic acid solutions or dispersions.

Abstract: Compositions and methods for reducing the formation of hydrates within subsea or over-land pipeline systems. The compositions and methods include the use of organic salt solutions, such as an acetate salt solution, to precondition, treat, and/or dewater the pipeline systems, or employ the use of the organic salt solutions during other pre-commissioning operations. An effective concentration of an organic salt solution acts to reduce hydrates and/or inhibit hydrate formation within the pipeline systems.

Abstract: A method for treating sulfide in an aqueous fluid comprises contacting the fluid with an oxidizer in the presence of a sulfur dye or sulfurized vat dye. In one embodiment, the method comprises treating sulfide contaminated water by contacting the contaminated water with air in the presence of a sulfur dye or a sulfurized vat dye. The method is useful for remediating industrial, agricultural, and municipal waste water.

Abstract: A method for inhibiting freezing of low salinity water (H2O) in a subsea low salinity water injection flowline comprises providing the flowline with a pressure control system, which may include a high pressure pump and a pair of pressure shut in valves, which maintains an elevated fluid pressure within the flowline throughout low salinity water injection operations and shut in periods, during which periods the flowline remains filled with pressurized non frozen low salinity water (H2O) that may have a temperature of about ?2 degrees Celsius.

Abstract: Methods for enhanced oil recovery from subterranean formations by treating a produced water prior to injection into the subterranean hydrocarbon reservoir and manipulating produced water compositions to increase the rate and/or amount of oil that is recovered from producing wells and/or a hydrocarbon reservoir. The treatment of the produced water can increase the pH of the water from about 0.75 to about 2.0.

Abstract: A process of producing liquid oil from shale gas condensate reservoirs and, more particularly, to increase liquid oil production by huff-n-puff in shale gas condensate reservoirs. The process includes performing a huff-n-puff gas injection mode and flowing the bottom-hole pressure lower than the dew point pressure.

Abstract: A method and apparatus for producing hydrocarbons from a subterranean formation. A first well is provided in the formation, the first well being separated by an isolating material into at least a first and second zone, the first zone being substantially isolated from the second zone. A second well is provided in the formation. The second well is separated by an isolating material into at least a first and second zone, the first zone being substantially isolated from the second zone. A first fracture is provided in the formation, the first fracture extending substantially between the first zones. A second fracture is provided in the formation, the second fracture extending substantially between the second zones of the first and second wells. A fluid is injected into the formation from the first zone in the first well. Hydrocarbons are produced at the second zone of the second well.

Abstract: Treating distilled water with bacteria and other micro-organisms to remove nitrogen compounds from the distilled water. The distilled water may be produced from pretreating and distilling wastewater, such as wastewater from oil and natural gas production. The treatment steps of the distilled water include subjecting the water to microbial action under both anoxic and aerobic conditions and employing a membrane bioreactor to further purify the water. The purified water is still further purified by either reverse osmosis or ion exchange systems.

Abstract: This method comprises cooling the feed natural gas in a first heat exchanger and introducing the cooled, feed natural gas into a first separation flask. It comprises the dynamic expansion of a turbine supply flow in a first expansion turbine and introducing the expanded flow into a separation column. This method comprises removing, at the head of the separation column, a head flow rich in methane and removing a first recirculation flow from the compressed head flow rich in methane. The method comprises forming at least a second recirculation flow obtained from the head flow rich in methane downstream of the separation column and forming a dynamic expansion flow from the second recirculation flow.

Abstract: A method for recovering natural gas liquids from a recycle stream having natural gas is provided. In one embodiment, a carbon dioxide recycle stream that comprises carbon dioxide, natural gas, and natural gas liquids is received. The carbon dioxide recycle stream is separated into a purified carbon dioxide recycle stream and a natural gas liquids stream. The purified carbon dioxide recycle stream comprises the carbon dioxide and the natural gas, and the natural gas liquids stream comprises the natural gas liquids. In another embodiment, a system comprises piping and a separator. The piping is configured to receive a recycle stream, and the separator is coupled to the piping and is configured to separate the recycle stream into a purified recycle stream and a natural gas liquids stream.

Abstract: A monitoring device and method for monitoring a longwall mining system having a plurality of roof supports, each roof support including a pressure sensor to determine pressure levels of the roof support during a monitoring cycle. Pressure data is obtained for the plurality of roof supports. The pressure data includes pressure information for each roof support of the plurality of roof supports over a monitoring cycle. The pressure data is analyzed to determine, for each roof support, whether a first type pressure failure occurred during the monitoring cycle. A fault quantity is generated that represents the number of roof supports determined to have had the first type of pressure failure occur during the monitoring cycle. An alert is generated upon determining that the fault quantity exceeds an alert threshold.