Abstract: A method and system for the recovery and conversion of subsurface gas hydrates is provided. This is accomplished by accessing a subsurface hydrate formation and treating the formation with a treating system so that gas is released from the hydrate formation. The released gas is then delivered and collected by means of a gas recovery system at a surface location. The gas is converted to liquid hydrocarbons in a conversion system utilizing a synthesis gas unit for producing synthesis gas from the hydrate gas, and a synthesis unit for converting the synthesis gas into liquid hydrocarbons. In at least one embodiment, the synthesis unit utilizes a Fischer-Tropsch reactor. Excess energy produced during the conversion of the hydrate gas can be utilized in the treating and recovery of the hydrate gas.

Abstract: Frac sand from a well completion operation is transported to a recycling facility by truck. The frac sand is passed into a washing facility where is it separated from frac sand carrier residue, clays, drilling mud and metal particles. The wash water used in the washing facility is settled and re-used. Mud from the settled wash water is removed and re-used in drilling operations. The frac sand is removed from the washing facility by an inclined dehydration screw, and discharged into a counterflow hot air drying facility. Dust from the drying facility is collected and removed. Hot frac sand from the drying facility is passed through a chiller, and collected. The collected material is sized, and stored for re-use.

Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a synthesis gas production temperature. A synthesis gas generating fluid may be introduced into the portion. Synthesis gas may be produced from the formation Synthesis gas may be used as a feed stream in an ammonia synthesis process. Ammonia may be used as a feed stream in a urea synthesis process.

Abstract: A coal formation may be treated using an in situ thermal process. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heat input into the formation may be controlled to raise a temperature of the formation at a selected rate.

Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heat and pressure applied to the formation may be controlled so that a majority of the hydrocarbons produced from the formation have carbon numbers less than 25. Conditions may be controlled to produce low quantities of olefins in condensable hydrocarbons produced from the formation and low quantities of olefins in non-condensable hydrocarbons produced from the formation.

Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. The mixture produced from the formation may contain condensable hydrocarbons fluids with some nitrogen containing hydrocarbons and/or with some sulfur containing hydrocarbons.

Abstract: A method for separating oil from geological formations by application of an aqueous oxidant. The oxidant breaks the interfacial attraction between the oil phase and the geological formation and also produces ketone moieties which assist in separating the oil phase from the mineral phase and also dissolve into the oil phase, thereby decreasing the viscosity. The method is especially useful in recovering heavy oil from geological formations wherein oil has been previously extracted to exhaustion by prior art methods.

Abstract: A system and process for reducing the flowing bottom-hole pressure in a natural gas well has a first discrete fluid flow path extending from the surface well head through a valve to an inlet of a separator, the valve being actuable between a closed condition and an open condition, and a second discrete gas flow path extending from an outlet of the separator to an inlet of a compressor, the compressor maintaining a near or below zero PSIG pressure at the separator inlet. When the valve is in the closed condition, positive pressure builds on the well head side of the valve and, when the valve is in the open condition, the near or below zero PSIG pressure of the separator is applied to the well head.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. The produced mixture may contain condensable hydrocarbons with sulfur containing hydrocarbons.

Abstract: Oil which has been heated by use in a gas compressor is cooled by transferring the heat from the oil to gas upstream from the compressor. Specifically, the hot oil and gas leaving the compressor are separated by feeding the oil-gas mixture along a tangent of a cylindrical chamber. The oil drops through holes in the bottom of the chamber into a upper reservoir. The oil flows from the upper reservoir into a tube which extends through a heat exchange having cold natural gas outside the tube. The oil flows from the tube into a lower reservoir and from there into the compressor.

Abstract: The present invention generally relates to a system and method for using a gas in a well. In one aspect, the system includes a source of fluid and at least one multiphase pump for transporting the fluid. The system further includes a separator for separating phases in the fluid and an injector for injecting the gas into the well. The gas may be used for kicking off a shut-in well by the simultaneous injection of the gas into the shut-in well and the reduction of the wellhead pressure. The gas may also be used for maintaining production of the well, cleaning out the well or lightening the wellbore fluid in riser system. In another aspect, the invention provides a portable multiphase pump system. In yet another aspect, the invention provides a method for recycling gas from a wellbore fluid.

Abstract: A process for producing a diesel fuel stock from bitumen uses steam, naphtha and a hydroisomerized diesel fraction produced by a gas conversion process, to respectively (i) stimulate the bitumen production, (ii) dilute it for pipeline transport to an upgrading facility, and (iii) increase the cetane number of a hydrotreated diesel fuel fraction produced by upgrading the bitumen by blending it with the hydroisomerized gas conversion diesel fraction, to form the diesel stock. This diesel stock has a higher cetane number than that produced from the bitumen alone, and is used for blending and forming diesel fuel.

Abstract: There is disclosed a method and apparatus for treating produced water from a heavy oil thermal recovery unit to achieve water recovery and recycle levels of greater than 80% and as high as 100% to achieve zero discharge criteria. The method includes the initial steps of capturing the waste heat energy from the high pressure steam separator located downstream of the steam generators. Further, transferring the heat energy into a heated separator and reboiler exchanger to distill oil reservoir produced water and recover distilled water and a concentrated brine or solid product. The heated separator concentrated stream is circulated through the reboiler exchanger to maintain from 1% to about 50% mass vapour in the stream returning to the heated separator and prevent fouling and scaling. The apparatus includes a low pressure waste energy separator, heated separator and vapour compressor in combination with a forced circulation circuit to generate the distilled water.

Abstract: A method and system for extraction of chemicals from an groundwater remediation aqueous effluent are provided. The extraction method utilizes a critical fluid for separation and recovery of chemicals employed in remediating groundwater contaminated with hazardous organic substances, and is particularly suited for separation and recovery of organic contaminants and process chemicals used in surfactant-based remediation technologies. The extraction method separates and recovers high-value chemicals from the remediation effluent and minimizes the volume of generated hazardous waste. The recovered chemicals can be recycled to the remediation process or stored for later use.

Abstract: A process for recovery of hydrocarbons in a production fluid from an underground reservoir of said hydrocarbons, the process comprising of: (a) injecting a viscosity reducing solvent of a fraction of said hydrocarbons into said reservoir at a pressure in the reservoir of above a liquid/vapor phase change pressure of a fraction of said solvent; said pressure in said reservoir also being sufficient to cause geomechanical formation dilation or pore fluid compression, and then, (b) allowing said solvent to mix with said hydrocarbons under pore dilation conditions, and then, (c) reducing the pressure in said reservoir to below said liquid/vapor phase change pressure of at least said fraction of said solvent thereby evincing solvent gas drive of said fraction of said hydrocarbons from said reservoir; and then, (d) repeating steps (a) to (c) as required.

Abstract: For the purification of an effluent that contains carbon dioxide and hydrocarbons resulting from a carbon dioxide-assisted recovery stage, the effluent is circulated in a gas-liquid separator (3) to recover C3+ liquid and a gas that contains carbon dioxide and, for example, less than 10% of methane and ethane. Pressurized combustion (13) of the gas with air produced a combustion gas (21) enriched with carbon dioxide and water vapor. The combustion gas (21) is cooled (11) (22) to recover heat, and the cooled combustion gas is recycled under pressure by a compressor (27) to an injection well (29). Nitrogen is at least partly separated from the combustion gas before the recycling, and in an optional intermediate step the condensed water is also separated from the carbon dioxide. The invention has a particular application for the assisted recovery of petroleum by CO2 with a reduction of the greenhouse effect.

Abstract: A system and method for recovery of hydrocarbon gas and liquids from a sub-sea environment utilizing a sub-sea membrane separation system. The system includes a production string located in a sub-sea wellbore for removing hydrocarbons and contaminants from a sub-sea formation. At least one membrane separator for separating contaminants from hydrocarbons removed from the sub-sea formation is located underwater between the production string and a hydrocarbon collection tank such that a predetermined temperature of the hydrocarbons is obtained by the location of the membrane. In another embodiment, a tube is connected to a sub-sea production string for removing hydrocarbons and contaminants from a sub-sea wellbore. At least one membrane separator for separating contaminants from hydrocarbons in the tube is positioned between the production string and a hydrocarbon collection tank wherein the temperature of the hydrocarbons and contaminants is controlled by the location of the membrane.

Abstract: Process for pretreating a natural gas under pressure containing hydrocarbons, acid compounds such as hydrogen sulfide and carbon dioxide, and water. The natural gas is cooled to condense part of the water. The partially dehydrated natural gas is then contacted with a liquid stream consisting of a majority of hydrogen in two successive contact zones so as to obtain a natural gas containing substantially no water any more. Finally, this dehydrated natural gas is cooled to condense and separate the acid compounds, this cooling stage being carried out by means of a heat exchanger, an expander or a venturi neck.

Abstract: A process for recovery of hydrocarbons from an underground reservoir penetrated by an injection well and a production well spaced from the injection well, the process comprising:

Abstract: A system and method for recovery of hydrocarbon gas and liquids from a sub-sea environment utilizing a sub-sea membrane separation system. The system includes a production string located in a sub-sea wellbore for removing hydrocarbons and contaminants from a sub-sea formation. At least one membrane separator for separating contaminants from hydrocarbons removed from the sub-sea formation is located underwater between the production string and a hydrocarbon collection tank such that a predetermined temperature of the hydrocarbons is obtained by the location of the membrane. In another embodiment, a tube is connected to a sub-sea production string for removing hydrocarbons and contaminants from a sub-sea wellbore. At least one membrane separator for separating contaminants from hydrocarbons in the tube is positioned between the production string and a hydrocarbon collection tank wherein the temperature of the hydrocarbons and contaminants is controlled by the location of the membrane.

Abstract: The present invention provides a clean water separation system with an electric submersible pumping device and a surface separator and pumping device for the separation and transfer of different density fluids and solids. The electric submersible pumping device can be an encapsulated device that works in conjunction with a separator and pumping system that are located on the surface, to separate fluids and solids.

Abstract: Frac sand from a well completion operation is transported to a recycling facility by truck. The frac sand is passed into a washing facility where is it separated from frac sand carrier residue, clays, drilling mud and metal particles. The wash water used in the washing facility is settled and re-used. Mud from the settled wash water is removed and re-used in drilling operations. The frac sand is removed from the washing facility by an inclined dehydration screw, and discharged into a counterflow hot air drying facility. Dust from the drying facility is collected and removed. Hot frac sand from the drying facility is passed through a chiller, and collected. The collected material is sized, and stored for re-use.

Abstract: An apparatus for enhancing fluid and gas flow recovery as well as remote on demand control of flow in a well includes an upstream flow line communicably connected at one end to the well in a manner to receive fluid and gas therefrom, a fluid and gas separator communicably connected to another end of the upstream flow line in a manner to receive fluid and gas flow therefrom, a downstream sales flow line communicably connected to the fluid and gas separator in a manner to receive gas flow therefrom, a control valve operably disposed in the upstream flow line, a local controller device operably controllably connected to the control valve in a manner to permit regulated flow through the upstream flow line at a predetermined amount and having a communications device associated therewith, and a remote controller device having a communications device therewith, wherein the local controller device and remote controller device communicate with one another to enable remote control of the control valve.

Abstract: A system takes low pressure (LP) liquid and transfers them into a high pressure (HP) gas pipeline using an energy transfer system. A volume of HP gas is used as the energy source for driving a lesser volume of LP liquid into a HP downstream system. Preferably, liquids separated from wellhead effluent are separated from gases and are directed to the energy transfer pump for transfer into a HP gas pipeline. Substantially dry gases from the HP pipeline are directed to the energy transfer pump for providing the drive energy for elevating the pressure of the liquids. This system eliminates the prior art blowcase vessel system and does not require onsite utilities.

Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heating may be controlled such that at least a selected amount of a total organic carbon content of the hydrocarbon material in the formation may be converted into formation fluids.

Abstract: An apparatus and method for recovering waste production gas at an oil or gas production site using a gas-vacuum compressor, a gas-vacuum compressor cylinder or a regenerative vacuum blower to evacuate the waste production gas from the salt water tank and the oil tanks under vacuum and transporting the gas under pressure to a waste production gas recovery device without contaminating the atmosphere.

Abstract: A process for in situ upgrading of a heavy hydrocarbon includes the steps of (a) positioning a well in a reservoir containing a heavy hydrocarbon having an initial API gravity of less than or equal to about 8; (b) injecting a light solvent into the well at reservoir conditions so as to provide an upgraded hydrocarbon in the reservoir, the upgraded hydrocarbon having an improved API gravity greater than the initial API gravity; and (c) producing the upgraded hydrocarbon from the well.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heat sources may be used to heat the formation. The heat sources may be positioned within the formation in a pattern. The pattern may be a repeating pattern of triangles.

Abstract: A process for the recovery of energy from a pressurised well stream containing a gas/liquid mixture, the process comprising: treating the well stream to a pre-separation process to separate it into gaseous and liquid phases, selecting appropriate proportions of said separated gaseous and liquid phases, recombining said selected proportions, and supplying the recombined mixture to the inlet of a rotary separation turbine, wherein said components are separated and energy is recovered from the flow by rotation of the turbine, said proportions of said gaseous and liquid phases being selected to produce an optimum mixture for supply to the rotary separation turbine.

Abstract: The present invention provides a process for the management of H2S containing gas streams and high alkalinity water streams in which process the H2S is selectively removed from the gas stream and combusted to form an SO2 rich waste gas stream. The SO2 gas stream is then scrubbed with the water stream to substantially remove the SO2 from the gas while subsequent treatment of the water such as softening or settling is improved.

Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. A formation may be selected that will produce a relatively large amount of condensable hydrocarbons and/or a relatively large amount of non-condensable hydrocarbons. Hydrocarbons within the formation may have a relatively low initial elemental oxygen weight percentage. The formation to be treated may be selected based on initial elemental oxygen to carbon ratio of the formation.

Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. After pyrolysis, the portion may be heated to a synthesis gas production temperature. A synthesis gas producing fluid may be introduced into the portion to generate synthesis gas. Synthesis gas may be produced from the formation in a batch manner or in a substantially continuous manner.

Abstract: A coal formation may be treated using an in situ thermal process. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a synthesis gas production temperature. A synthesis gas producing fluid may be introduced into the formation to generate synthesis gas. Production wells may be operated at selected temperatures to obtain a desired synthesis gas composition.

Abstract: A process for purification of an effluent that contains carbon dioxide and hydrocarbons that are produced by carbon dioxide-assisted recovery is described in which the effluent is circulated in a gas-liquid separator (3) to recover a gas that contains carbon dioxide and, for example, less than 10% of methane and ethane, and pressurized combustion (13) is produced to recover an effluent (21) that is enriched with carbon dioxide and water vapor. Effluent (21) is cooled (11) (22) to recover the heat, and the effluent that is cooled in an injection well (29) by a compressor (27) is recycled under pressure. It is possible to separate (24) the condensed water from carbon dioxide.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to a relatively impermeable formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Vaporized hydrocarbons and pyrolysis fluids may be produced from the formation.

Abstract: A process and system which integrates on-site heavy oil or bitumen upgrading and energy recovery for steam production with steam-assisted gravity drainage (SAGD) production of the heavy oil or bitumen. The heavy oil or bitumen produced by SAGD is flashed to remove the gas oil fraction, and the residue is solvent deasphalted to obtain deasphalted oil, which is mixed with the gas oil fraction to form a pumpable synthetic crude. The synthetic crude has an improvement of 4-5 degrees of API and lower in sulfur, nitrogen and metal compounds. The synthetic crude is not only more valuable than the heavy oil or bitumen, but also has substantial economic advantage of reducing the diluent requirement since it has lower viscosity than the heavy oil or bitumen. The asphaltenes, following an optional pelletizing and/or slurrying step, are used as a fuel for combustion in boilers near the steam injection wells for injection into the heavy oil or bitumen reservoir.

Abstract: The present invention provides a process for the management of H2S containing gas streams and high alkalinity water streams in which process the H2S is selectively removed from the gas stream and combusted to form an SO2 rich waste gas stream. The SO2 gas stream is then scrubbed with the water stream to substantially remove the SO2 from the gas while subsequent treatment of the water such as softening or setting is improved.

Abstract: An improved method for the recovery of hydrocarbons from a hydrocarbon deposit comprising the steps of introducing a diluent gas along a predominantly horizontal injection well drilled at the base of a hydrocarbon deposit; creating an initial communication path with a predominantly horizontal production well spaced laterally apart from the injection well; gradually enriching the diluent gas with a hydrocarbon solvent to produce a hydrocarbon solvent vapor which is saturated at reservoir conditions; continuously circulating the diluent gas and the saturated hydrocarbon solvent vapor through the hydrocarbon deposit; and producing mobilized hydrocarbons from the hydrocarbon deposit.

Abstract: A system and process for reducing the flowing bottom-hole pressure in a natural gas well has a first discrete fluid flow path extending from the surface well head through a valve to an inlet of a separator, the valve being actuable between a closed condition and an open condition, and a second discrete gas flow path extending from an outlet of the separator to an inlet of a compressor, the compressor maintaining a near or below zero PSIG pressure at the separator inlet. When the valve is in the closed condition, positive pressure builds on the well head side of the valve and, when the valve is in the open condition, the near or below zero PSIG pressure of the separator is applied to the well head.

Abstract: Methods of placing off-shore wells on production comprising the steps of separating a gas from oil or oil and water produced by the well, introducing the gas into the seawater surrounding the well at a depth where the temperature and pressure of the seawater are such that solid gas hydrates are formed when the gas is mixed with the seawater, mixing the gas with the seawater whereby the gas is converted to solid gas hydrates and depositing the solid gas hydrates on the sea floor.

Abstract: The present invention provides a process for the management of H2S containing gas streams and high alkalinity water streams in which process the H2S is selectively removed from the gas stream and combusted to form an SO2 rich waste gas stream. The SO2 gas stream is then scrubbed with the water stream to substantially remove the SO2 from the gas while subsequent treatment of the water such as softening or settling is improved.

Abstract: A method and device for separating a fluid from a formation into several fluid components in a well is disclosed. The method and device include feeding the fluid into a mainly horizontal section of pipe located in a down-hole, mainly horizontal section of the well, such that the fluid is set to flow at a speed through a length of the mainly horizontal section of pipe such that the fluid components are separated and a boundary layer is formed between the fluid components. The fluid components with a lower density are formed in a top part of the mainly horizontal section of pipe and fluid components with a higher density are formed in a bottom part of the mainly horizontal section of pipe. The fluid components with the lower density and the fluid components with the higher density are removed through separate outlets of the mainly horizontal section of pipe.

Abstract: A subsea gas separation system use in drilling an offshore well includes a subsea blowout preventor connected to the well and a gas separator connected to the blowout preventor near the seafloor. Gas released into the well bore during a well control event is removed at the separator and not returned with the drilling mud recirculated to the surface. A method offshore drilling includes a mud circulation circuit established leading down the drill string, through the drill bit, up the borehole, through a subsea pump, and to the surface through a return riser. The subsea pump is protected during critical well control events by removing gas released into the mud at a gas separator located upstream of the subsea pump and in communication with the blowout preventor.

Abstract: A subsea primary separating vessel (2,22) is installed close to the wellhead (1,31) of an oil producing well to effect primary separation of the liquid and gas phases of the fluids produced. A line (3,23) connected to the top of the separating vessel allows separated gas to flow to a gathering vessel (8,28) located at any gathering center. At least one flow line (4,5,24) connects the lower part of the separating vessel to a vessel (9,29) located at any gathering center. When the volume of liquid phase which separates out within the at least one flow line begins to exert a back pressure which adversely affects production from the well, pressurized gas can be injected into the flow line(s) for a specific period of time in order to promote the flow of liquid gas to the vessel (9,29). If it is desired that flow efficiency should be increased a mechanical interface driven by the pressurized gas may be used to encourage flow of the liquid phase.

Abstract: A wellhead device for the isolation of solid particles carried by production fluid includes a closed housing to be integrated with a wellhead element, a lining tightly fixed on the inner wall of the body producing the fluid upstream of the side outlet(s) provided with the valves, and a cylindrical partition arranged inside the housing around the lining, from which it is separated by a second ring-shaped space. First openings are provided in the upper portion of the partition above the lining, second openings are provided in the lower portion of the partition, and a filter is arranged inside the housing at the periphery of the partition lower portion, opposite the second openings. The filter is arranged such that all the fluid entering through the first partition openings into the volume separating this partition from the housing outer portion passes through the filter before entering the second ring-shaped volume through the partition second openings.

Abstract: A method for separating excess water, sludge, or both, from recovered crude petroleum oil. The method comprises adding to crude petroleum oil a composition comprising about 40 to 99 wt % of a fatty acid alkyl ester blend and about 1 to 25 wt % of at least one lower alkyl glycol ether, and then agitating the mixture.

Abstract: A method and system for removing contaminants from the phreatic zone, also known as the saturation zone, or groundwater. The technique preferably involves gas sparging while slowing down the sparging process by placing packing balls into an eductor tube. A preferred embodiment of the system is comprised of a means for supplying gas to the lower extent of a well which induces a flow of groundwater and gas bubbles up the well. The system may also contain a conduit within the well which extends below the water table. The conduit has a lower fluid-permeable section which is located below the water table and an upper fluid-permeable section which is adjacent to the water table. The system may further comprise an eductor tube contained in the conduit which extends from the top extent of the conduit to the saturation zone. Packing balls may be located between the eductor tube and the means for supplying gas to the lower extent of the well.

Abstract: Disclosed are improved methods of separation and control of drilling fluids in under-balanced drilling. The separated returning stream materials are measured and used to control the additive gas mixing process to maintain under-balanced drilling conditions. Separation is conducted at reduced pressures to improve gas separation efficiencies. Preferably, separation is performed in multiple steps of pressure drops to eliminate foaming and to enhance gas removal.

Abstract: A well production apparatus is provided for a well having a pressure control device operatively associated with the well for controlling pressure within the apparatus and well, wherein the apparatus includes a buoyant tubing member of a sufficient diameter to contain a submersible pump therein which is connected to a compressor. The apparatus further includes a gas fluids separator in the casing of the well. A fluids composition sensor and transmitter are provided for aiding in operating the apparatus.

Abstract: An apparatus for enhancing fluid and gas flow recovery in a well includes an upstream flow line communicably connected at one end to the well in a manner to receive fluid and gas therefrom, a fluid and gas separator communicably connected to another end of the upstream flow line in a manner to receive fluid and gas flow therefrom, a downstream sales flow line communicably connected to the fluid and gas separator in a manner to receive gas flow therefrom, a control valve operably disposed in the upstream flow line, a local controller device operably controllably connected to the control valve in a manner to permit regulated flow through the upstream flow line at a predetermined amount and having a communications device associated therewith, and a remote controller device having a communications device therewith, wherein the local controller device and remote controller device communicate with one another to enable remote control of the control valve.