21574 results about "Natural gas" patented technology

A method of and system for providing an incentive program for conserving a consumable resource such as electricity, natural gas, oil, air or water. The present invention monitors utilization of the resource at a location, and then determines a type and quantity of variable resource points to be provided to an account associated with the location or with a participant by analyzing the monitored resource utilization with respect to a plurality of varying conditions (time-variant, location-variant, cost-variant etc.). These conditions may be independent or interdependent; these relationships will be incorporated into the calculations resulting in the award of the type and quantity of resource points determined by the Program. The resource points are then stored in an account associated with the location or with a participant for future use.

An auction service is provided that stimulates competition between energy suppliers (i.e., electric power or natural gas). A bidding moderator (Moderator) receives bids from the competing suppliers of the rate each is willing to charge to particular end users for estimated quantities of electric power or gas supply (separate auctions). Each supplier receives competing bids from the Moderator and has the opportunity to adjust its own bids down or up, depending on whether it wants to encourage or discourage additional energy delivery commitments in a particular geographic area or to a particular customer group. Each supplier's bids can also be changed to reflect each supplier's capacity utilization. Appropriate billing arrangements are also disclosed.

The present invention is concerned with a method and computer-based system for configuring, monitoring and / or operating a graphical user interface in two or three dimensions. In particular it is concerned with a graphical user interface used for controlling, monitoring and / or operating equipment in a control system of an industrial process or an installation for oil and gas or for an installation for electrical power generating, transmission and / or distribution.

A system for hydraulically fracturing an underground formation in an oil or gas well to extract oil or gas from the formation, the oil or gas well having a wellbore that permits passage of fluid from the wellbore into the formation. The system includes a plurality of pumps powered by electric induction motors and fluidly connected to the well, the pumps configured to pump fluid into the wellbore at high pressure so that the fluid passes from the wellbore into the, and fractures the formation. The system can also include a plurality of natural gas powered generators electrically connected to the plurality of pumps to provide electrical power to the pumps.

An apparatus and method produces nitrate ions on-site from water, natural gas and air extracted in proximity to the apparatus. The apparatus generates nitrate ions and brings the nitrate ions into contact with an aqueous system. Hydrogen sulfide present in the aqueous system is removed and the production of hydrogen sulfide by sulfate-reducing bacteria (SRB) is eliminated by introducing into the system nitrate ions, whereby denitrifying microorganisms, using nitrate, outcompete the sulfate-reducing bacteria for the available carbon nutrients, thus preventing the SRB from producing hydrogen sulfide. Nitrate ions generated by the apparatus and added to the aqueous system which contains the denitrifying microorganisms can enhance oil recovery by means of microbial enhanced oil recovery mechanisms.

A system and method of communicating among devices via a piping structure using at least one induction choke about the piping structure to route a time-varying current carrying communication signals between the devices. A communications system comprises a piping structure, a first communication device, a second communication device, and an induction choke. The piping structure comprises a first location, a second location, and an electrically conductive portion extending between the first and second locations. The first and second locations are distally spaced along the piping structure. The first and second communication devices are each electrically connected to the electrically conductive portion of the piping structure along the first location and second location, respectively, and each is adapted to send and receive communication signals via time-varying current. The induction choke is located about an electrically choked portion of the electrically conductive portion of the piping structure, such that the induction choke is adapted to route time-varying current within the piping structure between the electrical connection location for the first communication device and the electrical connection location for the second communication device, and such that the first communication device can communicate with the second communication device via the piping structure. A preferred application of the present invention is a well for producing petroleum products (e.g., oil, natural gas), comprising a communication system as described above.

The invention provides apparatus and methods for monitoring and controlling hydrocarbon production wells and / or injection wells from a remote location. The apparatus for monitoring and controlling one or more hydrocarbon production wells or injection wells from a remote location comprises one or more surface control and data acquisition systems; one or more sensors disposed in communication with the one or more control and data acquisition systems; one or more downhole flow control devices disposed in communication with the one or more control and data acquisition systems; and one or more remote controllers disposed in communication with the one or more control and data acquisition systems. Preferably, the remote controller comprises a computer having an internet access disposed in communication with the one or more control and data acquisition systems through a communication device comprising an internet web site server. The method for monitoring and controlling a downhole hydrocarbon production well or an injection well comprises: transmitting data collected by a downhole sensor module to a control and data acquisition system; evaluating downhole operating conditions and optimizing downhole operating parameters utilizing an optimization software program disposed in communication with the control and data acquisition system; and transmitting signals between the control and data acquisition system system and a remote controller utilizing a satellite communication system, the remote controller comprising a computer and an internet browser control access adapted to display operating conditions and parameters and to accept instructions to change operating parameters.

A system for hydraulically fracturing an underground formation in an oil or gas well to extract oil or gas from the formation, the oil or gas well having a wellbore that permits passage of fluid from the wellbore into the formation. The system includes a plurality of electric pumps fluidly connected to the well, and configured to pump fluid into the wellbore at high pressure so that the fluid passes from the wellbore into the and fractures the formation. The system can also include a plurality of natural gas powered generators electrically connected to the plurality of electric pumps to provide electrical power to the pumps.

Downhole tools for use in oil and gas production which degrade into non-toxic materials, a method of making them and methods of using them. A frac ball and a bridge plug comprised of polyglycolic acid which can be used in fracking a well and then left in the well bore to predictably, quickly, and safely disintegrate into environmentally friendly products without needing to be milled out or retrieved.

A method of sequestering carbon dioxide and producing natural gas including: (a) injecting an injectant containing at least some amount of carbon dioxide into a zone containing natural gas hydrates; (b) releasing natural gas from the hydrates by allowing thermal transfer and pressure changes from the injectant to the hydrates; and (c) sequestering the carbon dioxide in the zone that previously contained the natural gas hydrates.

A system for stimulating oil or gas production from a wellbore includes a hydraulic fracturing pump unit having one or more hydraulic fracturing pumps driven by one or more electrical fracturing motors, a variable frequency drive (VFD) controlling the electrical fracturing motors, a fracturing pump blower unit driven by a blower motor, and a fracturing pump lubrication unit having a lubrication pump driven by a lubrication motor and a cooling fan driven by a cooling motor. The system may further include a blender unit and a hydration unit. A system control unit may control the operational parameters of the system.

A well servicing rig for communicating with a fluid source and an effluent reservoir (such as a flow back tank) has an apparatus for holding and dispensing coiled tubing. A manifold assembly is advantageously located on the rig for routing the pressurized fluid (such as nitrogen gas mixed with proppant) from the fluid source between the coiled tubing apparatus, the well and the effluent reservoir. The manifold assembly controls the flow of the fluid to perform fracturing operations, for reverse fluid circulation, for a common coiled tubing operation, for pressure testing, and the like. The assembly includes remotely controlled valves and pressure transducers for controlling the fluid flow, and chokes for diffusing fluid energy prior to entering the effluent reservoir. The rig, fluid source, effluent reservoir and a fluid pumper provide a novel method of servicing an underground formation (such as a coal bed) for natural gas.

The present invention relates to methods for separating and recovering ethane, propane and heavier components from a feed gas, e.g. raw natural gas or a refinery or petroleum plant gas stream or a petrochemical plant gas stream. These methods employ a common new concept which is the use of the turbo-expander shaft compressor to generate the reflux requirement for the cryogenic absorber or distillation columns. The power of the turbo-expander which is absorbed by the shaft compressor is always high enough so that reflux generation by a specific gas compression through the expander shaft compressor and subsequent cooling, condensation and sub-cooling can always be easily maintained. The present invention allows for higher cryogenic absorber pressure and a lower demethanizer / de-ethanizer column pressure thus eliminating the common cryogenic pump at absorber bottom. The present invention ultimately results in a lower residue compression and utilities consumption. The present invention as such allows for a higher 99+% recovery of NGL from the feed gas stream.

The process of the invention converts carbonaceous feedstock such as coal, hydrocarbon oil, natural gas, petroleum coke, oil shale, carbonaceous-containing waste oil, carbonaceous-containing medical waste, carbonaceous-containing military waste, carbonaceous-containing industrial waste, carbonaceous-containing medical waste, carbonaceous-containing sewage sludge and municipal solid waste, carbonaceous-containing agricultural waste, carbonaceous-containing biomass, biological and biochemical waste, and mixtures thereof into electrical energy without the production of unwanted greenhouse emissions. The process uses a steam / CO2 reformer operating in the exit range of at least 700° to about 1600° C. (1300-2900°0 F.) to convert the carbonaceous feedstock and a greenhouse gas stream into a synthesis gas comprising mostly carbon monoxide and hydrogen that contains poisons and the compounds that poison fuel cells. The syngas is sent to an interface zone to remove these poisons and other fouling compounds that are electrochemically oxidized in an electricity-producing fuel cell into an exit gas comprising carbon dioxide and water.

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.

A transmission line for downhole tools that make up all or part of a tool string for drilling and production of oil, gas, and geothermal wells that can withstand the dynamic gravitational forces and other accelerations associated with downhole excavations. The transmission line comprises a metal tube, or outer conductor, that houses a coaxial wire inner conductor. A non-metallic dielectric material is interposed between the inner and outer conductors. The outer and inner conductors and the dielectric are sufficiently compressed together so that independent motion between them is abated. Compression of the components of the transmission line may be achieved by drawing the transmission through one or more dies in order to draw down the outer conductor onto the dielectric, or by expanding the inner conductor against the dielectric using a mandrel or hydraulic pressure. Non-metallic bead segments may be used in aid of the compression necessary to resist the dynamic forces and accelerations of drilling.

Disclosed is a method of determining the extent of recovery of materials injected into a oil well comprising the steps of: a) preparing a material to be injected into an oil well; b) admixing therewith a chemical tracer compound at a predetermined concentration; c) injecting the admixture into an oil well; d) recovering from the oil well a production fluid; e) analyzing the production fluid for the concentration of the chemical tracer present in the production fluid; and f) calculating the amount of admixture recovered from the oil well using the concentration of the chemical tracer present in the production fluid as a basis for the calculation. Fluorinated benzoic acids are disclosed as a preferred tracer.

Methods and apparatus are disclosed for operation of a multiple fuel engine, which runs on a combination of two or more fuels. An electronic control unit (ECU) may be connected to the existing components of an engine system in order to control operation of the multiple fuel engine. The engine system may be mechanically governed or electronically controlled. The ECU inputs operating characteristics of the engine system, determines governing characteristics for multiple fuel operation based on the operating characteristics, and controls the amounts of fuel delivered to the engine based on the governing characteristics. In a preferred embodiment, a dual fuel engine operates using diesel as a first fuel and natural gas as a second fuel. The operating characteristics may include engine speed, throttle position, engine exhaust temperature, gas pressure of the second fuel, gas temperature of the second fuel, boost pressure of an intake manifold, or engine coolant temperature.

An apparatus is described for controlling flow of fluid in a tubular positioned in a wellbore extending through a subterranean formation. A flow control system is placed in fluid communication with a main tubular. The flow control system has a flow ratio control system and a pathway dependent resistance system. The flow ratio control system has a first and second passageway, the production fluid flowing into the passageways with the ratio of fluid flow through the passageways related to the characteristic of the fluid flow. The pathway dependent resistance system includes a vortex chamber with a first and second inlet and an outlet, the first inlet of the pathway dependent resistance system in fluid communication with the first passageway of the fluid ratio control system and the second inlet in fluid communication with the second passageway of the fluid ratio control system. The first inlet is positioned to direct fluid into the vortex chamber such that it flows primarily tangentially into the vortex chamber, and the second inlet is positioned to direct fluid such that it flows primarily radially into the vortex chamber. Undesired fluids, such as natural gas or water, in an oil well, are directed, based on their relative characteristic, into the vortex primarily tangentially, thereby restricting fluid flow when the undesired fluid is present as a component of the production fluid.

A system for hydraulically fracturing an underground formation in an oil or gas well to extract oil or gas from the formation, the oil or gas well having a wellbore that permits passage of fluid from the wellbore into the formation. The system includes a plurality of electric pumps fluidly connected to the well, and configured to pump fluid into the wellbore at high pressure so that the fluid passes from the wellbore into the and fractures the formation. The system can also include a plurality of natural gas powered generators electrically connected to the plurality of electric pumps to provide electrical power to the pumps.

A system for stimulating oil or gas production from a wellbore includes a hydraulic fracturing pump unit having one or more hydraulic fracturing pumps driven by one or more electrical fracturing motors, a variable frequency drive (VFD) controlling the electrical fracturing motors, a fracturing pump blower unit driven by a blower motor, and a fracturing pump lubrication unit having a lubrication pump driven by a lubrication motor and a cooling fan driven by a cooling motor. The system may further include a blender unit and a hydration unit. A system control unit may control the operational parameters of the system.

A process for in situ gasification of mineral oil in a subterranean formation comprises running a tool having a controllable thermal device therein from a surface production facility down to the subterranean formation, bringing said tool into operational proximity with the mineral oil in said subterranean formation, and activating the tool to operate the thermal device within a predetermined temperature range to generate gases or oily vapours from said mineral oil, which permits either an enhanced oil recovery (EOR) method with reduced water contamination, or a gas production process (GPP) which is useful in reducing environmental risks normally associated with transport of crude oil.

An energy monitoring and analysis system for a building includes a logging unit, a processing unit, temperature sensors that read the temperatures inside and outside the building, electric current sensors that read electric currents in all independent electric connections at the main connection panel of the building, and other types of sensors such as those related to natural gas flow. The logging unit periodically collects the data from all the sensors and transmits the data to the processing unit. The processing unit analyzes the data using highly sophisticated algorithms, extracts various parameters, profiles the electric energy usage, identifies potential problems with energy transfer and use, and lists recommendations for corrective actions. The processing unit analyzes data of the building, an HVAC system associated with the building, and consuming devices associated with the building.

Embodiments relate to hydraulic fracturing equipment powered by one or more natural gas turbine generators. Natural gas from a supply line is released via a valve into a turbine gas line. The turbine gas line includes one or more regulators to reduce the pressure of the natural gas stream in the turbine gas line to a pressure or pressure range optimum for one or more gas compressors. The gas compressors increase the pressure of the natural gas stream, which is then directed to one or more natural gas turbine generators. The natural gas turbine generators combust the natural gas to produce electricity, which powers electric hydraulic fracturing equipment.

A facility comprising integrated systems for the extraction, and optionally upgrading and / or refinement, of unconventional oil sources, using fossil fuels as a primary source of energy. In particular, this facility provides a means to gasify one or more fossil fuels in an efficient manner, converting it into intermediate products such as heat, steam and electricity, which are then used by the system to obtain useful fuel products from unconventional oil sources such as tar sands and oil shale. The design of the components of this facility is optimized such that the overall costs are competitive with an equivalent unconventional oil source processing facility that uses natural gas as a source of processing energy. The facility can be used on its own, may use supplemental natural gas energy sources, or may be used in conjunction with an existing facility that uses natural gas as an energy source in order to improve the overall cost effectiveness of the processing and / or reduce the requirement for other energy sources, such as natural gas.

Energy commodities in the form of electricity and combustible fuel (e.g. natural gas, propane) are used by appliances in a fashion which is monitored and controlled through a Premises Energy Management System (PEMS). The system facilitates direct monitoring and control of energy-consuming appliances, in real time, utilizing automated programmatic control and a plurality of human interfaces including local display and control, email, web browser, text messaging, and integrated voice response (IVR). A Monitoring and Control Coordinator (MCC) provides centralized coordination of functions and one or more Communicating Appliance Interfaces (CAI) interacting with energy consuming appliances are interconnected via wired and wireless communication networks and protocols. The system may retrieve information from third parties, such as weather services, for optimizing energy usage. An interface may be provided to the energy provider / purveyor to enhance the provision of energy by providing additional real-time services such as demand management and service outage management.

Systems, methods and devices are provided for detecting airborne particulates and / or gases at remote oil and natural gas sites, such as wells, and / or processing and refinery plants. One such system comprises an unmanned aerial vehicle (UAV), such as a drone aircraft, configured for aerial dispatch to the remote site and wireless connection to an external processor, cloud apparatus or the like. The UAV includes one or more on-board sensors configured to detect airborne particulates or gases, such as methane gas, hydrogen sulfide, hydrocarbons, weather conditions, ground-based elements or compounds or the like. The on-board sensors may comprise light transmitters, such as lasers, configured for transmitting light or laser pulses into the ambient environment around the remote site and detecting backscatter to detect the concentration and / or velocity vector(s) of the airborne particulates or gases. The UAV is further configured to wirelessly transmit data associated with the airborne particulates or gases to the external processor or cloud apparatus in real-time.