US20050072220A1 - Generator monitoring, control and efficiency - Google Patents

Generator monitoring, control and efficiency Download PDF

Info

Publication number
US20050072220A1
US20050072220A1 US10/624,302 US62430203A US2005072220A1 US 20050072220 A1 US20050072220 A1 US 20050072220A1 US 62430203 A US62430203 A US 62430203A US 2005072220 A1 US2005072220 A1 US 2005072220A1
Authority
US
United States
Prior art keywords
generator
emission
sample
monitoring
generators
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Abandoned
Application number
US10/624,302
Inventor
Stephen Staphanos
Marion Keyes
Gary Cacciatore
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Rosemount Inc
Original Assignee
Rosemount Analytical Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Rosemount Analytical Inc filed Critical Rosemount Analytical Inc
Priority to US10/624,302 priority Critical patent/US20050072220A1/en
Publication of US20050072220A1 publication Critical patent/US20050072220A1/en
Abandoned legal-status Critical Current

Links

Images

Classifications

    • GPHYSICS
    • G05CONTROLLING; REGULATING
    • G05BCONTROL OR REGULATING SYSTEMS IN GENERAL; FUNCTIONAL ELEMENTS OF SUCH SYSTEMS; MONITORING OR TESTING ARRANGEMENTS FOR SUCH SYSTEMS OR ELEMENTS
    • G05B23/00Testing or monitoring of control systems or parts thereof
    • G05B23/02Electric testing or monitoring
    • G05B23/0205Electric testing or monitoring by means of a monitoring system capable of detecting and responding to faults
    • G05B23/0259Electric testing or monitoring by means of a monitoring system capable of detecting and responding to faults characterized by the response to fault detection
    • G05B23/0286Modifications to the monitored process, e.g. stopping operation or adapting control
    • G05B23/0294Optimizing process, e.g. process efficiency, product quality
    • GPHYSICS
    • G05CONTROLLING; REGULATING
    • G05BCONTROL OR REGULATING SYSTEMS IN GENERAL; FUNCTIONAL ELEMENTS OF SUCH SYSTEMS; MONITORING OR TESTING ARRANGEMENTS FOR SUCH SYSTEMS OR ELEMENTS
    • G05B23/00Testing or monitoring of control systems or parts thereof
    • G05B23/02Electric testing or monitoring
    • G05B23/0205Electric testing or monitoring by means of a monitoring system capable of detecting and responding to faults
    • G05B23/0208Electric testing or monitoring by means of a monitoring system capable of detecting and responding to faults characterized by the configuration of the monitoring system
    • HELECTRICITY
    • H04ELECTRIC COMMUNICATION TECHNIQUE
    • H04LTRANSMISSION OF DIGITAL INFORMATION, e.g. TELEGRAPHIC COMMUNICATION
    • H04L67/00Network arrangements or protocols for supporting network services or applications
    • H04L67/2866Architectures; Arrangements
    • H04L67/30Profiles
    • H04L67/306User profiles
    • GPHYSICS
    • G05CONTROLLING; REGULATING
    • G05BCONTROL OR REGULATING SYSTEMS IN GENERAL; FUNCTIONAL ELEMENTS OF SUCH SYSTEMS; MONITORING OR TESTING ARRANGEMENTS FOR SUCH SYSTEMS OR ELEMENTS
    • G05B2223/00Indexing scheme associated with group G05B23/00
    • G05B2223/06Remote monitoring
    • YGENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02TCLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO TRANSPORTATION
    • Y02T10/00Road transport of goods or passengers
    • Y02T10/10Internal combustion engine [ICE] based vehicles
    • Y02T10/12Improving ICE efficiencies

Definitions

  • the present invention relates to monitoring and control of small-scale power generators.
  • generators include any system that converts any form of energy into electrical energy.
  • under-utilized generators can be found at facilities such as fast food restaurants, hotels, and other miscellaneous buildings. Such power systems are not used for back-up but generally run continuously or when the business is operating. However such generators are typically oversized and their demanded internal use is periodic (higher when temperature is either higher or lower due to heating or air conditioned needs, higher when more people are in the building, and generally not used when the facility is closed). On average, these resources are operated at less than approximately 50 percent capacity. Large-scale deployment of such generator is significanty limited by the lack of a cost-effective Continuous Emission Monitoring System (CEMS) solution and the economics of having to buy a system that is often twice as large as what is required.
  • CEMS Continuous Emission Monitoring System
  • a first issue relates to emissions from fossil fuel burning generators. As described above, current continuous operation of such fossil fuel burning generators is limited due to the lack of a suitable emissions monitoring system. Another challenge that must be surmounted is the large-scale monitoring, control and maintenance of such generators. Further, it is important to improve energy efficiency as much as possible in order to extract as much usable energy as possible from a given source.
  • CEMS Continuous Emission Monitoring Systems
  • a continuous emission monitoring system for small-scale fossil fuel generator systems that could be easily mounted on such generators and installed for a cost that could be justified, would facilitate enhanced emissions monitoring and use of such electrical generators.
  • Monitoring the operation of the generators would facilitate compliance with current United States Environmental Protection Agency Guidelines, thereby allowing such generators to operate full time if need be.
  • One potential use would be to allow the tens of thousands of smaller scale generators to assist in transition times where large-scale electrical generation plants are under construction.
  • the various corporations employing such generators could produce electricity with such generators and sell their excess electricity back to the energy or utility companies for transmission to others.
  • the advantages provided by these generators will only increase as technical advances are made to reduce the emissions of diesel engines and improve diesel fuels.
  • An improved continuous emissions monitoring system is disclosed that has been adapted for use with the fossil fuel burning generators.
  • the improved sample handling system for the continuous emissions monitoring emission monitoring system is much smaller than traditional sample handling systems while also significantly less expensive than such prior systems and can be set up in significantly less time that than that required for prior systems.
  • the generators are controlled through a centralized controller that provides control and reporting functions allowing cost reductions, associated with operation of such generators.
  • the dispatch, control, monitoring and optimization of such generators is done through communication means, such as the internet, an intranet, a virtual LAN, wireless communication, or any other suitable medium.
  • waste heat from the generator is recaptured and used to drive a metal hydride type heat pump system.
  • FIG. 1 is a diagrammatic view of a continuous emissions monitoring system.
  • FIG. 2 is a diagrammatic view of a typical sample handling system.
  • FIG. 3 is a diagrammatic view of a sample handling system in accordance with an embodiment of the present invention.
  • FIG. 4 is a diagrammatic view of an analyzer in accordance with an embodiment of the present invention.
  • FIG. 5 is a diagrammatic view of a power generation system in accordance with an embodiment of the present invention.
  • FIG. 6 is a diagrammatic view of a system for monitoring and controlling multiple power generating systems in accordance with an embodiment of the present invention.
  • FIG. 7 is a diagrammatic view of a power generating system and heat pump system operating in accordance with an embodiment of the invention.
  • FIG. 1 illustrates a Continuous Emission Monitoring System 10 coupled to a process container such as pipe 12 .
  • System 10 periodically, or continuously, extracts samples of exhaust gas from container 12 and analyzes such gases for constituent components. Based upon the analysis of such components, information can be obtained about the combustion process itself. Once this information is known, various parameters can be adjusted or modified in order to optimize the combustion process.
  • a Continuous Emission Monitoring System such as system 10 , includes two main components; a sample handling system and a suitable analyzer.
  • Sample handling system 14 is coupled to an analyzer 16 and is used to extract a process sample from a sampling point on process container 12 .
  • a sample handling system includes all requisite components to maintain a constant sample flow to analyzer 16 .
  • the sample handling system generally includes suitable pressure reduction components, filters, vaporizes, flow controls, and sample switching or selector valves for introducing multiple sample streams or calibration standards to the process analyzer.
  • Sample handling systems are an important component of effective emission monitoring systems because if the emission sample is not delivered to the analyzer in a condition that is representative of the combustion, errors will occur in the analysis. Many of the problems encountered in emission monitoring systems can be traced to problems occurring in the sample handling systems.
  • Analyzer 16 can include any suitable sensors and measurement techniques in order to generally quantify the presence of oxygen, oxides of nitrogen, soot, volatile organic compounds, and other substances as desired.
  • the output of analyzer 16 can be provided to a control system (which will be described in greater detail later in the specification) that makes decisions based upon the quantitative analysis and allows closed-loop control of the combustion process. For example, a parameter such as combustion air might be controlled based upon carbon monoxide content in the exhaust stream. In this manner, Continuous Emission Monitoring Systems are used to reduce emissions generated by sources by adjusting operating parameters to increase efficiency, or identify fault conditions which require repairs or system shut-down.
  • FIG. 2 is a diagrammatic view of a prior art sample handling system generally used with Continuous Emission Monitoring Systems.
  • Sample handling system 20 receives dry, oil-free instrument air at valve 22 which air is conveyed to pressure regulators 24 and 26 .
  • the regulated air from regulator 24 is provided to solenoid valve 28 which solenoid valve is controlled by energization signals from blow-back timer 30 .
  • the regulated output from pressure regulator 26 is provided to solenoid valve 32 which operates based upon an energization signal received from blow-back timer 30 .
  • the selectable air output from solenoid valve 32 operates four-way pneumatic valve 34 while the output from solenoid valve 28 provides blow-back through pneumatic four-way valve 34 .
  • Pneumatic four-way valve 34 is coupled to sample probe 36 which is adapted to couple to an emission source and receive a sample therefrom. The sample is conveyed through pneumatic four-way valve 34 to thermoelectric cooler 38 via a heated sample line 40 .
  • Heated sample line 40 is maintained at a temperature of approximately 250° F. in order to inhibit condensation of the sample flow. Since this line is heated, it is relatively costly to provide and often costs in the range of $50.00 per foot. This cost, coupled with the fact that typical heated sample line is approximately 100 to 200 feet long in order to span the distance between the sample handling system and the analyzer, creates a significant cost for the sample handling system.
  • thermoelectric cooler 38 Once the heated sample is conveyed to thermoelectric cooler 38 , the sample is cooled and condensation is allowed to drain through line 42 which is assisted by peristaltic pump 44 . The cooled sample is conveyed from thermoelectric cooler 38 to thermoelectric cooler 46 via line 48 and the assistance of sample pump 50 .
  • thermoelectric cooler 38 condensation from thermoelectric cooler 46 is drained via line 52 and the assistance of peristaltic pump 44 .
  • the doubly-cooled sample is provided from thermoelectric cooler 46 through filter 54 , through selector valve 56 , flow meter 58 , and filter 60 to analyzer 16 .
  • Sources of span gas 64 and zero gas 66 are also provided to selector valve 56 as well as pneumatic four-way valve 34 . These gases are used to provide known quantities to the analyzer to establish analyzer calibration. The complexity and costs of such a system make it not readily applicable to small scale operations such as for diesel generators.
  • system 20 includes two enclosures.
  • the first enclosure is provided at the sample point on the stack or exhaust port and is generally sized to be approximately 24 inches high by 24 inches wide by 10 inches deep and is of standard design. This enclosure is generally heated to 250° F. plus or minus approximately 10° F.
  • the first enclosure generally includes the sample probe, four-way valve which is air operated for blow-back and auto-calibration, as well as the solenoid valve.
  • the second enclosure of system 20 is generally sized to be approximately 72 inches high by 24 inches high by 30 inches deep and is also generally of NEMA 4 design.
  • the second enclosure generally includes both thermoelectric coolers, the peristaltic pumps for water drainage, the diaphragm pump for back pressure, the valves, filters, solenoid valves for auto-calibration with check valves, pressure regulators with pressure gauges for the four-way valve operation and for sample blow-back, and the flowmeter.
  • FIG. 3 is a diagrammatic view of an improved sample handling system 70 in accordance with an embodiment of the present invention.
  • System 70 is provided within a single enclosure 72 which enclosure 72 is divided into portions 74 and 76 .
  • enclosure 72 is sized to be approximately 24 inches by 24 inches by 10 inches and of NEMA 4 design. Due to the size of enclosure 72 , it can be mounted on top of an emissions stack. It is appreciated that enclosure 72 can be mounted on an exhaust port at a variety of locations.
  • Portion 74 of enclosure 72 is maintained at an elevated temperature, such as 250° F., by heater element 78 operating in conjunction with feedback from temperature sensor 80 .
  • a suitable sample probe 82 is operably coupled to a source of emissions such as via pipe 84 and the sample is conveyed through four-way valve 86 , through filter 88 , to thermoelectric cooler 90 .
  • Four-way valve 86 is also coupled to a pressurized source of air or nitrogen for blow-back.
  • the pressurized source of air or nitrogen is provided at approximately 30 pounds per square inch gauge (PSIG).
  • PSIG pounds per square inch gauge
  • four-way valve 86 can be a conventional pneumatic four-way valve, it can also be a cost-effective chromatograph multi-position valve.
  • the pressurized air/nitrogen is conveyed through pressure regulator 90 and solenoid valve 92 , both of which are generally disposed within portion 76 of housing 72 .
  • blow-back air can be selectively provided through four-way 86 .
  • a components of system 70 are provided within a single enclosure 72 , certain synergies can be achieved.
  • a single electric operator 94 can be provided in portion 76 and mechanically coupled to valve 86 .
  • electrical devices such as electric operator 94 or solenoids cannot be provided within the heated portion 74 since the heat would degrade, if not destroy, the electrical components.
  • thermoelectric cooler 90 An emission sample from sample probe 82 is conveyed through heated section 74 of enclosure 72 through four-way valve 86 , through filter 88 , to thermoelectric cooler 90 . Since thermoelectric cooler 90 is disposed relatively closely to heated portion 74 , a heated line is not required for embodiments of the present invention. Specifically, unheated sample line such as one quarter inch diameter tubing can be used to convey the sample from valve 86 to thermoelectric cooler 90 .
  • the sample tubing is formed of a chemically inert material such as polytetrafluoroethylene (PTFE) such as that available from E. I. du Pont de Nemours and Company, under the trade designation Teflon. The cost of such tubing is approximately $2.00 to $3.00 per foot.
  • PTFE polytetrafluoroethylene
  • this sample line runs from the probe enclosure to the analyzer enclosure which is generally a small 19 inch rack. Condensation from thermoelectric cooler 90 is drained with the assistance with peristaltic pump 96 , and the sample is conveyed from thermoelectric cooler 90 to the analyzer with the assistance of sample pump 98 at a rate of preferably 2 to 3 liters per minute. A back pressure relief valve 100 is also provided to relieve excess back pressure.
  • System 70 can also receive a calibration standard through line 102 which is coupled to four-way valve 86 .
  • system 70 includes check valve 104 interposed upon line 102 between the analyzer and four-way valve 86 .
  • Check valve 104 prevents contamination of the calibration line and the calibration cylinder.
  • sample handling system 70 can be easily installed or replaced in typically less than 20 minutes and is not a high maintenance item due to its simplified, efficient design.
  • System 70 can require less than one hour to install, and complete start-up can generally be achieved in less than four hours.
  • Typical sample handling systems such as that shown in FIG. 2 and described previously, generally require one week of installation and three to four days before start-up can be achieved.
  • system 70 can generally be designed to weigh less than 50 pounds thereby facilitating transportation.
  • conventional sample handling systems often weigh over 300 pounds, are bulky, large and require special transportation and special handling.
  • conventional sample handling systems require both high pressure air and electrical power.
  • system 70 as described above, requires only electrical power and low pressure nitrogen or air for blow-back.
  • system 70 can be designed to cost approximately $2,700.00 where conventional sample handling systems typically cost in the neighborhood of $16,500.00.
  • FIG. 4 is a diagrammatic view of an analyzer in accordance with an embodiment of the present invention.
  • Analyzer 200 can be used with sample handling system embodiments set forth above, such as in place of analyzer 16 , or can be used with conventional sample handling systems.
  • Analyzer 200 is generally provided within an enclosure 202 and receives sample gas through line 204 which is coupled to a sample handling system such as line 101 of sample handling system 70 (shown in FIG. 3 ).
  • analyzer 200 includes calibration source gases 206 which can be selectively provided to a sample handling system, such as sample handling system 70 via line 208 .
  • Sample gas is received on line 204 and passes through flow meter 210 which provides a signal to Central Processing Unit (CPU) 212 , which signal is related to sample gas flow passing through flowmeter 210 .
  • sample gas passes through a paramagnetic oxygen detector which is specifically adapted to measure oxygen in the 0 to 20% range and provide a signal related to oxygen concentration to CPU 212 .
  • sample gas passes through Non-Dispersive Infrared Detector 216 which provides a signal to CPU 212 that is related to carbon oxides in the 0 to 100 parts-per-million range.
  • sample gas is conveyed to Chemiluminescent nitrogen oxide detector 218 .
  • Detector 218 provides a signal to CPU 212 based upon the quantitative presence of nitrogen oxide in the 0 to 100 parts-per-million range.
  • sample gas vents through vent 220 .
  • CPU 212 receives signals from flowmeter 210 , paramagnetic oxygen detector 214 , NDIR detector 216 and Chemiluminescent detector 218 at analog inputs 222 .
  • CPU 212 may also preferably receive numerous inputs from the engine as described later.
  • Inputs 222 are coupled to a multi-channel analog-to-digital converter 224 .
  • a to D converter 224 has a relatively high resolution (20-24 bits or higher) and is used to improve signal-to-noise ratio of the underlying analytical measurements.
  • the signal-to-noise ratio can be measured online and automatically optimized by adjusting digital filter parameters either at initial setup, during auto-calibration, or continuously online.
  • CPU 212 preferably includes an embedded control system such as a PC 104 .
  • the PC includes a microprocessor operating at approximately 100 MHz.
  • CPU 212 and all other components of analyzer 200 , preferably receive electrical power via input 231 . This power is conveyed to power supply 234 which typically reduces the voltage to a 24 volt DC power supply which provides 24 volts DC to the various components of analyzer 200 .
  • the embedded PC 104 system is commercially available.
  • CPU 212 also preferably includes a display 226 , such as, a color LCD touch-pad display, a PCMCIA interface 228 , and a printer port 230 . Additionally, CPU 212 provides a number of outputs such as serial data output 232 which can provide serial data in any suitable form, such as RS232 to a customer supplied device such as a Programmable Logic Controller (PLC) or Data Acquisition System (DAS).
  • PLC Programmable Logic Controller
  • DAS Data Acquisition System
  • CPU 212 Although one output of CPU 212 is described as serial data emanating from serial port 232 , additional outputs can be provided such as, for example data in any suitable format conveyed over radio, wire, fiber-optic, or cellular phone communications. Such data can provide, for example, reports, alarms, generators/power system diagnostics, instrument diagnostics and analytical data as well as received control signals. The data can facilitate system self diagnostics and remote monitoring.
  • the computational power of CPU 212 allows the measurements provided by flowmeter 210 and detectors 214 , 216 and 218 to be used to determine process and/or power system energy and/or plant efficiency and/or capacity as will be described in greater detail below. These quantities can be used to maximize efficiency by adjusting controls using gradient-based, search-based, or other optimization techniques. This data can also be used to adjust or control the engine or generator to thereby reduce or maintain emission levels at or below environmental restrictions or other constraints.
  • CPU 212 preferably provides analog outputs in the 4 to 20 milliamp regime corresponding to oxygen percentage, carbon monoxide parts-per-million, and nitrogen oxide parts-per-million. Further still, CPU 212 can provide multiple TTL inputs and outputs. TTL inputs can be used to manually initiate auto-calibration. TTL outputs can provide signals that indicate system faults, carbon monoxide parts-per-million exceeding a selected threshold, nitrogen oxide exceeding a selected threshold, and a signal indicating that the system is in need of calibration. Further still, digital outputs relating to zero calibration, mid-point calibration, span calibration, purge control, calibration control and pump control can be provided as well.
  • sample probe 82 can be designed to use semi-permeable membranes to separate out particulates from exhaust gases to process gases to be analyzed. Additionally, a swept carrier gas can be provided proximate the semi-permeable membranes to thereby preclude direct sampling of the emission. This indirect sampling eliminates corrosion or condensation problems that result from some contact with process or exhaust gases.
  • FIG. 5 is a system block diagram of a system for generating electricity in accordance with an embodiment of the present invention.
  • Powerplant 100 includes fossil fuel engine 102 coupled to generator 104 such that operation of engine 102 generates electricity which is provided to switch-fuse 106 on line 108 .
  • Switch-fuse 106 selectively provides electricity from generator- 104 - to distribution grid 110 and provides a fusible link between the generator and the distribution grid.
  • Fossil-fuel engine 102 operates based upon a number of inputs including manual inputs and soft inputs.
  • manual inputs include a start signal such as an operator pressing a start button, a start signal being provided by a remote operator, a shut-down signal, and a throttle signal.
  • Soft inputs include data about what physically is being provided to the engine such as the fuel level, fuel consumption rate, fuel composition, fuel filter, and the fuel-air mixture.
  • emission control of engine 102 is of primary concern and thus an emission monitoring system 120 is preferably employed.
  • Emission monitoring system 120 is preferably located near engine 102 and is able to sample emissions from the exhaust stack or exhaust port and can sense emission characteristics such as oxides of nitrogen, oxides of carbon, and oxygen.
  • emission monitoring system 120 can also preferably monitor unburned fuel in the emission stream, emission volume, emission heat, and even emission noise.
  • Another parameter that can be monitored is the fuel composition itself.
  • diesel fuel is available in different mixes, and such mixes may require different engine operational characteristics.
  • system 120 can provide suitable outputs to the engine in order to ensure proper operation.
  • Emission monitoring system 120 can also be provided with engine data such as engine RPM (revolutions per minute), hours remaining before engine 102 is due for overhaul, engine throttle position, engine oil pressure, engine temperature, and engine oil level. System 120 can also receive data on the electricity generated (low power factor power).
  • engine data such as engine RPM (revolutions per minute), hours remaining before engine 102 is due for overhaul, engine throttle position, engine oil pressure, engine temperature, and engine oil level.
  • System 120 can also receive data on the electricity generated (low power factor power).
  • monitoring system employs predictive emission monitoring as set forth in U.S. Pat. No. 5,970,426, which patent is assigned to the Assignee of the present invention, and is incorporated herein by reference. Using combined predictive monitoring and, measured emission monitoring provides enhanced accuracy and maintenance. However, using either method alone allows for an element of redundancy.
  • Monitoring system 120 also preferably includes an interface to allow remote performance monitoring, control, and administration of multiple generators 100 as will be described in greater detail later in the Specification. As illustrated, emission monitoring system 120 includes a wireless interface 122 and local area network (LAN) interface 124 .
  • LAN local area network
  • node 128 includes suitable software to allow node 128 to function as an application service provider.
  • An application service provider as defined herein, is an entity, such as a business, that provides remote access to an application program across a network protocol.
  • node 128 can be designed to allow a user to simultaneously control, monitor, and calibrate simultaneous operation of a multitude of systems 100 . More importantly, embodiments of the present invention allow automated reporting to the EPA on such generator emissions, as indicated by arrow. This significantly reduces administrative costs and facilitates cost effective power generation.
  • a remote operator 152 can interface with a generator or engine through node 128 in order to monitor and control a vast array of powerplant and power grid operational characteristics and system wide controls, as indicated by arrow 154 .
  • Such characteristics include, but are not limited to, fuel consumption, electrical loading of system 100 , anticipating peak demand times, historical use of system 100 , line stability in terms of voltage fluctuation, phase balance of the produced electricity, reflections present on the power grid, operational time restrictions, reporting parameters such as sending data automatically to system owners and/or federal regulators, system maintenance report generation, emergency shut-downs, initiation of auxiliary cooling, and load-flow calculations.
  • node 128 can allow remote operator 152 to monitor characteristics of individual units such as unit fuel level, fuel capacity unit alarms, unit diagnostics, and other suitable parameters.
  • Remote operator 152 can also monitor an entire bank of systems 100 simultaneously. Such monitoring allows calculation of reserve power capacity of all generators both individually and in combination, calculation of profitability of operating individual units, the bank of units, or portions thereof, calculation of percent capacity of individual generators in use, power factor correction, and costs per kilowatt of produced electricity.
  • Remote operation and monitoring through node 128 also allows the user to activate individual systems 100 based upon external information such as the geographical location of each individual powerplant such that generation costs versus electrical transportation costs can be balanced.
  • external information such as the geographical location of each individual powerplant such that generation costs versus electrical transportation costs can be balanced.
  • An example of this is if the operator knows that a specific region is undergoing peak demand for electricity, operation of generators in that general vicinity can be initiated first based upon all parameters to thereby reduce the cost of generating and transporting electricity to that region.
  • node 128 can facilitate a payment system to automatically receive or provide payments based upon the operation of one or more generators.
  • a remote operator or the node 128 , can request fuel delivery to the powerplant either manually or automatically and specify quantity and/or quality of fuel to be delivered to each and every system 100 via electronic communication.
  • Node 128 or an individual can also generate requests for scheduled maintenance upon individual powerplants via the Internet.
  • FIG. 6 is a system block diagram of a generating system in accordance with an embodiment of the present invention.
  • System 300 includes generators 302 , each of which is coupled to the Internet 304 via local controllers 306 .
  • generators 302 can take any form including, electrical generators coupled to such primary power sources as reciprocating diesel engines, reciprocating gas engines, gas turbines, steam turbines, package boilers and waste heat boilers.
  • generator 302 can also take the form of solar-based generators, wind-based generators, fuel-cell based generators, or any other suitable device that is capable of transforming any form of potential energy into electricity.
  • local controllers 306 take the form of CPU 212 described above.
  • controllers 306 are each adapted to provide local monitoring and control intelligence for its associated generator.
  • Each of local controllers 306 is also preferably adapted to sense the phase of the power grid to which the generator is attached and control the generator such that the phase of the generated electricity matches that of the grid.
  • each of local controllers 306 is coupled to monitor and control node 308 via internet 304 .
  • Local controllers 306 can take the form of CPU 212 described above. This is simply a preferred arrangement since it allows a virtually infinite number of control nodes 308 to be coupled to generators 302 at virtually any location in the world. However, in embodiments where control node 308 is located suitably close to generators 302 , various other communications can be used.
  • generators 302 can be coupled to monitor and control node 308 via wireless, wired, or fiber optic communications. Regardless of the manner in which local controllers 306 are coupled to control node 308 , the arrangement provides for the abilities to remotely start, run and dispatch generated power to the grid from nodes 308 .
  • Generators 302 preferably include suitable detection devices such as temperature, pressure, differential pressure, mass flow and analytical detection devices to determine such quantities as composition, heating value and cost of fuel, for example. Additionally, by also measuring power output, power generation unit costs and thermal efficiency can be calculated provided to the user.
  • the data from individual generators 302 can be provided to a centralized controller such as node 308 that can be adapted to perform area monitoring and provide data to allocate the deployment, operating level, and other appropriate parameters to reduce aggregate or maximum area pollution levels or to maximize power production within an allowable area (e.g. the bubble concept) pollution levels (maximum or area aggregate average).
  • a centralized controller such as node 308 that can be adapted to perform area monitoring and provide data to allocate the deployment, operating level, and other appropriate parameters to reduce aggregate or maximum area pollution levels or to maximize power production within an allowable area (e.g. the bubble concept) pollution levels (maximum or area aggregate average).
  • LIDAR Light Detection And Ranging
  • multiple stationary environmental monitoring stations can take emissions data into a local or remote environmental quality measurement, mapping, management, control and optimization system.
  • This data can be used to automatically control and select the generators that are on-line. This ensures that only those generators that would not cause the environment to exceed established limits are operated. Alternatively, individual units could be controlled and/or selected such that the mix of generation and operating point for each resource is optimized to minimize aggregate environmental pollution.
  • Information about the combustion process in fossil-fuel based generators can also be conveyed via the Internet and calculations can be stored and performed by an Internet server or other suitable service. Further, the various devices to which CPU 212 can be coupled either directly or via a global computer network can assist in the optimization process and thereby provide communications related to optimization via an internet application service provider server.
  • the sophistication of analyzer 200 allows the entire system, including the engine to be remotely monitored and/or controlled either from a control room or even from an electrical grid in response to central energy management controls.
  • communication node 304 is illustrated as the Internet, any suitable medium can be used to couple the local controllers 306 to monitor and control node 308 .
  • the Internet is preferred because it allows a virtually infinite number of control nodes 308 to be coupled to generators 302 at virtually any location in the world.
  • communication node 304 can take a variety of forms such as internet, intranet, virtual LAN, etc.
  • the generator include a continuous emission monitoring system such as that disclosed above. Further still, it is preferred that emissions calculations for such continuous emission systems be shared among local controllers 306 or even control nodes 308 .
  • the distributed control and monitoring system illustrated in FIG. 6 facilitates acquisition of local sensor data, such as unprocessed emissions sensors and communication to additional devices such as other controllers 306 or control node(s) 308 such that a shared computing resource is used to calculate generation parameters.
  • Control node 308 can also include an application service provider as discussed above. These calculations can be used to optimize an individual generator 302 while minimizing or at least reducing its emissions. Emissions can be automatically reported to suitable authorities via the internet or other communication methods and operating data can be monitored globally via these same-communication methods.
  • embedded model-based optimization of the generating equipment can be used to minimize pollutants such as oxide nitrogen and carbon as well as maximize generating efficiency by adjusting generating equipment parameters.
  • parameters include, but are certainly not limited to, excess air, operating temperature, and timing, depending on the nature of the generating equipment.
  • various processes and techniques can be used to relate individual, or combinations of sensor information for minimization of emissions or optimization of generator efficiency.
  • maximization of generator efficiency can be done using vector gradient or other techniques known in the art.
  • This optimization can optionally run on local microprocessor(s) (such as the embedded PC's described above) and provide redundancies.
  • the optimization can be executed remotely by a server over a global network, such as the internet. The internet can also be used a back-up means for both optimization and control should the local capability be unavailable for any reason.
  • on-site measurement or monitoring of key generating equipment analytical sensors or controllers (including self-diagnosis by the equipment) can determine and report operating health of the generating equipment, sensors or controllers and conceivably even predict time to failure. Such measurements and predictions can be provided to suitable personnel to automatically dispatch such persons as well as provide data regarding parts, equipment, and other resources needed to perform the anticipated maintenance. Further, the system can provide a fail-soft capability such that when aberrant operation is detected, the controls (either local or remote) can be used to initiate particular operating modes of the generator, which modes will prolong the generator life until it can be serviced.
  • control- and optimization could be executed via a shared remote server at the dispatch site or elsewhere.
  • a remote application server provider ASP
  • ASP remote application server provider
  • any number of variables including, but not limited to, carbon monoxide levels, nitrogen oxide levels, sulfurous oxide levels and oxygen could be used to facilitate any or all of the following: emission compliance, combustion optimization, power output maximization, emission control through power source optimization, emission control by addition of suitable agents such as nitrogen oxides, adsorbents of sulfurous oxides, steam or water.
  • Any suitable variables for each generator can also be adjusted for any of the above purposes. For example, the fuel feed rate, timing, air/fuel ratio, temperature, and amount of steam injection could be varied to provide the above advantages.
  • the economics of large-scale implementation of micro power generators and controllers would be improved if the efficiency of such systems could be enhanced.
  • the waste heat flowing from the powerplant itself could be put to additional use.
  • many of the facilities listed above with excess generating capacity also employ air conditioning systems, especially in locations with warmer climates.
  • a relatively recent innovation in air conditioning systems is the hydride heat pump.
  • An example of a hydride heat pump system is set forth in U.S. Pat. No. 5,497,630.
  • a hydride heat pump system is an alternative to traditional vapor compression and absorption refrigeration systems.
  • hydride heat pump systems do not use refrigerants such as ozone-depleting chloro-fluoro-carbon refrigerants (CFC's)
  • CFC's chloro-fluoro-carbon refrigerants
  • a low temperature metal hydride (a refrigerant hydride) is coupled to a high temperature hydride (the regenerator hydride) permitting energy to be extracted from the refrigerated space.
  • the energy absorbed at low temperature during the refrigeration step dissociates hydrogen from the refrigerant hydride where it flows into the regenerator hydride, which is at a lower pressure.
  • the hydride heat pump system does not include any moving parts and operates using virtually any heat source.
  • FIG. 7 is a diagrammatic view of a power generating system and heat pump system operating in accordance with an embodiment of the invention.
  • Engine 102 is coupled to generator 104 as described previously with respect to FIG. 5 .
  • CEMS 120 is coupled to both engine 102 and generator 104 in accordance with embodiments of the invention described above.
  • FIG. 7 illustrates metal hydride heat pump system 180 thermally coupled to stack or exhaust port 12 .
  • Embodiments of the invention described herein essentially thermally couple the waste heat from the electricity generating source (engine 102 ) to hydride heat pump system 180 to take further advantage of energy otherwise lost during power generation.
  • One of the synergies created by the combination of the metal hydride heat pump system 180 and continuous emission monitoring system 120 described above is that changes and/or deteriorations in the internal chemistry, or other parameters of interest, within the metal hydride heat pump system can be detected and/or controlled.
  • This optional feature is illustrated as dashed line 182 in FIG. 7 .
  • CEMS 120 employs a number of relatively sophisticated sensors, and can easily be scaled to include additional sensors that sense parameters of interest within metal hydride heat pump system 180 .
  • the heat source for the metal hydride heat pump system is the waste stream itself flowing through stack or exhaust port 12 , it is possible to remove particular components from a combustion waste stream to thereby continually, or periodically, regenerate the internal chemistry within the metal hydride heat pump 180 .
  • maintenance of the metal hydride heat pump 180 could be reduced and the longevity thereof could be increased.

Abstract

A system for generating electricity includes a generator and an interface. The generator is coupled to the interface and provides data to the interface regarding electricity generation. The interface is coupled to a control node for monitoring and controlling the generator. The control node may be coupled to the generator through a medium such as the internet. In some aspects of the invention, a continuous emissions monitoring system is provided for fossil-fuel based generators to enhance operation and reduce emissions of such generators.

Description

    CROSS REFERENCE TO RELATED APPLICATIONS
  • This application claims the benefit of earlier-filed co-pending provisional applications: 60/269,921 entitled CONTINUOUS EMISSIONS MONITORING SYSTEM FOR DIESEL GENERATORS, filed Feb. 19, 2001; 60/270,429 entitled WEB-BASED MICRO POWERPLANT MONITOR AND CONTROL, filed Feb. 21, 2001; 60/272,924 entitled WEB-BASED MICRO POWERPLANT MONITOR AND CONTROL, filed Mar. 2, 2001; 60/276,158 entitled CENTRALIZED DISPATCH SYSTEM FOR BACK-UP POWER SYSTEM, filed Mar. 15, 2001; and 60/229,291 entitled POWER GENERATING MONITORING, CONTROL AND EFFICIENCY, filed Jun. 19, 2001. All of the above: applications are fully incorporated herein by reference.
  • BACKGROUND OF THE INVENTION
  • The present invention relates to monitoring and control of small-scale power generators.
  • Worldwide, the demand for energy continues to increase while the supply of energy, such as electricity, is not always able to keep up with the increased demand. For instance, recently the west coast of the United States has been gripped by an energy crisis as the demand for energy, and more specifically electricity, has increased faster than improvements in infrastructure and capacity. The result of this was most pronounced in Calif. where electricity producing plants have been running at virtually maximum capacity in order to provide electricity to the residents and industry of California. Even running at capacity, there have been rolling brown-outs where entire grids are provided with reduced power for a period of time. In order to remedy this problem, additional electrical power generating plants are required. However, the construction of such a large-scale electrical generating facility takes years to complete and is a very costly process. Thus, there is currently a dire need in many places, such as the west coast of the United States of America, to reduce energy consumption and to increase electrical capacity.
  • It is somewhat surprising to learn that even while the power plants operating in the western regions of the United States are running at virtually maximum capacity, they have back-up and peak generators that sit idle. These idled generators are used to provide additional electricity during peak demand. Many of these generators cannot be run full-time because they are powered by fossil fuel engines such as reciprocating diesel engines, reciprocating gas engines and gas turbines which generally produce relatively large emissions, especially if operated at less than optimal conditions. The United States Environmental Protection Agency (EPA) has promulgated rules such as 40 CFR 60, part 75, that prescribe the maximum emissions that such fossil fuel-based generators can produce. The result of this is that while many parts of the western United States wrestle with dire electrical capacity and demand., thousands of back-up and peak generators in that very region sit idle.
  • Many large facilities also have their own back-up generators to provide back-up electricity for mission critical processes if their own supply of electricity is interrupted. Examples of such facilities include large corporations, hospitals, water and waste treatment facilities, shopping centers, prisons, universities, and any other facilities where the unit cost of electricity prohibits operation during non-emergency situations. Thus, in such situations, these generators also sit idle. As used herein, generator includes any system that converts any form of energy into electrical energy.
  • Another group of under-utilized generators can be found at facilities such as fast food restaurants, hotels, and other miscellaneous buildings. Such power systems are not used for back-up but generally run continuously or when the business is operating. However such generators are typically oversized and their demanded internal use is periodic (higher when temperature is either higher or lower due to heating or air conditioned needs, higher when more people are in the building, and generally not used when the facility is closed). On average, these resources are operated at less than approximately 50 percent capacity. Large-scale deployment of such generator is significanty limited by the lack of a cost-effective Continuous Emission Monitoring System (CEMS) solution and the economics of having to buy a system that is often twice as large as what is required.
  • There are a number of technical hurdles that must be surmounted before large-scale implementation of available generators can occur. A first issue relates to emissions from fossil fuel burning generators. As described above, current continuous operation of such fossil fuel burning generators is limited due to the lack of a suitable emissions monitoring system. Another challenge that must be surmounted is the large-scale monitoring, control and maintenance of such generators. Further, it is important to improve energy efficiency as much as possible in order to extract as much usable energy as possible from a given source.
  • With respect to the emissions of fossil fuel based generators, it has been long known that fossil fuel engines such as diesel engines, also known as compression ignition engines, have high exhaust emissions. Emissions include carbon soot, carbon dioxide, volatile organic compounds, hydrocarbons and oxides of nitrogen.
  • The United States EPA is particularly concerned with emissions of diesel engines and numerous efforts are currently underway to reduce the emissions of such engines. See, for example, U.S. Pat. No. 6,173,567 to Poola et al. Currently all power generation plants are required to record emissions and allow the EPA to conduct an on-site, audit. During the audit, the EPA reviews emission data and typically requests an emission monitor calibration in their presence. To record and demonstrate calibration on each generator is an administrative burden. The cost of outfitting, calibrating and demonstrating each generator is one constraint that has heretofore prohibited effective use of such generators.
  • Regardless of the methods in which fossil fuel engines are controlled, in order to reduce exhaust emissions therefrom, it is generally necessary to somehow monitor the exhaust emissions themselves to provide a closed-loop system. The EPA does allow diesel peak generators to operate for short periods of time without monitoring of emissions, however this constraint reduces capacity. In electrical power producing plants, Continuous Emission Monitoring Systems (CEMS) are used to continuously sample exhaust emissions and analyze them for constituent components.
  • Currently, the CEMS equipment used for electrical power producing plants is wholly unsuitable for relatively small-scale generators that sit idle or are underutilized. This is because such current CEMS equipment is extremely unwieldy, often weighing over 300 pounds and requiring special transportation and special handling. Further typical CEMS sample handling systems require approximately 120 hours of assembly and can cost upwards of $16,000.00. These factors in comparison to the cost and number of individual diesel-electric generators renders current CEMS equipment, though technically feasible, wholly impractical for such smaller applications.
  • A continuous emission monitoring system for small-scale fossil fuel generator systems that could be easily mounted on such generators and installed for a cost that could be justified, would facilitate enhanced emissions monitoring and use of such electrical generators. Monitoring the operation of the generators would facilitate compliance with current United States Environmental Protection Agency Guidelines, thereby allowing such generators to operate full time if need be. One potential use would be to allow the tens of thousands of smaller scale generators to assist in transition times where large-scale electrical generation plants are under construction. Further, the various corporations employing such generators could produce electricity with such generators and sell their excess electricity back to the energy or utility companies for transmission to others. The advantages provided by these generators will only increase as technical advances are made to reduce the emissions of diesel engines and improve diesel fuels.
  • As discussed above, management and control of such generators also presents a challenge. Specifically, in order to effectively utilize the capacity provided by such generators, it is important to be able to manage such devices without having to manually monitor and adjust each and every generator during operation to comply with EPA regulations. It is also important to be able to monitor emissions from fossil-fuel based generators without being present at the generator's location, given that such generators may number in the thousands.
  • Further, the economics of large-scale implementation of such generators and controllers would be improved if the efficiency of such systems could be improved. For example, it would be beneficial if the waste heat flowing from the generator itself could be put to additional use.
  • SUMMARY OF THE INVENTION
  • An improved continuous emissions monitoring system is disclosed that has been adapted for use with the fossil fuel burning generators. The improved sample handling system for the continuous emissions monitoring emission monitoring system is much smaller than traditional sample handling systems while also significantly less expensive than such prior systems and can be set up in significantly less time that than that required for prior systems. These features will become apparent with reference to
  • In another aspect of the invention, the generators are controlled through a centralized controller that provides control and reporting functions allowing cost reductions, associated with operation of such generators. In one embodiment, the dispatch, control, monitoring and optimization of such generators is done through communication means, such as the internet, an intranet, a virtual LAN, wireless communication, or any other suitable medium.
  • In yet another aspect of the invention, waste heat from the generator is recaptured and used to drive a metal hydride type heat pump system.
  • BRIEF DESCRIPTION OF THE DRAWINGS
  • FIG. 1 is a diagrammatic view of a continuous emissions monitoring system.
  • FIG. 2 is a diagrammatic view of a typical sample handling system.
  • FIG. 3 is a diagrammatic view of a sample handling system in accordance with an embodiment of the present invention.
  • FIG. 4 is a diagrammatic view of an analyzer in accordance with an embodiment of the present invention.
  • FIG. 5 is a diagrammatic view of a power generation system in accordance with an embodiment of the present invention.
  • FIG. 6 is a diagrammatic view of a system for monitoring and controlling multiple power generating systems in accordance with an embodiment of the present invention.
  • FIG. 7 is a diagrammatic view of a power generating system and heat pump system operating in accordance with an embodiment of the invention.
  • DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS
  • The following description of the preferred embodiments is organized by function. However, the organization of the description should not be considered a limitation upon the invention, since various functions can be combined or omitted as desired.
  • Continuous Emission Monitoring System (CEMS)
  • FIG. 1 illustrates a Continuous Emission Monitoring System 10 coupled to a process container such as pipe 12. System 10 periodically, or continuously, extracts samples of exhaust gas from container 12 and analyzes such gases for constituent components. Based upon the analysis of such components, information can be obtained about the combustion process itself. Once this information is known, various parameters can be adjusted or modified in order to optimize the combustion process. Generally, a Continuous Emission Monitoring System, such as system 10, includes two main components; a sample handling system and a suitable analyzer.
  • Sample handling system 14 is coupled to an analyzer 16 and is used to extract a process sample from a sampling point on process container 12. Generally, a sample handling system includes all requisite components to maintain a constant sample flow to analyzer 16. Thus, the sample handling system generally includes suitable pressure reduction components, filters, vaporizes, flow controls, and sample switching or selector valves for introducing multiple sample streams or calibration standards to the process analyzer. Sample handling systems are an important component of effective emission monitoring systems because if the emission sample is not delivered to the analyzer in a condition that is representative of the combustion, errors will occur in the analysis. Many of the problems encountered in emission monitoring systems can be traced to problems occurring in the sample handling systems.
  • Once the emissions sample is extracted from container 12, it is provided to analyzer 16 for quantitative analysis. Analyzer 16 can include any suitable sensors and measurement techniques in order to generally quantify the presence of oxygen, oxides of nitrogen, soot, volatile organic compounds, and other substances as desired. The output of analyzer 16 can be provided to a control system (which will be described in greater detail later in the specification) that makes decisions based upon the quantitative analysis and allows closed-loop control of the combustion process. For example, a parameter such as combustion air might be controlled based upon carbon monoxide content in the exhaust stream. In this manner, Continuous Emission Monitoring Systems are used to reduce emissions generated by sources by adjusting operating parameters to increase efficiency, or identify fault conditions which require repairs or system shut-down.
  • FIG. 2 is a diagrammatic view of a prior art sample handling system generally used with Continuous Emission Monitoring Systems. Sample handling system 20 receives dry, oil-free instrument air at valve 22 which air is conveyed to pressure regulators 24 and 26. The regulated air from regulator 24 is provided to solenoid valve 28 which solenoid valve is controlled by energization signals from blow-back timer 30. The regulated output from pressure regulator 26 is provided to solenoid valve 32 which operates based upon an energization signal received from blow-back timer 30. The selectable air output from solenoid valve 32 operates four-way pneumatic valve 34 while the output from solenoid valve 28 provides blow-back through pneumatic four-way valve 34. Pneumatic four-way valve 34 is coupled to sample probe 36 which is adapted to couple to an emission source and receive a sample therefrom. The sample is conveyed through pneumatic four-way valve 34 to thermoelectric cooler 38 via a heated sample line 40.
  • Heated sample line 40 is maintained at a temperature of approximately 250° F. in order to inhibit condensation of the sample flow. Since this line is heated, it is relatively costly to provide and often costs in the range of $50.00 per foot. This cost, coupled with the fact that typical heated sample line is approximately 100 to 200 feet long in order to span the distance between the sample handling system and the analyzer, creates a significant cost for the sample handling system. Once the heated sample is conveyed to thermoelectric cooler 38, the sample is cooled and condensation is allowed to drain through line 42 which is assisted by peristaltic pump 44. The cooled sample is conveyed from thermoelectric cooler 38 to thermoelectric cooler 46 via line 48 and the assistance of sample pump 50. As with thermoelectric cooler 38, condensation from thermoelectric cooler 46 is drained via line 52 and the assistance of peristaltic pump 44. The doubly-cooled sample is provided from thermoelectric cooler 46 through filter 54, through selector valve 56, flow meter 58, and filter 60 to analyzer 16. Sources of span gas 64 and zero gas 66 are also provided to selector valve 56 as well as pneumatic four-way valve 34. These gases are used to provide known quantities to the analyzer to establish analyzer calibration. The complexity and costs of such a system make it not readily applicable to small scale operations such as for diesel generators.
  • Generally, system 20 includes two enclosures. The first enclosure is provided at the sample point on the stack or exhaust port and is generally sized to be approximately 24 inches high by 24 inches wide by 10 inches deep and is of standard design. This enclosure is generally heated to 250° F. plus or minus approximately 10° F. The first enclosure generally includes the sample probe, four-way valve which is air operated for blow-back and auto-calibration, as well as the solenoid valve. The second enclosure of system 20 is generally sized to be approximately 72 inches high by 24 inches high by 30 inches deep and is also generally of NEMA 4 design. The second enclosure generally includes both thermoelectric coolers, the peristaltic pumps for water drainage, the diaphragm pump for back pressure, the valves, filters, solenoid valves for auto-calibration with check valves, pressure regulators with pressure gauges for the four-way valve operation and for sample blow-back, and the flowmeter. Thus, it is apparent that the heated sample is conveyed from the first enclosure to the second enclosure and thus a suitable amount of heated sample line must be conveyed to span the distance between these two enclosures. This is a costly process since a typical span can range between 100 and 200 feet. At $50.00/foot, the tubing alone can cost between five and ten thousand dollars.
  • FIG. 3 is a diagrammatic view of an improved sample handling system 70 in accordance with an embodiment of the present invention. System 70 is provided within a single enclosure 72 which enclosure 72 is divided into portions 74 and 76. Preferably enclosure 72 is sized to be approximately 24 inches by 24 inches by 10 inches and of NEMA 4 design. Due to the size of enclosure 72, it can be mounted on top of an emissions stack. It is appreciated that enclosure 72 can be mounted on an exhaust port at a variety of locations. Portion 74 of enclosure 72 is maintained at an elevated temperature, such as 250° F., by heater element 78 operating in conjunction with feedback from temperature sensor 80. A suitable sample probe 82 is operably coupled to a source of emissions such as via pipe 84 and the sample is conveyed through four-way valve 86, through filter 88, to thermoelectric cooler 90. Four-way valve 86 is also coupled to a pressurized source of air or nitrogen for blow-back. Preferably, the pressurized source of air or nitrogen is provided at approximately 30 pounds per square inch gauge (PSIG). Although four-way valve 86 can be a conventional pneumatic four-way valve, it can also be a cost-effective chromatograph multi-position valve. The pressurized air/nitrogen is conveyed through pressure regulator 90 and solenoid valve 92, both of which are generally disposed within portion 76 of housing 72. As such, blow-back air can be selectively provided through four-way 86. Those skilled in the art will recognize since a components of system 70 are provided within a single enclosure 72, certain synergies can be achieved. Specifically, where previously four-way valve 86 was a pneumatic valve operated by pneumatic signals generated by multiple solenoids, a single electric operator 94 can be provided in portion 76 and mechanically coupled to valve 86. Generally, electrical devices such as electric operator 94 or solenoids cannot be provided within the heated portion 74 since the heat would degrade, if not destroy, the electrical components.
  • An emission sample from sample probe 82 is conveyed through heated section 74 of enclosure 72 through four-way valve 86, through filter 88, to thermoelectric cooler 90. Since thermoelectric cooler 90 is disposed relatively closely to heated portion 74, a heated line is not required for embodiments of the present invention. Specifically, unheated sample line such as one quarter inch diameter tubing can be used to convey the sample from valve 86 to thermoelectric cooler 90. Preferably, the sample tubing is formed of a chemically inert material such as polytetrafluoroethylene (PTFE) such as that available from E. I. du Pont de Nemours and Company, under the trade designation Teflon. The cost of such tubing is approximately $2.00 to $3.00 per foot. Preferably, this sample line runs from the probe enclosure to the analyzer enclosure which is generally a small 19 inch rack. Condensation from thermoelectric cooler 90 is drained with the assistance with peristaltic pump 96, and the sample is conveyed from thermoelectric cooler 90 to the analyzer with the assistance of sample pump 98 at a rate of preferably 2 to 3 liters per minute. A back pressure relief valve 100 is also provided to relieve excess back pressure.
  • System 70 can also receive a calibration standard through line 102 which is coupled to four-way valve 86. Preferably, system 70 includes check valve 104 interposed upon line 102 between the analyzer and four-way valve 86. Check valve 104 prevents contamination of the calibration line and the calibration cylinder.
  • The above-described sample handling system 70 can be easily installed or replaced in typically less than 20 minutes and is not a high maintenance item due to its simplified, efficient design. System 70 can require less than one hour to install, and complete start-up can generally be achieved in less than four hours. Typical sample handling systems such as that shown in FIG. 2 and described previously, generally require one week of installation and three to four days before start-up can be achieved. Moreover, system 70 can generally be designed to weigh less than 50 pounds thereby facilitating transportation. In contrast, conventional sample handling systems often weigh over 300 pounds, are bulky, large and require special transportation and special handling. Further still, conventional sample handling systems require both high pressure air and electrical power. In contrast, system 70, as described above, requires only electrical power and low pressure nitrogen or air for blow-back. As an illustration of the improved, simplified design of embodiments of the present invention, system 70 can be designed to cost approximately $2,700.00 where conventional sample handling systems typically cost in the neighborhood of $16,500.00.
  • FIG. 4 is a diagrammatic view of an analyzer in accordance with an embodiment of the present invention. Analyzer 200 can be used with sample handling system embodiments set forth above, such as in place of analyzer 16, or can be used with conventional sample handling systems. Analyzer 200 is generally provided within an enclosure 202 and receives sample gas through line 204 which is coupled to a sample handling system such as line 101 of sample handling system 70 (shown in FIG. 3). Additionally, analyzer 200 includes calibration source gases 206 which can be selectively provided to a sample handling system, such as sample handling system 70 via line 208. Sample gas is received on line 204 and passes through flow meter 210 which provides a signal to Central Processing Unit (CPU) 212, which signal is related to sample gas flow passing through flowmeter 210. In one embodiment, after passing through flowmeter 210, sample gas passes through a paramagnetic oxygen detector which is specifically adapted to measure oxygen in the 0 to 20% range and provide a signal related to oxygen concentration to CPU 212. After passing through oxygen detector 214, sample gas passes through Non-Dispersive Infrared Detector 216 which provides a signal to CPU 212 that is related to carbon oxides in the 0 to 100 parts-per-million range. Finally, sample gas is conveyed to Chemiluminescent nitrogen oxide detector 218. Detector 218 provides a signal to CPU 212 based upon the quantitative presence of nitrogen oxide in the 0 to 100 parts-per-million range. After passing through detector 218, sample gas vents through vent 220.
  • In this embodiment, CPU 212 receives signals from flowmeter 210, paramagnetic oxygen detector 214, NDIR detector 216 and Chemiluminescent detector 218 at analog inputs 222. CPU 212 may also preferably receive numerous inputs from the engine as described later. Inputs 222 are coupled to a multi-channel analog-to-digital converter 224. Preferably A to D converter 224 has a relatively high resolution (20-24 bits or higher) and is used to improve signal-to-noise ratio of the underlying analytical measurements. The signal-to-noise ratio can be measured online and automatically optimized by adjusting digital filter parameters either at initial setup, during auto-calibration, or continuously online.
  • CPU 212 preferably includes an embedded control system such as a PC 104. In this particular embodiment, the PC includes a microprocessor operating at approximately 100 MHz. CPU 212, and all other components of analyzer 200, preferably receive electrical power via input 231. This power is conveyed to power supply 234 which typically reduces the voltage to a 24 volt DC power supply which provides 24 volts DC to the various components of analyzer 200. The embedded PC 104 system is commercially available. CPU 212 also preferably includes a display 226, such as, a color LCD touch-pad display, a PCMCIA interface 228, and a printer port 230. Additionally, CPU 212 provides a number of outputs such as serial data output 232 which can provide serial data in any suitable form, such as RS232 to a customer supplied device such as a Programmable Logic Controller (PLC) or Data Acquisition System (DAS).
  • Although one output of CPU 212 is described as serial data emanating from serial port 232, additional outputs can be provided such as, for example data in any suitable format conveyed over radio, wire, fiber-optic, or cellular phone communications. Such data can provide, for example, reports, alarms, generators/power system diagnostics, instrument diagnostics and analytical data as well as received control signals. The data can facilitate system self diagnostics and remote monitoring. The computational power of CPU 212 allows the measurements provided by flowmeter 210 and detectors 214, 216 and 218 to be used to determine process and/or power system energy and/or plant efficiency and/or capacity as will be described in greater detail below. These quantities can be used to maximize efficiency by adjusting controls using gradient-based, search-based, or other optimization techniques. This data can also be used to adjust or control the engine or generator to thereby reduce or maintain emission levels at or below environmental restrictions or other constraints.
  • In one embodiment, CPU 212 preferably provides analog outputs in the 4 to 20 milliamp regime corresponding to oxygen percentage, carbon monoxide parts-per-million, and nitrogen oxide parts-per-million. Further still, CPU 212 can provide multiple TTL inputs and outputs. TTL inputs can be used to manually initiate auto-calibration. TTL outputs can provide signals that indicate system faults, carbon monoxide parts-per-million exceeding a selected threshold, nitrogen oxide exceeding a selected threshold, and a signal indicating that the system is in need of calibration. Further still, digital outputs relating to zero calibration, mid-point calibration, span calibration, purge control, calibration control and pump control can be provided as well.
  • Although the sample probe used for embodiments of the present invention can include conventional sample probes, sample probe 82 can be designed to use semi-permeable membranes to separate out particulates from exhaust gases to process gases to be analyzed. Additionally, a swept carrier gas can be provided proximate the semi-permeable membranes to thereby preclude direct sampling of the emission. This indirect sampling eliminates corrosion or condensation problems that result from some contact with process or exhaust gases.
  • Control and Operation
  • FIG. 5 is a system block diagram of a system for generating electricity in accordance with an embodiment of the present invention. Powerplant 100 includes fossil fuel engine 102 coupled to generator 104 such that operation of engine 102 generates electricity which is provided to switch-fuse 106 on line 108. Switch-fuse 106 selectively provides electricity from generator-104- to distribution grid 110 and provides a fusible link between the generator and the distribution grid.
  • Fossil-fuel engine 102 operates based upon a number of inputs including manual inputs and soft inputs. Examples of manual inputs include a start signal such as an operator pressing a start button, a start signal being provided by a remote operator, a shut-down signal, and a throttle signal. Examples of Soft inputs include data about what physically is being provided to the engine such as the fuel level, fuel consumption rate, fuel composition, fuel filter, and the fuel-air mixture. As described above, emission control of engine 102 is of primary concern and thus an emission monitoring system 120 is preferably employed.
  • Emission monitoring system 120 is preferably located near engine 102 and is able to sample emissions from the exhaust stack or exhaust port and can sense emission characteristics such as oxides of nitrogen, oxides of carbon, and oxygen.
  • Further, emission monitoring system 120 can also preferably monitor unburned fuel in the emission stream, emission volume, emission heat, and even emission noise. Another parameter that can be monitored is the fuel composition itself. For example, diesel fuel is available in different mixes, and such mixes may require different engine operational characteristics. By determining fuel composition, system 120 can provide suitable outputs to the engine in order to ensure proper operation.
  • Emission monitoring system 120 can also be provided with engine data such as engine RPM (revolutions per minute), hours remaining before engine 102 is due for overhaul, engine throttle position, engine oil pressure, engine temperature, and engine oil level. System 120 can also receive data on the electricity generated (low power factor power).
  • Preferably, monitoring system employs predictive emission monitoring as set forth in U.S. Pat. No. 5,970,426, which patent is assigned to the Assignee of the present invention, and is incorporated herein by reference. Using combined predictive monitoring and, measured emission monitoring provides enhanced accuracy and maintenance. However, using either method alone allows for an element of redundancy. Monitoring system 120 also preferably includes an interface to allow remote performance monitoring, control, and administration of multiple generators 100 as will be described in greater detail later in the Specification. As illustrated, emission monitoring system 120 includes a wireless interface 122 and local area network (LAN) interface 124. Those skilled in the art will appreciate that a number of options exist for communicating with remote locations, and all such options are expressly contemplated. One feature which facilitates remote operation and administration of such generators or powerplants is that at least one of interfaces 122 and 124 is coupled to a global computer network such as the Internet 126.
  • This arrangement allows remote monitoring and control node 128 to couple to engine 102 and generator 104 via an internet service provider 130. Preferably, node 128 includes suitable software to allow node 128 to function as an application service provider. An application service provider, as defined herein, is an entity, such as a business, that provides remote access to an application program across a network protocol. Moreover, node 128 can be designed to allow a user to simultaneously control, monitor, and calibrate simultaneous operation of a multitude of systems 100. More importantly, embodiments of the present invention allow automated reporting to the EPA on such generator emissions, as indicated by arrow. This significantly reduces administrative costs and facilitates cost effective power generation. Using the data provided to monitoring system 120, a remote operator 152 can interface with a generator or engine through node 128 in order to monitor and control a vast array of powerplant and power grid operational characteristics and system wide controls, as indicated by arrow 154. Such characteristics include, but are not limited to, fuel consumption, electrical loading of system 100, anticipating peak demand times, historical use of system 100, line stability in terms of voltage fluctuation, phase balance of the produced electricity, reflections present on the power grid, operational time restrictions, reporting parameters such as sending data automatically to system owners and/or federal regulators, system maintenance report generation, emergency shut-downs, initiation of auxiliary cooling, and load-flow calculations. Further still, node 128 can allow remote operator 152 to monitor characteristics of individual units such as unit fuel level, fuel capacity unit alarms, unit diagnostics, and other suitable parameters.
  • Remote operator 152 can also monitor an entire bank of systems 100 simultaneously. Such monitoring allows calculation of reserve power capacity of all generators both individually and in combination, calculation of profitability of operating individual units, the bank of units, or portions thereof, calculation of percent capacity of individual generators in use, power factor correction, and costs per kilowatt of produced electricity.
  • Remote operation and monitoring through node 128 also allows the user to activate individual systems 100 based upon external information such as the geographical location of each individual powerplant such that generation costs versus electrical transportation costs can be balanced. An example of this is if the operator knows that a specific region is undergoing peak demand for electricity, operation of generators in that general vicinity can be initiated first based upon all parameters to thereby reduce the cost of generating and transporting electricity to that region. By understanding operational costs such as fuel consumption and system maintenance cost, node 128 can facilitate a payment system to automatically receive or provide payments based upon the operation of one or more generators. Finally, a remote operator, or the node 128, can request fuel delivery to the powerplant either manually or automatically and specify quantity and/or quality of fuel to be delivered to each and every system 100 via electronic communication. Node 128 or an individual can also generate requests for scheduled maintenance upon individual powerplants via the Internet.
  • Distributed Monitoring and Control
  • FIG. 6 is a system block diagram of a generating system in accordance with an embodiment of the present invention. System 300 includes generators 302, each of which is coupled to the Internet 304 via local controllers 306. Although each of generators 302 is illustrated diagrammatically as a small power plant, in reality such generators can take any form including, electrical generators coupled to such primary power sources as reciprocating diesel engines, reciprocating gas engines, gas turbines, steam turbines, package boilers and waste heat boilers. Further, generator 302 can also take the form of solar-based generators, wind-based generators, fuel-cell based generators, or any other suitable device that is capable of transforming any form of potential energy into electricity. Preferably, local controllers 306 take the form of CPU 212 described above. Thus, controllers 306 are each adapted to provide local monitoring and control intelligence for its associated generator. Each of local controllers 306 is also preferably adapted to sense the phase of the power grid to which the generator is attached and control the generator such that the phase of the generated electricity matches that of the grid. As illustrated in FIG. 6, each of local controllers 306 is coupled to monitor and control node 308 via internet 304. Local controllers 306 can take the form of CPU 212 described above. This is simply a preferred arrangement since it allows a virtually infinite number of control nodes 308 to be coupled to generators 302 at virtually any location in the world. However, in embodiments where control node 308 is located suitably close to generators 302, various other communications can be used. For example, generators 302 can be coupled to monitor and control node 308 via wireless, wired, or fiber optic communications. Regardless of the manner in which local controllers 306 are coupled to control node 308, the arrangement provides for the abilities to remotely start, run and dispatch generated power to the grid from nodes 308. Generators 302 preferably include suitable detection devices such as temperature, pressure, differential pressure, mass flow and analytical detection devices to determine such quantities as composition, heating value and cost of fuel, for example. Additionally, by also measuring power output, power generation unit costs and thermal efficiency can be calculated provided to the user.
  • Using the improved dispatch, control, and monitoring system in accordance with embodiments of the present invention facilitates high-level emission monitoring and control. For example, the data from individual generators 302 can be provided to a centralized controller such as node 308 that can be adapted to perform area monitoring and provide data to allocate the deployment, operating level, and other appropriate parameters to reduce aggregate or maximum area pollution levels or to maximize power production within an allowable area (e.g. the bubble concept) pollution levels (maximum or area aggregate average). Further still, Light Detection And Ranging (LIDAR)-scanning environmental quality monitoring equipment and/or multiple stationary environmental monitoring stations (not shown) can take emissions data into a local or remote environmental quality measurement, mapping, management, control and optimization system. This data can be used to automatically control and select the generators that are on-line. This ensures that only those generators that would not cause the environment to exceed established limits are operated. Alternatively, individual units could be controlled and/or selected such that the mix of generation and operating point for each resource is optimized to minimize aggregate environmental pollution.
  • Information about the combustion process in fossil-fuel based generators can also be conveyed via the Internet and calculations can be stored and performed by an Internet server or other suitable service. Further, the various devices to which CPU 212 can be coupled either directly or via a global computer network can assist in the optimization process and thereby provide communications related to optimization via an internet application service provider server. The sophistication of analyzer 200 allows the entire system, including the engine to be remotely monitored and/or controlled either from a control room or even from an electrical grid in response to central energy management controls.
  • Although communication node 304 is illustrated as the Internet, any suitable medium can be used to couple the local controllers 306 to monitor and control node 308. The Internet is preferred because it allows a virtually infinite number of control nodes 308 to be coupled to generators 302 at virtually any location in the world. However, communication node 304 can take a variety of forms such as internet, intranet, virtual LAN, etc.
  • For embodiments where the primary power source for a generator is based upon fossil-fuel combustion, it is preferred that the generator include a continuous emission monitoring system such as that disclosed above. Further still, it is preferred that emissions calculations for such continuous emission systems be shared among local controllers 306 or even control nodes 308. Those skilled in the art will recognize that the distributed control and monitoring system illustrated in FIG. 6 facilitates acquisition of local sensor data, such as unprocessed emissions sensors and communication to additional devices such as other controllers 306 or control node(s) 308 such that a shared computing resource is used to calculate generation parameters. Control node 308 can also include an application service provider as discussed above. These calculations can be used to optimize an individual generator 302 while minimizing or at least reducing its emissions. Emissions can be automatically reported to suitable authorities via the internet or other communication methods and operating data can be monitored globally via these same-communication methods.
  • It is appreciated that the above-described system can be used to facilitate various optimizations in generator operation. For example, embedded model-based optimization of the generating equipment can be used to minimize pollutants such as oxide nitrogen and carbon as well as maximize generating efficiency by adjusting generating equipment parameters. Such parameters include, but are certainly not limited to, excess air, operating temperature, and timing, depending on the nature of the generating equipment. As described above, various processes and techniques can be used to relate individual, or combinations of sensor information for minimization of emissions or optimization of generator efficiency. Such maximization of generator efficiency can be done using vector gradient or other techniques known in the art. This optimization can optionally run on local microprocessor(s) (such as the embedded PC's described above) and provide redundancies. Alternately, the optimization can be executed remotely by a server over a global network, such as the internet. The internet can also be used a back-up means for both optimization and control should the local capability be unavailable for any reason.
  • Further, on-site measurement or monitoring of key generating equipment, analytical sensors or controllers (including self-diagnosis by the equipment) can determine and report operating health of the generating equipment, sensors or controllers and conceivably even predict time to failure. Such measurements and predictions can be provided to suitable personnel to automatically dispatch such persons as well as provide data regarding parts, equipment, and other resources needed to perform the anticipated maintenance. Further, the system can provide a fail-soft capability such that when aberrant operation is detected, the controls (either local or remote) can be used to initiate particular operating modes of the generator, which modes will prolong the generator life until it can be serviced.
  • Alternatively, the control- and optimization could be executed via a shared remote server at the dispatch site or elsewhere. Another alternative is to utilize a remote application server provider (ASP) to execute the control and optimization and CEMS calculations, and reporting, monitoring (alarms, operator guides, etc.) and to deliver such control, optimization and monitoring information via the internet, virtual LAN, or other communication means.
  • Although embodiments have been described with respect to specific process variables being used for generator optimization, it is expressly contemplated that any number of variables including, but not limited to, carbon monoxide levels, nitrogen oxide levels, sulfurous oxide levels and oxygen could be used to facilitate any or all of the following: emission compliance, combustion optimization, power output maximization, emission control through power source optimization, emission control by addition of suitable agents such as nitrogen oxides, adsorbents of sulfurous oxides, steam or water. Any suitable variables for each generator can also be adjusted for any of the above purposes. For example, the fuel feed rate, timing, air/fuel ratio, temperature, and amount of steam injection could be varied to provide the above advantages.
  • Efficiency
  • The economics of large-scale implementation of micro power generators and controllers would be improved if the efficiency of such systems could be enhanced. Pursuant to another aspect of this invention, the waste heat flowing from the powerplant itself could be put to additional use. For example, many of the facilities listed above with excess generating capacity, also employ air conditioning systems, especially in locations with warmer climates. A relatively recent innovation in air conditioning systems is the hydride heat pump. An example of a hydride heat pump system is set forth in U.S. Pat. No. 5,497,630. A hydride heat pump system is an alternative to traditional vapor compression and absorption refrigeration systems. One of the primary advantages of hydride heat pump systems is that they do not use refrigerants such as ozone-depleting chloro-fluoro-carbon refrigerants (CFC's) In hydride heat pump systems, a low temperature metal hydride. (a refrigerant hydride) is coupled to a high temperature hydride (the regenerator hydride) permitting energy to be extracted from the refrigerated space. The energy absorbed at low temperature during the refrigeration step dissociates hydrogen from the refrigerant hydride where it flows into the regenerator hydride, which is at a lower pressure. The hydride heat pump system does not include any moving parts and operates using virtually any heat source.
  • FIG. 7 is a diagrammatic view of a power generating system and heat pump system operating in accordance with an embodiment of the invention. Engine 102 is coupled to generator 104 as described previously with respect to FIG. 5. CEMS 120 is coupled to both engine 102 and generator 104 in accordance with embodiments of the invention described above. Unlike previous embodiments, however, FIG. 7 illustrates metal hydride heat pump system 180 thermally coupled to stack or exhaust port 12. Embodiments of the invention described herein essentially thermally couple the waste heat from the electricity generating source (engine 102) to hydride heat pump system 180 to take further advantage of energy otherwise lost during power generation.
  • One of the synergies created by the combination of the metal hydride heat pump system 180 and continuous emission monitoring system 120 described above is that changes and/or deteriorations in the internal chemistry, or other parameters of interest, within the metal hydride heat pump system can be detected and/or controlled. This optional feature is illustrated as dashed line 182 in FIG. 7. CEMS 120 employs a number of relatively sophisticated sensors, and can easily be scaled to include additional sensors that sense parameters of interest within metal hydride heat pump system 180. Moreover, since the heat source for the metal hydride heat pump system is the waste stream itself flowing through stack or exhaust port 12, it is possible to remove particular components from a combustion waste stream to thereby continually, or periodically, regenerate the internal chemistry within the metal hydride heat pump 180. Thus, maintenance of the metal hydride heat pump 180 could be reduced and the longevity thereof could be increased.
  • Although the invention has been described with reference to preferred embodiments, workers skilled in the art will recognize that changes can be made in form and detail without departing from the spirit and scope of the invention.

Claims (36)

1. A Continuous Emission Monitoring System for fossil fuel based generators, the system comprising:
an analyzer adapted to receive a sample flow and provide an output indicative of at least one constituent of the sample flow;
a sample handling system coupleable to an emission source and adapted to extract an emission sample from the sample source and provide the extracted emission sample to the sample analyzer; and
wherein the sample handling system is embodied within a single enclosure.
2. The system of claim 1 wherein the single enclosure has two compartments which are maintained at different temperatures with respect to one another.
3. The system of claim 2, wherein the first compartment includes a sample probe and valve, and wherein the first compartment is maintained at an elevated temperature, and wherein the second compartment includes a thermoelectric cooler.
4. The system of claim 3, wherein non-heated tubing connects the valve to the thermoelectric cooler.
5. The system of claim 1 wherein polytetrafluoroethylene tubing conveys a sample from a sample probe to the analyzer.
6. A distributed control and monitoring system comprising:
an emission monitoring system coupleable to a fossil fuel engine and an electric generator, the emission monitoring system for acquiring emission monitoring data; and
a remote access node coupled to the emission monitoring system through a computer network, the node allowing remote access to the fossil fuel engine and the generator output.
7. The system of claim 6, wherein the remote access node comprises a remote monitoring and control node.
8. The system of claim 6, wherein the system is adapted to self-diagnose and provide one or more alerts based on the self-diagnostics.
9. The system of claim 6, wherein the emission monitoring system further acquires generator data.
10. The system of claim 6, wherein the emission monitoring system further acquires power generation data.
11. The system of claim 6, wherein the emission monitoring system further acquires fuel data.
12. The system of claim 6, wherein the remote monitoring and control system reports emission data to a selected entity.
13. The apparatus of claim 6 and further comprising;
a second emission monitoring system coupleable to a second diesel-electric generator providing emissions information to the user interface via the computer network.
14. An electricity generation system comprising:
a first generator;
a first controller coupled to the first generator;
a second generator;
a second controller coupled to the second generator; and
a remote control and monitoring node coupled to the first and second controllers to monitor and control the first and second generators.
15. The system of claim 14, wherein the first generator includes a primary power source selected from a group consisting of a reciprocating diesel engine, reciprocating gas engine, gas turbine, steam turbine, package boiler, and waste heat boiler.
16. The system of claim 14, wherein the first controller includes an embedded personal computer (PC) controller.
17. The system of claim 14, wherein the first controller provides local monitoring and control relative to the first generator.
18. The system of claim 14, wherein the first controller senses a phase of electricity in a power grid to match a phase of electricity generated by the first generator to that of the power grid.
19. The system of claim 14, wherein the node is coupled to the first and second-controllers through a communication medium selected from the group consisting of a wireless interface, a local area network interface, a wide area network interface, and a fiberoptic link.
20. The system of claim 14, wherein the control node includes an Application Service.
21. The system of claim 14, wherein the first generator is a fossil-fuel based generator and the first controller comprises a continuous emissions monitoring system.
22. The system of claim 21, wherein the first controller measures power output of the first generator.
23. The system of claim 22, wherein the first controller measured power generation cost of the first generator.
24. The system of claim 22, wherein the first controller measures thermal efficiency of the first generator.
25. The system of claim 21, wherein the first controller is adapted to receive data indicative of a parameter of the first generator, and provide an input to the first generator based upon an optimization algorithm.
26. The system of claim 25, wherein the parameter is selected from the group consisting of exhaust gas composition, unburned fuel in an emission stream, emission volume, emission heat, emission noise, engine speed engine hours remaining before maintenance, engine throttle position, engine oil pressure, engine temperature, engine oil level and fuel composition.
27. The system of claim 25, wherein the input is selected from the group consisting of a start signal, a shut-down signal, and a throttle signal.
28. The system of claim 14, wherein the control node is adapted to report data relative to the system.
29. The system of claim 28, wherein the data facilitates area monitoring.
30. The system of claim 29, wherein the node adjusts the first and second generators through their respective controllers to reduce aggregate pollution.
31. The system of claim 14, and further comprising Light Detection and Ranging (LIDAR) equipment adapted to monitor an environment of the first generator.
32. A system for generating electricity comprising:
a generator adapted to receive fuel and generate electricity and waste heat; and
a metal hydride heat pump coupled to the generator to receive the waste heat to provide cooling.
33. The system of claim 32, wherein the cooling is provided as an air conditioning system.
34. The system of claim 32, wherein the generator is a fossil-fuel based generator.
35. The system of claim 34, and further comprising a continuous emissions monitoring system coupled to the generator and the heat pump and provide control of at least one of the generator and the heat pump based upon a chemical analysis of a monitored species.
36. The system of claim 35, wherein the monitored species is present in exhaust gas from the generator.
US10/624,302 2001-02-19 2003-07-22 Generator monitoring, control and efficiency Abandoned US20050072220A1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US10/624,302 US20050072220A1 (en) 2001-02-19 2003-07-22 Generator monitoring, control and efficiency

Applications Claiming Priority (7)

Application Number Priority Date Filing Date Title
US26992101P 2001-02-19 2001-02-19
US27042901P 2001-02-21 2001-02-21
US27292401P 2001-03-02 2001-03-02
US27615801P 2001-03-15 2001-03-15
US29929101P 2001-06-19 2001-06-19
US10/079,054 US6912889B2 (en) 2001-02-19 2002-02-18 Generator monitoring, control and efficiency
US10/624,302 US20050072220A1 (en) 2001-02-19 2003-07-22 Generator monitoring, control and efficiency

Related Parent Applications (1)

Application Number Title Priority Date Filing Date
US10/079,054 Division US6912889B2 (en) 2001-02-19 2002-02-18 Generator monitoring, control and efficiency

Publications (1)

Publication Number Publication Date
US20050072220A1 true US20050072220A1 (en) 2005-04-07

Family

ID=27540526

Family Applications (4)

Application Number Title Priority Date Filing Date
US10/079,054 Expired - Fee Related US6912889B2 (en) 2001-02-19 2002-02-18 Generator monitoring, control and efficiency
US10/624,302 Abandoned US20050072220A1 (en) 2001-02-19 2003-07-22 Generator monitoring, control and efficiency
US10/624,301 Abandoned US20050188745A1 (en) 2001-02-19 2003-07-22 Generator monitoring, control and efficiency
US10/624,300 Expired - Fee Related US6983640B1 (en) 2001-02-19 2003-07-22 Generator monitoring, control and efficiency

Family Applications Before (1)

Application Number Title Priority Date Filing Date
US10/079,054 Expired - Fee Related US6912889B2 (en) 2001-02-19 2002-02-18 Generator monitoring, control and efficiency

Family Applications After (2)

Application Number Title Priority Date Filing Date
US10/624,301 Abandoned US20050188745A1 (en) 2001-02-19 2003-07-22 Generator monitoring, control and efficiency
US10/624,300 Expired - Fee Related US6983640B1 (en) 2001-02-19 2003-07-22 Generator monitoring, control and efficiency

Country Status (5)

Country Link
US (4) US6912889B2 (en)
EP (1) EP1381762A2 (en)
AU (1) AU2002244045A1 (en)
CA (1) CA2438735A1 (en)
WO (1) WO2002066974A2 (en)

Cited By (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20050033481A1 (en) * 2003-08-08 2005-02-10 Budhraja Vikram S. Real-time performance monitoring and management system
US20090307233A1 (en) * 2008-06-02 2009-12-10 Guorui Zhang Efficient Handling of PMU Data for Wide Area Power System Monitoring and Visualization
US8670224B2 (en) 2011-11-04 2014-03-11 Kohler Co. Power management system that includes a membrane
US8942854B2 (en) 2011-11-28 2015-01-27 Kohler Co. System and method for identifying electrical devices in a power management system
US9281716B2 (en) 2011-12-20 2016-03-08 Kohler Co. Generator controller configured for preventing automatic transfer switch from supplying power to the selected load
US9293914B2 (en) 2011-11-04 2016-03-22 Kohler Co Power management system that includes a generator controller
US9678162B2 (en) 2011-11-04 2017-06-13 Kohler Co. Load control module that permits testing of power switching devices that are part of the load control module
US9841799B2 (en) 2011-12-20 2017-12-12 Kohler Co. System and method for using a network to control a power management system
US9991709B2 (en) 2011-11-04 2018-06-05 Kohler Co. Adding and shedding loads using load levels to determine timing
US10366594B2 (en) * 2015-05-04 2019-07-30 Mountain Optech, Inc. Oil and gas production facility emissions sensing and alerting device, system and method

Families Citing this family (98)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7266429B2 (en) * 2001-04-30 2007-09-04 General Electric Company Digitization of field engineering work processes at a gas turbine power plant through the use of portable computing devices operable in an on-site wireless local area network
WO2003007120A2 (en) * 2001-07-11 2003-01-23 Mazzarella Joseph R A system and method for creating and operating an enhanced distributed energy network or virtual power plant
US6839613B2 (en) * 2001-07-17 2005-01-04 General Electric Company Remote tuning for gas turbines
JP2003052083A (en) * 2001-08-07 2003-02-21 Hitachi Ltd Power plant remotely-operating system
JP2003288115A (en) * 2002-03-28 2003-10-10 Toshiba Corp Power plant integrated control system
US7222001B2 (en) * 2002-05-14 2007-05-22 Plug Power Inc. System for monitoring and controlling fuel cell-based power generation units
US9733625B2 (en) 2006-03-20 2017-08-15 General Electric Company Trip optimization system and method for a train
US9233696B2 (en) 2006-03-20 2016-01-12 General Electric Company Trip optimizer method, system and computer software code for operating a railroad train to minimize wheel and track wear
US10569792B2 (en) 2006-03-20 2020-02-25 General Electric Company Vehicle control system and method
US10308265B2 (en) 2006-03-20 2019-06-04 Ge Global Sourcing Llc Vehicle control system and method
US7180210B1 (en) 2002-10-11 2007-02-20 Joel Jorgenson Standby generator integration system
US6658850B1 (en) * 2002-11-05 2003-12-09 General Electric Company Radio frequency communications network for power plant control systems
US8511105B2 (en) 2002-11-13 2013-08-20 Deka Products Limited Partnership Water vending apparatus
CN100531841C (en) 2002-11-13 2009-08-26 迪卡产品合伙有限公司 Pressurized vapor cycle liquid distiller
US8718827B2 (en) * 2003-07-28 2014-05-06 Deka Products Limited Partnership Systems and methods for distributed utilities
US8069676B2 (en) 2002-11-13 2011-12-06 Deka Products Limited Partnership Water vapor distillation apparatus, method and system
ITMI20022752A1 (en) * 2002-12-23 2004-06-24 Nuovo Pignone Spa CONCENTRATION ESTIMATE AND MANAGEMENT SYSTEM
US8924049B2 (en) 2003-01-06 2014-12-30 General Electric Company System and method for controlling movement of vehicles
FR2854710B1 (en) * 2003-05-07 2005-06-24 Elyo SYSTEM OF MEASUREMENTS AND ANALYZES FOR CLASSIFIED INSTALLATIONS EMITTING POLLUTANTS
US6988549B1 (en) * 2003-11-14 2006-01-24 John A Babcock SAGD-plus
US7072801B2 (en) * 2003-12-12 2006-07-04 Bellsouth Intellectual Property Corp. Remote generator fuel monitoring system
US7020585B2 (en) * 2003-12-12 2006-03-28 Bellsouth Intellectual Property Corp. Remote DC plant monitoring system
US7010467B2 (en) * 2003-12-12 2006-03-07 Bellsouth Intellectual Property Co. Web-based generator testing and monitoring system
US7021126B1 (en) * 2004-09-15 2006-04-04 General Electric Company Methods for low-cost estimation of steam turbine performance
US8579999B2 (en) 2004-10-12 2013-11-12 Great River Energy Method of enhancing the quality of high-moisture materials using system heat sources
US7275644B2 (en) 2004-10-12 2007-10-02 Great River Energy Apparatus and method of separating and concentrating organic and/or non-organic material
US8523963B2 (en) 2004-10-12 2013-09-03 Great River Energy Apparatus for heat treatment of particulate materials
US7987613B2 (en) 2004-10-12 2011-08-02 Great River Energy Control system for particulate material drying apparatus and process
US8062410B2 (en) 2004-10-12 2011-11-22 Great River Energy Apparatus and method of enhancing the quality of high-moisture materials and separating and concentrating organic and/or non-organic material contained therein
US9771834B2 (en) * 2004-10-20 2017-09-26 Emerson Process Management Power & Water Solutions, Inc. Method and apparatus for providing load dispatch and pollution control optimization
US8768664B2 (en) * 2005-03-18 2014-07-01 CMC Solutions, LLC. Predictive emissions monitoring using a statistical hybrid model
US7421348B2 (en) * 2005-03-18 2008-09-02 Swanson Brian G Predictive emissions monitoring method
US20070078629A1 (en) * 2005-09-30 2007-04-05 Neil Gollhardt Distributed control system diagnostic logging system and method
US8290645B2 (en) 2006-03-20 2012-10-16 General Electric Company Method and computer software code for determining a mission plan for a powered system when a desired mission parameter appears unobtainable
US8401720B2 (en) 2006-03-20 2013-03-19 General Electric Company System, method, and computer software code for detecting a physical defect along a mission route
US8370006B2 (en) 2006-03-20 2013-02-05 General Electric Company Method and apparatus for optimizing a train trip using signal information
US8788135B2 (en) 2006-03-20 2014-07-22 General Electric Company System, method, and computer software code for providing real time optimization of a mission plan for a powered system
US8126601B2 (en) 2006-03-20 2012-02-28 General Electric Company System and method for predicting a vehicle route using a route network database
US8249763B2 (en) 2006-03-20 2012-08-21 General Electric Company Method and computer software code for uncoupling power control of a distributed powered system from coupled power settings
US8768543B2 (en) 2006-03-20 2014-07-01 General Electric Company Method, system and computer software code for trip optimization with train/track database augmentation
US8370007B2 (en) 2006-03-20 2013-02-05 General Electric Company Method and computer software code for determining when to permit a speed control system to control a powered system
US9156477B2 (en) 2006-03-20 2015-10-13 General Electric Company Control system and method for remotely isolating powered units in a vehicle system
US8473127B2 (en) 2006-03-20 2013-06-25 General Electric Company System, method and computer software code for optimizing train operations considering rail car parameters
US9527518B2 (en) 2006-03-20 2016-12-27 General Electric Company System, method and computer software code for controlling a powered system and operational information used in a mission by the powered system
US9201409B2 (en) 2006-03-20 2015-12-01 General Electric Company Fuel management system and method
US9266542B2 (en) 2006-03-20 2016-02-23 General Electric Company System and method for optimized fuel efficiency and emission output of a diesel powered system
US9689681B2 (en) 2014-08-12 2017-06-27 General Electric Company System and method for vehicle operation
US11826681B2 (en) 2006-06-30 2023-11-28 Deka Products Limited Partneship Water vapor distillation apparatus, method and system
CA2680706C (en) * 2007-03-12 2018-01-09 Emerson Process Management Power & Water Solutions, Inc. Use of statistical analysis in power plant performance monitoring
CA2959009C (en) 2007-06-07 2020-02-25 Deka Products Limited Partnership Water vapor distillation apparatus, method and system
US11884555B2 (en) 2007-06-07 2024-01-30 Deka Products Limited Partnership Water vapor distillation apparatus, method and system
US20090056413A1 (en) * 2007-09-05 2009-03-05 General Electric Company Method And System For Predicting Gas Turbine Emissions Utilizing Meteorological Data
WO2009039155A2 (en) * 2007-09-19 2009-03-26 Briggs And Stratton Corporation Power monitoring system
ATE486308T1 (en) * 2007-10-12 2010-11-15 Powitec Intelligent Tech Gmbh CONTROL CIRCUIT FOR REGULATING A PROCESS, PARTICULARLY A COMBUSTION PROCESS
MX2011001778A (en) 2008-08-15 2011-05-10 Deka Products Lp Water vending apparatus with distillation unit.
JP4698718B2 (en) * 2008-09-30 2011-06-08 株式会社日立製作所 Wind turbine generator group control device and control method
WO2010096135A1 (en) 2009-02-18 2010-08-26 W R Systems, Ltd. Emissions monitoring apparatus, system, and method
KR101071923B1 (en) * 2009-02-23 2011-10-10 한국에너지기술연구원 Evaluation method of co2 emission rate for chp plant using steam turbine and system for the method
US20100217451A1 (en) * 2009-02-24 2010-08-26 Tetsuya Kouda Energy usage control system and method
CA2694597C (en) * 2009-02-25 2017-02-21 Robert Joseph Berry, Jr. Universal remote machinery controller and monitor
US9834237B2 (en) 2012-11-21 2017-12-05 General Electric Company Route examining system and method
US20100262403A1 (en) * 2009-04-10 2010-10-14 Bradford White Corporation Systems and methods for monitoring water heaters or boilers
US9267443B2 (en) 2009-05-08 2016-02-23 Gas Turbine Efficiency Sweden Ab Automated tuning of gas turbine combustion systems
US9671797B2 (en) 2009-05-08 2017-06-06 Gas Turbine Efficiency Sweden Ab Optimization of gas turbine combustion systems low load performance on simple cycle and heat recovery steam generator applications
US9354618B2 (en) 2009-05-08 2016-05-31 Gas Turbine Efficiency Sweden Ab Automated tuning of multiple fuel gas turbine combustion systems
US8437941B2 (en) 2009-05-08 2013-05-07 Gas Turbine Efficiency Sweden Ab Automated tuning of gas turbine combustion systems
US8234023B2 (en) 2009-06-12 2012-07-31 General Electric Company System and method for regulating speed, power or position of a powered vehicle
US20110161250A1 (en) * 2009-12-31 2011-06-30 Koeppel Adam R Distributed energy generator monitor and method of use
US20110295436A1 (en) * 2010-05-27 2011-12-01 General Electric Company Engine Generator Control Module
US8489363B2 (en) * 2010-09-28 2013-07-16 General Electric Company Monitoring and diagnosing generator operation
US8744731B2 (en) * 2010-11-15 2014-06-03 Governors America Corp. Electronic digital governor and method of assembly
JP5025807B1 (en) * 2011-03-25 2012-09-12 株式会社東芝 Reserve power calculation device and method, and computer program
US8831788B2 (en) * 2011-04-20 2014-09-09 General Electric Company Systems, methods, and apparatus for maintaining stable conditions within a power grid
AT509557B1 (en) * 2011-06-10 2012-05-15 Avl List Gmbh METHOD AND DEVICE FOR ANALYZING THE EXHAUST GASES OF COMBUSTION ENGINES, AND EXHAUST GAS COOLERS FOR THIS DEVICE
US20130085683A1 (en) * 2011-10-01 2013-04-04 Javier D'Carlo Garcia Preventive Activated Sludge Microlife Interpreter
US9552029B2 (en) 2012-02-20 2017-01-24 Engineered Electric Company Micro grid power distribution unit
US8892267B2 (en) * 2012-03-13 2014-11-18 International Business Machines Corporation Real-time monitoring, controlling, and optimizing electrical generation assets based on emission level measurements
US9431942B2 (en) * 2012-07-02 2016-08-30 Kohler Co. Generator management system that selectively activates generators based on an operating parameter
US9778632B2 (en) * 2012-07-02 2017-10-03 Kohler Co. Generator management system and method that selectively activate at least one of a plurality of generators in a power generation system
US9593809B2 (en) 2012-07-27 2017-03-14 Deka Products Limited Partnership Water vapor distillation apparatus, method and system
US9368972B2 (en) 2012-07-27 2016-06-14 Kohler Co. Generator management system that determines a time to activate and deactivate generators based on the load level
KR101374623B1 (en) * 2012-09-20 2014-03-17 한국전력공사 Apparatus and method for cooperation control of energy management system and distribution management system
US9682716B2 (en) 2012-11-21 2017-06-20 General Electric Company Route examining system and method
US9669851B2 (en) 2012-11-21 2017-06-06 General Electric Company Route examination system and method
US10521518B2 (en) 2012-12-05 2019-12-31 Deif A/S Emulating power system operations
US9890677B2 (en) 2013-12-16 2018-02-13 Cummins, Inc. System and method for the monitoring and controlling of emissions for multiple engines
US9874547B2 (en) 2014-08-29 2018-01-23 Fluke Corporation Wireless combustion/efficiency analyzer
US10066535B2 (en) * 2016-11-17 2018-09-04 Caterpillar Inc. Compact design exhaust aftertreatment system with NOx sensor
DE102017205573A1 (en) * 2017-03-31 2018-10-04 Rolls-Royce Deutschland Ltd & Co Kg Measuring device and measuring method for a flow
CN108121329A (en) * 2018-02-14 2018-06-05 中国人民解放军第四三二八工厂 Supply vehicle measurement and control system, method, supply vehicle, computer system and medium
US11059474B2 (en) 2018-10-09 2021-07-13 Ford Global Technologies, Llc Hybrid vehicle with electrical power outlet
US11043801B2 (en) 2018-10-09 2021-06-22 Ford Global Technologies, Llc Hybrid vehicle with electrical power outlet
CN110411929B (en) * 2019-08-27 2024-02-06 广州昊致电气自动化有限公司 Generator insulation overheat monitoring device and detection method based on laser scattering principle
US11018508B1 (en) 2020-01-17 2021-05-25 BWR Innovations LLC Electrical power generating system
US11710970B2 (en) 2020-01-17 2023-07-25 BWR Innovations LLC Remotely controlled electrical power generating system
US11698624B2 (en) * 2020-09-23 2023-07-11 Rockwell Automation Technologies, Inc. Actuation assembly for display for industrial automation component
CN114687867A (en) * 2022-03-14 2022-07-01 大连理工大学 Micro turbojet engine control system and starting control method
CN114996979B (en) * 2022-08-05 2022-12-09 深圳市信润富联数字科技有限公司 Method and system for managing carbon-capable data, electronic device and storage medium

Citations (29)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3593023A (en) * 1968-09-18 1971-07-13 Beckman Instruments Inc Apparatus and method for exhaust analysis
US3792327A (en) * 1972-10-05 1974-02-12 L Waldorf Hybrid electrical vehicle drive
US4191541A (en) * 1978-08-14 1980-03-04 Container Corporation Of America Method and apparatus for gas sample analysis
US4336772A (en) * 1980-02-11 1982-06-29 Young Don H Water vapor injection system
US4435663A (en) * 1981-04-09 1984-03-06 International Business Machines Corporation Thermochemical magnetic generator
US4578986A (en) * 1984-07-06 1986-04-01 Champion International Corporation Gas analyzer for dry/dusty kilns
US4883505A (en) * 1988-07-22 1989-11-28 Iit Research Institute Methods and apparatus for atmospheric sampling and analysis of trace contaminants
US5251588A (en) * 1991-11-15 1993-10-12 Toyota Jidosha Kabushiki Kaisha Controller for hybrid vehicle drive system
US5264764A (en) * 1992-12-21 1993-11-23 Ford Motor Company Method for controlling the operation of a range extender for a hybrid electric vehicle
US5428274A (en) * 1991-11-22 1995-06-27 Toyota Jidosha Kabushiki Kaisha Drive control apparatus of series hybrid vehicle
US5473228A (en) * 1993-10-07 1995-12-05 Toyota Jidosha Kabushiki Kaisha Control method for electrical appliance in hybrid vehicle
US5608308A (en) * 1994-08-22 1997-03-04 Honda Giken Kogyo Kabushiki Kaisha Electric generation control system for hybrid vehicle
US5614809A (en) * 1994-08-22 1997-03-25 Honda Giken Kogyo Kabushiki Kaisha Electric generation control system for hybrid vehicle
US5621304A (en) * 1994-08-22 1997-04-15 Honda Giken Kogyo Kabushiki Kaisha Electric generation control system for hybrid vehicle
US5734255A (en) * 1996-03-13 1998-03-31 Alaska Power Systems Inc. Control system and circuits for distributed electrical power generating stations
US5754033A (en) * 1996-03-13 1998-05-19 Alaska Power Systems Inc. Control system and circuits for distributed electrical-power generating stations
US5798633A (en) * 1996-07-26 1998-08-25 General Electric Company Battery energy storage power conditioning system
US5893895A (en) * 1996-08-02 1999-04-13 Honda Giken Kogyo Kabushiki Kaisha Control system for hybrid vehicle
US5939848A (en) * 1997-09-17 1999-08-17 Honda Giken Kogyo Kabushiki Kaisha Control system for hybrid vehicle
US5955865A (en) * 1996-06-17 1999-09-21 Hino Jidosha Kogyo Kabushiki Kaisha Control system for a vehicle-mounted battery
US6118680A (en) * 1999-05-28 2000-09-12 Peco Ii Methods and apparatus for load sharing between parallel inverters in an AC power supply
US6150955A (en) * 1996-10-28 2000-11-21 Tracy Corporation Ii Apparatus and method for transmitting data via a digital control channel of a digital wireless network
US6390214B1 (en) * 1998-06-19 2002-05-21 Honda Giken Kogyo Kabushiki Kaisha Control device of hybrid drive vehicle
US6553336B1 (en) * 1999-06-25 2003-04-22 Telemonitor, Inc. Smart remote monitoring system and method
US6554088B2 (en) * 1998-09-14 2003-04-29 Paice Corporation Hybrid vehicles
US6561295B1 (en) * 1999-10-29 2003-05-13 Honda Giken Kogyo Kabushiki Kaisha Control system and method of hybrid vehicle
US6603278B2 (en) * 1997-09-17 2003-08-05 Honda Giken Kogyo Kabushiki Kaisha Control system for hybrid vehicle
US6825575B1 (en) * 1999-09-28 2004-11-30 Borealis Technical Limited Electronically controlled engine generator set
US6998727B2 (en) * 2003-03-10 2006-02-14 The United States Of America As Represented By The Administrator Of The Environmental Protection Agency Methods of operating a parallel hybrid vehicle having an internal combustion engine and a secondary power source

Family Cites Families (28)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE2460066C3 (en) 1974-12-19 1981-08-06 Brown, Boveri & Cie Ag, 6800 Mannheim Method and device for the automatic control of the fuel-air ratio of a combustion
US6384903B1 (en) * 1977-02-28 2002-05-07 Bae Systems Information And Electronic Systems Integration, Inc. Range gated remote measurement utilizing two-photon absorption
DE2807075C2 (en) 1978-02-18 1986-12-18 Daimler-Benz Ag, 7000 Stuttgart Process for operating a thermal power station and a suitable thermal power station
US4419667A (en) * 1979-07-02 1983-12-06 Sangamo Weston, Inc. System for controlling power distribution to customer loads
DE3020565A1 (en) * 1980-05-30 1981-12-10 Studiengesellschaft Kohle mbH, 4330 Mülheim METHOD AND DEVICE FOR ENERGY-SAVING PRODUCT HEAT FROM THE ENVIRONMENT OR FROM WASTE HEAT
US4494380A (en) * 1984-04-19 1985-01-22 Bilan, Inc. Thermoelectric cooling device and gas analyzer
JPH0721362B2 (en) * 1984-04-24 1995-03-08 株式会社明電舍 Waste heat recovery power generator
US4738147A (en) * 1986-12-16 1988-04-19 Sampling Technology, Inc. Low flow sampling and analysis system
GB8715131D0 (en) 1987-06-27 1987-08-05 Combined Power Systems Ltd Building heat & power system
US6155212A (en) * 1989-06-12 2000-12-05 Mcalister; Roy E. Method and apparatus for operation of combustion engines
US5205177A (en) * 1991-01-23 1993-04-27 Research-Cottrell, Inc. Method and apparatus for gas monitoring
US5497630A (en) 1992-09-30 1996-03-12 Thermal Electric Devices, Inc. Method and apparatus for hydride heat pumps
GB2278519B (en) * 1993-05-28 1997-03-12 Motorola Israel Ltd A system for time synchronisation
DE4322923C2 (en) * 1993-07-05 1997-08-07 Hartmann & Braun Ag Equipment for the preparation and analysis of sample gases
US5539638A (en) 1993-08-05 1996-07-23 Pavilion Technologies, Inc. Virtual emissions monitor for automobile
JPH08210171A (en) * 1995-02-03 1996-08-20 Komatsu Ltd Exhaust emission control device for engine
US5661463A (en) * 1995-04-17 1997-08-26 Communications Test Design, Inc. D.C. battery plant alarm monitoring remote apparatus
US5970426A (en) * 1995-09-22 1999-10-19 Rosemount Analytical Inc. Emission monitoring system
DE19630092A1 (en) * 1996-07-26 1998-01-29 Sachsenring Automobiltechnik G Method for recording and / or paying a fee for exhaust gas pollutants and a motor vehicle with an exhaust gas pollutant set operating according to this method
US5778675A (en) * 1997-06-20 1998-07-14 Electric Power Research Institute, Inc. Method of power generation and load management with hybrid mode of operation of a combustion turbine derivative power plant
US6173567B1 (en) 1998-09-14 2001-01-16 The University Of Chicago Method to reduce diesel engine exhaust emissions
US6095793A (en) * 1998-09-18 2000-08-01 Woodward Governor Company Dynamic control system and method for catalytic combustion process and gas turbine engine utilizing same
US6148659A (en) * 1998-10-08 2000-11-21 Traina; John E. Gas concentration monitor having a bridge configured flow system
US6362540B1 (en) * 1999-10-20 2002-03-26 Pinnacle West Capital Corporation Expandable hybrid electric generator and method therefor
CN1496499A (en) * 2000-06-09 2004-05-12 ͨ�õ�����˾ System and method for utility enterprise management
US6610263B2 (en) * 2000-08-01 2003-08-26 Enviroscrub Technologies Corporation System and process for removal of pollutants from a gas stream
US6351692B1 (en) * 2000-10-24 2002-02-26 Kohler Co. Method and apparatus for configuring a genset controller for operation with particular gensets
US6603290B2 (en) 2001-11-26 2003-08-05 Visteon Global Technologies, Inc. Anti-islanding detection scheme for distributed power generation

Patent Citations (31)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3593023A (en) * 1968-09-18 1971-07-13 Beckman Instruments Inc Apparatus and method for exhaust analysis
US3792327A (en) * 1972-10-05 1974-02-12 L Waldorf Hybrid electrical vehicle drive
US4191541A (en) * 1978-08-14 1980-03-04 Container Corporation Of America Method and apparatus for gas sample analysis
US4336772A (en) * 1980-02-11 1982-06-29 Young Don H Water vapor injection system
US4435663A (en) * 1981-04-09 1984-03-06 International Business Machines Corporation Thermochemical magnetic generator
US4578986A (en) * 1984-07-06 1986-04-01 Champion International Corporation Gas analyzer for dry/dusty kilns
US4883505A (en) * 1988-07-22 1989-11-28 Iit Research Institute Methods and apparatus for atmospheric sampling and analysis of trace contaminants
US5251588A (en) * 1991-11-15 1993-10-12 Toyota Jidosha Kabushiki Kaisha Controller for hybrid vehicle drive system
US5428274A (en) * 1991-11-22 1995-06-27 Toyota Jidosha Kabushiki Kaisha Drive control apparatus of series hybrid vehicle
US5264764A (en) * 1992-12-21 1993-11-23 Ford Motor Company Method for controlling the operation of a range extender for a hybrid electric vehicle
US5473228A (en) * 1993-10-07 1995-12-05 Toyota Jidosha Kabushiki Kaisha Control method for electrical appliance in hybrid vehicle
US5608308A (en) * 1994-08-22 1997-03-04 Honda Giken Kogyo Kabushiki Kaisha Electric generation control system for hybrid vehicle
US5614809A (en) * 1994-08-22 1997-03-25 Honda Giken Kogyo Kabushiki Kaisha Electric generation control system for hybrid vehicle
US5621304A (en) * 1994-08-22 1997-04-15 Honda Giken Kogyo Kabushiki Kaisha Electric generation control system for hybrid vehicle
US5734255A (en) * 1996-03-13 1998-03-31 Alaska Power Systems Inc. Control system and circuits for distributed electrical power generating stations
US5754033A (en) * 1996-03-13 1998-05-19 Alaska Power Systems Inc. Control system and circuits for distributed electrical-power generating stations
US5955865A (en) * 1996-06-17 1999-09-21 Hino Jidosha Kogyo Kabushiki Kaisha Control system for a vehicle-mounted battery
US5798633A (en) * 1996-07-26 1998-08-25 General Electric Company Battery energy storage power conditioning system
US5893895A (en) * 1996-08-02 1999-04-13 Honda Giken Kogyo Kabushiki Kaisha Control system for hybrid vehicle
US6150955A (en) * 1996-10-28 2000-11-21 Tracy Corporation Ii Apparatus and method for transmitting data via a digital control channel of a digital wireless network
US6603278B2 (en) * 1997-09-17 2003-08-05 Honda Giken Kogyo Kabushiki Kaisha Control system for hybrid vehicle
US5939848A (en) * 1997-09-17 1999-08-17 Honda Giken Kogyo Kabushiki Kaisha Control system for hybrid vehicle
US6390214B1 (en) * 1998-06-19 2002-05-21 Honda Giken Kogyo Kabushiki Kaisha Control device of hybrid drive vehicle
US6554088B2 (en) * 1998-09-14 2003-04-29 Paice Corporation Hybrid vehicles
US7104347B2 (en) * 1998-09-14 2006-09-12 Paice Llc Hybrid vehicles
US6118680A (en) * 1999-05-28 2000-09-12 Peco Ii Methods and apparatus for load sharing between parallel inverters in an AC power supply
US6553336B1 (en) * 1999-06-25 2003-04-22 Telemonitor, Inc. Smart remote monitoring system and method
US6825575B1 (en) * 1999-09-28 2004-11-30 Borealis Technical Limited Electronically controlled engine generator set
US7105938B2 (en) * 1999-09-28 2006-09-12 Borealis Technical Limited Electronically controlled engine generator set
US6561295B1 (en) * 1999-10-29 2003-05-13 Honda Giken Kogyo Kabushiki Kaisha Control system and method of hybrid vehicle
US6998727B2 (en) * 2003-03-10 2006-02-14 The United States Of America As Represented By The Administrator Of The Environmental Protection Agency Methods of operating a parallel hybrid vehicle having an internal combustion engine and a secondary power source

Cited By (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20050033481A1 (en) * 2003-08-08 2005-02-10 Budhraja Vikram S. Real-time performance monitoring and management system
US7233843B2 (en) * 2003-08-08 2007-06-19 Electric Power Group, Llc Real-time performance monitoring and management system
US20100100250A1 (en) * 2003-08-08 2010-04-22 Electric Power Group, Llc Real-time performance monitoring and management system
US8060259B2 (en) 2003-08-08 2011-11-15 Electric Power Group, Llc Wide-area, real-time monitoring and visualization system
US8401710B2 (en) 2003-08-08 2013-03-19 Electric Power Group, Llc Wide-area, real-time monitoring and visualization system
US20090307233A1 (en) * 2008-06-02 2009-12-10 Guorui Zhang Efficient Handling of PMU Data for Wide Area Power System Monitoring and Visualization
US8670224B2 (en) 2011-11-04 2014-03-11 Kohler Co. Power management system that includes a membrane
US9293914B2 (en) 2011-11-04 2016-03-22 Kohler Co Power management system that includes a generator controller
US9678162B2 (en) 2011-11-04 2017-06-13 Kohler Co. Load control module that permits testing of power switching devices that are part of the load control module
US9991709B2 (en) 2011-11-04 2018-06-05 Kohler Co. Adding and shedding loads using load levels to determine timing
US10790664B2 (en) 2011-11-04 2020-09-29 Kohler Co. Adding and shedding loads using load levels to determine timing
US8942854B2 (en) 2011-11-28 2015-01-27 Kohler Co. System and method for identifying electrical devices in a power management system
US9281716B2 (en) 2011-12-20 2016-03-08 Kohler Co. Generator controller configured for preventing automatic transfer switch from supplying power to the selected load
US9841799B2 (en) 2011-12-20 2017-12-12 Kohler Co. System and method for using a network to control a power management system
US10366594B2 (en) * 2015-05-04 2019-07-30 Mountain Optech, Inc. Oil and gas production facility emissions sensing and alerting device, system and method

Also Published As

Publication number Publication date
AU2002244045A1 (en) 2002-09-04
CA2438735A1 (en) 2002-08-29
EP1381762A2 (en) 2004-01-21
US20050188745A1 (en) 2005-09-01
US6912889B2 (en) 2005-07-05
WO2002066974A3 (en) 2003-11-20
US20020134083A1 (en) 2002-09-26
WO2002066974A2 (en) 2002-08-29
US6983640B1 (en) 2006-01-10

Similar Documents

Publication Publication Date Title
US6983640B1 (en) Generator monitoring, control and efficiency
US7222111B1 (en) Multi-utility energy control and facility automation system with dashboard having a plurality of interface gateways
EP1864193B1 (en) Predictive emissions monitoring system and method
US7676285B2 (en) Method for monitoring driven machinery
CN101454967A (en) Modular electric power generation system and method of use
CN102054124A (en) Predicting NOx emissions
JP4562108B2 (en) Method for online measurement of fuel thermal function of fuel in a combustion turbine unit
Jenicek et al. Optimized control of generalized compressor station
Swanson et al. An alternative approach to continuous compliance monitoring and turbine plant optimization using a PEMS (Predictive Emission Monitoring System)
Swanson A cost effective advanced emissions monitoring solution for gas turbines: statistical hybrid predictive system that accurately measures nitrogen oxides, carbon monoxide, sulfur dioxide, hydrocarbon and carbon dioxide mass emission rates
Swanson Alternative Approaches to Continuous Compliance Monitoring for Gas Turbines Under 40 CFR Part 60, Part 75, and Part 98 Regulations in the United States
Team Greenhouse Gas Technology Verification Center
KR100680238B1 (en) Control apparatus and method for distributed power generator
Zheng et al. Certification of a Statistical Hybrid Predictive Emission Monitoring System in the USA and Development of a Small Gas Turbine Class Model
CN116050857A (en) Power generation enterprise-level low-carbon transformation decision support system
Gopalakrishnan et al. Compressed Air Energy Saving Assessments (ESA) for the Automotive Supply Chain
Wilber Maintenance of continuous emissions mercury monitoring systems (HgCEMS) under the US EPA Portland Cement (PC) MACT rules
CN115957603A (en) Denitration system monitoring device and denitration system monitoring system
Headley et al. Predicting NO x emissions
CN115544457A (en) Method and system for metering and accounting carbon emission of park
Brambley et al. Monitoring and commissioning verification algorithms for CHP systems
Duguay et al. Installing PEMS on an Offshore Oil and Gas Complex: Developing Atmospheric Emissions Abatement Strategies with Reliable Scientific Data
Apostol et al. Environmental protection-a national and international problem to solve
PowerWorks Test and Quality Assurance Plan
LNG Improving Natural Gas Liquefaction Plant Performance with Process Analyzers

Legal Events

Date Code Title Description
STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION