| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 121 | POWER RECOVERY | US14626199 | 2015-02-19 | US20150167501A1 | 2015-06-18 | Harald B. CARRICK; Graham R. AIRD; Graeme HUMPHRIES |
| The invention relates to a method and apparatus for recovering power from the gaseous stream produced by an oxidation reaction. Specifically, the invention is based on heating the gaseous stream from the oxidation reaction to a temperature of at least 800° C. and recovering energy through a gas turbine. The compressor stage of the gas turbine compresses the oxidant feed to the reactor thereby at least partially offsetting the cost of providing the high temperature and pressure reaction conditions in the reactor. The invention also provides improved control of the power recovery system by optimising the efficiency of the gas turbine by feeding gas to the gaseous stream to modulate the flow of gas to the turbine relative to the compressor discharge flow in order to compensate for the consumption of oxidant in the reactor. | ||||||
| 122 | Systems and Methods for Integrating Alarm Processing and Presentation of Alarms for a Power Generation System | US13708405 | 2012-12-07 | US20140159907A1 | 2014-06-12 | Justin Alexander Sykes; Scott Wood; Jia Q. Ma; Dibakar Chandra; William Darryl Herbert; Craig Foster |
| Systems and methods for integrating alarm processing and presentation of alarms for a power generation system are described. A template or graphical user interface (GUI) for displaying information associated with alarms may be generated for various types of alarms. Information associated with an alarm may be identified based on certain criteria and stored in a template associated with the alarm for presentation to a user. One or more status messages may be output to a display such a that a user or other person responsible for responding to an alarm may receive a current status associated with an alarm, including that an alarm has been processed and is ready to be acted upon. An alarm may be analyzed, categorized, and escalated based on historical information associated with the alarm, as well as determinations made by a user based on information stored in a template associated with alarm. | ||||||
| 123 | STEAM TURBINE PERFORMANCE TESTING | US13366481 | 2012-02-06 | US20130204816A1 | 2013-08-08 | Scott Victor Hannula; Duncan George Watt |
| A steam turbine performance testing system, including at least one computer hardware device, including a neural network created using a dynamic steam turbine thermodynamic model and preliminary data collected from a steam turbine; a network tester for testing the neural network with testing data; a current performance calculator for calculating a current performance of the steam turbine from operation data of the steam turbine; and a projected performance calculator for calculating a projected performance of the steam turbine from the current performance. | ||||||
| 124 | System and method for measuring efficiency and leakage in a steam turbine | US12542580 | 2009-08-17 | US08419344B2 | 2013-04-16 | Virginia Yang |
| In certain embodiments, a system includes a physical computing device having a tangible machine-readable medium including code. The code is adapted to determine an efficiency of a section of a steam turbine based on a relationship between enthalpy difference values and leakage flow rate values between adjacent sections of the steam turbine. The relationship includes a point of equalizing an enthalpy of the leakage and an enthalpy at a destination of the leakage. | ||||||
| 125 | Method for determining when to perform a test of an overspeed protection system of a powerplant machine | US12729654 | 2010-03-23 | US08370100B2 | 2013-02-05 | Frederick William Block; Richard Lee Nichols; Joseph Robert Law; Bret Stephen Dalton; George Allen Ellis |
| Embodiments of the present invention have the technical effect of determining when to test an overspeed protection system of a powerplant machine. As described herein, embodiments of the present invention may be applied to a wide variety of powerplant machines, each comprising a shaft. After determining that test of the overspeed protection system should be performed, embodiments of the present invention may allow for a variety of methods to test the overspeed protection system. | ||||||
| 126 | THERMAL MEASUREMENT SYSTEM FOR FAULT DETECTION WITHIN A POWER GENERATION SYSTEM | US12850777 | 2010-08-05 | US20120032810A1 | 2012-02-09 | Rahul Jaikaran Chillar; Eric J. Kauffman; Adil Ansari |
| A system includes a radiation sensor configured to direct a field of view toward a conduit within a heat recovery steam generator, and to output a signal indicative of a temperature of the conduit. The system also includes a controller communicatively coupled to the radiation sensor. The controller is configured to determine the temperature based on the signal, and to compare the temperature to a threshold value. | ||||||
| 127 | METHOD FOR DETERMINING WHEN TO PERFORM A TEST OF AN OVERSPEED PROTECTION SYSTEM OF A POWERPLANT MACHINE | US12729654 | 2010-03-23 | US20110238358A1 | 2011-09-29 | Frederick William Block; Richard Lee Nichols; Joseph Robert Law; Bret Stephen Dalton; George Allen Ellis |
| Embodiments of the present invention have the technical effect of determining when to test an overspeed protection system of a powerplant machine. As described herein, embodiments of the present invention may be applied to a wide variety of powerplant machines, each comprising a shaft. After determining that test of the overspeed protection system should be performed, embodiments of the present invention may allow for a variety of methods to test the overspeed protection system. | ||||||
| 128 | METHOD FOR MEASURING CONDITIONS IN A POWER BOILER FURNACE USING A SOOTBLOWER | US12991133 | 2009-05-13 | US20110056313A1 | 2011-03-10 | Erik Dahlen; Mikael Niklasson |
| The present invention relates to a method for measuring the conditions inside a power boiler wherein a sootblower is used as a measuring probe. The invention also relates to a system for measuring the conditions in a power boiler, comprising a control unit, at least one sensor and a measuring probe placed inside said furnace, wherein said probe is arranged on a soot blower. | ||||||
| 129 | Measurement of Steam Quality in Steam Turbine | US12428428 | 2009-04-22 | US20100272147A1 | 2010-10-28 | Scott Victor Hannula; Randy Scott Rosson; Kevin Wood Wilkes |
| A solution for measuring steam quality in a steam turbine is disclosed. A steam quality measurement (SQM) device and an ejector are coupled to a steam turbine through an appropriate piping configuration to draw steam emitted from the turbine through the SQM device for measurement of the steam quality, for example, continuously, during operation of the turbine. | ||||||
| 130 | Volatile tracers for diagnostic use in steam generating systems | US862964 | 1992-04-03 | US5282379A | 1994-02-01 | Scott R. Harder; Claudia C. Pierce; Brian F. Post |
| In a diagnostic method wherein steam condensate is evaluated, the proportion of condensate water from one steam source, versus other steam sources, is determined by adding at an addition point a tracer that is selectively carried over into the steam. | ||||||
| 131 | Liquid acoustic waveguide tube | US240779 | 1988-09-06 | US4955004A | 1990-09-04 | Paul W. Viscovich |
| A monitor for detecting the presence of liquid in a fluid supply conduit wherein the fluid has at least a liquid phase, and wherein bubbles may form in the fluid, is shown to include an ultrasonic signal transmitter for generating and transmitting an ultrasonic signal, an ultrasonic signal receiver, means for attaching the transmitter and receiver to the conduit, and a waveguide which confines a portion of the fluid so that the ultrasonic signal is guided to the receiver when liquid is present in the confined portion. The waveguide also tends to exclude bubbles from the confined portion. The waveguide may include a cylinder positioned in the conduit between the transmitter and the receiver and which has a plurality of openings to allow the ingress and egress of liquid. | ||||||
| 132 | System for determining abnormal plant operation based on whiteness indexes | US618713 | 1984-06-08 | US4630189A | 1986-12-16 | Kazunori Ohmori; Kensuke Kawai |
| In a method and a system for diagnosing a thermal power plant system including a thermal power plant, provided with an automatic power plant control system performing PID control, and a direct digital control system utilizing a control model representing the combination of the plant and the automatic power plant control system and controlling the plant to conduct an optimum control, the automatic power plant control system and the direct digital control system conducting control complementarily: a plant diagnostic model formed of a mathematical model representing the combination of the plant, the automatic power plant control system, the control model and the direct digital control system, is provided and used to determine predicted values of the plant variables; difference between the predicted value of each of the plant variables and the actual value of the same plant variable is determined, and stored thereby to provide a time series of the differences which have been successively determined; whiteness indexes used for testing the whiteness level of the time series of the differences are determined in accordance with the time series of the differences; judgement is made as to whether or not any of the plant variables is abnormal in accordance with the whiteness indexes; judgement is made as to whether or not any of the manipulated variables is faulty in accordance with the whiteness indexes and the result of judgement as to abnormality; and an alarm is outputted when an abnormality or a fault is detected. | ||||||
| 133 | Apparatus and method for obtaining an electrical signal corresponding to the specific enthalpy of steam | US555541 | 1975-03-05 | US3970832A | 1976-07-20 | Bruno Itschner |
| Apparatus and method for obtaining an electrical signal corresponding to the enthalpy of steam expressed by Koch's state equation, is disclosed. In the form of Koch's state equation which is used, terms of minor significance are neglected and the equation is converted into a logarithmic form suitable for solution by electrical analog computer elements. A circuit arrangement comprised of adders, multipliers and function generators is disclosed for simulating and solving the potential and exponential functions in the formula for the enthalpyi = j.sub.o (t) - A.sup.. p(1/t.sup.2.82) - e.sup.(1n B .sup.+ 3 in p .sup.- 14 1n t) ,where i.sub.o is a basic quantity dependent only on the temperature t, the pressure, p, and A and B are constants. | ||||||
| 134 | WASTE HEAT RECOVERY SYSTEM | EP16798890.6 | 2016-11-09 | EP3377735A1 | 2018-09-26 | HUSCHER, Frederick M. |
| A waste heat recovery system is disclosed. The waste heat recovery system may include a turbine expander. The turbine expander may include a turbine blade rotatably coupled to a shaft and the shaft may be rotatably engaged with a nozzle ring. The nozzle ring may include a de Laval-nozzle. The waste heat recovery system may additionally include a pressure sensor. The pressure sensor may be located fluidly upstream of the de Laval-nozzle and fluidly downstream of an evaporator. The pressure sensor may be configured to measure pressure of a working fluid and transmit a working fluid pressure signal. Further, the waste heat recovery system may include an electronic controller. The electronic controller may be configured to receive the working fluid pressure signal and transmit a working fluid flowrate adjustment signal in response to the working fluid pressure signal. | ||||||
| 135 | SCHEDULING MAINTENANCE TO REDUCE DEGRADATION OF A POWER GENERATION SYSTEM | EP18157023.5 | 2018-02-15 | EP3373233A1 | 2018-09-12 | EWENS, David, Spencer; RAFFENSPERGER, John Joseph; SEELY, William Forrester |
A system includes a power generation system (10) and controllers (18) that control operations of the power generation system (10). The controllers (18) include processors (19) that receive multiple values associated with operating parameters (72) of the power generation system (10), and determine a degradation cost function (92) that quantifies a degradation cost based on the values. The processors (19) further receive an operation cost that includes a fixed financial cost of performing an operation on the power generation system (10), and determine an operation cost function that quantifies the operation cost. The processors (19) further determine a total cost function of the power generation system (10) based on the degradation cost function (92) and the operation cost function, and determine times (98) to perform the operation on the power generation system (10) based on the total cost function. The processors (19) further send an alert to perform the operation of the power generation system (10) at the times.
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| 136 | METHOD FOR THE CALCULATION OF THE WORKING FLUID LOSS IN AN ORGANIC RANKINE CYCLE PLANT | EP16745167.3 | 2016-06-23 | EP3320192A1 | 2018-05-16 | BONAFIN, Joseph; CASALI, Isaia; DEL CARRIA, Marco; GIRARDI, Pietro |
| Method for the calculation of the working fluid loss in an organic Rankine cycle plant, comprising at least one evaporator (1), a preheater (5), a turbine (2), a condenser (3), a pump (4), a collecting well (7) and a process piping (8), wherein said working fluid, when the plant is stopped, is in part present in known volumes inside the plant and partly drained in at least a storage tank (6) comprising at least three rooms or volumes: —a first volume (Vck) for storing the fluid to be measured, —a second volume (Vc) having a restricted section for measuring the volume of fluid stored in said first volume (Vck), —a third volume (Vckd) containing the portion of the fluid already measured, wherein, in said method, the working fluid loss of the plant is calculated as the difference between the fluid amount measured in two different instants of time. | ||||||
| 137 | DEVICE MAINTENANCE APPARATUS, DEVICE MAINTENANCE METHOD, DEVICE MAINTENANCE PROGRAM, AND RECORDING MEDIUM | EP17172428.9 | 2017-05-23 | EP3249486A1 | 2017-11-29 | Furihata, Ryouhei; Kono, Ayako; Iketsuki, Yuya |
A device maintenance apparatus includes: a comparison target selector configured to select comparison targets of a device information of a device as a maintenance target; and a display configured to display a comparative information generated based on changes in the device information.
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| 138 | EVAPORATOR, RANKINE CYCLE APPARATUS, AND COMBINED HEAT AND POWER SYSTEM | EP15171741.0 | 2015-06-11 | EP2957734B1 | 2017-09-13 | Kosuda, Osamu; Okaichi, Atsuo; Kido, Osao; Hikichi, Takumi; Nakamura, Takahiro |
| An evaporator which heats working fluid with high-temperature fluid to evaporate the working fluid includes: a working fluid channel which is arranged in a flow direction of the high temperature fluid and through which the working fluid flows; and a temperature sensor which is provided for the working fluid channel. A part of the working fluid channel is exposed to outside of a housing of the evaporator, and the temperature sensor is provided in the part of the working fluid channel exposed to the outside of the housing of the evaporator in a region other than an inlet of the working fluid channel into which the working fluid flows from the outside of the evaporator and other than an outlet of the working fluid channel through which the working fluid flows out of the evaporator. The output value of the temperature sensor is used to adjust the temperature of the working fluid in the evaporator. | ||||||
| 139 | WASTE MANAGEMENT | EP15726280.9 | 2015-06-02 | EP3152411A1 | 2017-04-12 | CHALABI, Rifat Al; PERRY, Ophneil Henry; LI, Ke |
| The present invention relates to a method for producing steam, the method comprising: (a) passing waste gas through a first boiler to produce steam having a first temperature, and cooled waste gas; (b) removing contaminants from the cooled waste gas to produce clean waste gas; (c) passing the steam having a first temperature through a second boiler; and (d) burning at least a portion of the clean waste gas in the second boiler to produce steam having a second temperature, the second temperature being higher than the first temperature. The method is particularly suited to efficiently generating high temperature, high pressure steam derived from the pyrolysis/gasification of organic waste. | ||||||
| 140 | Hydrostatic test device and hydrostatic test method for high pressure turbine | EP15151197.9 | 2015-01-14 | EP2896947A1 | 2015-07-22 | Nam, Ki Young; Baek, Seung Hack; Song, Ho Joo |
A hydrostatic test device for a turbine may include a plurality of feeding holes having a groove part formed with a greater diameter. Sealing members may be fitted into feeding holes in upper or lower casings of a turbine to seal the feeding holes.
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