Gas turbine lower heating value methods and systems

• US 11,112,118 B2
• Filed: 06/27/2016
• Issued: 09/07/2021
• Est. Priority Date: 06/27/2016
• Status: Active Grant

• Current Assignee: GE Infrastructure Technology, LLC (General Electric Company)
• Original Assignee: General Electric Company
• Inventors: Vela, Veronica Elizabeth
• Primary Examiner(s): Walthour, Scott J
• Assistant Examiner(s): Olynick, David P.
• Application Number:
  US15/194,218
• Publication Number:
  US 20170370297A1
• Time in Patent Office: 1,898 Days
• CPC Class Codes: F02C 7/143 before or between the compressor stages
• CPC Class Codes: F02C 9/00 Controlling gas-turbine plants; Controlling fuel supply in air- breathing jet-propulsion plants controlling air intakes F02C7/057; controlling turbines F01D; controlling compressors F04D27/00; controlling in general G05
• CPC Class Codes: F02C 9/28 Regulating systems responsive to plant or ambient parameters, e.g. temperature, pressure, rotor speed F02C9/30 - F02C9/38, F02C9/44 take precedence
• CPC Class Codes: F05D 2220/75 equipment using fuel having a low calorific value, e.g. low BTU fuel, waste end, syngas, biomass fuel or flare gas
• CPC Class Codes: F05D 2270/71 synthesized, i.e. parameter computed by a mathematical model
• CPC Class Codes: F23N 1/002 using electronic means F23N1/04 - F23N1/10 take precedence
• CPC Class Codes: F23N 2221/10 Analysing fuel properties, e.g. density, calorific
• CPC Class Codes: F23N 2223/40 Simulation
• CPC Class Codes: F23N 2241/20 Gas turbines
• CPC Class Codes: F23R 3/14 by using swirl vanes
• CPC Class Codes: F23R 3/36 Supply of different fuels

Abstract

A control system for a gas turbine includes a controller. The controller includes a processor configured to receive a plurality of signals comprising a temperature signal, a pressure signal, a speed signal, a mass flow signal, or a combination thereof, from sensors disposed in the gas turbine system. The processor is further configured to apply the plurality of signals as input to a heating value model. The processor is also configured to execute the heating value model to derive a heating value for a fuel combusted by the gas turbine system. The processor is additionally configured to control operations of the gas turbine system based on the heating value for the fuel.

Claims

1. A control system for a gas turbine system, comprising:

a controller comprising a processor, wherein the processor is configured to;

receive a plurality of signals comprising a temperature signal, a pressure signal, a speed signal and a mass flow signal from sensors disposed in the gas turbine system;

execute a heating value model to derive a Lower Heating Value (LHV) for a gas turbine fuel combusted by the gas turbine system, using the plurality of signals as input to the heating value model;

control operations of the gas turbine system based on the LHV derived via the heating value model, wherein the heating value model comprises at least one LHV dynamic equation configured to use as input at least a plurality of enthalpy values, a fuel-to-air ratio and a value for sensed mass air flow into a combustor, wherein the LHV dynamic equation comprises LHV=(HFL*(WAR36+FAR+1.0)−

H3/FAR)−

C, wherein HFL comprises a first enthalpy of the gas turbine fuel having a range of between 30 to 60 Wobbe numbers, FAR comprises the fuel-to-air ratio, H3 comprises a second enthalpy, C comprises a constant, and WAR36 comprises the value for sensed mass air flow into the combustor and sensed via the mass flow signal.

2. The control system of claim 1, wherein the processor is configured to use a first lookup table and a combustion flame temperature to derive HFL and a second lookup table and the combustion flame temperature to derive H3.

3. The control system of claim 1, wherein FAR is derived via FAR=(WF36DMD/3600)/WA4Model, wherein WF36DMD comprises a current demand for the gas turbine fuel, for air, or for a combination thereof, and wherein WA4Model comprises an airflow model configured to receive the speed signal and the pressure signal to derive an expected airflow by using a lookup table.

4. The control system of claim 1, wherein the gas turbine fuel comprises a LHV fuel and wherein the controller is configured to control operations of the gas turbine system by comparing the LHV to a heating value range, and by increasing fuel flow when the LHV is below the heating value range, and by decreasing fuel flow when the LHV is above the range.

5. The control system of claim 1, wherein the plurality of signals comprises a fuel heating value signal derived via a gas chromatograph or a Wobbe meter, and wherein the LHV is compared to a second LHV derived from the fuel heating value signal to provide for redundant operations.

6. The control system of claim 1, wherein the gas turbine system comprises a spray intercooler (SPRINT) or an efficient spray intercooler (ESPRINT) configured to cool a compressed oxidant using a fluid, and wherein the controller is configured to control the SPRINT or the ESPRINT.

7. A non-transitory computer-readable medium having computer executable code stored thereon, the computer executable code comprising instructions to:

receive a plurality of signals comprising a temperature signal, a pressure signal, a speed signal and a mass flow signal from sensors disposed in a gas turbine system;

execute a heating value model to derive a Lower Heating Value (LHV) for a gas turbine fuel combusted by the gas turbine system, using the plurality of signals as input to the heating value model;

control operations of the gas turbine system based on the LHV derived via the heating value model, wherein the heating value model comprises at least one LHV dynamic equation configured to use as input at least a plurality of enthalpy values, a fuel-to-air ratio and a value for sensed mass air flow into a combustor, wherein the LHV dynamic equation comprises LHV=(HFL*(WAR36+FAR+1.0)−

H3/FAR)−

C, wherein HFL comprises a first enthalpy of the gas turbine fuel having a range of between 30 to 60 Wobbe numbers, FAR comprises the fuel-to-air ratio, H3 comprises a second enthalpy, C comprises a constant, and WAR36 comprises the value for sensed mass air flow into the combustor and sensed via the mass flow signal.

8. The non-transitory computer-readable medium of claim 7, comprising instructions configured to use a first lookup table and the combustion flame temperature to derive HFL and a second lookup table and the combustion flame temperature to derive H3.

9. The non-transitory computer-readable medium of claim 7, wherein FAR is derived via FAR=(WF36DMD/3600)/WA4Model, wherein WF36DMD comprises a current demand for the gas turbine fuel, for air, or for a combination thereof, and wherein WA4Model comprises an airflow model configured to receive the speed signal and the pressure signal to derive an expected airflow by using a lookup table.

10. The non-transitory computer-readable medium of claim 7, wherein the gas turbine fuel comprises a LHV fuel and wherein the controller is configured to control operations of the gas turbine system by comparing the LHV to a heating value range, and by increasing fuel flow when the LHV is below the heating value range, and by decreasing fuel flow when the LHV is above the range.

11. The non-transitory computer-readable medium of claim 7, wherein the plurality of signals comprises a fuel heating value signal derived via a gas chromatograph or a Wobbe meter, and wherein the LHV is compared to a second LHV derived from the fuel heating value signal to provide for redundant operations.

12. A method for a gas turbine system, comprising:

receiving a plurality of signals comprising a temperature signal, a pressure signal, a speed signal and a mass flow signal from sensors disposed in the gas turbine system;

executing a heating value model to derive a Lower Heating Value (LHV) for a gas turbine fuel combusted by the gas turbine system, using the plurality of signals as input to the heating value model;

controlling operations of the gas turbine system based on the LHV derived via the heating value model, wherein the heating value model comprises at least one LHV dynamic equation configured to use as input at least a plurality of enthalpy values, a fuel-to-air ratio and a value for sensed mass air flow into a combustor, wherein the LHV dynamic equation comprises LHV=(HFL*(WAR36+FAR+1.0)−

H3/FAR)−

C, wherein HFL comprises a first enthalpy of the gas turbine fuel having a range of between 30 to 60 Wobbe numbers, FAR comprises the fuel-to-air ratio, H3 comprises a second enthalpy, C comprises a constant, and WAR36 comprises the value for sensed mass air flow into the combustor and sensed via the mass flow signal.

13. The method of claim 12, comprising using a first lookup table and the combustion flame temperature to derive HFL and a second lookup table and the combustion flame temperature to derive H3.

14. The method of claim 12, wherein FAR is derived via FAR=(WF36DMD/3600)/WA4Model, wherein WF36DMD comprises a current demand for the gas turbine fuel, for air, or for a combination thereof, and wherein WA4Model comprises an airflow model configured to receive the speed signal and the pressure signal to derive an expected airflow by using a lookup table.