Abstract: A method and system for monitoring a gas turbine engine (20) to predict maintenance requirements. Particles suspended in a gas flow (24, 32) of the engine (20) are monitored and quantified to predict a particle accumulation rate. Monitoring may be done using particle flow sensors (61-63) in a diverted portion (33) of the working gas flow (24), such as in the cooling gas flow (32). Particle sampling (S1-S3) may be done to determine particle size and composition distributions. Particle mass flow rates may then be continuously monitored per engine operating condition, and compared to predetermined values such as a normal upper limit per engine operating condition. An integrated particle mass flow may be used in conjunction with an instantaneous mass flow rate to predict a maintenance requirement. Multiple locations (L1-L3) may be monitored to recognize a maintenance requirement by flow section or component.

Abstract: A method and system for monitoring a gas turbine engine (20) to predict maintenance requirements. Particles suspended in a gas flow (24, 32) of the engine (20) are monitored and quantified to predict a particle accumulation rate. Monitoring may be done using particle flow sensors (61-63) in a diverted portion (33) of the working gas flow (24), such as in the cooling gas flow (32). Particle sampling (S1-S3) may be done to determine particle size and composition distributions. Particle mass flow rates may then be continuously monitored per engine operating condition, and compared to predetermined values such as a normal upper limit per engine operating condition. An integrated particle mass flow may be used in conjunction with an instantaneous mass flow rate to predict a maintenance requirement. Multiple locations (L1-L3) may be monitored to recognize a maintenance requirement by flow section or component.

Abstract: A power generating system (20) includes a generator (22) and a combustion turbine (24) for driving the generator (22). The combustion turbine (24) may have a combustion turbine air inlet (30) for receiving an inlet airflow (25). The power generating system (20) may include an evaporative water cooler (26) or fogging evaporative system (26?) for cooling inlet airflow (25), and an inlet airflow temperature sensor (28) proximate or within the combustion turbine air inlet (30). The inlet airflow temperature sensor (28) may sense a drybulb temperature of the inlet airflow (25) proximate the air inlet (30). A controller (47?) is provided for controlling the cooling of inlet airflow (25) across transient load conditions of the power generating system (20?). This control may be based upon the sensed drybulb temperature used to calculate an approach temperature with respect to the inlet airflow (25?) that is compared to an approach temperature setpoint based on load.

Abstract: A gas turbine system (100) includes a compressor (110) for receiving air and producing compressor discharge air, a combustor (120) for combusting an oxygen comprising gas flow including the discharge air and a fuel into a hot gas flow, and a turbine expander (130) generating output power from the hot gas flow and providing a hot exhaust gas flow. An extractor (135) is provided for splitting the discharge air into a direct flow portion (121) which directly reaches the combustor (120) and an indirect flow portion (122). A mixing device (140) receives the indirect flow portion (122) and mixes it with a water flow (145), either in the form of water or steam, to produce a water enhanced indirect flow portion (150). A recuperative heat exchanger (155) heats the water enhanced indirect flow portion (150) using heat from at least a portion of the hot exhaust gas flow. The heated water enhanced indirect flow portion (158) is then reintroduced into the oxygen comprising gas flow.

Abstract: A gas turbine system (100) includes a compressor (110) for receiving air and producing compressor discharge air, a combustor (120) for combusting an oxygen comprising gas flow including the discharge air and a fuel into a hot gas flow, and a turbine expander (130) generating output power from the hot gas flow and providing a hot exhaust gas flow. An extractor (135) is provided for splitting the discharge air into a direct flow portion (121) which directly reaches the combustor (120) and an indirect flow portion (122). A mixing device (140) receives the indirect flow portion (122) and mixes it with a water flow (145), either in the form of water or steam, to produce a water enhanced indirect flow portion (150). A recuperative heat exchanger (155) heats the water enhanced indirect flow portion (150) using heat from at least a portion of the hot exhaust gas flow. The heated water enhanced indirect flow portion (158) is then reintroduced into the oxygen comprising gas flow.

Abstract: A power generating system (20) includes a generator (22) and a combustion turbine (24) for driving the generator (22). The combustion turbine (24) may have a combustion turbine air inlet (30) for receiving an inlet airflow (25). The power generating system (20) may include an evaporative water cooler (26) or fogging evaporative system (26?) for cooling inlet airflow (25), and an inlet airflow temperature sensor (28) proximate or within the combustion turbine air inlet (30). The inlet airflow temperature sensor (28) may sense a drybulb temperature of the inlet airflow (25) proximate the air inlet (30). A controller (47?) is provided for controlling the cooling of inlet airflow (25) across transient load conditions of the power generating system (20?). This control may be based upon the sensed drybulb temperature used to calculate an approach temperature with respect to the inlet airflow (25?) that is compared to an approach temperature setpoint based on load.

Abstract: A combined cycle power plant (10) utilizing an air injection apparatus (60) for lowering the temperature and raising the mass of the exhaust gas provided to the heat recovery steam generator (22) from the gas turbine portion (12) of the plant. The air injection apparatus is utilized during startup of the plant to permit the gas turbine portion to be operated at a power level sufficiently high to ensure compliance with emissions regulations while at the same time not exceeding an upper exhaust temperature limit for warming the steam generator. The augmented exhaust stream (76) allows the steam generator to more quickly generate enough steam to roll the steam turbine (30), thereby shortening the overall startup sequence.

Abstract: A combined cycle power plant (10) utilizing an air injection apparatus (60) for lowering the temperature and raising the mass of the exhaust gas provided to the heat recovery steam generator (22) from the gas turbine portion (12) of the plant. The air injection apparatus is utilized during startup of the plant to permit the gas turbine portion to be operated at a power level sufficiently high to ensure compliance with emissions regulations while at the same time not exceeding an upper exhaust temperature limit for warming the steam generator. The augmented exhaust stream (76) allows the steam generator to more quickly generate enough steam to roll the steam turbine (30), thereby shortening the overall startup sequence.