EP0821137A1 - System for power generation - Google Patents

System for power generation Download PDF

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Publication number
EP0821137A1
EP0821137A1 EP97202269A EP97202269A EP0821137A1 EP 0821137 A1 EP0821137 A1 EP 0821137A1 EP 97202269 A EP97202269 A EP 97202269A EP 97202269 A EP97202269 A EP 97202269A EP 0821137 A1 EP0821137 A1 EP 0821137A1
Authority
EP
European Patent Office
Prior art keywords
gas
outlet
oxygen
containing gas
turbine
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.)
Withdrawn
Application number
EP97202269A
Other languages
German (de)
French (fr)
Inventor
Maarten Johannes Van Der Burgt
Jacobus Van Liere
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.)
Kema NV
Original Assignee
Kema NV
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
Priority claimed from EP96202076A external-priority patent/EP0821135A1/en
Priority claimed from EP97200464A external-priority patent/EP0821136A1/en
Application filed by Kema NV filed Critical Kema NV
Priority to EP97202269A priority Critical patent/EP0821137A1/en
Publication of EP0821137A1 publication Critical patent/EP0821137A1/en
Withdrawn legal-status Critical Current

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Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K21/00—Steam engine plants not otherwise provided for
    • F01K21/04—Steam engine plants not otherwise provided for using mixtures of steam and gas; Plants generating or heating steam by bringing water or steam into direct contact with hot gas
    • F01K21/047—Steam engine plants not otherwise provided for using mixtures of steam and gas; Plants generating or heating steam by bringing water or steam into direct contact with hot gas having at least one combustion gas turbine

Definitions

  • the present invention relates to a system for power generation from non-gaseous fuels.
  • Such systems generally comprise a turbine system, comprising both gas turbines and steam turbines, and a power generating system.
  • the efficiency of the best known systems for power generation from non-gaseous fuels is about 40 -45 %.
  • the invention therefore provides a system for power generation from non-gaseous fuels comprising a turbine system and a power generating system connected to said turbine system, wherein the said turbine system comprises:
  • the fluid is supplied directly to the oxygen-containing gas in and/or after the compressor means and the cooling is essentially obtained by evaporation of the fluid.
  • the exhaust gas from the gas turbine means is expanded to a sub-atmospheric pressure of 0.2 - 0.8 bara.
  • the exhaust gases leaving the gas turbine means are cooled and water is condensed out.
  • At least part of the exhaust gas from said gas turbine means is recycled to the inlet of the oxygen-containing gas of said compressor means.
  • At least part of the exhaust gas from the gas turbine means is used to supply heat for drying of the fuel in a drier.
  • an organic fuel is used in said power generating system.
  • the flue gas outlet of the combustion means passes through a gas cleaning means.
  • the flue gas is cleaned in the combustion means.
  • fluid to be supplied to the compressor is atomized in the oxygen-containing gas to be fed to the compressor means.
  • Fig. 1-4 flow sheets of power stations according to the present invention.
  • Fig. 1 shows a power station 1 according to the present invention.
  • This power station 1 comprises a compressor unit 2 for quasi-isothermal compression.
  • the compressor unit 2 comprises an oxygen-containing gas inlet 3 and a compressed outlet for oxygen-containing gas 4.
  • the compressor unit 2 is further provided with means 5 for direct water cooling of oxygen-containing gas in the compressor unit.
  • the means 5 comprise a water inlet 6 and waterpipes 7. Furthermore, it is possible to supply water into the compressed oxygen-containing gas outlet 4.
  • the compressor unit 2 is mounted on a shaft 8 to which is connected a turbine 9 and a generator 10.
  • the compressed oxygen-containing gas outlet 4 is connected to a combustion means 11 to which is also added fuel via a fuel inlet 12 via a fuel pressurizing device 13.
  • This fuel is non-gaseous and therefore may consist of particulate fuel, liquid fuel and/or mixtures thereof.
  • the flue gas outlet 14 of the combustion unit 11 is provided with a flue gas cleaning unit 15. Subsequently the flue gas is expanded in the turbine 9 and the exhaust gas leaves the turbine 9 via the turbine exhaust gas outlet 16. This outlet 16 passes through a recuperator 17 for heat exchange with compressed oxygen-containing gas that passes through the recuperator 17 via the compressed oxygen-containing gas outlet 4 of the compressor means 2. Finally the cooled exhaust gas is routed to a stack via duct 18.
  • a by-pass line 19 may be arranged over the combustion and/or cleaning unit providing an opportunity to control the combustion and/or the turbine temperature.
  • Fig. 2 shows a power station 20 of which unit operations and processes similar to those of the power station 1 of Fig. 1 are referred to by using the same reference numbers.
  • the compressor means 2 comprises two consecutive compressors 21 and 22 for compressing oxygen-containing gas to respectively 0,8 bara and 8 bara. After each oxygen-containing compression stage water is directly injected for cooling and to that end the direct water cooling means 5 comprise water inlets 23 and 24.
  • the fuel supplied via the fuel inlet 12 consists of coal which is combusted at a low pressure of 8 bara and slash is removed from the combustion means 11 via the slash outlet 25.
  • the combustion means may consist of a fluidized bed. Cooled flue gas is routed via duct 18 to a stack 32. The efficiency of the power station 20 is about 48.0%.
  • the shaft 8 and the generator 10 are omitted for reasons of clarity.
  • Fig. 3 shows a power station 26 having a lay-out similar to the power station 20 of Fig. 2. Same or equivalent operation units and processes as for the power station 20 are referred to by the same reference numbers in Fig. 2.
  • the power station 26 is provided with a subatmospheric expansion turbine means 27 expanding exhaust gas to a subatmospheric pressure of about 0.5 bara.
  • This flue gas passes through the recuperator 17 and subsequently through a condensor unit 28.
  • heat and condensate are removed in a cooler 29 and a condensor 30 respectively.
  • the cooler 29 may be substituted for another condensor such that two types of condensate may be obtained of which the condensate originating from the condensor 30 is the most pure.
  • the dry cool exhaust gas is compressed in a compressor 31 to atmospheric pressure and subsequently released into the atmosphere via the stack 32.
  • the power station efficiency is about 50%.
  • Fig. 4 shows a power station 33 for firing wet biomass.
  • the lay-out of this power station 33 is similar to the power station 20 of Fig. 2 and similar or equivalent unit operations and processes are referred to by the same reference numbers.
  • biomass supplied via the biomass inlet 12 is first dried in a biomass dryer 34 using the low temperature heat (about 140°C) of the exhaust gas leaving the recuperator 17 via the outlet 35.
  • the dry and heated (110°C) biomass is fed via a pressurizing device 13 to the combustion unit 11. Any combustion ash is removed from the flue gas cleaning unit 15 via the outlet 36.
  • the power station efficiency is dependent on the operation parameters about 50 to 54%.
  • Fig.5 shows a power station 37 for firing wet biomass.
  • the lay-out of this power station 37 is similar to the power station 33 of Fig.4, and similar or equivalent unit operations and processes are referred to by the same reference numbers.
  • the water inlet is connected to an atomizing unit 38 for atomizing water in the air fed to the compressor 22 via the air inlet 3.
  • Water is atomized in an amount of about 12-15 wt% in the oxygen containing gas in the form of droplets (size 1-5 ⁇ m).
  • the power station efficiency is about 55%.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)

Abstract

The invention relates to a system for power generation comprising a turbine system and a power generating system connected to said turbine system, wherein the said turbine system comprises:
  • a) a compressor means (22) provided with an inlet for oxygen-containing gas, an outlet for compressed oxygen-containing gas and inlet means (38) for supplying fluid to said compressor means for cooling the said oxygen-containing gas;
  • b) a combustion means (11) provided with a non-gaseous fuel inlet and a flue gas outlet, said combustion means being connected with the said outlet for compressed oxygen-containing gas of the said compressor means;
  • c) a gas turbine means (9) connected with said flue gas outlet of the said combustion means and being provided with an outlet for exhaust gases;
  • d) a recuperator means (17) connected with 1 the said outlet for compressed oxygen-containing gas of the said compressor means and 2 the said outlet for exhaust gases of the said gas turbine means, for mutual heat exchange.

Description

The present invention relates to a system for power generation from non-gaseous fuels. Such systems generally comprise a turbine system, comprising both gas turbines and steam turbines, and a power generating system. At present the efficiency of the best known systems for power generation from non-gaseous fuels is about 40 -45 %. In such systems for power generation there is a need to improve their performance and their efficiency. It is an object of the present invention to provide a system for power generation having an increased efficiency, in particular above 45% and more in particular 46-57%.
The invention therefore provides a system for power generation from non-gaseous fuels comprising a turbine system and a power generating system connected to said turbine system, wherein the said turbine system comprises:
  • a) a compressor means connected with an inlet for oxygen-containing gas, an outlet for compressed oxygen-containing gas and inlet means for supplying fluid to said compressor means for cooling the said oxygen-containing gas;
  • b) a combustion means provided with a non-gaseous fuel inlet and a flue gas outlet, said combustion means being connected with the said outlet for compressed oxygen-containing gas of the said compressor means;
  • c) a gas turbine means connected with said flue gas outlet of the said combustion means and being provided with an outlet for exhaust gases;
  • d) a recuperator means connected with 1 the said outlet for compressed oxygen-containing gas of the said compressor means and 2 the said outlet for exhaust gases of the said gas turbine means, for mutual heat exchange;
In an advantageous embodiment of the present invention the fluid is supplied directly to the oxygen-containing gas in and/or after the compressor means and the cooling is essentially obtained by evaporation of the fluid.
Further, advantageously, the exhaust gas from the gas turbine means is expanded to a sub-atmospheric pressure of 0.2 - 0.8 bara.
In another advantageous embodiment the exhaust gases leaving the gas turbine means are cooled and water is condensed out.
In another advantageous embodiment of the invention at least part of the exhaust gas from said gas turbine means is recycled to the inlet of the oxygen-containing gas of said compressor means.
Still more advantageously, at least part of the exhaust gas from the gas turbine means is used to supply heat for drying of the fuel in a drier.
Advantageously an organic fuel is used in said power generating system.
Advantageously the flue gas outlet of the combustion means passes through a gas cleaning means.
Further advantageously the flue gas is cleaned in the combustion means.
More advantageously the exhaust gases leaving the gas turbine means are cleaned.
Still more advantageously the exhaust gases routed to the stack are cleaned.
Advantageously part of the heat developed in the power generating system is used for heating purposes.
More advantageously the condensation takes place in two consecutive steps.
Preferably fluid to be supplied to the compressor is atomized in the oxygen-containing gas to be fed to the compressor means.
The present invention will now be described in more detail by way of example by reference to the accompanying drawings, in which:
  • Fig.1 represents schematically a power generation system according to the present invention;
  • Fig.2 represents schematically an advantageous embodiment of the present invention;
  • Fig.3 represents schematically another advantageous embodiment of the present invention;
  • Fig.4 represents schematically still another advantageous embodiment of the present invention; and
  • Fig.5 represents a preferred embodiment of the present invention.
    • The drawings show in:
    Fig. 1-4 flow sheets of power stations according to the present invention.
    Fig. 1 shows a power station 1 according to the present invention. This power station 1 comprises a compressor unit 2 for quasi-isothermal compression. The compressor unit 2 comprises an oxygen-containing gas inlet 3 and a compressed outlet for oxygen-containing gas 4. The compressor unit 2 is further provided with means 5 for direct water cooling of oxygen-containing gas in the compressor unit. Thereto the means 5 comprise a water inlet 6 and waterpipes 7. Furthermore, it is possible to supply water into the compressed oxygen-containing gas outlet 4.
    The compressor unit 2 is mounted on a shaft 8 to which is connected a turbine 9 and a generator 10.
    The compressed oxygen-containing gas outlet 4 is connected to a combustion means 11 to which is also added fuel via a fuel inlet 12 via a fuel pressurizing device 13. This fuel is non-gaseous and therefore may consist of particulate fuel, liquid fuel and/or mixtures thereof.
    The flue gas outlet 14 of the combustion unit 11 is provided with a flue gas cleaning unit 15. Subsequently the flue gas is expanded in the turbine 9 and the exhaust gas leaves the turbine 9 via the turbine exhaust gas outlet 16. This outlet 16 passes through a recuperator 17 for heat exchange with compressed oxygen-containing gas that passes through the recuperator 17 via the compressed oxygen-containing gas outlet 4 of the compressor means 2. Finally the cooled exhaust gas is routed to a stack via duct 18.
    It is noted that a by-pass line 19 may be arranged over the combustion and/or cleaning unit providing an opportunity to control the combustion and/or the turbine temperature.
    Fig. 2 shows a power station 20 of which unit operations and processes similar to those of the power station 1 of Fig. 1 are referred to by using the same reference numbers. In power station 20 the compressor means 2 comprises two consecutive compressors 21 and 22 for compressing oxygen-containing gas to respectively 0,8 bara and 8 bara. After each oxygen-containing compression stage water is directly injected for cooling and to that end the direct water cooling means 5 comprise water inlets 23 and 24.
    In this case the fuel supplied via the fuel inlet 12 consists of coal which is combusted at a low pressure of 8 bara and slash is removed from the combustion means 11 via the slash outlet 25. In this case the combustion means may consist of a fluidized bed. Cooled flue gas is routed via duct 18 to a stack 32. The efficiency of the power station 20 is about 48.0%. Finally it is noted that the shaft 8 and the generator 10 are omitted for reasons of clarity.
    Fig. 3 shows a power station 26 having a lay-out similar to the power station 20 of Fig. 2. Same or equivalent operation units and processes as for the power station 20 are referred to by the same reference numbers in Fig. 2.
    The power station 26 is provided with a subatmospheric expansion turbine means 27 expanding exhaust gas to a subatmospheric pressure of about 0.5 bara. This flue gas passes through the recuperator 17 and subsequently through a condensor unit 28. In the condensor unit 28 heat and condensate are removed in a cooler 29 and a condensor 30 respectively. The cooler 29 may be substituted for another condensor such that two types of condensate may be obtained of which the condensate originating from the condensor 30 is the most pure.
    Subsequently, the dry cool exhaust gas is compressed in a compressor 31 to atmospheric pressure and subsequently released into the atmosphere via the stack 32.
    The power station efficiency is about 50%.
    Fig. 4 shows a power station 33 for firing wet biomass. The lay-out of this power station 33 is similar to the power station 20 of Fig. 2 and similar or equivalent unit operations and processes are referred to by the same reference numbers.
    Wet biomass supplied via the biomass inlet 12 is first dried in a biomass dryer 34 using the low temperature heat (about 140°C) of the exhaust gas leaving the recuperator 17 via the outlet 35. The dry and heated (110°C) biomass is fed via a pressurizing device 13 to the combustion unit 11. Any combustion ash is removed from the flue gas cleaning unit 15 via the outlet 36.
    The power station efficiency is dependent on the operation parameters about 50 to 54%.
    Finally, Fig.5 shows a power station 37 for firing wet biomass. The lay-out of this power station 37 is similar to the power station 33 of Fig.4, and similar or equivalent unit operations and processes are referred to by the same reference numbers.
    The water inlet is connected to an atomizing unit 38 for atomizing water in the air fed to the compressor 22 via the air inlet 3. Water is atomized in an amount of about 12-15 wt% in the oxygen containing gas in the form of droplets (size 1-5 µm). The power station efficiency is about 55%.
    It will be appreciated that various modifications of the present invention will be apparent to those skilled in the art from the foregoing description. Such modifications are intended to fall within the scope of the appended claims.

    Claims (15)

    1. A system for power generation comprising a turbine system and a power generating system connected to said turbine system, wherein the said turbine system comprises:
      a) a compressor means connected with an inlet for oxygen-containing gas, an outlet for compressed oxygen-containing gas and inlet means for supplying fluid to said compressor means for cooling the said oxygen-containing gas;
      b) a combustion means provided with a non-gaseous fuel inlet and a flue gas outlet, said combustion means being connected with the said outlet for compressed oxygen-containing gas of the said compressor means;
      c) a gas turbine means connected with said flue gas outlet of the said combustion means and being provided with an outlet for exhaust gases;
      d) a recuperator means connected with 1 the said outlet for compressed oxygen-containing gas of the said compressor means and 2 the said outlet for exhaust gases of the said gas turbine means, for mutual heat exchange;
    2. The system as claimed in claim 1 wherein said fluid is directly supplied to the oxygen-containing gas in and/or after the compressor means and the cooling is essentially obtained by evaporation of said fluid.
    3. The system as claimed in any of claims 1-2, wherein the said exhaust gases from the said gas turbine means are expanded to a sub-atmospheric pressure of 0.2-0.8 bara.
    4. The system as claimed in any of the claims 1-3, wherein the exhaust gases leaving the gas turbine system are cooled and water is condensed out.
    5. The system as claimed in any of the claims 1-4, wherein at least part of the exhaust gas from said gas turbine means is recycled to the said inlet for oxygen-containing gas of said compressor means.
    6. The system as claimed in any of the claims 1-5, wherein the fuel is dried in a dryer for which the heat required is taken from the exhaust gas from the gas turbine means.
    7. The system as claimed in any of the claims 1-6, wherein the non-gaseous fuel is an organic material.
    8. The system as claimed in any of the claims 1-7, wherein the flue gas outlet of the combustion passes through a gas cleaning unit.
    9. The system as claimed in any of the claims 1-8, wherein the gas is cleaned during combustion.
    10. The system as claimed in any of the claims 1-9, wherein the exhaust gases are cleaned after leaving the gas turbine means.
    11. The system as claimed in any of the claims 1-10, wherein the exhaust gases which are routed to the stack are cleaned.
    12. The system as claimed in any of the claims 1-11, wherein part of the heat developed in the power generating system is applied for heating purposes.
    13. The system as claimed in any of the claims 1-12, wherein condensation takes place in two consecutive steps.
    14. The system as claimed in any of the claims 1-13, wherein the inlet means for fluid comprise means for atomizing said fluid in the oxygen-containing gas.
    15. The system as claimed in claim 14, wherein fluid is atomized in an amount of up to 12-15% by weight in the oxygen containing gas in the form of droplets having a size of about 1-5 µm.
    EP97202269A 1996-07-22 1997-07-22 System for power generation Withdrawn EP0821137A1 (en)

    Priority Applications (1)

    Application Number Priority Date Filing Date Title
    EP97202269A EP0821137A1 (en) 1996-07-22 1997-07-22 System for power generation

    Applications Claiming Priority (5)

    Application Number Priority Date Filing Date Title
    EP96202076 1996-07-22
    EP96202076A EP0821135A1 (en) 1996-07-22 1996-07-22 Energy generation by means of a combined gas and coalcycle
    EP97200464 1997-02-17
    EP97200464A EP0821136A1 (en) 1996-07-22 1997-02-17 System for power generation
    EP97202269A EP0821137A1 (en) 1996-07-22 1997-07-22 System for power generation

    Publications (1)

    Publication Number Publication Date
    EP0821137A1 true EP0821137A1 (en) 1998-01-28

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    EP97202269A Withdrawn EP0821137A1 (en) 1996-07-22 1997-07-22 System for power generation

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    Cited By (4)

    * Cited by examiner, † Cited by third party
    Publication number Priority date Publication date Assignee Title
    EP0959235A2 (en) 1998-05-20 1999-11-24 Hitachi, Ltd. Gas turbine power plant
    NL1009484C2 (en) 1998-06-24 1999-12-27 Kema Nv Device for compressing a gaseous medium
    NL1011383C2 (en) 1998-06-24 1999-12-27 Kema Nv Apparatus for compressing a gaseous medium and systems comprising such an apparatus.
    EP1609958A1 (en) * 2004-06-22 2005-12-28 Siemens Aktiengesellschaft Gasturbine with compressor and recuperator

    Citations (9)

    * Cited by examiner, † Cited by third party
    Publication number Priority date Publication date Assignee Title
    GB1056722A (en) * 1964-01-15 1967-01-25 Arthur Morton Squires Improvements in or relating to power-generating steam cycle
    GB1284335A (en) * 1970-04-15 1972-08-09 Rolls Royce Improvements in or relating to gas turbine engines
    US4893469A (en) * 1988-01-07 1990-01-16 Yasui Yamashita Steam and combustion gas engine
    EP0361065A1 (en) * 1988-09-28 1990-04-04 Westinghouse Electric Corporation Power generating method using solid fuel for a gas turbine
    EP0384336A1 (en) * 1989-02-22 1990-08-29 Mario Gaia A method and equipment for converting thermal energy into mechanical energy
    EP0444913A1 (en) * 1990-02-27 1991-09-04 Turbine Developments Aktiengesellschaft A gas turbine
    US5067317A (en) * 1990-02-26 1991-11-26 The United States Of America As Represented By The United State Department Of Energy Process for generating electricity in a pressurized fluidized-bed combustor system
    DE4335136A1 (en) * 1992-10-22 1994-04-28 Evt Energie & Verfahrenstech Gas prodn. for gas turbine operation - in combined gas and steam turbine power station
    EP0602795A2 (en) * 1992-11-13 1994-06-22 Foster Wheeler Energy Corporation Circulating fluidized bed reactor combined cycle power generation system

    Patent Citations (9)

    * Cited by examiner, † Cited by third party
    Publication number Priority date Publication date Assignee Title
    GB1056722A (en) * 1964-01-15 1967-01-25 Arthur Morton Squires Improvements in or relating to power-generating steam cycle
    GB1284335A (en) * 1970-04-15 1972-08-09 Rolls Royce Improvements in or relating to gas turbine engines
    US4893469A (en) * 1988-01-07 1990-01-16 Yasui Yamashita Steam and combustion gas engine
    EP0361065A1 (en) * 1988-09-28 1990-04-04 Westinghouse Electric Corporation Power generating method using solid fuel for a gas turbine
    EP0384336A1 (en) * 1989-02-22 1990-08-29 Mario Gaia A method and equipment for converting thermal energy into mechanical energy
    US5067317A (en) * 1990-02-26 1991-11-26 The United States Of America As Represented By The United State Department Of Energy Process for generating electricity in a pressurized fluidized-bed combustor system
    EP0444913A1 (en) * 1990-02-27 1991-09-04 Turbine Developments Aktiengesellschaft A gas turbine
    DE4335136A1 (en) * 1992-10-22 1994-04-28 Evt Energie & Verfahrenstech Gas prodn. for gas turbine operation - in combined gas and steam turbine power station
    EP0602795A2 (en) * 1992-11-13 1994-06-22 Foster Wheeler Energy Corporation Circulating fluidized bed reactor combined cycle power generation system

    Cited By (7)

    * Cited by examiner, † Cited by third party
    Publication number Priority date Publication date Assignee Title
    EP0959235A2 (en) 1998-05-20 1999-11-24 Hitachi, Ltd. Gas turbine power plant
    US6247302B1 (en) 1998-05-20 2001-06-19 Hitachi, Ltd. Gas turbine power plant
    US6397578B2 (en) 1998-05-20 2002-06-04 Hitachi, Ltd. Gas turbine power plant
    NL1009484C2 (en) 1998-06-24 1999-12-27 Kema Nv Device for compressing a gaseous medium
    NL1011383C2 (en) 1998-06-24 1999-12-27 Kema Nv Apparatus for compressing a gaseous medium and systems comprising such an apparatus.
    US6453659B1 (en) 1998-06-24 2002-09-24 N. V. Kema Device for compressing a gaseous medium and systems comprising such device
    EP1609958A1 (en) * 2004-06-22 2005-12-28 Siemens Aktiengesellschaft Gasturbine with compressor and recuperator

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