gas & coal oxy-combustion feasibility studies · case 1. oxy-fired usc pc key design features...
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© 2016 Electric Power Research Institute, Inc. All rights reserved.
George Booras
Principal Technical Leader
P66 Advisory Meeting
Orlando, FL
September 13, 2016
Gas & Coal Oxy-Combustion
Feasibility StudiesInterim Results
2© 2016 Electric Power Research Institute, Inc. All rights reserved.
Detailed Economic Feasibility Study of
Advanced Fossil Power
Detailed engineering-economic feasibility study of atmospheric pressure Oxy-Fired USC PC Plant with CO2 capture
Essentially an update of EPRI Report 1021782, Aug. 2011
‒ Nominal 700 MW plant size
‒ 600⁰C steam conditions with PRB coal
Includes Oxy-Fired Natural Gas Cases
‒ Cases similar to those in 2015 IEA GHG Report by Amec Foster Wheeler
‒ Cycles using recycled CO2
‒ Semi-Closed Oxy-Combustion Combined Cycle (SCOC-CC)
‒ NET Power – Allam Cycle
‒ Cycles using mainly H2O
‒ Modified S-Graz Cycle
‒ Clean Energy Systems (CES)
Report to be published December 2016 (3002008148)
3© 2016 Electric Power Research Institute, Inc. All rights reserved.
Study Cases
Number Coal Steam Conditions Plant Net Power CO2 Capture
1 PRB 600°C / 620°C 700 MWe 90%
Number Description Plant thermal input CO2 capture
2 Semi-Closed Oxy-Combustion
Combined Cycle (SCOC-CC)
2 x 620 MWth
(Equivalent to 2 F-class gas
turbines, suitable for 60 Hz)
90%
3 NET Power – Allam Cycle Same thermal input of case 2 90%
4 Modified S-Graz Cycle Same thermal input of case 2 90%
5 Clean Energy Systems (CES) Same thermal input of case 2 90%
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Main Design Basis
The site location is Kenosha, Wisconsin, a greenfield site typical of power
generation facilities located in Middle America and having access to water and
rail transportation, with a reference ambient temperature of 15°C (59°F).
The plant has access to raw water, mainly used as make-up water for the
cooling water system (based on forced draft cooling towers).
The steam turbine is designed to operate in normal conditions with an exhaust
steam condensing pressure of 0.0677 bara (2” Hg), corresponding to 38.4°C
(101°F).
CO2 capture rate is set to 90% for all the cases. CO2 is delivered at plant BL at
the supercritical conditions (152 barg, 30°C) and purity >99.0% wt (< 0.1 ppmv
moisture content)
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Case 1. Oxy-fired USC PCMain Design Basis
The as-received PRB coal has the following main characteristics:
– Moisture = 30.2 wt %
– Ash = 5.3 wt %
– Sulfur = 0.37 wt %
– Heating Value (HHV) = 8,340 Btu/lb (19.4 MJ/kg)
The ultra-supercritical steam conditions are:
‒ Main steam: 290 bar / 600 °C (4200 psi / 1110°F)
‒ Reheat steam: 60 bar / 620 °C (870 psi / 1150°F)
‒ Condenser pressure = 2.0 in. Hg (0.0677 bar)
Generic low pressure pumped oxygen air separation unit,
– Oxygen purity = 97% by vol.
Combustion efficiency = 92% (LHV basis)
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Case 1. Oxy-fired USC PCBlock Flow Diagram
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Case 1. Oxy-fired USC PCKey Design Features
Two streams of recycle flue gas are required for the oxy-combustion system.
– The Primary recycle stream, taken downstream the final contact cooler,
which passes through the coal mills, is used for drying and transportation
of the pulverized fuel to the burners.
– The Secondary recycle stream, taken downstream the fabric filter,
provides the additional gas heat capacity to the burners to maintain
temperatures within the furnace similar to those of air firing boilers.
The combined primary and secondary gas recycle is approximately 69% of
the original flue gas leaving the economizer.
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Case 1. Oxy-fired USC PCUSC PC Boiler Scheme
(*) as % wt of the flue gas leaving the economizer
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Case 1. Oxy-fired USC PCKey Design Features
CO2 Purification Unit is based on sour compression technology for nitrogen oxide
removal and auto-refrigerated technology for inerts removal. Three flash vessel
are required to meet 90% CO2 capture at required purity (99% wt min)
De-SOx is not required to meet emission limits as sulfur oxides (SOx) are
removed in the compression section of the CO2 purification unit as sulfuric acid.
In oxy-combustion plant, a small FGD could be required to lower the sulfur
content in the furnace and limit corrosion issues. However, in the specific study
case, firing PRB, the sulfur content in the furnace recirculation remains below
2000 ppm normally considered as the threshold level for the corrosion issues.
De-NOx is not required as nitrogen oxides (NOx) are removed in the
compression section of the CO2 purification unit as nitric acid.
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Case 1. Oxy-fired USC PCPerformance Summary
(1) including step-up transformer losses
Case 1
USC PC Boiler
Coal flowrate k lb/h 940.1
Thermal input (LHV/HHV basis) MWth 2,125 / 2,298
Gross Electric Power Output MWe 1,010.8
Auxiliary power demand (1) MWe 297.2
Net Electric Power Output MWe 713.6
Net Electrical Efficiency (LHV/HHV basis) % 33.6 / 31.1
Net Plant Heat Rate (LHV/HHV basis) Btu/kWh 10,158 / 10,974
CO2 removal efficiency % 90.1
Fuel consumption per net power production MWth / MWe 2.98
CO2 emission per net power production kg/MWh 104.1
CO2 emission per net power production lb/MWh 229.4
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Case 2, 3, 4, 5. Oxy-fired TurbineMain Design Basis
Natural gas, available at 35 bar, has a heating value of 47.9 MJ/kg (LHV)
and a total inert content (nitrogen, CO2) lower than 2%.
Plant capacity is selected in order to fully load two gas turbines, equivalent to
the commercially available, air-fired, heavy duty F-class turbine, in terms of
thermal duty, mass flowrates and temperature profile.
3% oxygen excess in the combustion chamber, accounting also the oxygen
in the recycle gas
Pressure ratio is fixed in order to keep the same temperature increase
through the compressor of the reference air blown plant (SCOC-CC, S-Graz)
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Case 2, 3, 4, 5. Oxy-fired TurbineTurbine Design Parameters Definition
Combustor outlet temperature (COT): Flue gas temperature at combustor outlet
Turbine inlet temperature (TIT): Flue gas total temperature at first gas turbine stator outlet,
after mixing with the first cooling flow.
Turbine outlet temperature (TOT): Flue gas temperature at gas turbine expander outlet
Pressure ratio: ratio between that gas turbine compressor outlet pressure (P1) and the
compressor inlet pressure (P0)
NATURAL GAS
OXYGEN
RECYCLE GAS FLUE GAS
TIT
COT
first stator
Pressure ratio = P1/P0
P0
P1
TOT
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Case 2. SCOC-CCMain Design Basis
Power island including:
– Two F-class equivalent oxy-fired gas turbines
– Two heat recovery steam generators (HRSG), generating steam at two levels of
pressure, plus a LP integrated deaerator:
– Two recycle gas indirect contact cooling systems
– One steam turbine, water-cooled and condensing type, common to the two parallel trains
Turbine parameters as detailed below:
– Combustor outlet temperature: 1530°C
– Maximum allowable metal temperature: 860/830 °C (1st / other stator), 830/800 °C (1st /
other rotor)
– Expander inlet pressure: 45 bar (NG compressor required)
Generic low pressure air separation unit, producing 97 % vol purity oxygen at 55 bar
CO2 Purification Unit, including sour gas compression and purification, TSA, auto-
refrigerated Inerts Removal section and final CO2 compression. Three flash vessel process
is required to meet 90% CO2 capture at required purity (99% wt min)
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Case 2. SCOC-CCPower Island Scheme
NG
Gas Turbine
O2
HRSG
ST
Waste Water
CO2 to CPU
1,529°C (2,784°F)
45 bar (650 psi)
1.06 bar (15.4 psi)
610°C (1,130°F)
NG Compressor
Condenser
0.0677 bar
(2” Hg)
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Case 3. NET Power CycleMain Design Basis
Plant based on two power and CO2 cycles, each including:
– One oxy-combustion direct-fired CO2 turbine
– One main heat exchanger (MHE), for recycled gas pre-heating, compact multi-channel
plate-fin type
– One recycled gas compression loop
– NG compressor
Turbine parameters as detailed below:
– Combustor outlet temperature: 1150 °C
– Maximum allowable metal temperature: 860 °C
– Expander inlet pressure: 300 bar / expander outlet pressure: 34 bar
Generic low pressure air separation unit, producing 99.5% vol purity oxygen at 120 bar
CO2 Purification Unit, including TSA, auto-refrigerated Inerts Removal section and final CO2
compression. Two flash vessels are required to meet 90% CO2 capture at required purity
(99% wt min)
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Case 3. NET Power CyclePower and CO2 Cycle Scheme
NG
sCO2 turbine
300 bar (4,350 psi)
1,150°C (2,102°F)
34 bar (490 psi)
740°C (1,365 °F)O2
CO2 to CPU
< 400°C
(< 750°F)718°C
(1,325°F)
Heat input from
ASU air compressor
O2 +
CO2
CO2
Waste Water
NG Compressor
CoolerCooler
Recycle stream
80 bar
(1,160 psi)
100 - 120 bar
(1,450 - 1,740 psi)
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Case 4. Modified S-Graz CycleMain Design Basis
Power island composed by two trains, each including:
– One F-class equivalent oxy-fired gas turbine
– One heat recovery steam generator (HRSG) generating steam at one pressure level
– One back pressure steam turbine expanding the steam to the pressure level required for turbine blade
cooling (HPT)
– Wet flue gas compression and low pressure steam turbine (LPT)
– Recycled gas compression train (part of the gas turbine package)
Turbine parameters as detailed below, in line with SCOC-CC:
– Combustor outlet temperature: 1530 °C
– Maximum allowable metal temperature: 860/830°C (1st / other stator), 830/800°C (1st / other rotor)
– Expander inlet pressure: 45 bar (NG compressor required)
Generic low pressure air separation unit, producing 97 % vol purity oxygen at 55 bar
CO2 Purification Unit, including sour gas compression and purification, TSA, auto-refrigerated Inerts
Removal section and final CO2 compression. Three flash vessel process is required to meet 90% CO2
capture at required purity (99% wt min)
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Case 4. Modified S-Graz CyclePower Island Scheme
O2NG
HPT
HRSG
HHT
CO2 to CPU
Steam
LPT
WaterWaste Water
45 bar (650 psi)
1,529 °C (2,785°F)
1.05 bar
(15.2 psi)
170 bar (2,465 psi)
550°C (1,022°F)
90% steam
10% CO2
NG Compressor
Condenser
Recycle flue gas Flue gas
BFW
0.0677 bar
(2” Hg)
538 °C
(1,000°F)
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Case 5. Supercritical CESMain Design Basis
Power island composed by two trains, each including:
– One F-class equivalent oxy-fired gas turbine, composed of:
• HP turbine (HPT): combustor and expansion section
• MP turbine (MPT): combustor and expansion section
• LP turbine (LPT): combustor and expansion section.
– One flue gas condenser at vacuum conditions
– Wet flue gas compressor.
– BFW/Steam system for combustor and HPT cooling (steam generated at
supercritical conditions, 350 bar, 650°C)
Generic low pressure air separation unit, producing 97 % vol purity oxygen at 65 bar
CO2 Purification Unit, including sour gas compression and purification, TSA, auto-
refrigerated Inerts Removal section and final CO2 compression. Three flash vessels
are required to meet 90% CO2 capture at required purity (99% wt min)
20© 2016 Electric Power Research Institute, Inc. All rights reserved.
Case 5. Supercritical CESMain Design Basis
HP Turbine parameters as detailed below, in line with NET Power:
– Combustor outlet temperature: 1150°C
– Maximum allowable metal temperature: 860°C
– Expander inlet pressure: 300 bar / expander outlet pressure: 60 bar
MP/LP Turbine parameters as detailed below, in line with SCOC-CC:
– Combustor outlet temperature: 1530°C
– Maximum allowable metal temperature: 860/830°C (1st / other stator),
830/800°C (1st / other rotor)
– MP/LP Expander inlet pressure: 58.5 bar / 7.6 bar
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Case 5. Supercritical CESPower Island Scheme
O2
NG
MPTHPT
CO2 to CPU
Steam
LPT
BFW
Waste Water
300 bar (4,350 psi)
1,150 °C (2,102 °F)
58.5 bar
(848 psi)
7.6 bar
(110 psi)
0.17 bar
(2.5 psi)
NG Compressor
O2 Compressor~23%* ~34%* ~43%*
(*) % wt of the total NG flowrate
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Performance Summary
(1) including step-up transformer losses
OVERALL PERFORMANCECase 2
SCOC-CC
Case 3
NET Power Cycle
Case 4
Modified S-Graz
Cycle
Case 5
Supercritical CES
Cycle
Natural gas flowrate k lb/h 205.6 205.6 205.6 205.6
Thermal input (LHV/HHV basis) MWth 1,240 / 1,373 1,240 / 1,373 1,240 / 1,373 1,240 / 1,373
Gross Electric Power Output MWe 763.6 850 791.4 812
Auxiliary power demand (1) MWe 179.2 185.8 204.1 215.9
Net Electric Power Output MWe 584.4 664.2 587.4 596.1
Net Efficiency (LHV/HHV basis) % 47.1 / 42.5 53.6 / 48.4 47.4 / 42.8 48.1 / 43.4
Net Heat Rate (LHV/HHV basis) Btu/kWh 7,246 / 8,026 6,368 / 7,052 7,200 / 7,975 7,096 / 7,859
CO2 removal rate % 90.4 90.1 90.2 90.2
Fuel consumption per net power
production MWth/MWe 2.12 1.87 2.11 2.08
CO2 emission per net power production kg/MWh 40.9 37.4 41.8 41.7
CO2 emission per net power production lb/MWh 90.1 82.5 92.1 91.9
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