行政院國家科學委員會專題研究計畫成果報告
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- 迈偕 濮
- 5 years ago
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1 ( )
2 15 26% STIG Cycle ( GE 6B GE 7B) i
3 60% NO x ii
4 ABSTRACT In Taiwan, many existing simple-cycle gas turbine generation sets (GENSET) that were originally designated as peak load units can be started up in a very short time(say 15 minutes), but suffer from very low efficiency (around 26%). Unfortunately, the simple-cycle units are forced to operate entire summer daytime due to the power shortage in Taiwan. In addition, the power generation of gas turbine degrades significantly during summer peaking hours (when electricity is most needed) due to the hot ambient temperatures. The aim of this research is to evaluate the feasibility of retrofitting these simple-cycle units into more advanced cycle with higher power output and efficiency. A computer code was developed to evaluate the performance improvement of different modifications for simple cycle GENSETs. The accuracy of our developed code was validated by simulating the actual GE Frame 6B and 7B simple-cycle GENSETs. The results from computer simulation indicated that the steam injection gas turbine (STIG) cycle with regenerator was found to be the most effective in boosting both the power output and thermal efficiency among many proven technologies. From thermoeconomic analysis, the retrofitting project with STIG and regeneration features also has the best rate of return. In the consideration of local hot/humid weather and the complication of retrofitting, the integration of STIG and inlet air cooling (IAC) was also iii
5 proposed in this study. This integrated system can boost 60% of power output under hot and humid weather condition and greatly depress the emission of NO x. The performance of this system is less sensitive to ambient temperature, and its heat-to-power ratio can be swiftly adjusted to meet the actual demand. iv
6 ...i...iii... v v
7 vi
8 % (simple-cycle gas turbine generation system, GENSET) 27 %( 1.1 ) ( ) (peak and intermediate load) 1.1 ISO 15 (60 ) 32 (90 ) 12 % (heat rate, kcal/kw-h) 4 %( 4 %) ( ) (retrofit) 500 1
9 2
10 1.1 (, 1999) (MW) (%) () () (WH)W501B* 4 (GE)MS7001B* 4 (FIAT)TG16* 4 (GE)MS7001EA* ( ) 3
11 1.1 ( GE-MS7001B ) 4
12 1-2 (Performance improvement methods) Brayton cycle (high back-work-ratio) () (Increase turbine inlet temperature) turbine inlet temperature, TIT () (Increase component efficiency) ( ) 87 % (90 %) 5
13 () (Adding modifications to basic cycle) (1) (Inlet air cooling, IAC) (evaporative cooling) (vapor compression refrigeration) (absorption chiller) (thermal energy storage system) (2) (Intercooling) (3) (Regeneration) 6
14 (gas to gas recuperation) (4) (Reheating) () (Waste-heat recovery):, (1) (Cogeneration Combined heat-and-power, CHP) fossil fuels (2) Combined cycle 1.2 (topping cycle) (Heat Recovery 7
15 Steam Generator, HRSG) (steam turbine) (bottoming cycle) (3) (Steam injection gas turbine, STIG) 1.3 (HRSG) HRSG h Cp T NOx 8
16 (after-burner, ) (4) HAT(Humid air turbine)cycle (Evaporation Cycle) (Chemical Recuperation Gas Turbine, CRGT)Kalina Cycle HAT cycle Evaporation cycle STIG ( ) STIG CRGT Kalina cycle (CRGT) (Kalina) ( ) 9
17 1.2 stack gas Process Steam feed water HRSG injection stream fuel Combustion Chamber Air Compressor Gas Turbine Generator
18 1-3 () Heppenstall (1998) (combined cycle)stig HAT(humid air turbine)kalina CRGT(chemical recuperation gas turbine) Najjar (2001, 2000, 1996) Pilavachi (2000) (European Union) McDonald (1996) ( ) Annerwall (1991) ( ) Pak (1989, 1990) TIT STIG (exergy) exergy loss TIT 11
19 HRSG (Pak, 1997) (Horlock, 2000) STIG (Penning, 1996; Rice, 1995) Larson (1987) STIG STIG Cheng (1992) STIG Saad (1992,1997) STIG Bram (1997) ASPEN Kim (2000) HAT Harvey (1997) CRGT (Harvey, 2001) () (absorption refrigeration) (low grade) (prime mover) (Mostafavi, 1998; Bruno, 1999) Mone (2001) 12
20 (Hadik, 1990), (Najjar, 1996) Lucia(1996) (IAC) Sundbom (1994) (off-peak) (Hufford, 1991; Mohanty, 1995) ABSIM (1998) Grossman (1994) ABSIM ( ) () quantity quality (exergy analysis) quality (Kotas, 1985; Horlock, 1992; Bejan, 1996) El-Marsi (1987)Habib (1994)Doldersun (1998)Facchini (2000) 13
21 thermoeconomic analysis (Bejan, 1996; Tsatsaronis, 1996) (Guarinello, 2000; Massardo, 2000) Valero (1994)Frangopolus (1994) Cerqueira (1999) Krause (1999) Tsatsaronis (1997) Kim (1997) El-Sayed (1999)Bejan (1996) (exergy-costing equation) (retrofitting) STIG IAC 14
22 STIG IAC 15
23 2-1 (Equation of state) (Dalton s law for mixtures of ideal gas) (Maxwell Relation) ( ) (subroutine) quantity quality (exergy analysis) (exergy loss) 16
24 17
25 (The ideal Brayton cycle) (Bryton cycle) 2.1 (Van Wylen, 1994) 1 η = (2-1) 1 k 1 k ( P2 P1 ) (irreversibility) (2-1) 2-1(b)P-V ( back work) 40% 18
26 2-2-2 (steady state) (control volume) (1) (mass rate balance) i mi = me e (2-2) mi i me e (2) (energy rate balance) W cv = Q cv + i 1 mi hi + Vi gz i e 1 me he + V 2 2 e + gz e (2-3) W cv Q cv (3) (entropy rate balance) Q j S gen = + mi si me se (2-4) Tj i e gen (entropy generation rate) S m i si 19
27 m e se Q j T j Q j T j (4) (exergy rate balance) E D = E q, j j W cv + i i E e E e (2-5) E D (exergy destruction rate) E q, j T 0 T T j = 0 E q, 1 Q j T j E i = mi ei e = me ee E j (e) (physical exergy) (chemical exergy) e + PH CH = e e (2-6) PH ( e ) e PH ( h h ) ( 0 T0 s s0 = ) (2-7) T0 20
28 h0 0 T s0 0 T CH ( e ) Bejan(1996) (gases) CH (gas mixtures) ( e CH CH k ek = x + RT x ln x (2-8) x k 0 k k k e CH e k k (kj/kmol) R (=8.314 kj/kmol-k) n h = x k h k= 1 k (2-9) n s = x k sk k= 1 (2-10) n hk k (kj/kmol) s k k (kj/kmol-k) 21
29 ( ) CO 2 H 2 O (Bejan, 1996) s ( T, P ) k k 0 x P P 0 k = s k ( T ) R ln (2-11) ref s k ( T ) k T Pref x k P k k k P P ref ( ) 22
30 2-2-3 (generation efficiency, g ) W net ηgen η g = (2-12) m f (LHV ) η gen (utilization factor, UF) UF W net ηgen + Q p = m f (LHV ) (2-13) Q p (process heat demand) (exergy efficiency, ) E R E R ε = = (2-14) E S E R + E D E S (supplied) E R (recovered) E D (2-5) 23
31 (1) steady state (quasi steady state) (2) 2 (Low heating valvelhv) (adiabatic) (3) (4) 303K MPa (5) (6) (7) 1% 3% 5 %(Bejan, 1996) Irvine and Liley (1984) Bejan (1996) (subroutine) (N 2, O 2, CO 2, H 2 O ) 24
32 (Ideal Gas Law) - (Gibbs-Dalton s Law) (Bejan, 1996) (physical exergy) (chemical exergy) ( ) (1) (Air compressor, ac) m1 = m2 (2-15) xco 2 W ac = m ( h 2 1 ) 2 h2 m1 h1 = n a h (2-16) n a h h1 2 (kj/kg) h1 2 h (kj/kmol) =77.48=20.59 xn 2 x O 2 =0.03=1.9 h xh 2 O [ x h N2 + x ho2 + x hco2 x h H O ]( ) = (2-17) T N 2 O2 CO2 H 2O 1 25
33 h 2 = h 1 h 2s h + η s, ac 1 s h2 T ( ) 2s P s 2s N2 2s 1 ln P s1 = x s ( T ) s ( T ) R + x s ( T ) s ( T ) N2 O2 2s 1 P 2 R ln P x s ( T ) s ( T ) R ln + x s ( T ) s ( T ) R ln = 0 CO2 2s 1 P P 1 CO2 H 2O 2s 1 P P 1 P2 r = (iteration) T 2s P 1 s h2 (2-9) [ x h N2 + x ho2 + x hco2 x h H O ]( T ) h2s N O CO H O 2 2s H 2O = (2-18) O2 E D, ac = W ac ( E 2 E1) (2-19) PH CH E 1 = E1 + E1 = 0 PH = PH CH PH E 2 E 2 + E 2 = E 2 ( 1 ) = ( 2 ) E 2 n 2[ h 2 h0 T ( s 2 s0)] 0 [ h0 = x h N2 + x ho2 + x hco2 + x h H2O ]( T ) N 2 O2 CO2 H2O 0 s 0 = [ x s N2 + x so2 + x sco2 + x s H2O ]( T ) N 2 O2 CO2 H 2O 0 s 2 = [ x s N2 + x so2 + x sco2 x s H 2O ]( T, x ) + P N 2 O2 CO2 H 2O 2 k 2 26
34 s N 2 s O 2 s CO 2 s H 2 O (2-11) E R E 2 E1 ε = ac = (2-20) E S W ac (2) (gas turbine, gt) 4 = m5 m (2-21) W gt = m ( h4 5 ) 4 h m 4 5 h = n 5 4 h W net = W gt W ac = n ( 4 5 ) 1( 2 1) 4 h h n h h (2-22) (2-23) E D, gt = ( E 4 E 5) W net (2-24) 5 = E PH CH E 5 + E 5 PH = n 5 5[ h5 h0 T ( s5 s0 )] E [ s5 = x s N2 + x so2 + x sco2 + x s H 2O ]( ) N 0 2 O2 CO T 2 H 2O x x x x O N 2 O 2 CO 2 H
35 ( h 4 h s ) h = h 4 η 5 s, gt 5 s h5 T 5s P s 5s N2 5s 4 ln P s 4 = x s ( T ) s ( T ) + R + x s ( T ) s ( T ) N 2 O 2 5s 4 P5 + R ln P x s ( T ) s ( T ) + R ln + x s ( T ) s ( T ) + R ln 0 CO 2 5s 4 P P 4 CO 2 H 2 0 5s 4 = P4 H O T 5s s h5 [ x h N2 + x ho2 + x hco2 x h H O ]( T ) h5s = N O CO H O 2 5s P O 2 2 CH E 5 CH = n5( e5 ) CH e5 (2-8) E R = W net ε = (2-25) gt E S E 4 E 5 (3) (combustion chamber, cc) fuel-air ratio n f λ = (2-26) n a f n n a 28
36 (steam injection ratio) w = ms (2-27) ma m s m a w = ns (2-28) na n s n P = ( 1+ λ + w) na (2-29) ( ) λ CH [ x N + x O + x CO + x H O] wh O 4 + N2 2 O2 2 CO2 2 H 2O ( ) + + w x N + x O + x CO + x H O N2 O2 CO2 H 2O λ (2-30) 1 2 x N2 xn2 = 1+ λ + w x O2 xo 2λ 2 = 1+ λ + w x CO2 xco + λ 2 = 1+ λ + w x H2 O = x H2O + 2λ + w 1+ λ + w 29
37 4 = m3+ m10 + m13 m = m a + m f + ms (2-31) n4 h4 Qcv + n10 h10 + n3 h3 + n13 h13 = (2-32) Qcv Qcv = 0.02n10 LHV ( 1 + w) λLHV = h3 + λh10 + wh13 λ h (2-33) h3 4 h (CH 4 ) LHV = kj/kmol x h + x h + x h + x h + wh ( T ) N N2 O O2 CO CO2 H O H2O H2O 4 λ = (2-34) h LHV ( 2hO2 + hco2 + 2h H2O )( T ) 4 h T 3 T 4 (dew point temperature) 30
38 E D, cc = E 3+ E 10 + E13 E 4 (2-35) 3 = E PH CH PH E 3 + E 3 = E 3 [ h3 h0 T ( s3 )] 0 PH 3 = n 3 0 s E PH CH E 4 E 4 E 4 = + PH = n 4 4[ h 4 h0 T ( s 4 s0 )] E 0 (2-9) 0 h (2-10)0 s CH E 4 CH = n 4( e4 ) (2-36) CH e4 (2-8) PH CH E10 E10 E10 = + (2-37) PH 10 = 10[ h10 h0 T0 ( s10 s0 )] E m CH E 10 = CH n10( ech4 ) PH CH E13 E13 E13 = + (2-38) PH 13 = 13[ h ( 13 h0 T0 s13 s )] 0 E m CH E 13 = CH n13( eh2o ) E R E 4 ε = = cc (2-39) E S E 3+ E 10 + E 13 31
39 (4) (HRSG) 6 = m 7 m 8 = m9 + m13 m (2-40) n6( h6 h7 ) = m8( h h ) + m13( h h h7 = [ x h N2 + x ho2 + x hco2 + x h H O ]( ) h7 N O CO H O 2 T T7 ) (2-41) T 7 (stack gas temperature) T 7 400K (127 ºC) HRSG E D,HRSG = E 6 + E 8 E7 E 9 E 13 (2-42) E = E PH CH E7 PH 7 = n 7[ h7 h0 T ( s 7 s 0 )] E 0 CH E 7 CH = n7( e7 ) CH e7 (2-8) PH CH E 8 E 8 E 9 = + 32
40 PH CH E 9 E 9 E 9 = + HRSG E E 9 + E 13 E R 8 ε = = (2-43) HRSG E S E 6 E 7 (5) (regenerator, reg) 2 = m3 m 5 = m6 m (2-44) n2 ( h3 h 2 ) = n5( h5 h6 ) (2-45) h 6 h [ x h N2 + x ho2 + x hco2 + x h H O ]( ) 6 = N 2 2 O T 2 CO2 H2O 6 T6 E D, reg = ( E 5 E 6) ( E 3 E 2) (2-46) 6 = E PH CH E 6 E 6 + PH = n 6 6[ h6 h0 T ( s6 s0 )] E 0 CH E 6 CH = n6( e6 ) CH e6 (2-8) 33
41 E R E 3 E 2 ε = = (2-47) reg E S E 5 E 6 (exergy loss) 34
42 2-4 (TIT) GE Frame 6B 2.4 ISO 2.1 Improved STIG cycle2.5 gas to gas recuperation regenerator (verification) GE Frame 6B 2.1 ISO 1atm288 K 38.34MW 31.4 TIT 38.2W s,ac s,gt (sensitivity analysis)
43
44 4 7 (stack loss) 10 (chemical exergy) STIG (irreversibility) STIG (mixing) (stack loss) 773 K(500 ) HRSG HRSG HRSG 37
45 MW MW 49.8 MW ( ) (75 %) HRSG % 2.11 (utilization factor, UF) 38
46 UF UF STIG (heat-to-power ratio) after burner or duct burner 2.11 UF 50 % 39
47 (a) (b) (c) 2.1 P-V T-S 40
48 fuel
49 regenerator 3 m 5 m 6 m 2 m fuel steam injection 3 m 4 m 10 m 13 m Combustion Chamber gas turbine 4 m 5 m net output HRSG steam injection process stack 8 m 9 m 6 m 7 m 13 m air air compressor 1 m 2 m work work
50 2.4 GE Frame 6B 43
51 stack gas Qp Process Steam feed water HRSG 6 steam injection 13 Fuel 10. m f Air Compressor 2 Regenerator. Wc 11 3 Combustion Chamber... m a +m s +m f 4 Gas Turbine 5. W net 12 Generator 1. m a
52 60 Power output (MW) T 0 =288K, TIT = 1380K Simple Cycle STIG Compression ratio (r) 2.6 STIG 45
53 Power output (MW) STIG(w=0.1) Simple Cycle TIT = 1380K power output generation efficiency ISO STIG (w=0.1) Simple Cycle Ambient temperature (K) Power generation efficiency (%)
54 60 Exergy destruction rate (MW) r = 13, T 0 = 303K, TIT = 1380K Simple Cycle (output = 36.7MW) STIG ( w=0.1) (output = 49.8MW) HRSG stack gas combustor 0 compressor turbine regenerator
55 1.5 Exergy destruction rate per MW output r = 13, T 0 = 303K, TIT = 1380K Simple Cycle ( output = 36.7MW) STIG (w=0.1) ( output = 49.8MW) stack gas HRSG compressor turbine regenerator combustor
56 Exergy efficiency compressor turbine regenerator combustor HRSG r =13, T 0 = 303K, TIT = 1380K Steam injection ratio
57 60 r =13, T 0 = 303K, TIT = 1380K Efficiency (%) UF η g Steam injection ratio
58 2.1 GE Frame 6B ISO turbine inlet temperature compression pressure ratio net power output heat rate exhaust flow rate exhaust temperature nominal shaft speed 1380K(2020) 11.8: MW 11,457(kJ/kWh) (kg/s) 812K 5100rpm 2.2 s,gt = 0.85 s,gt = 0.86 s,gt = 0.87 s,ac = 0.85 s,ac = 0.86 s,ac = 0.87 W (MW) g (%) W (MW) g (%) W (MW) g (%)
59 2.3 ( r =11.8, T 0 =303K, TIT=1380K ) Power output (MW) Generation efficiency (%) Simple cycle Inlet air cooling Regenerator Steam injection turbine inlet temperature 1380K(2020) compressor inlet temperature 303K pinch point temperature difference of HRSG 30K compressor efficiency 0.85 turbine efficiency 0.86 generator efficiency compression pressure ratio 13:1 mass flow rate of air (kg/s) mass flow rate of process steam 6.39(kg/s) low heating value (LHV) of fuel 802,361(kJ/kmol) chemical exergy of fuel 824,348(kJ/kmol) pressure of injected-steam 1.63 MPa pressure of injected-fuel 1.70 MPa pressure loss of combustor / HRSG 5% pressure loss of regenerator 3% pressure loss of compressor / turbine 1% 52
60 2.5 state point pressure P (MPa) temperature T(K) mass flow rate exergy flow rate (MW) m(kg/s) physical chemical Total
61 3-1 (Inlet-air-cooling system) (Hadik, 1990)1.1 GE-MS7001B ISO 15 (60 ) 32 (90 ) 12 % (heat rate, kcal/kw-hr) 4 %( 4 %) ( 36~37) (Inlet-air-cooling, IAC) (Najjar, 1996Lucia, 1996) 54
62 (1) (evaporative cooling system) (wet-bulb) (Ondryas, 1991) (2) (vapor compression refrigeration system) (cooling coil) (Ondryas, 1991) (3) (thermal energy storage system) (off-peak) (Sundbom, 1994) (4) (absorption refrigeration system) (low grade) 55
63 ( ) CFC (Mone, 2001) (moving parts) (partial load) (Mostafavi, 1998) COP ( ) 120 (0.2MPa) 175( HRSG ( ) 4 HRSG STIG IAC STIG ( )IAC ( 56
64 ) (condensate) STIG HRSG STIG STIG 57
65 IAC STIG 3.1 CFC (heat-driven) 3.2 ( ) (Desorber, D) ( ) (Condenser, C) (Evaporator, E) (Absorber, A) (weak solution) 58
66 ( K) (coil) 283 K(10) 3.3 (optimum) (flexible) (dew-point) (10) (air-washing) 59
67 (Stewart, 1999) 3.2 COP( ) ( 35~40) HRSG HRSG (feed water) HRSG 60
68 3-3 STIG IAC GE MS7001B GE MS7001B (Oak Ridge National Laboratory) ABSIM (Absorption simulation modular code, 1998) UA (Grossman, 1994) 61
69 ( ) mi = 0 i X i i i m = 0 (3-1) m h i = 0 (3-2) i i ( UA)( LMTD) = 0 Q (3-3) i i i ( P, T, X ) = 0 f (3-4) i i i (Mitsubishi, 2000) ABSIM 62
70 3-3-2 GE MS7001B K(991) 783 K(510) (kg/s) 3600 rpm ISO (15) 59 MW( )60.3 MW( ) %( BTU/kW-h)31.05 %( BTU/kW-h) STIG IAC 3.1 HRSG 3.3 (erosion) 400 K STIGIAC () (Steam injection gas turbine cycle, STIG) 63
71 1.41 MPa(Cheng, 2000) 0.2 MPa(Mitsubishi, 2000)4.3 HRSG m4 = m5 m7 = m8 (3-5) HRSG ( T 5 =400 K) ( h4 h5 ) + m8( h h ) + m14( h = n4 h HRSG ) (3-6) E D, HRSG = E 4 + E 6 + E 8 E 5 E 7 E 14 (3-7) HRSG E R ( E14 E 6) + ( E 7 E 8) ε = = (3-8) HRSG E S E 4 E 5 () (Absorption refrigeration cycle) 3.3 (single effect) 0.2 MPa (1kg/cm 2 G) 8.5 kg/hr (double 64
72 effect ) 0.9 MPa (8 kg/cm 2 G) 4.5 kg/s 280 K (7) m7 = m 10 m = m 8 9 (3-9) (desorber or generator) Q D h 4 = m ( h4 h5 ) m6 ( h14 6) (3-10) (coefficient of performance, COP) (evaporator) Q Q E COP abs = (3-11) D E D, ABS = E 7 + E 9 + E15 E 8 E 10 E16 (3-12) 65
73 () (Inlet air cooler) - (280 K) 283 K 3.3 (indirect type) (cooling coil) 283 K(10) (air side) Q iac = ( ha1 + ω1hv1) ( ha 0 + ω0hv 0) + ( ω0 ω1) h (3-13) l1 m a1 h (kj/kg) a1 h (kj/kg) a0 h (kj/kg) l1 ω (kg H 2 O/kg dry air) 1 ω0 (kg H 2 O/kg dry air) (Hufford, 1991) = a m l1 m 1( ω ω1) (3-14) 0 66
74 E D, iac = E10 + E 0 E1 E 9 (3-15) (3-5) (3-15) IAC 67
75 3-4 GE MS7001B GE MS7001B ISO 1atm288 K r = 9.0TIT = 1264 K 783 K 60.3 MW( ) (heat rate = BTU/kW-h) 60.5 MW ISO 3.5 ( ) 288 K (ISO ) 305 K 14 %(60.5 MW 52.2 MW) ( ) 12 %(60.3 MW 53.0 MW) (heat rate) 7.5 %( % 29.1 %) 5 %(31.05 % 29.5 %) ( ) 68
76 ABSIM 3.6 (COP) 0.74 COP COP HRSG COP 3.7 COP 0.8 COP ( T 5 =400 K) (full injection) w= MW w= K 293 K 85.3 MW w=
77 K( ) 88.2 MW (w=0.11) (283 K) 84.3 MW STIG IAC K 88.2 MW (85.5 MW) STIG IAC (32, 80 %RH) %RH 3.6 kg/s(12.96 Ton/hr) ( w= kg/s) (10 ) COP HRSG STIG IAC 3.2 ( ) ( T K) 70
78 52.14 MW MW STIG IAC MW 0.39 (54.4 MW) STIG IAC MW (0.6) 3.2 ( 3.57 MW 0.87 MW) 3.2 ( MW IAC MW IAC+STIG MW) (MW) ( 2.61 MW IAC 2.58MW IAC+STIG 1.99 MW)
79 HRSG 3.9 STIG IAC 72
80 turbine inlet temperature ambient temperature 3.1 ( GE MS7001B ) 1264K 305K compressor efficiency 0.85 turbine efficiency 0.86 generator efficiency compression pressure ratio 9:1 mass flow rate of air low heating value (LHV) of fuel chemical exergy of fuel pressure of injected-steam pressure of injected-fuel (kg/s) 802,361(kJ/kmol) 824,348(kJ/kmol) 1.41 MPa 1.70 MPa pressure loss of combustor / HRSG 5 % pressure loss of compressor / turbine 1 % desorber inlet temperature of absorption chiller desorber inlet pressure of absorption chiller supply chilling water temperature of absorption chiller return chilling water temperature of absorption chiller supply cooling water temperature of absorption chiller 393 K 0.2 MPa 285K 280K 305K 73
81 3.2 (T 0 = 305K, r = 9, TIT = 1264K) System Existing Simple cycle IAC Cycle STIG cycle + IAC Power output (MW) Power generation efficiency Component E D (MW) E D (MW) E D (MW) Compressor Combustor Turbine Stack-loss HRSG Absorption Chiller Inlet Air Cooler E D E D /MW output
82 3.1 75
83 3.2 76
84 3.3 77
85 3.4 GE MS7001B 78
86 80 45 Power output (MW) Power output TIT = 1264K, r = 9.0 Simulation results Manufacture's data Efficiency Power generation efficiency (%) 20 ISO Condition Taiwan Local Ambient temperature (K)
87 COP =
88 COP of absorption chiller Saturated Steam to absorption chiller Desorber P 7 =0.2MPa (single effect) Desorber P 7 =0.9MPa (double effect) Evaporator, chiller water supply, T10=280K Evaporator, chiller water return, T9=285K double-effect Single-effect Cooling water temperature, T15 (K) 3.7 COP 81
89 90 Full injection w=0.19 w= Power output (MW) 70 T 1 limit with inlet air cooling w=0.15 w=0.14 w=0.13 w= simple-cycle r = 9, TIT=1264K Compressor inlet air temperature (K)
90 1.5 Exergy destruction rate per MW output Combustion Chamber Gas Turbine Air Compressor TIT=1264K, r = 9, T0=305K STIG+IAC (output = MW) IAC (output = MW) SIMPLE (output = MW) HRSG Absorption Inlet Chiller Air Cooler Stack
91 4-1 ( ) (thermoeconomic analysis) (Agazzani, 1997; Massardo, 2000) (exergoeconomics) (Tsatsaronis, 1997) (exergy-aided cost minimization) ( ) (Bejan, 1996) quantity quality (exergy analysis) 84
92 (exergy costing balance) 4-1 (a) HRSG (CHP only)(b) HRSG (CHP+STIG)(c) HRSG (CHP+STIG+REG) 85
93 4-2 ( ) ( ) ($/s) CI OM P, tot = C F, tot + Z tot + Z tot (4-1) C C P,tot (product) ($/s) C F,tot (fuel) ($/s) CI Z tot (capital investment) ($/s) OM Z tot (operating and maintenance) (levelized) CI OM = Z tot + Z tot (4-2) Z (levelized cost) (inflation rate) (escalation rate) (purchase equipment cost, PEC) (Massardo, 2000) 86
94 Z ( PEC) k ( CRF) = N 3600 φ k k (4-3) φk (φ k =1.09 9%) PEC k k (Bejan, 1996) Massardo (2000) N CRF (capital recovery factor) CRF = n i( 1+ i) n ( 1 + i) 1 n i (exergy) (exergy cost rate) = c E C (4-4) c ($/kj) E = m e (kw) (exergy costing balance) i ( c i, k E i, k ) + ( cq, k E q, k ) + Z k = ( ce, k E e, k ) + cw, k W cv, k e (4-5) k k 87
95 c i c e c w c q 88
96 (1) C1+ C11+ Z ac = C 2 (4-6) ac Z (2) 4 + Z gt = C 5 + C11+ C12 C (4-7) Z gt C 12 C 511 C 12 C 2 c 4 = c5 ( E 4 E 5 ) c 11 = c12 ( E ) E (3) 3 C 13 C 10 Z cc C 4 C = (4-8) Z cc 89
97 C 13 C 10 (4) 2 + C 5 + Z reg = C 3+ C 6 C (4-9) Z reg C 5 6 C 1 c 5 = c6 ( 5 E 6 E ) (5) 6 C 8 Z hrsg C7 C 9 C 13 C + + = + + (4-10) Z hrsg C 79 C 13 C 2 c6 = c7 6 (HRSG E 7 E ) c9 = c13 9 (HRSG E 13 E ) 90
98 4-4 (GE Frame 6B) ( ) ( 4.1 ) n=15 i=7.5% φ k = (Massardo, 2000)φ k =1.06 N= NT$/m 3 ( 6.5 US$/GJ) (PEC) (HRSG ) (Bejan, 1996) (salvage value) 1/3 4.1 case(c) (CHP+STIG) (34.94 MW MW) (TIT=1380K) ( 28% 33%) 91
99 (CHP+STIG+REG) (38 %) (UF) 20% UF 50% (UF = 0.51) 4.2 (CHP+STIG) (45.32 MW MW) MW MW HRSG( ) HRSG 4.3 STIG (MW) (STIGREG) 4.4 ( ) 92
100 () ($/GJ) ($/GJ) 16.56($/GJ) 5.1 c 12 = 14.59($/GJ) C 7 =401.73($/hr) E 9 E ( 8 12 E ) (weighting) ( ) 20.1 $/GJ ( 73 $/MWh) ($/GJ) 93
101 4.1 (case c) state pressure temperature mass flow exergy flow rate (MW) cost flow cost per exergy point (MPa) (K) rate (kg s -1 ) physical chemical Total rate ($ h -1 ) unit ($ GJ -1 )
102 4.2 W net (MW) g UF ( Q p Product Q p + W net ) Cost ($ GJ -1 ) Component compressor regenerator combustor turbine HRSG stack CHP % Ė D (MW) CHP + STIG % Ė D (MW) CHP + STIG + REG % Ė D (MW)
103 5 stack gas 8 feed water HRSG fuel Process Steam Combustion 2 Chamber 3 1 Air Compressor 11 Gas 12 Turbine (a) Generator 8 feed water 5 HRSG stack gas 9 injection stream 13 fuel Process Steam Combustion Chamber 3 1 Air Compressor 11 Gas 12 Turbine (b) Generator fuel (c) (a) CHP only (b) CHP with STIG (c) CHP with STIG and Regeneration 95
104 regenerator 3 C 5 C 6 C 2 C fuel steam injection 3 C 4 C 10 C 13 C Combustion Chamber gas turbine 4 C 5 C power output HRSG steam injection process stack 8 C 9 C 6 C 7 C 13 C air air compressor 1 C 2 C work
105 Exergy destruction rate per MW output combustor r = 11.8, T 0 = 303K, TIT = 1380K STIG+Reg ( output = 51.39MW) STIG ( output = 52.08MW) CHP ( output = 34.94MW) stack HRSG turbine compressor regenerator
106 40 cost of electricity ($ GJ -1 ) r =11.8, T 0 =303K, TIT=1380K CHP STIG cycle STIG+Reg current electricity price current fuel price cost of fuel ($ GJ -1 )
107 99
108 100
109 ABSIM version 5.0. (1998) Modular simulation of absorption systems user s guide and reference. Oak Ridge National Laboratory, Tennessee. Agazzani, A. and Massardo A.F. (1997) A tool for thermoeconomic analysis and optimization of gas, steam, and combined plants, Journal of Engineering for Gas Turbines and Power, Vol. 119, pp Annerwall, K and Svelberg, G. (1991) A study on modified gas turbine systems with steam injection or evaporative regeneration, ASME COGEN-TURBO, IGTI, Vol. 6, pp ASHRAE Handbook-Fundamental, (2001) American Society of Heating Refrigeration and Air-Conditioning Engineers. Badran, O.O. (1999) Gas-turbine performance improvements, Applied Energy, Vol.64, pp Bejan, A., Tsatsaronis G. and Moran, M. J. (1996) Thermal Design and Optimization, John Wiley & Sons, New York. Bidini, G. and Bosio, A. (1989) A second-law analysis of intercooled gas turbine combined cycles, ASME COGEN-TURBO, IGTI, Vol. 4, pp Bisio, G., (1998) Thermodynamic analysis of the main devices for thermal energy upgrading, Energy Conversion and Management, Vol. 39, pp Bram, S. and De Ruyck, J. (1997) Exergy analysis tools for ASPEN applied to evaporative cycle design, Energy Conversion and 101
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114 Energy Conversion and Management, Vol. 42, pp Massardo, S.A. and Scialo, M. (2000) Thermoeconomic analysis of gas turbine based cycles, Journal of Engineering for Gas Turbine and Power, Vol.122, pp McDonald, C.F. and Wilson, D.G. (1996) The utilization of recuperated and regenerated engine cycles for high-efficiency gas turbines in the 21 st century, Applied Thermal Engineering, Vol.16, pp Mitsubishi Inc. (2000) Catalogue of absorption chiller for standard rating. Mohanty B. and Paloso, G. (1995) Enhancing gas turbine performance by intake air cooling using an absorption chiller, Heat Recovery System & CHP, Vol. 15, pp Mone, C.D., Chau, D.S. and Phelan, P.E., (2001) Economic feasibility of combined heat and power and absorption refrigeration with commercially available gas turbines, Energy Conversion and Management, Vol. 42, pp Moran, M. J. and Sciubba, E. (1994) Exergy analysis principles and practice, Journal of Engineering for Gas Turbines and Power, Vol. 116, pp Mostafavi, M., Alaktiwi, A. and Agnew, B. (1998) Thermodynamic analysis of combined open-cycle-twin-shaft gas turbine (Brayton cycle) and exhaust gas operated absorption refrigeration unit, Applied Thermal Engineering, Vol. 18, pp Najjar, Y. S. H. (1996) Enhancement of performance of gas turbine engines by inlet air cooling and cogeneration system, Applied Thermal Engineering, Vol. 16, pp
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117 inlet air cooling, ASME COGEN-TURBO, IGTI, Vol. 9, pp Szargut, J., Morris, D. R. and Steward, F. R. (1988) Exergy Analysis of Thermal, Chemical and Metallurgical Processes, Hemisphere, New York. Talbi, M.M. and Agnew, B. (2000) Exergy analysis: an absorption refrigerator using lithium bromide and water as the work fluids, Applied Thermal Engineering, Vol. 20, pp Tsatsaronis, G. and Moran, M. J. (1997) Exergy-aided cost minimization, Energy Conversion and Management, Vol. 38, pp Tsatsaronis, G. and Pisa, J. (1994) Exergoeconomic evaluation and optimization of energy system application to the CGMA problem, Energy, Vol. 19, pp Tuzson, J. (1992) Status of steam-injected gas turbine, Journal of Engineering for Gas Turbines and Power, Vol. 114, pp Valero, A., Lozano M.A., Serra, L., Tsatsaronis, G., Pisa, J., Frangopoulos, C. and Spakovsky, M.R.V. (1994) CGAM problem: definition and conventional solution, Energy, Vol. 19, pp Van Wylen, G.J. Sonntag, R.E. and Borgnakke, C. (1994) Fundamentals of Classical Thermodynamics, John Wiley & Sons, New York. Zhang, Z. and Pate, M.B. (1988) A methodology for implementing a psychrometric chart in a computer graphics system, ASHRAE Transactions, Vol. 94, pp
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