NOx Emissions from Stationary Gas Turbines - US Environmental ...

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For wet injection plus SCR, the combined cost effectiveness ranges <strong>from</strong> $4,460 for a 3.3 MW (4,430 hp) application to $988 for a 160 MW (216,000 hp) site. The $645 cost-effectiveness value for the 83 MW (111,000 hp) turbine is lower than the other turbine models shown in Figure 2-10 due to 2-36
2-37
Page 1 and 2: Alternative Control Techniques Docu
Page 3 and 4: TABLE OF CONTENTS Section Page 1.0
Page 5 and 6: TABLE OF CONTENTS (continued) Secti
Page 7 and 8: LIST OF FIGURES (continued) Figure
Page 9 and 10: LIST OF FIGURES (continued) Figure
Page 11 and 12: LIST OF TABLES (continued) Table Pa
Page 13 and 14: 1.0 INTRODUCTION Congress, in the C
Page 15 and 16: 2.0 SUMMARY This chapter summarizes
Page 17 and 18: TABLE 2-1. UNCONTROLLED NO EMISSION
Page 19 and 20: flame temperatures. This control te
Page 21 and 22: Figure 2-2. Uncontrolled NO emissio
Page 23 and 24: 2-9
Page 25 and 26: gas and coal have achieved controll
Page 27 and 28: emoved, are shown in Section 2.3.2.
Page 29 and 30: These capital costs include both wa
Page 31 and 32: Figure 2-4. Capital costs for dry l
Page 33 and 34: Figure 2-5. Capital costs, in $/MW,
Page 35 and 36: Figure 2-6. Capital costs for selec
Page 37 and 38: Figure 2-7. Capital costs, in $/MW,
Page 39 and 40: 2-25
Page 41 and 42: 2-27
Page 43 and 44: Figure 2-8. Cost effectiveness of c
Page 45 and 46: For water injection, cost effective
Page 47 and 48: Figure 2-9. Cost effectiveness for
Page 49: Figure 2-10. Combined cost effectiv
Page 53 and 54: Figure 2-11. Controlled NO emission
Page 55 and 56: equirements and may result in incre
Page 57 and 58: 3.0 STATIONARY GAS TURBINE DESCRIPT
Page 59 and 60: Figure 3-1. The three primary secti
Page 61 and 62: Figure 3-2. Types of gas turbine co
Page 63 and 64: 3-49
Page 65 and 66: 3-5
Page 67 and 68: which can vary over as wide a range
Page 69 and 70: Figure 3-6. Simple cycle gas turbin
Page 71 and 72: Figure 3-7. Regenerative cycle gas
Page 73 and 74: 3-13
Page 75 and 76: Figure 3-8. Cogeneration cycle gas
Page 77 and 78: Figure 3-9. Combined cycle gas turb
Page 79 and 80: 3-19
Page 81 and 82: 3.3.2 Stand-By/Emergency Electric P
Page 83 and 84: are being negotiated. Capital costs
Page 85 and 86: shows, DOE expects 36,000 MW of com
Page 87 and 88: Figure 3-11. Capital costs for elec
Page 89 and 90: 3-29
Page 91 and 92: 11. Reference 8, p. 3-43. 12. Refer
Page 93 and 94: The major contributing chemical rea
Page 95 and 96: shows the flame temperature and equ
Page 97 and 98: 6. N + OH º NO + H, and further to
Page 99 and 100: currently a major contributor to ov
Page 101 and 102:
Figure 4-2. Thermal NO production a
Page 103 and 104:
As is shown in Figure 4-3 4-12
Page 105 and 106:
, DF-2 burns at a flame temperature
Page 107 and 108:
substantially lower thermal NO x em
Page 109 and 110:
This effect of humidity and tempera
Page 111 and 112:
H = observed humidity of ambient ai
Page 113 and 114:
4-22
Page 115 and 116:
Uncontrolled emission factors are p
Page 117 and 118:
4.4 REFERENCES FOR CHAPTER 4 1. Con
Page 119 and 120:
24. Letters and attachments from Le
Page 121 and 122:
TABLE 5-1. NO x EMISSION LIMITS AS
Page 123 and 124:
TABLE 5-2. NO COMPLIANCE LIMITS AS
Page 125 and 126:
5-34
Page 127 and 128:
This chapter discusses the control
Page 129 and 130:
5-38
Page 131 and 132:
TABLE 5-4. WATER QUALITY SPECIFICAT
Page 133 and 134:
(HRSG) that recovers the gas turbin
Page 135 and 136:
TABLE 5-5. MANUFACTURER'S GUARANTEE
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distillate oil fuels, respectively,
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increases. As shown in Tables 5-5 a
Page 141 and 142:
5.1.4 Achievable NO Emissions Level
Page 143 and 144:
Figure 5-3. Uncontrolled NO emissio
Page 145 and 146:
5-54
Page 147 and 148:
75 ppmv for most oil-fired turbines
Page 149 and 150:
Figures 5-4, 5-5, and 5-6 present t
Page 151 and 152:
Figure 5-5. Nitrogen oxide emission
Page 153 and 154:
for water injection on turbines fir
Page 155 and 156:
Figure 5-8. Nitrogen oxide emission
Page 157 and 158:
approximately 30 to 135 ppm, with W
Page 159 and 160:
5-68
Page 161 and 162:
5-70
Page 163 and 164:
again shows that higher WFR's are r
Page 165 and 166:
Figure 5-11. Nitrogen oxide emissio
Page 167 and 168:
TABLE 5-7. ACHIEVABLE GAS TURBINE N
Page 169 and 170:
Figure 5-12. Comparison of the WFR
Page 171 and 172:
5-80
Page 173 and 174:
5-82
Page 175 and 176:
Gas turbine model TABLE 5-8. UNCONT
Page 177 and 178:
As an example, a 21.8 MW turbine bu
Page 179 and 180:
shows the impact of water injection
Page 181 and 182:
Figure 5-14. Like CO emissions, hyd
Page 183 and 184:
5-92
Page 185 and 186:
5.1.6 Impacts of Wet Controls on Ga
Page 187 and 188:
5.1.7 Impacts of Wet Controls on Ga
Page 189 and 190:
As this table shows, the maintenanc
Page 191 and 192:
5.2 COMBUSTION CONTROLS The formati
Page 193 and 194:
For combustors with reduced residen
Page 195 and 196:
5 shows a comparison of NO emission
Page 197 and 198:
Figure 5-6. Cross-section of a lean
Page 199 and 200:
Figure 5-17. Operating modes for a
Page 201 and 202:
5-110
Page 203 and 204:
Figure 5-18. Cross-section of lean
Page 205 and 206:
35,48 Figure 5-19. Cross-section of
Page 207 and 208:
48 Figure 5-20. Low-NO x burner for
Page 209 and 210:
5-118
Page 211 and 212:
For operation on distillate oil wit
Page 213 and 214:
Figure 5-21. "Stepped" NO and CO em
Page 215 and 216:
shows these stepped NO emissions le
Page 217 and 218:
shows the emissions for a silo comb
Page 219 and 220:
The emission levels shown in Figure
Page 221 and 222:
water injection. Subsequent emissio
Page 223 and 224:
at base load for No. 2 fuel oil are
Page 225 and 226:
5-134
Page 227 and 228:
TABLE 5-14. POTENTIAL NO REDUCTIONS
Page 229 and 230:
TABLE 5-15. COMPARISON OF NO AND CO
Page 231 and 232:
Figure 5-24. The CO emission test r
Page 233 and 234:
5-142
Page 235 and 236:
and are in the range of 0 to 2 ppmv
Page 237 and 238:
Figure 5-25. Nitrogen oxide emissio
Page 239 and 240:
Figure 5-26. Effects of fuel bound
Page 241 and 242:
5-150
Page 243 and 244:
5-152
Page 245 and 246:
An ammonia injection grid is locate
Page 247 and 248:
increased using a zeolite catalyst
Page 249 and 250:
In addition to the locations shown,
Page 251 and 252:
installation using oil fuel, a Unit
Page 253 and 254:
egan operating recently and have li
Page 255 and 256:
combined cycle applications to acco
Page 257 and 258:
of this waste could be costly. Some
Page 259 and 260:
. Ammonia slip levels were not repo
Page 261 and 262:
5-170
Page 263 and 264:
Figure 5-29 shows a typical natural
Page 265 and 266:
installation. Figure 5-30 is a cros
Page 267 and 268:
5-176
Page 269 and 270:
73,75 Figure 5-31. Low-NO x duct bu
Page 271 and 272:
77 TABLE 5-19. NO x EMISSIONS MEASU
Page 273 and 274:
5-182
Page 275 and 276:
5.6.2 Methanol Methanol has a flame
Page 277 and 278:
The NO emissions from firing methan
Page 279 and 280:
methanol and natural gas. Reduction
Page 281 and 282:
62 to 100 ppm for natural gas. In a
Page 283 and 284:
Figure 5-33. A lean catalytic combu
Page 285 and 286:
Catalytic combustors can also be de
Page 287 and 288:
of gas turbine combustors. Addition
Page 289 and 290:
8. Letter and attachment from Swing
Page 291 and 292:
33. Schorr, M. NO Control for Gas T
Page 293 and 294:
55. Cutrone, M., and M. Hilt (Gener
Page 295 and 296:
78. Backlund, J., and A. Spoormaker
Page 297 and 298:
6.0 CONTROL COSTS Capital and annua
Page 299 and 300:
TABLE 6-1. GAS TURBINE MODEL PLANTS
Page 301 and 302:
plant for this turbine. As a result
Page 303 and 304:
for each model plant. Fuel rates we
Page 305 and 306:
2 . Water (or steam) injection rate
Page 307 and 308:
. These costs were developed based
Page 309 and 310:
6-218
Page 311 and 312:
turbines, the water treatment syste
Page 313 and 314:
TABLE 6-5. ANNUAL COSTS FOR WATER A
Page 315 and 316:
determine the fuel penalty for each
Page 317 and 318:
plants that use diesel fuel instead
Page 319 and 320:
6-228
Page 321 and 322:
The uncontrolled and controlled NO
Page 323 and 324:
. LOW-NO COMBUSTORS x Incremental c
Page 325 and 326:
TABLE 6-7. COST-EFFECTIVENESS SUMMA
Page 327 and 328:
also lower. According to two turbin
Page 329 and 330:
TABLE 6-8. PROCEDURES FOR ESTIMATIN
Page 331 and 332:
TABLE 6-9. CAPITAL AND ANNUAL COSTS
Page 333 and 334:
ii. Annual Costs Total annual costs
Page 335 and 336:
6-244
Page 337 and 338:
facilities as described below and i
Page 339 and 340:
costs are equal to 4 percent of the
Page 341 and 342:
and 6-12, respectively. For continu
Page 343 and 344:
6-252
Page 345 and 346:
TABLE 6-13. COMBINED COST-EFFECTIVE
Page 347 and 348:
figures are calculated by dividing
Page 349 and 350:
sum of the annual reduction of NO e
Page 351 and 352:
without adjustment because there is
Page 353 and 354:
REFERENCES FOR CHAPTER 6 I. 1990 Pe
Page 355 and 356:
XXV. Kolp, D. (Energy Services, Inc
Page 357 and 358:
6-266
Page 359 and 360:
TABLE 7-1. MODEL PLANT UNCONTROLLED
Page 361 and 362:
TABLE 7-1. (continued) Controlled N
Page 363 and 364:
(1) Impacts of Wet Controls on CO a
Page 365 and 366:
in small communities, or in areas w
Page 367 and 368:
for each model plant. Water purity
Page 369 and 370:
Water and steam injection controls
Page 371 and 372:
atio of the fuel. The derivation of
Page 373 and 374:
Gas turbine: Solar Centaur 'H' Powe
Page 376 and 377:
APPENDIX B. COST DATA AND METHODOLO
Page 378 and 379:
B.1.3 General Electric General Elec
Page 380 and 381:
natural gas were used for both fuel
Page 382 and 383:
Figure B-2. Annual Maintenance Cost
Page 384 and 385:
Figure B-4. Inlet Air Flow Rate for
Page 386 and 387:
B-10
Page 388 and 389:
B-12
Page 390 and 391:
TABLE B-1. COMBUSTOR REPAIR INTERVA
Page 392 and 393:
TABLE B-2. ANNUAL COST OF ADDITIONA
Page 394 and 395:
TABLE B-3. TOTAL CAPITAL INVESTMENT
Page 396 and 397:
TABLE B-4. MAINTENANCE COSTS FOR SC
Page 398 and 399:
B.3 REFERENCES FOR APPENDIX B I. Le
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