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# OAR Box 1828 Prepped by Ollie Stewart



### Document

Number: 

# 317 ) IV-B-2 1 Docket Number: 

# A-83-2 7

Printed 11/12/2008 11:12:59 AM Sheet 317 of 325P. 2 

# A v * 

# RADIA N 

# A-83-2 7

CORPORATIO N ^ ^ MEMORANDU

M
DATE : Ma y

15 , 198 7 TO : Fre dPorte r an d Wal t Stevenson , EPA/SD B FROM : JohnMartine z an d E d Aul , Radia nCorporatio n SUBJECT : Assumption s an d Procedure s Use dt o Generat e Mode l Boile r Impact s 1. 0 INTRODUCTIO N Thi s memorandu

m document s th e assumption s an d procedure s use dt o examin e th e cos t an

d emissio nimpact s associate dwit hsevera l sulfu r dioxid e (SO- ) regulator y

alternative s on variou s mode l boilers . Th e primar y purpos e o f thi s analysi s wa s t o updat e th e cos t an d cos t effectivenes s estimate s fo r SO - reduction s resultin g fro m (1 ) inclusio no f additiona l coals , (2 ) change s infue l prices , an

d (3 ) us e o f "generic " cost s fo r flu e ga s desulfurizatio n (FGD) . Excep t fo r th e change s note dabov e an d thos e i

nAppendi xF , al l othe r assumption s an d procedure s use dt o calculat e th e cost s o f th e 1 2 regulator y

alternative s ar e consisten t wit hthos e inprior analyses . ' Regulator y

alternative s i

n thi s analysi s includ e th e us e o f lo w sulfu r fuel s (i.e. , 1. 2 l bS0 2 /10 6 Bt u fo r coa l an d 0. 8 l bS0 2 /10 6 Bt u fo r oil ) an d ver y lo w sulfu r fuel s (i.e. , 0. 7 an d 0. 9 l bS0-/1 0 Bt u fo r coa l an d 0. 3 l b S0-/1 0 Bt u fo r oil ) a s wel l a s 9 0 percen t SO - reductio nbase do nFGD . Mode l boile r cost s wer e calculate di nJun e 198 5 dollar s usin g th e industria l boile r cos t program (IBCOST) . Capita l cost s wer e update dfro m Januar y 198 3 t o Jun e 198 5 dollar s usin g a n escalatio nfacto r o f 1.03 , base d o nth e Chemica l Engineerin g Plan t Cos t Index . Fo r updatin g non-fue l operatin g an

d maintenanc e (0&M ) costs , a nescalatio nfacto r o f 1.03 5 wa s used , base donBurea uo f Labo r Statistics ' Inde xo f Al l Industria l Commodities . N o escalatio nfacto r wa s use dfo r updatin g th e fue l cost s becaus e thes e cost s wer e already i n Jun e 198 5 dollars .

Progres s Center/320 0 E . Chape l Hil l Rd./Nelso n Hwy./P.O . Bo x13000/Researc h Triangl e Park . N.C . 27709/(919)541-910 0P. 3

Sectio n2. 0 present s th e assumption s use dt o generat e coal-fire dmode l boile r costs . Section s 3. 0 an d4. 0 presen t th e sam e fo r th e oil - an

d natura l gas-fire dmode l boilers , respectively . Result s o f th e analysi s fo r eac hfue l typ e ar e presente dinAppendice s A throug hC . Dat a use dfo r developin g generi c FG D cost s ar e presente di nAppendi xD . Appendi xD als o present s cost s fo r boiler s firin g th e ver y lo w sulfu r coals . Appendi xE discusse s assumption s mad e concernin g th e sulfu r variabilit y o f lo w an dvery lo w sulfu r coals . Appendi xF discusse s adjustment s mad e t o IBCOS T input s t o assur e consistenc y

wit hboile r cos t analyse s conducte dsinc e publicatio no f Referenc e 2 . 2. 0 COAL-FIRE D MODE L BOILE RCOST S Cost s wer e estimate dfo r mode l coal-fire dboiler s o f 15 0 an d40 0 millio nBtu/hou r hea t input s locate dinEPA Region s III , IV , V

an dVIII . Th e 15 0 millio nBtu/hou r mode l boile r wa s represente db y a coal-fire d spreade r stoker , an

dth e 40 0 millio nBtu/hou r mode l boile r wa s represente d b y a pulverize dcoal-fire dboiler . Th e boiler s operate da t a 0. 6 capacit y factor . Coa l type s an dprice s use dinthi s analysi s ar e presente din Tabl e 2- 1 fo r eac hregion . Fo r estimating capita l an dannualize dcost s o f mode l boiler s firin g very lo w sulfu r bituminou s coal s (A-Bi t an dAA-Bit) , th e heatin g value s an d as hcontent s o f B-Bi t coa l wer e assumed . Similarly , th e heatin g value s an d as hcontent s o f th e A-Su ban dAA-Su bcoal s wer e assume dequa l t o thos e o f B-Su bcoal . Fo r mode l boiler s firin g ver y highsulfu r bituminou s coa l (J-Bit) , th e heatin g value s an das hcontent s o f H-Bi t coa l wer e used . Fue l price s fo r J-Bi t coa l wer e estimate db y linearl y

extrapolatin g th e pric e versu s sulfu r conten t relationshi pfo r th e othe r coa l type s t o th e sulfu r conten t o f J-Bi t coa l (i.e. , 8. 0 l bS0-/1 0 Btu) . 6 FG D contro l cost s wer e base do na "generic " FG D system cost . T o estimat e th e generi c cost s o f FGD system , th e existin g algorithm s inIBCOS T fo r sodiu

m scrubbing , dua l alkali , an dlime spray

dryin g wer e execute dfo r eac hboile r size , fue l type , an dregion . Th e lowes t an dhighes t cost s amon g thes e thre e type s o f FG D system s wer e the naverage dt o obtai nth e generi c cost s fo r a FG D system .CJ J

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Cost s fo r FG D malfunctio nwer e als o include di nth e generi c cost s o f a n FGD system

an dwer e base donth e boile r firin g natura l ga s durin g FG D malfunction . Include di nth e cost s wer e th e capita l cost s o f natura l ga s burnin g equipmen t designe dt o fir e a t 10 0 percen t loa dan dth e fue l cos t o f burnin g natura l ga s (base do nth e ga s price s correspondin g t o th e lo w oi l scenari o an

dnon-carriage/rigi dmarket ) durin g perio do f FG D malfunction . Appendi xF discusse s th e procedure s an dassumption s use dt o calculat e boile r an dFG D system

costs . 3. 0 OIL-FIRE D MODE L BOILE RCOST S Cost s wer e estimate dfo r anoiT-fire dmode l boile r rate da t 15 0 millio n Btu/hou r hea t inpu t locate dinEPA Regio nV . Th e boile r operate da t a 0.5 5 capacit y factor . Oi l price s use dinthi s analysi s ar e presente di n Tabl e 3- 1 fo r Regio nV . Th e 15 0 millio nBtu/hou r mode l boile r wa s represente db y a packag e boiler . Generi c FG D cost s ar e base donth e averag e cost s o f dua l alkal i an d sodiu m scrubbing . Spra y

dryin g FG D wa s no t evaluate ddu e t o it s limite d application s onoil-fire dboilers . Appendi xF discusse s th e assumption s an d methodolog y

change s fo r FG D control s onoil-fire dboilers . 4. 0 NATURA L GAS-FIRE D MODE L BOILE RCOST S Cost s wer e estimate dfo r natura l gas-fire dmode l boiler s rate da t 15 0 an d40 0 millio nBtu/hou r hea t input s an dlocate dinEPA

Region s III , IV , V an dVIII . Th e natura l gas-fire dboiler s operate da t th e sam e capacit y facto r a s th e oil-fire dmode l boile r (0.55) . Tabl e 4- 1 present s th e natura l ga s price s fo r th e flexibl e carriag e marke t unde r th e lo w oi l pric e scenario . Th e 15 0 millio nBtu/hou r natura l gas-fire dmode l boile r wa s represente d b y a packag e boiler . Th e 40 0 millio nBtu/hou r natura l gas-fire dmode l boile r wa s represente db y two packag e boiler s eac hrate da t 20 0 millio n 2 Btu/hou r hea t input , a s wa s don e i nth e previou s boile r cos t analysis .P. 6

TABL E 3-1 . OI L PRICE S USE D I N ESTIMATINGTH E OIL-FIRE D MODE L BOILE RCOST S I N EP A REGION V a

Percen t Sulfu r Oi l Prices , g Fue l Typ e b y Weigh t Jun e 198 5 Dollars/1 0 Bt u Residua l Oi l 3. 0 2.9 0 1. 6 3.0 9 0. 8 3.3 5 0. 3 3.4 9 Distillat e Oi l 0. 3 3.8 6

a 0i l price s wer e base donth e lo w oi l pric e scenari o a s cite din Referenc e 9 .P. 7

TABL E 4-1 . NATURAL GA S PRICE S USE D I N ESTIMATINGTH E NATURAL GAS-FIRE D MODE L BOILE RCOSTS 3

Carriage , Flexibl e Marke t Prices , EPA Regio nJune 198 5 Dollars/1 0 Bt u II I 3.0 6
I V 3.0 1 3.1 7
VII I 3.0 6 

### a Referenc e 5 .P. 8

5. 0 REFERENCE S 1 . Radia nCorporation . Cost s o f Sulfu r Dioxide , Particulat e Matter , an d Nitroge nOxid e Control s o nFossi l Fuel-Fire dIndustria l Boilers . Prepare dfo r th e U.S . Environmenta l Protectio nAgency . Researc h Triangl e Park , NC . Publicatio nNo . EPA-450/3-82-021 . Augus t 1982 . p . A- l t o A-34 . 2 . Radia nCorporation . Industria l Boile r SO - Cos t Report . Prepare dfo r th e U.S . Environmenta l Protectio nAgency . Researc hTriangl e Park , NC . Publicatio nNo . EPA-450/3-85-011 . Novembe r 1984 . p . 2- 1 t o 2-27 . 3 . ICF , Incorporated . Availabilit y an dCos t o f Ver y

Lo w Sulfu r Coal s fo r th e Industria l Market . Prepare dfo r th e U.S . Environmenta l Protectio n Agency . Researc hTriangl e Park , NC . Marc h6 , 1987 . p . 4-33 . 4 . Lette r fro

m Hogan , T. , Energy

an dEnvironmenta l Analysis , Inc. , t o Pahel-Short , R. , EPA/EAB . Annualize dIndustria l Coa l Prices . Augus t 29 , 1986 . 5 . Lette r fro

m Hogan , T. , Energy

an dEnvironmenta l Analysis , Inc. , t o Pahel-Short , R. , EPA/EAB . Annualize dIndustria l Natura l Ga s Prices . Augus t 27 , 1986 . 6 . Memorandu

m fro m Shumaker , J . L . an

dJ . T . Waddell , Radia nCorporation , t o Porter , F . L. , EPA/SDB . Apri l 29 , 1987 . 1 0 p . Us e o f a Generi c Cos t Algorith

m t o Represen t th e Cost s o f Industria l Flu e Ga s Desulfurizatio n(FGD ) Systems . 7 . Memorandu

m fro m Martinez , J. , Radia nCorporation , t o SO - Docke t Files . Januar y 8 , 1986 . 1 1 p . Updat e o nFlu e Ga s Desulfurizatio nSystem Malfunctio nCosts . 8 . U.S . Environmenta l Protectio nAgency . Summar y o f Regulator y

Analysi s New Sourc e Performanc e Standards : Industrial-Commercial-Institutiona l Steam Generatin g Unit s o f Greate r Tha n10 0 MillionBtu/h r Hea t Input . Researc hTriangl e Park , NC . Publicatio nNo . EPA-450/3-86-005 . Jun e 1986 . p . 6-1 . 9 . Lette r fro

m Hogan , T. , Energy

an dEnvironmenta l Analysis , Inc. , t o Pahel-Short , R. , EPA/EAB . Annualize dIndustria l Oi l Prices . Augus t 26 , 1986 . 10 . Margerum , S. , an dG . Giguer e (Radia nCorporation) . Variabilit y o f S0 - Emission s fro

m Lo w Sulfu r Coal-Fire dIndustria l Boilers . Prepare dfo r th e U.S . Environmenta l Protectio nAgency . Researc hTriangl e Park , NC . Jul y 1985 . 11 . Referenc e 8 . p . 5-5 5 t o 5-56 .P. 9



### 12 . Giguere , G. , an

dS . Margeru

m (Radia nCorporation) . Determinatio no f Mea nSO - Emissio nLevel s Require dt o Mee t a 1. 2 l bS0-/Milli'o nBt u Emissio nStandar dfo r Variou s Averagin g Time s an dComplianc e Policies . Prepare dfo r th e U.S . Environmenta l Protectio nAgency . Researc h Triangl e Park , N . C . Marc h1985 . pp . A- 8 t o B-4 .



# JP.1 0



### APPENDI XA COS T AN D COS T EFFECTIVENES S RESULT S FOR COAL-FIRE D MODE L BOILER S I N REGION S 3 , 4 , 5 AN D 8TABL E A-l . COS T RESULT S FO R

STANDAR D ANALYZE D Millio n BTU/H R Percen t

1 NOMINA L S O 2 \ NOMINA L EMISSIO N | PERCEN T | REDUCTIO N | COMMEN T REQUIRE D 3 > i Tt ' ' b | BASELIN E - leas t cos t optio nN A | COMPLIANC E COA L - leas t cos t optio nN A | VER YLO USULFU RCOA L | *0. 9 St d - leas t cos t optio nN A | *0. 7 St d - leas t cos t optio nN A | PERCEN T REDUCTIO N | *90 Xo n leas t cos t optio n9 0 | *90 I o nhig hsulfu r coa l 9 0 | *90 Xo nmediu m sulfu r coa l 9 0 LIMI T (LB S PE R 1 0 BTU ) 2. 5 1. 2

0. 9 0. 7

N A N A N A a Tota l annualize d cost s fo r boile r and al l applicabl e emis s l c N A = no t applicabl e Les s expensiv e tha nth e 0. 7 standar d optio n COA L TYP E E-Bl t B-Bi t

A-Bi t AA-Bi t

F-Bi t J-Bi t G-Bi t A

15 0 MILLIO N

BTU/HOU RCOAL-FIRE D BOILE RI N REGIO N

II I

COA L SELE C AVERAG E S O 2 EMISSION S (LB S PE R 6 1 0 BTU ) 2. 1 1.0 8

0.8 2 0.6 2

0.21 7 0.60 8 0.31 6
ncontro l system s rE D ANNUA L EMISSION S (TON S PE R YEAR ) 82 8 42 6

32 3 24 4

8 6 24 0 12 5 ANNUALIZE D

COST S ($100 0 PE RYEAR ) 5,73 1 5,92 6

6,06 8 6,71 4

6,47 3 6,63 4 6,53 0 INCREMENTA L COS T EFFECTIVENES S ( $ PE RTO N

O F S O REMOVED ) 2 BASELIN E

—

1. 2 COAL — 0. 9 COA L
N A 48 5

1,38 5

4,34 6

1,60 8 1,70 4 3,80 5 6,77 3 2,00 6 2,32 5 -

0. 7 COA L

-1,51 7 -16,91 2 c -1,53 5 04/15/8 7 # 

## 1TABL E A-2 . COS T RESULT S FO RA 40 0 MILLIO N

BTU/HOU R COAL-FIRE D BOILE R I N REGIO N

II I

FUE L TYPE 3 > r o FO R REGION BOILE RSIZE COA L

40 0 Millio n BTU/H R CAPACIT YFACTOR - 6 0 Percen t

STANDARD ANALYZE D

COMMEN T NOMINA L S O 2 NOMINA L EMISSIO N PERCEN T LIMI T REDUCTIO N

(LB S PE R REQUIRE D 1 0 BTU ) BASELIN E - leas t cos t optio n COMPLIANC E COA L - leas t cos t optio n VER YLO USULFU RCOA L *0. 9 St d - leas t cos t optio n *0. 7 St d - leas t cos t optio n PERCEN T REDUCTIO N *90 Z o n leas t cos t optio n *90 Z o n hig hsulfu r coa l *90 Xo nmediu m

sulfu r coa l N A N A

NA NA

9 0 9 0 9 0 2. 5

1. 2

0. 9 0. 7

N A H A N A COA L SELECTE D

| COA L | TYP E AVERAG E S O 2

EMISSION S (LB S PE R 6 1 0 BTU ) ANNUA L

EMISSION S (TON S PE R YEAR ) ANNUALIZE D

COST S ($100 0 PE RYEAR ) E-Bl t B-Bi t

A-Bl t AA-Bl t

F-Bl t J-Bl t G-Bi t 2. 1 2,20 8

1.0 8 1,13 5

0.8 2 0.6 2 86 2

65 2 14,02 7

14,55 0

14,93 2 16,67 5

0.21 7 0.60 8 0.31 6 22 8

63 9 33 2 15,31 8

15,70 4 15,47 7 INCREMENTA L COS T EFFECTIVENES S

| BASELIN E

N A 48 8 ( $ PE RTO N O F S O REMOVED ) 2

— 1. 2 COAL — 0. 9 COA L

1,39 8 4,39 5

84 7 60 9 2,32 6 3,46 4 1,15 4 1,02 9 0. 7 COA L |

-3,20 3 | -.76,97 6 | -3,74 9 |
Tota l annualize d cost s fo r boile r an d al l applicabl e emissio ncontrol-system s b N A = no t applicabl e c Les s expensiv e tha n th e 0. 7 standar d optio n 04/15/8 7TABL E A-3 . COS T RESULT S FO RA 15 0 MILLIO N

BTU/HOU RCOAL-FIRE D BOILE RI N REGIO N

I V

FUE L TYPE - COA L FO R REGION BOILE RSIZE - 15 0 Millio nBTU/H R CAPACIT YFACTOR - 6 0 Percen t

STANDAR D ANALYZE D COA L SELECTE D INCREMENTA L COS T EFFECTIVENES S

I c o | COMMEN T | BASELIN E - leas t cos t optio n | COMPLIANC E COA L - leas t cos t optio n | VER YLO USULFU R COA L | *0. 9 St d - leas t cos t optio n | "0. 7 St d - leas t cos t optio n | PERCEN T REDUCTIO N | *90 Xo n leas t cos t optio n | *90 Xo n hig hsulfu r coa l | *90 Xo n medium sulfu r coa l NOMINA L PERCEN T REDUCTIO N REQUIRE D
b N A N A

N A N A

9 0 9 0 9 0 ROMINAL S O 2

EMISSIO N LIMI T (LB S PE R 6 1 0 BTU )
2. 5 1. 2

0. 9 0. 7

N A N A N A COA L

TYP E
E-Bl t B-Bi t

A-Bl t AA-Bit

D-Bi t J-Bl t G-Bi t AVERAG E S O 2

EMISSION S (LB S PE R 6 1 0 BTU )
2. 1 1.0 8

0.8 2 0.6 2

0.1 1 0.60 8 0.31 6 ANNUA L

EMISSION S (TON S PE R YEAR )
82 8 42 6

32 3 24 4

4 3 24 0 12 5 ANNUALIZE D

COST S ($100 0 PE RYEAR )
5,87 3 5,93 4

6,14 7 6,69 8

6,62 0 6,85 8 6,71 3 ( $ PE RTO N O F S O REMOVED ) 2 BASELIN E 1. 2 COAL — 0. 9 COA L

H A 15 2

2,07 8

4,21 3

1,79 4 1,69 0 4,96 6 8,50 8 2,58 7 2,84 9 0. 7 COA L |

-38 8 | 33,82 4 | 12 5 |
Tota l annualize d cost s fo r boile r an d al l applicabl e emissio ncontro l system s b N A = No t applicabl e c Les s expensiv e tha nth e 0. 7 standar d optio n 04/15/8 7TABLE A-4 . COS T RESULT S FO R A 40 0 MILLIO

N BTU/HOU

R COAL-FIRE

D BOILE R IN REGIO N I V

3 > I FUE L TYPE FO R REGION BOILE R SIZE CAPACIT YFACTOR COA L

40 0 Millio

n BTU/H R 6 0 Percent STANDAR D ANALYZE

D

COMMEN T NOMINA L S O 2 NOMINA L EMISSIO

N PERCEN T LIMI T REDUCTIO

N (LB S PE

R 6 REQUIRE D 1 0 BTU ) BASELIN E - leas t cos t optio nN

A COMPLIANCE COA

L - leas t cos t optio nN A VER YLO USULFU R COA L *0. 9 St d - leas t cos t optio n *0. 7 St d - leas t cos t optio n PERCEN T REDUCTIO

N *90 Xo n leas t cos t optio

n *90 Xo n hig hsulfu r coa l *90 Xo n mediu m sulfu r coa l N

A N A

9 0 9 0 9 0 2. 5

1. 2

0. 9 0. 7

H A H A H A COA

L SELECTE

D
| COA L | TYP E AVERAG

E S O 2 EMISSIONS (LBS PE R 6 1 0 BTU ) ANNUA

L EMISSIONS (TON S PE R YEAR ) ANNUALIZE D COST S ($100 0 PE R YEAR ) E-Bl t 2. 1 2,20 8 14,40 7 B-Bl t 1.0 8 1,13 5 14,56 9

A-Bi t 0.8 2 AA-Bl t 0.6 2

D-Bl t0.1 1 J-Bi t0.60 8 G-Bi t0.31 6 86 2 15,14 3 65 2 16,63 0

11 6 15,71 7 63 9 16,27 6 33 2 15,95 7 .INCREMENTA L COS T EFFECTIVENESS_ ( $ PE R TO N OF S O REMOVED ) 2 BASELIN E

— 1. 2 COAL N A 15 1

2,10 0

4,26 2

1,12 6 3,44 0 1,72 8 0. 9 COA L 0. 7 COA

L

76 9 -1,70 3 5,08 4 r28,06 3 1,53 6 -2,10 6 Tota l annualize

d cost s fo

r boiler an

d al l applicabl e emissio n contro l system

s b N A = not applicabl e c Les s expensiv

e tha n th e 0. 7 standar

d optio n 04/15/8 7TABL E A-5 . COS T RESULT S FO RA 15 0 MILLIO N

BTU/HOU R COAL-FIRE D BOILE R IN REGIO N

V

I c n FUE L TYPE FO RREGION BOILE R SIZE CAPACIT YFACTOR COA L

15 0 Millio n BTU/H R 6 0 Percen t STANDARD ANALYZE D

COMMEN T NOMINA L S O 2 NOMINA L EMISSIO N PERCEN T LIMI T REDUCTIO N

(LB S PE R REQUIRE D 1 0 BTU ) BASELIN E - leas t cos t optio nN A COMPLIANC E COA L - leas t cos t optio nN A VER YLO USULFU RCOA L *0. 9 St d - leas t cos t optio n *0. 7 St d - leas t cos t optio n PERCEN T REDUCTIO N *90 Xo n leas t cos t optio n *90 Xo n hig hsulfu r coa l *90 Xo nmediu m

sulfu r coa l N A N A

9 0 9 0 9 0 2. 5

1. 2

0. 9 0. 7 COA L SELECTE D

| COA L | TYP E AVERAG E S O 2

EMISSION S (LB S PE R 6 1 0 BTU ) ANNUA L

EMISSION S (TON S PE R YEAR ) ANNUALIZE D

COST S ($100 0 PE RYEAR ) E-Bi t 2. 1 B-Bi t 1.0 8 82 8 42 6

A-Su b0.6 5 25 6 AA-Su b0.4 5 17 7

N A H A N A F-Bl t

J-Bl t G-Bl t 0.21 7

0.60 8 0.31 6 8 6

24 0 12 5 5,88 5

6,01 4
6,15 7 6,26 7
6,62 2 6,65 6 6,63 6 INCREMENTA L COS T EFFECTIVENES S

1 ( $ PE RTO N O F S O REMOVED ) 2 | BASELIN E | —1. 2 COAL — | 0. 9 COA L

N A 32 1

84 4

1,01 9

1,78 7 2,72 4 3,45 0 30,13 9 2,06 5 3,63 8 0. 7 COA L |

3,86 5 | r6,246 C | 6,98 6 | Tota l annualize d cost s fo r boile r an d al l applicabl e emissio ncontro l system s b N A = no t applicabl e c Inferio r optio n 04/15/8 7TABL E A-6 . COS T RESULT S FO R A 40 0 MILLIO N

BTU/HOURCOAL-FIRE D BOILE RI N REGIO N

V

FUE L TYPE I c n FO RREGION BOILE RSIZE CAPACIT YFACTOR COA L 5 40 0 Millio nBTU/H R 6 0 Percen t STANDAR D ANALYZE D COA L SELECTE D

COMMEN T NOMINA L PERCEN T REDUCTIO N REQUIRE D b NOMINA L S O 2 EMISSIO N LIMI T (LB S PE R 6 1 0 BTU ) COA L

TYP E AVERAG E S O 2

EMISSION S (LB S PE R 6 1 0 BTU ) ANNUA L

EMISSION S (TON S PE R YEAR ) ANNUALIZE D

COST S ($100 0 PE RYEAR ) BASELIN E - leas t cos t coa l optio nN A COMPLIANC E COA L - leas t cos t coa l N A optio n VER YLO USULFU RCOA L *0. 9 St d - leas t cos t coa l optio nN A *0. 7 St d - leas t cos t coa l optio nN A PERCEN T REDUCTIO N . 5

. 2 E-Bl t

B-Su b 2. 1

0.9 6 2,20 8

1,00 9 14,39 5

14,75 7

*90 Xo n leas t cos t optio n *90 Xo nhig hsulfu r coa l *90 Xo n medium

sulfu r coa l 9 0 9 0 9 0 0. 9 A-Su b0.6 5

0. 7 AA-Su b0.4 5

N A F-Bl t 0.21 7 N A J-Bi t 0.60 8 N A G-Bl t 0.31 6 68 3 14,75 7 47 3 15,05 4

22 8 15,67 0 63 9 15,75 1 33 2 15,75 4 INCREMENTA L COS T EFFECTIVENES S 1 ( $ PE RTO N O F S O REMOVED ) 2 | BASELIN E | —1. 2 COAL — | 0. 9 COA L

N A 30 2

0

55 4

1,16 9 2,00 6 2,68 6 22,51 4 1,47 3 2,84 0 0. 7 COA L |

2,51 5 | -4,19 7 | 4,96 9 |
Tota l annualize d cost s fo r boile r an d al l applicabl e emissio ncontro l system s b N A = no t applicabl e c Inferio r optio n 04/15/8 7TABL E A-7 . COS T RESULT S FO RA 15 0 MILLION

BTU/HOURCOAL-FIRE D BOILE RI N REGION VII I
FUE L TYPE I FO RREGION BOILE RSIZE CAPACIT YFACTOR COA L

15 0 Millio nBTU/H R 6 0 Percen t STANDAR D ANALYZE D

COMMEN T NOMINA L S O 2 NOMINA L EMISSIO N PERCEN T LIMI T REDUCTIO N

(LB S PE R 6 REQUIRE D 1 0 BTU ) BASELIN E - leas t cos t optio nN A 2. 5 COMPLIANC E COA L - leas t cos t optio n N A 1. 2 VER YLO USULFU RCOA L *0. 9 St d - leas t cos t optio nN A 0. 9 *0. 7 St d - leas t cos t optio nN A 0. 7 PERCEN T REDUCTIO N *90 Xo nleas t cos t optio n9 0 NA *90 Xo nhig hsulfu r coa l 9 0 H A *90 Xo n medium

sulfu r coa l 9 0 NA COA L SELECTE D

| COA L | TYP E D-Su b B-Su b AVERAG E S O 2

EMISSION S (LB S PE R 6 1 0 BTU ) 1.4 4 0.9 6 ANNUA L

EMISSION S (TON S PE R YEAR ) 56 8 37 8 ANNUALIZE D

COST S ($100 0 PE RYEAR ) 5,11 8 5,15 3

A-Su b0.6 5 25 6 AA-Su b0.4 5 17 7

B-Su b0.07 3 2 9 E-Su b0.16 1 6 3 B-Su b0.07 3 2 9 5,15 3 5,26 3

5,82 4 5,88 9 5,82 4 INCREMENTA L COS T EFFECTIVENES S

BASELIN E

N A 18 5 ( $ PE RTO N O F S O REMOVED ) 2

— 1. 2 COAL — 0. 9 COA L

0 54 7

1,91 9 2,95 0 2,33 7 3,81 8 1,91 9 2,95 0 0. 7 COA L |

3,77 5 |

• 5,49 5 | 3,77 5 |
Tota l annualize d cost s fo r boile r an d al l applicabl e emissio ncontro l system s b N A = no t applicabl e 04/15/8 7TABL E A-8 . COS T RESULT S FO R A 40 0 MILLION

BTU/HOU RCOAL-FIRE D BOILE RI N REGIO N VII I
FUE L TYPE - COA L FO RREGION BOILE R SIZ E 40 0

STANDARD ANALYZE D Millio nBT U Percen t

1 NOMINA L S O 2 | NOMINA L EMISSIO N | PERCEN T | REDUCTIO N 1 COMMEN T REQUIRE D ** • 1 1 1 C O t > | BASELIN E - leas t cos t optio nN A | COMPLIANC E COA L - leas t cos t optio nN A | VER YLO USULFU R COA L | *0. 9 St d - leas t cos t optio nNA | *0. 7 St d - leas t cos t optio nN A | PERCEN T REDUCTIO H | *90 Z o nleas t cos t optio n9 0 | *90 Xo n hig hsulfu r coa l 9 0 1 *90 Z o nmedium sulfu r coa l 9 0 LIMI T (LB S PE R 1 0 BTU ) 2. 5 1. 2

0. 9 0. 7

N A H A H A a Tota l annualize d cost s fo r boile r and al l applicabl e emissl o N A = no t applicabl e ra n

COA L TYP E D-Su b B-Su b

A-Su b AA-Su b

D-Su b E-Su b B-Su b COA L SELEC 1 AVERAG E S O 2 EMISSION S (LB S PE R 6 1 0 BTU ) 1.4 4 0.9 6

0.6 5 0.4 5

0.10 9 0.16 1 0.07 3
ncontro l system s "E D ANNUA L EMISSION S (TON S PE R YEAR ) 1,51 4 1,00 9

68 3 47 3

11 5 16 9 7 7 ANNUALIZE D

COST S ($100 0 PE RYEAR ) 11,95 6 12,06 4

12,06 4 12,36 1

13,24 2 13,41 0 13,25 4 INCREMENTA L COS T EFFECTIVENES S ( $ PE RTO N

O F S O REMOVED ) 1 2 - . BASELIN E |

—-1. 2 COAL —

| 0. 9 COA L |

0. 7 COA L |
H A | 21 4 |

0 1 55 4 |

1,31 7 2,07 1 2,45 8 | 1,60 3 2,61 8 . 3,45 3 | 1,27 6 1,96 2 2,25 3 | 04/15/8 7P.1 9



### APPENDI XB COS T AN D COS T EFFECTIVENES S RESULT S FOR OIL-FIRE D MODE L BOILER S I N REGION 5TABL E B-l . COS T RESULT S FO R A15 0 MILLIO NBTU/HOU

R RESIDUA

L OIL-FIRE D BOILE R INREGIONV

C O I FUE L TYPE FOR REGION BOILE R SIZE CAPACITY FACTOR OI L

15 0 Milio n BTU/H

R 5 5 Percen t STANDAR D ANALYZE

D OI L SELECTE D

COMMEN T NOMINA L S O 2 NOMINA L EMISSIO

N PERCEN T LIMI T REDUCTIO

N(LB S PE R 6 REQUIRE D 1 0 BTU ) | OI L | TYP E AVERAG E S O 2

EMISSIONS (LB S PE R 6 1 0 BTU ) ANNUA

L EMISSION S (TOH S PE R YEAR ) ANNUALIZE D

b COST S | ($100 0 | PE R YEAR ) | BASELINE - leas t cos t optio n N A COMPLIANC E OI L - leas t cos t optio n N A VERY LO H SULFU

R OI L *0. 3 St d - leas t cos t optio n N A PERCEN T REDUCTIO

N *90 X o n leas t cos t optio n 9 0 *90 X o n hig h sulfur optio n 9 0 *90 X o n mediu

msulfur oi l 9 0 3. 0 0. 8

0. 3

N A H A H A 3.0XS

0.8X S 3.24 3 1,17 2 0.86 5 31 3 3,23 6 3,55 9

0.3XS 0.32 4 11 7 3,65 9

0.8XS 3.0XS 1.6X S 0.06 6 0.24 6 0.13 1 2 4

8 9 4 7 4,09 4

4,10 3 4,13 2 INCREMENTA L COS T EFFECTIVENES S ( $ PE R BASELINE

N A 37 6 TO

NO F S O 2

- —0. 8 OIL 51 2

1,85 3 2,43 2 2,16 0 REMOVED ) |

0. 3 OI L |

4,66 6 | 15,75 3 | 6,78 2 | XS • * percen t sulfu r b Tota i annualize d cost s fo r boile r an d al l applicabl e contro l systems c N A= no t applicabl e 04/15/8 7TABL E B-2 . COS T RESULT S FO RA 15 0 MILLIO N

BTU/HOU R RESIDUA L AN D DISTILLAT E OIL-FIRE D BOILE RI N REGIO N

V

FUE L TYP E FO RREGIO N BOILE RSIZ E CAPACIT YFACTO R

STANDAR D ANALYZE D OI L (Residual/Distillate )

15 0 Millio n BTU/H R 5 5 Percen t OI L SELECTE D

NOMINA L PERCEN T NOMINA L S O 2

EMISSIO N LIMI T COMMEN T REDUCTIO N (LB S PE R REQUIRE D 1 0 BTU ) AVERAG E S O ANNUA L 2 EMISSION S EMISSION S ANNUALIZE D b (LB S (TON S COST S OI L PE

R TYP E 1 0 BTU ) PE R YEAR ) ($100 0

PE RYEAR )

BASELIN E - leas t cos t optio nNA COMPLIANC E OI L - leas t cos t optio nN A VER YLO USULFU ROI L c *0. 3 St d - leas t cos t optio nH A PERCEN T REDUCTIO N *90 Xo nleas t cos t optio n9 0 *90 Xo nhig hsulfu r oi l 9 0 *90 Xo nmedium

sulfu r oi l 9 0 3. 0 0. 8

0. 3

N A H A H A 3.0X S R O 3.24 3

0.8X S R O 0.86 5

0.3X S D O 0.32 4

0.8X S R O 0.06 6 3.0X S R O 0.24 6 1.6X S R O 0.13 1 1,17 2 31 3

11 7

2 4 8 9 4 7 3,23 6

3,55 9

3,91 7
4,09 4 4,10 3 4,13 2 INCREMENTA L COS T EFFECTIVENES S

( $ PE R BASELIN E

N A 37 6 TO N

O F S O 2
—0. 8 OIL 1,83 1

1,85 3 2,43 2 2,16 0 REMOVED ) |

— 0. 3

1 6 3 OI L |

89 9 | 59 9 | 08 3 | Z S - percen t sulfur ; R O = residua l oil ; an d D O - distillat e oi l b Tota l annualize d cost s fo r boile r an d al l applicabl e contro l system s c Leas t cos t optio nusin g distillat e oi l d N A = no t applicabl e 04/15/8 7P.2 2



### APPENDI XC COST S FO RTH E NATURAL GAS-FIRE D MODE L BOILER S IN REGION S 3 , 4 , 5 , AN D 8P.2 3

TABL E C-1 . ANNUALIZE D COST S (I N JUN E 198 5 DOLLARS ) FORNATURAL GAS-FIRE D MODE L BOILER S IN REGION S III , IV , V , AN D VII I

Model K Boile r Size , Annualize dCos t 10 ° Btu/h r EPA Regio n($l,000) a 

### 15 0
400 II I I V V VII I 

### II I I V V VII I 3,29 3 3,25 0 3,37 2 3,29 3 8,39 4 8,28 4 8,60 4 8,39 4

a Natura l ga s fue l price s ar e base donth e lo w oi l pric e scenari o an d carriage/flexibl e marke t a s cite di nReferenc e 5 .



### C- 1P.2 4



### APPENDI XD ANNUALIZE D COST S FORBOILER S USINGFG D SYSTEM S (GENERI C COSTS ) AND VERYLO W SULFURCOAL

### TABL E D-1 . ANNUALIZE D COST S FO RCOAL-FIRE D MODE L BOILER S I N REGION II I UNDE RTH E PERCEN T S0 2 

### REDUCTIO N ALTERNATIVE 3

Mode l Boile r Size , 10 ° Btu/h r 

### 150

40 0 Coa l

Typ e J-Bi t H-Bi t G-Bi t F-Bi t E-Bi t D-Bi t B-Bi t J-Bi t H-Bi t G-Bi t F-Bi t E-Bi t D-Bi t B-Bi t Uncontrolle d

SO , Emissions , fb/10 e Bt u 8.0 0 5.5 4 4.1 5 2.8 5 2.1 0 1.4 5 1.0 8 8.0 0 5.5 4 4.1 5 2.8 5 2.1 0 1.4 5 1.0 8 Annual i



### DA b 6,73 8 6,77 7 6,68 4 6,65 0 6,73 0 6,74 1 6,86 3 15,63 6 15,81 1 15,56 4 15,46 8 15,68 8 15,71 7 16,04 3 ze

d Costs , 

### DS C 6,64 1 6,63 9 6,52 9 6,47 4 6,53 4 6,53 1 6,63 8 15,64 5 15,69 8 15,40 8 15,25 7 15,43 0 15,42 4 15,71 1 ($1,000 )

NATH d 6,53 0 6,51 7 6,37 6 6,29 5 6,34 5 6,33 2 6,43 9 15,77 2 15,76 8 15,39 0 15,16 7 15,31 0 15,27 3 15,55 9 Jun e 198 5

Generi c 6,634 f 6,647 n 6,530 ? 6,473 n 6,53 8 6,53 7 6,65 1 15,704 f 15,755 f l 15,477 g 15,318 n 15,49 9 15,49 5 15,80 1 

### Boile r an

d continuou s emissio nmonitorin g system cost s ar e included . D A = Dua l Alkali ; cost s includ e a fabri c filte r fo r PM control . C 

### D S = Spra y

Drying ; cost s includ e a fabri c filte r fo r PM contro l (integra l t o th e FG D system) . NAT H = Sodiu

m Scrubbing ; cost s includ e a fabri c filte r fo r P M control . e 

### Generi c = Averag e cost s o f th e lowes t an d highes t o f th e thre e FGD/P M systems . f Tota l system

annualize dcost s fo r a boile r firin g highsulfu r coal . ^Tota l system

annualize dcost s fo r a boile r firin g mediu m sulfu r coal . Tota l system

annualize dcost s fo r th e lowes t cos t option .

D- 1P.2 6

TABL E D-2 . ANNUALIZE D COST S FO R COAL-FIRE D BOILER S I N REGION I V UNDE RTH E PERCEN T S0 2 REDUCTIO N ALTERNATIVE 3

Mode l Boiler Size , 10 ° Btu/h

r 

### 150

40 0 Coal

Typ e J-Bi t H-Bi t G-Bi t F-Bi t E-Bi t D-Bi t B-Bi t J-Bi t H-Bi t G-Bi t F-Bi t E-Bi t D-Bi t B-Bi t Uncontrolle d SO , Emissions , 

### fb/10 ° Bt u 8.0 0 5.5 4 4.1 5 2.8 5 2.1 0 1.4 5 1.0 8 8.0 0 5.5 4 4.1 5 2.8 5 2.1 0 1.4 5 1.0 8 Annual i



### DA b 6,96 2 6,87 8 6,86 7 6,89 1 6,86 7 6,82 5 6,87 3 16,21 8 16,07 6 16,04 7 16,11 4 16,05 2 15,93 9 16,06 5 ze

d Costs , 

### DS C 6,85 6 6,73 7 6,70 3 6,70 3 6,66 5 6,61 1 6,60 0 16,19 8 15,95 0 15,86 6 15,87 1 15,77 7 15,63 7 15,60 5 ($1,000 )

NATH d 6,75 4 6,61 9 6,55 8 6,53 5 6,48 3 6,41 5 6,44 9 16,35 4 16,03 2 15,87 2 15,81 3 15,67 5 15,49 4 15,58 2 Jun

e 198 5 Generi c 6,858 f 6,74 9 6,713 g 6,71 3 6,738 . 6,620 " 6,66 1 16,276 f 16,013 o 15,957 g 15,96 4 15,864 . 15,717 " 15,82 4 Boile r an

d continuou s emissio nmonitorin g system cost s ar e included . D A = Dua l Alkali ; cost s includ e a fabri c filte r fo r P M control . C D S = Spra y

Drying ; cost s includ e a fabri c filte r fo r P M contro l (integra l t o th e FG D system) . NAT H = Sodiu

m Scrubbing ; cost s includ e a fabri c filte r fo r P M control . e Generi c = Averag e cost s o f th e lowes t an d highes t o f th e thre e FGD/P M systems . fTota l system

annualize dcost s fo r a boile r firin g highsulfu r coal . 9 Tota l system

annualize dcost s fo r a boile r firin g mediu m sulfu r coal . Tota l system

annualize dcost s fo r th e lowes t cos t option .



### D- 2P.2 7

. * 

### TABL E D-3 . ANNUALIZE D COST S FORCOAL-FIRE D BOILER S I N REGION V UNDE RTH E PERCEN T S0 2 

### REDUCTION ALTERNATIVE 3

Mode l Boiler Size , 10 ° Btu/h

r 

### 150

40 0 Coa l

Typ e J-Bi t H-Bi t G-Bi t F-Bi t E-Bi t D-Bi t B-Bi t E-Su b D-Su b B-Su b J-Bi t H-Bi t G-Bi t F-Bi t E-Bi t D-Bi t B-Bi t E-Su b D-Su b B-Su b Uncontrolle

d SO , Emissions , Tb/10 5 Bt

u 8.0 0 5.5 4 4.1 5 2.8 5 2.1 0 1.4 5 1.0 8 2.1 0 1.4 5 0.9 6 8.0 0 5.5 4 4.1 5 2.8 5 2.1 0 1.4 5 1.0 8 2.1 0 1.4 5 0.9 6 Annual i



### DA b 6,76 0 6,80 6 6,79 0 6,80 0 6,86 2 6,87 9 6,94 2 6,99 2 6,92 8 6,98 5 15,68 5 15,88 1 15,84 3 15,86 1 16,02 8 16,07 6 16,24 9 16,10 1 15,92 8 16,08 2 ze

d Costs , 

### DS C 6,58 6 6,66 4 6,62 7 6,61 3 6,65 7 6,65 8 6,71 0 6,80 4 6,72 9 6,72 7 15,68 0 15,75 3 15,66 4 15,47 8 15,73 9 15,75 0 15,89 4 15,79 1 15,46 5 15,71 3 ($1,000 )

NATH d 6,55 1 6,54 7 6,48 2 6,44 4 6,47 8 6,46 9 6,51 9 6,67 3 6,58 3 6,62 0 15,82 1 15,83 8 15,66 9 15,56 0 15,65 1 15,63 2 15,76 6 15,81 1 15,57 1 15,67 2 Jun

e 198 5 Generi c 6,656 f 6,677 a 6,636 ? 6,622 " 6,67 0 6,67 4 6,73 1 6,83 3 6,74 6 6,80 3 15,751 f 15,817 n 15,754 ? 15,670 " 15,84 0 15,85 4 16,00 8 15,94 6 15,69 7 15,87 7 

### Boile r an

dcontinuou s emissio nmonitorin g syste m cost s ar e included . D A = Dua l Alkali ; cost s includ e a fabri c filte r fo r P M control . C 

### D S = Spra y

Drying ; cost s includ e a fabri c filte r fo r P M contro l (integra l t o th e FG D system) . NAT H = Sodiu

m Scrubbing ; cost s includ e a fabri c filte r P M control . e 

### Generi c = Averag e cost s o f th e lowes t an dhighes t o f th e three FGD/P M systems . f 

### Tota l system

annualize dcost s fo r a boile r firin g highsulfu r coal . g 

### Tota l system

annualize dcost s fo r a boile r firin g mediu m sulfu r coal . Tota l system

annualize dcost s fo r th e lowes t cos t option .
D- 3P.2 8



### TABL E D-4 . ANNUALIZE D COST S FORCOAL-FIRE D BOILER S I N REGION VII I UNDE RTH E PERCEN T S0 2 

### REDUCTION ALTERNATIVE 3

Mode l Boile r Size , 10 ° Btu/h r 

### 15 0

400 Coa l

Typ e E-Bi t D-Bi t B-Bi t E-Su b D-Sub B-Sub E-Bi t D-Bi t B-Bi t E-Sub D-Sub B-Sub Uncontrolle d

SO , Emissions , fb/10 ° Bt u 2.1 0 1.4 5 1.0 8 2.1 0 1.4 5 0.9 6 2.1 0 1.4 5 1.0 8 2.1 0 1.4 5 0.9 6 Annual i



### DA b 6,34 2 6,29 3 6,28 6 6,04 9 5,99 9 6,00 6 14,62 4 14,49 3 14,47 4 13,55 5 13,42 1 13,45 8 ze

dCosts , 

### DSC 6,14 0 6,07 9 6,06 4 5,88 4 5,82 2 5,81 9 14,34 1 14,18 3 14,14 4 13,30 8 13,14 7 13,16 6 ($1,000 )

NATH d 6,95 8 5,88 4 5,86 2 5,72 9 5,65 3 5,64 2 14,24 7 14,04 9 13,99 2 13,26 5 13,06 2 13,04 9 Jun e 198 5

Generi c 6,15 0 6,08 9 6,074 f 5,889 T 5,826 f l . 5,824 g ' ' 14,43 6 14,27 1 14,233 - 13,410. 1 13,242 " 13,254 g 

### Boile r an

d continuou s emissio nmonitorin g system cost s ar e included . DA • Dua l Alkali ; cost s includ e a fabri c filte r fo r P M control . C 

### D S = Spra y

Drying ; cost s includ e a fabri c filte r fo r P M contro l (integra l t o th e FG D system) . NAT H = Sodiu

m Scrubbing ; cost s includ e a fabri c filte r fo r P M control . e 

### Generi c = Averag e cost s o f th e lowes t an d highes t o f th e thre e FGD/P M systems . f Tota l system

annualize dcost s fo r a boile r firing highsulfu r coal . g 

### Tota l system

annualize dcost s fo r a boile r firin g mediu m sulfu r coal . Tota l system

annualize dcost s fo r th e lowes t cos t option .

D- 4P.2 9

TABL E D-5 . ANNUALIZE D COST S FO R RESIDUA L OIL-FIRE D MODE L BOILER S RATE D A T 15 0 MILLIO NBTU/HOU R HEA T INPU T I NREGIO NV UNDE R TH E PERCEN T S0 2 REDUCTIO NALTERNATIVE 3

Oi l Typ e Nomina l S0 2 Emissions , lb/10 ° Bt u Annualize d Costs , ($1,000 ) Jun e 198 5 

### DA C 4,16 7 4,22 2 4,26 4 4,33 3 NATH d

4,03 8 4,04 1 3,92 4 3,97 5 Generic e

4,103 f 4.132 9 4,094 h 4,15 4 3 Percen t Sulfu r R O 1. 6 Percen t Sulfu r R O 0. 8 Percen t Sulfu r R O 0. 3 Percen t Sulfu r R O 3. 0 1. 6 0. 8 0. 3 Boile r and continuou s emissio n monitorin g syste mcost s ar e included . D A» Dua l Alkali ; cost s includ e a fabri c filte r fo r P M control . C D S • Spra yDrying ; cost s includ e a fabri c filte r fo r P M contro l (integra l t o th e FG D system) . NAT H = Sodiu m

Scrubbing ; cost s includ e a fabri c filte r fo r P M control . e Generi c = Averag e cost s o f th e lowes t and highes t o f th e thre e FGD/P M systems . f Tota l syste mannualize d cost s fo r a boile r firin g hig h sulfu r oil . g Tota l syste mannualize d cost s fo r a boile r firin g mediu msulfu r oil . Tota l syste mannualize d cost s fo r th e lowes t cos t option .



### D-5TABL E D-6 . ANNUALIZE D COST S O F TH E VER YLO W SULFURCOAL-FIRE D MODE L BOILER S I N REGION S III , IV , V AND VII I

Averag e Uncontrolle d Mode l Boile r Size , SO ? Emissions , 10 ° Btu/h r Coa l Typ e tb/1 0 Bt u Annualize d Costs , ($1,000 ) Jun e 198 5 Regio n II I 6,06 8 6,71 4

_ a

- 14,93 2 16,67 5

-

— Regio n I

V 6,14 7 6,69 8

-

- 15,14 3 16,63 0

-

— Regio n V

6,16 3 6,32 9 6,15 7 6,26 7 15,17 9 15,62 5 14,75 7 15,05 4 Regio n VII I

5,34 8 5,45 1 5,15 3 5,26 3 12,97 7 13,25 3 12,06 4 12,36 1 o I Oi 

### 15 0

40 0 A-B1 t

AA-B1 t A-Su b AA-Sub A-B1 t AA-B1 t A-Su b AA-Sub 0.8 2 0.6 2 0.6 5 0.4 5 0.8 2 0.6 2 0.6 5 0.4 5

"— " denote s coa l typ e no t availabl e i n thi s region .P.3 1



### APPENDI XE ASSUMPTION S CONCERNINGCOAL SULFURVARIABILIT YP.3 2

Tabl e E- 1 summarize s th e variabilit y statistic s an

daverag e S0 2 emissio nlevel s fo r th e variou s coal s use dinthi s mode l boile r cos t analysi s t o mee t selecte dS0 2 emissio nlimits . Th e 24-hou r standar ddeviatio nvalue s inth e tabl e fo r lo w sulfu r bituminou s (B-Bit ) an dsubbituminou s (B-Sub ) coal s wer e base donth e CE M dat a fo r lo

w sulfu r coal-fire dboiler s presente dinReferenc e 10 . Th e us e o f 0.1 0 a s th e 24-hou r standar ddeviatio nfo r B-Bi t coa l i s a deviatio nfro m previou s studie s whic hassume da valu e o f 0.2 0 fo r bot hbituminou s an d subbituminou s coals . Th e new lowe r valu e fo r bituminou s coa l i s base do n th e S0 « emission s variabilit y dat a inReferenc e 10 . Th e B-Bi t coa l represent s a washe dand/o r blende dcoa l whic hth e Referenc e 1 0 dat a sho w typicall y

ha s a lowe r 24-hou r standar ddeviatio no f nea r 0.10 . Th e B-Sub coal , onth e othe r hand , represent s a nunwashe dsubbituminou s coa l delivere d directl y from th e min e whic hi s characterize db y a highe r 24-hou r standar d deviatio no f nea r 0.20 , accordin g t o th e Referenc e 1 0 data . Th e 24-hou r standar ddeviatio nfo r ver y lo w sulfu r bituminou s coal s (A-Bi t an

dAA-Bit ) o f 0.06 4 wa s calculate db y droppin g th e highes t 1 0 percen t o f th e S0 2 emissio nvalue s inth e Referenc e 1 0 dat a se t fo r washe d bituminou s coa l fire dinBoile r I . Thi s procedur e mimic s th e operation s anticipate da t a

nindustria l boile r sit e wher e th e operato r mus t compl y wit h a 0. 9 o r 0. 7 l bS0 2 /millio nBt ustandard . Inthi s case , th e operato r wil l likel y sampl e th e coa l upo narriva l an drejec t coa l portion s wit hhigh sulfu r contents . Th e samplin g an drejectio ncoul dals o b e don e a t th e min e befor e shipment . Thi s procedur e i s consisten t wit hth e cos t analysi s in Referenc e 3 whic hstate s tha t additiona l samplin g an dhandlin g wil l b e require dfo r thes e coals . Referenc e 3 indicate dtha t additiona l samplin g an dhandlin g woul dno t b e require dfo r ver y

lo w sulfu r subbituminou s coal s (A-Suban dAA-Sub ) fire d t o mee t th e 0. 9 an

d0. 7 l bS0 2 emissio nlimits , respectively . Henc e th e 24-hou r standar ddeviatio nvalu e assume dfo r thes e coal s wa s th e same a s tha t discusse dabov e fo r th e B-Subcoa l (i.e. , 0.20) . Th e 24-hou r autocorrelatio nvalue s show ninTabl e E- 1 wer e als o base d onth e emission s dat a fo r lo w sulfu r coal s inReferenc e 10 . Thes e dat a



### E- 1TABL E E-1 . S0 2 EMISSION S VARIABILIT YAMON G MODEL BOILE

RCOA L TYPES 3E-2 SO ? Emissio n z L1mi t (lb/10 ° Btu ) 2. 5 1. 2 0. 9 0. 7 2. 5 1. 2 0. 9 0. 7 Coa l Typ e

E-B1tum1nou s B-B1tum1nou s A-B11urn 1 nou s AA-B1tuminou s D-Subb1tum1nou s B-Subb1tum1nou s A-Subb1tum1nou s AA-Subbitum1nou s S0 2 Emis s 24-Hou r Standar d Deviatio

n ND b 0.1 0 0.06 4 0.06 4 N D 0.2 0 0.2 0 0.2 0 Ion

s Statistic s 24-Hou r Autocorrelatio

n N D 0. 7 0. 7 0. 7 N D 0. 7 0. 7 0. 7 Average S0 ~

Emissio nLeve l (lb/10 ° Btu ) 2.1 0 1.0 8 0.8 2 0.6 2 1.4 4 0.9 6 0.6 5 0.4 5 24-Hou r Relativ e Standar

d Deviatio

n N D 9. 3 7. 8 10. 3 N D 20. 8 30. 8 44. 4 Se e Referenc e 1 0 fo r definitio

n o f terms . 'N D = N o data .P.3 4

indicat e tha t autocorrelatio nvalue s ar e no t a functio no f coa l type , sulfu r content , o r standar ddeviation . Th e statistica l procedure s presente dinReferenc e 1 2 wer e use dt o calculat e th e averag e S0 2 emissio nlevel s require dt o compl y wit hth e selecte demissio nlimit , a s show ninTabl e E-1 , usin g th e standar ddeviatio n an dautocorrelatio nvalue s fo r eac hcoal . Th e calculation s assume da one-in-1 0 year s exceedanc e frequency , a 30-da y rollin g averag e period , an da norma l distributio no f th e 30-da y rollin g averages . A s a nexampl e o f th e calculationa l procedure s used , conside r th e cas e o f a B-Bi t coa l (wit ha 24-hou r S0 2 emissio nstandar ddeviatio no f 0.1 0 an d 24-hou r S0 ? emission s autocorrelatio no f 0.7 ) whic hi s fire dt o mee t a n emissio nlimi t o f 1. 2 l bS0 2 /millio nBt usubjec t t o th e assumption s discusse dabove . Sinc e onl y th e standar ddeviatio nan dautocorrelatio no f th e coa l ar e known , th e procedur e i s a niterativ e one . A

ninitia l estimat e o f th e relativ e standar ddeviatio n(RSD ) o f a coa l use dt o mee t thi s limi t coul db e 1 0 percent . Tabl e A- 8 o f Referenc e 1 2 indicate s tha t a coa l wit h a naverag e S0 2 emissio nleve l o f 1.0 7 o r les s woul db e require dt o mee t th e 1. 2 l bS0 2 /millio nBt ulimi t give nthes e variabilit y characteristics . Thi s correspond s t o a variabilit y allowance , C , o f 0.1 3 l bS0 2 /millio nBt u(i.e. , 1.2 0 - 1.0 7 - 0.13) . However , th e standar ddeviatio nfo r a coa l wit ha nRS D o f 1 0 percen t an

daverag e emissio nlimi t o f 1.0 7 lb/millio nBt ui s 0.10 7 (i.e. , 1.07x0.1 0 = 0.107) . Thi s i s greate r tha nth e 0.1 0 standar ddeviatio n characteristi c o f th e B-Bi t coal . Whil e i t i s possibl e t o iterat e onth e value s i nTabl e A- 8 alon e (thi s doe s requir e interpolatio no f tabl e values ) t o arriv e a t th e fina l solution , a usefu l relationshi pdiscusse d1n Appendi xB t o tha t repor t provide s a deterministi c approach . Th e equation s inAppendi xB show

tha t th e allowanc e fo r variability , C , i s directl y proportiona l t o th e standar ddeviation , SD , i f al l othe r thing s ar e equal . Thus ,
C j = C , |^- J (1 )



### E- 3P.3 5

t Substitutin g th e appropriat e value s fro m abov e yield s 

### /o.ioo \ C 

### l = 

### °' 1 3 

### \0A07) " °' 1 2 

### ( 2 

### ) an d Emission s averag e = 1.2 0 - 0.1 2 = 1.0 8 (3 ) Therefore , give na 24-hou r S0 2 emission s standar ddeviatio no f 0.1 0 an d autocorrelatio no f 0.7 , a B-Bi t coa l wit ha naverag e S0 2 emissio nleve l o f 1.0 8 lb/millio nBtu , o r less , coul db e fire dt o mee t a 1. 2 l bS0 2 /mill1o n Bt uemissio nlimit . Thes e same relationship s wer e use dt o calculat e th e remainde r o f th e averag e S0 2 emissio nlevel s inTabl e E-1 . Th e fina l colum ninthi s tabl e i s simpl y th e 24-hou r standar ddeviatio ndivide db y th e calculate daverag e S0 2 emissio nlevel .



### E-4P.3 6



### APPENDI XF METHODOLOG YAN D ASSUMPTION S USE D FO RMODE L BOILE RCOS T ANALYSE SP.3 7

Th e methodolog y

an dassumption s use dinthi s analysi s t o calculat e cost s fo r mode l boiler s an dassociate dai r pollutio ncontro l equipmen t ar e th e same a s thos e use dinprio r mode l boile r cos t analyse s (a s describe din Reference s 1 , 2 , 7 , an d8 ) excep t wher e note dinthi s appendix . Thes e exception s were : modification s t o th e maximu m fue l flexibilit y

optio no f IBCOS T whe nfirin g J-Bi t coal ; th e us e o f natura l ga s durin g FG D malfunction ; exces s ai r level s fo r NO contro l oncoal-fire dboilers ; an d FG D control s onboiler s firin g highe r sulfu r oils . Th e IBCOS T compute r program use dt o calculat e mode l boile r cost s wa s modifie dt o reflec t thes e changes . Maximu m Fue l Flexibilit y

Whe nFirin g J-Bi t Coa l Capita l cost s wer e estimate dinthi s analysi s usin g th e maximu m fue l 2 8 flexibilit y

optio no f IBCOS T a s wa s don e inpreviou s analyses . ' Thi s option , i f chosen , design s th e boile r an dFG D system

wit hth e flexibilit y t o fir e highsulfu r fuels . Fo r coal-fire dboilers , th e capita l cost s fo r th e boile r an

dFG D system

ar e base donth e flow rat e an

dS0 2 loadin g o f flu e ga s correspondin g t o th e generi c highsufu r coal . Fo r boiler s designe dt o fir e bituminou s coals , th e boile r an dFG D system

ar e designe dt o fir e a coa l wit h a heatin g valu e o f 11,50 0 Btu/l ban da sulfu r conten t o f 3.1 9 weigh t percen t (5.5 4 l bS0 2 /1 0 Btu) . Fo r boiler s designe dt o fir e subbituminou s coals , th e boile r andFG D system ar e designe dt o fir e a coa l wit ha heatin g valu e o f 8,80 0 Btu/l banda sulfu r conten t o f 0.9 3 weigh t percen t (2. 1 l bS0 2 /10 6 Btu) . Fo r boiler s firin g J-Bi t coal , thi s optio nwa s modifie dt o calculat e th e capita l cost s o f th e FG D system base donth e sulfu r conten t o f J-Bi t coa l (4.6 7 percent ) an dth e coa l heatin g valu e o f 11,50 0 Btu/lb . Operatin g an dmaintenanc e cost s whic hdepen donfue l propertie s wer e base dona heatin g valu e an

dsulfu r conten t o f th e actua l fue l typ e chosen . Unde r th e percen t reductio nalternative , th e FG D system i s designe dt o achiev e 9 0 percen t S0 2 removal .



### F- lP.3 8

Natura l Ga s Us e Durin g FG D Malfunctio n FG D contro l cost s include dth e cost s associate dwit hfirin g natura l ga s durin g FG D malfunction . Th e previou s analysi s fo r coal-fire dboiler s include dth e fue l cost s associate dwit hfirin g natura l ga s bu t omitte dth e cost s fo r natura l gas-burnin g equipmen t capabl e o f firin g a t 10 0 percen t e 7 2 load . Th e cos t result s presente dinthi s memo includ e th e cost s fo r th e natura l ga s burnin g equipmen t a s par t o f th e tota l FG D malfunctio ncosts , Th e equipmen t cost s fo r firin g natura l ga s a t 10 0 percen t loa dwer e already incorporate dint o th e oil-fire dboile r costs , sinc e th e boile r wa s designe d wit hth e capabilit y

t o fir e bot hfuels . A s discusse dinSectio n2.0 , th e natura l ga s pric e use dt o calculat e th e fue l cost s o f firin g natura l ga s durin g period s o f FG D malfunctio ni s base donth e lo w oi l pric e scenari o an d th e non-carriage/rigi dmarke t a s cite dinReferenc e 5 . Exces s Ai r Level s fo r N O Contro l wit hCoal-Fire dBoiler s Fo r coal-fire dboiler s usin g lo w exces s ai r (LEA ) t o contro l NO emissions , uncontrolle dan dcontrolle dexces s ai r level s wer e 4 8 an d3 2 percent , respectively . Thes e level s deviate dslightl y fro m thos e use di n th e 198 4 mode l boile r analysi s (5 0 percen t fo r uncontrolle dan d3 5 percen t fo r controlle dexces s ai r levels) . Th e cos t impact s o f thes e change s ar e minor . FG D Contro l fo r Boiler s Firin o Highe r Sulfu r Oil s Althoug hanFG D system i s capabl e o f reducin g P M level s t o les s tha n 0. 1 lb/1 0 Bt ufro

m a boile r firin g highsulfu r oil , th e previou s analysi s di dno t conside r th e cost s require dfo r handlin g th e highlevel s o f particulate s collecte db y a nFG D system . IBCOS T doe s no t currentl y includ e suc ha

nalgorith

m fo r sodiu

m scrubbin g (bu t doe s includ e on e fo r dua l alkali) . Th e approac huse dinthi s memo t o estimat e th e cost s fo r a combine dPM/S0 2 sodiu m scrubbe r ona boile r firin g mediu m o r highsulfu r



### F- 2P.3 9

_m_t. ••* ' oil s (i.e. , oil s containin g 1. 6 weigh t percen t sulfu r o r greater ) wa s t o

includ e th e cost s o f a separat e ventur i scrubbe r wit htha t o f a sodiu m scrubber . Thi s approac hprovide da conservativ e estimat e o f th e cost s o f a combine dPM/S0 2 sodiu m scrubbe r applie dt o a boile r firin g highe r sulfu r oils . Th e generi c cost s o f a nFG D system

fo r a boile r firin g a highe r sulfu r oi l wa s base donth e averag e cost s o f th e combine dPM/S0 2 dua l alkal i scrubbe r an

dth e estimate dcombine dPM/S0 2 sodiu m scrubber .



### F- 3