Page 1 of 935

6560-50-P

EN\¡IRONMENTAT PROTECTION AGENCY

40 CER Parts 60 and 63

[EPA-HQ-OAR-2009 -0234; EPA-HQ-OAR-2011-0044, E:RL-9+489286-

I

RIN 2O6O-AP52

National Emission Standards for Hazardous Air Pollutants

from Coal- and OiJ.-fired Electric UtiJ.ity Ste¡an¡ Generating

Units and Standards of Performance for Fossil-E\rel-Fired

Electric Utility, fndustrial-Comnercial-Institutional, and

Small Industrial-Commercial-Institutional Ste:'n Generating

Units

AGENCY: Environmental- Protection Agency.

ACTION: Proposed rul-e.

SIIM!{ARY: The united states (u . s . ) Environmental- protection

Agency (EPA or Agency) is proposing national emission

standards for hazardous air pofl-utants (NESHAp) from coal--

and oif-fired el-ectric utility steam generating units

(EGUs) under Cfean Air Act (CAA or the Act) section II2(d,)

and proposing revised new source performance standards

(NSPS) for fossil fuef-fired EGUs under CAA section 111 (b) .

publ-ic health by reducing emissions of the hazardous air

pollutants (HAP) l-isted in CAA section II2(b) . rn

dments to the NSPS are in
Page 21 of 935

and co-benefits of these rules, many premature deaths from

exposure to air pollution wil-l- be avoided by the

application of controls that are wel-I-known, broadly

applied, and availabl-e. To the extent that isol-ated issues

remain concerning the availability of electricity in some

more remote parts of the country, we bel-j-eve that EPA has

the ability to work with companies making good faith

efforts to comply with the standards so that consumers in

those areas are not adversely affected.

Consistent with the recentJ-y issued Executj-ve Order

(EO) 13563, "Improving Regulation and Regulatory Review, "

we have estimated the cost and benefits of the proposed

rul-e. The estimated net benefits of our proposed rule at a

3 percent discount rate are $48 to 130 billion or ç42 to

çI20 bill-ion at a 7 percent discount rate.

SUMMARY OF THE MONETIZED BENEFTTS, SOCIAL COSTS, AND NET

BENEFTTS FOR THE PROPOSED RULE rN 2016 (MTLLTONS OE 2007$)'

32 Discount Rate 1Z Discount Rate

Total- Monetized

Benefitsb

$59,0

00

to $140,00

0

$53, oo

0

to $130,0

00

Hg-related

Benefitsc

$4.1 to $5.9 $0.45 to

$0.89

COz-rel-ated

Benefits

$s70 570

PMz.s-related Cobenefitsd

$5958, 000 ro

$140, ooo

$53,000 to

$l-3+120,000

Totaf Social Costs" $10,900 $10,9oo

Net Benefits $48,0

00

to $13o, oo

0

ç42,00

0

to s130,00

0
Page 150 of 935

natural emissions or re-emissions from previously deposited

anthropogenic Hg.nn'.45'46 It is believed that hal-f of reemitted Hg originates from anthropogenic sources.4'7,48

Current estimates of total_ global Hg emissions based

on a 2005 inventory range from 7,300 to 8,300 tpy .Ae,so The

united Nations Environment Programme (uNEp) estimates of

2005 global Hg emissions are somewhat lower, at S7-?ge5,600

44 Lindberg, S., Bullock, R., Ebinghaus, R., Engstrom, D.,

Feng, X., Fitzgerald, W., et a1. (2001). A Synthesis of

Progress and uncertainties in Attributing the sources of

Mercury in Deposition. Anbio, 36(t), 19-33. 4s Lohman, K., Seigneur, C., Gustin, M., & Lindberg, S. (2008). Sensitivity of the global atmospheric cycÌe of

mercury to emissions. Applied Geochemistry, 23(3), 454-

466. 46 Seigneur, C., Vijayaraghavan, K. I Lohman, K. I

Karamchandani, p., & Scott, C. (2004) . Global_ Source Attribution for Mercury speciati-on in the united states.

Environmental- Science and Technol_oqy(38), 555-569. 41 Mason, R., Pirrone, N., & Mason, R. p. (2OOg) . Mercury

emissions from natural processes and their importance in the global mercury cyc1e. rn Mercury Fate and Transport in the Gl-obaL Atmosphere (pp. 173-191) : Springer U. S. 48 Selin, N. 8., Jacob, D. J., park, R. J., yantosca, R. M., Strode, S., JaegJ-é, L. , et al_. (2001) . Chemical

cycJ-i-ng and deposition of atmospheric mercury: Gl_oba1

constraints from observations. J. Geophys. Res, 172, 1071-

7011 .

4e Lindberg, S., Bullock, R., Ebinghaus, R., Engstrom, D.,

Feng, X., Fitzgerald, W., et al. (2001). A Synthesis of

Proqress and uncertainties in Attributing the Sources of

Mercury in Deposition. Anbio, 36(I), 19-33. s0 Pirrone, N., Cinnireì-la, S., Feng, X., Finkelman, R. 8., Friedli, H. R., Leaner, J., et al-. (2010) . Global mercury

emissions to the atmosphere from anthropogenic and natural

sources . Atmospheric chemistry and Physics Discussions,

7 0 (2) , 4119- 41 52 .
l-++10 6 ,

TABLE 4

000 tons for HCJ-,

. SUMMARY OF ACT

Page 170 of 935

and 36,OOO tons for HF.88

D GAS EMTSSIONS FROM EGU SOURCES

llUsing cyani-de emissions for HCN

Metal HAP

U.S. EGUs are the predominant source of emissions

nationally for many metal- HAP, incJ-uding Sb, As, Cr, Co,

and Se.

Metal-s are emj-tted prj-marily because they are present

in fuels. Table 5 of this preambJ-e shows sel-ected metals

emj-tted by EGUs and emission estimates based on data from

the 2005 NATA inventory. 2010 estimates of metal- HAP

emissions are 25 tpy for antimony (Sb), 43 tpy for As, 2

tpy for Bê, 3 tpy for Cd, 222 tpy for Cr, 1,9 tpy for Co,

88 I¡rle bel-ieve our estimate of the current l-evel- of acid HAP

emissions based on the 201,0 ICR database may underestimate

total- EGU acid HAP emissions due to targeting of the 20L0

fCR on the best performing EGUs.

2005 Acid HAP

Emissions from the

Nationaf Air Toxics

Assessment (NATA)

Percent of totalU. S. anthropogenic

emissions in 2005

U. S. EGU

Emissions

Non EGU

emission

S

r,200 14,000

Hydrogen

Chloride 78,000

Hydrogen

El-uoride 41,000 28 ,000
Page 171 of 935

183 tpy for Mn, 387 tpy for Nj-, and 258 tpy for Se.8e

Depending on the meta1, EGUs account for loetween f-13 and

.69-83 percent of national- metal HAP emissions, and as a

resul-t it remains approprj-ate to regulate EGUs.

TABLE 5. SUMMARY OF METAL EMISSIONS FROM EGU SOURCES

3. Quantitative Risk Characterizations to fnform the

Appropriate and Necessary Finding

EPA conducted quantitative risk analyses to eval_uate

8e Vüe bel-ieve our estimate of the current level- of metalHAP emissions based on the 2010 ICR database may

underestimate total EGU metal HAP emissi_ons due to targeting of the 201-0 fCR on the best performing EGUs.

2005 Metal HAP

Emissions from

the inventory

used for the

National Air

Toxics

Assessment

(NArA)

Percent of total U.S.

anthropogenic

emissions in 2005

U. S. EGU

Emissions

Non

EGU

emi

ssions

Antimony I9 83 r9z

Arsenic 200 120 622

Beryllium 10 13 442

Cadmium 25 3B 392

Chromium L20 430 22%

Cobalt 54 60 412

Manganese 210 180

tt

13%

Nickel- 320 840 2B%

Sel-enium s80 120 83%
Page 187 of 935

assumptj-on hol-ds j-n watersheds where air deposition is the

primary source of Hg loadings, and as a resul_t, watersheds

where this is not the case are removed from the risk

analysis. The practical application of the MMaps approach

is that U.S. EGUs wil-l- account for the same proportion of

fish tissue MeHg in a watershed as they do for Hg

depositi-on. MMaps is discussed in greater detait in

section 1. 3 and Appendix E of the National_ Scal_e Mercury

Risk Assessment TSD. Patterns of U.S. EGU-attributable

fish tissue MeHg concentratj-ons are summarized in Tables 8

an4-9--of this preamble. Tabl-e I of this preamble compares

total and U.S. EGU-attributable fish tissue Meg

concentratj-ons for the 2005 and 2016 scenarios by watershed

percentile.

TABLE 8. COMPARTSON OF TOTAL AND U.S. EGU_ATTRIBUTABLE FTSH

TISSUE MEHG CONCENTRATIONS FOR 2OO5 AND 2076

Because the focus of this analysis is on higherStatistic

Fish tissue MeHg concentration (ppm)

2005 2076

Total U. S. EGUattributable Total U.S. EGUattributabl-e

Mean 0. 31 0 .024 0 .29 0.008

50"'Percentile 0 .23 0.014 0 .20 0.00s

75"" Percentile 0. 39 0 .032 0. 36 0.01_1

90'" Percentil-e 0 .61 0. 056 0. 63 0.019

95"'Percentile 0. 91 0.079 0.87 0.026

99"" Percentil-e L .34 0.150 r .29 0.047

of the National- Scale Mercury Risk Assessment TSD).
Page 216 of 935

In 2016, EGUs are projected to account for an

estimated +45 percent of anthropogenic Hg (excluding

fires) in the continental US. Application of availabl-e Hg

control-s in 2016 that woufd be required under section 1L2

reduces Hg emissions from 29 down to 6 tons, achieving a 23

tpy reduction of Hg from EGUs, which results in a 19

percent reduction in U.S. EGU emJ-ssions, and a 36 percent

reduction of total anthropogeni-c Hg emissions nationally.

fn 2076, EGUs are projected to account for 54-53

percent of totaf U.S. anthropogenic HCI_. Application of

avail-abl-e HCI control-s in 201,6 that woul_d be required under

section I1,2 achieves a 68,000 tpy (reduction in HCf

emissions (a 91 percent reduction in EGU emissions),

resulting in a #49 percent reduction of anthropogenic

emissi-ons national-ly.

Metaf HAP emj-ssions are a component of pM, and are

expected to be reduced along with PM as a resul-t of

application of PM controls. In 2016, application of

control-s required under section II2 is expected to provide

an average reduction in PM for the continental_ U.S. of 38

percent. Although no specific projection of metal_s is

avail-abl-e for 2016, applying the 38 percent reduction in pM
Paqe 2t7 of 935

to the 20L0 ICR emissions l-evel_s of anthropogenic metalsl2e,

I resuJ-ts in reductions of approximately 53€-430 tons of t-metals per year.t3o

EPA bel-ieves these projected reductions in Hg, acid

gases, and metal- HAP emissions demonstrate the

ef fectiveness of avail-able control-s.

6. Consideration of the Role of U.S. EGU Hg Emissions in

the Gl-obal Effort to Decrease Hg Loadings j_n the

Envi-ronment

This woul-d alfow the U.S. to demonstrate effective

technologies to reduce Hg; such feadership could provlde

confidence to other countrj-es that they can succeed in

meeting their commitments. Mercury pollution is a

significant international environmental challenge, and it

is well- understood that efforts that reduce Hg emissions in

other countries will reduce Hg that impacts U.S. public

health and the environment. Recognizinq this, EpA and

others in the U.S. Government are actively involved in

international- efforts to reduce Hg pollution. These

efforts include global negotiations aimed at concluding a

1'2e It 1s generally assumed that the same types of controls that reduce PM wiff al-so reduce metals, because they are

components of the PM. 130 This value is 44-38 percent of 1,4ee-140 tons, which is the total tonnage of the metafs frora--*able-31-isted in TabÌe 5, based on the 20L0 ICR emissions data.
Page 288 of 935

derived fuel-fired" if the EGU burns any sol-id oil-derived

fuel (e.9., petroleum coke) and meets the proposed

definitlon of "fossil- fuel- fired." EpA is al-so considering

a l-imited-use subcategory to account for liquid oir-fired

units that only operate a limited amount of time per year

on oil and are inoperative the remainder of the year. such

units could have specific emission limitations, .reduced

monitoring requirements (fimited operation may preclude the

ability to conduct stack testing), or be held to the same

emission limi-tations (which could be met through fuel

sampling) as other liquid oil-fired units. EpA solicits

comment on all of these proposed subcategorization

approaches.

TABLE 10. EMISSTON LIMITATIONS FOR COAL-FIRED AND SOLTD

OTL-DERIVED FUEL-FIRED EGUS

Subcategory Totalparticulate

matter

Hydrogen

chl-oride

Mercury

Existing coal--

fired unit

designed for

coal

Btu/lb

0.030

1bIMMBtu

(0 . 30 lblMVüh )

0.0020

LbIMMBtu

( 0. 020

IblMvüh )

1.0 lblretu

(0 . €€€€-0 .008

lblGVrh)

Existing coal--

fi-red unit

designed for

coal

Btu/lb

0.030

l-blMMBIu

(0. 30 rblMvüh)

0.0020

1blMMBtu

( 0. 020

lblMvüh )

11.0 IblTBtu

(0.20 \blcvÙh)

4.0 LblTBtu*

(0.040

Iblcl/üh* )

Existing - IGCC 0.050

1blMMBtu

(0.30 lblMWh)

0.000s0

lbIMMBtu

(0.0030

1blMi/üh)

3. 0 l-blTBtu

( 0. 020

r_b/GWh )
Page 312 of 935

prepare for CAMR, and the fact that many state regulations

currentfy require the instal-l-ation and operation of Hg CEMS

i-n order to demonstrate compli-ance \^/ith various SIP and

consent decrees.

(3) For new or reconstructed IGCC units or coal-fired

or sol-id oil--derived fuel--fired units with SOz emissions

control devices, we are proposing two compliance options

for acid gases. First, âD SOz or an HCI- CEMS coul-d be

installed and certified. We are proposing that the SOz

monitor be certified and quality-assured according to 40

CFR part 15 or PS 2 or 6 and Procedure 1 in Appendices B

and E, respectively, of 40 CFR part 60. We bel-ieve this is

reasonable, because nearJ-y all utility units are subject to

the ARP, and coal--fj-red ARP units al-ready have certified SO2

monitors in place that meet Part 15 requirements. For HCImonitors, PS 15 or 6 in Appendix B to 40 CFR part 60 would

be used for certification and, tentatively, Procedure 1 of

Appendix F to 40 CFR part 60 would be foll-owed for on-goi-ng

QA.

Note that a PS specific to HCI- CEMS has not been

promulgated yet, but we expect to publish one prior to the

compliance date of this proposed rule and to make it

avail-abl-e to source o\^/ners and operators. In the meantime,
Paqe 462 of 935

Btu/l-b Btu/l-b

Soz 0 .20

1blMMBtu

(2.0

\blMWh )

0 .20

1blMMBtu

(2.0

lblMWh )

NA NA 0.40

1blMMBtu

(5. 0

rblMWh)

Total- nonHg metals

0.000040

1blMMBtu

(0.00040

\blMr/üh )

0.000040

IbIMMBtu

(0.00040

IblMWh)

5.0

(0.0s0)

NA 0.000050

l-blMMBtu

(1--+0. 00

1

lblMVüh)

Antimony,

Sb

0. 60

1blTBtu

(0.0060

rblGVüh )

0. 60

tblTBru

(0.0060

rblGWh)

0.40

(0.0040)

0 .20

(0.0030)

0. 40

1blTBtu

(0.0070

LblGWh)

Arsenic, As 2.0

1blTBtu

( 0. 020

IblcI/üh )

2.0

l-blTBtu

(0.020

IblGWh)

2.0

(0.020)

0.60

(0.0070)

0. 40

l-blTBtu

(0.0040

IblGVüh )

BeryÌlium,

Be

0 .20

1blTBtu

(0.0020

IblGVüh )

0 .20

1blTBtu

(0.0020

\blcl/üh )

0. 030

(0.0030)

0.060

(0.00070

)

0.070

1blTBtu

(0.00070

lblcvüh )

Cadmium, Cd 0.30

1blTBtu

( 0. 0030

lblc[/üh)

0.30

IblTBtu

( 0. 0030

Iblci/ùh)

0 .20

( 0. 0020 )

0. 10

(0.0020)

0.40

1blTBtu

(0.0040

\blGWh )

Chromium,

Cr

3.0

IblTBtu

(0.030

rblGVüh)

3.0

1blTBtu

( 0. 030

rblGVüh )

3.0

(0.020)

2.0

(0.020)

2.0

1blTBtu

(0.020

tblcwh)

Cobal-t, Co 0.80

1blTBtu

(0.0080

\blct/üh)

0.80

1blTBtu

(0.0080

rblGVüh )

æ2.0

(0.0040)

3.0

(0.020)

2.0

lblTBtu

( 0. 020

rblct/üh )

Lead, Pb 2.0

lblTBtu

(0.020

rblc[/üh)

2.0

lblTBtu

( 0. 020

lblcvrh )

2æ0. 00

02

l-blMMBtu

(0.3+

003

rblMvüh)

2.0

(0.030)

11.0

lblTBtu

( 0. 020

Iblcvüh )

Manganese,

Mn

5.0

l-blTBtu

( 0. 0s0

lblcwh

5.0

l-blTBtu

( 0. 050

lblGWh

3.0

(0.020)

5.0

(0.060)

3.0

1blTBtu

(0.040

Iblcwh )

Mercury, Hq NA NA NA 0.050 NA
Page 463 of 935

NA : Not appl-icabfe

TABLE L6. ALTERNATE EMTSSION LIMITAT]ONS FOR NEW COAL- AND

OTL-FTRED EGUS

lblTBtu

(0.00070

rblGWh )

NickeI, Ni 4 U

lblTBtu

(0.040

IblGWh)

4 .0

1blTBtu

(0.040

rblcwh )

5.0

(0.050)

8.0

(0.080)

9.0

1blTBtu

(0.090

IblGWh )

Selenium,

Se

6.0

l-blTBtu

(0.060

IblGWh)

6.0

l-blTBtu

(0.060

Iblcl/ùh )

22 .0

(0 .20)

2.U

(0.020)

2.0

lblTBtu

( 0. 020

IblGWh )

Subcategory Coal--

fired

unit

designed

for coalBtu/1b

Coalfired

unit

designed

for coaf

Btu/fb

rGCC* Liquid

oi1,

LblGWh

Solid

oil--

derived

Soz 0.40

rblMWh

0.40

LblMWh

0.40

]b/MVúh

NA 0. 40

l_b/MVüh

Totalmetals

0.000040

lblMWh

0.000040

IblMVüh

0.000040

1blMWh

NA 0.00020

1blMWh

Antimony,

Sb

0.000080

lblGi/üh

0.000080

lblcwh

0.000080

IblGVÙh

0.0020 0.00090

lblcwh

Arsenic, As 0.00020

IblGr/üh

0.00020

lblGWh

0.00020

lblc[/üh

0.0020 0.0020

IblGVüh

BeryIlium,

Be

0.000030

IblGWh

0.000030

lblGI/ùh

0.000030

rblcwh

0.00070 0.000080

rblcl/üh

Cadmium, Cd 0.00040

rblct/üh

0.00040

lblcwh

0.00040

rblGI/üh

0.00040 0.0070

1blGI/üh

Chromium,

Cr

0.0æ

020

\blGI/üh

0.eæ

020

lblGWh

0.eæ

020

IblGWh

0.020 0.0060

lblc[/üh

CobaIt, Co 0.00080

LblGVrh

0.00080

1blGr/üh

0.00080

Iblcl/ùh

0.0060 0.0020

\blGI/üh

Lead, Pb 0.00090

lblGVüh

0.00090

1blcwh

0.00090

Iblcvqh

0.0060 0 .020

IblGVüh

Mercury, Hq NA NA NA 0.00010

lblGVüh

NA

Manganese,

Mn

0.0040

Iblcvüh

0.0040

rblGWh

0.0040

lblcwh

0.030 0.0070

1blci/üh
Page 555 of 935

statistical-ly significant different from zero. As a

resul-t, the authors concl-ude that j-ncreases in pollution

abatement expenditures do not necessarily cause

economically significant employment changes. The

conclusi-on is simil-ar to Berman and Bui (200L) who found

that increased air quality regulation in Los Angeles did

not cause large employment changes.182 For more

information, please refer to the RIA for this proposed

rul-e.

The ranges of job effects calcul-ated using the

Morgenstern, et af., approach are l-isted in Table 26.

TABLE 26. RANGE OF JOB EFFECTS FOR THE ELECTRICITY SECTOR

u Expressed in 1,981 dollars. See footnote 2-a f rom Tabl-e

9-3 of the RIA for inflation adjustment factor used in the

anal-ysis. o According to the 2OO1 Economic Census, the electric por^/er

generation, transmission and distribution sector (NAICS

22IL) had approximately 510,000 paid employees.

r82 For al-ternative views in economic journals, see

Henderson (1996) and Greenstone (2002).

Estj-mates using Morgenstern, et al. (2001)

Demand Effect Cost Effect Factor Shift

Effect

Change in

Ful-l-Time Jobs

per Million

Dol-l-ars of

Environmental

ExPenditureu

-3.s6 2.42 2.68

Standard Error 2 .03 1. 35 0.83

BPA estimate

for Proposed

Rul-eb

-45,000 to

+2,500

+4t100 to

24,000 +200 to 32,000
Page 560 of 935

other air pollutants, ecosystem effects, and visibility

impairment. The benefits from reducing various HAP have

not been monetj-zed in this anal-ysis, including reducing

681000 tons of HCI-, and 3,200 tons of other metal-s each

year. Although we do not have sufficient information or

modeling availabl-e to provide monetized estimates for this

rulemaking, h/e include a qualitative assessment of the

health effects of these air po1J-utants in the RIA for this

proposed rule, which is avaj-labl-e in the docket.

TABLE 28. SUMMARY OF THE MONETIZED BENEFITS, SOCIAL COSTS,

AND NET BENEFITS FOR THE PROPOSED RULE IN 2016

(MTLLTONS OE 2006$).

" Al-I estimates are for 2016, and are rounded to two

significant figures. The net present value of reduced COz

emissions are calcul-ated differently than other benefits.

The same discount rate used to discount the value of

damages from future emissions (SCC at 5, 3,2.5 percent) is

3% Discount Rate 1Z Discount Rate

Total- Monetized

Benefitsb

$59, o

nn

to $140,00

n

$53, oo

tl

to $130, o

00

Hg-related

Benef i-ts"

$4.1 to $5.9 $0.45 to $0.89

CO2-related

Bene fits

$s70 $570

PMz.s-related Cobenefitsd

$59,000 to

$14o, ooo

$53,000 to

$J-3+120,000

Total- Social- Costs' $10,900 $10,900

Net Benefits $48,0

00

to $13o,oo

0

ç42,00

o

to $ 130, 00

0

Non-monetized

Benefits

Visibility in Class I areas

Cardiovascul-ar effects of Hq exposure

Other health effects of Hq exposure

Ecosystem effects

Commercial and non-freshwater fish

consumption
Page 601 of 935

this proposed rul-e, HAP h¡ould be reduced by thousands of

tons, incJ-uding reductions in HCI_, HF, metal_l_ic HAp

(incl-uding Hg), and several other organic HAp from BGUs.

studies have determined a relationship between exposure to

these HAP and the onset of cancer; however, the Agency is

unabl-e to provide a monetized estimate of the HAp benefits

at this time. fn addition, there are significant

reductlons in PMz.s and in So2 that would occur, including

approximately +€€-84 thousand tons of pMz.s and over 2

mj-l-l-ion tons of soz. These reductions occur by 2016 and are

expected to continue throughout the fife of the affected

sources. The major health effect associated with reducing

PMz.s and PMz.s precursors (such as SOz) is a reduction in

premature mortality. other hearth effects associated with

PMz.s emission reductions incl-ude avoiding cases of chronj-c

bronchitis, heart attacks, asthma attacks, and work-l_ost

days (i.e., days when employees are unabl_e to work) .

Although we are unable to monetize the benefits associated

with the HAP emissions reductions other than for Hg, r^re are

abl-e to monetize the benefits associated with the pMz.s and

soz emissions reducti-ons. For soz and PMz.s, r^rê estimated

the benefits associated wi-th health effects of pM but h/ere

unabl-e to quantify all categories of benefits (particularly
Page 602 of 935

those associated with ecosystem and visibil-ity effects).

Our estimates of the monetized benefits in 2016 associated

with the implementation of the proposed alternative range

from $59 bil-l-ion (2001 doll-ars) to $140 bi]tlon (2001

dol-l-ars) when using a 3 percent discount rate (or from $53

bill-ion (2001 dol-l-ars) to $130 billion (2001 dol-l-ars) when

using a 7 percent discount rate). Our estimate of socialcosts is $10.9 billion (2001 dollars). For more detailed

information on the benefits and costs estimated for this

proposed rulemaking, refer to the RfA in the docket.

3. Future and Disproportionate Costs

UMRA requires that we estimate, where accurate

estimatj-on is reasonably feasibl-e, future compliance costs

imposed by this proposed rule and any disproportionate

budgetary effects. Our estj-mates of the future compliance

costs of this proposed rule are discussed previousJ-y in

this preamble.

EPA assessed the economic and financial impacts of the

rul-e on government-owned entities using the ratio of

compliance costs to the val-ue of revenues from electricity

generation, and our resul-ts focus on those entities for

which this measure coul-d be greater than 1 percent or 3

percent of base revenues. EPA projects that 4€-55
Page 603 of 935

government entities wil-1 have compli-ance costs greater than

1 percent of base generation revenue in 2016, and +-37 may

experience compliance costs greater than 3 percent of base

revenues. Al-so, one government entity is esti_mated to have

all of its affected units retire. Overa11, +€-17 unj-ts

owned by government.entities retire. It is al-so worth

noting that two-thirds of the net compliance costs shown

above are due to l-ost profits from retirements. More than

haff of those lost profits arise from retiring two large

uni-ts, according to EPA modeling. For more detail_s on

these resul-ts and the methodol-ogy behind their estimation,

see the results i-ncfuded in the RrA and which are discussed

previously in this preambJ-e.

4. Effects on the National- Economy

UMRA requires that we estimate the effect of this

proposed rule on the national economy. To the extent

feasible, w€ must estimate the effect on productivity,

economic growth, full employment, creation of productive

jobs, and international competitiveness of the U.S. goods

and services, if we determine that accurate estimates are

reasonably feasible and that such effect is rel_evant and

materiaf.

The nationwide economic impact of thls proposed rule
Page 726 of 935

percent of the appropriate emissions limitation, or

(2) For me.rcury, emissions l-ess than 10 percent of the

mercury emissions l-¡-m:-tation or l-ess than 22.0 pounds per

year. OnJ-y exi-sting affected units may qualify for LEE

status for Hg. When qualifying for LEE status for Hg

I emissions l-ess than 22.0 pounds per year, the

I

I

affected unj-t must also demonstrate compliance with the

appJ-icable emission l_imitation.

(3) The fol-l-owing provisions appJ_y in demonstrating that a

unit qualifíes as a LEE. For all- poJ-lutants or surrogates

except for Hg, conduct the initial_ performance tests as

described in s63.10007 but note that the required minimum

sampJ-ing vol-ume must be increased nomlnally by a factor of

two; fol-l-ow the instructions in Table 5 to this subpart to

convert the test data to the units of the appJ_icable

standard. For Hg, you must conduct a 28 to 30 operating

day performance test, using Method 308 in appendix A-B to

part 60 of this chapter, to determine Hg concentration.

Locate the Method 308 sampring probe tip at a point within

the 10 percent centroidal area of the duct at a l-ocation

that meets Method 1 in appendix A-B to part 60 of this

chapter and conduct at l-east three nominarl-y equal length

test runs over the 28 to 30 day test period. you may not
specified in S63.9984

outlet of the EGU.

(1) fnstal-1, operate, and maintain the CEMS

the applicable procedures under Performance

Page 756 of 935

The HCl shal-l- be monitored at the

according to

Specification

(PS) 15 or 6 of 40 CFR part 60, Appendix B; and according

to the applicabÌe procedures under Quality Assurance

Procedure 1 of 40 CFR part 60, Appendix F; and according to

the site-specific monitorj-ng pJ-an developed according to

s63.10000 (d) .

(2) Conduct a performance

to the requirements j-n 563.

40 CFR part 60, Appendix B.

(3) Design and operate the

evaluation of the

B and according to

CEMS according

PS15or6of

CEMS to complete a mj-nimum of

one cycle of operation (sampling, analyzing, and data

recording) for each successive 15-minute period.

(4) Reduce the CEMS data as specified in 563.8 (g) (2) and

(4).

(5) Consistent with S63.10020, calculate and record a 30

boil-er operating day roJ-ling average emissions rate on a

daily basis. Daily, calcul-ate a new 30 boiler operating

day rolling average emissions rate as the average of all- of

the hourly HCl emissions data for the preceding 30 boiler

operating days.
Paqe 757 of 935

(d) If you use a HF CEMS, install, operate, and maintain a

CEMS for HF accordlng to the procedures in paragraphs

(d) (1) through ('5) of this section by the compliance date

specified in 563.9984. The HF shal-l_ be monitored at the

outlet of the EGU.

(1) Install, operate, and maintain the CEMS according to

the applicable procedures under Performance specification

(PS) 15 of 40 CFR part 60, Appendix B; and according to the

applicable procedures under Quality Assurance procedure 1

of 40 CFR part 60, Appendix F; and according to the sitespecific monitoring pJ-an developed according to

s63. 10000 (d) .

(2) conduct a performance evafuation of the CEMS accordj-ng

l ao the requirements in 563.8 and according to pS 15 or 6 of I-40 CFR part 60, Appendix B.

(3) Design and operate the CEMS to complete a minimum of

one cycle of operation (samptinj, analyzing, and data

recording) for each successive 1S-minute period.

(4) Reduce the CEMS data as specified in 563.8 (g) (2) and

(4).

(5) Consistent with 563.70020, cal_culate and record a 30

boiler operatJ-ng day rolling average emissions rate on a

daily basis. Daily, calculate a new 30 boil_er operating
Page 788 of 935

Specificati-ons 6 or 15 in Appendix B of 40 CFR part 60, and

procedure 2 in Appendix F of 40 CFR part 60.

(fi) Quarterly accuracy determinations and daily

calibration drift tests shall be performed in accordance

with procedure 1 in Appendix F of 40 CFR part 60.

(13) The ov/ner or operator of an affected source using a

CEMS measuring soz emissions to meet requirements of this

subpart shall instal-I, certify, operate, and maintain the

CEMS as specj-fied in paragraphs (a) (13) (f ) through (j_ii) of

this section.

(i) The oh¡ner or operator shall_ conduct a performance

evafuation of the CEMS according to the applicable

requirements of 560.13 of 40 CFR part 60, performance

Specification 2 or 6 in Appendix B of 40 CFR part 60, and

procedure 1 in Appendix F of 40 CFR part 60.

(ff) Quarterl-y accuracy determinations and daily

cafibration drift tests shal-1 be performed in accordance

with procedure 1 in Appendix F of 40 CFR part 60.

(14) The o\^/ner or operator of an affected source using a

CEMS measurinq Hg emissions to meet requirements of this

subpart shall instafl-, certify, operate, and maintain the

CBMS as specif ied in paragraphs (a) (14 ) (i ) through (i j_i ) of

this section.
Page 833 of 935

work practice, or operational standard, or combination

thereof, which is promulgated pursuant to CAA section

172 (h) .

TabJ.es to Subpart UUUUU of Part 63

Table 1 to Subpart IIIIIIIIU of Part 63 - Emission Li-mits for

New or Reconstructed EGUs

As stated in 563.999I, you must comply with the following

applicable emission l-imits :

If your EGU For the

is in this following

subcategory poJ-lutants

,You must meet the

lfollowing

emission ].i-mits

and work practice

rstandards

, 0.050 lb per

ìMVüh.

OR

0.000040 lb per

MWh.

,OR

0.000080 IblGI/üh

0.00020 Iblcwh

0.000030 Iblc[/üh

0.00040 lblct/rh

0.e-+020 rblcwh

0.00080 IblcI/üh

0.00090 Iblcvüh

0.0040 rblcwh

Using these

,requiraments,

as

appropriate,

(e. g. ,

specified

sampJ.ing

volr¡¡re or 'test run

duration)

with the teEt

methods in

Tat¡Ie 5...

Col-Iect a

rminimum of 4

dscm per run

Collect a

minimum of 4

dscm per run

Collect a

minimum of 4

dscm per run

l. Coal--

fired unit

designed for

coalBtu/]b.

a. Total

particulate

matter (PM)

OR

Total- non-Hg

HAP metal-s

OR

Individual HAP

metals:

Antimony (Sb)

Arsenic (As )

Beryllium (Be)

Cadmlum (Cd)

Chromium (Cr)

Cobal-t (Co)

Lead (Pb)

Manganese (Mn)
Page 834 of 935

Nickel (Nf )

Selenium (Se)

b. Hydrogen

chl-oride (HCI )

OR

Sulfur dioxide

(soz ) 

203

c. Mercury

(Hq)

a. Total

particulate

matter (PM)

OR

Total- non-Hg

HAP metals

OR

Individual HAP

metafs:

Antimony (Sb)

Arsenic (As )

Beryllium (Be)

Cadmium (Cd)

Chromium (Cr)

Cobal-t (Co)

Lead (Pb)

Manganese (Mn)

Nickel (Ni )

Sei-enium (Se )

b. Hydrogen

chloride (HCl)

0.0040 \blGWh

0.030 lblcwh

0.30 Ib per cVüh. iFor Method

26A, collect

'a minimum of

4 dscm per

Run

,soz cEMS

Hg CEMS or

Sorbent trap

monitorinçl

:system

Col-1ect a

minimum of 4

,dscm per run

Coll-ect a

minimum of 4

dscm per run

rColl-ect a

minimum of 4

dscm per run

For Method

26A, col-l-ect

a minimum of

4 dscm per

Run

be used if

0. 40 ]b

0. 000010

GWh.

per Müüh.

lb per

2. Coalfired unit

designed for

coalBtu/fb

0.050 ]b

MWh.

OR

0.000040

MVüh.

OR

per

lb per

0. 000080 Iblci/üh

0.00020 l_b/cwh

0. 000030 Iblci/üh

0.00040 lblGWh

0.€-+020 lblcvüh

0.00080 \blcwh

0. 00090 lblGVüh

0.0040 lblcvüh

0.0040 lblGVùh

0.030 lblcwh

0.30 1b per ci/üh.

203 The alternate sulfur dioxide limit may not

your EGU does not have some form of flue gas

desulfurization system install_ed.
Page 835 of 935

OR

Sulfur dioxide ', 0.40 Ib per MWh. SOz CBMS

(soz) 20n

c. Mercury 0.040 Ib per Hg CEMS or (Hq) GI/üh. Sorbent trap

.monitoring

system

3. fGCC a. Particul-ate,0.050 1b per Coll_ect a

unit matter (PM) :MVüh. mj_nimum of 4

dscm per run

OR ,OR

Total- non-Hg 0.000040 lb per Collect a

HAP metals MWh. minimum of 4

dscm per run

OR

Individual- HAP Col_l_ect a

metals: minimum of 4

Antimony (Sb) 0.000080 lblcwh dscm per run

Arsenj-c (As) ' 0.00020 lblctlüh

Beryllium (Be) 0.000030 rblcVüh

Cadmium (Cd) 0.00040 lblcVüh

Chromium (Cr) 0 . e€4-020 tblcVüh

Cobalt (Co) O.00080 Iblci/üh

Lead (Pb) 0.00090 lblcvüh

Manganese (Mn) 0.0040 lblcwh

Nickel (Ni) 0.0040 lblcr/üh

'Sel-enium (Se) 0.030 lblcl/üh

b. Hydrogen 0.30 1b per cVüh. For Method

chloride (HC]) 26A, col_lect

a minimum of

,4 dscm per

rRun

OR

Sul-fur dioxide 0.40 lb per MVrth. SOz CEMS

(Soz ) 'ot

c. Mercury 0.000010 lb per Hg CEMS or

204 The alternate sul-fur dioxide limit may not be used i-f

your EGU does not have some form of flue gas

desuffurization system install_ed. 20s The alternate suffur dioxide limit may not be used if

your BGU does not have some form of flue gas

desulfurization system instal_l_ed.

OR
Page 841 of 935

3. IGCC unit l

ra. Total- jparticulate

lmatter (PM)

l

ion ¡

jrotat non-Hg

]HAP metals

lon

jtndividual HAp

lmetals:

jAntimony (Sb)

I

iArsenj-c (As )

¡

,Beryllium (Be )

iCadmium (Cd)

iChromium (Cr)

iColoalt 1Co)

ì

ilead (Pb)

)

iManganese (Mn)

:

;Nickel (Ni )

iselenium (Se)

0.050 lblMMBru

0. 30 IblMVüh

ioR

5.0 lblTBtu or

0.050 1blcvùh

jon

OI

or

ng

ora

of

er

a

of

ô7VI

i

I

I

I

I

I

I

I

I

¡

I

I

i

I

I

I

i

I

I

I

i

I

i

i

I

I

i

I

I

I

I

I

i

I

I

i

i

I

0.40 lblTBtu or

0.0040 rblGI/üh

2.0 lblTBtu or

0.020 lblcvth

0.030 l-blTBtu or

0.0030 rblGI/üh

0.20 lblTBtu or

0.0020 Iblcvrh

3.0 lblTBtu or

0 .020 lblcvüh

æ2.0 lblTBtu or

0.0040 \blcvüh

2e-+0. q!!¿ lblMMBtu

or

æ0.003 lblMwh

3.0 \blTBtu or

0.020 lblcwh

5. 0 l-blTBtu or

0.050 Iblcwh

22.0 IblTBtu or

0.20 Iblcvüh

;b. Hydrogen

ichloride (HC1)

0.00050 lblMl¿Btu or

0.0030 IblMwh

For Method

!,26A,

lcoll-ect a
)

t

iBeryllium (Be)

I

lCadmium (Cd)

I

lChromj-um (Cr)

,Cobalt (Co)

I

,Lead (Pb)

I

I

iManganese (Mn)

i

iNickel (Ni )

,Selenium (Se )

b. Hydrogen

chloride (HC])

;OR

Sulfur dioxide

(Soz ) 1es

,c. Mercury

i(Hg)

Page 844 of 935

0.0040 lblcwh

0.070 \blTBtu or

0.00070 lblGWh

0.40 l-blTBLu or

0.0040 lblcl/üh

2.0 lblTBtu or

0. 020 rblGI/rh

2.0 l-blTBtu or

0. 020 IblGI/üh

1-1-.0 lblTBtu or

a.020 1blcvüh

3. 0 l-blTBtu or

0.040 lblcvüh

9. 0 lblTBtu or

0.090 \blcvüh

2.0 IblTBtu

0.020 lblcl/üh

0.0050 lblMMetu or

0.€+080 lblcwh

0.40 lblMMBtu

5. 0 lblMvüh

iFor Method

i26A,

lcollect a

lminimum of

lr dscm per

irun; for

itø"thod 26,

icoll-ect a

lminimum of

l

i60 liters

lper run

I

I

iSOz CEMS

i

iLsn

lTesting

ifor 28-30

lOays with

i10 davs

I

lmaxamum I

iner run or

lHg CEMS or

iSorbent

itrao

imonitoring

isystem

or

0.2A lblTBtu or

0.0020 lblcvüh
Page 851 of 935

art 60,

ppendix A-7

f this

chapter, or

cafculate

using mass

r-ssl_ons

rate and

l-ectricalutput data.

C] and/or

F CEMS

a. Install,

perate, and

intain the CEMS

S15or6at

0 CFR part

0, Appendix

B of this

hapter and

Procedure

1 at 40 CFR

art 60,

ppendix F of

his chapter

. Install, operate,

nd maintain the

il-uents 9âs, ffow

rate, and/or

isture monitoring

systems

Section 4.1.3

nd 5.3 of

endix A of

this subpart

c. Convert hourly

mi s sions

oncentrati-ons to 30

oil-er operating day

rolling average lb

r MMBtu emissions

ates or fblMWh

missions rates.

thod 19 Ffactor

thodology

t 40 CFR

art 60,

pendix A-7

f this

hapter, or

al-cul-ate

sing mass

lssl_ons

ate and

Iectrical

utput data

Mercury Emissions . Sel-ect sampling ethod 1 at
Page 865 of 935

Table 9 to Subpart, UUI(IU of part 63 - Reporting

Requirements

As stated in s63.10031, you must compty with the foJ-lowing

requirements for reports:

compliance with the appJ-icable

emissi-on limit according to

S63.10011(c) or (d) as applicable; and

b. Keeping monthly records of fuel

use accordi-ng to S63. 10021 (a) .

1 . Fil-terabf e PM as

measured through PM

CEMS

a. ColJ-ecting the PM concentration

data using a PM CEMS instalJ-ed,

operated and maintained in accordance

with PS 11 at 40 CFR part 60, Appendix

B of this chapter and QA Procedure 5

at 40 CFR part 60, Appendix F of this

chapter;

b. Converting hourly emissions

concentrations to 30 boj. LeT.' oper:at.inq

mg/dscm val Lres

emr ssíens raÈes usinq MeÈhed 1o F

¡\ppendì x A-7 ef Èhi ealeulaÈe usinq mass emissiens raËe

; and

i-ss-i-errs

i-nq

19 F faeËer meÈhedoloqy at 40 eFR pa-Ë

ealeulaÈe usinq mass emissíens raÈe

æ eutput eata; ane