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 theAct) section II2(d,) and 

### proposing 

### revised new source performance standards (NSPS)

### for fossil fuef-fired EGUsunder 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 inPage 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.

SUMMARYOF THE MONETIZED BENEFTTS, SOCIAL COSTS, AND NET BENEFTTS FOR THE PROPOSED RULE 

### rN 2016 (MTLLTONS OE2007$)' 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

0Page 150of 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 4000

### tons for HCJ-,



### . SUMMARYOF ACTPage 170of 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 EGUsand 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¡rlebel-ieve our estimate of the current l-evel- of acid HAP emissions based on the 201,0 ICR database may underestimate total- EGUacid HAP emissions dueto targeting of the 20L0 fCRon 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 ,000Page 171 of 935

183

### tpy for Mn, 387

### tpy for Nj-, and 258

### tpy for Se.8e Depending on

### the meta1, EGUsaccount 

### 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. SUMMARYOF 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 metalHAPemissions based on

### the 2010 ICR database may underestimate 

### total EGU

### metal HAP emissi_ons due

### to 

### targeting of the 201-0 fCRon

### 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 emissions 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-nwatersheds 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 higher

### Statistic Fish 

### tissue MeHg

### concentration (ppm) 2005 2076 Total U.

### S. EGU

### attributable Total 

### U.S. EGU

### attributabl-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. EGUemJ-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 EGUemissions), 

### 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 pMPaqe 2t7 of 935

to the 20L0 ICR emissions l-evel_s of anthropogenic metalsl2e, I resuJ-ts in reductions of approximately 53€-430tons 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_nthe 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 

### heldto the same emission 

### limi-tations (which 

### could be met

### through 

### fuel sampling) 

### as

### other liquid oil-fired units. EpA

### solicits
commenton 

### all of these proposed subcategorization approaches.
TABLE 10. EMISSTON LIMITATIONS FOR COAL-FIRED AND SOLTD

OTL-DERIVED FUEL-FIRED EGUS Subcategory Total

### particulate 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 312of 935



### prepare 

### for CAMR, and

### the fact that many 

### state regulations 

### currentfy require the instal-l-ation and

### operation 

### of Hg CEMS i-n

### orderto demonstrate compli-ance \^/ith

### various SIP and consent decrees. 

### (3) For new

### or reconstructed IGCC

### units or coal-fired
or sol-id

### oil--derivedfuel--fired units with SOzemissions 

### 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. Webel-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 HCI

### monitors, 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 60would 

### 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 462of 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 NAPage 463of 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 Coal

### fired 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/MVühTotalmetals 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/ühPage 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 FORTHE 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 economicjournals, 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 BPAestimate 

### for Proposed Rul-eb 

### -45,000 to +2,500 +4t100 

### to

24,000 +200

### to 32,000Page 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. SUMMARYOF THE MONETIZED BENEFITS, SOCIAL COSTS,

AND NET BENEFITS FOR THE PROPOSED RULE 

### IN 2016 (MTLLTONS OE2006$).



### " Al-I estimates 

### are for 2016, and 

### are rounded 

### to two 

### significant figures. The

### net presentvalue 

### 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 Benefits $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 consumptionPage 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 HApfrom 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.sand 

### in So2

### that would

### occur, including approximately +€€-84thousand 

### tons 

### of pMz.sand

### 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.sand PMz.s

### precursors (such 

### as SOz)

### is a reduction 

### in premature 

### mortality. other hearth 

### effects associated 

### with
PMz.semission 

### 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^reare abl-e

### to monetize

### the benefits associated

### with the pMz.s and
soz emissions 

### reducti-ons. For soz and PMz.s, r^rêestimated 

### the benefits associated wi-th 

### health effects of pM

### but h/ere unabl-e

### to quantify all categories 

### of benefits (particularlyPage 602of 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 social

### costs 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 

### requiresthat 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.
EPAassessed 

### 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€-55Page 603of 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, +€-17unj-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 

### requiresthat 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 wedetermine

### that accurate estimates are reasonably 

### feasible and

### that such 

### effect is rel_evant and 

### materiaf. The 

### nationwide economic impact 

### of thls proposed 

### rulePage 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 Hgconcentration. 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



### accordingto 

### Specification and according (PS) 15

### or 6 

### of 40 CFR 

### part 60, Appendix B; 

### 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-andeveloped 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 

### accordingtoCEMS according

PS15or6of

CEMSto 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 operatingPage 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 CEMSmeasuring 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 CEMSmeasurinq 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 833of 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 

### 1to 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 forcoal

### Btu/]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 834of 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 forcoalBtu/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 EGUdoes 

### not have someform 

### 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 CEMSor 

### (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€4-020tblcVüh 

### 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 CEMSor 204 The

### alternate sul-fur 

### dioxide limit may

### not be used 

### i-f 

### your EGUdoes 

### not have someform 

### of flue gas 

### desuffurization system install_ed. 20s The

### alternate suffur dioxide limit may 

### not be used 

### if your BGU does 

### not have someform 

### of flue gas 

### desulfurization system instal_l_ed. ORPage 841 of 935

3. IGCC 

### unit l

### ra. Total-



### jparticulate lmatter (PM)

lion

¡ 

### jrotat non-Hg ]HAP metals

lon 

### jtndividual HAp lmetals: jAntimony (Sb)

IiArsenj-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

ô7 VI i

I I

I

I

I

I

I I
¡

I I i

I
I
I
i I

I Ii

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)

IlCadmium (Cd)

I lChromj-um (Cr) 

### ,Cobalt (Co)

I,Lead (Pb)

I IiManganese (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

li60 

### liters lper run

I

IiSOz CEMS

i iLsn lTesting 

### ifor 28-30 lOays

### with i10 davs

I lmaxamum

I

### iner 

### run or lHg CEMSor iSorbent itrao imonitoring isystem or 0.2A 

### lblTBtu or 0.0020 lblcvühPage 851of 935 

### art 60, ppendix A-7 

### f this chapter, or 

### cafculate using mass r-ssl_ons 

### rate and

### l-ectrical

### utput 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 ssions oncentrati-ons 

### to 30 

### oil-er operating day rolling average lb 

### r MMBtu emissions 

### ates 

### or fblMWh 

### missions rates. 

### thod 19 F

### factor 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 atPage 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 PMconcentration



### 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

emrssíens raÈes usinq MeÈhed 1o F ¡\ppendìx A-7 ef Èhi ealeulaÈe usinq massemissiens raËe ; and i-ss-i-errs i-nq
19 F faeËer meÈhedoloqy at 40 eFR pa-Ë ealeulaÈe usinq massemissíens raÈe æ eutput eata; ane