[Code of Federal Regulations]
[Title 40, Volume 14]
[Revised as of July 1, 2003]
From the U.S. Government Printing Office via GPO Access
[CITE: 40CFR76.15]
[Page 458-463]
TITLE 40--PROTECTION OF ENVIRONMENT
CHAPTER I--ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)
PART 76--ACID RAIN NITROGEN OXIDES EMISSION REDUCTION PROGRAM--Table of Contents
Sec. 76.15 Test methods and procedures.
(a) The owner or operator may use the following tests as a basis for
the report required by Sec. 76.10(e)(7):
(1) Conduct an ultimate analysis of coal using ASTM D 3176-89
(incorporated by reference as specified in Sec. 76.4);
(2) Conduct a proximate analysis of coal using ASTM D 3172-89
(incorporated by reference as specified in Sec. 76.4); and
(3) Measure the coal mass flow rate to each individual burner using
ASME Power Test Code 4.2 (1991), ``Test Code for Coal Pulverizers'' or
ISO 9931 (1991), ``Coal--Sampling of Pulverized Coal Conveyed by Gases
in Direct Fired Coal Systems'' (incorporated by reference as specified
in Sec. 76.4).
(b) The owner or operator may measure and record the actual
NOX emission rate in accordance with the requirements of this
part while varying the following parameters where possible to determine
their effects on the emissions of NOX from the affected
boiler:
(1) Excess air levels;
(2) Settings of burners or coal and air nozzles, including tilt and
yaw, or swirl;
(3) For tangentially fired boilers, distribution of combustion air
within the NOX emission control system;
(4) Coal mass flow rates to each individual burner;
(5) Coal-to-primary air ratio (based on pound per hour) for each
burner, the average coal-to-primary air ratio for all burners, and the
deviations of individual burners' coal-to-primary air ratios from the
average value; and
(6) If the boiler uses varying types of coal, the type of coal.
Provide the results of proximate and ultimate analyses of each type of
as-fired coal.
(c) In performing the tests specified in paragraph (a) of this
section, the owner or operator shall begin the tests using the equipment
settings for which the NOX emission control system was
designed to meet the NOX emission rate guaranteed by the
primary NOX emission control system vendor. These results
constitute the ``baseline controlled'' condition.
(d) After establishing the baseline controlled condition under
paragraph (c) of this section, the owner or operator may:
(1) Change excess air levels 5 percent from the
baseline controlled condition to determine the effects on emissions of
NOX, by providing a minimum of three readings (e.g., with a
baseline reading of 20 percent excess air, excess air levels will be
changed to 19 percent and 21 percent);
[[Page 459]]
(2) For tangentially fired boilers, change the distribution of
combustion air within the NOX emission control system to
determine the effects on NOX emissions by providing a minimum
of three readings, one with the minimum, one with the baseline, and one
with the maximum amounts of staged combustion air; and
(3) Show that the combustion process within the boiler is optimized
(e.g., that the burners are balanced).
Appendix A to Part 76--Phase I Affected Coal-Fired Utility Units With
Group 1 or Cell Burner Boilers
Table 1--Phase I Tangentially Fired Units
----------------------------------------------------------------------------------------------------------------
State Plant Unit Operator
----------------------------------------------------------------------------------------------------------------
ALABAMA...................... EC GASTON.................... 5 ALABAMA POWER CO.
GEORGIA...................... BOWEN........................ 1BLR GEORGIA POWER CO.
GEORGIA...................... BOWEN........................ 2BLR GEORGIA POWER CO.
GEORGIA...................... BOWEN........................ 3BLR GEORGIA POWER CO.
GEORGIA...................... BOWEN........................ 4BLR GEORGIA POWER CO.
GEORGIA...................... JACK MCDONOUGH............... MB1 GEORGIA POWER CO.
GEORGIA...................... JACK MCDONOUGH............... MB2 GEORGIA POWER CO.
GEORGIA...................... WANSLEY...................... 1 GEORGIA POWER CO.
GEORGIA...................... WANSLEY...................... 2 GEORGIA POWER CO.
GEORGIA...................... YATES........................ Y1BR GEORGIA POWER CO.
GEORGIA...................... YATES........................ Y2BR GEORGIA POWER CO.
GEORGIA...................... YATES........................ Y3BR GEORGIA POWER CO.
GEORGIA...................... YATES........................ Y4BR GEORGIA POWER CO.
GEORGIA...................... YATES........................ Y5BR GEORGIA POWER CO.
GEORGIA...................... YATES........................ Y6BR GEORGIA POWER CO.
GEORGIA...................... YATES........................ Y7BR GEORGIA POWER CO.
ILLINOIS..................... BALDWIN...................... 3 ILLINOIS POWER CO.
ILLINOIS..................... HENNEPIN..................... 2 ILLINOIS POWER CO.
ILLINOIS..................... JOPPA........................ 1 ELECTRIC ENERGY INC.
ILLINOIS..................... JOPPA........................ 2 ELECTRIC ENERGY INC.
ILLINOIS..................... JOPPA........................ 3 ELECTRIC ENERGY INC.
ILLINOIS..................... JOPPA........................ 4 ELECTRIC ENERGY INC.
ILLINOIS..................... JOPPA........................ 5 ELECTRIC ENERGY INC.
ILLINOIS..................... JOPPA........................ 6 ELECTRIC ENERGY INC.
ILLINOIS..................... MEREDOSIA.................... 5 CEN ILLINOIS PUB SER.
ILLINOIS..................... VERMILION.................... 2 ILLINOIS POWER CO.
INDIANA...................... CAYUGA....................... 1 PSI ENERGY INC.
INDIANA...................... CAYUGA....................... 2 PSI ENERGY INC.
INDIANA...................... EW STOUT..................... 50 INDIANAPOLIS PWR & LT.
INDIANA...................... EW STOUT..................... 60 INDIANAPOLIS PWR & LT.
INDIANA...................... EW STOUT..................... 70 INDIANAPOLIS PRW & LT.
INDIANA...................... HT PRITCHARD................. 6 INDIANAPOLIS PWR & LT.
INDIANA...................... PETERSBURG................... 1 INDIANAPOLIS PWR & LT.
INDIANA...................... PETERSBURG................... 2 INDIANAPOLIS PWR & LT.
INDIANA...................... WABASH RIVER................. 6 PSI ENERGY INC.
IOWA......................... BURLINGTON................... 1 IOWA SOUTHERN UTL.
IOWA......................... ML KAPP...................... 2 INTERSTATE POWER CO.
IOWA......................... RIVERSIDE.................... 9 IOWA-ILL GAS & ELEC.
KENTUCKY..................... ELMER SMITH.................. 2 OWENSBORO MUN UTIL.
KENTUCKY..................... EW BROWN..................... 2 KENTUCKY UTL CO.
KENTUCKY..................... EW BROWN..................... 3 KENTUCKY UTL CO.
KENTUCKY..................... GHENT........................ 1 KENTUCKY UTL CO.
MARYLAND..................... MORGANTOWN................... 1 POTOMAC ELEC PWR CO.
MARYLAND..................... MORGANTOWN................... 2 POTOMAC ELEC PWR CO.
MICHIGAN..................... JH CAMPBELL.................. 1 CONSUMERS POWER CO.
MISSOURI..................... LABADIE...................... 1 UNION ELECTRIC CO.
MISSOURI..................... LABADIE...................... 2 UNION ELECTRIC CO.
MISSOURI..................... LABADIE...................... 3 UNION ELECTRIC CO.
MISSOURI..................... LABADIE...................... 4 UNION ELECTRIC CO.
MISSOURI..................... MONTROSE..................... 1 KANSAS CITY PWR & LT.
MISSOURI..................... MONTROSE..................... 2 KANSAS CITY PWR & LT.
MISSOURI..................... MONTROSE..................... 3 KANSAS CITY PWR & LT.
NEW YORK..................... DUNKIRK...................... 3 NIAGARA MOHAWK PWR.
NEW YORK..................... DUNKIRK...................... 4 NIAGARA MOHAWK PWR.
NEW YORK..................... GREENIDGE.................... 6 NY STATE ELEC & GAS.
NEW YORK..................... MILLIKEN..................... 1 NY STATE ELEC & GAS.
NEW YORK..................... MILLIKEN..................... 2 NY STATE ELEC & GAS.
OHIO......................... ASHTABULA.................... 7 CLEVELAND ELEC ILLUM.
[[Page 460]]
OHIO......................... AVON LAKE.................... 11 CLEVELAND ELEC ILLUM.
OHIO......................... CONESVILLE................... 4 COLUMBUS STHERN PWR.
OHIO......................... EASTLAKE..................... 1 CLEVELAND ELEC ILLUM.
OHIO......................... EASTLAKE..................... 2 CLEVELAND ELEC ILLUM.
OHIO......................... EASTLAKE..................... 3 CLEVELAND ELEC ILLUM.
OHIO......................... EASTLAKE..................... 4 CLEVELAND ELEC ILLUM.
OHIO......................... MIAMI FORT................... 6 CINCINNATI GAS & ELEC.
OHIO......................... WC BECKJORD.................. 5 CINCINNATI GAS & ELEC.
OHIO......................... WC BECKJORD.................. 6 CINCINNATI GAS & ELEC.
PENNSYLVANIA................. BRUNNER ISLAND............... 1 PENNSYLVANIA PWR & LT.
PENNSYLVANIA................. BRUNNER ISLAND............... 2 PENNSYLVANIA PWR & LT.
PENNSYLVANIA................. BRUNNER ISLAND............... 3 PENNSYLVANIA PWR & LT.
PENNSYLVANIA................. CHESWICK..................... 1 DUQUESNE LIGHT CO.
PENNSYLVANIA................. CONEMAUGH.................... 1 PENNSYLVANIA ELEC CO.
PENNSYLVANIA................. CONEMAUGH.................... 2 PENNSYLVANIA ELEC CO.
PENNSYLVANIA................. PORTLAND..................... 1 METROPOLITAN EDISON.
PENNSYLVANIA................. PORTLAND..................... 2 METROPOLITAN EDISON.
PENNSYLVANIA................. SHAWVILLE.................... 3 PENNSYLVANIA ELEC CO.
PENNSYLVANIA................. SHAWVILLE.................... 4 PENNSYLVANIA ELEC CO.
TENNESSEE.................... GALLATIN..................... 1 TENNESSEE VAL AUTH.
TENNESSEE.................... GALLATIN..................... 2 TENNESSEE VAL AUTH.
TENNESSEE.................... GALLATIN..................... 3 TENNESSEE VAL AUTH.
TENNESSEE.................... GALLATIN..................... 4 TENNESSEE VAL AUTH.
TENNESSEE.................... JOHNSONVILLE................. 1 TENNESSEE VAL AUTH.
TENNESSEE.................... JOHNSONVILLE................. 2 TENNESSEE VAL AUTH.
TENNESSEE.................... JOHNSONVILLE................. 3 TENNESSEE VAL AUTH.
TENNESSEE.................... JOHNSONVILLE................. 4 TENNESSEE VAL AUTH.
TENNESSEE.................... JOHNSONVILLE................. 5 TENNESSEE VAL AUTH.
TENNESSEE.................... JOHNSONVILLE................. 6 TENNESSEE VAL AUTH.
WEST VIRGINIA................ ALBRIGHT..................... 3 MONONGAHELA POWER CO.
WEST VIRGINIA................ FORT MARTIN.................. 1 MONONGAHELA POWER CO.
WEST VIRGINIA................ MOUNT STORM.................. 1 VIRGINIA ELEC & PWR.
WEST VIRGINIA................ MOUNT STORM.................. 2 VIRGINIA ELEC & PWR.
WEST VIRGINIA................ MOUNT STORM.................. 3 VIRGINIA ELEC & PWR.
WISCONSIN.................... GENOA........................ 1 DAIRYLAND POWER COOP.
WISCONSIN.................... SOUTH OAK CREEK.............. 7 WISCONSIN ELEC POWER.
WISCONSIN.................... SOUTH OAK CREEK.............. 8 WISCONSIN ELEC POWER.
----------------------------------------------------------------------------------------------------------------
Table 2--Phase I Dry Bottom-Fired Units
----------------------------------------------------------------------------------------------------------------
State Plant Unit Operator
----------------------------------------------------------------------------------------------------------------
ALABAMA....................... COLBERT....................... 1 TENNESSEE VAL AUTH.
ALABAMA....................... COLBERT....................... 2 TENNESSEE VAL AUTH.
ALABAMA....................... COLBERT....................... 3 TENNESSEE VAL AUTH.
ALABAMA....................... COLBERT....................... 4 TENNESSEE VAL AUTH.
ALABAMA....................... COLBERT....................... 5 TENNESSEE VAL AUTH.
ALABAMA....................... EC GASTON..................... 1 ALABAMA POWER CO.
ALABAMA....................... EC GASTON..................... 2 ALABAMA POWER CO.
ALABAMA....................... EC GASTON..................... 3 ALABAMA POWER CO.
ALABAMA....................... EC GASTON..................... 4 ALABAMA POWER CO.
FLORIDA....................... CRIST......................... 6 GULF POWER CO.
FLORIDA....................... CRIST......................... 7 GULF POWER CO.
GEORGIA....................... HAMMOND....................... 1 GEORGIA POWER CO.
GEORGIA....................... HAMMOND....................... 2 GEORGIA POWER CO.
GEORGIA....................... HAMMOND....................... 3 GEORGIA POWER CO.
GEORGIA....................... HAMMOND....................... 4 GEORGIA POWER CO.
ILLINOIS...................... GRAND TOWER................... 9 CEN ILLINOIS PUB SER.
INDIANA....................... CULLEY........................ 2 STHERN IND GAS & EL.
INDIANA....................... CULLEY........................ 3 STHERN IND GAS & EL.
INDIANA....................... GIBSON........................ 1 PSI ENERGY INC.
INDIANA....................... GIBSON........................ 2 PSI ENERGY INC.
INDIANA....................... GIBSON........................ 3 PSI ENERGY INC.
INDIANA....................... GIBSON........................ 4 PSI ENERGY INC.
INDIANA....................... RA GALLAGHER.................. 1 PSI ENERGY INC.
INDIANA....................... RA GALLAGHER.................. 2 PSI ENERGY INC.
INDIANA....................... RA GALLAGHER.................. 3 PSI ENERGY INC.
INDIANA....................... RA GALLAGHER.................. 4 PSI ENERGY INC.
INDIANA....................... FRANK E RATTS................. 1SG1 HOOSIER ENERGY REC.
INDIANA....................... FRANK E RATTS................. 2SG1 HOOSIER ENERGY REC.
INDIANA....................... WABASH RIVER.................. 1 PSI ENERGY INC.
[[Page 461]]
INDIANA....................... WABASH RIVER.................. 2 PSI ENERGY INC.
INDIANA....................... WABASH RIVER.................. 3 PSI ENERGY INC.
INDIANA....................... WABASH RIVER.................. 5 PSI ENERGY INC.
IOWA.......................... DES MOINES.................... 11 IOWA PWR & LT CO.
IOWA.......................... PRAIRIE CREEK................. 4 IOWA ELEC LT & PWR.
KANSAS........................ QUINDARO...................... 2 KS CITY BD PUB UTIL.
KENTUCKY...................... COLEMAN....................... C1 BIG RIVERS ELEC CORP.
KENTUCKY...................... COLEMAN....................... C2 BIG RIVERS ELEC CORP.
KENTUCKY...................... COLEMAN....................... C3 BIG RIVERS ELEC CORP.
KENTUCKY...................... EW BROWN...................... 1 KENTUCKY UTL CO.
KENTUCKY...................... GREEN RIVER................... 5 KENTUCKY UTL CO.
KENTUCKY...................... HMP&L STATION 2............... H1 BIG RIVERS ELEC CORP.
KENTUCKY...................... HMP&L STATION 2............... H2 BIG RIVERS ELEC CORP.
KENTUCKY...................... HL SPURLOCK................... 1 EAST KY PWR COOP.
KENTUCKY...................... JS COOPER..................... 1 EAST KY PWR COOP.
KENTUCKY...................... JS COOPER..................... 2 EAST KY PWR COOP.
MARYLAND...................... CHALK POINT................... 1 POTOMAC ELEC PWR CO.
MARYLAND...................... CHALK POINT................... 2 POTOMAC ELEC PWR CO.
MINNESOTA..................... HIGH BRIDGE................... 6 NORTHERN STATES PWR.
MISSISSIPPI................... JACK WATSON................... 4 MISSISSIPPI PWR CO.
MISSISSIPPI................... JACK WATSON................... 5 MISSISSIPPI PWR CO.
MISSOURI...................... JAMES RIVER................... 5 SPRINGFIELD UTL.
OHIO.......................... CONESVILLE.................... 3 COLUMBUS STHERN PWR.
OHIO.......................... EDGEWATER..................... 13 OHIO EDISON CO.
OHIO.......................... MIAMI FORT \1\................ 5-1 CINCINNATI GAS&ELEC.
OHIO.......................... MIAMI FORT \1\................ 5-2 CINCINNATI GAS&ELEC.
OHIO.......................... PICWAY........................ 9 COLUMBUS STHERN PWR.
OHIO.......................... RE BURGER..................... 7 OHIO EDISON CO.
OHIO.......................... RE BURGER..................... 8 OHIO EDISON CO.
OHIO.......................... WH SAMMIS..................... 5 OHIO EDISON CO.
OHIO.......................... WH SAMMIS..................... 6 OHIO EDISON CO.
PENNSYLVANIA.................. ARMSTRONG..................... 1 WEST PENN POWER CO.
PENNSYLVANIA.................. ARMSTRONG..................... 2 WEST PENN POWER CO.
PENNSYLVANIA.................. MARTINS CREEK................. 1 PENNSYLVANIA PWR & LT.
PENNSYLVANIA.................. MARTINS CREEK................. 2 PENNSYLVANIA PWR & LT.
PENNSYLVANIA.................. SHAWVILLE..................... 1 PENNSYLVANIA ELEC CO.
PENNSYLVANIA.................. SHAWVILLE..................... 2 PENNSYLVANIA ELEC CO.
PENNSYLVANIA.................. SUNBURY....................... 3 PENNSYLVANIA PWR & LT.
PENNSYLVANIA.................. SUNBURY....................... 4 PENNSYLVANIA PWR & LT.
TENNESSEE..................... JOHNSONVILLE.................. 7 TENNESSEE VAL AUTH.
TENNESSEE..................... JOHNSONVILLE.................. 8 TENNESSEE VAL AUTH.
TENNESSEE..................... JOHNSONVILLE.................. 9 TENNESSEE VAL AUTH.
TENNESSEE..................... JOHNSONVILLE.................. 10 TENNESSEE VAL AUTH.
WEST VIRGINIA................. HARRISON...................... 1 MONONGAHELA POWER CO.
WEST VIRGINIA................. HARRISON...................... 2 MONONGAHELA POWER CO.
WEST VIRGINIA................. HARRISON...................... 3 MONONGAHELA POWER CO.
WEST VIRGINIA................. MITCHELL...................... 1 OHIO POWER CO.
WEST VIRGINIA................. MITCHELL...................... 2 OHIO POWER CO.
WISCONSIN..................... JP PULLIAM.................... 8 WISCONSIN PUB SER CO.
WISCONSIN..................... NORTH OAK CREEK \2\........... 1 WISCONSIN ELEC PWR.
WISCONSIN..................... NORTH OAK CREEK \2\........... 2 WISCONSIN ELEC PWR.
WISCONSIN..................... NORTH OAK CREEK \2\........... 3 WISCONSIN ELEC PWR.
WISCONSIN..................... NORTH OAK CREEK \2\........... 4 WISCONSIN ELEC PWR.
WISCONSIN..................... SOUTH OAK CREEK \2\........... 5 WISCONSIN ELEC PWR.
WISCONSIN..................... SOUTH OAK CREEK \2\........... 6 WISCONSIN ELEC PWR.
----------------------------------------------------------------------------------------------------------------
\1\ Vertically fired boiler.
\2\ Arch-fired boiler.
Table 3--Phase I Cell Burner Technology Units
----------------------------------------------------------------------------------------------------------------
State Plant Unit Operator
----------------------------------------------------------------------------------------------------------------
INDIANA....................... WARRICK....................... 4 STHERN IND GAS & EL.
MICHIGAN...................... JH CAMPBELL................... 2 CONSUMERS POWER CO.
OHIO.......................... AVON LAKE..................... 12 CLEVELAND ELEC ILLUM.
OHIO.......................... CARDINAL...................... 1 CARDINAL OPERATING.
OHIO.......................... CARDINAL...................... 2 CARDINAL OPERATING.
OHIO.......................... EASTLAKE...................... 5 CLEVELAND ELEC ILLUM.
OHIO.......................... GENRL JM GAVIN................ 1 OHIO POWER CO.
OHIO.......................... GENRL JM GAVIN................ 2 OHIO POWER CO.
OHIO.......................... MIAMI FORT.................... 7 CINCINNATI GAS & EL.
[[Page 462]]
OHIO.......................... MUSKINGUM RIVER............... 5 OHIO POWER CO.
OHIO.......................... WH SAMMIS..................... 7 OHIO EDISON CO.
PENNSYLVANIA.................. HATFIELDS FERRY............... 1 WEST PENN POWER CO.
PENNSYLVANIA.................. HATFIELDS FERRY............... 2 WEST PENN POWER CO.
PENNSYLVANIA.................. HATFIELDS FERRY............... 3 WEST PENN POWER CO.
TENNESSEE..................... CUMBERLAND.................... 1 TENNESSEE VAL AUTH.
TENNESSEE..................... CUMBERLAND.................... 2 TENNESSEE VAL AUTH.
WEST VIRGINIA................. FORT MARTIN................... 2 MONONGAHELA POWER CO.
----------------------------------------------------------------------------------------------------------------
Appendix B to Part 76--Procedures and Methods for Estimating Costs of
Nitrogen Oxides Controls Applied to Group 1, Boilers
1. Purpose and Applicability
This technical appendix specifies the procedures, methods, and data
that the Administrator will use in establishing ``***the degree of
reduction achievable through this retrofit application of the best
system of continuous emission reduction, taking into account available
technology, costs, and energy and environmental impacts; and which is
comparable to the costs of nitrogen oxides controls set pursuant to
subsection (b)(1) (of section 407 of the Act).'' In developing the
allowable NOX emissions limitations for Group 2 boilers
pursuant to subsection (b)(2) of section 407 of the Act, the
Administrator will consider only those systems of continuous emission
reduction that, when applied on a retrofit basis, are comparable in cost
to the cost in constant dollars of low NOX burner technology
applied to Group 1, Phase I boilers.
The Administrator will evaluate the capital cost (in dollars per
kilowatt electrical ($/kW)), the operating and maintenance costs (in $/
year), and the cost-effectiveness (in annualized $/ton NOX
removed) of installed low NOX burner technology controls over
a range of boiler sizes (as measured by the gross electrical capacity of
the associated generator in megawatt electrical (MW)) and utilization
rates (in percent gross nameplate capacity on an annual basis) to
develop estimates of the capital costs and cost effectiveness for Group
1, Phase I boilers. The following units will be excluded from these
determinations of the capital costs and cost effectiveness of
NOX controls set pursuant to subsection (b)(1) of section 407
of the Act: (1) Units employing an alternative technology, or overfire
air as applied to wall-fired boilers or separated overfire air as
applied to tangentially fired boilers, in lieu of low NOX
burner technology for reducing NOX emissions; (2) units
employing no controls, only controls installed before November 15, 1990,
or only modifications to boiler operating parameters (e.g., burners out
of service or fuel switching) for reducing NOX emissions; and
(3) units that have not achieved the applicable emission limitation.
2. Average Capital Cost for Low NOX Burner Technology Applied
to Group 1 Boilers
The Administrator will use the procedures, methods, and data
specified in this section to estimate the average capital cost (in $/kW)
of installed low NOX burner technology applied to Group 1
boilers.
2.1 Using cost data submitted pursuant to the reporting
requirements in section 4 below, boiler-specific actual or estimated
actual capital costs will be determined for each unit in the population
specified in section 1 above for assessing the costs of installed low
NOX burner technology. The scope of installed low
NOX burner technology costs will include the following
capital costs for retrofit application: (1) For the burner portion--
burners or air and coal nozzles, burner throat and waterwall
modifications, and windbox modifications; and, where applicable, (2) for
the combustion air staging portion--waterwall modifications or panels,
windbox modifications, and ductwork, and (3) scope adders or
supplemental equipment such as replacement or additional fans, dampers,
or ignitors necessary for the proper operation of the low NOX
burner technology. Capital costs associated with boiler restoration or
refurbishment such as replacement of air heaters, asbestos abatement,
and recasing will not be included in the cost basis for installed low
NOX burner technology. The scope of installed low
NOX burner technology retrofit capital costs will include
materials, construction and installation labor, engineering, and
overhead costs.
2.2 Using gross nameplate capacity (in MW) for each unit as
reported in the National Allowance Data Base (NADB), boiler-specific
capital costs will be converted to a $/kW basis.
2.3 Capital cost curves ($/kW versus boiler size in MW) or
equations for installed low NOX burner technology retrofit
costs will be developed for: (1) Dry bottom wall fired boilers
(excluding units applying cell burner technology) and (2) tangentially
fired boilers.
[[Page 463]]
3. [Reserved]
4. Reporting Requirements
4.1 The following information is to be submitted by each designated
representative of a Phase I affected unit subject to the reporting
requirements of Sec. 76.14(c):
4.1.1 Schedule and dates for baseline testing, installation, and
performance testing of low NOX burner technology.
4.1.2 Estimates of the annual average baseline NOX
emission rate, as specified in section 3.1.1, and the annual average
controlled NOX emission rate, as specified in section 3.1.2,
including the supporting continuous emission monitoring or other test
data.
4.1.3 Copies of pre-retrofit and post-retrofit performance test
reports.
4.1.4 Detailed estimates of the capital costs based on actual
contract bids for each component of the installed low NOX
burner technology including the items listed in section 2.1. Indicate
number of bids solicited. Provide a copy of the actual agreement for the
installed technology.
4.1.5 Detailed estimates of the capital costs of system
replacements or upgrades such as coal pipe changes, fan replacements/
upgrades, or mill replacements/upgrades undertaken as part of the low
NOX burner technology retrofit project.
4.1.6 Detailed breakdown of the actual costs of the completed low
NOX burner technology retrofit project where low
NOX burner technology costs (section 4.1.4) are
disaggregated, if feasible, from system replacement or upgrade costs
(section 4.1.5).
4.1.7 Description of the probable causes for significant
differences between actual and estimated low NOX burner
technology retrofit project costs.
4.1.8 Detailed breakdown of the burner and, if applicable,
combustion air staging system annual operating and maintenance costs for
the items listed in section 3.3 before and after the installation,
shakedown, and/or optimization of the installed low NOX
burner technology. Include estimates and a description of the probable
causes of the incremental annual operating and maintenance costs (or
savings) attributable to the installed low NOX burner
technology.
4.2 All capital cost estimates are to be broken down into materials
costs, construction and installation labor costs, and engineering and
overhead costs. All operating and maintenance costs are to be broken
down into maintenance materials costs, maintenance labor costs,
operating labor costs, and fan electricity costs. All capital and
operating costs are to be reported in dollars with the year of
expenditure or estimate specified for each component.
[60 FR 18761, Apr. 13, 1995, as amended at 61 FR 67164, Dec. 19, 1996;
62 FR 3464, Jan. 23, 1997]