(E) Activation and deactivation dates and hours, when the maximum
hourly gross load, boundaries of the range of

operation, or normal load level change and are updated.
    (ix) For each unit with a flow monitor installed on a rectangular
stack or duct, if a wall effects adjustment factor (WAF) is determined
and applied to the hourly flow rate data:
    (A) Stack or duct width at the test location, ft;
    (B) Stack or duct depth at the test location, ft;
    (C) Wall effects adjustment factor (WAF), to the nearest 0.0001;
    (D) Method of determining the WAF;
    (E) WAF Effective date and hour;
    (F) WAF no longer effective date and hour (if applicable);
    (G) WAF determination date;
    (H) Number of WAF test runs;
    (I) Number of Method 1 traverse points in the WAF test;
    (J) Number of test ports in the WAF test; and
    (K) Number of Method 1 traverse points in the reference flow RATA.
    (2) Hardcopy.
    (i) Information, including (as applicable): identification of the
test strategy; protocol for the relative accuracy test audit; other
relevant test information; calibration gas levels (percent of span) for
the calibration error test and linearity check; calculations for
determining maximum potential concentration, maximum expected
concentration (if applicable), maximum potential flow rate, maximum
potential NOX emission rate, and span; and apportionment
strategies under Sec. Sec.  75.10 through 75.18.
    (ii) Description of site locations for each monitoring component in
the continuous emission or opacity monitoring systems, including
schematic diagrams and engineering drawings specified in paragraphs
(e)(2)(iv) and (e)(2)(v) of this section and any other documentation
that demonstrates each monitor location meets the appropriate siting
criteria.
    (iii) A data flow diagram denoting the complete information
handling path from output signals of CEMS components to final reports.
    (iv) For units monitored by a continuous emission or opacity
monitoring system, a schematic diagram identifying entire gas handling
system from boiler to stack for all affected units, using
identification numbers for units, monitoring systems and components,
and stacks corresponding to the identification numbers provided in
paragraphs (g)(1)(i) and (g)(1)(iii) of this section. The schematic
diagram must depict stack height and the height of any monitor
locations. Comprehensive and/or separate schematic diagrams shall be
used to describe groups of units using a common stack.
    (v) For units monitored by a continuous emission or opacity
monitoring system, stack and duct engineering diagrams showing the
dimensions and location of fans, turning vanes, air preheaters, monitor
components, probes, reference method sampling ports, and other
equipment that affects the monitoring system location, performance, or
quality control checks.
    (h) Contents of monitoring plan for specific situations. The
following additional information shall be included in the monitoring
plan for the specific situations described:
    (1) For each gas-fired unit or oil-fired unit for which the owner
or operator uses the optional protocol in appendix D to this part for
estimating heat input and/or SO2 mass emissions, or for each
gas-fired or oil-fired peaking unit for which the owner/operator uses
the optional protocol in appendix E to this part for estimating
NOX emission rate (using a fuel flowmeter), the designated
representative shall include the following additional information for
each fuel flowmeter system in the monitoring plan:
    (i) Electronic.
    (A) Parameter monitored;
    (B) Type of fuel measured, maximum fuel flow rate, units of
measure, and basis of maximum fuel flow rate (i.e., upper range value
or unit maximum) for each fuel flowmeter;
    (C) Test method used to check the accuracy of each fuel flowmeter;
    (D) Monitoring system identification code;
    (E) The method used to demonstrate that the unit qualifies for
monthly GCV sampling or for daily or annual fuel sampling for sulfur
content, as applicable; and
    (F) Activation date/hour and (if applicable) inactivation date/hour
for the fuel flowmeter system;
    (ii) Hardcopy.
    (A) A schematic diagram identifying the relationship between the
unit, all fuel supply lines, the fuel flowmeter(s), and the stack(s).
The schematic diagram must depict the installation location of each
fuel flowmeter and the fuel sampling location(s). Comprehensive and/or
separate schematic diagrams shall be used to describe groups of units
using a common pipe;
    (B) For units using the optional default SO2 emission
rate for ``pipeline natural gas'' or ``natural gas'' in appendix D to
this part, the information on the sulfur content of the gaseous fuel
used to demonstrate compliance with either section <IP_ADDRESS> or <IP_ADDRESS>
of appendix D to this part;
    (C) For units using the 720 hour test under 2.3.6 of Appendix D of
this part to determine the required sulfur sampling requirements,
report the procedures and results of the test; and
    (D) For units using the 720 hour test under 2.3.5 of Appendix D of
this part to determine the appropriate fuel GCV sampling frequency,
report the procedures used and the results of the test.
    (2) For each gas-fired peaking unit and oil-fired peaking unit for
which the owner or operator uses the optional procedures in appendix E
to this part for estimating NOX emission rate, the
designated representative shall include in the monitoring plan:
    (i) Electronic. Unit operating and capacity factor information
demonstrating that the unit qualifies as a peaking unit, as defined in
Sec.  72.2 of this chapter for the current calendar year or ozone
season, including: capacity factor data for three calendar years (or
ozone seasons) as specified in the definition of peaking unit in Sec.
72.2 of this chapter; the method of qualification used; and an
indication of whether the data are actual or projected data.
    (ii) Hardcopy.
    (A) A protocol containing methods used to perform the baseline or
periodic NOX emission test; and
    (B) Unit operating parameters related to NOX formation
by the unit.
    (3) For each gas-fired unit and diesel-fired unit or unit with a
wet flue gas pollution control system for which the designated
representative claims an opacity monitoring exemption under Sec.
75.14, the designated representative shall include in the hardcopy
monitoring plan the information specified under Sec.  75.14(b), (c), or
(d), demonstrating that the unit qualifies for the exemption.
    (4) For each unit using the low mass emissions excepted methodology
under Sec.  75.19 the designated representative shall include the
following additional information in the monitoring plan that
accompanies the initial certification application:
    (i) Electronic. For each low mass emissions unit, report the
results of the analysis performed to qualify as a low mass emissions
unit under Sec.  75.19(c). This report will include either the previous
three years actual or projected emissions. The following items should
be included:
    (A) Current calendar year of application;
    (B) Type of qualification;
    (C) Years one, two, and three;
    (D) Annual and/or ozone season measured, estimated or projected
NOX

mass emissions for years one, two, and three;
    (E) Annual measured, estimated or projected SO2 mass
emissions (if applicable) for years one, two, and three; and
    (F) Annual or ozone season operating hours for years one, two, and
three.
    (ii) Hardcopy.
    (A) A schematic diagram identifying the relationship between the
unit, all fuel supply lines and tanks, any fuel flowmeter(s), and the
stack(s). Comprehensive and/or separate schematic diagrams shall be
used to describe groups of units using a common pipe;
    (B) For units which use the long term fuel flow methodology under
Sec.  75.19(c)(3), the designated representative must provide a diagram
of the fuel flow to each affected unit or group of units and describe
in detail the procedures used to determine the long term fuel flow for
a unit or group of units for each fuel combusted by the unit or group
of units;
    (C) A statement that the unit burns only gaseous fuel(s) and/or
fuel oil and a list of the fuels that are burned or a statement that
the unit is projected to burn only gaseous fuel(s) and/or fuel oil and
a list of the fuels that are projected to be burned;
    (D) A statement that the unit meets the applicability requirements
in Sec. Sec.  75.19(a) and (b); and
    (E) Any unit historical actual, estimated and projected emissions
data and calculated emissions data demonstrating that the affected unit
qualifies as a low mass emissions unit under Sec. Sec.  75.19(a) and
75.19(b).
    (5) For qualification as a gas-fired unit, as defined in Sec.  72.2
of this part, the designated representative shall include in the
monitoring plan, in electronic format, the following: current calendar
year, fuel usage data for three calendar years (or ozone seasons) as
specified in the definition of gas-fired in Sec.  72.2 of this part,
the method of qualification used, and an indication of whether the data
are actual or projected data.
    (6) For each monitoring location with a stack flow monitor that is
exempt from performing 3-load flow RATAs (peaking units, bypass stacks,
or by petition) the designated representative shall include in the
monitoring plan an indicator of exemption from 3-load flow RATA using
the appropriate exemption code.
    22. Section 75.57 is amended by:
    a. Adding the phrase ``, or mmBtu/hr of thermal output, rounded to
the nearest mmBtu/hr'' after the phrase ``rounded to the nearest 1000
lb/hr'', in paragraph (b)(3); and
    b. Revising Table 4a in paragraph (c)(4)(iv).
    The revisions and additions read as follows:

Sec.  75.57  General recordkeeping provisions.

* * * * *
    (c) * * *
    (4) * * *
    (iv) * * *

     Table 4a.--Codes for Method of Emissions and Flow Determination
------------------------------------------------------------------------
                                  Hourly emissions/flow measurement or
             Code                          estimation method
------------------------------------------------------------------------
1............................  Certified primary emission/flow
                                monitoring system.
2............................  Certified backup emission/flow monitoring
                                system.
3............................  Approved alternative monitoring system.
4............................  Reference method:
                               SO2: Method 6C.
                               Flow: Method 2 or its allowable
                                alternatives under appendix A to part 60
                                of this chapter.
                               NOX: Method 7E.
                               CO2 or O2: Method 3A.
5............................  For units with add-on SO2 and/or NOX
                                emission controls: SO2 concentration or
                                NOX emission rate estimate from Agency
                                preapproved parametric monitoring
                                method.
6............................  Average of the hourly SO2 concentrations,
                                CO2 concentrations, O2 concentrations,
                                NOX concentrations, flow rates, moisture
                                percentages or NOX emission rates for
                                the hour before and the hour following a
                                missing data period.
7............................  Initial missing data procedures used.
                                Either: (a) The average of the hourly
                                SO2 concentration, CO2 concentration, O2
                                concentration, or moisture percentage
                                for the hour before and the hour
                                following a missing data period; or (b)
                                the arithmetic average of all NOX
                                concentration, NOX emission rate, or
                                flow rate values at the corresponding
                                load range (or a higher load range), or
                                at the corresponding operational bin
                                (non-load-based units, only); or (c) the
                                arithmetic average of all previous NOX
                                concentration, NOX emission rate, or
                                flow rate values (non-load-based units,
                                only).
8............................  90th percentile hourly SO2 concentration,
                                CO2 concentration, NOX concentration,
                                flow rate, moisture percentage, or NOX
                                emission rate or 10th percentile hourly
                                O2 concentration or moisture percentage
                                in the applicable lookback period
                                (moisture missing data algorithm depends
                                on which equations are used for
                                emissions and heat input).
9............................  95th percentile hourly SO2 concentration,
                                CO2 concentration, NOX concentration,
                                flow rate, moisture percentage, or NOX
                                emission rate or 5th percentile hourly
                                O2 concentration or moisture percentage
                                in the applicable lookback period
                                (moisture missing data algorithm depends
                                on which equations are used for
                                emissions and heat input).
10...........................  Maximum hourly SO2 concentration, CO2
                                concentration, NOX concentration, flow
                                rate, moisture percentage, or NOX
                                emission rate or minimum hourly O2
                                concentration or moisture percentage in
                                the applicable lookback period (moisture
                                missing data algorithm depends on which
                                equations are used for emissions and
                                heat input).
11...........................  Average of hourly flow rates, NOX
                                concentrations or NOX emission rates in
                                corresponding load range, for the
                                applicable lookback period. For non-load-
                                based units, report either the average
                                flow rate, NOX concentration or NOX
                                emission rate in the applicable lookback
                                period, or the average flow rate or NOX
                                value at the corresponding operational
                                bin (if operational bins are used).
12...........................  Maximum potential concentration of SO2,
                                maximum potential concentration of CO2,
                                maximum potential concentration of NOX
                                maximum potential flow rate, maximum
                                potential NOX emission rate, maximum
                                potential moisture percentage, minimum
                                potential O2 concentration or minimum
                                potential moisture percentage, as
                                determined using Sec.   72.2 of this
                                chapter and section 2.1 of appendix A to
                                this part (moisture missing data
                                algorithm depends on which equations are
                                used for emissions and heat input).
13...........................  Maximum expected concentration of SO2,
                                maximum expected concentration of NOX,
                                maximum expected Hg concentration, or
                                maximum controlled NOX emission rate.
                                (See Sec.   75.34(a)(5)).
14...........................  Diluent cap value (if the cap is
                                replacing a CO2 measurement, use 5.0
                                percent for boilers and 1.0 percent for
                                turbines; if it is replacing an O2
                                measurement, use 14.0 percent for
                                boilers and 19.0 percent for turbines).

15...........................  1.25 times the maximum hourly controlled
                                SO2 concentration, Hg concentration, NOX
                                concentration at the corresponding load
                                or operational bin, or NOX emission rate
                                at the corresponding load or operational
                                bin, in the applicable lookback period
                                (See Sec.   75.34(a)(5)).
16...........................  SO2 concentration value of 2.0 ppm during
                                hours when only ``very low sulfur
                                fuel'', as defined in Sec.   72.2 of
                                this chapter, is combusted.
17...........................  Like-kind replacement non-redundant
                                backup analyzer.
19...........................  200 percent of the MPC; default high
                                range value.
20...........................  200 percent of the full-scale range
                                setting (full-scale exceedance of high
                                range).
21...........................  Negative hourly SO2 concentration, NOX
                                concentration, percent moisture, or NOX
                                emission rate replaced with zero.
22...........................  Hourly average SO2 or NOX concentration,
                                measured by a certified monitor at the
                                control device inlet (units with add-on
                                emission controls only).
23...........................  Maximum potential SO2 concentration, NOX
                                concentration, CO2 concentration, NOX
                                emission rate or flow rate, or minimum
                                potential O2 concentration or moisture
                                percentage, for an hour in which flue
                                gases are discharged through an
                                unmonitored bypass stack.
24...........................  Maximum expected NOX concentration, or
                                maximum controlled NOX emission rate for
                                an hour in which flue gases are
                                discharged downstream of the NOX
                                emission controls through an unmonitored
                                bypass stack, and the add-on NOX
                                emission controls are confirmed to be
                                operating properly.
25...........................  Maximum potential NOX emission rate
                                (MER). (Use only when a NOX
                                concentration full-scale exceedance
                                occurs and the diluent monitor is
                                unavailable.)
26...........................  1.0 mmBtu/hr substituted for Heat Input
                                Rate for an operating hour in which the
                                calculated Heat Input Rate is zero or
                                negative.
32...........................  Hourly Hg concentration determined from
                                analysis of a single trap multiplied by
                                a factor of 1.222 when one of the paired
                                traps is invalidated or damaged (See
                                Appendix K Sec.   8).
33...........................  Hourly Hg concentration determined from
                                the trap resulting in the higher Hg
                                concentration when the relative
                                deviation between the paired traps is
                                greater than 10 percent (See Appendix K
                                Sec.   8).
54...........................  Other quality assured methodologies
                                approved through petition. These hours
                                are included in missing data lookback
                                and are treated as unavailable hours for
                                percent monitor availability
                                calculations.
55...........................  Other substitute data approved through
                                petition. These hours are not included
                                in missing data lookback and are treated
                                as unavailable hours for percent monitor
                                availability calculations.
------------------------------------------------------------------------

* * * * *
    23. Section 75.58 is amended by:
    a. Revising paragraph (b)(3) introductory text;
    b. Removing paragraphs (b)(3)(iii) and (b)(3)(iv);
    c. Removing the word ``and'' from paragraph (c)(1)(xii);
    d. Replacing the period with a semicolon and adding the word
``and'' to the end of the paragraph, in paragraph (c)(1)(xiii);
    e. Adding paragraph (c)(1)(xiv);
    f. Replacing the period with a semicolon and adding the word
``and'' to the end of the paragraph, in paragraph (c)(4)(x);
    g. Adding paragraph (c)(4)(xi);
    h. Replacing the period with a semicolon and adding the word
``and'' to the end of the paragraph, in paragraph (d)(1)(x);
    i. Adding paragraph (d)(1)(xi);
    j. Replacing the period with a semicolon and adding the word
``and'' to the end of the paragraph, in paragraph (d)(2)(x);
    k. Adding paragraph (d)(2)(xi);
    l. Revising paragraph (f)(1)(iii);
    m. Removing the word ``and'' at the end of paragraph (f)(1)(xi);
    n. Replacing the period with a semicolon at the end of paragraph
(f)(1)(xii);
    o. Adding paragraphs (f)(1)(xiii) and (f)(1)(xiv); and
    p. Replacing the word ``Component'' with the word ``Monitoring'',
in paragraph (f)(2)(x).
    The revisions and additions read as follows:

Sec.  75.58  General recordkeeping provisions for specific situations.

* * * * *
    (b) * * *
    (3) Except as otherwise provided in Sec.  75.34(d), for units with
add-on SO2 or NOX emission controls following the
provisions of Sec.  75.34(a)(1), (a)(2), (a)(3) or (a)(5), and for
units with add-on Hg emission controls, the owner or operator shall
record:
* * * * *
    (c) * * *
    (1) * * *
    (xiv) Heat input formula ID and SO2 Formula ID (required
beginning January 1, 2009).
* * * * *
    (4) * * *
    (xi) Heat input formula ID and SO2 Formula ID (required
beginning January 1, 2009).
* * * * *
    (d) * * *
    (1) * * *
    (xi) Heat input rate formula ID (required beginning January 1,
2009).
    (2) * * *
    (xi) Heat input rate formula ID (required beginning January 1,
2009).
* * * * *
    (f) * * *
    (1) * * *
    (iii) Fuel type (pipeline natural gas, natural gas, other gaseous
fuel, residual oil, or diesel fuel). If more than one type of fuel is
combusted in the hour, either:
    (A) Indicate the fuel type which results in the highest emission
factors for NOX (this option is in effect through December
31, 2008); or
    (B) Indicate the fuel type resulting in the highest emission factor
for each parameter (SO2, NOX emission rate, and
CO2) separately (this option is required on and after
January 1, 2009);
* * * * *
    (xiii) Base or peak load indicator (as applicable); and
    (xiv) Multiple fuel flag.
* * * * *
    24. Section 75.59 is amended by:
    a. Adding the phrase ``(on and after January 1, 2009, only the
component identification code is required)'' after the word ``code'',
in paragraph (a)(1)(i);
    b. Revising paragraph (a)(1)(viii);
    c. Replacing the phrase ``For the qualifying test for off-line
calibration, the owner or operator shall indicate'' with the phrase
``Indication of'', in paragraph (a)(1)(xi);
    d. Adding the phrase ``(after January 1, 2009, only the component

identification code is required)'' after the word ``code'', in
paragraph (a)(2)(i);
    e. Adding the phrase ``(on and after January 1, 2009, only the
component identification code is required)'' after the word ``code'',
in paragraph (a)(3)(i);
    f. Adding the phrase ``(only span scale is required on and after
January 1, 2009)'' after the word ``scale'', in paragraph (a)(3)(ii);
    g. Adding the phrase ``(on and after January 1, 2009, only the
system identification code is required)'' after the word ``code'', in
paragraph (a)(4)(i);
    h. Removing the word ``and'' after the semicolon at the end of
paragraph (a)(4)(vi)(L);
    i. Replacing the period with a semicolon and adding the word
``and'' at the end of paragraph (a)(4)(vi)(M);
    j. Adding paragraph (a)(4)(vi)(N);
    k. Removing the word ``and'' after the semicolon, at the end of
paragraph (a)(4)(vii)(K);
    l. Replacing the period with a semicolon and adding the word
``and'' at the end of paragraph (a)(4)(vii)(L);
    m. Adding paragraph (a)(4)(vii)(M);
    n. Revising paragraph (a)(6) introductory text;
    o. Adding the phrase ``(on and after January 1, 2009, only the
component identification code is required)'' after the word ``code'',
in paragraph (a)(6)(i);
    p. Replace the phrase ``Cycle time result for the entire system''
with the phrase ``Total cycle time'', in paragraph (a)(6)(ix);
    q. Adding paragraphs (a)(7)(ix) and (a)(7)(x);
    r. Revising paragraph (a)(8);
    s. Removing and reserving paragraph (a)(12)(iii);
    t. Removing the number ``(2)'' from the paragraph identifier
``Sec.  75.64(a)(2)'' in the second sentence of paragraph (a)(13);
    u. Adding the phrase ``(on and after January 1, 2009, only the
component identification code is required)'' after the word ``tested'',
in paragraphs (b)(1)(ii) and (b)(2)(i);
    v. Adding the phrase ``(on and after January 1, 2009, only the
monitoring system identification code is required)'' after the word
``code'', in paragraph (b)(4)(i)(A);
    w. Removing the word ``and'' after the semicolon at the end of
paragraph (b)(4)(i)(H);
    x. Replacing the period with a semicolon and adding the word
``and'' at the end of paragraph (b)(4)(i)(I);
    y. Adding paragraph (b)(4)(i)(J);
    z. Revising paragraphs (b)(4)(ii)(A), (b)(4)(ii)(B), and
(b)(4)(ii)(F);
    aa. Removing the word ``and'' after the semicolon at the end of
paragraph (b)(4)(ii)(L);
    bb. Replacing the period with a semicolon and adding the word
``and'' at the end of paragraph (b)(4)(ii)(M);
    cc. Adding paragraph (b)(4)(ii)(N);
    dd. Adding the phrase ``(on and after January 1, 2009, component
identification codes shall be reported in addition to the monitoring
system identification code)'' after the second occurrence of the word
``system'' in paragraphs (b)(5)(i)(B), (b)(5)(ii)(B), and
(b)(5)(iii)(B);
    ee. Adding the phrase ``This requirement remains in effect through
December 31, 2008'' after the word ``run'', in paragraph (b)(5)(i)(H);
    ff. Adding the phrase ``(as applicable). This requirement remains
in effect through December 31, 2008'' after the word ``level'', in
paragraph (b)(5)(iv)(A);
    gg. Removing the word ``and'' after the semicolon at the end of
paragraph (b)(5)(iv)(G);
    hh. Replacing the period with a semicolon and adding the word
``and'' at the end of paragraph (b)(5)(iv)(H);
    ii. Adding paragraph (b)(5)(iv)(I);
    jj. Removing the word ``and'' after the semicolon at the end of
paragraph (d)(1)(xi);
    kk. Replacing the period with a semicolon and adding the word
``and'' at the end of paragraph (d)(1)(xii);
    ll. Adding paragraph (d)(1)(xiii);
    mm. Removing the phrase ``, multiplied by 1.15, if appropriate''
from paragraph (d)(2)(iii);
    nn. Removing the word ``and'' after the semicolon at the end of
paragraph (d)(2)(iv);
    oo. Replacing the period with a semicolon at the end of paragraph
(d)(2)(v); and
    pp. Adding paragraphs (d)(2)(vi), (d)(2)(vii), (e) and (f).
    The revisions and additions read as follows:

Sec.  75.59  Certification, quality, assurance, and quality control
record provisions.

* * * * *
    (a) * * *
    (1) * * *
    (viii) For 7-day calibration error tests, a test number and reason
for test;
* * * * *
    (4) * * *
    (vi) * * *
    (N) Test number.
    (vii) * * *
    (M) An indicator (``flag'') if separate reference ratios are
calculated for each multiple stack.
* * * * *
    (6) For each SO2, NOX, Hg, or CO2
pollutant concentration monitor, each component of a NOX-
diluent continuous emission monitoring system, and each CO2
or O2 monitor used to determine heat input, the owner or
operator shall record the following information for the cycle time
test:
* * * * *
    (7) * * *
    (ix) For a unit with a flow monitor installed on a rectangular
stack or duct, if a site-specific default or measured wall effects
adjustment factor (WAF) is used to correct the stack gas volumetric
flow rate data to account for velocity decay near the stack or duct
wall, the owner or operator shall keep records of the following for
each flow RATA performed with EPA Method 2, subsequent to the WAF
determination:
    (A) Monitoring system ID;
    (B) Test number;
    (C) Operating level;
    (D) RATA end date and time;
    (E) Number of Method 1 traverse points; and
    (F) Wall effects adjustment factor (WAF), to the nearest 0.0001.
    (x) For each RATA run using Method 29 to determine Hg
concentration:
    (A) Percent CO2 and O2 in the stack gas, dry
basis;
    (B) Moisture content of the stack gas (percent H2O);
    (C) Average stack gas temperature ([deg]F);
    (D) Dry gas volume metered (dscm);
    (E) Percent isokinetic;
    (F) Particulate Hg collected in the front half of the sampling
train, corrected for the front-half blank value ([mu]g); and
    (G) Total vapor phase Hg collected in the back half of the sampling
train, corrected for the back-half blank value ([mu]g).
    (8) For each certified continuous emission monitoring system,
continuous opacity monitoring system, excepted monitoring system, or
alternative monitoring system, the date and description of each event
which requires certification, recertification, or certain diagnostic
testing of the system and the date and type of each test performed. If
the conditional data validation procedures of Sec.  75.20(b)(3) are to
be used to validate and report data prior to the completion of the
required certification, recertification, or diagnostic testing, the
date and hour of the probationary calibration error test shall be
reported to mark the beginning of conditional data validation.
* * * * *
    (b) * * *
    (4) * * *
    (i) * * *
    (J) Test number.
    (ii) * * *
    (A) Completion date and hour of most recent primary element
inspection or

test number of the most recent primary element inspection (as
applicable); (on and after January 1, 2009, the test number of the most
recent primary element inspection is required in lieu of the completion
date and hour for the most recent primary element inspection);
    (B) Completion date and hour of most recent flow meter of
transmitter accuracy test or test number of the most recent flowmeter
or transmitter accuracy test (as applicable); (on and after January 1,
2009, the test number of the most recent flowmeter or transmitter
accuracy test is required in lieu of the completion date and hour for
the most recent flowmeter or transmitter accuracy test);
* * * * *
    (F) Average load, in megawatts, 1000 lb/hr of steam, or mmBtu/hr
thermal output;
* * * * *
    (N) Monitoring system identification code. * * *
* * * * *
    (5) * * *
    (iv) * * *
    (I) Component identification code (required on and after January 1,
2009).
* * * * *
    (d) * * *
    (1) * * *
    (xiii) An indicator (``flag'') if the run is used to calculate the
highest 3-run average NOX emission rate at any load level.
    (2) * * *
    (vi) Indicator of whether the testing was done at base load, peak
load or both (if appropriate); and
    (vii) The default NOX emission rate for peak load hours
(if applicable).
* * * * *
    (e) Excepted monitoring for Hg low mass emission units under Sec.
75.81(b). For qualifying coal-fired units using the alternative low
mass emission methodology under Sec.  75.81(b), the owner or operator
shall record the data elements described in Sec.  75.59(a)(7)(vii),
Sec.  75.59(a)(7)(viii), or Sec.  75.59(a)(7)(x), as applicable, for
each run of each Hg emission test and re-test required under Sec.
75.81(c)(1) or Sec.  75.81(d)(4)(iii).
    (f) DAHS Verification. For each DAHS (missing data and formula)
verification that is required for initial certification,
recertification, or for certain diagnostic testing of a monitoring
system, record the date and hour that the DAHS verification is
successfully completed. (This requirement only applies to units that
report monitoring plan data in accordance with Sec.  75.53(g) and (h).)
* * * * *
    25. Section 75.60 is amended by adding paragraph (b)(8) to read as
follows:

Sec.  75.60  General provisions.

* * * * *
    (b) * * *
    (8) Routine retest reports for Hg low mass emissions units. If
requested in writing (or by electronic mail) by the applicable EPA
Regional Office, appropriate State, and/or appropriate local air
pollution control agency, the designated representative shall submit a
hardcopy report for a semiannual or annual retest required under Sec.
75.81(d)(4)(iii) for a Hg low mass emissions unit, within 45 days after
completing the test or within 15 days of receiving the request,
whichever is later. The designated representative shall report, at a
minimum, the following hardcopy information to the applicable EPA
Regional Office, appropriate State, and/or appropriate local air
pollution control agency that requested the hardcopy report: A summary
of the test results; the raw reference method data for each test run;
the raw data and results of all pretest, post-test, and post-run
quality-assurance checks of the reference method; the raw data and
results of moisture measurements made during the test runs (if
applicable); diagrams illustrating the test and sample point locations;
a copy of the test protocol used; calibration certificates for the gas
standards or standard solutions used in the testing; laboratory
calibrations of the source sampling equipment; and the names of the key
personnel involved in the test program, including test team members,
plant contact persons, agency representatives and test observers.
* * * * *
    26. Section 75.61 is amended by:
    a. Revising the first sentence of paragraph (a)(1) introductory
text;
    b. Revising paragraph (a)(3);
    c. Revising the first sentence of paragraph (a)(5) introductory
text; and
    d. Adding paragraphs (a)(7) and (a)(8)
    The revisions and additions read as follows:

Sec.  75.61  Notifications.

    (a) * * *
    (1) Initial certification and recertification test notifications.
The owner or operator or designated representative for an affected unit
shall submit written notification of initial certification tests and
revised test dates as specified in Sec.  75.20 for continuous emission
monitoring systems, for the excepted Hg monitoring methodology under
Sec.  75.81(b), for alternative monitoring systems under subpart E of
this part, or for excepted monitoring systems under appendix E to this
part, except as provided in paragraphs (a)(1)(iii), (a)(1)(iv) and
(a)(4) of this section.* * *
* * * * *
    (3) Unit shutdown and recommencement of commercial operation. For
an affected unit that will be shutdown on the relevant compliance date
specified in Sec.  75.4 or in a State or Federal pollutant mass
emissions reduction program that adopts the monitoring and reporting
requirements of this part, if the owner or operator is relying on the
provisions in Sec.  75.4(d) to postpone certification testing, the
designated representative for the unit shall submit notification of
unit shutdown and recommencement of commercial operation as follows:
    (i) For planned unit shutdowns (e.g., extended maintenance
outages), written notification of the planned shutdown date shall be
provided at least 21 days prior to the applicable compliance date, and
written notification of the planned date of recommencement of
commercial operation shall be provided at least 21 days in advance of
unit restart. If the actual shutdown date or the actual date of
recommencement of commercial operation differs from the planned date,
written notice of the actual date shall be submitted no later than 7
days following the actual date of shutdown or of recommencement of
commercial operation, as applicable;
    (ii) For unplanned unit shutdowns (e.g., forced outages), written
notification of the actual shutdown date shall be provided no more than
7 days after the shutdown, and written notification of the planned date
of recommencement of commercial operation shall be provided at least 21
days in advance of unit restart. If the actual date of recommencement
of commercial operation differs from the expected date, written notice
of the actual date shall be submitted no later than 7 days following
the actual date of recommencement of commercial operation.
* * * * *
    (5) Periodic relative accuracy test audits, appendix E retests, and
low mass emissions unit retests. The owner or operator or designated
representative of an affected unit shall submit written notice of the
date of periodic relative accuracy testing performed under section
2.3.1 of appendix B to this part, of periodic retesting performed under
section 2.2 of appendix E to this part, of periodic retesting of low
mass emissions units performed under Sec.  75.19(c)(1)(iv)(D), and of
periodic

retesting of Hg low mass emissions units performed under Sec.
75.81(d)(4)(iii), no later than 21 days prior to the first scheduled
day of testing. * * *
* * * * *
    (7) Long-term cold storage and recommencement of commercial
operation. The designated representative for an affected unit that is
placed into long-term cold storage that is relying on the provisions in
Sec.  75.4(d) or Sec.  75.64(a), either to postpone certification
testing or to discontinue the submittal of quarterly reports during the
period of long-term cold storage, shall provide written notification of
long-term cold storage status and recommencement of commercial
operation as follows:
    (i) Whenever an affected unit has been placed into long-term cold
storage, written notification of the date and hour that the unit was
shutdown and a statement from the designated representative stating
that the shutdown is expected to last for at least two years from that
date, in accordance with the definition for long-term cold storage of a
unit as provided in Sec.  72.2.
    (ii) Whenever an affected unit that has been placed into long-term
cold storage is expected to resume operation, written notification
shall be submitted 45 calendar days prior to the planned date of
recommencement of commercial operation. If the actual date of
recommencement of commercial operation differs from the expected date,
written notice of the actual date shall be submitted no later than 7
days following the actual date of recommencement of commercial
operation.
    (8) Certification deadline date for new or newly affected units.
The designated representative of a new or newly affected unit shall
provide notification of the date on which the relevant deadline for
initial certification is reached, either as provided in Sec.  75.4(b)
or Sec.  75.4(c), or as specified in a State or Federal SO2,
NOX, or Hg mass emission reduction program that incorporates
by reference, or otherwise adopts, the monitoring, recordkeeping, and
reporting requirements of subpart F, G, H, or I of this part. The
notification shall be submitted no later than 7 calendar days after the
applicable certification deadline is reached.
* * * * *
    27. Section 75.62 is amended by:
    a. Revising paragraph (a)(1); and
    b. Replacing the number ``45'' with the number ``21'' before the
phrase ``days prior'', in paragraph (a)(2).
    The revisions and additions read as follows:

Sec.  75.62  Monitoring plan submittals.

    (a) * * *
    (1) Electronic. Using the format specified in paragraph (c) of this
section, the designated representative for an affected unit shall
submit a complete, electronic, up-to-date monitoring plan file (except
for hardcopy portions identified in paragraph (a)(2) of this section)
to the Administrator as follows: no later than 21 days prior to the
initial certification tests; at the time of each certification or
recertification application submission; and (prior to or concurrent
with) the submittal of the electronic quarterly report for a reporting
quarter where an update of the electronic monitoring plan information
is required, either under Sec.  75.53(b) or elsewhere in this part.
* * * * *
    28. Section 75.63 is amended by:
    a. Removing the phrase ``and a hardcopy certification application
form (EPA form 7610-14)'' from paragraph (a)(1)(i)(A);
    b. Revising paragraph (a)(1)(ii)(A);
    c. Adding the phrase ``or Sec.  75.53(h)(4)(ii) (as applicable)''
after the identifier ``Sec.  75.53(f)(5)(ii)'', in paragraph
(a)(1)(ii)(B);
    d. Removing the phrase ``and a hardcopy certification application
form (EPA form 7610-14)'' after the word ``section'', in paragraph
(a)(2)(i);
    e. Revising paragraph (a)(2)(iii);
    f. Removing and reserving paragraph (b)(2)(iii);
    g. Revising paragraph (b)(2)(iv) by adding the words ``certifying
the accuracy of the submission'' after the word ``signature''.
    The revisions read as follows:

Sec.  75.63  Initial Certification or Recertification Application.

    (a) * * *
    (1) * * *
    (ii) * * *
    (A) To the Administrator, the electronic low mass emission
qualification information required by Sec.  75.53(f)(5)(i) or Sec.
75.53(h)(4)(i) (as applicable) and paragraph (b)(1)(i) of this section;
and
* * * * *
    (2) * * *
    (iii) Notwithstanding the requirements of paragraphs (a)(2)(i) and
(a)(2)(ii) of this section, for an event for which the Administrator
determines that only diagnostic tests (see Sec.  75.20(b)) are required
rather than recertification testing, no hardcopy submittal is required;
however, the results of all diagnostic test(s) shall be submitted prior
to or concurrent with the electronic quarterly report required under
Sec.  75.64. Notwithstanding the requirement of Sec.  75.59(e), for
DAHS (missing data and formula) verifications, no hardcopy submittal is
required; the owner or operator shall keep these test results on-site
in a format suitable for inspection.
* * * * *
    29. Section 75.64 is amended by:
    a. Revising paragraph (a) introductory text;
    b. Revising paragraph (a)(2)(xiv);
    c. Removing paragraph (a)(8);
    d. Redesignating paragraphs (a)(3) through (a)(7) as paragraphs
(a)(8) through (a)(12), and redesignating paragraphs (a)(9) through
(a)(11) as paragraphs (a)(13) through (a)(15);
    e. Adding new paragraphs (a)(3) through (a)(7); and
    f. Replacing the citation ``Sec.  75.59'', with ``Sec.
75.58(f)(2)'' at the end of newly designated paragraph (a)(14).
    The revisions and additions read as follows:

Sec.  75.64  Quarterly reports.

    (a) Electronic submission. The designated representative for an
affected unit shall electronically report the data and information in
paragraphs (a), (b), and (c) of this section to the Administrator
quarterly, beginning with the data from the earlier of the calendar
quarter corresponding to the date of provisional certification or the
calendar quarter corresponding to the relevant deadline for initial
certification in Sec.  75.4(a), (b), or (c). The initial quarterly
report shall contain hourly data beginning with the hour of provisional
certification or the hour corresponding to the relevant certification
deadline, whichever is earlier. For an affected unit subject to Sec.
75.4(d) that is shutdown on the relevant compliance date in Sec.
75.4(a) or has been placed in long-term cold storage (as defined in
Sec.  72.2 of this chapter), quarterly reports are not required. In
such cases, the owner or operator shall submit quarterly reports for
the unit beginning with the data from the quarter in which the unit
recommences commercial operation (where the initial quarterly report
contains hourly data beginning with the first hour of recommenced
commercial operation of the unit). For units placed into long-term cold
storage during a reporting quarter, the exemption from submitting
quarterly reports begins with the calendar quarter following the date
that the unit is placed into long-term cold storage. For any
provisionally-certified monitoring system, Sec.  75.20(a)(3) shall
apply for initial certifications, and Sec.  75.20(b)(5) shall apply for
recertifications. Each electronic report must be submitted to

the Administrator within 30 days following the end of each calendar
quarter. Prior to January 1, 2008, each electronic report shall include
for each affected unit (or group of units using a common stack), the
information provided in paragraphs (a)(1), (a)(2), and (a)(8) through
(a)(15) of this section. During the time period of January 1, 2008 to
January 1, 2009, each electronic report shall include either the
information provided in paragraphs (a)(1), (a)(2), and (a)(8) through
(a)(15) of this section or the information provided in paragraphs
(a)(3) through (a)(15). On and after January 1, 2009, the owner or
operator shall meet the requirements of paragraphs (a)(3) through
(a)(15) of this section only. Each electronic report shall also include
the date of report generation.
* * * * *
    (2) * * *
    (xiii) Supplementary RATA information required under Sec.
75.59(a)(7), except that:
    (A) The applicable data elements under Sec.  75.59(a)(7)(ii)(A)
through (T) and under Sec.  75.59(a)(7)(iii)(A) through (M) shall be
reported for flow RATAs at circular or rectangular stacks (or ducts) in
which angular compensation for yaw and/or pitch angles is used (i.e.,
Method 2F or 2G), with or without wall effects adjustments;
    (B) The applicable data elements under Sec.  75.59(a)(7)(ii)(A)
through (T) and under Sec.  75.59(a)(7)(iii)(A) through (M) shall be
reported for any flow RATA run at a circular stack in which Method 2 is
used and a wall effects adjustment factor is determined by direct
measurement;
    (C) The data under Sec.  75.59(a)(7)(ii)(T) shall be reported for
all flow RATAs at circular stacks in which Method 2 is used and a
default wall effects adjustment factor is applied; and
    (D) The data under Sec.  75.59(a)(7)(ix)(A) through (F) shall be
reported for all flow RATAs at rectangular stacks or ducts in which
Method 2 is used and a wall effects adjustment factor is applied.
    (3) Facility identification information, including:
    (i) Facility/ORISPL number;
    (ii) Calendar quarter and year for the data contained in the
report; and
    (iii) Version of the electronic data reporting format used for the
report.
    (4) In accordance with Sec.  75.62(a)(1), if any monitoring plan
information required in Sec.  75.53 requires an update, either under
Sec.  75.53(b) or elsewhere in this part, submission of the electronic
monitoring plan update shall be completed prior to or concurrent with
the submittal of the quarterly electronic data report for the
appropriate quarter in which the update is required.
    (5) Except for the daily calibration error test data, daily
interference check, and off-line calibration demonstration information
required in Sec.  75.59(a)(1) and (2), which must always be submitted
with the quarterly report, the certification, quality assurance, and
quality control information required in Sec.  75.59 shall either be
submitted prior to or concurrent with the submittal of the relevant
quarterly electronic data report.
    (6) The information and hourly data required in Sec. Sec.  75.57
through 75.59, and daily calibration error test data, daily
interference check, and off-line calibration demonstration information
required in Sec.  75.59(a)(1) and (2).
    (7) Notwithstanding the requirements of paragraphs (a)(4) through
(a)(6) of this section, the following information is excluded from
electronic reporting:
    (i) Descriptions of adjustments, corrective action, and
maintenance;
    (ii) Information which is incompatible with electronic reporting
(e.g., field data sheets, lab analyses, quality control plan);
    (iii) Opacity data listed in Sec.  75.57(f), and in Sec.
75.59(a)(8);
    (iv) For units with SO2 or NOX add-on
emission controls that do not elect to use the approved site-specific
parametric monitoring procedures for calculation of substitute data,
the information in Sec.  75.58(b)(3);
    (v) Information required by Sec.  75.57(h) concerning the causes of
any missing data periods and the actions taken to cure such causes;
    (vi) Hardcopy monitoring plan information required by Sec.  75.53
and hardcopy test data and results required by Sec.  75.59;
    (vii) Records of flow monitor and moisture monitoring system
polynomial equations, coefficients, or ``K'' factors required by Sec.
75.59(a)(5)(vi) or Sec.  75.59(a)(5)(vii);
    (viii) Daily fuel sampling information required by Sec.
75.58(c)(3)(i) for units using assumed values under appendix D;
    (ix) Information required by Sec. Sec.  75.59(b)(1)(vi), (vii),
(viii), (ix), and (xiii), and (b)(2)(iii) and (iv) concerning fuel
flowmeter accuracy tests and transmitter/transducer accuracy tests;
    (x) Stratification test results required as part of the RATA
supplementary records under Sec.  75.59(a)(7);
    (xi) Data and results of RATAs that are aborted or invalidated due
to problems with the reference method or operational problems with the
unit and data and results of linearity checks that are aborted or
invalidated due to problems unrelated to monitor performance; and
    (xii) Supplementary RATA information required under Sec.
75.59(a)(7)(i) through Sec.  75.59(a)(7)(v), except that:
    (A) The applicable data elements under Sec.  75.59(a)(7)(ii)(A)
through (T) and under Sec.  75.59(a)(7)(iii)(A) through (M) shall be
reported for flow RATAs at circular or rectangular stacks (or ducts) in
which angular compensation for yaw and/or pitch angles is used (i.e.,
Method 2F or 2G), with or without wall effects adjustments;
    (B) The applicable data elements under Sec.  75.59(a)(7)(ii)(A)
through (T) and under Sec.  75.59(a)(7)(iii)(A) through (M) shall be
reported for any flow RATA run at a circular stack in which Method 2 is
used and a wall effects adjustment factor is determined by direct
measurement;
    (C) The data under Sec.  75.59(a)(7)(ii)(T) shall be reported for
all flow RATAs at circular stacks in which Method 2 is used and a
default wall effects adjustment factor is applied; and
    (D) The data under Sec.  75.59(a)(7)(vii)(A) through (F) shall be
reported for all flow RATAs at rectangular stacks or ducts in which
Method 2 is used and a wall effects adjustment factor is applied.
* * * * *

Sec.  75.66  [Amended]

    30. Section 75.66 is amended by removing and reserving paragraph
(f).
    31. Section 75.71 is amended by:
    a. In paragraph (a)(1), by replacing the second occurrence of the
phrase ``CO2 diluent gas monitor'' with the phrase
``CO2 diluent gas monitoring system'';
    b. Replacing the phrase ``O2 or CO2 diluent
gas monitor'' with the phrase ``O2 or CO2
monitoring system'', in paragraph (a)(2); and
    c. Revising paragraph (e).
    The revision reads as follows:

Sec.  75.71  Specific provisions for monitoring NOX and heat
input for the purpose of calculating NOX mass emissions.

* * * * *
    (e) Low mass emissions units. Notwithstanding the requirements of
paragraphs (c) and (d) of this section, for an affected unit using the
low mass emissions (LME) unit under Sec.  75.19 to estimate hourly
NOX emission rate, heat input and NOX mass
emissions, the owner or operator shall calculate the ozone season
NOX mass emissions by summing all of the estimated hourly
NOX mass emissions in the ozone season, as determined under

Sec.  75.19(c)(4)(ii)(A), and dividing this sum by 2000 lb/ton.
* * * * *
    32. Section 75.72 is amended by:
    a. Revising the section heading and the introductory text; and
    b. Removing and reserving paragraph (f).
    The revisions read as follows:

Sec.  75.72  Determination of NOX mass emissions for common
stack and multiple stack configurations.

    The owner or operator of an affected unit shall either: calculate
hourly NOX mass emissions (in lbs) by multiplying the hourly
NOX emission rate (in lbs/mmBtu) by the hourly heat input
rate (in mmBtu/hr) and the unit or stack operating time (as defined in
Sec.  72.2); or, as provided in paragraph (e) of this section,
calculate hourly NOX mass emissions from the hourly
NOX concentration (in ppm) and the hourly stack flow rate
(in scfh). Only one methodology for determining NOX mass
emissions shall be identified in the monitoring plan for each
monitoring location at any given time. The owner or operator shall also
calculate quarterly and cumulative year-to-date NOX mass
emissions and cumulative NOX mass emissions for the ozone
season (in tons) by summing the hourly NOX mass emissions
according to the procedures in section 8 of appendix F to this part.
* * * * *
    (f) [Reserved]
* * * * *
    33. Section 75.73 is amended by:
    a. Revising paragraph (c)(3);
    b. Replacing the number ``45'' with the number ``21'' in paragraphs
(e)(1) and (e)(2);
    c. Revising paragraph (f)(1) introductory text;
    d. Replacing the phrase ``paragraph (a)'' with the phrase
``paragraphs (a) and (b)'' in paragraph (f)(1)(ii) introductory text;
and
    e. Revising paragraph (f)(1)(ii)(K).
    The revisions read as follows:

Sec.  75.73  Recordkeeping and reporting.

* * * * *
    (c) * * *
    (3) Contents of the monitoring plan for units not subject to an
Acid Rain emissions limitation. Prior to January 1, 2009, each
monitoring plan shall contain the information in Sec.  75.53(e)(1) or
Sec.  75.53(g)(1) in electronic format and the information in Sec.
75.53(e)(2) or Sec.  75.53(g)(2) in hardcopy format. On and after
January 1, 2009, each monitoring plan shall contain the information in
Sec.  75.53(g)(1) in electronic format and the information in Sec.
75.53(g)(2) in hardcopy format, only. In addition, to the extent
applicable, prior to January 1, 2009, each monitoring plan shall
contain the information in Sec.  75.53(f)(1)(i), (f)(2)(i), and (f)(4)
or Sec.  75.53(h)(1)(i), and (h)(2)(i) in electronic format and the
information in Sec.  75.53(f)(1)(ii) and (f)(2)(ii) or Sec.
75.53(h)(1)(ii) and (h)(2)(ii) in hardcopy format. On and after January
1, 2009, each monitoring plan shall contain the information in Sec.
75.53(h)(1)(i), and (h)(2)(i) in electronic format and the information
in Sec.  75.53(h)(1)(ii) and (h)(2)(ii) in hardcopy format, only. For
units using the low mass emissions excepted methodology under Sec.
75.19, prior to January 1, 2009, the monitoring plan shall include the
additional information in Sec.  75.53(f)(5)(i) and (f)(5)(ii) or Sec.
75.53(h)(4)(i) and (h)(4)(ii). On and after January 1, 2009, for units
using the low mass emissions excepted methodology under Sec.  75.19 the
monitoring plan shall include the additional information in Sec.
75.53(h)(4)(i) and (h)(4)(ii), only. Prior to January 1, 2008, the
monitoring plan shall also identify, in electronic format, the
reporting schedule for the affected unit (ozone season or quarterly),
and the beginning and end dates for the reporting schedule. The
monitoring plan also shall include a seasonal controls indicator, and
an ozone season fuel-switching flag.
* * * * *
    (f) * * *
    (1) Electronic submission. The designated representative for an
affected unit shall electronically report the data and information in
this paragraph (f)(1) and in paragraphs (f)(2) and (3) of this section
to the Administrator quarterly, unless the unit has been placed in
long-term cold storage (as defined in Sec.  72.2 of this chapter). For
units placed into long-term cold storage during a reporting quarter,
the exemption from submitting quarterly reports begins with the
calendar quarter following the date that the unit is placed into long-
term cold storage. In such cases, the owner or operator shall submit
quarterly reports for the unit beginning with the data from the quarter
in which the unit recommences operation (where the initial quarterly
report contains hourly data beginning with the first hour of
recommenced operation of the unit). Each electronic report must be
submitted to the Administrator within 30 days following the end of each
calendar quarter. Except as otherwise provided in Sec. Sec.
75.64(a)(4) and (a)(5), each electronic report shall include the
information provided in paragraphs (f)(1)(i) through (1)(vi) of this
section, and shall also include the date of report generation. Prior to
January 1, 2009, each report shall include the facility information
provided in paragraphs (f)(1)(i)(A) and (B), for each affected unit or
group of units monitored at a common stack. On and after January 1,
2009, only the facility identification information provided in
paragraph (f)(1)(i)(A) is required.
* * * * *
    (ii) * * *
    (K) Supplementary RATA information required under Sec.
75.59(a)(7), except that:
    (1) The applicable data elements under Sec.  75.59(a)(7)(ii)(A)
through (T) and under Sec.  75.59(a)(7)(iii)(A) through (M) shall be
reported for flow RATAs at circular or rectangular stacks (or ducts) in
which angular compensation for yaw and/or pitch angles is used (i.e.,
Method 2F or 2G), with or without wall effects adjustments;
    (2) The applicable data elements under Sec.  75.59(a)(7)(ii)(A)
through (T) and under Sec.  75.59(a)(7)(iii)(A) through (M) shall be
reported for any flow RATA run at a circular stack in which Method 2 is
used and a wall effects adjustment factor is determined by direct
measurement;
    (3) The data under Sec.  75.59(a)(7)(ii)(T) shall be reported for
all flow RATAs at circular stacks in which Method 2 is used and a
default wall effects adjustment factor is applied; and
    (4) The data under Sec.  75.59(a)(7)(ix)(A) through (F) shall be
reported for all flow RATAs at rectangular stacks or ducts in which
Method 2 is used and a wall effects adjustment factor is applied.
* * * * *
    34. Section 75.74 is amended by:
    a. Replacing the phrase ``In the time period to the start of the
current ozone season (i.e., in the period extending from October 1 of
the previous calendar year through April 30 of the current calendar
year), the'', with the word ``The'', in paragraph (c)(2) introductory
text;
    b. Adding the words ``in the second calendar quarter no later than
April 30'' to the end of paragraph (c)(2)(i) introductory text;
    c. Removing the phrase ``of the current calendar year'' from the
first sentence, and removing the last sentence of paragraph
(c)(2)(i)(C);
    d. Revising paragraph (c)(2)(i)(D);
    e. Adding the words ``in the first or second calendar quarter, but
no later than April 30'' to the end of the first sentence, and by
removing the second sentence of paragraph (c)(2)(ii) introductory text;
    f. Removing the words ``of the current calendar year'' from
paragraph (c)(2)(ii)(E);

    g. Revising paragraph (c)(2)(ii)(F);
    h. Removing paragraphs (c)(2)(ii)(G) and (c)(2)(ii)(H);
    i. Revising paragraph (c)(3)(ii);
    j. Removing and reserving paragraphs (c)(3)(vi) through (viii);
    k. Replacing all occurrences of the words ``Sec.  75.31, Sec.
75.33, or Sec.  75.37'' with the words ``Sec. Sec.  75.31 through
75.37'' in paragraphs (c)(3)(xi), (c)(3)(xii)(A), and (c)(3)(xii)(B);
    l. Revising paragraph (c)(6)(iii);
    m. Replacing the words ``October 1 of the previous calendar year''
with ``January 1'' in paragraph (c)(6)(v); and
    n. Revising paragraph (c)(11).
    The revisions and additions read as follows:

Sec.  75.74  Annual and ozone season monitoring and reporting
requirements.

* * * * *
    (c) * * *
    (2) * * *
    (i) * * *
    (D) If the linearity check is not completed by April 30, data
validation shall be determined in accordance with paragraph
(c)(3)(ii)(E) of this section.
    (ii) * * *
    (F) Data Validation. For each RATA that is performed by April 30,
data validation shall be done according to sections 2.3.2(a)-(j) of
appendix B to this part. However, if a required RATA is not completed
by April 30, data from the monitoring system shall be invalid,
beginning with the first unit operating hour on or after May 1. The
owner or operator shall continue to invalidate all data from the CEMS
until either:
    (1) The required RATA of the CEMS has been performed and passed; or
    (2) A probationary calibration error test of the CEMS is passed in
accordance with Sec.  75.20(b)(3)(ii). Once the probationary
calibration error test has been passed, the owner or operator shall
perform the required RATA in accordance with the conditional data
validation provisions and within the 720 unit or stack operating hour
time frame specified in Sec.  75.20(b)(3) (subject to the restrictions
in paragraph (c)(3)(xii) of this section), and the term ``quality
assurance'' shall apply instead of the term ``recertification.''
However, in lieu of the provisions in Sec.  75.20(b)(3)(ix), the owner
or operator shall follow the applicable provisions in paragraphs
(c)(3)(xi) and (c)(3)(xii) of this section.
    (3) * * *
    (ii) For each gas monitor required by this subpart, linearity
checks shall be performed in the second and third calendar quarters, as
follows:
    (A) For the second calendar quarter, the pre-ozone season linearity
check required under paragraph (c)(2)(i) of this section shall be
performed by April 30.
    (B) For the third calendar quarter, a linearity check shall be
performed and passed no later than July 30.
    (C) Conduct each linearity check in accordance with the general
procedures in section 6.2 of appendix A to this part, except that the
data validation procedures in sections 6.2(a) through (f) of appendix A
do not apply.
    (D) Each linearity check shall be done ``hands-off,'' as described
in section 2.2.3(c) of appendix B to this part.
    (E) Data Validation. For second and third quarter linearity checks
performed by the applicable deadline (i.e., April 30 or July 30), data
validation shall be done in accordance with sections 2.2.3(a), (b),
(c), (e), and (h) of Appendix B to this part. However, if a required
linearity check for the second calendar quarter is not completed by
April 30, or if a required linearity check for the third calendar
quarter is not completed by July 30, data from the monitoring system
(or range) shall be invalid, beginning with the first unit operating
hour on or after May 1 or July 31, respectively. The owner or operator
shall continue to invalidate all data from the CEMS until either:
    (1) The required linearity check of the CEMS has been performed and
passed; or
    (2) A probationary calibration error test of the CEMS is passed in
accordance with Sec.  75.20(b)(3)(ii). Once the probationary
calibration error test has been passed, the owner or operator shall
perform the required linearity check in accordance with the conditional
data validation provisions and within the 168 unit or stack operating
hour time frame specified in Sec.  75.20(b)(3) (subject to the
restrictions in paragraph (c)(3)(xii) of this section), and the term
``quality assurance'' shall apply instead of the term
``recertification.'' However, in lieu of the provisions in Sec.
75.20(b)(3)(ix), the owner or operator shall follow the applicable
provisions in paragraphs (c)(3)(xi) and (c)(3)(xii) of this section.
    (F) A pre-season linearity check performed and passed in April
satisfies the linearity check requirement for the second quarter.
    (G) The third quarter linearity check requirement in paragraph
(c)(3)(ii)(B) of this section is waived if:
    (1) Due to infrequent unit operation, the 168 operating hour
conditional data validation period associated with a pre-season
linearity check extends into the third quarter; and
    (2) A linearity check is performed and passed within that
conditional data validation period.
* * * * *
    (6) * * *
    (iii) For the time periods described in paragraphs (c)(2)(i)(C) and
(c)(2)(ii)(E) of this section, hourly emission data and the results of
all daily calibration error tests and flow monitor interference checks
shall be recorded. The results of all daily calibration error tests and
flow monitor interference checks performed in the time period from
April 1 through April 30 shall be reported. The owner or operator shall
also report unit operating data recorded in the time period from April
1 through April 30 beginning with the day of the first required daily
calibration error test or flow monitor interference check performed
whenever the XML reporting format is used. The owner or operator may
also report the hourly emission data in the time period from April 1
through April 30. However, only the emission data recorded in the time
period from May 1 through September 30 shall be used for NOX
mass compliance determination;
* * * * *
    (11) Units may qualify to use the optional NOX mass
emissions estimation protocol for gas-fired and oil-fired peaking units
in appendix E to this part on an ozone season basis. In order to be
allowed to use this methodology, the unit must meet the definition of
``peaking unit'' in Sec.  72.2 of this chapter, except that the words
``year'', ``calendar year'' and ``calendar years'' in that definition
shall be replaced by the words ``ozone season'', ``ozone season'', and
``ozone seasons'', respectively. In addition, in the definition of the
term ``capacity factor'' in Sec.  72.2 of this chapter, the word
``annual'' shall be replaced by the words ``ozone season'' and the
number ``8,760'' shall be replaced by the number ``3,672''.
    35. Section 75.81 is amended by:
    a. Revising paragraph (a)(4);
    b. Revising paragraph (c)(1);
    c. Revising paragraph (c)(2);
    c. Removing Eq. 1 from paragraph (d)(1);
    d. Revising paragraph (d)(2);
    e. Adding paragraph (d)(4)(iv); and
    f. Revising paragraphs (d)(5) and (e)(1).
    The revisions and additions read as follows:

Sec.  75.81  Monitoring of Hg mass emissions and heat input at the unit
level.

* * * * *
    (a) * * *
    (4) If heat input is required to be reported under the applicable
State or Federal Hg mass emission reduction

program that adopts the requirements of this subpart, the owner or
operator must meet the general operating requirements for a flow
monitoring system and an O2 or CO2 monitoring
system to measure heat input rate.
* * * * *
    (c) * * *
    (1) The owner or operator must perform Hg emission testing one year
or less before the compliance date in Sec.  75.80(b), to determine the
Hg concentration (i.e., total vapor phase Hg) in the effluent. The
testing shall be performed using one of the Hg reference methods listed
in Sec.  75.22(a)(7), and shall consist of a minimum of 3 runs at the
normal unit operating load, while combusting coal. The coal combusted
during the testing must be from the same source of supply as the coal
combusted at the start of the Hg mass emissions reduction program. The
minimum time per run shall be 1 hour if an instrumental reference
method is used. If Method 29 or the Ontario Hydro method is used,
paired sampling trains are required for each test run and the run must
be long enough to ensure that sufficient Hg is collected to analyze.
When Method 29 or the Ontario Hydro method is used, the test results
shall be based on the vapor phase Hg collected in the back-half of the
sampling trains (i.e., the non-filterable impinger catches). For each
Method 29 or Ontario Hydro method test run, the paired trains must meet
the percent relative deviation (RD) requirement in Sec.  75.22(a)(7).
If the RD specification is met, the results of the two trains shall be
averaged arithmetically. If the unit is equipped with flue gas
desulfurization or add-on Hg emission controls, the controls must be
operating normally during the testing, and, for the purpose of
establishing proper operation of the controls, the owner or operator
shall record parametric data or SO2 concentration data in
accordance with Sec.  75.58(b)(3)(i).
    (2) Based on the results of the emission testing, Equation 1 of
this section shall be used to provide a conservative estimate of the
annual Hg mass emissions from the unit:
[GRAPHIC] [TIFF OMITTED] TP22AU06.050

Where:

E = Estimated annual Hg mass emissions from the affected unit, (ounces/
year)
K = Units conversion constant, 9.978 x 10-10 oz-scm/[mu]g-
scf
8760 = Number of hours in a year
CHg = The highest Hg concentration ([mu]g/scm) from any of
the test runs or 0.50 [mu]g/scm, whichever is greater
Qmax = Maximum potential flow rate, determined according to section
<IP_ADDRESS> of appendix A to this part, (scfh)

    Equation 1 of this section assumes that the unit operates year-
round at its maximum potential flow rate. Also, note that if the
highest Hg concentration measured in any test run is less than 0.50
[mu]g/scm, a default value of 0.50 [mu]g/scm must be used in the
calculations.
* * * * *
    (d) * * *
    (2) Following initial certification, the same default Hg
concentration value that was used to estimate the unit's annual Hg mass
emissions under paragraph (c) of this section shall be reported for
each unit operating hour, except as otherwise provided in paragraph
(d)(4)(iv) or (d)(6) of this section. The default Hg concentration
value shall be updated as appropriate, according to paragraph (d)(5) of
this section.
* * * * *
    (4) * * *
    (iv) An additional retest is required when there is a change in the
fuel supply. The retest shall be performed within 720 unit operating
hours of the change.
    (5) The default Hg concentration used for reporting under Sec.
75.84 shall be updated after each required retest. This includes
retests that are required prior to the compliance date in Sec.
75.80(b). The updated value shall either be the highest Hg
concentration measured in any of the test runs or 0.50 [mu]g/scm,
whichever is greater. The updated value shall be applied beginning with
the first unit operating hour in which Hg emissions data are required
to be reported after completion of the retest, except as provided in
paragraph (d)(4)(iv) of this section, where the need to retest is
triggered by a change in the fuel supply. In that case, apply the
updated default Hg concentration beginning with the first unit
operating hour in which Hg emissions are required to be reported after
the date and hour of the fuel switch.
* * * * *
    (e) * * *
    (1) The methodology may not be used for reporting Hg mass emissions
at a common stack unless all of the units using the common stack are
affected units and each individual unit is tested to demonstrate that
its potential to emit does not exceed 464 ounces of Hg per year, in
accordance with paragraphs (c) and (d) of this section. If the units
sharing the common stack qualify as a group of identical units in
accordance with Sec.  75.19(c)(1)(iv)(B), the owner or operator may
test a subset of the units in lieu of testing each unit individually.
If this option is selected, the number of units required to be tested
shall be determined from Table LM-4 in Sec.  75.19. If the test results
demonstrate that the units sharing the common stack qualify as low mass
emitters, the default Hg concentration used for reporting Hg mass
emissions at the common stack shall either be the highest value
obtained in any test run for any of the tested units serving the common
stack or 0.50 [mu]g/scm, whichever is greater. Notwithstanding these
requirements, the emission testing required under paragraphs (c) and/or
(d)(3) of this section may be performed at the common stack in the
following circumstances:
    (i) The initial certification testing required under paragraph (c)
of this section may be performed at the common stack if all of the
units using the stack are affected units and if, prior to entering the
common stack, the effluent gas streams from the individual units are
combined together upstream of an emission control device that reduces
the Hg concentration. If this testing option is chosen:
    (A) The testing must be done at a combined load corresponding to
the designated normal load level (low, mid, or high) for the units
sharing the common stack, in accordance with section <IP_ADDRESS> of
appendix A to this part;
    (B) All of the units that share the stack must be operating in a
normal, stable manner and at typical load levels during the emission
testing;
    (C) When calculating E, the estimated maximum potential annual Hg
mass emissions from the stack, the maximum potential flow rate through
the common stack (as defined in the monitoring plan) and the highest
concentration from any test run (or 0.50 [mu]g/scm, if greater) shall
be substituted into Equation 1;
    (D) The calculated value of E shall be divided by the number of
units sharing the stack. If the result, when rounded to the nearest
ounce, does not exceed 464 ounces, the units qualify to use the low
mass emission methodology; and
    (E) If the units qualify to use the methodology, the default Hg
concentration used for reporting at the common stack shall be the
highest value obtained in any test run or 0.50 [mu]g/scm, whichever is
greater; or
    (ii) For all common stack configurations, the retests required
under paragraph (d)(3) of this section may be done at the common stack.
If this testing option is chosen, the testing shall be done at a
combined load corresponding to the designated normal

load level (low, mid, or high) for the units sharing the common stack,
in accordance with section <IP_ADDRESS> of appendix A to this part. The due
date for the next retest shall be determined as follows:
    (A) To calculate E, the maximum potential flow rate for the common
stack (as defined in the monitoring plan) and the highest Hg
concentration from any test run (or 0.50 [mu]g/scm, if greater) shall
be substituted into Equation 1;
    (B) If the value of E obtained from Equation 1, rounded to the
nearest ounce, is greater than 144 times the number of units sharing
the common stack, but less than or equal to 464 times the number of
units sharing the stack, the next retest is due in two QA operating
quarters;
    (C) If the value of E obtained from Equation 1, rounded to the
nearest ounce, is less than or equal to 144 times the number of units
sharing the common stack, the next retest is due in four QA operating
quarters.
* * * * *
    36. Section 75.82 is amended by adding paragraphs (b)(3), (c)(4),
and (d)(3) to read as follows:

Sec.  75.82  Monitoring of Hg mass emissions and heat input at common
and multiple stacks.

* * * * *
    (b) * * *
    (3) If the monitoring option in paragraph (b)(2) of this section is
selected, and if heat input is required to be reported under the
applicable State or Federal Hg mass emission reduction program that
adopts the requirements of this subpart, the owner or operator shall
either:
    (i) Apportion the common stack heat input rate to the individual
units according to the procedures in Sec.  75.16(e)(3); or
    (ii) Install a flow monitoring system and a diluent gas
(O2 or CO2) monitoring system in the duct leading
from each affected unit to the common stack, and measure the heat input
rate in each duct, according to section 5.2 of appendix F to this part.
    (c) * * *
    (4) If the monitoring option in paragraph (c)(1) or (c)(2) of this
section is selected, and if heat input is required to be reported under
the applicable State or Federal Hg mass emission reduction program that
adopts the requirements of this subpart, the owner or operator shall:
    (i) Use the installed flow and diluent monitors to determine the
hourly heat input rate at each stack (mmBtu/hr), according to section
5.2 of appendix F to this part; and
    (ii) Calculate the hourly heat input at each stack (in mmBtu) by
multiplying the measured stack heat input rate by the corresponding
stack operating time; and
    (iii) Determine the hourly unit heat input by summing the hourly
stack heat input values.
    (d) * * *
    (3) If the monitoring option in paragraph (d)(1) or (d)(2) of this
section is selected, and if heat input is required to be reported under
the applicable State or Federal Hg mass emission reduction program that
adopts the requirements of this subpart, the owner or operator shall:
    (i) Use the installed flow and diluent monitors to determine the
hourly heat input rate at each stack or duct (mmBtu/hr), according to
section 5.2 of appendix F to this part; and
    (ii) Calculate the hourly heat input at each stack or duct (in
mmBtu) by multiplying the measured stack (or duct) heat input rate by
the corresponding stack (or duct) operating time; and
    (iii) Determine the hourly unit heat input by summing the hourly
stack (or duct) heat input values.
    37. Section 75.84 is amended by:
    a. Removing ``Sec.  75.53(e)(1)'' and ``Sec.  75.53(e)(2)'' and
adding in their place ``Sec.  75.53(g)(1)'' and ``Sec.  75.53(g)(2)'',
respectively, in paragraph (c)(3);
    b. Removing the number ``45'' and adding in its place the number
``21'' in paragraphs (e)(1) and (e)(2);
    c. Revising paragraph (f)(1) introductory text;
    d. Removing ``Sec.  75.64(a)(1)'' and adding in its place ``Sec.
75.64(a)(3)'' in paragraph (f)(1)(i);
    e. Replacing the phrase ``paragraph (a)'' with the phrase
``paragraphs (a) and (b)'' in paragraph (f)(1)(ii) introductory text;
    f. Revising paragraph (f)(1)(ii)(I).
    The revisions read as follows:

Sec.  75.84  Recordkeeping and reporting.

* * * * *
    (f) * * *
    (1) Electronic submission. Electronic quarterly reports shall be
submitted, beginning with the calendar quarter containing the
compliance date in Sec.  75.80(b), unless otherwise specified in the
final rule implementing a State or Federal Hg mass emissions reduction
program that adopts the requirements of this subpart. The designated
representative for an affected unit shall report the data and
information in this paragraph (f)(1) and the applicable compliance
certification information in paragraph (f)(2) of this section to the
Administrator quarterly, except as otherwise provided in Sec.  75.64(a)
for units in long-term cold storage. Each electronic report must be
submitted to the Administrator within 30 days following the end of each
calendar quarter. Except as otherwise provided in Sec. Sec.
75.64(a)(4) and (a)(5), each electronic report shall include the date
of report generation and the following information for each affected
unit or group of units monitored at a common stack:
* * * * *
    (ii) * * *
    (I) Supplementary RATA information required under Sec.
75.59(a)(7), except that:
    (1) The applicable data elements under Sec.  75.59(a)(7)(ii)(A)
through (T) and under Sec.  75.59(a)(7)(iii)(A) through (M) shall be
reported for flow RATAs at circular or rectangular stacks (or ducts) in
which angular compensation for yaw and/or pitch angles is used (i.e.,
Method 2F or 2G), with or without wall effects adjustments;
    (2) The applicable data elements under Sec.  75.59(a)(7)(ii)(A)
through (T) and under Sec.  75.59(a)(7)(iii)(A) through (M) shall be
reported for any flow RATA run at a circular stack in which Method 2 is
used and a wall effects adjustment factor is determined by direct
measurement;
    (3) The data under Sec.  75.59(a)(7)(ii)(T) shall be reported for
all flow RATAs at circular stacks in which Method 2 is used and a
default wall effects adjustment factor is applied; and
    (4) The data under Sec.  75.59(a)(7)(ix)(A) through (F) shall be
reported for all flow RATAs at rectangular stacks or ducts in which
Method 2 is used and a wall effects adjustment factor is applied.
* * * * *
    38. Appendix A to Part 75 is amended by:
    a. Revising paragraph (c) of section <IP_ADDRESS>;
    b. Revising paragraph (b)(2) of section <IP_ADDRESS>;
    c. Revising paragraph (b)(2) of section <IP_ADDRESS>; and
    d. Adding a new fourth sentence after the third sentence of section
2.1.3.
    e. Revising paragraph (3) of section 3.2;
    f. Replacing the phrase ``continuous emission monitoring
system(s)'' with the phrase ``monitoring component of a continuous
emission monitoring system that is'' in section 3.5;
    g. Revising section 5.1;
    h. Redesignating section 6.1 as section 6.1.1;
    i. Adding new sections 6.1 and 6.1.2;
    j. Revising the second and third sentences and adding a new fourth
sentence to section 6.2, introductory text;

    k. Replacing the words ``section 2.6'' with the words ``section
2.2.1'', in paragraph (g) of section 6.2;
    l. Adding paragraph (h) to section 6.2;
    m. Adding a new fourth sentence to section 6.3.1, introductory
text;
    n. Revising the introductory text of section 6.4;
    o. Removing the words ``that uses CEMS to account for its emissions
and for each unit that uses the optional fuel flow-to-load quality
assurance test in section 2.1.7 of appendix D to this part'' from
paragraph (a) of section <IP_ADDRESS>;
    p. Adding the words ``or mmBtu/hr'' after the words ``klb/hr of
steam production'', and by adding the words ``or mmBtu/hr of thermal
output'' after the words ``thousands of lb/hr of steam load'' in
paragraph (a)(1) of section <IP_ADDRESS>;
    q. Adding the words ``and units using the low mass emissions (LME)
excepted methodology under Sec.  75.19'' after the words ``(except for
peaking units'' in the second sentence in paragraph (c) of section
<IP_ADDRESS>;
    r. Adding the words ``and LME units'' after the words ``For peaking
units'' in the third sentence of paragraph (d)(1) of section <IP_ADDRESS>;
    s. Replacing the words ``quarterly report'' in the first sentence
with the words ``monitoring plan'', by adding the words ``or mmBtu/hr''
after the term ``lb/hr'', by replacing the number ``75.64'' with the
number ``75.53'', by adding the words ``and LME units'' after the words
``Except for peaking units'', and by revising the words ``electronic
quarterly report (as part of the electronic monitoring plan)'' to read
``electronic monitoring plan'' in paragraph (e) of section <IP_ADDRESS>;
    t. Replacing all occurrences of the words ``section 3.2'' with the
words ``section 8.1.3'' in paragraph (b)(3) of section 6.5.6, paragraph
(a) of section <IP_ADDRESS>, and paragraph (a) of section <IP_ADDRESS>;
    u. Adding the words ``and the same type of sorbent material'' after
the words ``same-size trap'' in the third-to-last sentence of section
6.5.7, paragraph (a);
    v. Revising section 6.5.10;
    w. Adding a sentence at the end of section 7.6.1;
    x. Revising the words ``scfh/megawatts or scfh/1000 lb/hr of
steam'' to read ``scfh/megawatts, scfh/1000 lb/hr of steam, or scfh/
(mmBtu/hr of steam output)'' at the end of the Rref variable
definition, and by revising the words ``megawatts or 1000 lb/hr of
steam,'' to read ``megawatts, 1000 lb/hr of steam, or mmBtu/hr thermal
output'' at the end of the Lavg variable definition in
paragraph (a) of section 7.7; and
    y. Revising the words ``Btu/kwh or Btu/lb steam load'' to read
``Btu/kwh, Btu/lb steam load, or mmBtu heat input/mmBtu steam output''
in the (GHR)ref variable definition, and by revising the
words ``megawatts or 1000 lb/hr of steam'' to read ``megawatts, 1000
lb/hr of steam, or mmBtu/hr thermal output'' at the end of the
Lavg variable definition, in paragraph (c) of section 7.7.
    The revisions and additions read as follows:

Appendix A to Part 75--Specifications and Test Procedures

* * * * *

2. Equipment Specifications

<IP_ADDRESS> Maximum Potential Concentration

* * * * *
    (c) When performing fuel sampling to determine the MPC, use ASTM
Methods: ASTM D3177-89 (1997), ``Standard Test Methods for Total
Sulfur in the Analysis Sample of Coal and Coke''; ASTM D4239-02,
``Standard Test Methods for Sulfur in the Analysis Sample of Coal
and Coke Using High Temperature Tube Furnace Combustion Methods'';
ASTM D4294-98, ``Standard Test Method for Sulfur in Petroleum
Products by Energy-Dispersive X-Ray Fluorescence Spectroscopy'';
ASTM D1552-01, ``Standard Test Method for Sulfur in Petroleum
Products (High Temperature Method)''; ASTM D129-00, ``Standard Test
Method for Sulfur in Petroleum Products (General Bomb Method)'';
ASTM D2622-98, ``Standard Test Method for Sulfur in Petroleum
Products by X-Ray Spectrometry'' for sulfur content of solid or
liquid fuels; ASTM D3176-89 (1997)e1, ``Standard Practice for
Ultimate Analysis of Coal and Coke''; ASTM D240-00 (Reapproved
1991), ``Standard Test Method for Heat of Combustion of Liquid
Hydrocarbon Fuels by Bomb Calorimeter''; or ASTM D5865-01ae1,
``Standard Test Method for Gross Calorific Value of Coal and Coke''
(incorporated by reference under Sec.  75.6).
* * * * *
    <IP_ADDRESS> * * *
    (b) * * *
    (2) For units with two SO2 spans and ranges, if the
low range is exceeded, no further action is required, provided that
the high range is available and its most recent calibration error
test and linearity check have not expired. However, if either of
these quality assurance tests has expired and the high range is not
able to provide quality assured data at the time of the low range
exceedance or at any time during the continuation of the exceedance,
report the MPC as the SO2 concentration until the
readings return to the low range or until the high range is able to
provide quality assured data (unless the reason that the high-scale
range is not able to provide quality assured data is because the
high-scale range has been exceeded; if the high-scale range is
exceeded follow the procedures in paragraph (b)(1) of this section).
* * * * *
    <IP_ADDRESS> * * *
    (b) * * *
    (2) For units with two NOX spans and ranges, if the
low range is exceeded, no further action is required, provided that
the high range is available and its most recent calibration error
test and linearity check have not expired. However, if either of
these quality assurance tests has expired and the high range is not
able to provide quality assured data at the time of the low range
exceedance or at any time during the continuation of the exceedance,
report the MPC as the NOX concentration until the
readings return to the low range or until the high range is able to
provide quality assured data (unless the reason that the high-scale
range is not able to provide quality assured data is because the
high-scale range has been exceeded; if the high-scale range is
exceeded follow the procedures in paragraph (b)(1) of this section).
* * * * *

2.1.3 CO2 and O2 Monitors

    * * * An alternative CO2 span value below 6.0 percent
may be used if an appropriate technical justification is included in
the hardcopy monitoring plan.
* * * * *
    3.2 * * *
    (3) For the linearity check and the 3-level system integrity
check of an Hg monitor, which are required, respectively, under
Sec. Sec.  75.20(c)(1)(ii) and (c)(1)(vi), the measurement error
shall not exceed 5.0 percent of the span value at any of the three
gas levels. To calculate the measurement error at each level, take
the absolute value of the difference between the reference value and
mean CEM response, divide the result by the span value, and then
multiply by 100. Alternatively, the results at any gas level are
acceptable if the absolute value of the difference between the
average monitor response and the average reference value, i.e.,
[bond] R-A [bond] in Equation A-4 of this appendix, does not exceed
0.6 [mu]g/m\3\. The principal and alternative performance
specifications in this section also apply to the single-level system
integrity check described in section 2.6 of appendix B to this part.
* * * * *
    5.1 Reference Gases.
    For the purpose of part 75, calibration gases include the
following:

5.1.1 EPA Protocol Gases

    (a) An EPA Protocol Gas is a calibration gas mixture prepared
and analyzed according to Section 2 of the ``EPA Traceability
Protocol for Assay and Certification of Gaseous Calibration
Standards,'' September 1997, EPA-600/R-97/121 or such revised
procedure as approved by the Administrator (EPA Traceability
Protocol).
    (b) An EPA Protocol Gas must have a specialty gas producer-
certified uncertainty (95-percent confidence interval) that must not
be greater than 2.0 percent of the certified concentration (tag
value) of the gas mixture. The uncertainty must be calculated using
the statistical procedures (or equivalent statistical techniques)
that are listed in Section 2.1.8 of the EPA Traceability Protocol.

    (c) A specialty gas producer advertising calibration gas
certification with the EPA Traceability Protocol or distributing
calibration gases as ``EPA Protocol Gas'' must participate in the
EPA Protocol Gas Verification Program (PGVP) described in Section
2.1.10 of the EPA Traceability Protocol or it cannot use ``EPA'' in
any form of advertising for these products, unless approved by the
Administrator. A specialty gas producer may not certify a
calibration gas as an EPA Protocol Gas unless it participates in the
PGVP, unless approved by the Administrator.
    (d) A copy of EPA-600/R-97/121 is available from the National
Technical Information Service, 5285 Port Royal Road, Springfield,
VA,<PHONE_NUMBER> or http://www.ntis.gov, and from http://www.epa.gov/ttn/emc/news.html or http://www.epa.gov/appcdwww/tsb/

index.html.

5.1.2 Mercury Standards

    For 7-day calibration error tests of Hg concentration monitors
and for daily calibration error tests of Hg monitors, either
elemental Hg standards or a NIST-traceable source of oxidized Hg may
be used. For linearity checks, elemental Hg standards shall be used.
For 3-level and single-point system integrity checks under Sec.
75.20(c)(1)(vi), sections 6.2(g) and 6.3.1 of this appendix, and
sections 2.1.1, 2.2.1 and 2.6 of appendix B to this part, a NIST-
traceable source of oxidized Hg shall be used. Alternatively, other
NIST-traceable standards may be used for the required checks,
subject to the approval of the Administrator.

5.1.3 Zero Air Material

    (a) A calibration gas certified by the specialty gas producer or
vendor not to contain concentrations of SO2,
NOX, or total hydrocarbons above 0.1 parts per million
(ppm), a concentration of CO above 1 ppm, or a concentration of
CO2 above 400 ppm;
    (b) Ambient air conditioned and purified by a CEMS for which the
CEMS manufacturer or vendor certifies that the particular CEMS model
produces conditioned gas that does not contain concentrations of
SO2, NOX, or total hydrocarbons above 0.1 ppm,
a concentration of CO above 1 ppm, or a concentration of
CO2 above 400 ppm;
    (c) For dilution-type CEMS, conditioned and purified ambient air
provided by a conditioning system concurrently supplying dilution
air to the CEMS; or
    (d) A multi-component mixture certified by the supplier of the
mixture that the concentration of the component being zeroed is less
than or equal to the applicable concentration specified in paragraph
(a) of this section, and that the mixture's other components do not
interfere with the CEM readings.
* * * * *

6.1 General Requirements

* * * * *

6.1.2 Requirements for Air Emission Testing Bodies

    (a) Any Air Emission Testing Body (AETB) conducting relative
accuracy test audits of CEMS and sorbent trap monitoring systems
under this part must conform to the requirements of ASTM D7036-04.
This section is not applicable to daily operation, daily calibration
error checks, daily flow interference checks, quarterly linearity
checks or routine maintenance of CEMS.
    (b) The AETB shall provide to the affected source(s)
certification that the AETB operates in conformance with, and that
data submitted to the Agency has been collected in accordance with,
the requirements of ASTM D7036-04. This certification may be
provided in the form of:
    (1) A certificate of accreditation of relevant scope issued by a
recognized, national accreditation body; or
    (2) A letter of certification signed by a member of the senior
management staff of the AETB.
    (c) The AETB shall either provide a Qualified Individual on-site
to conduct or shall oversee all relative accuracy testing carried
out by the AETB as required in ASTM D7036-04. The Qualified
Individual shall provide the affected source(s) with copies of the
qualification credentials relevant to the scope of the testing
conducted.
* * * * *

6.2 Linearity Check (General Procedures)

    * * * Notwithstanding these requirements, if the SO2
or NOX span value for a particular monitor range is <=30
ppm, that range is exempted from the linearity check requirements of
this part, both for initial certification and for on-going quality-
assurance. For units with two measurement ranges (high and low) for
a particular parameter, perform a linearity check on both the low
scale (except for SO2 or NOX span values <=30
ppm) and the high scale. Note that for a NOX-diluent
monitoring system with two NOX measurement ranges, if the
low NOX scale has a span value <=30 ppm and is exempt
from linearity checks, this does not exempt either the diluent
monitor or the high NOX scale (if the span is >30 ppm)
from linearity check requirements.
* * * * *
    (g) For Hg monitors, follow the guidelines in section 2.2.3 of
this appendix in addition to the applicable procedures in section
6.2 when performing the system integrity checks described in Sec.
75.20(c)(1)(vi) and in sections 2.1.1, 2.2.1 and 2.6 of appendix B
to this part.
    (h) For Hg concentration monitors, if moisture is added to the
calibration gas during the required linearity checks or system
integrity checks, and if the Hg monitor measures on a dry basis, the
moisture content of the calibration gas must be accounted for. Under
these circumstances, the dry basis concentration of the calibration
gas shall be used to calculate the linearity error or measurement
error (as applicable).
* * * * *

6.3.1 Gas Monitor 7-Day Calibration Error Test

    * * * Also for Hg monitors, if moisture is added to the
calibration gas and the monitoring system measures Hg concentration
on a dry basis, the added moisture must be accounted for and the
dry-basis concentration of the calibration gas shall be used to
calculate the calibration error.
* * * * *

6.4 Cycle Time Test

    Perform cycle time tests for each pollutant concentration
monitor and continuous emission monitoring system while the unit is
operating, according to the following procedures (see also Figure 6
at the end of this appendix). Use a zero-level and a high-level
calibration gas (as defined in section 5.2 of this appendix)
alternately. To determine the upscale elapsed time, inject a zero-
level concentration calibration gas into the probe tip (or injection
port leading to the calibration cell, for in situ systems with no
probe). Record the stable starting gas value and start time, using
the data acquisition and handling system (DAHS). Next, allow the
monitor to measure the concentration of flue gas emissions until the
response stabilizes. Record the stable ending stack emissions value
and the end time of the test using the DAHS. Determine the upscale
elapsed time as the time it takes for 95.0 percent of the step
change to be achieved between the stable starting gas value and the
stable ending stack emissions value. Then repeat the procedure,
starting by injecting the high-level gas concentration to determine
the downscale elapsed time, which is the time it takes for 95.0
percent of the step change to be achieved between the stable
starting gas value and the stable ending stack emissions value. End
the downscale test by measuring the stable concentration of flue gas
emissions. Record the stable starting and ending monitor values, the
start and end times, and the downscale elapsed time for the monitor
using the DAHS. A stable value is equivalent to a reading with a
change of less than 2.0 percent of the span value for 2 minutes, or
a reading with a change of less than 6.0 percent from the measured
average concentration over 6 minutes. Alternatively, the reading is
considered stable if it changes by no more than 0.5 ppm or 0.2%
CO2 or O2 (as applicable) for two minutes.
(Owners or operators of systems which do not record data in 1-minute
or 3-minute intervals may petition the Administrator under Sec.
75.66 for alternative stabilization criteria). For monitors or
monitoring systems that perform a series of operations (such as
purge, sample, and analyze), time the injections of the calibration
gases so they will produce the longest possible cycle time. Report
the slower of the two elapsed times (upscale or downscale) as the
cycle time for the analyzer. (See Figure 5 at the end of this
appendix.) Prior to January 1, 2009 for the NOX-diluent
continuous emission monitoring system test, either record and report
the longer cycle time of the two component analyzers as the system
cycle time or record the cycle time for each component analyzer
separately (as applicable). On and after January 1, 2009, record the
cycle time for each component analyzer separately. For time-shared
systems, perform the cycle time tests at each probe locations that
will be polled within the same 15-minute period during monitoring
system operations. To determine the cycle time for time-shared
systems, at each monitoring location, report the sum of the cycle
time

observed at that monitoring location plus the sum of the time
required for all purge cycles (as determined by the continuous
emission monitoring system manufacturer) at each of the probe
locations of the time-shared systems. For monitors with dual ranges,
report the test results from on the range giving the longer cycle
time. Cycle time test results are acceptable for monitor or
monitoring system certification, recertification or diagnostic
testing if none of the cycle times exceed 15 minutes. The status of
emissions data from a monitor prior to and during a cycle time test
period shall be determined as follows:
* * * * *

6.5.10 Reference Methods

    The following methods from appendix A to part 60 of this chapter
or their approved alternatives are the reference methods for
performing relative accuracy test audits: Method 1 or 1A for siting;
Method 2 or its allowable alternatives in appendix A to part 60 of
this chapter (except for Methods 2B and 2E) for stack gas velocity
and volumetric flow rate; Methods 3, 3A or 3B for O2 and
CO2; Method 4 for moisture; Methods 6, 6A or 6C for
SO2; Methods 7, 7A, 7C, 7D or 7E for NOX,
excluding the exceptions of Method 7E identified in Sec.
75.22(a)(5); and either the Ontario Hydro Method, Method 29 in
appendix A-8 to part 60 of this chapter, or an approved instrumental
method for Hg (see Sec.  75.22).
* * * * *

7.6 Bias Test and Adjustment Factor

* * * * *
    7.6.1 * * * To calculate bias for a Hg monitoring system when
using the Ontario Hydro Method or Method 29 in appendix A-8 to part
60 of this chapter, ``d'' is, for each data point, the difference
between the average Hg concentration value (in [mu]g/m3)
from the paired Ontario Hydro or Method 29 sampling trains and the
concentration measured by the monitoring system. For sorbent trap
monitoring systems, use the average Hg concentration measured by the
paired traps in the calculation of ``d''.
* * * * *
    39. Appendix B to Part 75 is amended by:
    a. adding section 1.1.4;
    b. Revising section 2.1.1;
    c. Revising paragraph (2) of section <IP_ADDRESS>;
    d. Revising paragraph (2) of section <IP_ADDRESS>;
    e. Adding paragraph (3) to section <IP_ADDRESS>;
    f. Adding a new fourth sentence to paragraph (e) of section 2.2.3;
    g. Revising the words ``scfh/megawatts or scfh/1000 lb/hr of steam
load'' to read ``scfh/megawatts, scfh/1000 lb/hr of steam load, or
scfh/(mmBtu/hr thermal output)'' at the end of the Rh
variable definition, and by revising the words ``megawatts or 1000 lb/
hr of steam'' to read ``megawatts, 1000 lb/hr of steam, or mmBtu/hr
thermal output'' in the Lh variable definition, in paragraph
(a) of section 2.2.5;
    h. Revising the words Btu/kwh or Btu/lb steam load'' to read ``Btu/
kwh, Btu/lb steam load, mmBtu heat input/mmBtu thermal output'' in the
(GHR)h variable definition, and by revising the words
``megawatts or 1000 lb/hr of steam'' to read ``megawatts, 1000 lb/hr of
steam, or mmBtu/hr thermal output'' in the Lh variable
definition, in paragraph (a)(2) of section 2.2.5;
    i. Replacing the word ``five'' with the word ``twenty'', and by
replacing the word ``years'' with the word ``quarters'', in paragraph
(c)(4) of section <IP_ADDRESS>;
    j. Revising paragraph (g) of section 2.3.2;
    k. Revising paragraphs (a)(2) and (c) of section 2.3.3;
    l. Adding paragraph (d) to section 2.3.3;
    m. Revising section 2.6; and
    n. Replacing the term ``dscm'' with ``scm'' in Figure 2.
    The revisions and additions read as follows:

Appendix B to Part 75--Quality Assurance and Quality Control Procedures

1. Quality Assurance/Quality Control Program

* * * * *
    1.1.4 The requirements in section 6.1.2 of appendix A to this
part shall be met by any Air Emissions Testing Body (AETB)
performing the semiannual/annual RATAs described in section 2.3 of
this appendix and the periodic Hg emission tests described in
Sec. Sec.  75.81(c)(1) and 75.81(d)(4)(iii).
* * * * *

2. Frequency of Testing

* * * * *

2.1.1 Calibration Error Test

    Except as provided in section <IP_ADDRESS> of this appendix, perform
the daily calibration error test of each gas monitoring system
(including moisture monitoring systems consisting of wet- and dry-
basis O2 analyzers) according to the procedures in
section 6.3.1 of appendix A to this part, and perform the daily
calibration error test of each flow monitoring system according to
the procedure in section 6.3.2 of appendix A to this part. When two
measurement ranges (low and high) are required for a particular
parameter, perform sufficient calibration error tests on each range
to validate the data recorded on that range, according to the
criteria in section 2.1.5 of this appendix.
* * * * *
    <IP_ADDRESS> * * *
    (2) For each monitoring system that has passed the off-line
calibration demonstration, off-line calibration error tests may be
used on a limited basis to validate data, in accordance with
paragraph (2) in section <IP_ADDRESS> of this appendix.
    <IP_ADDRESS> * * *
    (2) For a monitor that has passed the off-line calibration
demonstration, off-line calibration error tests may be used to
validate data from the monitor for up to 26 consecutive unit or
stack operating hours, after which data from the monitor become
invalid until an on-line calibration error test of the monitor is
passed. Once the required on-line calibration error test has been
passed, another 26 operating hour cycle of data validation using
off-line calibration error tests may begin. Each off-line
calibration error test that is used for data validation has a
prospective data validation window of 26 clock hours, as described
in section 2.1.5 of this appendix. If the sequence of consecutive
operating hours validated by off-line calibrations is broken before
reaching the 26th consecutive unit or stack operating hour, data
from the monitor become invalid and an on-line calibration error
test must be passed to re-establish the quality-assured data status.
The sequence is considered broken when a unit or stack operating
hour is not contained within the 26 clock hour data validation
window of a passed off-line calibration error test.
    (3) For units with two measurement ranges (low and high) for a
particular parameter, when separate analyzers are used for the low
and high ranges, a failed or expired calibration on one of the
ranges does not affect the quality-assured data status on the other
range. For a dual-range analyzer (i.e., a single analyzer with two
measurement scales), a failed calibration error test on either the
low or high scale results in an out-of-control period for the
monitor. Data from the monitor remain invalid until corrective
actions are taken and ``hands-off'' calibration error tests have
been passed on both ranges. However, if the most recent calibration
error test on the high scale has expired, while the low scale is up-
to-date on its calibration error test requirements (or vice-versa),
the expired calibration error test does not affect the quality-
assured status of the data recorded on the other scale.
* * * * *
    2.2.3 * * *
    (e) * * * For a dual-range analyzer, ``hands-off'' linearity
checks must be passed on both measurement scales to end the out-of-
control period.
* * * * *
    2.3.2 * * *
    (g) Data validation for failed RATAs for a CO2
pollutant concentration monitor (or an O2 monitor used to
measure CO2 emissions), a NOX pollutant
concentration monitor, and a NOX-diluent monitoring
system shall be done according to paragraphs (g)(1) and (g)(2) of
this section:
    (1) For a CO2 pollutant concentration monitor (or an
O2 monitor used to measure CO2 emissions)
which also serves as the diluent component in a NOX-
diluent monitoring system, if the CO2 (or O2)
RATA is failed, then both the O2 (or O2)
monitor and the associated NOX-diluent system are
considered out-of-control, beginning with the hour of completion of
the failed CO2 (or O2) monitor RATA, and
continuing until the hour of completion of subsequent hands-off
RATAs which demonstrate that both systems

have met the applicable relative accuracy specifications in sections
3.3.2 and 3.3.3 of appendix A to this part, unless the option in
paragraph (b)(3) of this section to use the data validation
procedures and associated timelines in Sec. Sec.  75.20(b)(3)(ii)
through (b)(3)(ix) has been selected, in which case the beginning
and end of the out-of-control period shall be determined in
accordance with Sec. Sec.  75.20(b)(3)(vii)(A) and (B).
    (2) This paragraph (g)(2) applies only to a NOX
pollutant concentration monitor that serves both as the
NOX component of a NOX concentration
monitoring system (to measure NOX mass emissions) and as
the NOX component in a NOX-diluent monitoring
system (to measure NOX emission rate in lb/mmBtu). If the
RATA of the NOX concentration monitoring system is
failed, then both the NOX concentration monitoring system
and the associated NOX-diluent monitoring system are
considered out-of-control, beginning with the hour of completion of
the failed NOX concentration RATA, and continuing until
the hour of completion of subsequent hands-off RATAs which
demonstrate that both systems have met the applicable relative
accuracy specifications in sections 3.3.2 and 3.3.7 of appendix A to
this part, unless the option in paragraph (b)(3) of this section to
use the data validation procedures and associated timelines in
Sec. Sec.  75.20(b)(3)(ii) through (b)(3)(ix) has been selected, in
which case the beginning and end of the out-of-control period shall
be determined in accordance with Sec. Sec.  75.20(b)(3)(vii)(A) and
(B).
* * * * *

2.3.3 RATA Grace Period

    (a) * * *
    (2) A required 3-load flow RATA has not been performed by the
end of the calendar quarter in which it is due; or
* * * * *
    (c) If, at the end of the 720 unit (or stack) operating hour
grace period, the RATA has not been completed, data from the
monitoring system shall be invalid, beginning with the first unit
operating hour following the expiration of the grace period. Data
from the CEMS remain invalid until the hour of completion of a
subsequent hands-off RATA. The deadline for the next test shall be
either two QA operating quarters (if a semiannual RATA frequency is
obtained) or four QA operating quarters (if an annual RATA frequency
is obtained) after the quarter in which the RATA is completed, not
to exceed eight calendar quarters.
* * * * *
    (d) When a RATA is done during a grace period in order to
satisfy a RATA requirement from a previous quarter, the deadline for
the next RATA shall be determined as follows:
    (1) If the grace period RATA qualifies for a reduced, (i.e.,
annual), RATA frequency the deadline for the next RATA shall be set
at three QA operating quarters after the quarter in which the grace
period test is completed.
    (2) If the grace period RATA qualifies for the standard, (i.e.,
semiannual), RATA frequency the deadline for the next RATA shall be
set at two QA operating quarters after the quarter in which the
grace period test is completed.
    (3) Notwithstanding these requirements, no more than eight
successive calendar quarters shall elapse after the quarter in which
the grace period test is completed, without a subsequent RATA having
been conducted.
* * * * *

2.6 System Integrity Checks for Hg Monitors

    For each Hg concentration monitoring system (except for a Hg
monitor that does not have a converter), perform a single-point
system integrity check weekly, i.e., at least once every 168 unit or
stack operating hours, using a NIST-traceable source of oxidized Hg.
Perform this check using a mid-or high-level gas concentration, as
defined in section 5.2 of appendix A to this part. The performance
specifications in paragraph (3) of section 3.2 of appendix A to this
part must be met, otherwise the monitoring system is considered out-
of-control, from the hour of the failed check until a subsequent
system integrity check is passed. If a required system integrity
check is not performed and passed within 168 unit or stack operating
hours of last successful check, the monitoring system shall also be
considered out of control, beginning with the 169th unit or stack
operating hour after the last successful check, and continuing until
a subsequent system integrity check is passed. This weekly check is
not required if the daily calibration assessments in section 2.1.1
of this appendix are performed using a NIST-traceable source of
oxidized Hg.
* * * * *
    40. Appendix D to Part 75 is amended by:
    a. Revising section <IP_ADDRESS>;
    b. Removing all ``'' symbols from paragraph (c) of
section <IP_ADDRESS>;
    c. Revising the Rbase and Lavg variable
definitions in paragraph (a) of section <IP_ADDRESS>;
    d. Revising the words ``Btu/kwh or Btu/lb steam load'' to read
``Btu/kwh, Btu/lb steam load, or mmBtu heat input/mmBtu thermal
output'' in the (GHR)base variable definition, and by
revising the words ``megawatts or 1000 lb/hr of steam'' to read
``megawatts, 1000 lb/hr of steam, or mmBtu/hr thermal output'' in the
Lavg variable definition, in paragraph (c) of section
<IP_ADDRESS>;
    e. Removing the word ``or'' and adding the phrase'',100 scfh/
(mmBtu/hr of steam load), or (lb/hr)/(mmBtu/hr thermal output )'' at
the end of the Rh variable definition, and by replacing the
phrase ``megawatts or 1000 lb/hr of steam'' with the phrase
``megawatts, 1000 lb/hr of steam, or mmBtu /hr thermal output'' in the
Lh variable definition, in paragraph (a) of section <IP_ADDRESS>;
    f. Replacing the phrase the ``Btu/kwh or Btu/lb steam load'' with
the phrase ``Btu/kwh, Btu/lb steam load, or mmBtu heat input/mmBtu
thermal output'' in the (GHR)h variable definition; and by
replacing the phrase ``megawatts or 1000 lb/hr of steam'' with the
phrase ``megawatts, 1000 lb/hr of steam, or mmBtu/hr thermal output''
in the Lh variable definition, in paragraph (c) of section
<IP_ADDRESS>;
    g. Replacing ``D4177-82 (Reapproved 1990)'' with ``D4177-95
(2000)'', in the first sentence of section 2.2.3;
    h. Replacing ``D4057-88'' with ``D4057-95 (2000)'', in sections
<IP_ADDRESS> and <IP_ADDRESS>, and in paragraph (c) of section <IP_ADDRESS>;
    i. Revising sections 2.2.5, 2.2.6, and 2.2.7;
    j. Revising paragraphs (a)(2) and (e) of section <IP_ADDRESS>;
    k. Revising section <IP_ADDRESS>.2;
    l. Replacing the identifier ``D1826-88'' with the identifier
``D1826-94 (1998)'', by replacing the identifier ``D3588-91'' with the
identifier ``D3588-98'', by adding the number ``(2001)'' after the
identifier ``ASTM D4891-89'', by replacing the numbers ``2172-86'' with
the numbers ``2172-1996'', and by replacing the numbers ``2261-90''
with the numbers ``2261-1999'', in section 2.3.4;
    m. Adding two sentences at the end of section <IP_ADDRESS>;
    n. Replacing the phrase ``Gas Total Sulfur Content'' in the
``Parameter'' column of Table D-6 with the phrase ``Gas Total Sulfur
Content*'', and adding the following footnote beneath the Table `` *
Required no later than July 1, 2003''; and
    o. Replacing the words ``(Reapproved 1990)'' with the words
``(1997)e1'' in section 3.2.2.
    The revisions and additions read as follows:

Appendix D to Part 75--Optional SO2 Emissions Data Protocol
for Gas-Fired and Oil-Fired Units.

2. Procedure

* * * * *
    <IP_ADDRESS> Use the procedures in the following standards to verify
flowmeter accuracy or design, as appropriate to the type of
flowmeter: ASME MFC-3M-1989 (Reaffirmed 1995) (``Measurement of
Fluid Flow in Pipes Using Orifice, Nozzle, and Venturi''); ASME MFC-
4M-1986 (Reaffirmed 1990), ``Measurement of Gas Flow by Turbine
Meters;'' American Gas Association Report No. 3, ``Orifice Metering
of Natural Gas and Other Related Hydrocarbon Fluids Part 1: General
Equations and Uncertainty Guidelines'' (October 1990 Edition), Part
2: ``Specification and Installation Requirements'' (February 1991
Edition), and Part 3: ``Natural Gas Applications'' (August 1992
edition) (excluding the modified flow-calculation method in part 3);
Section 8, Calibration from American Gas Association Transmission
Measurement Committee Report No. 7: Measurement of Gas by Turbine
Meters (Second Revision, April 1996); ASME

MFC-5M-1985 (Reaffirmed 2001) (``Measurement of Liquid Flow in
Closed Conduits Using Transit-Time Ultrasonic Flowmeters''); ASME
MFC-6M-1998 (``Measurement of Fluid Flow in Pipes Using Vortex Flow
Meters''); ASME MFC-7M-1987 (Reaffirmed 2001), ``Measurement of Gas
Flow by Means of Critical Flow Venturi Nozzles;'' ISO 8316: 1987(E)
``Measurement of Liquid Flow in Closed Conduits-Method by Collection
of the Liquid in a Volumetric Tank;'' American Petroleum Institute
(API) Manual of Measurement Standards, Chapter 4: Section 2,
``Conventional Pipe Provers'' (Provers Accumulating at Least 10,000
Pulses), Measurement Coordination (Second Edition, March 2001),
Section 3, ``Small Volume Provers'' (First Edition), and Section 5,
``Master-Meter Provers'', Measurement Coordination (Second Edition,
May 2000); API Manual of Petroleum Measurement Standards, Chapter
22--Testing Protocol: Section 2--Differential Pressure Flow
Measurement Devices (First Edition, August 2005); or ASME MFC-9M-
1988 (Reaffirmed 2001) (``Measurement of Liquid Flow in Closed
Conduits by Weighing Method''), for all other flowmeter types
(incorporated by reference under Sec.  75.6). The Administrator may
also approve other procedures that use equipment traceable to
National Institute of Standards and Technology standards. Document
such procedures, the equipment used, and the accuracy of the
procedures in the monitoring plan for the unit, and submit a
petition signed by the designated representative under Sec.
75.66(c). If the flowmeter accuracy exceeds 2.0 percent of the upper
range value, the flowmeter does not qualify for use under this part.
* * * * *
    <IP_ADDRESS>(a) * * *

Where:

Rbase = Value of the fuel flow rate-to-load ratio during
the baseline period; 100 scfh/MWe, 100 scfh/klb per hour steam load,
or 100 scfh/mmBtu per hour thermal output for gas-firing; (lb/hr)/
MWe, (lb/hr)/klb per hour steam load, or (lb/hr)/mmBtu per hour
thermal output for oil-firing.
* * * * *
Lavg = Arithmetic average unit load during the baseline
period, megawatts, 1000 lb/hr of steam, or mmBtu/hr thermal output.
* * * * *
    2.2.5 For each oil sample that is taken on-site at the affected
facility, split and label the sample and maintain a portion (at
least 200 cc) of it throughout the calendar year and in all cases
for not less than 90 calendar days after the end of the calendar
year allowance accounting period. This requirement does not apply to
oil samples taken from the fuel supplier's storage container, as
described in section <IP_ADDRESS> of this appendix. Analyze oil samples
for percent sulfur content by weight in accordance with ASTM D129-
00, ``Standard Test Method for Sulfur in Petroleum Products (General
Bomb Method),'' ASTM D1552-01, ``Standard Test Method for Sulfur in
Petroleum Products (High Temperature Method),'' ASTM D2622-98,
``Standard Test Method for Sulfur in Petroleum Products by X-Ray
Spectrometry,'' or ASTM D4294-98, ``Standard Test Method for Sulfur
in Petroleum Products by Energy-Dispersive X-Ray Fluorescence
Spectroscopy'' (incorporated by reference under Sec.  75.6).
    2.2.6 Where the flowmeter records volumetric flow rate rather
than mass flow rate, analyze oil samples to determine the density or
specific gravity of the oil. Determine the density or specific
gravity of the oil sample in accordance with ASTM D287-92(2000)e1,
``Standard Test Method for API Gravity of Crude Petroleum and
Petroleum Products (Hydrometer Method),'' ASTM D1217-93(1998),
``Standard Test Method for Density and Relative Density (Specific
Gravity) of Liquids by Bingham Pycnometer,'' ASTM D1481-93 (1997),
``Standard Test Method for Density and Relative Density (Specific
Gravity) of Viscous Materials by Lipkin Bicapillary,'' ASTM D1480-93
(1997), ``Standard Test Method for Density and Relative Density
(Specific Gravity) of Viscous Materials by Bingham Pycnometer,''
ASTM D1298-99, ``Standard Practice for Density, Relative Density
(Specific Gravity) or API Gravity of Crude Petroleum and Liquid
Petroleum Products by Hydrometer Method,'' or ASTM D4052-96
(2002)e1, ``Standard Test Method for Density and Relative Density of
Liquids by Digital Density Meter'' (incorporated by reference under
Sec.  75.6).
    2.2.7 Analyze oil samples to determine the heat content of the
fuel. Determine oil heat content in accordance with ASTM D240-00
(Reapproved 1991), ``Standard Test Method for Heat of Combustion of
Liquid Hydrocarbon Fuels by Bomb Calorimeter,'' ASTM D4809-00,
``Standard Test Method for Heat of Combustion of Liquid Hydrocarbon
Fuels by Bomb Calorimeter (Precision Method),'' or ASTM D5865-01ae1,
``Standard Test Method for Gross Calorific Value of Coal and Coke''
(incorporated by reference under Sec.  75.6) or any other procedures
listed in section 5.5 of appendix F of this part.
* * * * *
    <IP_ADDRESS> * * *
    (a) * * *
    (2) Historical fuel sampling data for the previous 12 months,
documenting the total sulfur content of the fuel and the GCV and/or
percentage by volume of methane. The results of all sample analyses
obtained by or provided to the owner or operator in the previous 12
months shall be used in the demonstration, and each sample result
must meet the definition of pipeline natural gas in Sec.  72.2 of
this chapter, except where the results of at least 100 daily (or
more frequent) total sulfur samples are provided by the fuel
supplier. In that case you may convert these data to monthly
averages and then if, for each month, the average total sulfur
content is 0.5 grains/100 scf or less, and if the GCV or percent
methane requirement is also met, the fuel qualifies as pipeline
natural gas. Alternatively, the fuel qualifies as pipeline natural
gas if the GCV or percent methane requirement is met and if >= 98
percent of the 100 (or more) samples have a total sulfur content of
0.5 grains/100 scf or less; or
* * * * *
    (e) If a fuel qualifies as pipeline natural gas based on the
specifications in a fuel contract or tariff sheet, no additional,
on-going sampling of the fuel's total sulfur content is required,
provided that the contract or tariff sheet is current, valid and
representative of the fuel combusted in the unit. If the fuel
qualifies as pipeline natural gas based on fuel sampling and
analysis, on-going sampling of the fuel's sulfur content is required
annually and whenever the fuel supply source changes. For the
purposes of this paragraph, (e), sampling ``annually'' means that at
least one sample is taken in each calendar year. If the results of
at least 100 daily (or more frequent) total sulfur samples have been
provided by the fuel supplier since the last annual assessment of
the fuel's sulfur content, the data may be used to satisfy the
annual sampling requirement for the current year. If this option is
chosen, all of the data provided by the fuel supplier shall be used.
First, convert the data to monthly averages. Then, if, for each
month, the average total sulfur content is 0.5 grains/100 scf or
less, and if the GCV or percent methane requirement is also met, the
fuel qualifies as pipeline natural gas. Alternatively, the fuel
qualifies as pipeline natural gas if the GCV or percent methane
requirement is met and if the analysis of the 100 (or more) total
sulfur samples since the last annual assessment shows that > 98
percent of the samples have a total sulfur content of 0.5 grains/100
scf or less. The effective date of the annual total sulfur sampling
requirement is January 1, 2003.
* * * * *
    <IP_ADDRESS>.2 Use one of the following methods when using manual
sampling (as applicable to the type of gas combusted) to determine
the sulfur content of the fuel: ASTM D1072-90(1999), ``Standard Test
Method for Total Sulfur in Fuel Gases,'' ASTM D4468-85 (2000)
``Standard Test Method for Total Sulfur in Gaseous Fuels by
Hydrogenolysis and Radiometric Colorimetry,'' ASTM D5504-01
``Standard Test Method for Determination of Sulfur Compounds in
Natural Gas and Gaseous Fuels by Gas Chromatography and
Chemiluminescence,'' ASTM D6667-04 ``Standard Test Method for
Determination of Total Volatile Sulfur in Gaseous Hydrocarbons and
Liquified Petroleum Gases by Ultraviolet Fluorescence,'' or ASTM
D3246-96 ``Standard Test Method for Sulfur in Petroleum Gas By
Oxidative Microcoulometry'' (incorporated by reference under Sec.
75.6).
* * * * *

<IP_ADDRESS> GCV of Pipeline Natural Gas

    * * * If multiple GCV samples are taken and analyzed in a
particular month, the GCV values from all samples shall be averaged
arithmetically to obtain the monthly GCV. Then, for the purposes of
implementing paragraph (c) in section 2.3.7 of this appendix,
consider the latest date of any of the individual GCV samples used
in the monthly average to be the ``date on which the sample was
taken''.
* * * * *
    41. Appendix E to Part 75 is amended by:
    a. Adding a new sentence to the end of section 2.1;

    b. Replacing the words ``section 5.1'' with the words ``section
8.3.1'' in section <IP_ADDRESS>;
    c. Replacing the phrase ``(MWge or steam load in 1000 lb/hr)'' with
the phrase ``(MWge or steam load in 1000 lb/hr, or mmBtu/hr thermal
output)'', in section 2.4.1;
    d. Revising section 2.5.2; and
    e. Adding section <IP_ADDRESS>.
    The revisions and additions read as follows:

Appendix E to Part 75--Optional NOX Emissions Estimation
Protocol for Gas-Fired Peaking Units and Oil-Fired Peaking Units.

* * * * *

2.1 Initial Performance Testing

    * * * The requirements in section 6.1.2 of appendix A to this
part shall be met by any Air Emissions Testing Body (AETB)
performing O2 and NOX concentration
measurements under this appendix, either for units using the
excepted methodology in this appendix or for units using the low
mass emissions excepted methodology in Sec.  75.19.
* * * * *
    2.5.2 Substitute missing NOX emission rate data using
the highest NOX emission rate tabulated during the most
recent set of baseline correlation tests for the same fuel or, if
applicable, combination of fuels, except as provided in sections
<IP_ADDRESS>, <IP_ADDRESS>, <IP_ADDRESS>, and <IP_ADDRESS> of this section.
* * * * *
    <IP_ADDRESS> Whenever 20 full calendar quarters have elapsed
following the quarter of the last baseline correlation test for a
particular type of fuel (or fuel mixture), without a subsequent
baseline correlation test being done for that type of fuel (or fuel
mixture), substitute the fuel-specific NOX MER (as
defined in Sec.  72.2 of this chapter) for each hour in which that
fuel (or mixture) is combusted until a new baseline correlation test
for that fuel (or mixture) has been successfully completed. For fuel
mixtures, report the highest of the individual MER values for the
components of the mixture.

    42. Appendix F to Part 75 is amended by:
    a. Removing the second and third sentences from the introductory
text of section 2;
    b. Replacing the phrase ``method 19 in appendix A of part 60 of
this chapter'' with the phrase ``Method 19 in appendix A-7 to part 60
of this chapter'', in the last sentence of section 3.1 and in the last
sentence of section 3.2;
    c. Adding the phrase ``, or (if applicable) in the equations in
Method 19 in appendix A-7 to part 60 of this chapter'' after the words
``of this appendix'', in section 3.3;
    d. Removing the second and third sentences from section 3.3.4;
    e. Adding sections <IP_ADDRESS> and <IP_ADDRESS>;
    f. Revising Table 1;
    g. Revising the text preceding Equation F-7a, in section 3.3.6;