(1) the following conditions when using ASTM D6348-03:
(A) The test plan preparation and implementation in the Annexes to ASTM D6348-03, Sections A1 through A8 are mandatory;
(B) For ASTM D6348-03 Annex A5 (Analyte Spiking Technique), the percent (%) R must be determined for each target analyte (see Equation A5.5);
(C) For the ASTM D6348-03 test data to be acceptable for a target analyte, %R must be 70% >= R <= 130%; and
(2) spiking levels nominally no greater than two times the level corresponding to the applicable emission limit.
Method 26A must be used if there are entrained water droplets in the exhaust stream.

f. Convert emissions concentration to lb/MMBtu or lb/MWh emissions rates
Method 19 F-factor methodology at Appendix A - 7 to part 60 of this chapter, or calculate using mass emissions rate and electrical output data (see §63.10007(e)).

OR
OR

HCl and/or HF CEMS
a. Install, certify, operate, and maintain the HCl or HF CEMS
Appendix B of this subpart.

b. Install, certify, operate, and maintain the diluent gas, flow rate, and/or moisture monitoring systems
Part 75 of this chapter and §§63.10010(a), (b), (c), and (d).

c. Convert hourly emissions concentrations to 30 boiler operating day rolling average lb/MMBtu or lb/MWh emissions rates
Method 19 F-factor methodology at Appendix A - 7 to part 60 of this chapter, or calculate using mass emissions rate and electrical output data (see §63.10007(e)).
4. Mercury (Hg)
Emissions Testing
a. Select sampling ports location and the number of traverse points
Method 1 at Appendix A - 1 to part 60 of this chapter or Method 30B at Appendix A - 8 for Method 30B point selection.

b. Determine velocity and volumetric flow-rate of the stack gas
Method 2, 2A, 2C, 2F, 2G or 2H at Appendix A - 1 or A - 2 to part 60 of this chapter.

c. Determine oxygen and carbon dioxide concentrations of the stack gas
Method 3A or 3B at Appendix A - 1 to part 60 of this chapter, or ANSI/ASME PTC 19.10 - 1981.[3]

d. Measure the moisture content of the stack gas
Method 4 at Appendix A - 3 to part 60 of this chapter.

e. Measure the Hg emission concentration
Method 30B at Appendix A - 8 to part 60 of this chapter, ASTM D6784[3], or Method 29 at Appendix A - 8 to part 60 of this chapter; for Method 29, the permittee shall report the front half and back half results separately.

f. Convert emissions concentration to lb/TBtu or lb/GWh emission rates
Method 19 F-factor methodology at Appendix A - 7 to part 60 of this chapter, or calculate using mass emissions rate and electrical output data (see §63.10007(e)).

OR
OR

Hg CEMS
a. Install, certify, operate, and maintain the CEMS
Sections 3.2.1 and 5.1 of Appendix A of this subpart.

b. Install, certify, operate, and maintain the diluent gas, flow rate, and/or moisture monitoring systems
Part 75 of this chapter and §§63.10010(a), (b), (c), and (d).

c. Convert hourly emissions concentrations to 30 boiler operating day rolling average lb/TBtu or lb/GWh emissions rates
Section 6 of Appendix A to this subpart.

OR
OR

Sorbent trap monitoring system
a. Install, certify, operate, and maintain the sorbent trap monitoring system
Sections 3.2.2 and 5.2 of Appendix A to this subpart.

b. Install, operate, and maintain the diluent gas, flow rate, and/or moisture monitoring systems
Part 75 of this chapter and §§63.10010(a), (b), (c), and (d).

c. Convert emissions concentrations to 30 boiler operating day rolling average lb/TBtu or lb/GWh emissions rates
Section 6 of Appendix A to this subpart.

OR
OR

LEE testing
a. Select sampling ports location and the number of traverse points
Single point located at the 10% centroidal area of the duct at a port location per Method 1 at Appendix A - 1 to part 60 of this chapter or Method 30B at Appendix A - 8 for Method 30B point selection.

b. Determine velocity and volumetric flow-rate of the stack gas
Method 2, 2A, 2C, 2F, 2G, or 2H at Appendix A - 1 or A - 2 to part 60 of this chapter or flow monitoring system certified per Appendix A of this subpart.

c. Determine oxygen and carbon dioxide concentrations of the stack gas
Method 3A or 3B at Appendix A - 1 to part 60 of this chapter, or ANSI/ASME PTC 19.10 - 1981,[3]or diluent gas monitoring systems certified according to Part 75 of this chapter.

d. Measure the moisture content of the stack gas
Method 4 at Appendix A - 3 to part 60 of this chapter, or moisture monitoring systems certified according to part 75 of this chapter.

e. Measure the Hg emission concentration
Method 30B at Appendix A - 8 to part 60 of this chapter; perform a 30 operating day test, with a maximum of 10 operating days per run ( i.e., per pair of sorbent traps) or sorbent trap monitoring system or Hg CEMS certified per Appendix A of this subpart.

f. Convert emissions concentrations from the LEE test to lb/TBtu or lb/GWh emissions rates
Method 19 F-factor methodology at Appendix A - 7 to part 60 of this chapter, or calculate using mass emissions rate and electrical output data (see §63.10007(e)).

g. Convert average lb/TBtu or lb/GWh Hg emission rate to lb/year, if the permittee is attempting to meet the 29.0 lb/year threshold
Potential maximum annual heat input in TBtu or potential maximum electricity generated in GWh.
5. Sulfur dioxide (SO2)
SO2CEMS
a. Install, certify, operate, and maintain the CEMS
Part 75 of this chapter and §§63.10010(a) and (f).

b. Install, operate, and maintain the diluent gas, flow rate, and/or moisture monitoring systems
Part 75 of this chapter and §§63.10010(a), (b), (c), and (d).

c. Convert hourly emissions concentrations to 30 boiler operating day rolling average lb/MMBtu or lb/MWh emissions rates
Method 19 F-factor methodology at Appendix A - 7 to part 60 of this chapter, or calculate using mass emissions rate and electrical output data (see §63.10007(e)).
[1]Regarding emissions data collected during periods of startup or shutdown, see §§63.10020(b) and (c) and §63.10021(h).
[2]See Tables 1 and 2 to this subpart for required sample volumes and/or sampling run times.
[3]Incorporated by reference, see §63.14.

The permittee may conduct the initial performance testing in accordance with §63.10005(h), to determine whether the unit qualifies as a low emitting EGU (LEE) for one or more applicable emissions limits. (§63.10000(c)(1)(i))
 For a qualifying LEE for Hg emissions limits, the permittee shall conduct a 30-day performance test using Method 30B at least once every 12 calendar months to demonstrate continued LEE status. (§63.10000(c)(1)(ii))
 For a qualifying LEE of any other applicable emissions limits, the permittee shall conduct a performance test at least once every 36 calendar months to demonstrate continued LEE status. (§63.10000(c)(1)(iii))
 If the permittee's coal-fired EGU does not qualify as a LEE for total non-mercury HAP metals, individual non-mercury HAP metals, or filterable particulate matter (PM), the permittee shall demonstrate compliance through an initial performance test and the permittee shall monitor continuous performance through either use of a particulate matter continuous parametric monitoring system (PM CPMS), a PM CEMS, or compliance performance testing repeated quarterly. (§63.10000(c)(1)(iv))
 If the permittee's coal-fired EGU does not qualify as a LEE for hydrogen chloride (HCl), the permittee may demonstrate initial and continuous compliance through use of an HCl CEMS, installed and operated in accordance with Appendix B to this subpart. As an alternative to HCl CEMS, the permittee may demonstrate initial and continuous compliance by conducting an initial and periodic quarterly performance stack test for HCl. If the permittee's EGU uses wet or dry flue gas desulfurization technology (this includes limestone injection into a fluidized bed combustion unit), the permittee may apply a second alternative to HCl CEMS by installing and operating a sulfur dioxide (SO2) CEMS installed and operated in accordance with part 75 of this chapter to demonstrate compliance with the applicable SO2emissions limit. (§63.10000(c)(1)(v))
 If the permittee's coal-fired EGU does not qualify as a LEE for Hg, the permittee shall demonstrate initial and continuous compliance through use of a Hg CEMS or a sorbent trap monitoring system, in accordance with appendix A to this subpart. (§63.10000(c)(1)(vi))
 (A) You may choose to use separate sorbent trap monitoring systems to comply with this subpart: One sorbent trap monitoring system to demonstrate compliance with the numeric mercury emissions limit during periods other than startup or shutdown and the other sorbent trap monitoring system to report average mercury concentration during startup periods or shutdown periods. (§63.10000(c)(1)(vi)(A))
 (B) You may choose to use one sorbent trap monitoring system to demonstrate compliance with the mercury emissions limit at all times (including startup periods and shutdown periods) and to report average mercury concentration. You must follow the startup or shutdown requirements that follow and as given in Table 3 to this subpart for each coal-fired, liquid oil-fired, or solid oil-derived fuel-fired EGU. (§63.10000(c)(1)(vi)(B))

Low emitting EGUs. The provisions of this paragraph (h) apply to pollutants with emissions limits from new EGUs except Hg and to all pollutants with emissions limits from existing EGUs. The permittee may not pursue this compliance option if the permittee's existing EGU is equipped with an acid gas scrubber and has a main stack and bypass stack exhaust configuration. (§63.10005(h))

 An EGU may qualify for low emitting EGU (LEE) status for Hg, HCl, HF, filterable PM, total non-Hg HAP metals, or individual non-Hg HAP metals if the permittee collects performance test data that meet the requirements of this paragraph (h), and if those data demonstrate: (§63.10005(h)(1))
 For all pollutants except Hg, performance test emissions results less than 50 percent of the applicable emissions limits in Table 1 or 2 to this subpart for all required testing for 3 consecutive years; or
 For Hg emissions from an existing EGU, either:
 Average emissions less than 10 percent of the applicable Hg emissions limit in Table 2 to this subpart (expressed either in units of lb/TBtu or lb/GWh); or
 Potential Hg mass emissions of 29.0 or fewer pounds per year and compliance with the applicable Hg emission limit in Table 2 to this subpart (expressed either in units of lb/TBtu or lb/GWh).
 For all pollutants except Hg, the permittee shall conduct all required performance tests described in §63.10007 to demonstrate that a unit qualifies for LEE status. (§63.10005(h)(2))
 When conducting emissions testing to demonstrate LEE status, the permittee shall increase the minimum sample volume specified in Table 1 or 2 nominally by a factor of two.
 Follow the instructions in §63.10007(e) and Table 5 to this subpart to convert the test data to the units of the applicable standard.
 For Hg, the permittee shall conduct a 30-boiler operating day performance test using Method 30B in appendix A - 8 to part 60 of this chapter to determine whether a unit qualifies for LEE status. Locate the Method 30B sampling probe tip at a point within the 10 percent centroidal area of the duct at a location that meets Method 1 in appendix A - 1 to part 60 of this chapter and conduct at least three nominally equal length test runs over the 30-boiler operating day test period. You may use a pair of sorbent traps to sample the stack gas for a period consistent with that given in section 5.2.1 of appendix A to this subpart. Collect Hg emissions data continuously over the entire test period (except when changing sorbent traps or performing required reference method QA procedures). As an alternative to constant rate sampling per Method 30B, you may use proportional sampling per section 8.2.2 of Performance Specification 12 B in appendix B to part 60 of this chapter.. (§63.10005(h)(3))
 Depending on whether the permittee intends to assess LEE status for Hg in terms of the lb/TBtu or lb/GWh emission limit in Table 2 to this subpart or in terms of the annual Hg mass emissions limit of 29.0 lb/year, the permittee will have to collect some or all of the following data during the 30-boiler operating day test period (see paragraph (h)(3)(iii) of this section):
 Diluent gas (CO2or O2) data, using either Method 3A in appendix A - 3 to part 60 of this chapter or a diluent gas monitor that has been certified according to part 75 of this chapter.
 Stack gas flow rate data, using either Method 2, 2F, or 2G in appendices A - 1 and A - 2 to part 60 of this chapter, or a flow rate monitor that has been certified according to part 75 of this chapter.
 Stack gas moisture content data, using either Method 4 in appendix A - 1 to part 60 of this chapter, or a moisture monitoring system that has been certified according to part 75 of this chapter. Alternatively, an appropriate fuel-specific default moisture value from §75.11(b) of this chapter may be used in the calculations or the permittee may petition the Administrator or the Department under §75.66 of this chapter for use of a default moisture value for non-coal-fired units.
 Hourly electrical load data (megawatts), from facility records.
 If the permittee uses CEMS to measure CO2(or O2) concentration, and/or flow rate, and/or moisture, record hourly average values of each parameter throughout the 30-boiler operating day test period. If the permittee opts to use EPA reference methods rather than CEMS for any parameter, the permittee shall perform at least one representative test run on each operating day of the test period, using the applicable reference method.
 Calculate the average Hg concentration, in ug/m[3] (dry basis), for the 30-boiler operating day performance test, as the arithmetic average of all Method 30B sorbent trap results. Also calculate, as applicable, the average values of CO2or O2concentration, stack gas flow rate, stack gas moisture content, and electrical load for the test period. Then:
 To express the test results in units of lb/TBtu, follow the procedures in §63.10007(e). Use the average Hg concentration and diluent gas values in the calculations.
 To express the test results in units of lb/GWh, use Equations A - 3 and A - 4 in section 6.2.2 of appendix A to this subpart, replacing the hourly values "Ch", "Qh", "Bws" and "(MW)h" with the average values of these parameters from the performance test.
 To calculate pounds of Hg per year, use one of the following methods:
 Multiply the average lb/TBtu Hg emission rate (determined according to paragraph (h)(3)(iii)(A) of this section) by the maximum potential annual heat input to the unit (TBtu), which is equal to the maximum rated unit heat input (TBtu/hr) times 8,760 hours. If the maximum rated heat input value is expressed in units of MMBtu/hr, multiply it by 10[−6]to convert it to TBtu/hr; or
 Multiply the average lb/GWh Hg emission rate (determined according to paragraph (h)(3)(iii)(B) of this section) by the maximum potential annual electricity generation (GWh), which is equal to the maximum rated electrical output of the unit (GW) times 8,760 hours. If the maximum rated electrical output value is expressed in units of MW, multiply it by 10[−3]to convert it to GW; or
 If an EGU has a federally-enforceable permit limit on either the annual heat input or the number of annual operating hours, the permittee may modify the calculations in paragraph (h)(3)(iii)(C)(1) of this section by replacing the maximum potential annual heat input or 8,760 unit operating hours with the permit limit on annual heat input or operating hours (as applicable).
 For a group of affected units that vent to a common stack, the permittee may either assess LEE status for the units individually by performing a separate emission test of each unit in the duct leading from the unit to the common stack, or the permittee may perform a single emission test in the common stack. If the permittee chooses the common stack testing option, the units in the configuration qualify for LEE status if:
 The emission rate measured at the common stack is less than 50 percent (10 percent for Hg) of the applicable emission limit in Table 1 or 2 to this subpart; or
 For Hg from an existing EGU, the applicable Hg emission limit in Table 2 to this subpart is met and the potential annual mass emissions, calculated according to paragraph (h)(3)(iii) of this section (with some modifications), are less than or equal to 29.0 pounds times the number of units sharing the common stack. Base the permittee's calculations on the combined heat input capacity of all units sharing the stack ( i.e. , either the combined maximum rated value or, if applicable, a lower combined value restricted by permit conditions or operating hours).

For coal-fired EGUs using PM CPMS to monitor continuous performance with an applicable emission limit as provided for under §63.10000(c), the permittee shall conduct all applicable performance tests according to Table 5 to this subpart and §63.10007 at least every year. (§63.10006(a))

For a meeting the LEE requirements of §63.10005(h), the permittee shall repeat the performance test once every 3 years (once every year for Hg) according to Table 5 and §63.10007. Should subsequent emissions testing results show the unit does not meet the LEE eligibility requirements, LEE status is lost. If this should occur: (§63.10006(b))

 For all pollutant emission limits except for Hg, the permittee shall conduct emissions testing quarterly, except as otherwise provided in §63.10021(d)(1). (§63.10006(b)(1))
 For Hg, the permittee shall install, certify, maintain, and operate a Hg CEMS or a sorbent trap monitoring system in accordance with appendix A to this subpart, within 6 calendar months of losing LEE eligibility. Until the Hg CEMS or sorbent trap monitoring system is installed, certified, and operating, the permittee shall conduct Hg emissions testing quarterly, except as otherwise provided in §63.10021(d)(1). The permittee shall have 3 calendar years of testing and CEMS or sorbent trap monitoring system data that satisfy the LEE emissions criteria to reestablish LEE status. (§63.10006(b)(2), §63.10006(c))

Except where paragraph (b) of this section applies, for coal-fired EGUs that do not use either an HCl CEMS to monitor compliance with the HCl limit or an SO2CEMS to monitor compliance with the alternate equivalent SO2emission limit, the permittee shall conduct all applicable periodic HCl emissions tests according to Table 5 to this subpart and §63.10007 at least quarterly, except as otherwise provided in §63.10021(d)(1). (§63.10006(d))

Time between performance tests. (§63.10006(f))

 (1) Notwithstanding the provisions of §63.10021(d)(1), the requirements listed in paragraphs (g) and (h) of this section, and the requirements of paragraph (f)(3) of this section, you must complete performance tests for your EGU as follows:
 (i) At least 45 calendar days, measured from the test's end date, must separate performance tests conducted every quarter;
 (ii) For annual testing:
 (A) At least 320 calendar days, measured from the test's end date, must separate performance tests;
 (B) At least 320 calendar days, measured from the test's end date, must separate annual sorbent trap mercury testing for 30-boiler operating day LEE tests;
 (C) At least 230 calendar days, measured from the test's end date, must separate annual sorbent trap mercury testing for 90-boiler operating day LEE tests; and
 (iii) At least 1,050 calendar days, measured from the test's end date, must separate performance tests conducted every 3 years.
 (2) For units demonstrating compliance through quarterly emission testing, you must conduct a performance test in the 4th quarter of a calendar year if your EGU has skipped performance tests in the first 3 quarters of the calendar year.
 (3) If your EGU misses a performance test deadline due to being inoperative and if 168 or more boiler operating hours occur in the next test period, you must complete an additional performance test in that period as follows:
 (i) At least 15 calendar days must separate two performance tests conducted in the same quarter.
 (ii) At least 107 calendar days must separate two performance tests conducted in the same calendar year.
 (iii) At least 350 calendar days must separate two performance tests conducted in the same 3 year period.

If the permittee elects to demonstrate compliance using emissions averaging under §63.10009, the permittee shall continue to conduct performance stack tests at the appropriate frequency given in section (c) through (f) of this section. (§63.10006(g))

If a performance test on a non-mercury LEE shows emissions in excess of 50 percent of the emission limit and if the permittee chooses to reapply for LEE status, the permittee shall conduct performance tests at the appropriate frequency given in section (c) through (e) of this section for that pollutant until all performance tests over a consecutive 3-year period show compliance with the LEE criteria. (§63.10006(h))

Except as otherwise provided in this section, the permittee shall conduct all required performance tests according to §63.7(d), (e), (f), and (h). The permittee shall also develop a site-specific test plan according to the requirements in §63.7(c). (§63.10007(a))
 If the permittee uses CEMS (Hg, HCl, SO2, or other) to determine compliance with a 30-boiler operating day rolling average emission limit, the permittee shall collect quality- assured CEMS data for all unit operating conditions, including startup and shutdown (see §63.10011(g) and Table 3 to this subpart), except as otherwise provided in §63.10020(b). Emission rates determined during startup periods and shutdown periods (as defined in §63.10042) are not to be included in the compliance determinations, except as otherwise provided in §§63.10000(c)(1)(vi)(B) and 63.10005(a)(2)(iii). (§63.10007(a)(1))
 If the permittee conducts performance testing with test methods in lieu of continuous monitoring, operate the unit at maximum normal operating load conditions during each periodic (e.g., quarterly) performance test. Maximum normal operating load shall be generally between 90 and 110 percent of design capacity but should be representative of site specific normal operations during each test run. (§63.10007(a)(2))
 For establishing operating limits with particulate matter continuous parametric monitoring system (PM CPMS) to demonstrate compliance with a PM or non Hg metals emissions limit, operate the unit at maximum normal operating load conditions during the performance test period. Maximum normal operating load shall be generally between 90 and 110 percent of design capacity but should be representative of site specific normal operations during each test run. (§63.10007(a)(3))

The permittee shall conduct each performance test (including traditional 3-run stack tests, 30-boiler operating day tests based on CEMS data (or sorbent trap monitoring system data), and 30-boiler operating day Hg emission tests for LEE qualification) according to the requirements in Table 5 to this subpart. (§63.10007(b))

If the permittee chooses to comply with the filterable PM emission limit and demonstrate continuous performance using a PM CPMS for an applicable emission limit as provided for in §63.10000(c), the permittee shall also establish an operating limit according to §63.10011(b) and Tables 4 and 6 to this subpart. Should the permittee desire to have operating limits that correspond to loads other than maximum normal operating load, the permittee shall conduct testing at those other loads to determine the additional operating limits. (§63.10007(c))

Except for a 30-boiler operating day performance test based on CEMS (or sorbent trap monitoring system) data, where the concept of test runs does not apply, the permittee shall conduct a minimum of three separate test runs for each performance test, as specified in §63.7(e)(3). Each test run shall comply with the minimum applicable sampling time or volume specified in Table 1 or 2 to this subpart. Sections 63.10005(d) and (h), respectively, provide special instructions for conducting performance tests based on CEMS or sorbent trap monitoring systems, and for conducting emission tests for LEE qualification. (§63.10007(d))

To use the results of performance testing to determine compliance with the applicable emission limits in Table 1 or 2 to this subpart, proceed as follows: (§63.10007(e))
 Except for a 30-boiler operating day performance test based on CEMS (or sorbent trap monitoring system) data, if measurement results for any pollutant are reported as below the method detection level (e.g., laboratory analytical results for one or more sample components are below the method defined analytical detection level), the permittee shall use the method detection level as the measured emissions level for that pollutant in calculating compliance. The measured result for a multiple component analysis (e.g., analytical values for multiple Method 29 fractions both for individual HAP metals and for total HAP metals) may include a combination of method detection level data and analytical data reported above the method detection level. (§63.10007(e)(1))
 If the limits are expressed in lb/MMBtu or lb/TBtu, the permittee shall use the F-factor methodology and equations in sections 12.2 and 12.3 of EPA Method 19 in appendix A - 7 to part 60 of this chapter. In cases where an appropriate F-factor is not listed in Table 19 - 2 of Method 19, the permittee may use F-factors from Table 1 in section 3.3.5 of appendix F to part 75 of this chapter, or F-factors derived using the procedures in section 3.3.6 of appendix to part 75 of this chapter. Use the following factors to convert the pollutant concentrations measured during the initial performance tests to units of lb/scf, for use in the applicable Method 19 equations: (§63.10007(e)(2))
 Multiply SO2ppm by 1.66 x 10[−7];
 Multiply HCl ppm by 9.43 x 10[−8];
 Multiply HF ppm by 5.18 x 10[−8];
 Multiply HAP metals concentrations (mg/dscm) by 6.24 x 10[−8]; and
 Multiply Hg concentrations (ug/scm) by 6.24 x 10[−11].

 To determine compliance with emission limits expressed in lb/MWh or lb/GWh, the permittee shall first calculate the pollutant mass emission rate during the performance test, in units of lb/h. For Hg, if a CEMS or sorbent trap monitoring system is used, use Equation A - 2 or A - 3 in appendix A to this subpart (as applicable). In all other cases, use an equation that has the general form of Equation A - 2 or A - 3, replacing the value of K with 1.66 x 10[−7]lb/scf-ppm for SO2, 9.43 x 10[−8]lb/scf-ppm for HCl (if an HCl CEMS is used), 5.18 x 10[−8]lb/scf-ppm for HF (if an HF CEMS is used), or 6.24 x 10[−8]lb-scm/mg-scf for HAP metals and for HCl and HF (when performance stack testing is used), and defining Chas the average SO2, HCl, or HF concentration in ppm, or the average HAP metals concentration in mg/dscm. This calculation requires stack gas volumetric flow rate (scfh) and (in some cases) moisture content data (see §§63.10005(h)(3) and 63.10010). Then, if the applicable emission limit is in units of lb/GWh, use Equation A - 4 in appendix A to this subpart to calculate the pollutant emission rate in lb/GWh. In this calculation, define (M)has the calculated pollutant mass emission rate for the performance test (lb/h), and define (MW)has the average electrical load during the performance test (megawatts). If the applicable emission limit is in lb/MWh rather than lb/GWh, omit the 10[3] term from Equation A - 4 to determine the pollutant emission rate in lb/MWh. (§63.10007(e)(3))

(f) If you elect to (or are required to) use CEMS to continuously monitor Hg, HCl, HF, SO2, or PM emissions (or, if applicable, sorbent trap monitoring systems to continuously collect Hg emissions data), the following default values are available for use in the emission rate calculations during startup periods or shutdown periods (as defined in §63.10042). For the purposes of this subpart, these default values are not considered to be substitute data.
 (1) Diluent cap values. If you use CEMS (or, if applicable, sorbent trap monitoring systems) to comply with a heat input-based emission rate limit, you may use the following diluent cap values for a startup or shutdown hour in which the measured CO2 concentration is below the cap value or the measured O2 concentration is above the cap value:
 (i) For an IGCC EGU, you may use 1% for CO2 or 19% for O2.
 (ii) For all other EGUs, you may use 5% for CO2 or 14% for O2.
 (2) Default gross output. If you use CEMS to continuously monitor Hg, HCl, HF, SO2, or PM emissions (or, if applicable, sorbent trap monitoring systems to continuously collect Hg emissions data), the following default value is available for use in the emission rate calculations during startup periods or shutdown periods (as defined in §63.10042). For the purposes of this subpart, this default value is not considered to be substitute data. For a startup or shutdown hour in which there is heat input to an affected EGU but zero gross output, you must calculate the pollutant emission rate using a value equivalent to 5% of the maximum sustainable gross output, expressed in megawatts, as defined in section <IP_ADDRESS>(a)(1) of appendix A to part 75 of this chapter. This default gross output is either the nameplate capacity of the EGU or the highest gross output observed in at least four representative quarters of EGU operation. For a monitored common stack, the default gross output is used only when all EGUs are operating (i.e., combusting fuel) are in startup or shutdown mode, and have zero electrical generation. Under those conditions, a default gross output equal to 5% of the combined maximum sustainable gross output of the EGUs that are operating but have a total of zero gross output must be used to calculate the hourly gross output-based pollutant emissions rate.

Upon request, the permittee shall make available to the EPA Administrator or the Department such records as may be necessary to determine whether the performance tests have been done according to the requirements of this section. (§63.10007(g))

If the permittee is subject to an operating limit in Table 4 to this subpart, the permittee demonstrates initial compliance with HAP metals or filterable PM emission limit(s) through performance stack tests and the permittee elects to use a PM CPMS to demonstrate continuous performance, the permittee shall also establish a site-specific operating limit, in accordance with Table 4 to this subpart, §63.10007, and Table 6 to this subpart. The permittee may use only the parametric data recorded during successful performance tests ( i.e. , tests that demonstrate compliance with the applicable emissions limits) to establish an operating limit. (§63.10011(b))

(c)(1) If you use CEMS or sorbent trap monitoring systems to measure a HAP (e.g., Hg or HCl) directly, the initial performance test, shall consist of a 30-boiler operating day (or, for certain coal-fired, existing EGUs that use emissions averaging for Hg, a 90-boiler operating day) rolling average emissions rate obtained with a certified CEMS or sorbent trap system, expressed in units of the standard. If the monitoring system is certified prior to the applicable compliance date, the initial averaging period shall either begin with: The first boiler operating day on or after the compliance date; or 30 (or, if applicable, 90) boiler operating days prior to that date, as described in §63.10005(b). In all cases, the initial 30- or 90-boiler operating day averaging period must be completed on or before the date that compliance must be demonstrated, in accordance with §63.9984(f). Initial compliance is demonstrated if the results of the performance test meet the applicable emission limit in Table 1 or 2 to this subpart. (§63.10011(c)(1))

(2) For an EGU that uses a CEMS to measure SO2 or PM emissions for initial compliance, the initial performance test shall consist of a 30-boiler operating day average emission rate obtained with certified CEMS, expressed in units of the standard. If the monitoring system is certified prior to the applicable compliance date, the initial averaging period shall either begin with: The first boiler operating day on or after the compliance date; or 30 boiler operating days prior to that date, as described in §63.10005(b). In all cases, the initial 30- boiler operating day averaging period must be completed on or before the date that compliance must be demonstrated, in accordance with §63.9984(f). Initial compliance is demonstrated if the results of the performance test meet the applicable SO2 or PM emission limit in Table 1 or 2 to this subpart. (§63.10011(c)(2))

For candidate LEE units, use the results of the performance testing described in §63.10005(h) to determine initial compliance with the applicable emission limit(s) in Table 1 or 2 to this subpart and to determine whether the unit qualifies for LEE status. (§63.10011(d))

The permittee shall submit a Notification of Compliance Status containing the results of the initial compliance demonstration, according to §63.10030(e). (§63.10011(e))

When the permittee is required to conduct a performance test, the permittee shall submit a Notification of Intent to conduct a performance test at least 30 days before the performance test is scheduled to begin. (§63.10030(d))

Monitoring Requirements

The permittee shall meet each applicable operating limit in Table 4 of 40 CFR Part 63 Subpart UUUUU.  (§63.9991(a)(2))

 For demonstrating compliance using PM CPMS, the permitte shall maintain the 30-boiler operating day rolling average PM CPMS output at or below the highest 1-hour average measured during the most recent performance test demonstrating compliance with the filterable PM, total non-mercury HAP metals, or individual non-mercury HAP metals  emissions limitation(s). (Table 4 to Subpart UUUUU of Part 63, §63.9991)

The permittee shall demonstrate continuous compliance with the emissions limitations in Condtion V.M.1.b above  according to the following in Table V.M.4:  (§63.10021(a), Table 7 of 40 CFR Part 63 Subpart UUUUU)

                                  TABLE V.M.4

If the permittee uses one of the following to meet applicable emissions limits, operating limits, or work practice standards . . .
        The permittee shall demonstrate continuous compliance by . . .
 CEMS to measure filterable PM, SO2, HCl, HF, or Hg emissions, or using a sorbent trap monitoring system to measure Hg
Calculating the 30- (or 90-) boiler operating day rolling arithmetic average emissions rate in units of the applicable emissions standard basis at the end of each boiler operating day using all of the quality assured hourly average CEMS or sorbent trap data for the previous 30-boiler operating days, excluding data recorded during periods of startup or shutdown.
 PM CPMS to measure compliance with a parametric operating limit
Calculating the arithmetic 30-boiler operating day rolling average of all of the quality assured hourly average PM CPMS output data (e.g., milliamps, PM concentration, raw data signal) collected for all operating hours for the previous 30 boiler operating days, excluding data recorded during periods of startup or shutdown.

 Quarterly performance testing for coal-fired units to measure compliance with one or more applicable emissions limit in Table 1 or 2
Calculating the results of the testing in units of the applicable emissions standard.
 Conducting periodic performance tune-ups of the permittee's EGU(s)
Conducting periodic performance tune-ups of the permittee's EGU(s), as specified in §63.10021(e).
 Work practice standards for coal-fired EGUs during startup
Operating in accordance with Table 3.
 Work practice standards for coal-fired EGUs during shutdown
Operating in accordance with Table 3.

If the permittee demonstrates compliance with any applicable emissions limit through use of a continuous monitoring system (CMS), where a CMS includes a continuous parameter monitoring system (CPMS) as well as a continuous emissions monitoring system (CEMS), the permittee shall develop a site-specific monitoring plan and submit this site-specific monitoring plan, if requested, at least 60 days before the permittee's initial performance evaluation (where applicable) of the permittee's CMS. This requirement also applies to the permittee if the permittee petitions the Administrator or the Department for alternative monitoring parameters under §63.8(f). This requirement to develop and submit a site-specific monitoring plan does not apply to affected sources with existing monitoring plans that apply to CEMS and CPMS prepared under Appendix B to part 60 or part 75 of this chapter, and that meet the requirements of §63.10010. Using the process described in §63.8(f)(4), the permittee may request approval of monitoring system quality assurance and quality control procedures alternative to those specified in this paragraph of this section and, if approved, include those in the permittee's site-specific monitoring plan. The monitoring plan shall address the provisions in paragraphs (d)(2) through (5) of this section. (§63.10000(d)(1))

The site-specific monitoring plan shall include the information specified in paragraphs (d)(5)(i) through (d)(5)(vii) of this section. Alternatively, the requirements of paragraphs (d)(5)(i) through (d)(5)(vii) are considered to be met for a particular CMS or sorbent trap monitoring system if: (§63.10000(d)(2))
 (i) The CMS or sorbent trap monitoring system is installed, certified, maintained, operated, and quality-assured either according to part 75 of this chapter, or appendix A or B to this subpart; and
 (ii) The recordkeeping and reporting requirements of part 75 of this chapter, or appendix A or B to this subpart, that pertain to the CMS are met.

If requested by the Administrator or the Department, the permittee shall submit the monitoring plan (or relevant portion of the plan) at least 60 days before the initial performance evaluation of a particular CMS, except where the CMS has already undergone a performance evaluation that meets the requirements of §63.10010 (e.g., if the CMS was previously certified under another program). (§63.10000(d)(3))

The permittee shall operate and maintain the CMS according to the site-specific monitoring plan. (§63.10000(d)(4))

The provisions of the site-specific monitoring plan shall address the following items: (§63.10000(d)(5))
 Installation of the CMS or sorbent trap monitoring system sampling probe or other interface at a measurement location relative to each affected process unit such that the measurement is representative of control of the exhaust emissions (e.g., on or downstream of the last control device). See §63.10010(a) for further details. For PM CPMS installations, follow the procedures in §63.10010(h).
 Performance and equipment specifications for the sample interface, the pollutant concentration or parametric signal analyzer, and the data collection and reduction systems.
 Schedule for conducting initial and periodic performance evaluations.
 Performance evaluation procedures and acceptance criteria (e.g., calibrations), including the quality control program in accordance with the general requirements of §63.8(d).
 On-going operation and maintenance procedures, in accordance with the general requirements of §§63.8(c)(1)(ii), (c)(3), and (c)(4)(ii).
 Conditions that define a CMS that is out of control consistent with §63.8(c)(7)(i) and for responding to out of control periods consistent with §§63.8(c)(7)(ii) and (c)(8).
 On-going recordkeeping and reporting procedures, in accordance with the general requirements of §§63.10(c), (e)(1), and (e)(2)(i), or as specifically required under this subpart.

All monitoring systems necessary for compliance with any newly applicable monitoring requirements which apply as a result of the cessation or commencement or recommencement of operations that cause the permittee's EGU to meet the definition of an EGU subject to this subpart shall be installed and operational as of the date the permittee's source ceases to be or becomes subject to this subpart. All calibration and drift checks shall be performed as of the date the permittee's source ceases to be or becomes subject to this subpart. The permittee shall also comply with provisions of §§63.10010, 63.10020, and 63.10021 of this subpart. Relative accuracy tests shall be performed as of the performance test deadline for PM CEMS, if applicable. Relative accuracy testing for other CEMS need not be repeated if that testing was previously performed consistent with CAA section 112 monitoring requirements or monitoring requirements under this subpart. (§63.10000(k))

CMS requirements. If, for a particular emission or operating limit, the permittee is required to (or elect to) demonstrate initial compliance using a continuous monitoring system, the CMS shall pass a performance evaluation prior to the initial compliance demonstration. If a CMS has been previously certified under another state or federal program and is continuing to meet the on-going quality-assurance (QA) requirements of that program, then, provided that the certification and QA provisions of that program meet the applicable requirements of §§63.10010(b) through (h), an additional performance evaluation of the CMS is not required under this subpart. (§63.10005(d))

 For an affected coal-fired EGU, the permittee may demonstrate initial compliance with the applicable SO2, HCl, or HF emissions limit in Table 1 or 2 to this subpart through use of an SO2, HCl, or HF CEMS installed and operated in accordance with part 75 of this chapter or Appendix B to this subpart, as applicable. The permittee may also demonstrate compliance with a filterable PM emission limit in Table 1 or 2 to this subpart through use of a PM CEMS installed, certified, and operated in accordance with §63.10010(i). Initial compliance is achieved if the arithmetic average of 30-boiler operating days of quality-assured CEMS data, expressed in units of the standard (see §63.10007(e)), meets the applicable SO2, PM, HCl, or HF emissions limit in Table 1 or 2 to this subpart. Use Equation 19 - 19 of Method 19 in appendix A - 7 to part 60 of this chapter to calculate the 30-boiler operating day average emissions rate. (Note:For this calculation, the term Ehjin Equation 19 - 19 shall be in the same units of measure as the applicable HCl or HF emission limit in Table 1 or 2 to this subpart). (§63.10005(d)(1))
 For affected coal-fired EGUs that demonstrate compliance with the applicable emission limits for total non-mercury HAP metals, individual non-mercury HAP metals, total HAP metals, individual HAP metals, or filterable PM listed in Table 1 or 2 to this subpart using initial performance testing and continuous monitoring with PM CPMS: (§63.10005(d)(2))
 The permittee shall demonstrate initial compliance no later than the applicable date specified in §63.9984(f) for existing EGUs and in paragraph (g) of this section for new EGUs.
 The permittee shall demonstrate continuous compliance with the PM CPMS site-specific operating limit that corresponding to the results of the performance test demonstrating compliance with the pollutant with which the permittee chooses to comply.
 The permittee shall repeat the performance test annually for the selected pollutant emissions limit and reassess and adjust the site-specific operating limit in accordance with the results of the performance test.
 For affected EGUs that are either required to or elect to demonstrate initial compliance with the applicable Hg emission limit in Table 1 or 2 of this subpart using Hg CEMS or sorbent trap monitoring systems, initial compliance shall be demonstrated no later than the applicable date specified in §63.9984(f) for existing EGUs and in paragraph (g) of this section for new EGUs. Initial compliance is achieved if the arithmetic average of 30-boiler operating days of quality-assured CEMS (or sorbent trap monitoring system) data, expressed in units of the standard (see section 6.2 of appendix A to this subpart), meets the applicable Hg emission limit in Table 1 or 2 to this subpart. (§63.10005(d)(3))

Single unit-single stack configurations. For an affected unit that exhausts to the atmosphere through a single, dedicated stack, the permittee shall either install the required CEMS, PM CPMS, and sorbent trap monitoring systems in the stack or at a location in the ductwork downstream of all emissions control devices, where the pollutant and diluents concentrations are representative of the emissions that exit to the atmosphere. (§63.10010(a)(1))

If the permittee uses an oxygen (O2) or carbon dioxide (CO2) CEMS to convert measured pollutant concentrations to the units of the applicable emissions limit, the O2or CO2concentrations shall be monitored at a location that represents emissions to the atmosphere, i.e., at the outlet of the EGU, downstream of all emission control devices. The permittee shall install, certify, maintain, and operate the CEMS according to part 75 of this chapter. Use only quality-assured O2or CO2data in the emissions calculations; do not use part 75 substitute data values. (§63.10010(b))

If the permittee is required to use a stack gas flow rate monitor, either for routine operation of a sorbent trap monitoring system or to convert pollutant concentrations to units of an electrical output-based emission standard in Table 1 or 2 to this subpart, the permittee shall install, certify, operate, and maintain the monitoring system and conduct on-going quality-assurance testing of the system according to part 75 of this chapter. Use only unadjusted, quality-assured flow rate data in the emissions calculations. Do not apply bias adjustment factors to the flow rate data and do not use substitute flow rate data in the calculations. (§63.10010(c))

If the permittee is required to make corrections for stack gas moisture content when converting pollutant concentrations to the units of an emission standard in Table 1 of 2 to this subpart, the permittee shall install, certify, operate, and maintain a moisture monitoring system in accordance with part 75 of this chapter. Alternatively, for coal-fired units, the permittee may use appropriate fuel-specific default moisture values from §75.11(b) of this chapter to estimate the moisture content of the stack gas or the permittee may petition the Administrator or the Department under §75.66 of this chapter for use of a default moisture value for non-coal-fired units. If the permittee installs and operate a moisture monitoring system, do not use substitute moisture data in the emissions calculations. (§63.10010(d))

If the permittee uses an HCl and/or HF CEMS, the permittee shall install, certify, operate, maintain, and quality-assure the data from the monitoring system in accordance with appendix B to this subpart. Calculate and record a 30-boiler operating day rolling average HCl or HF emission rate in the units of the standard, updated after each new boiler operating day. Each 30-boiler operating day rolling average emission rate is the average of all the valid hourly HCl or HF emission rates in the preceding 30 boiler operating days (see section 9.4 of appendix B to this subpart). (§63.10010(e))

If the permittee uses an SO2CEMS, the permittee shall install the monitor at the outlet of the EGU, downstream of all emission control devices, and the permittee shall certify, operate, and maintain the CEMS according to part 75 of this chapter. (§63.10010(f)(1))

 For on-going QA, the SO2CEMS shall meet the applicable daily, quarterly, and semiannual or annual requirements in sections 2.1 through 2.3 of appendix B to part 75 of this chapter, with the following addition: The permittee shall perform the linearity checks required in section 2.2 of appendix B to part 75 of this chapter if the SO2CEMS has a span value of 30 ppm or less. (§63.10010(f)(2))
 Calculate and record a 30-boiler operating day rolling average SO2emission rate in the units of the standard, updated after each new boiler operating day. Each 30-boiler operating day rolling average emission rate is the average of all of the valid SO2emission rates in the preceding 30 boiler operating days. (§63.10010(f)(3))
 Use only unadjusted, quality-assured SO2concentration values in the emissions calculations; do not apply bias adjustment factors to the part 75 SO2data and do not use part 75 substitute data values. (§63.10010(f)(4))

If the permittee uses a Hg CEMS or a sorbent trap monitoring system, the permittee shall install, certify, operate, maintain and quality-assure the data from the monitoring system in accordance with appendix A to this subpart. The permittee shall calculate and record a 30- (or, if alternate emissions averaging is used, 90-) boiler operating day rolling average Hg emission rate, in units of the standard, updated after each new boiler operating day. Each 30- (or, if alternate emissions averaging is used, 90-) boiler operating day rolling average emission rate, calculated according to section 6.2 of appendix A to the subpart, is the average of all of the valid hourly Hg emission rates in the preceding 30- (or, if alternate emissions averaging is used, a 90-) boiler operating days. Section <IP_ADDRESS> of appendix A to this subpart explains how to reduce sorbent trap monitoring system data to an hourly basis. (§63.10010(g))

If the permittee uses a PM CPMS to demonstrate continuous compliance with an operating limit, the permittee shall install, calibrate, maintain, and operate the PM CPMS and record the output of the system as specified in paragraphs (h)(1) through (5) of this section. (§63.10010(h))

 Install, calibrate, operate, and maintain the permittee's PM CPMS according to the procedures in the permittee's approved site-specific monitoring plan developed in accordance with §63.10000(d), and meet the requirements in paragraphs (h)(1)(i) through (iii) of this section. (§63.10010(h)(1))
 The operating principle of the PM CPMS shall be based on in-stack or extractive light scatter, light scintillation, beta attenuation, or mass accumulation detection of the exhaust gas or representative sample. The reportable measurement output from the PM CPMS may be expressed as milliamps, stack concentration, or other raw data signal.
 The PM CPMS shall have a cycle time ( i.e. , period required to complete sampling, measurement, and reporting for each measurement) no longer than 60 minutes.
 The PM CPMS shall be capable, at a minimum, of detecting and responding to particulate matter concentrations of 0.5 mg/acm.
 For a new unit, complete the initial PM CPMS performance evaluation no later than October 13, 2012 or 180 days after the date of initial startup, whichever is later. For an existing unit, complete the initial performance evaluation no later than October 13, 2015. (§63.10010(h)(2))
 Collect PM CPMS hourly average output data for all boiler operating hours except as indicated in paragraph (h)(5) of this section. Express the PM CPMS output as milliamps, PM concentration, or other raw data signal value. (§63.10010(h)(3))
 Calculate the arithmetic 30-boiler operating day rolling average of all of the hourly average PM CPMS output collected during all nonexempt boiler operating hours data (e.g., milliamps, PM concentration, raw data signal). (§63.10010(h)(4))
 The permittee shall collect data using the PM CPMS at all times the process unit is operating and at the intervals specified in paragraph (h)(1)(ii) of this section, except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions, required monitoring system quality assurance or quality control activities (including, as applicable, calibration checks and required zero and span adjustments), and any scheduled maintenance as defined in the permittee's site-specific monitoring plan. (§63.10010(h)(5))
 The permittee shall use all the data collected during all boiler operating hours in assessing the compliance with the permittee's operating limit except: (§63.10010(h)(6))
 Any data collected during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or quality control activities conducted during monitoring system malfunctions are not used in calculations (report any such periods in the permittee's annual deviation report);
 Any data collected during periods when the monitoring system is out of control as specified in the permittee's site-specific monitoring plan, repairs associated with periods when the monitoring system is out of control, or required monitoring system quality assurance or quality control activities conducted during out-of-control periods are not used in calculations (report emissions or operating levels and report any such periods in the permittee's annual deviation report);
 Any data recorded during periods of startup or shutdown.
 The permittee shall record and make available upon request results of PM CPMS system performance audits, as well as the dates and duration of periods from when the PM CPMS is out of control until completion of the corrective actions necessary to return the PM CPMS to operation consistent with the permittee's site-specific monitoring plan. (§63.10010(h)(7))
 If the permittee chooses to comply with the PM filterable emissions limit in lieu of metal HAP limits, the permittee may choose to install, certify, operate, and maintain a PM CEMS and record the output of the PM CEMS as specified in paragraphs (i)(1) through (5) of this section. The compliance limit shall be expressed as a 30-boiler operating day rolling average of the numerical emissions limit value applicable for the permittee's unit in tables 1 or 2 to this subpart. (§63.10010(h)(7)(i))
 Install and certify the permittee's PM CEMS according to the procedures and requirements in Performance Specification 11 -- Specifications and Test Procedures for Particulate Matter Continuous Emission Monitoring Systems at Stationary Sources in Appendix B to part 60 of this chapter, using Method 5 at Appendix A - 3 to part 60 of this chapter and ensuring that the front half filter temperature shall be 160° +- 14 °C (320° +- 25 °F). The reportable measurement output from the PM CEMS shall be expressed in units of the applicable emissions limit (e.g., lb/MMBtu, lb/MWh). (§63.10010(h)(7)(i)(1))
 Operate and maintain the permittee's PM CEMS according to the procedures and requirements in Procedure 2 -- Quality Assurance Requirements for Particulate Matter Continuous Emission Monitoring Systems at Stationary Sources in Appendix F to part 60 of this chapter. (§63.10010(h)(7)(i)(2))
 The permittee shall conduct the relative response audit (RRA) for the permittee's PM CEMS at least once annually.
 The permittee shall conduct the relative correlation audit (RCA) for the permittee's PM CEMS at least once every 3 years.
 Collect PM CEMS hourly average output data for all boiler operating hours except as indicated in paragraph (i) of this section. (§63.10010(h)(7)(i)(3))
 Calculate the arithmetic 30-boiler operating day rolling average of all of the hourly average PM CEMS output data collected during all nonexempt boiler operating hours. (§63.10010(h)(7)(i)(4))
 The permittee shall collect data using the PM CEMS at all times the process unit is operating and at the intervals specified in paragraph (a) of this section, except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions, and required monitoring system quality assurance or quality control activities. (§63.10010(h)(7)(i)(5))
 The permittee shall use all the data collected during all boiler operating hours in assessing the compliance with the permittee's operating limit except:
 Any data collected during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities conducted during monitoring system malfunctions in calculations and report any such periods in the permittee's annual deviation report;
 Any data collected during periods when the monitoring system is out of control as specified in the permittee's site-specific monitoring plan, repairs associated with periods when the monitoring system is out of control, or required monitoring system quality assurance or control activities conducted during out of control periods in calculations used to report emissions or operating levels and report any such periods in the permittee's annual deviation report;
 Any data recorded during periods of startup or shutdown.
 The permittee shall record and make available upon request results of PM CEMS system performance audits, dates and duration of periods when the PM CEMS is out of control to completion of the corrective actions necessary to return the PM CEMS to operation consistent with the permittee's site-specific monitoring plan.

The permittee may choose to comply with the metal HAP emissions limits using CEMS approved in accordance with §63.7(f) as an alternative to the performance test method specified in this rule. If approved to use a HAP metals CEMS, the compliance limit shall be expressed as a 30-boiler operating day rolling average of the numerical emissions limit value applicable for the permittee's unit in tables 1 or 2. If approved, the permittee may choose to install, certify, operate, and maintain a HAP metals CEMS and record the output of the HAP metals CEMS as specified in paragraphs (j)(1) through (5) of this section. (§63.10010(j))

 Install and certify the permittee's HAP metals CEMS according to the procedures and requirements in the permittee's approved site specific test plan as required in §63.7(e). The reportable measurement output from the HAP metals CEMS shall be expressed in units of the applicable emissions limit (e.g., lb/MMBtu, lb/MWh) and in the form of a 30-boiler operating day rolling average. (§63.10010(j)(1))
 Operate and maintain the permittee's HAP metals CEMS according to the procedures and criteria in the permittee's site specific performance evaluation and quality control program plan required in §63.8(d). (§63.10010(j)(1)(i))
 Collect HAP metals CEMS hourly average output data for all boiler operating hours except as indicated in section (j)(4) of this section. (§63.10010(j)(2))
 Calculate the arithmetic 30-boiler operating day rolling average of all of the hourly average HAP metals CEMS output data collected during all nonexempt boiler operating hours data. (§63.10010(j)(3))
 The permittee shall collect data using the HAP metals CEMS at all times the process unit is operating and at the intervals specified in paragraph (a) of this section, except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions, and required monitoring system quality assurance or quality control activities. (§63.10010(j)(4))
 The permittee shall use all the data collected during all boiler operating hours in assessing the compliance with the permittee's emission limit except: (§63.10010(j)(4)(i))
 Any data collected during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities conducted during monitoring system malfunctions in calculations and report any such periods in the permittee's annual deviation report;
 Any data collected during periods when the monitoring system is out of control as specified in the permittee's site-specific monitoring plan, repairs associated with periods when the monitoring system is out of control, or required monitoring system quality assurance or control activities conducted during out of control periods in calculations used to report emissions or operating levels and report any such periods in the permittee's annual deviation report;
 Any data recorded during periods of startup or shutdown.
 The permittee shall record and make available upon request results of HAP metals CEMS system performance audits, dates and duration of periods when the HAP metals CEMS is out of control to completion of the corrective actions necessary to return the HAP metals CEMS to operation consistent with the permittee's site-specific performance evaluation and quality control program plan. (§63.10010(j)(4)(ii))

The permittee shall operate the monitoring system and collect data at all required intervals at all times that the affected EGU is operating, except for periods of monitoring system malfunctions or out-of-control periods (see §63.8(c)(7) of this part), and required monitoring system quality assurance or quality control activities, including, as applicable, calibration checks and required zero and span adjustments. the permittee is required to affect monitoring system repairs in response to monitoring system malfunctions and to return the monitoring system to operation as expeditiously as practicable. (§63.10020(b))

The permittee may not use data recorded during EGU startup or shutdown or monitoring system malfunctions or monitoring system out-of-control periods, repairs associated with monitoring system malfunctions or monitoring system out-of-control periods, or required monitoring system quality assurance or control activities in calculations used to report emissions or operating levels. The permittee shall use all the data collected during all other periods in assessing the operation of the control device and associated control system. (§63.10020(c))

Except for periods of monitoring system malfunctions or monitoring system out-of-control periods, repairs associated with monitoring system malfunctions or monitoring system out-of-control periods, and required monitoring system quality assurance or quality control activities including, as applicable, calibration checks and required zero and span adjustments), failure to collect required data is a deviation from the monitoring requirements. (§63.10020(d))

Except as otherwise provided in §63.10020(c), if the permittee uses a CEMS to measure SO2, PM, HCl, HF, or Hg emissions, or using a sorbent trap monitoring system to measure Hg emissions, the permittee shall demonstrate continuous compliance by using all quality-assured hourly data recorded by the CEMS (or sorbent trap monitoring system) and the other required monitoring systems (e.g., flow rate, CO2, O2, or moisture systems) to calculate the arithmetic average emissions rate in units of the standard on a continuous 30-boiler operating day (or, if alternate emissions averaging is used for Hg, 90-boiler operating day) rolling average basis, updated at the end of each new boiler operating day. Use Equation 8 to determine the 30- (or, if applicable, 90-) boiler operating day rolling average. (§63.10021(b))

      Where:
            Heriis the hourly emissions rate for hour i and n is the number of hourly emissions rate values collected over 30- (or, if applicable, 90-) boiler operating days.
If the permittee uses a PM CPMS data to measure compliance with an operating limit in Table 4 to this subpart, the permittee shall record the PM CPMS output data for all periods when the process is operating and the PM CPMS is not out-of-control. The permittee shall demonstrate continuous compliance by using all quality-assured hourly average data collected by the PM CPMS for all operating hours to calculate the arithmetic average operating parameter in units of the operating limit (e.g., milliamps, PM concentration, raw data signal) on a 30 operating day rolling average basis, updated at the end of each new boiler operating day. Use Equation 9 to determine the 30 boiler operating day average. (§63.10021(c))

      Where:
            Hpviis the hourly parameter value for hour i and n is the number of valid hourly parameter values collected over 30 boiler operating days.
If the permittee uses quarterly performance testing to demonstrate compliance with one or more applicable emissions limits in Table 1 or 2 to this subpart, the permittee (§63.10021(d))

 May skip performance testing in those quarters during which less than 168 boiler operating hours occur, except that a performance test shall be conducted at least once every calendar year. (§63.10021(d)(1))
 Shall conduct the performance test as defined in Table 5 to this subpart and calculate the results of the testing in units of the applicable emissions standard. (§63.10021(d)(2))

During the initial performance test or any such subsequent performance test that demonstrates compliance with the filterable PM, individual non-mercury HAP metals, or total non-mercury HAP metals limit in Table 1 or 2, record all hourly average output values (e.g., milliamps, stack concentration, or other raw data signal) from the PM CPMS for the periods corresponding to the test runs (e.g., nine 1-hour average PM CPMS output values for three 3-hour test runs). (§63.10023(a))

Determine the permittee's operating limit as the highest 1-hour average PM CPMS output value recorded during the performance test. The permittee shall verify an existing or establish a new operating limit after each repeated performance test. (§63.10023(b))

The permittee shall operate and maintain the permittee's process and control equipment such that the 30 operating day average PM CPMS output does not exceed the operating limit determined in paragraphs (a) and (b) of this section. (§63.10023(c))

Record Keeping Requirements

The permittee shall keep records according to paragraphs (a)(1) and (2) of this section. If the permittee is required to (or elect to) continuously monitor Hg and/or HCl and/or HF emissions, the permittee shall also keep the records required under appendix A and/or appendix B to this subpart. (§63.10032(a))

 A copy of each notification and report that the permittee submitted to comply with this subpart, including all documentation supporting any Initial Notification or Notification of Compliance Status or semiannual compliance report that the permittee submitted, according to the requirements in §63.10(b)(2)(xiv). (§63.10032(a)(1))
 Records of performance stack tests, fuel analyses, or other compliance demonstrations and performance evaluations, as required in §63.10(b)(2)(viii). (§63.10032(a)(2))

For each CEMS and CPMS, the permittee shall keep records according to paragraphs (b)(1) through (4) of this section. (§63.10032(b))

 Records described in §63.10(b)(2)(vi) through (xi). (§63.10032(b)(1))
 Previous ( i.e. , superseded) versions of the performance evaluation plan as required in §63.8(d)(3). (§63.10032(b)(2))
 Request for alternatives to relative accuracy test for CEMS as required in §63.8(f)(6)(i). (§63.10032(b)(3))
 Records of the date and time that each deviation started and stopped, and whether the deviation occurred during a period of startup, shutdown, or malfunction or during another period. (§63.10032(b)(4))

The permittee shall keep the records required in Table 7 to this subpart including records of all monitoring data and calculated averages for applicable PM CPMS operating limits to show continuous compliance with each emission limit and operating limit that applies to the permittee. (§63.10032(c))

For each EGU subject to an emission limit, the permittee shall also keep the records in paragraphs (d)(1) through (3) of this section. (§63.10032(d))

 The permittee shall keep records of monthly fuel use by each EGU, including the type(s) of fuel and amount(s) used. ((§63.10032(d)(1))
 If the permittee combusts non-hazardous secondary materials that have been determined not to be solid waste pursuant to 40 CFR 241.3(b)(1), the permittee shall keep a record which documents how the secondary material meets each of the legitimacy criteria. If the permittee combusts a fuel that has been processed from a discarded non-hazardous secondary material pursuant to 40 CFR 241.3(b)(2), the permittee shall keep records as to how the operations that produced the fuel satisfies the definition of processing in 40 CFR 241.2. If the fuel received a non-waste determination pursuant to the petition process submitted under 40 CFR 241.3(c), the permittee shall keep a record which documents how the fuel satisfies the requirements of the petition process. (§63.10032(d)(2))
 For an EGU that qualifies as an LEE under §63.10005(h), the permittee shall keep annual records that document that the permittee's emissions in the previous stack test(s) continue to qualify the unit for LEE status for an applicable pollutant, and document that there was no change in source operations including fuel composition and operation of air pollution control equipment that would cause emissions of the pollutant to increase within the past year. (§63.10032(d)(3))

If the permittee elects to average emissions consistent with §63.10009, the permittee shall additionally keep a copy of the emissions averaging implementation plan required in §63.10009(g), all calculations required under §63.10009, including daily records of heat input or steam generation, as applicable, and monitoring records consistent with §63.10022. (§63.10032(e))

The permittee shall keep records of the occurrence and duration of each startup and/or shutdown. (§63.10032(f))

The permittee shall keep records of the occurrence and duration of each malfunction of an operation ( i.e. , process equipment) or the air pollution control and monitoring equipment. (§63.10032(g))

The permittee shall keep records of actions taken during periods of malfunction to minimize emissions in accordance with §63.10000(b), including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation. (§63.10032(h))

The permittee shall keep records of the type(s) and amount(s) of fuel used during each startup or shutdown. (§63.10032(h)(i))

The permittee's records shall be in a form suitable and readily available for expeditious review, according to §63.10(b)(1). (§63.10033(a))

As specified in §63.10(b)(1), the permittee shall keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. (§63.10033(b))

The permittee shall keep each record on site for at least 2 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to §63.10(b)(1). The permittee can keep the records off site for the remaining 3 years. (§63.10033(c))

Reporting Requirements

The permittee shall submit each report in Table 8 to this subpart that applies to the permittee. If the permittee is required to (or elect to) continuously monitor Hg and/or HCl and/or HF emissions, the permittee shall also submit the electronic reports required under appendix A and/or appendix B to the subpart, at the specified frequency. (§63.10031(a))

Unless the Administrator or the Department has approved a different schedule for submission of reports under §63.10(a), the permittee shall submit each report by the date in Table 8 to this subpart and according to the requirements in paragraphs (b)(1) through (5) of this section. (§63.10031(b))
 The first compliance report shall cover the period beginning on the compliance date that is specified for the permittee's affected source in §63.9984 and ending on June 30 or December 31, whichever date is the first date that occurs at least 180 days after the compliance date that is specified for the permittee's source in §63.9984. (§63.10031(b)(1))
 The first compliance report shall be postmarked or submitted electronically no later than July 31 or January 31, whichever date is the first date following the end of the first calendar half after the compliance date that is specified for the permittee's source in §63.9984. (§63.10031(b)(2))
 Each subsequent compliance report shall cover the semiannual reporting period from January 1 through June 30 or the semiannual reporting period from July 1 through December 31. (§63.10031(b)(3))
 Each subsequent compliance report shall be postmarked or submitted electronically no later than July 31 or January 31, whichever date is the first date following the end of the semiannual reporting period. (§63.10031(b)(4))
 For each affected source that is subject to permitting regulations pursuant to part 70 or part 71 of this chapter, and if the permitting authority has established dates for submitting semiannual reports pursuant to 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), the permittee may submit the first and subsequent compliance reports according to the dates the permitting authority has established instead of according to the dates in paragraphs (b)(1) through (4) of this section. (§63.10031(b)(5))

The compliance report shall contain the information required in paragraphs (c)(1) through (4) of this section. (§63.10031(c))
 The information required by the summary report located in 63.10(e)(3)(vi). (§63.10031(c)(1))
 The total fuel use by each affected source subject to an emission limit, for each calendar month within the semiannual reporting period, including, but not limited to, a description of the fuel, whether the fuel has received a non-waste determination by EPA or the permittee's basis for concluding that the fuel is not a waste, and the total fuel usage amount with units of measure. (§63.10031(c)(2))
 Indicate whether the permittee burned new types of fuel during the reporting period. If the permittee did burn new types of fuel the permittee shall include the date of the performance test where that fuel was in use. (§63.10031(c)(3))
 Include the date of the most recent tune-up for each unit subject to the requirement to conduct a performance tune-up according to §63.10021(e). Include the date of the most recent burner inspection if it was not done every 36 (or 48) months and was delayed until the next scheduled unit shutdown. (§63.10031(c)(4))

For each excess emissions occurring at an affected source where the permittee is using a CMS to comply with that emission limit or operating limit, the permittee shall include the information required in §63.10(e)(3)(v) in the compliance report specified in section (c). (§63.10031(d))

Each affected source that has obtained a Title V operating permit pursuant to part 70 or part 71 of this chapter shall report all deviations as defined in this subpart in the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A). If an affected source submits a compliance report pursuant to Table 8 to this subpart along with, or as part of, the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), and the compliance report includes all required information concerning deviations from any emission limit, operating limit, or work practice requirement in this subpart, submission of the compliance report satisfies any obligation to report the same deviations in the semiannual monitoring report. Submission of a compliance report does not otherwise affect any obligation the affected source may have to report deviations from permit requirements to the permit authority. (§63.10031(e))

On or after July 1, 2020, and within 60 days after the date of completing each performance test, the permittee shall submit the results of the performance tests required by this subpart to EPA's WebFIRE database by using the Compliance and Emissions Data Reporting Interface (CEDRI) that is accessed through EPA's Central Data Exchange (CDX) ( www.epa.gov/cdx ). Performance test data shall be submitted in the file format generated through use of EPA's Electronic Reporting Tool (ERT) (see http://www.epa.gov/ttn/chief/ert/index.html ). Only data collected using those test methods on the ERT Web site are subject to this requirement for submitting reports electronically to WebFIRE. Owners or operators who claim that some of the information being submitted for performance tests is confidential business information (CBI) shall submit a complete ERT file including information claimed to be CBI on a compact disk or other commonly used electronic storage media (including, but not limited to, flash drives) to EPA. The electronic media shall be clearly marked as CBI and mailed to U.S. EPA/OAPQS/CORE CBI Office, Attention: WebFIRE Administrator, MD C404 - 02, 4930 Old Page Rd., Durham, NC 27703. The same ERT file with the CBI omitted shall be submitted to EPA via CDX as described earlier in this paragraph. At the discretion of the delegated authority, the permittee shall also submit these reports, including the confidential business information, to the delegated authority in the format specified by the delegated authority. (§63.10031(f))

 On or after July 1, 2020, within 60 days after the date of completing each CEMS (SO2, PM, HCl, HF, and Hg) performance evaluation test, as defined in §63.2 and required by this subpart, the permittee shall submit the relative accuracy test audit (RATA) data (or, for PM CEMS, RCA and RRA data) required by this subpart to EPA's WebFIRE database by using the Compliance and Emissions Data Reporting Interface (CEDRI) that is accessed through EPA's Central Data Exchange (CDX) ( www.epa.gov/cdx ). The RATA data shall be submitted in the file format generated through use of EPA's Electronic Reporting Tool (ERT) ( http://www.epa.gov/ttn/chief/ert/index.html ). Only RATA data compounds listed on the ERT Web site are subject to this requirement. Owners or operators who claim that some of the information being submitted for RATAs is confidential business information (CBI) shall submit a complete ERT file including information claimed to be CBI on a compact disk or other commonly used electronic storage media (including, but not limited to, flash drives) by registered letter to EPA and the same ERT file with the CBI omitted to EPA via CDX as described earlier in this paragraph. The compact disk or other commonly used electronic storage media shall be clearly marked as CBI and mailed to U.S. EPA/OAPQS/CORE CBI Office, Attention: WebFIRE Administrator, MD C404 - 02, 4930 Old Page Rd., Durham, NC 27703. At the discretion of the delegated authority, owners or operators shall also submit these RATAs to the delegated authority in the format specified by the delegated authority. Owners or operators shall submit calibration error testing, drift checks, and other information required in the performance evaluation as described in §63.2 and as required in this chapter. (§63.10031(f)(1))
 On or after July 1, 2020, for a PM CEMS, PM CPMS, or approved alternative monitoring using a HAP metals CEMS, within 60 days after the reporting periods ending on March 31st, June 30th, September 30th, and December 31st, the permittee shall submit quarterly reports to EPA's WebFIRE database by using the Compliance and Emissions Data Reporting Interface (CEDRI) that is accessed through EPA's Central Data Exchange (CDX) ( www.epa.gov/cdx ). The permittee shall use the appropriate electronic reporting form in CEDRI or provide an alternate electronic file consistent with EPA's reporting form output format. For each reporting period, the quarterly reports shall include all of the calculated 30-boiler operating day rolling average values derived from the CEMS and PM CPMS. (§63.10031(f)(2))
 Reports for an SO2CEMS, a Hg CEMS or sorbent trap monitoring system, an HCl or HF CEMS, and any supporting monitors for such systems (such as a diluent or moisture monitor) shall be submitted using the ECMPS Client Tool, as provided for in Appendices A and B to this subpart and §63.10021(f). (§63.10031(f)(3))
 On or after July 1, 2020, submit the compliance reports required under paragraphs (c) and (d) of this section and the notification of compliance status required under §63.10030(e) to EPA's WebFIRE database by using the Compliance and Emissions Data Reporting Interface (CEDRI) that is accessed through EPA's Central Data Exchange (CDX) ( www.epa.gov/cdx ). The permittee shall use the appropriate electronic reporting form in CEDRI or provide an alternate electronic file consistent with EPA's reporting form output format. (§63.10031(f)(4))
 All reports required by this subpart not subject to the requirements in paragraphs (f)(1) through (4) of this section shall be sent to the Administrator or the Department at the appropriate address listed in §63.13. If acceptable to both the Administrator or the Department and the owner or operator of a source, these reports may be submitted on electronic media. The Administrator or the Department retains the right to require submittal of reports subject to paragraphs (f)(1), (2), and (3) of this section in paper format. (§63.10031(f)(5))

If the permittee had a malfunction during the reporting period, the compliance report shall include the number, duration, and a brief description for each type of malfunction which occurred during the reporting period and which caused or may have caused any applicable emission limitation to be exceeded. (§63.10031(g))

The permittee shall submit the reports required under §63.10031 and, if applicable, the reports required under appendices A and B to this subpart. The electronic reports required by appendices A and B to this subpart shall be sent to the Administrator or the Department electronically in a format prescribed by the Administrator or the Department, as provided in §63.10031. CEMS data (except for PM CEMS and any approved alternative monitoring using a HAP metals CEMS) shall be submitted using EPA's Emissions Collection and Monitoring Plan System (ECMPS) Client Tool. Other data, including PM CEMS data, HAP metals CEMS data, and CEMS performance test detail reports, shall be submitted in the file format generated through use of EPA's Electronic Reporting Tool, the Compliance and Emissions Data Reporting Interface, or alternate electronic file format, all as provided for under §63.10031. (§63.10021(f))

The permittee shall report each instance in which the permittee did not meet an applicable emissions limit or operating limit in Tables 1 through 4 to this subpart or failed to conduct a required tune-up. These instances are deviations from the requirements of this subpart. These deviations shall be reported according to §63.10031. (§63.10021(g))

When the permittee is required to conduct an initial compliance demonstration as specified in §63.10011(a), the permittee shall submit a Notification of Compliance Status according to §63.9(h)(2)(ii). The Notification of Compliance Status report shall contain all the information specified in paragraphs (e)(1) through (7), as applicable. (§63.10030(e))

 A description of the affected source(s) including identification of which subcategory the source is in, the design capacity of the source, a description of the add-on controls used on the source, description of the fuel(s) burned, including whether the fuel(s) were determined by the permittee or EPA through a petition process to be a non-waste under 40 CFR 241.3, whether the fuel(s) were processed from discarded non-hazardous secondary materials within the meaning of 40 CFR 241.3, and justification for the selection of fuel(s) burned during the performance test. (§63.10030(e)(1))
 Summary of the results of all performance tests and fuel analyses and calculations conducted to demonstrate initial compliance including all established operating limits. (§63.10030(e)(2))
 Identification of whether the permittee plans to demonstrate compliance with each applicable emission limit through performance testing; fuel moisture analyses; performance testing with operating limits (e.g., use of PM CPMS); CEMS; or a sorbent trap monitoring system. (§63.10030(e)(3))
 Identification of whether the permittee plans to demonstrate compliance by emissions averaging. (§63.10030(e)(4))
 A signed certification that the permittee has met all applicable emission limits and work practice standards. (§63.10030(e)(5))
 If the permittee had a deviation from any emission limit, work practice standard, or operating limit, the permittee shall also submit a brief description of the deviation, the duration of the deviation, emissions point identification, and the cause of the deviation in the Notification of Compliance Status report. (§63.10030(e)(6))
 In addition to the information required in §63.9(h)(2), the permittee's notification of compliance status shall include the following: (§63.10030(e)(7))
 A summary of the results of the annual performance tests and documentation of any operating limits that were reestablished during this test, if applicable. If the permittee  is conducting stack tests once every 3 years consistent with §63.10006(b), the date of the last three stack tests, a comparison of the emission level the permittee achieved in the last three stack tests to the 50 percent emission limit threshold required in §63.10006(i), and a statement as to whether there have been any operational changes since the last stack test that could increase emissions.
 Certifications of compliance, as applicable, and shall be signed by a responsible official stating:
 "This EGU complies with the requirements in §63.10021(a) to demonstrate continuous compliance." and
 "No secondary materials that are solid waste were combusted in any affected unit."

Work Practice Standards

The permittee shall meet each of the following work practice standards: (§63.9991(a)(1), Table 3 to 40 CFR Part 63 Subpart UUUUU, §63.10011(g), (§63.10005(e))

 Conduct a tune-up of the EGU burner and combustion controls at least each 36 calendar months, or each 48 calendar months if neural network combustion optimization software is employed, as specified in §63.10021(e).
 During startup, the permitte shall operate all CMS during startup. Startup means either the first-ever firing of fuel in a boiler for the purpose of producing electricity, or the firing of fuel in a boiler after a shutdown event for any purpose. Startup ends when any of the steam from the boiler is used to generate electricity for sale over the grid or for any other purpose (including on site use). For startup of a unit, the permitee shall use clean fuels, either natural gas or distillate oil or a combination of clean fuels for ignition. Once the permittee converts to firing coal or synfuel, the permittee shall engage all of the applicable control technologies except the SCR. The permittee shall start the SCR system, appropriately to comply with relevant standards applicable during normal operation. The permittee shall comply with all applicable emissions limits at all times except for periods that meet the definitions of startup and shutdown in 40 CFR Part 63 Subpart UUUUU.. The permittee shall keep records during periods of startup. The permittee shall provide reports concerning activities and periods of startup, as specified in §63.10011(g) and §63.10021(h) and (i).
 During shutdown, the permitte shall operate all CMS during shutdown. Shutdown means the cessation of operation of a boiler for any purpose. Shutdown begins either when none of the steam from the boiler is used to generate electricity for sale over the grid or for any other purpose (including on-site use) or at the point of no fuel being fired in the boiler. Shutdown ends when there is both no electricity being generated and no fuel being fired in the boiler. During shutdown, the permitte shall operate all applicable control technologies while firing coal, residual oil, or solid oil-derived fuel. The permittee shall comply with all applicable emissions limits at all times except for periods that meet the definitions of startup and shutdown in this subpart. The permittee shall keep records during periods of startup. The permittee shall provide reports concerning activities and periods of startup, as specified in §63.10011(g) and §63.10021(h) and (i).

All air pollution control equipment necessary for compliance with any newly applicable emissions limits which apply as a result of the cessation or commencement or recommencement of operations that cause the permittee's EGU to meet the definition of an EGU subject to this subpart shall be installed and operational as of the date the permittee's source ceases to be or becomes subject to this subpart. (§63.10000(j))

For an existing EGU without a neural network, a tune-up, following the procedures in §63.10021(e), must occur within 6 months (180 days) after April 16, 2015. For an existing EGU with a neural network, a tune-up must occur within 18 months (545 days) after April 16, 2016. If a tune-up occurs prior to April 16, 2015, you must keep records showing that the tune-up met all rule requirements. (§63.10005(f))

If the permittee shall conduct periodic performance tune-ups of the permittee's EGU(s), as specified in paragraphs (e)(1) through (9) of this section, perform the first tune-up as part of the permittee's initial compliance demonstration. Notwithstanding this requirement, the permittee may delay the first burner inspection until the next scheduled unit outage provided the permittee meets the requirements of §63.10005. Subsequently, the permittee shall perform an inspection of the burner at least once every 36 calendar months unless the permittee's EGU employs neural network combustion optimization during normal operations in which case the permittee shall perform an inspection of the burner and combustion controls at least once every 48 calendar months. (§63.10021(e))

 As applicable, inspect the burner and combustion controls, and clean or replace any components of the burner or combustion controls as necessary upon initiation of the work practice program and at least once every required inspection period. Repair of a burner or combustion control component requiring special order parts may be scheduled as follows: (§63.10021(e)(1))
 Burner or combustion control component parts needing replacement that affect the ability to optimize NOXand CO shall be installed within 3 calendar months after the burner inspection,
 Burner or combustion control component parts that do not affect the ability to optimize NOXand CO may be installed on a schedule determined by the operator;
 As applicable, inspect the flame pattern and make any adjustments to the burner or combustion controls necessary to optimize the flame pattern. The adjustment should be consistent with the manufacturer's specifications, if available, or in accordance with best combustion engineering practice for that burner type; (§63.10021(e)(2))
 As applicable, observe the damper operations as a function of mill and/or cyclone loadings, cyclone and pulverizer coal feeder loadings, or other pulverizer and coal mill performance parameters, making adjustments and effecting repair to dampers, controls, mills, pulverizers, cyclones, and sensors; (§63.10021(e)(3))
 As applicable, evaluate windbox pressures and air proportions, making adjustments and effecting repair to dampers, actuators, controls, and sensors; (§63.10021(e)(4))
 Inspect the system controlling the air-to-fuel ratio and ensure that it is correctly calibrated and functioning properly. Such inspection may include calibrating excess O2probes and/or sensors, adjusting overfire air systems, changing software parameters, and calibrating associated actuators and dampers to ensure that the systems are operated as designed. Any component out of calibration, in or near failure, or in a state that is likely to negate combustion optimization efforts prior to the next tune-up, should be corrected or repaired as necessary; (§63.10021(e)(5))
 Optimize combustion to minimize generation of CO and NOX. This optimization should be consistent with the manufacturer's specifications, if available, or best combustion engineering practice for the applicable burner type. NOXoptimization includes burners, overfire air controls, concentric firing system improvements, neural network or combustion efficiency software, control systems calibrations, adjusting combustion zone temperature profiles, and add-on controls such as SCR and SNCR; CO optimization includes burners, overfire air controls, concentric firing system improvements, neural network or combustion efficiency software, control systems calibrations, and adjusting combustion zone temperature profiles; (§63.10021(e)(6))
 While operating at full load or the predominantly operated load, measure the concentration in the effluent stream of CO and NOXin ppm, by volume, and oxygen in volume percent, before and after the tune-up adjustments are made (measurements may be either on a dry or wet basis, as long as it is the same basis before and after the adjustments are made). The permittee may use portable CO, NOXand O2monitors for this measurement. EGU's employing neural network optimization systems need only provide a single pre- and post-tune-up value rather than continual values before and after each optimization adjustment made by the system; (§63.10021(e)(7))
 Maintain on-site and submit, if requested by the Administrator or the Department, an annual report containing the information in paragraphs (e)(1) through (e)(9) of this section including: (§63.10021(e)(8))
 The concentrations of CO and NOXin the effluent stream in ppm by volume, and oxygen in volume percent, measured before and after an adjustment of the EGU combustion systems;
 A description of any corrective actions taken as a part of the combustion adjustment; and
 The type(s) and amount(s) of fuel used over the 12 calendar months prior to an adjustment, but only if the unit was physically and legally capable of using more than one type of fuel during that period; and
 Report the dates of the initial and subsequent tune-ups in hard copy, as specified in 63.10031(f)(5), through June 30, 2020. On or after July 1, 2020, report the date of all tune-ups electronically, in accordance with §63.10031(f). The tune-up report date is the date when tune-up requirements in paragraphs (e)(6) and (7) of this section are completed. (§63.10021(e)(9))

If the permittee is required to meet an applicable tune-up work practice standard, the permittee shall conduct a performance tune-up according to §63.10021(e). (§63.10006(i))

 For EGUs not employing neural network combustion optimization during normal operation, each performance tune-up specified in §63.10021(e) shall be no more than 36 calendar months after the previous performance tune-up. (§63.10006(i)(1))
 For EGUs employing neural network combustion optimization systems during normal operation, each performance tune-up specified in §63.10021(e) shall be no more than 48 calendar months after the previous performance tune-up. (§63.10006(i)(2))

Hg Monitoring Provisions

General Provisions

 Applicability. The Hg CEMS or sorbent trap monitoring system shall be capable of measuring the total vapor phase mercury in units of the applicable emissions standard (e.g., lb/TBtu or lb/GWh), regardless of speciation. (40 CFR Part 63 Subpart UUUUU Appendix A 1.1)
 Initial Certification and Recertification Procedures. The owner or operator of an affected unit that uses a Hg CEMS or a sorbent trap monitoring system together with other necessary monitoring components to account for Hg emissions in units of the applicable emissions standard shall comply with the initial certification and recertification procedures in section 4 of this appendix. (40 CFR Part 63 Subpart UUUUU Appendix A 1.2)
 Quality Assurance and Quality Control Requirements. The owner or operator of an affected unit that uses a Hg CEMS or a sorbent trap monitoring system together with other necessary monitoring components to account for Hg emissions in units of the applicable emissions standard shall meet the applicable quality assurance requirements in section 5 of this appendix. (40 CFR Part 63 Subpart UUUUU Appendix A 1.3)
 Missing Data Procedures. The owner or operator of an affected unit is not required to substitute for missing data from Hg CEMS or sorbent trap monitoring systems. Any process operating hour for which quality-assured Hg concentration data are not obtained is counted as an hour of monitoring system downtime. (40 CFR Part 63 Subpart UUUUU Appendix A 1.4)
 Preventive Maintenance. Keep a written record of procedures needed to maintain the Hg CEMS and/or sorbent trap monitoring system(s) in proper operating condition and a schedule for those procedures. Include, at a minimum, all procedures specified by the manufacturers of the equipment and, if applicable, additional or alternate procedures developed for the equipment. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Recordkeeping and Reporting. Keep a written record describing procedures that shall be used to implement the recordkeeping and reporting requirements of this appendix. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Maintenance Records. Keep a record of all testing, maintenance, or repair activities performed on any Hg CEMS or sorbent trap monitoring system in a location and format suitable for inspection. A maintenance log may be used for this purpose. The following records should be maintained: date, time, and description of any testing, adjustment, repair, replacement, or preventive maintenance action performed on any monitoring system and records of any corrective actions associated with a monitor outage period. Additionally, any adjustment that may significantly affect a system's ability to accurately measure emissions data shall be recorded (e.g., changing the dilution ratio of a CEMS), and a written explanation of the procedures used to make the adjustment(s) shall be kept. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)

Monitoring of Hg Emissions

 Monitoring System Installation Requirements. Flue gases from the affected units under this subpart vent to the atmosphere through a variety of exhaust configurations including single stacks, common stack configurations, and multiple stack configurations. For each of these configurations, §63.10010(a) specifies the appropriate location(s) at which to install continuous monitoring systems (CMS). These CMS installation provisions apply to the Hg CEMS, sorbent trap monitoring systems, and other continuous monitoring systems that provide data for the Hg emissions calculations in section 6.2 of this appendix. (40 CFR Part 63 Subpart UUUUU Appendix A 2.1)
 Primary and Backup Monitoring Systems. In the electronic monitoring plan described in section <IP_ADDRESS>.1 of this appendix, the permittee must designate a primary Hg CEMS or sorbent trap monitoring system. The primary system must be used to report hourly Hg concentration values when the system is able to provide quality-assured data, i.e., when the system is "in control". However, to increase data availability in the event of a primary monitoring system outage, the permittee may install, operate, maintain, and calibrate backup monitoring systems, as follows: (40 CFR Part 63 Subpart UUUUU Appendix A 2.2)
 Redundant Backup Systems. A redundant backup monitoring system may be either a separate Hg CEMS with its own probe, sample interface, and analyzer, or a separate sorbent trap monitoring system. A redundant backup system is one that is permanently installed at the unit or stack location, and is kept on "hot standby" in case the primary monitoring system is unable to provide quality-assured data. A redundant backup system must be represented as a unique monitoring system in the electronic monitoring plan. Each redundant backup monitoring system must be certified according to the applicable provisions in section 4 of this appendix and must meet the applicable on-going QA requirements in section 5 of this appendix. (40 CFR Part 63 Subpart UUUUU Appendix A 2.2.1)
 Non-redundant Backup Monitoring Systems. A non-redundant backup monitoring system is a separate Hg CEMS or sorbent trap system that has been certified at a particular unit or stack location, but is not permanently installed at that location. Rather, the system is kept on "cold standby" and may be reinstalled in the event of a primary monitoring system outage. A non-redundant backup monitoring system must be represented as a unique monitoring system in the electronic monitoring plan. Non-redundant backup Hg CEMS must complete the same certification tests as the primary monitoring system, with one exception. The 7-day calibration error test is not required for a non-redundant backup Hg CEMS. Except as otherwise provided in section <IP_ADDRESS> of this appendix, a non-redundant backup monitoring system may only be used for 720 hours per year at a particular unit or stack location. (40 CFR Part 63 Subpart UUUUU Appendix A 2.2.2)
 Temporary Like-kind Replacement Analyzers. When a primary Hg analyzer needs repair or maintenance, the permittee may temporarily install a like-kind replacement analyzer, to minimize data loss. Except as otherwise provided in section <IP_ADDRESS> of this appendix, a temporary like-kind replacement analyzer may only be used for 720 hours per year at a particular unit or stack location. The analyzer must be represented as a component of the primary Hg CEMS, and must be assigned a 3-character component ID number, beginning with the prefix "LK". (40 CFR Part 63 Subpart UUUUU Appendix A 2.2.3)
 Quality Assurance Requirements for Non-redundant Backup Monitoring Systems and Temporary Like-kind Replacement Analyzers. To quality-assure the data from non-redundant backup Hg monitoring systems and temporary like-kind replacement Hg analyzers, the following provisions apply: (40 CFR Part 63 Subpart UUUUU Appendix A 2.2.4)
 When a certified non-redundant backup sorbent trap monitoring system is brought into service, the permittee must follow the procedures for routine day-to-day operation of the system, in accordance with Performance Specification (PS) 12B in appendix B to part 60 of this chapter. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 When a certified non-redundant backup Hg CEMS or a temporary like-kind replacement Hg analyzer is brought into service, a calibration error test and a linearity check must be performed and passed. A single point system integrity check is also required, unless a NIST-traceable source of oxidized Hg was used for the calibration error test. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Each non-redundant backup Hg CEMS or temporary like-kind replacement Hg analyzer shall comply with all required daily, weekly, and quarterly quality-assurance test requirements in section 5 of this appendix, for as long as the system or analyzer remains in service. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 For the routine, on-going quality-assurance of a non-redundant backup Hg monitoring system, a relative accuracy test audit (RATA) must be performed and passed at least once every 8 calendar quarters at the unit or stack location(s) where the system will be used. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 To use a non-redundant backup Hg monitoring system or a temporary like-kind replacement analyzer for more than 720 hours per year at a particular unit or stack location, a RATA must first be performed and passed at that location. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)

Continuous Monitoring Methods.  The Hg CEMS shall meet the performance specifications in 40 CFR Part 63 Subpart UUUUU Appendix A Section 4.1.1.  The methods used shall comform to the standards and procedures in 40 CFR Part 63 Subpart UUUUU Appendix A Section 3.2. (40 CFR Part 63 Subpart UUUUU Appendix A 3.2)

Certification and Recertification Requirements

 Certification Requirements. All Hg CEMS and sorbent trap monitoring systems and the additional monitoring systems used to continuously measure Hg emissions in units of the applicable emissions standard in accordance with this appendix must be certified in a timely manner, such that the initial compliance demonstration is completed no later than the applicable date in §63.10005(g). (40 CFR Part 63 Subpart UUUUU Appendix A 4.1)
 Hg CEMS. Table A - 1, below, summarizes the certification test requirements and performance specifications for a Hg CEMS. The CEMS may not be used to report quality-assured data until these performance criteria are met. Paragraphs <IP_ADDRESS> through <IP_ADDRESS> of this section provide specific instructions for the required tests. All tests must be performed with the affected unit(s) operating ( i.e., combusting fuel). Except for the RATA, which must be performed at normal load, no particular load level is required for the certification tests. (40 CFR Part 63 Subpart UUUUU Appendix A 4.1.1)
 7-Day Calibration Error Test. Perform the 7-day calibration error test on 7 consecutive source operating days, using a zero-level gas and either a high-level or a mid-level calibration gas standard (as defined in sections 3.1.8, 3.1.10, and 3.1.11 of this appendix). Either elemental or oxidized NIST-traceable Hg standards (as defined in sections 3.1.4 and 3.1.5 of this appendix) may be used for the test. If moisture and/or chlorine is added to the calibration gas, the dilution effect of the moisture and/or chlorine addition on the calibration gas concentration must be accounted for in an appropriate manner. Operate the Hg CEMS in its normal sampling mode during the test. The calibrations should be approximately 24 hours apart, unless the 7-day test is performed over nonconsecutive calendar days. On each day of the test, inject the zero-level and upscale gases in sequence and record the analyzer responses. Pass the calibration gas through all filters, scrubbers, conditioners, and other monitor components used during normal sampling, and through as much of the sampling probe as is practical. Do not make any manual adjustments to the monitor ( i.e., resetting the calibration) until after taking measurements at both the zero and upscale concentration levels. If automatic adjustments are made following both injections, conduct the calibration error test such that the magnitude of the adjustments can be determined, and use only the unadjusted analyzer responses in the calculations. Calculate the calibration error (CE) on each day of the test, as described in Table A - 1. The CE on each day of the test must either meet the main performance specification or the alternative specification in Table A - 1. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Linearity Check. Perform the linearity check using low, mid, and high-level concentrations of NIST-traceable elemental Hg standards. Three gas injections at each concentration level are required, with no two successive injections at the same concentration level. Introduce the calibration gas at the gas injection port, as specified in section <IP_ADDRESS>.3.6 of this appendix. Operate the CEMS at its normal operating temperature and conditions. Pass the calibration gas through all filters, scrubbers, conditioners, and other components used during normal sampling, and through as much of the sampling probe as is practical. If moisture and/or chlorine is added to the calibration gas, the dilution effect of the moisture and/or chlorine addition on the calibration gas concentration must be accounted for in an appropriate manner. Record the monitor response from the data acquisition and handling system for each gas injection. At each concentration level, use the average analyzer response to calculate the linearity error (LE), as described in Table A - 1. The LE must either meet the main performance specification or the alternative specification in Table A - 1. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Three-Level System Integrity Check. Perform the 3-level system integrity check using low, mid, and high-level calibration gas concentrations generated by a NIST-traceable source of oxidized Hg. Follow the same basic procedure as for the linearity check. If moisture and/or chlorine is added to the calibration gas, the dilution effect of the moisture and/or chlorine addition on the calibration gas concentration must be accounted for in an appropriate manner. Calculate the system integrity error (SIE), as described in Table A - 1. The SIE must either meet the main performance specification or the alternative specification in Table A - 1. (Note:This test is not required if the CEMS does not have a converter). (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)

                Table A - 1 -- Required Certification Tests and Performance Specifications for Hg CEMS

                  For this required certification test . . .
                 The main performance specification[1]is . . .
              The alternate performance specification[1]is . . .
          And the conditions of the alternate specification are . . .
7-day calibration error test[2]
R − A; <=5.0% of span value, for both the zero and upscale gases, on each of the 7 days
R − A; <=1.0 ug/scm
The alternate specification may be used on any day of the test.
Linearity check[3]
R − Aavg; <=10.0% of the reference gas concentration at each calibration gas level (low, mid, or high)
R − Aavg; <=0.8 ug/scm
The alternate specification may be used at any gas level.
3-level system integrity check[4]
R − Aavg; <=10.0% of the reference gas concentration at each calibration gas level
R − Aavg; <=0.8 ug/scm
The alternate specification may be used at any gas level.
RATA
20.0% RA
RMavg− Cavg; <=1.0 ug/scm**
RMavg<5.0 ug/scm.
Cycle time test[2]
 minutes.[5]

       [1]Note that R − A; is the absolute value of the difference between the reference gas value and the analyzer reading. R − Aavg,; is the absolute value of the difference between the reference gas concentration and the average of the analyzer responses, at a particular gas level.

       [2]Use either elemental or oxidized Hg standards; a mid-level or high-level upscale gas may be used. This test is not required for Hg CEMS that use integrated batch sampling; however, those monitors must be capable of recording at least one Hg concentration reading every 15 minutes.

       [3]Use elemental Hg standards.

       [4]Use oxidized Hg standards. Not required if the CEMS does not have a converter.

       [5]Stability criteria -- Readings change by <2.0% of span or by <=0.5 ug/scm, for 2 minutes.

       ** Note that RMavg−Cavg; is the absolute difference between the mean reference method value and the mean CEMS value from the RATA. The arithmetic difference between RMavgand Cavgcan be either + or −.

 Cycle Time Test. Perform the cycle time test, using a zero-level gas and a high-level calibration gas.Either an elemental or oxidized NIST-traceable Hg standard may be used as the high-level gas. Perform the test in two stages -- upscale and downscale. The slower of the upscale and downscale response times is the cycle time for the CEMS. Begin each stage of the test by injecting calibration gas after achieving a stable reading of the stack emissions. The cycle time is the amount of time it takes for the analyzer to register a reading that is 95 percent of the way between the stable stack emissions reading and the final, stable reading of the calibration gas concentration. Use the following criterion to determine when a stable reading of stack emissions or calibration gas has been attained -- the reading is stable if it changes by no more than 2.0 percent of the span value or 0.5 ug/scm (whichever is less restrictive) for two minutes, or a reading with a change of less than 6.0 percent from the measured average concentration over 6 minutes. Integrated batch sampling type Hg CEMS are exempted from this test; however, these systems must be capable of delivering a measured Hg concentration reading at least once every 15 minutes. If necessary to increase measurement sensitivity of a batch sampling type Hg CEMS for a specific application, the permittee may petition the Administrator for approval of a time longer than 15 minutes between readings. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Relative Accuracy Test Audit (RATA). Perform the RATA of the Hg CEMS at normal load. Acceptable Hg reference methods for the RATA include ASTM D6784 - 02 (Reapproved 2008), "Standard Test Method for Elemental, Oxidized, Particle-Bound and Total Mercury in Flue Gas Generated from Coal-Fired Stationary Sources (Ontario Hydro Method)" (incorporated by reference, see §63.14) and Methods 29, 30A, and 30B in appendix A - 8 to part 60. When Method 29 or ASTM D6784 - 02 is used, paired sampling trains are required. To validate a Method 29 or ASTM D6784 - 02 test run, calculate the relative deviation (RD) using Equation A - 1 of this section, and assess the results as follows to validate the run. The RD must not exceed 10 percent, when the average Hg concentration is greater than 1.0 ug/dscm. If the average concentration is <= 1.0 ug/dscm, the RD must not exceed 20 percent. The RD results are also acceptable if the absolute difference between the two Hg concentrations does not exceed 0.2 ug/dscm. If the RD specification is met, the results of the two samples shall be averaged arithmetically. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)

       Where:

       RD = Relative deviation between the Hg concentrations of samples "a" and "b" (percent)

       Ca= Hg concentration of Hg sample "a" (ug/dscm)

       Cb= Hg concentration of Hg sample "b" (ug/dscm)

 Special Considerations. A minimum of nine valid test runs must be performed, directly comparing the CEMS measurements to the reference method. More than nine test runs may be performed. If this option is chosen, the results from a maximum of three test runs may be rejected so long as the total number of test results used to determine the relative accuracy is greater than or equal to nine; however, all data must be reported including the rejected data. The minimum time per run is 21 minutes if Method 30A is used. If Method 29, Method 30B, or ASTM D6784 - 02 (Reapproved 2008), "Standard Test Method for Elemental, Oxidized, Particle-Bound and Total Mercury in Flue Gas Generated from Coal-Fired Stationary Sources (Ontario Hydro Method)" (incorporated by reference, see §63.14) is used, the time per run must be long enough to collect a sufficient mass of Hg to analyze. Complete the RATA within 168 unit operating hours, except when Method 29 or ASTM D6784 - 02 is used, in which case up to 336 operating hours may be taken to finish the test. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>.1)
 Calculation of RATA Results. Calculate the relative accuracy (RA) of the monitoring system, on a ug/scm basis, as described in section 12 of Performance Specification (PS) 2 in Appendix B to part 60 of this chapter (see Equations 2 - 3 through 2 - 6 of PS2). For purposes of calculating the relative accuracy, ensure that the reference method and monitoring system data are on a consistent moisture basis, either wet or dry. The CEMS must either meet the main performance specification or the alternative specification in Table A - 1. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>.2)
 Bias Adjustment. Measurement or adjustment of Hg CEMS data for bias is not required. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>.3)
 Sorbent Trap Monitoring Systems. For the initial certification of a sorbent trap monitoring system, only a RATA is required. (40 CFR Part 63 Subpart UUUUU Appendix A 4.1.2)
 Reference Methods. The acceptable reference methods for the RATA of a sorbent trap monitoring system are the same as those listed in paragraph <IP_ADDRESS> of this section. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 4"The special considerations specified in paragraph <IP_ADDRESS>.1 of this section apply to the RATA of a sorbent trap monitoring system. During the RATA, the monitoring system must be operated and quality-assured in accordance with Performance Specification (PS) 12B in Appendix B to part 60 of this chapter with the following exceptions for sorbent trap section 2 breakthrough: (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 For stack Hg concentrations >1 ug/dscm, <=10% of section 1 Hg mass;
 For stack Hg concentrations <=1 ug/dscm and >0.5 ug/dscm, <= 20% of section 1 Hg mass;
 For stack Hg concentrations <=0.5 ug/dscm and >0.1 ug/dscm, <= 50% of section 1 Hg mass; and
  For stack Hg concentrations <=0.1ug/dscm, no breakthrough criterion assuming all other QA/QC specifications are met.
 The type of sorbent material used by the traps during the RATA must be the same as for daily operation of the monitoring system; however, the size of the traps used for the RATA may be smaller than the traps used for daily operation of the system. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Calculation of RATA Results. Calculate the relative accuracy (RA) of the sorbent trap monitoring system, on a ug/scm basis, as described in section 12 of Performance Specification (PS) 2 in appendix B to part 60 of this chapter (see Equations 2 - 3 through 2 - 6 of PS2). For purposes of calculating the relative accuracy, ensure that the reference method and monitoring system data are on a consistent moisture basis, either wet or dry.The main and alternative RATA performance specifications in Table A - 1 for Hg CEMS also apply to the sorbent trap monitoring system. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Bias Adjustment. Measurement or adjustment of sorbent trap monitoring system data for bias is not required. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Diluent Gas, Flow Rate, and/or Moisture Monitoring Systems . Monitoring systems that are used to measure stack gas volumetric flow rate, diluent gas concentration, or stack gas moisture content, either for routine operation of a sorbent trap monitoring system or to convert Hg concentration data to units of the applicable emission limit, must be certified in accordance with the applicable provisions of part 75 of this chapter. (40 CFR Part 63 Subpart UUUUU Appendix A 4.1.3)
 Recertification. Whenever the owner or operator makes a replacement, modification, or change to a certified CEMS or sorbent trap monitoring system that may significantly affect the ability of the system to accurately measure or record pollutant or diluent gas concentrations, stack gas flow rates, or stack gas moisture content, the owner or operator shall recertify the monitoring system. Furthermore, whenever the owner or operator makes a replacement, modification, or change to the flue gas handling system or the unit operation that may significantly change the concentration or flow profile, the owner or operator shall recertify the monitoring system. The same tests performed for the initial certification of the monitoring system shall be repeated for recertification, unless otherwise specified by the Administrator. Examples of changes that require recertification include: replacement of a gas analyzer; complete monitoring system replacement, and changing the location or orientation of the sampling probe. (40 CFR Part 63 Subpart UUUUU Appendix A 4.2)

5. Ongoing Quality Assurance (QA) and Data Validation

 Hg CEMS.
 Required QA Tests. Periodic QA testing of each Hg CEMS is required following initial certification. The required QA tests, the test frequencies, and the performance specifications that must be met are summarized in Table A - 2, below. All tests must be performed with the affected unit(s) operating ( i.e., combusting fuel). Except for the RATA, which must be performed at normal load, no particular load level is required for the tests. For each test, follow the same basic procedures in section 4.1.1 of this appendix that were used for initial certification. (40 CFR Part 63 Subpart UUUUU Appendix A 5.1.1)
 Test Frequency. The frequency for the required QA tests of the Hg CEMS shall be as follows: (40 CFR Part 63 Subpart UUUUU Appendix A 5.1.2)
 Calibration error tests of the Hg CEMS are required daily, except during unit outages. Use either NIST-traceable elemental Hg standards or NIST-traceable oxidized Hg standards for these calibrations. Both a zero-level gas and either a mid-level or high-level gas are required for these calibrations. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Perform a linearity check of the Hg CEMS in each QA operating quarter, using low-level, mid-level, and high-level NIST-traceable elemental Hg standards. For units that operate infrequently, limited exemptions from this test are allowed for "non-QA operating quarters". A maximum of three consecutive exemptions for this reason are permitted, following the quarter of the last test. After the third consecutive exemption, a linearity check must be performed in the next calendar quarter or within a grace period of 168 unit or stack operating hours after the end of that quarter. The test frequency for 3-level system integrity checks (if performed in lieu of linearity checks) is the same as for the linearity checks. Use low-level, mid-level, and high-level NIST-traceable oxidized Hg standards for the system integrity checks. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 If required, perform a single-level system integrity check weekly, i.e., once every 7 operating days (see the third column in Table A - 2). (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 The test frequency for the RATAs of the Hg CEMS shall be annual, i.e., once every four QA operating quarters. For units that operate infrequently, extensions of RATA deadlines are allowed for non-QA operating quarters. Following a RATA, if there is a subsequent non-QA quarter, it extends the deadline for the next test by one calendar quarter. However, there is a limit to these extensions; the deadline may not be extended beyond the end of the eighth calendar quarter after the quarter of the last test. At that point, a RATA must either be performed within the eighth calendar quarter or in a 720 hour unit or stack operating hour grace period following that quarter. When a required annual RATA is done within a grace period, the deadline for the next RATA is three QA operating quarters after the quarter in which the grace period test is performed. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Grace Periods.
 A 168 unit or stack operating hour grace period is available for quarterly linearity checks and 3-level system integrity checks of the Hg CEMS. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 A 720 unit or stack operating hour grace period is available for RATAs of the Hg CEMS. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 There is no grace period for weekly system integrity checks. The test must be completed once every 7 operating days. (40 CFR Part 63 Subpart UUUUU Appendix A <IP_ADDRESS>)
 Data Validation. The Hg CEMS is considered to be out-of-control, and data from the CEMS may not be reported as quality-assured, when any one of the acceptance criteria for the required QA tests in Table A - 2 is not met. The CEMS is also considered to be out-of-control when a required QA test is not performed on schedule or within an allotted grace period. To end an out-of-control period, the QA test that was either failed or not done on time must be performed and passed. Out-of-control periods are counted as hours of monitoring system downtime. (40 CFR Part 63 Subpart UUUUU Appendix A 5.1.4)
 Conditional Data Validation. For certification, recertification, and diagnostic testing of Hg monitoring systems, and for the required QA tests when non-redundant backup Hg monitoring systems or temporary like-kind Hg analyzers are brought into service, the conditional data validation provisions in §§75.20(b)(3)(ii) through (b)(3)(ix) of this chapter may be used to avoid or minimize data loss. The allotted window of time to complete 7-day calibration error tests, linearity checks, cycle time tests, and RATAs shall be as specified in §75.20(b)(3)(iv) of this chapter. Required system integrity checks must be completed within 168 unit or stack operating hours after the probationary calibration error test. (40 CFR Part 63 Subpart UUUUU Appendix A 5.1.5)
      Table A - 2 -- On-Going QA Test Requirements for Hg CEMS
                      Perform this type of QA test . . .
                            At this frequency . . .
                With these qualifications and exceptions . . .
                           Acceptance criteria . . .
Calibration error test
Daily
:: Use either a mid- or high-level gas
R−A <= 5.0% of span value.
or
R−A <= 1.0 ug/scm.

:: Use either elemental or oxidized Hg

:: Calibrations are not required when the unit is not in operation

Single-level system integrity check
Weekly[1]
:: Required only for systems with converters
R−Aavg <= 10.0% of the reference gas value.
or
R−Aavg <= 0.8 ug/scm.

:: Use oxidized Hg -- either mid- or high-level

:: Not required if daily calibrations are done with a NIST-traceable source of oxidized Hg

Linearity check
or
3-level system integrity check
Quarterly[3]
:: Required in each "QA operating quarter"[2] -- and no less than once every 4 calendar quarters
R−Aavg <= 10.0% of the reference gas value, at each calibration gas level.
or
R−Aavg <= 0.8 ug/scm.

:: 168 operating hour grace period available

:: Use elemental Hg for linearity check

:: Use oxidized Hg for system integrity check

:: For system integrity check, CEMS must have a converter

RATA
Annual[4]
:: Test deadline may be extended for "non-QA operating quarters", up to a maximum of 8 quarters from the quarter of the previous test
20.0% RA.
or
RMavg−Cavg <= 1.0 ug/scm,
if
RMavg< 5.0 ug/scm.

:: 720 operating hour grace period available

      [1]"Weekly" means once every 7 operating days.
      [2]A "QA operating quarter" is a calendar quarter with at least 168 unit or stack operating hours.
      [3]"Quarterly" means once every QA operating quarter.
      [4]"Annual" means once every four QA operating quarters.