| (a) Nitrogen oxides (NOX )
monitoring. The owner or operator of each unit subject to the emission
specifications in §117.1105 of this title (relating to Emission
Specifications for Reasonably Available Control Technology (RACT)),
shall install, calibrate, maintain, and operate a continuous emissions
monitoring system (CEMS) or predictive emissions monitoring system
(PEMS) to measure NOX on an individual
basis.
(1) Each CEMS or PEMS is subject to the relative accuracy
test audit relative accuracy requirements of 40 Code of Federal Regulations
(CFR) Part 75, Appendix B, Figure 2, except the concentration options
(parts per million by volume (ppmv) and pound per million British
thermal units (lb/MMBtu)) do not apply. Each CEMS or PEMS must meet
either the relative accuracy percent requirement of 40 CFR Part 75,
Appendix B, Figure 2, or an alternative relative accuracy requirement
of ± 2.0 ppmv from the reference method mean value.
(2) Each CEMS or PEMS is subject to the requirements
of §117.8110 of this title (relating to Emission Monitoring System
Requirements for Utility Electric Generation Sources).
(3) Each PEMS must predict NOX emissions
in the units of the applicable emission limitations of this division
and PEMS and fuel flow meters must be used to demonstrate continuous
compliance with the emission specifications of this division.
(b) Acid rain peaking units. In lieu of the NOX monitoring requirements in subsection (a)
of this section, the owner or operator of each peaking unit as defined
in 40 CFR §72.2, may monitor operating parameters for each unit
in accordance with 40 CFR Part 75, Appendix E, and calculate NOX emission rates based on those procedures.
(c) Totalizing fuel flow meters. The owner or operator
of each unit subject to the emission specifications in §117.1105
of this title and each unit using the exemption in §117.1103(1)
of this title (relating to Exemptions) shall install, calibrate, maintain,
and operate totalizing fuel flow meters to individually and continuously
measure the gas and liquid fuel usage. A computer that collects, sums,
and stores electronic data from continuous fuel flow meters is an
acceptable totalizer. In lieu of installing a totalizing fuel flow
meter on a unit, an owner or operator may opt to assume fuel consumption
at maximum design fuel flow rates during hours of the unit's operation.
(d) Run time meters. The owner or operator of a unit
using the exemption of §117.1103(2) of this title shall record
the operating time hours with an elapsed run time meter.
(e) Loss of exemption. The owner or operator of any
unit claimed exempt from the emission specifications of this division
using the exemptions in §117.1103(1) or (2) of this title, shall
notify the executive director within seven days if the applicable
limit is exceeded.
(1) If the limit is exceeded, the exemption from the
emission specifications of this division is permanently withdrawn.
(2) Within 90 days after loss of the exemption, the
owner or operator shall submit a compliance plan detailing a plan
to meet the applicable compliance limit as soon as possible, but no
later than 24 months after exceeding the limit. The plan must include
a schedule of increments of progress for the installation of the required
control equipment.
(3) The schedule is subject to the review and approval
of the executive director.
(f) Data used for compliance. The methods required
in this section must be used to demonstrate compliance with the emission
specifications of §117.1105 of this title and the system cap
in §117.1120 of this title (relating to System Cap). For enforcement
purposes, the executive director may also use other commission compliance
methods to determine whether the unit is in compliance with applicable
emission specifications.
(1) For units complying with the NOX
emission specifications of §117.1105 of this title in
pounds per million British thermal units (lb/MMBtu) on a rolling 30-day
average basis, the rolling 30-day average is calculated for each day
that fuel was combusted in the unit, and is the total NOX emissions (in pounds) from the unit for the
preceding 30 days that fuel was combusted in the unit, divided by
the total heat input (in MMBtu) for the unit during the same 30-day
period.
(2) For any electric generating facility (EGF) complying
with the system cap in §117.1120 of this title (relating to System
Cap) in pounds per day on a rolling 30-day average basis, the rolling
30-day average is calculated for each day and is the average of the
total pounds of NOX emissions per day
from all EGFs included in the system cap for the preceding 30 days.
(g) Data Substitution. The missing data procedures
specified in 40 CFR Part 75, Subpart D (Missing Data Substitution
Procedures) must be used to provide substitute emissions compliance
data during periods when the NOX monitor
is off-line except as follows.
(1) A peaking unit, as defined in 40 CFR §72.2,
subject to 40 CFR Part 75, Appendix E, may use the missing data procedures
specified in 40 CFR Part 75, Appendix E, §2.5 (Missing Data Procedures).
(2) A PEMS for units not subject to the requirements
of 40 CFR Part 75 may use calculations in accordance with §117.8110(b)
of this title (relating to Emission Monitoring System Requirements
for Utility Electric Generation Sources).
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