(a) Nitrogen oxides (NOX )
monitoring. The owner or operator of each unit subject to the emission
specifications of this division, shall install, calibrate, maintain,
and operate a continuous emissions monitoring system (CEMS), predictive
emissions monitoring system (PEMS), or other system specified in this
section to measure NOX on an individual
basis. Each NOX monitor (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 NOX monitor 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.
(b) Carbon monoxide (CO) monitoring. The owner or operator
shall monitor CO exhaust emissions from each unit subject to the emission
specifications of this division using one or more of the methods specified
in §117.8120 of this title (relating to Carbon Monoxide (CO)
Monitoring).
(c) Ammonia monitoring requirements. The owner or operator
of units that are subject to the ammonia emission specification of §117.1310(b)(3)
of this title (relating to Emission Specifications for Eight-Hour
Attainment Demonstration) shall comply with the ammonia monitoring
requirements of §117.8130 of this title (relating to Ammonia
Monitoring).
(d) CEMS requirements. The owner or operator of any
CEMS used to meet a pollutant monitoring requirement of this section
shall comply with the requirements of §117.8110(a) of this title
(relating to Emission Monitoring System Requirements for Utility Electric
Generation Sources).
(e) Acid rain peaking units. The owner or operator
of each peaking unit as defined in 40 CFR §72.2, may:
(1) monitor operating parameters for each unit in accordance
with 40 CFR Part 75, Appendix E, §1.1 or §1.2 and calculate
NOX emission rates based on those procedures;
or
(2) use CEMS or PEMS in accordance with this section
to monitor NOX emission rates.
(f) Auxiliary steam boilers. The owner or operator
of each auxiliary steam boiler shall comply with the following to
monitor NOX emission rates:
(1) install, calibrate, maintain, and operate a CEMS
in accordance with this section; or
(2) comply with the appropriate (considering boiler
maximum rated capacity and annual heat input) industrial boiler monitoring
requirements of §117.440 of this title (relating to Continuous
Demonstration of Compliance).
(g) PEMS requirements. The owner or operator of any
PEMS used to meet a pollutant monitoring requirement of this section
shall comply with the following. The required PEMS and fuel flow meters
must be used to demonstrate continuous compliance with the emission
specifications of this division.
(1) The PEMS must predict the pollutant emissions in
the units of the applicable emission limitations of this division.
(2) The PEMS must meet the requirements of §117.8110(b)
of this title.
(h) Stationary gas turbine monitoring. The owner or
operator of each stationary gas turbine subject to the emission specifications
of §117.1310 of this title, instead of monitoring emissions in
accordance with the monitoring requirements of 40 CFR Part 75, may
comply with the following monitoring requirements:
(1) for stationary gas turbines rated less than 30
megawatts (MW) or peaking gas turbines (as defined in §117.10
of this title (relating to Definitions)) that use steam or water injection
to comply with the emission specifications of §117.1310(a)(3)
of this title:
(A) install, calibrate, maintain and operate a CEMS
or PEMS in compliance with this section; or
(B) install, calibrate, maintain, and operate a continuous
monitoring system to monitor and record the average hourly fuel and
steam or water consumption. The system must be accurate to within ±
5.0%. The steam-to-fuel or water-to-fuel ratio monitoring data must
be used for demonstrating continuous compliance with the applicable
emission specification of §117.1310 of this title; and
(2) for all other stationary gas turbines subject to
the emission specifications of §117.1310 of this title, install,
calibrate, maintain, and operate a CEMS or PEMS in compliance with
this section.
(i) Totalizing fuel flow meters. The owner or operator
of units listed in this subsection 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.
The units are:
(1) any unit subject to the emission specifications
of §117.1310 of this title;
(2) any stationary gas turbine with an MW rating greater
than or equal to 1.0 MW operated more than 850 hours per year; and
(3) any unit claimed exempt from the emission specifications
of this division using the low annual capacity factor exemption of §117.1303(a)(2)
of this title (relating to Exemptions).
(j) Run time meters. The owner or operator of any stationary
gas turbine using the exemption of §117.1303(a)(3) of this title
shall record the operating time with an elapsed run time meter.
(k) Monitoring for output-based NOX emission
specification. The owner or operator of any unit that complies with
the optional output-based NOX emission
specification in §117.1310(a)(1)(C) of this title, shall comply
with the following:
(1) install, calibrate, maintain, and operate a system
to continuously monitor, at least once every 15 minutes, and record
the gross energy production of the unit in megawatt-hours;
(2) for each hour of operation, determine the total
mass emission of NOX , in pounds, from
the unit using the NOX monitoring requirements
of subsection (a) of this section and the fuel monitoring requirements
of subsection (i) of this section; and
(3) for each hour of operation, calculate and record
the NOX emissions in pounds per megawatt-hour
using the monitoring specified in paragraphs (1) and (2) of this subsection.
(l) Loss of exemption. The owner or operator of any
unit claimed exempt from the emission specifications of this division
using the exemptions in §117.1303(a)(2) or (3) 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.
(m) Data used for compliance. After the initial demonstration
of compliance required by §117.1335 of this title (relating to
Initial Demonstration of Compliance), the methods required in this
section must be used to determine compliance with the emission specifications
of §117.1310 of this title. Compliance with the emission specifications
may also be determined at the discretion of the executive director
using any commission compliance method.
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