(iv) If the SCR system uses input from an exhaust NOX sensor (or other sensor) to alert owners
or operators when the reductant quality is inadequate, the reductant
quality does not need to be monitored separately by the diagnostic
system.
(v) The reductant tank level must be monitored in accordance
with the manufacturer's design to demonstrate compliance with this
subparagraph.
(vi) The method of alerting an owner or operator must
be a visual or audible alarm.
(3) The owner or operator shall use one of the following
methods to provide substitute emissions compliance data during periods
when the NOX monitor is off-line:
(A) if the NOX monitor
is a CEMS:
(i) subject to 40 CFR Part 75, use the missing data
procedures specified in 40 CFR Part 75, Subpart D (Missing Data Substitution
Procedures); or
(ii) subject to 40 CFR Part 75, Appendix E, use the
missing data procedures specified in 40 CFR Part 75, Appendix E, §2.5
(Missing Data Procedures);
(B) use 40 CFR Part 75, Appendix E monitoring in accordance
with §117.1240(e) of this title (relating to Continuous Demonstration
of Compliance);
(C) if the NOX monitor
is a PEMS:
(i) use the methods specified in 40 CFR Part 75, Subpart
D; or
(ii) use calculations in accordance with §117.8110(b)
of this title (relating to Emission Monitoring System Requirements
for Utility Electric Generation Sources); or
(D) use the maximum block one-hour emission rate as
measured during the initial demonstration of compliance required in §117.335(f)
of this title (relating to Initial Demonstration of Compliance); or
(E) use the following procedures:
(i) for NOX monitor downtime
periods less than 24 consecutive hours, use the maximum block one-hour
NOX emission rate, in lb/MMBtu, from
the previous 24 operational hours of the unit;
(ii) for NOX monitor downtime
periods equal to or greater than 24 consecutive hours, use the maximum
block one-hour NOX emission rate, in
lb/MMBtu, from the previous 720 operational hours of the unit; and
(iii) if the fuel flow or stack exhaust flow monitor
required by subsection (a) of this section is off-line simultaneous
with the NOX monitor downtime, the owner
or operator shall use the maximum block one-hour NO
X pound per hour emission rate for the substitute data under
clause (i) or (ii) of this subparagraph in lieu of the lb/MMBtu emission
rate.
(d) Ammonia monitoring requirements. The owner or operator
of units that are subject to the ammonia emission specifications of §117.310(c)(2)
of this title shall comply with the ammonia monitoring requirements
of §117.8130 of this title (relating to Ammonia Monitoring).
Units identified in subsection (c)(2)(C) of this section are exempt
from the ammonia monitoring requirements of this subsection.
(e) CO monitoring. The owner or operator shall monitor
CO exhaust emissions from each unit listed in subsection (c)(1) of
this section using one or more of the methods specified in §117.8120
of this title (relating to Carbon Monoxide (CO) Monitoring).
(f) CEMS requirements. The owner or operator of any
CEMS used to meet a pollutant monitoring requirement of this section
shall comply with the following.
(1) The CEMS must meet the requirements of §117.8100(a)
of this title (relating to Emission Monitoring System Requirements
for Industrial, Commercial, and Institutional Sources).
(2) For units subject to §117.310 of this title:
(A) all bypass stacks must be monitored, in order to
quantify emissions directed through the bypass stack:
(i) if the CEMS is located upstream of the bypass stack,
then:
(I) no effluent streams from other potential sources
of NOX emissions may be introduced between
the CEMS and the bypass stack; and
(II) the owner or operator shall install, operate,
and maintain a continuous monitoring system to automatically record
the date, time, and duration of each event when the bypass stack is
open; and
(ii) process knowledge and engineering calculations
may be used to determine volumetric flow rate for purposes of calculating
mass emissions for each event when the bypass stack is open, provided
that:
(I) the maximum potential calculated flow rate is used
for emission calculations; and
(II) the owner or operator maintains, and makes available
upon request by the executive director, records of all process information
and calculations used for this determination; and
(B) exhaust streams of units that vent to a common
stack do not need to be analyzed separately.
(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.
(1) The PEMS must predict the pollutant emissions in
the units of the applicable emission specifications of this division
(relating to Houston-Galveston-Brazoria Ozone Nonattainment Area Major
Sources).
(2) The PEMS must meet the requirements of §117.8100(b)
of this title.
(h) Engine monitoring. The owner or operator of any
stationary gas engine subject to §117.305 of this title that
is not equipped with NOX CEMS or PEMS
shall stack test engine NOX and CO emissions
as specified in §117.8140(a) of this title (relating to Emission
Monitoring for Engines). The owner or operator of any stationary internal
combustion engine subject to §117.310 of this title that is not
equipped with NOX CEMS or PEMS shall
stack test engine NOX and CO emissions
as specified in §117.8140(a) and (b) of this title.
(i) Monitoring for stationary gas turbines less than
30 MW. The owner or operator of any stationary gas turbine rated less
than 30 MW using steam or water injection to comply with the emission
specifications of §117.305 or §117.315 of this title (relating
to Emission Specifications for Reasonably Available Control Technology
(RACT) and Alternative Plant-Wide Emission Specifications) shall either:
(1) install, calibrate, maintain, and operate a NOX CEMS or PEMS in compliance with this section
and monitor CO in compliance with subsection (e) of this section;
or
(2) install, calibrate, maintain, and operate a continuous
monitoring system to monitor and record the average hourly fuel and
steam or water consumption:
(A) the system must be accurate to within ±
5.0%;
(B) the steam-to-fuel or water-to-fuel ratio monitoring
data must constitute the method for demonstrating continuous compliance
with the applicable emission specification of §117.305 or §117.315
of this title; and
(C) steam or water injection control algorithms are
subject to executive director approval.
(j) Run time meters. The owner or operator of any stationary
gas turbine or stationary internal combustion engine claimed exempt
using the exemption of §117.303(a)(6)(D), (a)(10), (a)(11), (b)(2)
or (b)(9) of this title shall record the operating time with an elapsed
run time meter. Any run time meter installed on or after October 1,
2001, must be non-resettable.
(k) Hydrogen (H2 ) monitoring.
The owner or operator claiming the H2 multiplier
of §117.305(b)(6) or §117.315(g)(4) or (h) of this title
shall sample, analyze, and record every three hours the fuel gas composition
to determine the volume percent H2 .
(1) The total H2 volume
flow in all gaseous fuel streams to the unit must be divided by the
total gaseous volume flow to determine the volume percent of H2 in the fuel supply to the unit.
(2) Fuel gas analysis must be tested according to American
Society for Testing and Materials (ASTM) Method D1945-81 or ASTM Method
D2650-83, or other methods that are demonstrated to the satisfaction
of the executive director and the United States Environmental Protection
Agency to be equivalent.
(3) A gaseous fuel stream containing 99% H2 by volume or greater may use the following
procedure to be exempted from the sampling and analysis requirements
of this subsection.
(A) A fuel gas analysis must be performed initially
using one of the test methods in this subsection to demonstrate that
the gaseous fuel stream is 99% H2 by
volume or greater.
(B) The process flow diagram of the process unit that
is the source of the H2 must be supplied
to the executive director to illustrate the source and supply of the
hydrogen stream.
Cont'd... |