| (a) Totalizing fuel flow meters. The owner or operator
of units listed in this subsection shall install, calibrate, maintain,
and operate a totalizing fuel flow meter, with an accuracy of ±
5%, 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. The owner
or operator of units with totalizing fuel flow meters installed prior
to March 31, 2005, that do not meet the accuracy requirements of this
subsection shall either recertify or replace existing meters to meet
the ± 5% accuracy required as soon as practicable but no later
than March 31, 2007. For the purpose of compliance with this subsection
for units having pilot fuel supplied by a separate fuel system or
from an unmonitored portion of the same fuel system, the fuel flow
to pilots may be calculated using the manufacturer's design flow rates
rather than measured with a fuel flow meter. The calculated pilot
fuel flow rate must be added to the monitored fuel flow when fuel
flow is totaled.
(1) The units are the following:
(A) for units that are subject to §117.305 of
this title (relating to Emission Specifications for Reasonably Available
Control Technology (RACT)), for stationary gas turbines that are exempt
under §117.303(b)(7) of this title (relating to Exemptions):
(i) if individually rated more than 40 million British
thermal units per hour (MMBtu/hr):
(I) boilers;
(II) process heaters;
(III) boilers and industrial furnaces that were regulated
as existing facilities by 40 Code of Federal Regulations (CFR) Part
266, Subpart H, as was in effect on June 9, 1993; and
(IV) gas turbine supplemental-fired waste heat recovery
units;
(ii) stationary reciprocating internal combustion engines
not exempt by §117.303(a)(6), (a)(8), (b)(9), or (b)(10) of this
title;
(iii) stationary gas turbines with a megawatt (MW)
rating greater than or equal to 1.0 MW operated more than 850 hours
per year; and
(iv) fluid catalytic cracking unit boilers using supplemental
fuel; and
(B) for units subject to §117.310 of this title
(relating to Emission Specifications for Attainment Demonstration):
(i) boilers (excluding wood-fired boilers that must
comply by maintaining records of fuel usage as required in §117.345(f)
of this title (relating to Notification, Recordkeeping, and Reporting
Requirements) or monitoring in accordance with paragraph (2)(A) of
this subsection);
(ii) process heaters;
(iii) boilers and industrial furnaces that were regulated
as existing facilities by 40 CFR Part 266, Subpart H, as was in effect
on June 9, 1993;
(iv) duct burners used in turbine exhaust ducts;
(v) stationary, reciprocating internal combustion engines;
(vi) stationary gas turbines;
(vii) fluid catalytic cracking unit boilers and furnaces
using supplemental fuel;
(viii) lime kilns;
(ix) lightweight aggregate kilns;
(x) heat treating furnaces;
(xi) reheat furnaces;
(xii) magnesium chloride fluidized bed dryers; and
(xiii) incinerators (excluding vapor streams resulting
from vessel cleaning routed to an incinerator, provided that fuel
usage is quantified using good engineering practices, including calculation
methods in general use and accepted in new source review permitting
in Texas. All other fuel and vapor streams must be monitored in accordance
with this subsection.)
(2) The following are alternatives to the fuel flow
monitoring requirements of paragraph (1) of this subsection.
(A) Units operating with a nitrogen oxides (NOX ) and diluent continuous emissions monitoring
system (CEMS) under subsection (f) of this section may monitor stack
exhaust flow using the flow monitoring specifications of 40 CFR Part
60, Appendix B, Performance Specification 6 or 40 CFR Part 75, Appendix
A.
(B) Units that vent to a common stack with a NOX and diluent CEMS under subsection (f) of
this section may use a single totalizing fuel flow meter.
(C) Diesel engines operating with run time meters may
meet the fuel flow monitoring requirements of this subsection through
monthly fuel use records maintained for each engine.
(D) Stationary reciprocating internal combustion engines
and stationary gas turbines equipped with a continuous monitoring
system that continuously monitors horsepower and hours of operation
are not required to install totalizing fuel flow meters. The continuous
monitoring system must be installed, calibrated, maintained, and operated
according to manufacturers' recommended procedures.
(b) Oxygen (O2 ) monitors.
(1) The owner or operator shall install, calibrate,
maintain, and operate an O2 monitor to
measure exhaust O2 concentration on the
following units operated with an annual heat input greater than 2.2(1011 ) British thermal units per year (Btu/yr):
(A) boilers with a rated heat input greater than or
equal to 100 MMBtu/hr; and
(B) process heaters with a rated heat input greater
than or equal to 100 MMBtu/hr, except as provided in subsection (g)
of this section.
(2) The following are not subject to this subsection:
(A) units listed in §117.303(b)(3) - (5) and (8)
- (10) of this title;
(B) process heaters operating with a carbon dioxide
CEMS for diluent monitoring under subsection (g) of this section;
and
(C) wood-fired boilers.
(3) The O2 monitors required
by this subsection are for process monitoring (predictive monitoring
inputs, boiler trim, or process control) and are only required to
meet the location specifications and quality assurance procedures
referenced in subsection (f) of this section if O2 is
the monitored diluent under that subsection. However, if new O2 monitors are required as a result of this
subsection, the criteria in subsection (f) of this section should
be considered the appropriate guidance for the location and calibration
of the monitors.
(c) NOX monitors.
(1) The owner or operator of units listed in this paragraph
shall install, calibrate, maintain, and operate a CEMS or predictive
emissions monitoring system (PEMS) to monitor exhaust NOX . The units are:
(A) boilers with a rated heat input greater than or
equal to 250 MMBtu/hr and an annual heat input greater than 2.2(1011 ) Btu/yr;
(B) process heaters with a rated heat input greater
than or equal to 200 MMBtu/hr and an annual heat input greater than
2.2(1011 ) Btu/yr;
(C) stationary gas turbines with an MW rating greater
than or equal to 30 MW operated more than 850 hours per year;
(D) units that use a chemical reagent for reduction
of NOX ;
(E) units that the owner or operator elects to comply
with the NOX emission specifications
of §117.305 of this title using a pound per MMBtu (lb/MMBtu)
limit on a 30-day rolling average;
(F) lime kilns and lightweight aggregate kilns;
(G) units with a rated heat input greater than or equal
to 100 MMBtu/hr that are subject to §117.310(a) of this title;
and
(H) fluid catalytic cracking units (including carbon
monoxide (CO) boilers, CO furnaces, and catalyst regenerator vents).
In addition, the owner or operator shall monitor the stack exhaust
flow rate with a flow meter using the flow monitoring specifications
of 40 CFR Part 60, Appendix B, Performance Specification 6 or 40 CFR
Part 75, Appendix A.
(2) The following are not required to install CEMS
or PEMS under this subsection:
(A) for purposes of §117.305 of this title, units
listed §117.303(b)(3) - (5) and (8) - (10) of this title;
(B) units subject to the NOX CEMS
requirements of 40 CFR Part 75; and
(C) stationary diesel engines equipped with selective
catalytic reduction (SCR) systems that meet the following criteria.
(i) The SCR system must use a reductant other than
the engine's fuel.
(ii) The SCR system must operate with a diagnostic
system that monitors reductant quality and tank levels.
(iii) The diagnostic system must alert owners or operators
to the need to refill the reductant tank before it is empty or to
replace the reductant if the reductant does not meet applicable concentration
specifications.
Cont'd... |
