Sec. 4.
(a) The owner
or operator of an affected source shall limit nitrogen oxide
(NOx) emissions from affected facilities by complying
with any of the NOx limits specified as follows:
(1) Subsection (b).
(2) Subsection (c).
(3) A combination of limits in subsections
(b) and (c).
(b)
NOx emissions limits applicable to affected facilities
are as follows:
(1) For portland cement kilns,
the following:
(A) NOx
emissions from each portland cement long dry kiln with a clinker production
capacity greater than or equal to twenty (20) tons per hour shall not exceed
ten and eight-tenths (10.8) pounds per ton of clinker produced on an operating
day basis and six (6.0) pounds per ton of clinker produced on a thirty (30) day
rolling average basis.
(B)
NOx emissions from each portland cement dry preheater
process kiln with a clinker production capacity greater than or equal to twenty
(20) tons per hour shall not exceed five and nine-tenths pounds per ton (5.9
lbs/ton) of clinker produced on an operating day basis and four and four-tenths
pounds per ton (4.4 lbs/ton) clinker produced on a thirty (30) day rolling
average basis.
(2) For
electric utility steam generating boilers, NOx emissions
from each electric utility steam generating unit that has heat input capacity
greater than or equal to two hundred fifty (250) million Btu per hour, and that
combusts only coal, oil, or gas shall not exceed the following limits on a
thirty (30) day rolling average basis:
| Boiler Type |
Fuel Type |
Emissions Limit (lb/million Btu input) |
| Wall-fired dry bottom |
Pulverized coal |
0.5 |
|
|
Distillate oil |
0.2 |
|
|
Residual oil |
0.3 |
|
|
Gas |
0.2 |
(3)
For industrial, commercial, institutional boilers, NOx
emissions from each industrial, commercial, or institutional steam generating
unit that has heat input capacity greater than or equal to one hundred (100)
million Btu per hour, and that combusts only coal, oil, or gas shall not exceed
the following limits:
| Boiler Type |
Fuel Type |
Emissions Limit (lb/million Btu input) |
| Wall-fired dry bottom |
Pulverized coal |
0.5 |
| Tangentially fired |
Pulverized coal |
0.4 |
| Spreader stoker |
Pulverized coal |
0.5 |
| Overfeed stoker |
Pulverized coal |
0.4 |
| Oil fired |
Distillate oil |
0.2 |
|
|
Residual oil |
0.3 |
| Gas fired |
Gas |
0.2 |
Limits shall be complied with on a three (3) hour basis in
accordance with section 5 of this rule; however, if a continuous emissions
monitor (CEM) is installed then limits shall be complied with on a thirty (30)
day rolling average basis.
(4) Each facility listed in subdivision (2)
or (3) that simultaneously combusts a mixture of coal, oil, or gas shall comply
with emissions limits determined by the following equation: Equation 1
E = (A × E1 + B × E2 + C × E3)/(A + B +
C)
Where: E = the NOx limit expressed as
pounds per million Btu.
A = heat input in million Btu from combustion of coal.
B = heat input in million Btu from combustion of oil.
C = heat input in million Btu from combustion of gas.
E1 = applicable emissions limit in subdivision (2) or (3) in
pounds per million Btu for coal.
E2 = applicable emissions limit in subdivision (2) or (3) in
pounds per million Btu for oil.
E3 = applicable emission limit in subdivision (2) or (3) in
pounds per million Btu for gas.
(5) NOx emissions from
any facility other than those listed in subdivision (1), (2), or (3) that emits
or that has potential to emit NOx equal to or greater
than forty (40) tons per year shall comply with an emissions limit that shall
be achieved by controlling actual NOx emissions by at
least forty percent (40%). This requirement does not apply to facilities of the
type listed in subdivision (1), (2), or (3), including those that are smaller
than the applicable size cutoff. Limits shall be complied with on a three (3)
hour basis in accordance with section 5 of this rule; however, if a CEM is
installed then limits shall be complied with on a thirty (30) day rolling
average basis.
(c)
Instead of complying with the emissions limits in subsection (b), the owner or
operator of an affected facility may elect to comply with the following
alternative emissions limits:
(1) Where an
owner or operator of a source existing on the effective date of this rule
claims that an emissions limit in subsection (b) is technically or economically
infeasible, the owner or operator may petition for an alternative emissions
limit according to the procedures in section 3(3)(A) of this rule and 326 IAC
8-1-5. An alternative RACT petition approved by the department shall be
submitted to the U.S. EPA for approval.
(2) Instead of complying with the emissions
limits for steam generating units in subsection (b)(2) or (b)(3), the owner or
operator may comply with an emissions limit based on a fuel switching program.
Provisions applicable to fuel switching are as follows:
(A) Fuel may be switched as follows:
(i) A coal fired unit may combust oil, gas,
or a combination of oil and gas during the period from May 1 through and
including September 30. The unit shall comply with the applicable limit for
coal combustion in subsection (b)(2) or (b)(3) on an annual basis and the
applicable limit for coal combustion during the period May 1 through and
including September 30.
(ii) An oil
fired unit may combust oil with a lower NOx emitting
potential, gas, or a combination of oil and gas during the period from May 1
through and including September 30. The unit shall comply with the applicable
limit for oil combustion in subsection (b)(2) or (b)(3) on an annual basis and
the applicable limit for oil during the period May 1 through and including
September 30.
(B) The
owner or operator shall submit to the department a fuel switching plan
addressing the following information:
(i) Date
the plan will be implemented.
(ii)
Identification of each facility to be included in the fuel switching
program.
(iii) For each facility in
the fuel switching program the following information:
(AA) Type of steam generating unit based on
fuels used in the baseline year and the applicable emissions limit in
subsection (b)(2) or (b)(3).
(BB)
Fuels that will be combusted.
(CC)
Emission rate for each fuel, including basis, expressed as pounds per million
Btu, and the amount of heat that will be derived from each fuel, expressed as
million Btu.
(DD) Period of time
during the year in which each fuel shall be used.
(EE) A demonstration that the actual annual
fuel Btu weighted average emissions rate shall not exceed the applicable annual
emissions limit using the following equation:
Equation 2
EL = (E1 × H1 + E2 × H2 +...)/(H1 + H2
+...)
Where: EL = applicable emissions limit, expressed in pounds
per million Btu.
E1, E2,... = emission rate of alternative fuels 1, 2, etc.,
expressed in pounds per million Btu.
H1, H2,... = amount of heat derived from alternative fuels 1,
2, etc., expressed in million Btu per year.
(FF) Monitoring and record keeping
procedures.
(GG) Procedures that
shall be used to demonstrate compliance with the emissions limits as follows:
(aa) Annually.
(bb) During the fuel switching
period.
(3) Instead of complying with the emissions
limits in subsection (b), the owner or operator of an affected source may
comply with an emission limit based on an approved emissions averaging plan.
Provisions applicable to emissions averaging are as follows:
(A) Emissions may be averaged between
facilities located at sources in Indiana provided the following:
(i) The sources are under the control of the
same owner and have the same designated representative.
(ii) The facilities in Clark or Floyd County
engaging in the averaging plan achieve at least the equivalent
NOx reductions that would be achieved if each facility
complied with the emissions limit in subsection (b).
(B) Emissions may be averaged only between
the facilities in any category in subsection (b)(1), (b)(2), (b)(3), or
(b)(5).
(C) The owner or operator
of an affected source electing to comply with emissions averaging shall submit
to the department an emissions averaging plan that uses 40 CFR 76.11 * as a
guideline, except that the compliance averaging time shall be as specified in
this section.
(d) The commissioner may require verification
of the emissions rates used by the owner or operator in subsection (c)(2) and
(c)(3) using procedures and test methods in section 5 of this rule.
*This document is incorporated by reference. Copies may be
obtained from the Government Printing Office, 732 North Capitol Street NW,
Washington, D.C. 20401 or are available for review and copying at the Indiana
Department of Environmental Management, Office of Air Quality, Indiana
Government Center-North, Tenth Floor, 100 North Senate Avenue, Indianapolis,
Indiana 46204.
