250-RICR-120-05-27
250-RICR-120-05-27. Air Pollution Control Regulation No. 27 - Control of Nitrogen Oxide Emissions (version Periodic Refile, 12/31/2001 to 07/19/2007)
Effective 1 February 1994
Amended 16 January 1996
AIR POLLUTION CONTROL REGULATION NO. 27
CONTROL OF NITROGEN OXIDES EMISSIONS
1
RHODE ISLAND DEPARTMENT OF ENVIRONMENTAL MANAGEMENT
DIVISION OF AIR RESOURCES
AIR POLLUTION CONTROL REGULATION NO. 27
CONTROL OF NITROGEN OXIDES EMISSIONS
27. Control of Nitrogen Oxides Emissions
27.1 Definitions
As used in these regulations, the following terms shall, where
the context permits, be construed as follows:
27.1.1
"Actual
emissions"
means
the
actual
rate
of
emissions of a pollutant from a piece of equipment
or a pollutant-emitting activity as determined in
accordance with Subsections (a) through (c) below:
(a)
In
general,
actual
emissions
as
of
a
particular date shall equal the average rate,
in tons per year, at which the unit actually
emitted the pollutant during a two year period
which precedes the particular date and which
is representative of normal stationary source
operation.
Actual
emissions
shall
be
calculated using the equipment's or activity's
actual operating hours, production rates and
types
of
materials
processed,
stored
or
combusted during the selected time period;
(b)
The Director may presume that stationary
source specific allowable emissions for the
equipment or activity are equivalent to the
actual emissions of the equipment or activity;
(c)
For any equipment or activity which has not
begun normal operations on the particular
date,
actual
emissions
shall
equal
the
potential to emit of the equipment or activity
on that date.
27.1.2
"Best Available Control Technology" or "BACT" means
an
emissions
limitation
(including
a
visible
emissions standard) based on the maximum degree of
reduction for each air pollutant which would be
emitted from any proposed stationary source or
modification which the Director, on a case-by-case
basis, taking into account energy, environmental
and economic impacts and other costs, determines is
achievable
for
such
stationary
source
or
modification
through
application
of
production
2
processes
or
available
methods,
systems
and
techniques, including fuel cleaning or treatment or
innovative fuel combustion techniques for control
of such pollutant. In no event shall application
of best available control technology result in
emissions of any pollutant which would exceed the
emissions allowed by an applicable standard under
40 CFR Parts 60 and 61. If the Director determines
that technological or economic limitations on the
application
of
measurement
methodology
to
a
particular emissions unit would make the imposition
of air emissions standards infeasible, a design,
equipment, work practice, operational standard or
combination thereof, may be prescribed instead to
satisfy the requirement of best available control
technology. Such standard shall to the degree
possible
set
forth
the
emission
reduction
achievable
by
implementation
of
such
design,
equipment, work practice or operation and shall
provide for compliance by means which achieve
equivalent results.
27.1.3
"CFR" means the Code of Federal Regulations
27.1.4
"Combined cycle gas turbine" means any stationary
gas turbine which recovers heat from the gas
turbine exhaust gases to heat water or generate
steam.
27.1.5
"Combustion turbine" means any simple cycle gas
turbine or any combined cycle gas turbine including
the duct burner portion thereof.
27.1.6
"Distillate Oil" means fuel oil that complies with
the specifications for fuel oil numbers 1 or 2, as
defined by the American Society for Testing and
Materials in ASTM D396-78, "Standard Specification
for Fuel Oils".
27.1.7
"EPA"
means
the
United
States
Environmental
Protection Agency.
27.1.8
"Emergency
standby
internal
combustion
engine"
means an internal combustion engine operated only
as a mechanical or electrical power source for a
stationary source when the primary power source has
been rendered inoperable. This does not include
power interruptions pursuant to an interruptable
power service agreement.
27.1.9
"Enforceable document" means a permit issued under
3
the
requirements
of
Air
Pollution
Control
Regulation No.9, an approval issued under this
regulation, or a consent agreement.
27.1.10
"Equivalent control" means a control system that
may
be
substituted
for
the
required
control
system(s). The stationary source applying to use
an equivalent control must demonstrate to the
satisfaction of the Division and EPA that the
emission reductions achieved are equal to or
greater than the emission reductions required by
the regulation. Appropriate test methods or other
replicable criteria in accordance with DEM and EPA
guidance must be used to demonstrate equivalence.
27.1.11
"Federally enforceable" means all limitations and
conditions
which
are
enforceable
by
the
Administrator of the USEPA.
27.1.12
"Industrial-Commercial-Institutional Boiler" means
a device that combusts any fuel and produces steam
or heats water or any other heat transfer medium.
This term does not include utility boilers used by
electric utilities to generate electricity.
27.1.13
"Internal combustion engine" means any engine in
which power, produced by heat and/or pressure
developed in the engine cylinder(s) by burning a
mixture of air and fuel, is subsequently converted
to mechanical work by means of 1 or more pistons.
27.1.14
"Lean-burn engine" means an internal combustion
engine where the amount of oxygen in the exhaust
gases is 1% or more, by weight.
27.1.15
"Liquified petroleum (LP) gas" means liquified
petroleum gas as defined by the American Society
for
Testing
and
Materials
in
ASTM
D1835-82,
"Standard Specification for Liquified Petroleum
Gases".
27.1.16
"Low NOx burner" means a commercially available
modified combustion burner designed to minimize NOx
formation through low excess air firing, controlled
mixing of primary combustion air and fuel (staged
air
or
staged
fuel),
reducing
peak
furnace
temperature or other burner designs judged to be
low NOx burners by the Division and EPA based on a
review
of
evidence
submitted
by
the
subject
stationary source.
4
27.1.17
"Lowest Achievable Emission Rate" or "LAER" means
for any stationary source, the more stringent rate
of emissions based on the following:
(a)
The most stringent emissions limitation which
is contained in the implementation plan of any
state for such class or category of stationary
source, unless the owner or operator of the
proposed stationary source demonstrates that
such limitations are not achievable; or
(b)
The most stringent emissions limitation which
is achieved in practice by such class or
category
of
stationary
source.
This
limitation, when applied to a modification,
means the lowest achievable emission rate for
the new or modified equipment within the
stationary source. In no event shall the
application of this term permit a proposed new
or modified stationary source to emit any
pollutant in excess of the amount allowable
under
applicable
new
source
performance
standards.
27.1.18
"Natural gas" means a naturally occurring mixture
of hydrocarbon and non hydrocarbon gases found in
geologic formations beneath the earth's surface, of
which the principal constituent is methane.
27.1.19
"Nitrogen oxides" means nitric oxide (NO) and
nitrogen dioxide (NO2), and any other species of
nitrogen oxides, expressed as molecular weight of
NO2.
27.1.20
"Potential to emit" means the maximum capacity of a
stationary source to emit a pollutant under its
physical or operational design. Any physical or
operational
limitation
on
the
capacity
of
a
stationary source to emit a pollutant, including
air pollution control equipment and restrictions on
hours of operation or on the type or amount of
material combusted, stored or processed, shall be
treated as part of its design only if the
limitation or the effect it would have on emissions
is federally enforceable.
27.1.21
"Reasonably Available Control Technology" or "RACT"
means
the
lowest
emission
limitation
that
a
particular piece of equipment or pollutant emitting
activity is capable of meeting by using measures
that
are
reasonably
available
in
terms
of
5
technological and economic feasibility.
27.1.22
"Residual oil" means crude oil, fuel oil that does
not comply with the specifications under the
definition of distillate oil, and all fuel oil
numbers 4, 5, and 6 as defined by the American
Society for Testing and Materials in ASTM D396-78,
"Standard Specification for Fuel Oils".
27.1.23
"Rich-burn engine" means an internal combustion
engine where the amount of oxygen in the engine
exhaust gases is less than 1% by weight.
27.1.24
"Simple cycle gas turbine" means any stationary gas
turbine which does not recover heat from the gas
turbine
exhaust
gases
to
preheat
the
inlet
combustion air to the gas turbine, or which does
not recover heat from the gas turbine exhaust gases
to heat water or generate steam.
27.1.25
"Stationary source" means all of the pollutant-
emitting activities which belong to the same
industrial grouping, are located on one or more
contiguous or adjacent properties, and are under
the control of the same person (or persons under
common control). Pollutant-emitting activities
shall be considered as part of the same industrial
grouping if they have the same two-digit code as
described in the Standard Industrial Classification
Manual, 1972, as amended by the 1977 Supplement
(U.S. Government Printing Office Stock Numbers
4101-0066 and 003-005-00176-0, respectively).
27.1.26
"Utility boiler" means a device, with a heat input
capacity of 250 million BTUs per hour or greater,
that combusts any fuel and produces steam for the
primary purpose of generating electricity. This
term does not include combustion turbines.
27.2
Applicability and Exemptions
27.2.1
This regulation applies to all stationary sources
which have or ever have had, since 1 January 1990,
the potential to emit 50 tons of nitrogen oxides
(NOx) per year from all pollutant-emitting equipment
or activities.
27.2.2
A stationary source with potential yearly emissions
of 50 tons or more of NOx, but with actual emissions
not exceeding 50 tons per year of NOx any time after
1 January 1990, may apply to the Director for an
6
exemption from Sections 27.4 and 27.5 of this
regulation. Application for an exemption must be
submitted to the Director by 1 July 1994, and must
include
documentation
of
previous
yearly
NOx
emissions, in tons per year, since 1 January 1990.
Exemption from Section 27.4 of this regulation
will be in the form of an enforceable document
issued
by
the
Director
which
limits
actual
emissions to less than 50 tons per year of NOx and
shall include, but not necessarily be limited, to
the following conditions:
(a)
Actual annual emissions shall not exceed 50
tons of NOx per year, and
(b)
The stationary source shall meet the emission
cap over every consecutive 12 month period.
Recordkeeping to demonstrate compliance shall
be conducted as provided in Section 27.6.9 and
shall be kept on a monthly basis. The cap
must be consistent with the anticipated level
of
emissions
in
the
approved
State
Implementation Plan (SIP).
Any stationary source that has been issued an
emissions cap and fails to meet the requirements of
the enforceable document must immediately be in
compliance with RACT.
27.2.3
Any emergency standby internal combustion engines
which is operated less than 500 hours during any
consecutive twelve (12) month period is exempt from
Section 27.4 of this regulation. Recordkeeping
shall be conducted as provided in Subsection
27.6.10.
Any emergency standby internal combustion engine
operated under the provisions of this subsection
must immediately be in compliance with RACT if the
hours of operation in any twelve (12) month period
exceeds 500.
27.3
Reasonably Available Control Technology (RACT) Plan
Requirements
27.3.1
Any stationary source subject to the provisions of
Section 27.4 of this regulation shall, by 3 October
1994 or six months after becoming a potential 50
tons per year NOx stationary source, whichever is
later, submit to the Director a RACT proposal for
approval which includes all information specified
7
in Subsections 27.3.2 or 27.3.3.
27.3.2
All
RACT
proposals
submitted
to
comply
with
Subsection 27.4.1, 27.4.2 or 27.4.3 shall include
the following information:
(a)
an inventory of all NOx - emitting equipment
with a heat input capacity greater than or
equal to one million BTUs per hour at the
stationary source
(b)
the maximum capacity, in millions of BTUs per
hour, of each piece of NOx - emitting equipment
(c)
the type of fuel or fuels combusted in each
piece of NOx - emitting equipment
(d)
the maximum NOx emission rate for each piece of
NOx - emitting equipment in lbs per million BTU
for each fuel burned
(e)
the actual amount of NOx emitted for each
calendar year since 1 January 1990, from each
piece of NOx - emitting equipment
(f)
a summary of the applicable emission limits
and requirements of this regulation and how
the stationary source will comply
(g)
a schedule for the implementation of RACT,
including dates for each of the following
where applicable: completion of engineering,
awarding
of
contracts,
initiation
of
construction, completion of construction and
final compliance with RACT
(h)
any additional information requested by the
Director
27.3.3
All
RACT
proposals
submitted
to
comply
with
Subsection 27.4.4 or 27.4.9 shall include the
following information:
(a)
an inventory of all NOx - emitting equipment
with a heat input capacity greater than or
equal to one million BTUs per hour at the
stationary source
(b)
the maximum capacity, in million of BTUs per
hour, of each piece of NOx - emitting equipment
8
(c)
the type of fuel or fuels combusted in each
piece of NOx - emitting equipment
(d)
the maximum NOx emission rate for each piece of
NOx - emitting equipment, in lbs per million
BTU, for each fuel burned
(e)
the actual amount of NOx emitted for each
calendar year since 1 January 1990, from each
piece of NOx - emitting equipment
(f)
an examination of the technical and economic
feasibility of available NOx control techniques
for each piece of NOx - emitting equipment with
the potential to emit 10 tons or more of NOx
per year.
(g)
the control option or combination of control
options selected as RACT, including emission
limits and the test methods to be used to
demonstrate compliance
(h)
the amount of reduction in NOx emissions that
will be associated with implementing the
selected control option(s)
(i)
a schedule for the implementation of RACT,
including dates for each of the following
where applicable: completion of engineering,
awarding
of
contracts,
initiation
of
construction, completion of construction and
final compliance with RACT
(j)
the testing, monitoring, record keeping and
reporting procedures to be used to demonstrate
continuous compliance
(k)
any additional information requested by the
Director that is deemed necessary to determine
RACT
27.3.4
After reviewing a RACT proposal submitted to comply
with Subsection 27.4.1, 27.4.2 or 27.4.3 the
Division will issue a final approval or disapproval
of the proposal.
27.3.5
After reviewing a RACT proposal submitted to comply
with
Subsection
27.4.4,
the
Division,
in
consultation with the EPA, shall prepare a proposed
enforceable
document
specifying
RACT
for
the
stationary source. The enforceable document shall
9
be subject to a thirty day public comment period.
A public hearing for interested persons to appear
and to submit written or oral comments on the
enforceable document shall be held upon request.
The Director may also hold a hearing at his or her
discretion, whenever he or she believes there is a
significant degree of public interest in the
proposed action. If held, a hearing shall take
place no earlier than thirty (30) days nor later
than sixty (60) days following initial public
notice. Comments from the stationary source and/or
any interested persons shall be recorded at the
public hearing. Written comments, to be considered
part of the record, must be submitted during the
public comment period. The public comment period
shall commence on the date of initial public
notice. The public comment period shall close
thirty (30) days later, if no public hearing is
held. If a public hearing is held, the public
comment period shall close at the close of the
public hearing or on a later date set by the
Division. The final enforceable document shall be
submitted to the EPA for approval as a source
specific revision to the State Implementation Plan.
27.4 Reasonably Available Control Technology (RACT) Requirements
27.4.1
Utility Boilers
On and after 31 May 1995, no person shall cause or
allow the emission of NOx from any utility boiler in
excess of the following emission limitations:
(a)
0.20 lbs per million BTU of heat input when
operated on natural gas or liquified petroleum
gas (LP)
(b)
0.25 lbs per million BTU of heat input when
operated on fuel oil
27.4.2
Industrial - Commercial - Institutional Boilers
(a)
On and after 31 May 1995, no person shall
cause or allow the emission of NOx from any
Industrial
-
Commercial
-
Institutional
boiler, fired with natural gas or distillate
oil, with a heat input capacity of 50 million
BTUs per hour or greater, in excess of the
following emission limitations:
1.
0.10 lbs per million BTU of heat input
10
when operated on natural gas
2.
0.12 lbs per million BTU of heat input
when
operated
on
distillate
oil
or
liquified petroleum gas (LP)
(b)
On and after 31 May 1995, no person shall
cause or allow the emission of NOx from any
Industrial
-
Commercial
-
Institutional
boiler, fired with residual oil, with a heat
input capacity of 50 million BTUs per hour or
greater, unless the boiler is equipped with
low - NOx burners and flue gas recirculation
(with a minimum of 10% flue gas recirculation)
or equivalent control.
(c)
On and after 31 May 1995, no person shall
cause or permit the emission of NOx from any
Industrial
-
Commercial
-
Institutional
boiler, with a heat input capacity of 1
million BTU per hour or greater, but less than
50 million BTUs per hour, unless the boiler is
tuned at least once per year in accordance
with the procedure described in Appendix A.
27.4.3
Internal Combustion Engines
On and after 31 May 1995, no person shall cause or
permit the emission of NOx from any internal
combustion
engine,
capable
of
producing
400
horsepower (HP) or more, in excess of the following
emission limitations:
(a)
Rich-burn Engines
1.
1.5 grams per brake horsepower-hour when
operated on natural gas
(b)
Lean-burn Engines
1.
2.5 grams per brake horsepower-hour when
operated on natural gas
2.
9.0 grams per brake horsepower-hour when
operated on fuel oil
27.4.4
Miscellaneous Stationary Sources
(a)
Any stationary source, equipment or pollutant
emitting activity, with the potential to emit
10 tons or more of NOx per year, that is not
11
covered by Subsection 27.4.1, 27.4.2 or 27.4.3
shall install and operate in compliance with
RACT, as specified in an enforceable document
issued by the Director, by 31 May 1995.
(b)
Any stationary source that becomes a potential
50 ton per year NOx stationary source after 30
November 1993 shall install and operate in
compliance with RACT, within 18 months of the
date that the stationary source first becomes
a potential 50 ton per year NOx stationary
source. RACT shall be specified in an
enforceable document issued by the Director.
27.4.5
The RACT requirements in Subsections 27.4.1 -
27.4.4 do not apply to equipment and pollutant -
emitting activities that have been determined to be
BACT or LAER in any permit issued by the Division
pursuant to Air Pollution Control Regulation No. 9
since 15 November 1992.
27.4.6
The RACT requirements in Subsection 27.4.3 or
27.4.4 do not apply to equipment and pollutant
emitting activities listed below, that have been
issued a permit for the construction/installation
of new equipment by the Division, pursuant to Air
Pollution
Control
Regulation
No.9,
since
the
indicated date.
(a)
Combustion turbine facilities - 6 January 1989
(b)
Internal combustion engines - 28 September
1989
(c)
Fluidized bed boilers - 11 March 1991
27.4.7
The RACT requirements in Subsection 27.4.1 do not
apply to any utility boiler that commits, by 3
October 1994, in an enforceable document, to either
permanently shut down and dismantle that existing
utility boiler by 31 May 1995 or replace that
existing utility boiler by 31 December 1996 as part
of a repowering project. The repowered emissions
unit(s) must meet a NOx emission limitation that has
been determined to be BACT or LAER in a permit
issued by the Division pursuant to Air Pollution
Control Regulation No. 9. In addition to the
commitment,
the
source
must
comply
with
the
alternative RACT requirements of 27.4.8. The final
enforceable document and the alternative RACT
determination shall be submitted to the EPA for
12
approval as a source specific revision to the State
Implementation Plan (SIP).
27.4.8
Alternative RACT
(a)
The RACT requirements in Subsection 27.4.1 -
27.4.3 may be relaxed on a case-by-case basis,
if by 3 October 1994 or six months after
becoming a potential 50 ton per year NOx
stationary source, the owner or operator makes
application to the Division for an alternative
RACT determination. An application for an
alternative RACT determination must include
the following:
1.
an inventory of all NOx - emitting
equipment with a heat input capacity
greater than or equal to one million BTUs
per hour at the stationary source
2.
the maximum capacity, in million of BTUs
per hour, of each piece of NOx - emitting
equipment
3.
the type of fuel or fuels combusted in
each piece of NOx - emitting equipment
4.
the maximum NOx emission rate for each
piece of NOx - emitting equipment, in lbs
per million BTU, for each fuel burned
5.
the actual amount of NOx emitted for each
calendar year since 1 January 1990, from
each piece of NOx - emitting equipment
6.
economic and/or technical documentation
that demonstrates to the satisfaction of
the Division and EPA that the applicable
emission limitations cannot feasibly be
met.
7.
an examination of the technical and
economic feasibility of alternative NOx
control techniques for each piece of NOx
emitting equipment
8.
The control option or combination of
control options proposed as alternative
RACT, including emission limits and test
methods to demonstrate compliance.
13
9.
The amount of reduction in NOx emissions
that will be associated with implementing
the selected control option(s).
10.
A schedule for the implementation of
alternative RACT, including dates for
each of the following where applicable:
completion of engineering, awarding of
contracts, initiation of construction,
completion of construction and final
compliance with alternative RACT by 31
May 1995.
11.
The testing, monitoring, recordkeeping
and reporting procedures to be used to
demonstrate continuous compliance.
12.
Any additional information requested by
the Director that is deemed necessary to
determine alternative RACT.
(b)
Any alternative RACT determination will not
become final until approved by EPA as a source
specific State Implementation Plan (SIP)
revision;
(c)
The stationary source shall conduct a RACT
review every three years after the final
compliance date until the RACT requirements in
Subsections 27.4.1, 27.4.2 or 27.4.3 are
achieved. This RACT review must include the
same information required in an application
for an alternative RACT determination. This
RACT review will not become final until
approved by EPA as a source specific State
Implementation Plan (SIP) revision.
27.4.9
Fuel Switching
Any facility subject to the RACT requirements in
Subsections 27.4.1 - 27.4.4 may propose to comply
with those requirements by fuel switching. Fuel
switching refers to instances where a piece of NOx
emitting equipment historically burned one primary
fuel, such as residual oil, and under a fuel
switching program, the equipment would burn a
cleaner fuel, such as natural gas, during the ozone
season (May 1 - September 30) and may switch back
to the historic fuel for some or all of the non-
ozone season.
14
(a)
The owner or operator of a stationary source
proposing a fuel switching program must file
an application with the Division for approval
of a fuel switching program no later than 3
October 1994 or six months after becoming a
potential 50 ton per year NOx facility,
whichever is later.
(b)
An
application
for
approval
of
a
fuel
switching program must demonstrate that the NOx
reductions achieved will be the equivalent of
that which would be achieved if the stationary
source were operating in compliance with its
applicable emission limitations throughout the
year.
(c)
An
application
for
approval
of
a
fuel
switching program must demonstrate that the
program uses a long term emissions averaging
approach consistent with the Environmental
Protection Agency's guidance. This guidance
is contained in a 30 July 1993 memo from
Michael Shapiro entitled "Fuel Switching to
Meet
the
Reasonably
Available
Control
Technology Requirements for Nitrogen Oxides.
(d)
Any fuel switching program will not become
final until approved by EPA as a source
specific
State
Implementation
Plan
(SIP)
revision.
27.5 Compliance Testing and Emission Monitoring Requirements
27.5.1
Compliance with Subsections 27.4.1 and 27.4.9 shall
be
demonstrated
by
installation
calibration,
maintenance and operation of a continuous emission
monitoring system for NOx and O2 or CO2.
27.5.2
Compliance with Subsections 27.4.2(a) - (b),
27.4.3, 27.4.4, and 27.4.8 shall be demonstrated
either by emission testing or by installation
calibration,
maintenance
and
operation
of
a
continuous emission monitoring system for NOx and O2
or CO2.
27.5.3
Compliance with Subsection 27.4.2 (c) shall be
demonstrated by record keeping as specified in
Subsection 27.6.8.
27.5.4
Compliance
with
the
emission
limitations
in
Subsections 27.4.1 shall be based on 24 hour
15
average concentrations.
27.5.5
Compliance
with
the
emission
limitations
in
Subsections 27.4.2 and 27.4.3 shall be based on one
hour average concentrations. Emission testing
shall consist of 3 - one hour test runs.
Compliance with the emission limitation must be
demonstrated for each test run.
27.5.6
Continuous emission monitoring systems shall comply
with the following requirements:
(a)
Performance specification, monitor location,
calibration and operating procedures, quality
assurance procedures for each monitor and a
sample
calculation
showing
how
the
concentrations from the NOx CEMs will be
converted in to the applicable units and
averaging time of the emission limit must be
submitted to the Division for review and
approval at least 180 days prior to expected
installation.
(b)
All
emission
data
shall
be
continuously
monitored and recorded.
(c)
The continuous emission monitors must satisfy
the requirements of 40 CFR 60 Appendix B,
Performance Specification 2.
(d)
The continuous emission monitors must satisfy
the quality assurance requirements of 40 CFR
60, Appendix F.
(e)
The continuous emission monitoring system will
be used to determine compliance with the
applicable allowable NOx emission rates.
(f)
The
stationary
source
shall
have
the
capability
of
transmitting
all
of
the
collected continuous emission monitoring data
to the Division's office via a telemetry
system.
(g)
Each continuous emission monitoring system
shall be operated at all times except for
periods of CEMs calibration checks, zero and
span adjustment and preventative maintenance.
Notwithstanding such exceptions, in all cases
valid CEMs data shall be obtained for at least
75% of the hours per day, 75% of the days of
16
the month and 90% of the hours per quarter
that the stationary source is operating.
27.5.7
Emissions testing shall comply with the following
requirements:
(a)
Emissions testing shall be conducted by 30
November
1995,
initially
and
annually
thereafter to demonstrate compliance with the
applicable NOx emission limitation
(b)
An
emissions
testing
protocol
shall
be
submitted to the Division for review and
approval prior to the performance of any
tests. The Division shall be notified at
least 60 days prior to any emissions test.
(c)
All test procedures used for emissions testing
shall be in accordance with the methods set
forth in Appendix A of 40 CFR 60 or another
method approved by the Division and the USEPA.
(d)
The owner/operator of the stationary source
shall install any and all test ports or
platforms necessary to conduct the required
emissions testing, provide safe access to any
platforms and provide the necessary utilities
for sampling and testing equipment.
(e)
All testing shall be conducted under operating
conditions
deemed
acceptable
and
representative for the purpose of assessing
compliance
with
the
applicable
emission
limitation.
(f)
All emissions testing must be observed by the
Division or its authorized representative to
be considered acceptable.
(g)
A final report of the results of emissions
testing shall be submitted to the Division no
later than 60 days following completion of the
testing.
27.6 Recordkeeping and Reporting Requirements
27.6.1
A
record
of
all
measurements,
performance
evaluations, calibration checks, and maintenance or
adjustments for each continuous emission monitor
shall be maintained.
17
27.6.2
A written report of excess emissions as measured by
a continuous emission monitor shall be submitted to
the Division for every calendar quarter. All
quarterly reports shall be received no later than
30 days following the end of each calendar quarter
and shall include the following information:
(a)
The
date
and
time
of
commencement
and
completion of each period of excess emissions
and the magnitude of the excess emissions
(b)
Identification of the suspected reason for the
excess emissions and any corrective action
taken.
(c)
The date and time period any continuous
emission monitor was inoperative, except for
zero and span checks and the nature of system
repairs or adjustments.
(d)
The date and time periods of any missing data
or periods where compliance could not be
determined and the steps taken to cure the
cause of the missing data.
In the event none of the above items have occurred
such information shall be stated in the report.
27.6.3
The fuel used in each combustion unit subject to
RACT must be measured and recorded monthly.
As an alternative to measuring and recording fuel
used in each combustion unit, a stationary source
may petition the Division to use one of the
following methods to demonstrate compliance with
RACT:
(a)
The fuel used in multiple combustion units
which have equivalent NOx emission rates may be
measured and recorded monthly using a single
metering device. If more than one type of
fuel is used in the multiple combustion units
the amount of each type fuel must be measured
and recorded monthly;
(b)
The fuel used in multiple combustion units
which have different NOx emission rates may be
measured and recorded monthly using a single
metering device. If more than one type of
fuel is used in the multiple combustion units
the amount of each type fuel must be measured
18
and recorded monthly. The total NOx emissions
for these units will be determined using the
emission rate of the highest NOx emitting
combustion unit.
27.6.4
Stationary sources subject to Subsection 27.4.2
(a)(2) shall obtain a certification from the fuel
supplier for each shipment of distillate oil that
includes the following information:
(a)
The name of the oil supplier, and;
(b) That the oil complies with the specification
for fuel oil numbers 1 or 2, as defined by the
American Society for Testing and Materials in
ASTM D396-78 "Standard Specification for Fuel
Oils"
27.6.5
All stationary sources combusting residual fuel oil
shall obtain a certification from the fuel supplier
for each shipment of residual oil that includes the
following information:
(a)
The name of the oil supplier;
(b)
The nitrogen content of the oil from which the
shipment came or of the shipment itself;
(c)
The method used to determine the nitrogen
content of the oil. ASTM test methods D3228,
D4629 or any other method approved by the
Division and the USEPA may be used; and,
(d)
The location of the oil when the sample was
drawn for analysis to determine the nitrogen
content of the oil, specifically including
whether the oil was sampled as delivered to
the stationary source or whether the sample
was drawn from oil in storage at the oil
supplier's
or
oil
refiner's
facility
or
another location.
27.6.6
As
an
alternative
to
the
fuel
supplier
certification required in Subsection 27.6.5, a
stationary source may elect to sample the fuel oil
prior to combustion. Sampling and analysis shall
be conducted after each new shipment of residual
oil is received. Samples shall be collected from
the fuel tank immediately after the fuel tank is
filled and before any oil is combusted. The
residual oil must be sampled and analyzed according
19
to ASTM methods which have the prior approval of or
are required by the Director.
27.6.7
Copies of all fuel supplier certifications or fuel
oil analyses shall be maintained at the facility
and be made accessible for review by the Director
or the designated personnel of the Director and
EPA. These records shall include a certified
statement, signed by the owner/operator of the
stationary source, that the records represent all
of the fuel combusted during the quarter.
27.6.8
All stationary sources subject to Subsection 27.4.2
(c) shall maintain records verifying that a tune-up
has been performed in accordance with the procedure
described in Appendix A that includes the following
information:
(a)
The date the tune-up was performed;
(b)
The name of the person who performed the tune-
up; and,
(c)
The final excess oxygen setting.
(d)
The O2/CO curve or O2/smoke curve that has been
developed as part of this procedure.
27.6.9
Stationary sources subject to an emissions cap
pursuant to the provisions of Subsection 27.2.2
shall:
(a)
Measure and record monthly the fuel used in
each combustion unit with a heat input greater
than or equal to one million BTUs per hour;
(b)
On a monthly basis, no later than fifteen (15)
days after the first of each month, determine
the fuel usage and quantity of NOx emitted for
the previous twelve (12) month period for each
combustion unit or for the stationary source;
(c)
Notify the Division, in writing within 30 days
of the end of the month, whenever NOx emissions
exceed the emissions cap; or,
(d)
As an alternative to measuring and recording
fuel used in each combustion unit as required
in
27.6.9
(a),
a
stationary
source
may
petition the Division to use one of the
following methods to demonstrate compliance
20
with an emissions cap:
(1)
The fuel used in multiple combustion
units which have equivalent NOx emission
rates
may
be
measured
and
recorded
monthly using a single metering device.
If more than one type of fuel is used in
the multiple combustion units the amount
of each type fuel must be measured and
recorded monthly;
(2)
The fuel used in multiple combustion
units which have different NOx emission
rates
may
be
measured
and
recorded
monthly using a single metering device.
If more than one type of fuel is used in
the multiple combustion units the amount
of each type fuel must be measured and
recorded
monthly.
The
total
NOx
emissions
for
these
units
will
be
determined using the emission rate of the
highest NOx emitting unit.
27.6.10
All stationary sources with emergency standby
internal
combustion
engines
satisfying
the
provisions of Subsection 27.2.3 shall :
(a)
Notify the Division, in writing, by 31 May
1995 of:
(1)
the maximum capacity, in millions of BTUs
per hour, of each emergency standby
internal
combustion
engine
at
the
stationary source; and,
(2)
the type of fuel or fuels combusted in
each engine;
(b)
Install and maintain a non-resetable elapsed
time meter to indicate, in cumulative hours,
the elapsed engine operating time;
(c)
On a monthly basis, no later than five (5)
days after the first of each month, determine
and record the hours of operation for each
engine for the previous twelve (12) month
period;
(d)
Notify the Division, in writing, whenever the
hours of operation in any twelve (12) month
period exceeds 500 hours; and
21
(e)
Maintain records to certify that the ignition
timing of the engine has been inspected and
adjusted at least once every three (3) years.
27.6.11
All records required in this Subsection shall be
maintained at the stationary source for a minimum
of five (5) years and shall be made available to
representatives
of
the
Division
or
EPA
upon
request.
22
APPENDIX A
EQUIPMENT TUNING PROCEDURE
1
Nothing in this Equipment Tuning Procedure shall be construed to
require any act or omission that would result in unsafe conditions
or would be in violation of any regulation or requirement
established
by
Factory
Mutual,
National
Fire
Prevention
Association, the Rhode Island Department of Labor (Division of
Occupational Safety), the Federal Occupational Safety and Health
Administration or other relevant regulations or requirements.
1.
Operate the unit at the firing rate most typical of normal
operation.
If
the
unit
experiences
significant
load
variations during normal operation, operate it at its average
firing rate.
2.
At this firing rate, record stack gas temperature, oxygen
concentration and CO concentration (for gaseous fuels) or
smoke-spot number
2 (for liquid fuels) and observe flame
conditions after the unit stabilizes at the firing rate
selected. If the excess oxygen in the stack gas is at the
lower end of the range of typical minimum values
3, and if the
CO emissions are low and there is no smoke, the unit is
probably operating at near optimum efficiency - at this
particular firing rate. However, complete the remaining
portion of this procedure to determine whether still lower
oxygen levels are practical.
3.
Increase combustion air flow to the furnace until stack gas
oxygen levels increase by one to two percent over the value
measured in Step 2. As in Step 2, record the stack gas
temperature, CO concentration (for gaseous fuels) or smoke-
spot number (for liquid fuels) and observe flame conditions
for these higher oxygen levels after boiler operation
stabilizes.
4.
Decrease combustion air flow until the stack gas oxygen
concentration is at the level measured in Step 2. From this
level gradually reduce the combustion air flow in small
increments. After each increment, record the stack gas
temperature, oxygen concentration, CO concentration (for
gaseous fuels) and smoke-spot number (for liquid fuels). Also
observe the flame and record any changes in its condition.
5.
Continue to reduce combustion air flow stepwise until one of
these limits is reached:
a.
Unacceptable
flame
conditions
-
such
as
flame
impingement on furnace walls or burner parts, excessive
flame carryover or flame instability.
23
b.
Stack gas CO concentration greater than 400 ppm.
c.
Smoking at the stack.
d.
Equipment
related
limitations
-
such
as
low
windbox/furnace pressure differential, built in air flow
limits, etc.
6.
Develop an O2/CO curve (for gaseous fuels) or O2/smoke curve
(for liquid fuels) similar to those in Figures 1 and 2 using
the excess oxygen and CO or smoke-spot number data obtained at
each combustion air flow setting.
7.
From the curves prepared in Step 6, find the stack gas oxygen
levels where the CO emissions or smoke-spot number equal the
following values:
Fuel
Measurement
Value
Gaseous
CO emissions
400 ppm
#1 & #2 oils
smoke-spot number
number 1
#4 oil
smoke-spot number
number 2
#5 oil
smoke-spot number
number 3
#6 oil
smoke-spot number
number 4
The above conditions are referred to as CO or smoke threshold,
or as the minimum excess oxygen level.
Compare this minimum value of excess oxygen to the expected
value provided by the combustion unit manufacturer. If the
minimum value found is substantially higher than the value
provided
by
the
combustion
unit
manufacturer,
burner
adjustments shall be made to improve fuel and air mixing,
thereby allowing operation with less air.
8.
Add 0.5 to 2.0 percent to the minimum excess oxygen level
found in Step 7 and reset burner controls to operate
automatically at this higher stack gas oxygen level. This
margin
above
the
level
accounts
for
fuel
variations,
variations in atmospheric conditions, load changes and non
repeatability or play in automatic controls.
9.
If the load of the combustion unit varies significantly during
normal operation, repeat Steps 1-8 for firing rates that
represent the upper and lower limits of the range of the load.
Because control adjustments at one firing rate may affect
24
conditions at other firing rates, it may not be possible to
establish the optimum excess oxygen level at all firing rates.
If this is the case, choose the burner control settings that
give the best performance over the range of firing rates. If
one firing rate predominates, settings should optimize
conditions at that rate.
10.
Verify that the new settings can accommodate the sudden
changes that may occur in daily operation without adverse
affects. Do this by increasing and decreasing load rapidly
while observing the flame and stack. If any of the conditions
in Step 5 result, reset the combustion controls to provide a
slightly higher level of excess oxygen at the affect firing
rates. Next, verify these new settings in a similar fashion.
Then make sure that the final control settings are recorded
at steady state operating conditions for future reference.
_________________________________________________________________
1.
This tuning procedure is based on a tune-up procedure
developed by KVB Inc. for the USEPA.
2.
The smoke-spot number can be determined with ASTM Test Method
D-2156 or with the Bacharach method. ASTM Test Method D-2156
is included in a tune-up kit that can be purchased from the
Bacharach Company.
3.
Typical minimum oxygen levels for boilers at high firing rates
are:
For natural gas: 0.5% - 3.0%
For liquid fuels: 2.0% - 4.0%