Document ID: EPA-R01-OAR-2015-0306-0024
Agency: epa
Document Type: Supporting & Related Material
Title: 
Posted Date: 2016-07-25T04:00Z

STATE OF RHODE ISLAND AND PROVIDENCE PLANTATIONS

DEPARTMENT OF ENVIRONMENTAL MANAGEMENT

OFFICE OF AIR RESOURCES

AIR POLLUTION CONTROL REGULATION NO. 27

CONTROL OF NITROGEN OXIDE EMISSIONS 

Effective 1 February 1994

Last Amended   19 July 2007

AUTHORITY:	These regulations are authorized pursuant to R.I. Gen. Laws
§ 42-17.1-2(s) and 23-23, as amended, and have been promulgated
pursuant to the procedures set forth in the R.I. Administrative
Procedures Act, R.I. Gen. Laws Chapter 42-35.

RHODE ISLAND DEPARTMENT OF ENVIRONMENTAL MANAGEMENT

OFFICE OF AIR RESOURCES

AIR POLLUTION CONTROL REGULATION NO. 27

CONTROL OF NITROGEN OXIDE EMISSION

TABLE OF CONTENTS

  TOC \o "1-3" \h \z \u    HYPERLINK \l "_Toc168814918"  27.1
Definitions	  PAGEREF _Toc168814918 \h  1  

  HYPERLINK \l "_Toc168814919"  27.2	Applicability and Exemptions	 
PAGEREF _Toc168814919 \h  3  

  HYPERLINK \l "_Toc168814920"  27.3	Reasonably Available Control
Technology (RACT) Plan Requirements	  PAGEREF _Toc168814920 \h  3  

  HYPERLINK \l "_Toc168814921"  27.4	Reasonably Available Control
Technology (RACT) Requirements	  PAGEREF _Toc168814921 \h  6  

  HYPERLINK \l "_Toc168814922"  27.5	Compliance Testing and Emission
Monitoring Requirements	  PAGEREF _Toc168814922 \h  10  

  HYPERLINK \l "_Toc168814923"  27.6	Recordkeeping and Reporting
Requirements	  PAGEREF _Toc168814923 \h  12  

  HYPERLINK \l "_Toc168814924"  27.7	General Provisions	  PAGEREF
_Toc168814924 \h  16  

  HYPERLINK \l "_Toc168814925"  APPENDIX A	  PAGEREF _Toc168814925 \h 
18  

 

RHODE ISLAND DEPARTMENT OF ENVIRONMENTAL MANAGEMENT

OFFICE OF AIR RESOURCES

AIR POLLUTION CONTROL REGULATION NO. 27

CONTROL OF NITROGEN OXIDES EMISSIONS

	

27.1	Definitions

	Unless otherwise expressly defined in this section, the terms used in
this regulation shall be defined by reference to the Rhode Island Air
Pollution Control General Definitions Regulation.  As used in this
regulation, 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		"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. 3		"Combustion turbine" means any simple cycle gas turbine or any
combined cycle gas turbine including the duct burner portion thereof.

	27.1.4		"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 interruptible power service agreement.

	27.1.5		"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 Department and EPA guidance must be used to
demonstrate equivalence.

 

	27.1.6		"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.

	27.1.7		"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.

	27.1.8		"Lean-burn engine" means an internal combustion engine where
the amount of oxygen in the exhaust gases is 1% or more, by weight.

	27.1.9		"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".

	27.1.10		"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.

	27.1.11		"Rich-burn engine" means an internal combustion engine where
the amount of oxygen in the engine exhaust gases is less than 1% by
weight.

	27.1.12		“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.

	27.1.13		"Utility boiler" means a device, with a heat input capacity of
250 million Btu 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
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 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 Btu per hour at the
stationary source

			(b)	the maximum capacity, in millions of  Btu 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 Btu per hour at the
stationary source

			(b)	the maximum capacity, in million of Btu 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)	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 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 actual heat input when operated on
natural gas or liquified petroleum gas (LP)

			(b)	0.25 lbs per million Btu of actual 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 Btu per hour or greater, in excess of the
following emission limitations:

				1.	0.10 lbs per million Btu of actual heat input when operated on
natural gas

				2.	0.12 lbs per million Btu of actual 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 Btu
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 Btu 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
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
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 Btu per hour at the
stationary source

				2.	the maximum capacity, in million of Btu 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.

				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.

			(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 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 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 EPA.

			(d)	The owner or 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.

	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 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 EPA 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 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 or
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 capacity greater than or equal to one million Btu 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 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 Btu 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

			(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 Department or EPA upon request.

General Provisions

Purpose

The purpose of this regulation is to limit emissions of nitrogen oxides
from stationary sources

Authority

These regulations are authorized pursuant to R.I. Gen. Laws §
42-17.1-2(s) and 23-23, as amended, and have been promulgated pursuant
to the procedures set forth in the R.I. Administrative Procedures Act,
R.I. Gen. Laws Chapter 42-35

Application

The terms and provisions of this regulation shall be liberally construed
to permit the Department to effectuate the purposes of state law, goals
and policies.

Severability

If any provision of this regulation or the application thereof to any
person or circumstance, is held invalid by a court of competent
jurisdiction, the validity of the remainder of the regulation shall not
be affected thereby.

Effective Date

The foregoing regulation, "Control of Nitrogen Oxide Emissions”, as
amended, after due notice, is hereby adopted and filed with the
Secretary of State this __29th___ day of __June_________, 2007_ to
become effective twenty (20) days thereafter, in accordance with the
provisions of Chapters 23-23, 42-35, 42-17.1, 42-17.6, of the General
Laws of Rhode Island of 1956, as amended.

W. Michael Sullivan, PhD., Director

Department of Environmental Management

Notice Given on:  February 21, 2007

Public Hearing held:	March 23, 2007

Filing Date:	June 29, 2007

Effective Date:  July 19, 2007

APPENDIX A

EQUIPMENT TUNING PROCEDURE1

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
number2 (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 values3,
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.

	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 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 EPA.

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% 

 

 

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