Standards of Performance for New Stationary Sources: Industrial- Commercial-Institutional Steam Generating Units; Louisiana

40 CFR Part 60

40 CFR Part 60

[AD-FRL-5128-4]

Standards of Performance for New Stationary Sources: Industrial-

Commercial-Institutional Steam Generating Units; Louisiana

AGENCY: Environmental Protection Agency (EPA).

ACTION: Proposed revision of rule.

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SUMMARY: New source performance standards (NSPS) limiting emissions of

nitrogen oxides (NOX) from industrial-commercial-institutional

steam generating units capable of combusting more than 100 million Btu

per hour were proposed on June 19, 1984 and were promulgated on

November 25, 1986. These standards limit NOX emissions from the

combustion of fossil fuels, as well as the combustion of fossil fuels

with other fuels or wastes. The standards include provisions for

facility-specific NOX standards for steam generating units which

simultaneously combust fossil fuel and chemical byproduct waste(s)

under certain conditions. This action proposes to approve a facility-

specific NOX standard for a steam generating unit which

simultaneously combusts fossil fuel and chemical byproduct waste (vent

gas) at the Cytec Industries Fortier Plant located in Westwego,

Louisiana.

DATES: Comments. Comments on the proposed revision must be received by

January 27, 1995

ADDRESSES: Comments. Comments on the proposed revision should be

submitted (in duplicate, if possible) to: The Air and Radiation Docket

and Information Center, 401 M Street, SW, Washington, DC 20460,

attention Docket Number A-94-48.

Docket. Docket Number A-94-48, containing supporting information

used in developing the proposed revision, is available for public

inspection and copying between the hours of 8:00 a.m. and 5:30 p.m.,

Monday through Friday (except for government holidays) at The Air and

Radiation Docket and Information Center, 401 M Street, SW, Washington,

DC 20460. A reasonable fee may be charged for copying.

FOR FURTHER INFORMATION CONTACT: Mr. George Smith at (919) 541-1549,

Standards Development Branch, Emission Standards Division (MD-13), U.S.

Environmental Protection Agency, Research Triangle Park, North Carolina

27711.

SUPPLEMENTARY INFORMATION:

Background

Combustion is one means for disposal of chemical by-product wastes.

Combustion in a flare or an incinerator is effective, in terms of

disposal of the waste, but provides no additional benefit. Combustion

in a steam generating unit, on the other hand, provides the benefit of

energy recovery, thereby reducing overall energy consumption and

conserving energy resources.

Depending on the composition of the waste, however, combustion of

chemical by-product waste may be an emission source of toxic air

pollutants. For this reason, steam generating units are a source

category scheduled for regulation by national emissions standards for

hazardous air pollutants (NESHAP) under section 112 of the Clean Air

Act by November 15, 2000.

Currently, any steam generating unit which commenced construction,

modification, or reconstruction after June 19, 1984 and is capable of

combusting greater than 100 million Btu per hour of fossil fuel or a

combination of fossil fuel with other fuels or wastes is subject to

NSPS. These NSPS are codified under 40 CFR part 60 as subpart Db and

include emission limits for NOX.

These NSPS allow for two different NOX emission limits for

steam generating units that combust either natural gas or distillate

oil, depending on whether the steam generating unit has a low heat

release rate or high heat release rate. A low heat release rate is

defined in the NSPS as being 70,000 Btu/hour-cubic foot or less; a high

heat release rate is greater than 70,000 Btu/hour-cubic foot. The

NOX emission limit for low heat release rate steam generating

units that combust either natural gas or distillate oil is 0.1 pounds

per million Btu and for high heat release rate units it is 0.2 pounds

per million Btu.

The objective of the NSPS is to limit NOX emissions from the

combustion of fossil fuel. For steam generating units combusting by-

product waste, the requirements of the NSPS vary depending on the

operation of the steam generating units.

During periods when only fossil fuel is combusted, the steam

generating unit must comply with the NOX emission limits in the

NSPS for fossil fuel. During periods when only by-product waste is

combusted, the steam generating unit may be subject to other

requirements or regulations which limit NOX emissions, but it is

not subject to NOX emission limits under the NSPS. In addition, if

the steam generating unit is subject to Federally enforceable permit

conditions limiting the amount of fossil fuel combusted in the steam

generating unit to an annual capacity factor of 10 percent or less, the

steam generating unit is not subject to NOX emission limits under

the NSPS, when it simultaneously combusts fossil fuel and by-product

waste.

With the exception noted above, during periods when fossil fuel and

by-product waste is simultaneously combusted in a steam generating

unit, the unit must generally comply with NOX emission limits

under Sec. 60.44b(e) of the NSPS. Under Sec. 60.44b(e) the applicable

NOX emission limit depends on the nature of the by-product waste

combusted. In some situations, however, ``facility specific'' NOX

emission limits developed under Sec. 60.44b(f) may apply. The order for

determining which NOX emission limit applies is as follows.

A steam generating unit simultaneously combusting fossil fuel and

by-product waste is expected to comply with the NOX emission limit

under Sec. 60.44b(e); only in a few situations may NOX emission

limits developed under Sec. 60.44b(f) apply. Section 60.44b(e) includes

an equation to determine the NOX emission limit applicable to a

steam generating unit when it simultaneously combusts fossil fuel and

by-product waste.

In essence, if the by-product waste is gaseous in nature and it is

combusted with natural gas or distillate oil, the equation in

Sec. 60.44b(e) subjects the steam generating unit to the NOX

emission rate for natural gas or distillate oil, which are the same

under the NSPS. If the by-product waste is liquid in nature and it is

combusted with residual oil, the equation subjects the steam generating

unit to the NOX emission limit for residual oil. The heat input to

the steam generating unit released by combustion of both the natural

gas, distillate oil or residual oil, as well as the heat input released

from combustion of the by-product waste, are used to determine

compliance with the NOX emission limit.

Finally, if the by-product waste is gaseous in nature or liquid in

nature and is combusted with natural gas, distillate oil, residual oil,

or coal, the equation subjects the steam generating unit to an NOX

emission limit derived from the NOX emission limits for natural

gas, distillate oil, residual oil, and coal. This NOX emission

limit depends on the relative heat input to the steam generating unit

provided by combustion of the gaseous and/or liquid by-product waste,

natural gas, distillate oil, residual oil, and/or coal.

As mentioned above, the objective of the NSPS is to limit NOX

emissions from the combustion of fossil fuel. Consequently, in

determining compliance with the NOX emission limits, NOX

introduced into the steam generating unit with the combustion air or

the fuel may be subtracted from NOX emissions released from the

steam generating unit in determining compliance with the NOX

emission limits under the NSPS. Such situations may arise where the

exhaust from a gas turbine is used as a source of preheated combustion

air to a steam generating unit. The gas turbine exhaust will contain

NOX (which may be subject to the NOX emission limits in the

NSPS applicable to gas turbines) and this NOX may be subtracted

from the NOX released from the steam generating unit, in

determining compliance with the NSPS applicable to steam generating

units. Similarly, NOX contained in a by-product waste may be

subtracted from the NOX released by the steam generating unit in

determining compliance with the NSPS when the steam generating unit

simultaneously combusts fossil fuel and by-product waste.

Only where a steam generating unit which simultaneously combusts

fossil fuel and by-product waste is unable to comply with the NOX

emission limit determined under Sec. 60.44b(e), might a facility

specific NOX emission limit under Sec. 60.44b(f) apply. This

section permits a steam generating unit to petition the Administrator

for a facility specific NOX emission limit. A facility specific

NOX emission limit will be proposed and promulgated by the

Administrator for the steam generating unit, however, only where the

petition is judged to be complete.

To be considered complete, a petition for a facility-specific

NOX standard under Sec. 60.44b(f) consists of three components.

The first component is a demonstration that the steam generating unit

is able to comply with the NOX emission limit for fossil fuel when

combusting fossil fuel alone. The purposes of this provision are to

ensure that the steam generating unit has installed best demonstrated

NOX control technology, to identify the NOX control

technology installed, and to identify the manner in which this

technology is operated to achieve compliance with the NOX emission

limit for fossil fuel.

The second component of a complete petition is a demonstration that

this NOX control technology does not enable compliance with the

NOX emission limit for fossil fuel when the steam generating unit

simultaneously combusts fossil fuel with chemical byproduct waste under

the same conditions used to demonstrate compliance on fossil fuel

alone. In addition, this component of the petition must identify what

unique and specific properties of the chemical byproduct waste(s) are

responsible for preventing the steam generating unit from complying

with the NOX emission limit for fossil fuel.

The third component of a complete petition consists of data and or

analysis to support a facility-specific NOX standard for the steam

generating unit when it simultaneously combusts fossil fuel and

chemical byproduct waste and operates the NOX control technology

in the same manner it would be operated in to demonstrate and maintain

compliance with the NOX emission limit for fossil fuel, if only

fossil fuel were combusted. This component of the petition must

identify the NOX emission limit(s) and/or operating parameter

limits, and appropriate testing, monitoring, reporting and

recordkeeping requirements which will ensure operation of the NOX

control technology and minimize NOX emissions at all times.

Upon receipt of a complete petition, the Administrator will propose

a facility-specific NOX standard for the steam generating unit

when it simultaneously combusts chemical byproduct waste with fossil

fuel. The NOX standard will include the NOX emission limit(s)

and/or operating parameter limit(s) to ensure operation of the NOX

control technology at all times, as well as appropriate testing,

monitoring, reporting and recordkeeping requirements.

Cytec Industries Petition

Cytec Industries of Westwego, Louisiana has submitted a petition

for a facility-specific NOX standard under Sec. 60.44b(f) of

Subpart Db. The facility-specific standard would apply to a steam

generating unit referred to by Cytec Industries as their C.AOG off-gas

incinerator. This steam generating unit has a heat input capacity of

approximately 260 million Btu per hour and simultaneously combusts the

fossil fuel natural gas with the chemical byproduct wastes (vent gas)

described below. The C.AOG off-gas incinerator has a heat release rate

of less than 70,000 Btu/hour-cubic foot, and is therefore a low heat

release rate steam generating unit. Because the C.AOG off-gas

incinerator combusts natural gas, its applicable NOX emission

limit is the low heat release rate NOX emission limit for natural

gas of 0.1 pounds per million Btu.

The merits of the Cytec Industries petition are discussed below in

terms of the components of a complete petition for a facility-specific

NOX standard under Sec. 60.44b(f) of Subpart Db.

Component One: Fossil Fuel Compliance

As discussed above, the first component of a complete petition is a

demonstration that the steam generating unit is able to comply with the

NOX emission limit for fossil fuel when combusting fossil fuel

alone. This ensures the steam generating unit has installed best

demonstrated NOX control technology, identifies the NOX

control technology, and identifies the manner in which the NOX

control technology is operated to demonstrate compliance.

Section 60.44b(f) states that the owner or operator must conduct a

30-day performance test with the steam generating unit combusting

fossil fuel alone to demonstrate compliance with the NOX emission

limit for fossil fuel. The General Provisions of Part 60, however,

permit the Administrator to waive the requirements for a performance

test. Specifically, paragraph (b)(4) of Sec. 60.8, entitled Performance

Tests, states the Administrator may waive the requirement for a

performance test where the owner or operator demonstrates by other

means to the satisfaction of the Administrator that the affected

facility (i.e., the steam generating unit) is in compliance.

While a 30-day performance test is the most direct means of

ensuring that best demonstrated NOX control technology has been

installed, Cytec Industries' C.AOG incinerator is not capable of

combusting the fossil fuel (i.e., natural gas) at the full rated heat

input capacity of the steam generating unit. Instead of conducting this

performance test, Cytec Industries has submitted to the Administrator

engineering calculations on NOX formation for its C.AOG

incinerator.

These calculations were made by employing a computer program

written by Cytec Industries' C.AOG incinerator designer and

manufacturer and by utilizing published equilibrium and kinetic data on

NOX formation. Cytec Industries has installed staged air

combustion on its C.AOG incinerator to control NOX emissions. This

staged air combustion system effectively divides the combustion process

into two zones: a fuel-rich or reducing zone and an oxygen-rich or

oxidizing zone. To reduce NOX emissions, the staged air combustion

system will operate with a maximum of 81 percent of the total inlet air

entering the reducing zone. The computer program predicts the NOX

emissions when combusting natural gas alone would be a maximum of 0.036

pounds per million Btu. This is less than the 0.1 pounds per million

Btu emission limit specified in subpart Db.

The engineering calculations, data and information provided by

Cytec Industries demonstrate to the Administrator's satisfaction that

their C.AOG incinerator would comply with the NOX emission limit

for fossil fuel (i.e., natural gas), if the steam generating unit

combusted fossil fuel alone. Consequently, the requirement to conduct a

30 day performance test is waived. However, this waiver is not to be

construed as any abrogation of the Administrator's authority to require

testing under section 114 of the Clean Air Act. In addition, the data

and information provided by Cytec industries identifies staged air

combustion as the best demonstrated technology installed to comply with

Subpart Db. It also demonstrates that this technology will operate with

a maximum of 81 percent of the inlet air provided to the reducing zone

to demonstrate and maintain compliance with the NOX emission limit

for fossil fuel.

The Administrator considers the above data and information

submitted by Cytec Industries sufficient to satisfy the criteria of

component one of a complete petition.

Component Two: Fossil Fuel/Waste Noncompliance

As discussed above, the second component of a complete petition is

a demonstration that the steam generating unit's NOX control

technology does not enable compliance with the NOX emission limit

for fossil fuel when the steam generating unit simultaneously combusts

fossil fuel with chemical byproduct waste under the same conditions

used to demonstrate compliance on fossil fuel alone. This component of

the petition must also identify the unique and specific properties of

the chemical by-product waste(s) which prevent the steam generating

unit from complying with the NOX emission limit for fossil fuel.

Because Cytec Industries has no operating data yet on their C.AOG

incinerator, they have submitted to the Administrator data and

information on the composition of the wastes and the projected NOX

emissions resulting from the combustion of the wastes.

Cytec Industries' C.AOG incinerator was designed to destroy the

hydrocarbons in absorber off gas (AOG) from its acrylonitrile

production at its Fortier Plant. This AOG contains approximately 90

percent nitrogen and its oxides and can not support combustion on its

own. The C.AOG incinerator is also designed to accept relatively

smaller vent gas volumes from an adjacent and related production unit

(a methyl methacrylate plant), as well as vaporous hydrogen cyanide and

acetonitrile, when conditions are such that they can not be condensed

for sale.

The waste materials (vent gas) being burned include 90 pounds of

NOX per hour from the reactor waste gas, as well as a varying load

of organic nitrogen compounds. Although Cytec Industries' C.AOG

incinerator will employ staged air combustion to reduce NOX

emissions, these emissions will still be above the 0.1 pounds per

million Btu emission limit specified in Subpart Db. (This is still the

case even when subtracting the incoming 90 pounds of NOX per hour

from the reactor waste gas.) The computer program written by Cytec

Industries' C.AOG incinerator designer and manufacturer predicts

NOX emissions of 0.67 pounds per million Btu.

The engineering calculations, data, and information provided by

Cytec Industries demonstrates to the Administrator's satisfaction that

the NOX control technology installed and operated in a manner to

achieve compliance with the NOX emission limit for fossil fuel, if

fossil fuel alone were combusted in the unit, is unable to achieve

compliance with the fossil fuel NOX emission limit when a mixture

of chemical byproduct waste and fossil fuel is combusted in the unit.

It also indicates the reason is the high level of nitrogen and its

oxides contained in the chemical byproduct wastes.

The Administrator considers the above data and information

submitted by Cytec Industries sufficient to satisfy the criteria of

component two of a complete petition.

Component Three: Facility Specific NOX Standard

As discussed above, the third component of a complete petition is

data and/or analysis to support a facility-specific NOX standard

for the steam generating unit when it simultaneously combusts fossil

fuel and chemical byproduct waste and operates the NOX control

technology in the manner it would be operated in to demonstrate and

maintain compliance with the NOX emission limit for fossil fuel,

if only fossil fuel were combusted in the unit. This component of the

petition must identify the NOX emission limit(s) and/or operating

parameter limits, and appropriate testing, monitoring, reporting and

recordkeeping requirements to ensure operation of the NOX control

technology at all times.

As discussed above, the information and analysis supplied by Cytec

Industries indicates:

1. Staged air combustion is the technology installed to comply with

the NOX emission limit for fossil fuel (i.e., natural gas).

2. When combusting natural gas alone, this staged air combustion

system will ensure compliance with the NOX emission limit of 0.1

pounds per million Btu, when it is operated with 81 percent of the

inlet air diverted to the reducing zone.

3. When simultaneously combusting natural gas and chemical by

product waste, this staged air combustion system will limit NOX

emissions to 0.67 pounds per million Btu or less, when it is operated

with a maximum of 81 percent of the inlet air diverted to the reducing

zone.

The information supplied by Cytec Industries also indicates

NOX emissions, as well as air flow to the reducing and oxidizing

zones, will be continuously measured and monitored to ensure operation

of the NOX control technology in the manner it would be operated

in to demonstrate and maintain compliance with the NOX emission

limit for fossil fuel, if only fossil fuel were combusted.

The Administrator considers the above data and information

submitted by Cytec Industries sufficient to satisfy the criteria of

component three of a complete petition.

Proposed Facility-Specific NOX Standard

The Administrator considers the petition from Cytec Industries

complete and proposes a facility-specific NOX standard for the

C.AOG steam generating unit. The NOX standard for Cytec

Industries' C.AOG incinerator when it simultaneously combusts natural

gas (fossil fuel) with chemical byproduct waste (vent gas) is proposed

as 0.67 pounds per million Btu. A continuous NOX monitor shall be

used to monitor compliance with the NOX emission limit in

accordance with the requirements of Subpart Db. In addition, the staged

air combustion system shall be operated with a maximum of 81 percent of

the total inlet air entering the reducing zone. The percent of total

inlet air provided for the reducing zone shall be determined

continuously by measuring the air flow of all the air entering the

reducing zone and the air flow of all the air entering the oxidation

zone.

Administrative Requirements

Executive Order 12866

Under Executive Order 12866 {58 FR 51735, (October 4, 1993)}, the

Agency must determine whether the regulatory action is ``significant''

and therefore subject to OMB review and the requirements of the

Executive Order. The Order defines ``significant regulatory action'' as

one that is likely to result in a rule that may:

1. Have an annual effect on the economy of $100 million or more or

adversely affect in a material way the economy, a sector of the

economy, productivity, competition, jobs, the environment, public

health or safety, or State, local, or tribal governments or

communities;

2. Create a serious inconsistency or otherwise interfere with an

action taken or planned by another agency;

3. Materially alter the budgetary impact of entitlements, grants,

user fee, or lan programs or the rights and obligations of recipients

thereof; or

4. Raise novel legal or policy issues arising out of legal

mandates, the President's priorities , or the principles set forth in

the Executive Order.

This rule was classified ``non-significant'' under Executive Order

12866 and, therefore was not reviewed by the Office of Management and

Budget.

Paperwork Reduction Act

The information collection requirements of the previously

promulgated NSPS under 40 CFR Part 60, Subpart Db were submitted to and

approved by the Office Of Management and Budget. A copy of this

Information Collection Request (ICR) document (OMB control number 2060-

0135) may be obtained from Sandy Farmer, Information Policy Branch (PM-

223Y); U.S. Environmental Production Agency; 401 M Street, SW;

Washington, DC 20460, or by calling (202) 260-2740. Today's changes to

the NSPS do not affect the information collection burden estimates made

previously. The information that is required to be collected for this

facility specific NOx standard is the same as for all other affected

facilities subject to these NSPS. Therefore, the ICR has not been

revised.

Regulatory Flexibility Act

The Regulatory Flexibility Act of 1980 requires the identification

of potentially adverse impacts of federal regulations upon small

business entities. The Act specifically requires the completion of a

Regulatory Flexibility Analysis in those instances where small business

impacts are possible. Because this rulemaking imposes no adverse

economic impacts, a Regulatory Flexibility Analysis has not been

prepared.

Pursuant to the provisions of 5 U.S.C. 605(b), I hereby certify

that this rule will not have a significant economic impact on a

substantial number of small business entities.

List of Subjects in 40 CFR Part 60

Environmental protection, Administrative practice and procedure,

Air pollution control, Cement industry, Coal, Electric power plants,

Gasoline, Heaters, Intergovernmental relations, Natural gas, Nitrogen

dioxide, Petroleum, Reporting and recordkeeping requirements, Steel,

Waste treatment and disposal.

Dated: December 20, 1994.

Carol M. Browner,

Administrator.

Title 40, chapter I, part 60, of the Code of Federal Regulations is

proposed to be amended to read as follows:

PART 60--STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES

Subpart Db--Standards of Performance for Industrial-Commercial-

Institutional Steam Generating Units

1. The authority citation for part 60 continues to read as follows:

Authority: 42 U.S.C. 7401-7601.

2. Section 60.49b is amended by adding paragraph (s) to read as

follows:

Sec. 60.49b Reporting and recordkeeping requirements.

* * * * *

(s) Facility specific nitrogen oxides standard for Cytec Industries

Fortier Plant's C.AOG incinerator located in Westwego, Louisiana:

(1) Definitions.

Oxidation zone is defined as the portion of the C.AOG incinerator

that extends from the inlet of the oxidizing zone combustion air to the

outlet gas stack.

Reducing zone is defined as the portion of the C.AOG incinerator

that extends from the burner section to the inlet of the oxidizing zone

combustion air.

Total inlet air is defined as the total amount of air introduced

into the C.AOG incinerator for combustion of natural gas and chemical

byproduct waste and is equal to the sum of the air flow into the

reducing zone and the air flow into the oxidation zone.

(2) Standard for nitrogen oxides. (i) When fossil fuel alone is

combusted, the nitrogen oxides emission limit for fossil fuel in

Sec. 60.44b(a) applies.

(ii) When natural gas and chemical byproduct waste are

simultaneously combusted, the nitrogen oxides emission limit is 289 ng/

J (0.67 lb/million Btu) and a maximum of 81 percent of the total inlet

air provided for combustion shall be provided to the reducing zone of

the C.AOG incinerator.

(3) Emission monitoring. (i) The percent of total inlet air

provided to the reducing zone shall be determined at least every 15

minutes by measuring the air flow of all the air entering the reducing

zone and the air flow of all the air entering the oxidation zone, and

compliance with the percentage of total inlet air that is provided to

the reducing zone shall be determined on a 3-hour average basis.

(ii) The nitrogen oxides emission limit shall be determined by the

compliance and performance test methods and procedures for nitrogen

oxides in Sec. 60.46b.

(iii) The monitoring of the nitrogen oxides emission limit shall be

performed in accordance with Sec. 60.48b.

(4) Reporting and recordkeeping requirements. (i) The owner or

operator of the C.AOG incinerator shall submit a report on any

excursions from the limits required by paragraph (a)(2) of this section

to the Administrator with the quarterly report required by

Sec. 60.49b(i).

(ii) The owner or operator of the C.AOG incinerator shall keep

records of the monitoring required by paragraph (a)(3) of this section

for a period of 2 years following the date of such record.

(iii) The owner or operator of the C.AOG incinerator shall perform

all the applicable reporting and recordkeeping requirements of

Sec. 60.49b.

[FR Doc. 94-31744 Filed 12-27-94; 8:45 am]

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