obtain certification, the owner or
operator of a unit must submit a
request to the EPA Administrator.
The request must include the follow-
ing information:

* Unit identification.

« Stack inside diameter at monitor
location and stack height.

* Description of CEMS and con-
tinuous opacity monitoring sys-
tem (COMS) installed.

« Results and date of each perfor-
mance verification test for cer-
tification.

¢ Supporting documentation to
substantiate the test results.

¢ Calculations to verify that the
data acquisition and handling
system properly calculates and
converts the recorded emissions
data into units of the standard.

EPA will issue a notice approving
or disapproving the request for cer-
tification within 120 days. If the
proposed system is disapproved, the
owner or operator must revise the
equipment, procedures, or methods
as necessary and resubmit a request
for certification.

What Quality Assurance/
Quality Control
Procedures Are Required?

Tre proposed rule requires the
owner or operator to develop and
implement a written quality as-
surance/quality control plan for
each system. This plan must be sub-
mitted as part of the utility’s acid rain
permit application. The quality con-
trol plan must include complete,
step-by-step procedures and opera-
tions for calibration checks,
calibration adjustments, preventive
maintenance, audits, and record-
keeping and reporting. The
roposed rule specifies procedures
or assessment of calibration error,
relative accuracy, and bias. The
quality assurance plan must in-
clude relative accuracy test audits,
calibration error tests, and bias tests.

What Alternative
Monitoring Systems Are
Allowed?

Tt owner or operator of an af-
fected unit may apply to the

EPA Administrator for approval of
an alternative monitoring system to
determine hourly emissions data for
SO2, NOx, and/or volumetric flow.
An alternative system must
provide the same or better
precision, reliability, accessibility,
and timeliness as a certified CEM
system. The owner or operator
must submit certain information
and data to demonstrate that the
alternative system meets these
criteria.

The proposed rule includes an
exception for units fired 90 percent
or more by natural gas because
emissions from the 525 units in this
category emitted only about 7,600
tons of SOz in 1985. These units
may use in-line oil flow meters and
oil sampling and analysis to es-
timate tons of SO2 emitted. Units
burning greater than 10 percent oil
may also use this approved, ex-
cepted method, although they must
sample the oil hourly using flow-
proportional or continuous drip
methods. This exception is based on
a combination of factors: (1) the
relative ease of obtaining oil
samples; (2) the fact that oil is much
more homogeneous in sulfur con-
tent than coal; and (3) the approved
oil sampling and analysis methods
produce SO2 emission estimates
consistently higher than actual
CEM data.

What Are the
Recordkeeping, Reporting,
and Notification
Requirements?

Ihe CEM _ rule _ proposes

requirements for notification,
recordkeeping, and reporting for the
Acid Rain Program. The require-
ments include:

* Submission of monitoring plans
as part of the compliance plan
and permit required under the
Permits Rule.

Written notifications of
monitor certification tests.

¢ Daily recording of hourly emis-
sions data and other informa-
tion.

¢ Maintaining records of emis-
sions, flow data, and other in-
formation.

¢ Initial and quarterly reports
of quality assurance and

4

quality control tests for the
EM system.

¢ Reports of recorded emissions,
flow, unit operating status, and
monitoring performance data.
The proposed rule also requir
the owner or operator to electronica
ly report the required information o1
a quarterly basis as an ASCII flat file
via either an IBM-compatible per-
sonal computer flopp’ diskette ora
modem. EPA will use the information
to determine compliance with the
emissions reductions mandated by
the Clean Air Act.

What Are the Deadlines
for Compliance?

he proposed rule applies to ex-

isting units regulated under
Phase I or Phase II of the Acid Rain
Program, and to each new utility
unit when it begins its operation.
(A “new unit” is a defined as a unit
that begins commercial operation
on or after November 15, 1990.)
Equipment required by the
proposed rule must be installed,
certified, and operational by
November 15, 1993, for Phase I af-
fected units, and by January 1, 1995,
for any Phase II units. A unit that
formally commits to retireme:
before December 31, 1994, will a
exempt from the requirements o!
the proposed rule.

For More Information
fF" more information, write to:

U.S. EPA Office of Air and

Radiation

Acid Rain Division

(ANR-445)

Washington, DC 20460

If you would like to receive other
fact sheets in this series, call the Acid
Rain Hotline at (617) 641-5377 or the

EPA Public Information Center (PIC)
at 202-260-2080.

Fact sheets are available on the fol-
lowing subjects:

¢ Allowance System

¢ Environmental Benefits

« Excess Emissions

© Permits

¢ Proposed Acid Rain Rules


United States
Environmental Protection

Agency

Air and Radiation
(ANR-445)

400/1-91/036
December 1991

SEPA

Monitoring
Proposed Acid Rain Rule

The U.S.

Environmental Protection Agen

containing the core acid rain requiremen

the Allowances Rule (40 CFR Part

3), the

Continuous Emission

(EPA) has proposed four mules

the Permits Rule (40 CFR Part 72),

“ontinuous Emission Monitoring

Rule (40 CFR Part 75), and the Excess Emissions Rule (40 CFR Part 77). EPA

will also propose additional rules at a future date. These rules will in
requirements for facilities that elect to opt in to the Acid Rain Program (40 CFR
Part 74) and for the nitrogen oxide (NOx) control program (40 CFR Part 76).

This fact sheet summarizes the key co

Emission Monitoring Rule (40 CFR Part 75)

nder Title IV of the Clean Air Act

Amendments of 1990, Congress
authorized the U.S. Environmental
Protection Agency (EPA) to establish
the Acid Rain Program. The overall
Roel of this program is to significant-
ly reduce sulfur dioxide (SOz) and
nitrogen oxide (NO;,) emissions, the
precursors of acid rain. To achieve
this goal at the lowest cost, the

“ygram will employ both traditional
.<d innovative, market-based ap-
proaches for controlling air pollution.
In addition, the program will en-
courage energy conservation and
promote pollution prevention.

The legislation sets as its primary
goal the reduction of annual SQ? emis-
sions by 10 million tons below 1980
levels. ‘To achieve these SOz reduc-
tions, the law requires a two-phase
tightening of the restrictions placed on
fossil fuel-fired power plants.

Phase I begins in 1995 and affects
110 mostly coal-burning electric
utility plants located in 21 eastern
and midwestern states. Phase II,
which begins in the year 2000,
tightens the annual emissions limits
imposed on these large higher emit-
ting plants and also sets restrictions
onsmaller and cleaner plants fired by
coal, oil, and gas.

All existing utility units with an
output capacity of 25 megawatts or

eater and all new utility units will

affected in Phase II. In addition,
ather sources of SO2 (such as in-

\strial facilities) may elect to par-
uCipate in the Acid Rain SO2 Program
by opting in.

The Act also calls for a 2-million ton
reduction in NOx emissions by the year
2000. A significant portion of this
reduction will be achieved by coal-
fired utility boilers, which will be re-
quired to install low-NOx burner
technologies and meet new emissions
requirements.

These requirements will also be
implemented in two phases. For
Phase I, EPA will establish emis-
sions limitations for two types of
utility boilers (tangentially fired
and dry bottom, wall-fired boilers).
For Phase II, regulations for all
other types of coal-fired boilers will
be issued by 1997, and must be met
beginning in the year 2000 by all
units not subject to the Phase I NOx
limits. Regulations for tangentially
fired and dry bottom, wall-fired
boilers not covered in Phase I may
be tightened at this time.

The innovative, market-based SO2
allowance trading component of the
Acid Rain Program allows utilities to
adopt the most cost-effective strategy
to reduce SO2 emissions at units in
their system. The Acid Rain Program
operating permit spells out the
specific program requirements and
compliance options chosen by each
source. Affected utilities also will be
required to install systems that con-
tinuously monitor emissions of SO2,
NOx, and other related pollutants in
order to track progress, ensure com-
pliance, and provide credibility to the
trading program. In any year that
compliance is not achieved, excess
emissions penalties will apply, and

1

ude

ponents of the proposed Continuous

sources will be required to submit a
plan to EPA that specifies how the
excess SO2 emissions will be offset.

Introduction

ontinuous emission monitoring

(CEM) is the measurement on a
continuous basis of pollutants
emitted into the atmosphere in ex-
haust gases from combustion
processes or as the by-product of in-
dustrial processes. EPA is proposing
requirements for the continuous
monitoring of SO2, volumetric flow,
NOx, diluent, and opacity for units
regulated under Phase I and Phase II
of the Acid Rain Program. In addi-
tion, procedures for monitoring or es-
timating COz are specified. The
proposed rule also contains require-
ments for equipment performance
specifications, certification proce-
dures, and recordkeeping and report-

Why Is CEM Necessary?

he Acid Rain Program establishes

an “allowance trading” system as
a market-based approach to reduce
SO2 emissions in a cost-effective
manner. (One allowance is an
authorization to emit 1 ton of SO2
during or after a specified calendar
year; a utility may buy, sell, or hold
allowances as part of its compliance
strategy.) Complete and accurate
emissions data are key to implement-
ing this market-based approach.

x) Printed on Recycled Paper.


Table 1. CEM Monitor Components Required for Proposed Acid Rain Monitoring

Monitoring Required CEM Monitoring Component

requirement

(units required) SO2 NOx Flow Opacity Diluent Gas Data Handling
SOz (Ibs/hr) Yes Yes Yes

NO, (Ibs/mmBtu)' Yes Yes Yes
Opacity (%) Yes Yes

CO (Ibs/hr)? Yes Yes Yes

An essential feature of smoothly
operating markets is a method for
certifying the existence of the com-
modity being traded. The CEM data
will, in effect, supply the “gold
standard” to back up the paper cur-
rency of emissions allowances. The
CEM requirements, therefore, will
instill confidence in the market-
based approach by certifying the ex-
istence and value of the trading
commodity (the allowance).

CEM will also be instrumental in
ensuring that the mandated reduc-
tions of SOz and NOx are achieved.
While traditional emissions limita-
tion programs have required
facilities to meet specific emissions
rate limitations, the Acid Rain
Program requires an accounting of
the total emissions from regulated
units during each year. Compliance
for each unit is then determined
through a direct comparison of
SO2 emissions totals reported by
CEM and allowances held for the
unit.

What Are the Proposed
Monitoring
Requirements?
Unie the proposed rule, the
owner or operator of a unit regu-
lated under Phase | or Phase II (or a
unit that opts in to the program) and
any new unit must install a CEM sys-
tem on the unit unless otherwise
specified in the regulation. A CEM
system includes:

* An SQ? pollutant concentration
monitor.

e A NOx pollutant concentration
monitor.

¢ A volumetric flow monitor.
« Anopacity monitor.
¢ Adiluent gas monitor.

¢ Adata acquisition and handling
system (computer-based) for
recording an tforming cal-
culations with te data.

Table 1 summarizes the CEM
monitors required by the proposed
rule. In all cases, a data acquisition
and handling system must be used to
collect and report the data.

To monitor SO2 emissions using
a CEM system, a facility must use
both an SQ? pollutant concentration
monitor and a volumetric flow
monitor to measure the emissions in
pounds per hour (the units needed to
determine compliance). If the SO2
monitor measures on a dry basis and
the flow monitor measures on a wet
basis, the owner or operator must
determine the hourly moisture content
of the flue gases and correct the
measured flow rate for moisture using
procedures specified in the rule.

To measure NOx emissions, both
an NOx pollutant concentration
monitor and a diluent gas monitor
are required to calculate an emissions
rate in pounds per million British
thermal units (lbs/mmBtu).

Opacity monitoring, which
involves a percentage calculatiun,
requires only an opacity monitor.
(Under the proposed rule, units
firing 90 percent or more natural gas
with oil as the backup fuel are ex-
empted from the opacity monitoring
requirements.)

The proposed rule does not re-
quire a utility to usea CEM system to
measure COs. If a utility chooses to
use a CEM system, however, a CO2z
diluent monitor plus a flow monitor
may be used to compute emissions in
pounds per hour.

If a CEM system is installed in
such a way that any portion of the
flue gases from an affected unit can
bypass the monitoring system, a
separate CEM system is required on
the bypass flue gas stream.

2

Heat input in mm/Btu/hr is also required. “Alternative methods may be used to monitor CO2.

All CEM systems must be in con-
tinuous operation and must be able
to sample, analyze, and record data
at least every 15 minutes. All emis-
sions and flow data will be reduced
to 1-hour averages. The proposed
rule specifies procedures for convert-
ing the hourly emissions data into
the appropriate units (pounds per
hour for SO2 and pounds per million
Btus for NOx)

How Will Emissions Be
Calculated for Periods
of Missing Data?

fo or more data points are
needed to compile valid 1-houg
averages for emissions flow data, ex
cept during calibration, main-
tenance, repair, or other required
quality assurance activity periods,
where two or more data points may
comprise a valid hour. Failure of the
system to acquire the data points
would result in the loss of data for the
entire hour. The proposed rule con-
tains procedures for “filling in” data
when no valid hour or hours of data
have been recorded by the SO2z
monitor, the flow monitor, and the
NOx CEM system consisting of the
NOx monitor and the diluent gas
monitor. The proposed rule uses a
conservative approach to substitut-
ing for missing data. The proposed
procedures are summarized in Table 2.

What Are the
Requirements for Units
Using a Phase |
Qualifying Technology?

T" proposed rule specifies addi-
tional monitoring requiremen'
for units that are implementin;
optional compliance method
specified under the Permits Rule
that allows a unit to use a Phase |


qualifying technology (a system that
achieves a 90-percent reduction in
SO2 emissions). Each such unit must
be equipped with pollutant and

iluent gas monitors to measure SO2z

nissions at the inlet to the control
device, in addition to the monitors
required for measuring SO2 emis-
sions discharged to the atmosphere.

What Are the
Requirements for
Multiple Units with a
Common Stack?

f two or more units share a

common stack, the proposed rule
allows the owner or operator to com-
bine SO2 allowances according to
the procedures outlined in the
Allowance System Rule and install
one monitoring system. If a Phase I
and Phase II unit share a common
stack, the owner or operator must
either (1) install a separate CEM sys-
tem in each duct leading to the stack;
(2) declare the Phase If unit as a sub-
stitute unit in accordance with the
requirements of the Permits Rule; or
(3) obtain the Administrator’s ap-

proval to differentiate between the
nits parametricly.
If a regulated unit and a

nonregulated unit share a common
stack, the owner or operator must
either (1) install a separate CEM sys-

ible 2. Summary of CEM Subst

Annual availability (%) of monitor
lor system

tem in each duct leading to the stack;
(2) declare the nonregulated unit as
an opt-in unit under the Opt-in Rule;
or (3) obtain the Administrator’s ap-
proval to differentiate the units
parametricly.

What Tests Are Required
for Performance
Certification?

Tr proposed rule requires the fol-
lowing performance certification
tests for CEM systems:

¢ Calibration error tests for
each pollutant concentration
monitor, diluent gas monitor,
and flow monitor capable of
daily calibration tests.

An electronic stability test for
each flow monitor not capable of
daily calibration tests.

A relative accuracy test for each
SOz pollutant concentration
monitor, flow monitor, and the
NOx CEM system. (Units with
SO2 concentrations of 250 parts
per million or less, gas velocities
of 10 feet per second or less, or
NOx emissions rates of 0.5
Ibs/mmBtu or less are not re-
quired to meet the relative ac-
curacy requirement for the SO2
monitor, the flow monitor, or the
NOx monitoring system, respec-
tively, but must meet an alterna-

ion Criteria for Estimating Values for Missing Data Periods

Number of hours missing (N)

tive requirement specified in the
rule.)

A bias test for each SOz pol-
lutant concentration monitor,
flow monitor, and the NOx
CEM systems.

Acycle response test for SO2 pol-
Jutant concentration monitors

and NOx CEM sytems.

For differential pressure flow
monitors, an orientation sen-
sitivity test, and for ultrasonic
and differential pressure flow
monitors, an interference test,
and calibration error tests
whenever possible.

For continuous opacity
monitoring systems, perfor-
mance verification tests for
calibration error, response time,
zero drift, and calibration drift.
These tests must be conducted
according to the requirements of
40 CFR Part 60, Appendix B
("Performance Specification 1—
Standards of Performance for
New Stationary Sources").

What Are the Certification

Requirements for CEMS?
nder the proposed rule, the EPA
Administrator must certify the

CEM system (CEMS) before it can be
used in the Acid Rain Program. To

Value substituted for each missing hour

Greater than or equal to 95%

IN s 24 hours

Average of the hour before missing period
land the hour recorded after missing period

N> 24 hours

90th percentile value recorded in previous
30 days of service or the before/after
value, whichever is greater

Less than 95% but greater than or equal to
90%

Ns6 hours

AY je of the hour recorded before
missing period and the howr recorded after
missing period

IN> 6 and < 24 hours

{90th percentile value recorded in previous
30 days of service or the before/after
value, whichever is greater

IN > 24 hours 90th percentile value recorded in previous
365 days of service or the before/after
value, whichever is greater.
Less than 90% IN > O hours

90th ‘percentile value recorded in previous
365

la’ ice or the before/after

— —_ —_
'SOz and fiow monitors are Individually evaluated for missing data. For NOx monitoring, the monitor system (NOx polilutant concentration

monitor and diluent gas monitor) are considered In combination. NOx and flow monitoring data Is correlated to unit gross operating load

before selecting the percentile v

3

SOz data are correlated to fuel sulfur content before selecting the percentile value.