CPFP|7001011|072213|12290|80A191P2 

# Iowa Department of Natural Resources

Air Quality Construction Permit

Permit Holder

Firm: Muscatine Power and Water

Contact: Responsible Party:

Jean Brewster Jean Brewster

Mgr. Environmental Affairs Mgr. Environmental Affairs

563-262-3259

3205 Cedar Street

Muscatine, IA 52761



# Permitted Equipment

Emission Unit(s): Unit 9 Tangentially Fired Boiler (EU90)

Maximum Heat Input: 1556 MMBtu/hr, fired by either coal or fuel oil

Control Equipment: 2 Electrostatic Precipitators (ESP) CE91, CE92, Over-fired Air (CE95)

2 Scrubbers CE93, CE94

Emission Point: EP90

Equipment Location: 1700 Dick Drake Way

Muscatine, IA 52761

Plant Number: 70-01-011

Permit No. Proj. No. Description Date Testing

80-A-191 80-243 Original DNR permit 11/21/80 Yes

80-A-191-P1 07-355 Add overfired air, PSD for CO 10/31/07 Yes

80-A-191-P2 12-290 Add PM 10 

### and PM 2.5 

### limits 07/22/13 Yes

__

Under the Direction of the Director of

the Department of Natural Resources

### Muscatine Power and Water Unit 9 Boiler (EP90) Page 2 of 10

Muscatine, Iowa 80-A-191-P2



## PERMIT CONDITIONS

The permit holder, owner and operator of the facility shall assure that the installation, operation, and maintenance of

this equipment is in compliance with all of the conditions of this permit and all other applicable requirements. This

permit and its provisions are subject to the appeal rights set forth in Iowa Administrative Code (IAC), rule 561

— 7.5.



### 1. Departmental Review

This permit is issued based on information submitted by the applicant. Any misinformation, false statements or

misrepresentations by the applicant shall cause this permit to be void. In addition, the applicant may be subject to

criminal penalties according to Iowa Code Section 455B.146A.

This permit is issued under the authority of 567 Iowa Administrative Code (IAC) 22.3. The proposed equipment has

been evaluated for conformance with Iowa Code Chapter 455B; 567 IAC Chapters 20

– 34; and 40 CFR Parts 51,

52, 60, 61, and 63 and has the potential to comply.

No review has been undertaken on the engineering aspects of the equipment or control equipment other than the

potential of that equipment for reducing air contaminant emissions. The DNR assumes no liability, directly or

indirectly, for any loss due to damage to persons or property caused by, resulting from, or arising out of the design,

installation, maintenance or operation of the proposed equipment.



### 2. Transferability

As limited by 567 IAC 22.3(3)”f”, this permit is not transferable from one location to another or from one piece of

equipment to another, unless the equipment is portable. When portable equipment for which a permit has been

issued is to be transferred from one location to another, the DNR shall be notified in writing at least fourteen (14)

days prior to transferring to the new location unless the equipment will be located in an area which is classified as

nonattainment for the National Ambient Air Quality Standards (NAAQS) or is a maintenance area for the NAAQS

in which case notification shall be given thirty (30) days prior to the relocation of equipment 1 (See Permit Condition

8.A.6). The owner will be notified at least ten (10) days prior to the scheduled relocation if the relocation will cause

a violation of the (NAAQS). In such case, a supplements permit shall be required prior to the initiation of

construction of additional control equipment or equipments modifications needed to meet the standards.

The permit is for the construction and operation of specific emission unit(s), control equipment, and emission point

as described in this permit and in the application for this permit. Any owner or operator of the specified emission

unit(s), control equipment, or emission point, including any person who becomes an owner or operator subsequent to

the date on which this permit is issued, is responsible for compliance with the provisions of this permit. No person

shall construct, install, reconstruct or alter this emissions unit, control equipment or emission point without the

required revisions to this permit.

1 A list of nonattainment areas and maintenance areas for the NAAQS can be obtained from the Department.



### 3. Construction

It is the owner's responsibility to ensure that construction conforms to the final plans and specifications as submitted,

and that adequate operation and maintenance is provided to ensure that no condition of air pollution is created.

This permit shall become void if any one of the following conditions occur:

(1) the construction or modification of the proposed project, as it affects the emission point(s) permitted herein,

is not initiated within eighteen (18) months after the permit issuance date; or

(2) the construction or modification of the proposed project, as it affects the emission point(s) permitted

herein, is not completed within thirty-six (36) months after the permit issuance date; or

(3) the construction or modification of the proposed project, as it affects the emission point(s) permitted herein,

is not completed within a time period specified elsewhere in this permit.

### Muscatine Power and Water Unit 9 Boiler (EP90) Page 3 of 10

Muscatine, Iowa 80-A-191-P2

3. Construction (Continued)

3.a. Original Permits

The owner or operator shall obtain a new permit if any changes are made to the final plans and specifications

submitted for the proposed project.



### 3.b. Modified or Supplemental Permits

This permit supersedes any and all previous permits issued for the emission point(s) or emission unit(s) permitted

herein.

However, the permittee may continue to act under the provisions of the previous permit for the emission point(s) or

emission unit(s) until one of the following conditions occurs:

(1) The proposed project authorized by this permit is completed as it affects the emission point(s) permitted

herein; or

(2) The permit becomes void.

The owner or operator shall obtain a new permit if:

(1) Any changes are made to the final plans and specifications submitted for the proposed project; or

(2) This permit becomes void.



### 4. Credible Evidence

As stated in 567 IAC 21.5 and also in 40 CFR Part 60.11(g), where applicable, any credible evidence may be used

for the purpose of establishing whether a person has violated or is in violation of any provisions specified in this

permit or any provisions of 567 IAC Chapters 20 through 34.



### 5. Owner Responsibility

Issuance of this permit shall not relieve the owner or operator of the responsibility to comply fully with applicable

provisions of the State Implementation Plan (SIP), and any other requirements of local, state, and federal law.

The owner or operator of any emission unit or control equipment shall maintain and operate the equipment and

control equipment at all times in a manner consistent with good practice for minimizing emissions, as required by

paragraph 567 IAC 24.2(1) "Maintenance and Repair”

.



### 6. Excess Emissions

Excess emissions during a period of startup, shutdown, or cleaning of control equipment are not a violation of the

emission standard if it is accomplished expeditiously and in a manner consistent with good practice for minimizing

emissions except when another regulation applicable to the unit or process provides otherwise. Cleaning of control

equipment, which does not require the shutdown of process equipment, shall be limited to one six-minute period per

one-hour period. An incident of excess emissions other than the above is a violation and may be subject to criminal

penalties according to Iowa Code 455B.146A. If excess emissions are occurring, either the control equipment

causing the excess shall be repaired in an expeditious manner, or the process generating the emissions shall be

shutdown within a reasonable period of time, as specified in 567 IAC 24.1.

An incident of excess emissions shall be orally reported to the appropriate DNR field office within eight (8) hours

of, or at the start of, the first working day following the onset of the incident (See section 8.B.1). A written report of

an incident of excess emissions shall be submitted as a follow-up to all required oral reports within seven (7) days of

the onset of the upset condition.



### 7. Disposal of Contaminants

The disposal of materials collected by the control equipment shall meet all applicable rules.

### Muscatine Power and Water Unit 9 Boiler (EP90) Page 4 of 10

Muscatine, Iowa 80-A-191-P2

8. Notification, Reporting, and Recordkeeping

A. The owner shall furnish the DNR the following written notifications:

1. The date construction, installation, or alteration is initiated postmarked within thirty (30) days

following initiation of construction, installation, or alteration;

2. The actual date of startup, postmarked within fifteen (15) days following the start of operation;

3. The date of each compliance test required by Permit Condition 12, at least thirty (30) days before the

anticipated compliance test date;

4. The date of each pretest meeting, at least fifteen (15) days before the proposed meeting date. The

owner shall request a proposed test plan protocol questionnaire at least sixty (60) days prior to each

compliance test date. The completed questionnaire shall be received by the DNR at least fifteen (15)

days before the pretest meeting date;

5. Transfer of equipment ownership, within 30 days of the occurrence;

6. Portable equipment relocation:

a. at least thirty (30)days before equipment relocation if the equipment will be located in a

nonattainment area for the National Ambient Air Quality Standards (NAAQS) or a

maintenance area for the NAAQS;

b. at least fourteen (14) days before equipment relocation.

B. The owner shall furnish the DNR with the following reports:

1. Excess emissions reports, in accordance with 567 IAC 24.1;

2. A written compliance demonstration report for each compliance testing event, whether successful or

not, postmarked not later than six (6) weeks after the completion of the test period unless other

regulations provide for other notification requirements. In that case, the more stringent reporting

requirement shall be met;

3. Operation of this emission unit(s) or control equipment outside of those limits specified in Permit

Conditions 10 and 14 and according to the schedule set forth in 567 IAC 24.1.

C. The owner shall send correspondence regarding this permit to the following address:

Construction Permit Supervisor

Air Quality Bureau

Iowa Department of Natural Resources

7900 Hickman Road, Suite 1

Windsor Heights, IA 50324

Telephone: (515) 281-8189

Fax: (515) 242-5094

D. The owner shall send correspondence concerning stack testing to:

Stack Testing Coordinator

Air Quality Bureau

Iowa Department of Natural Resources

7900 Hickman Road, Suite 1

Windsor Heights, IA 50324

Telephone: (515) 281-4899

Fax: (515) 242-5098

E. The owner shall send reports and notifications to:

Compliance Unit Supervisor

Air Quality Bureau

Iowa Department of Natural Resources

7900 Hickman Road, Suite 1

Windsor Heights, IA 50324

Telephone: (515) 281-8448

Fax: (515) 242-5127 DNR Field Office 6

1023 West Madison

Washington, IA 52353

Telephone: (319) 653-2135

Fax: (319) 653-2856

### Muscatine Power and Water Unit 9 Boiler (EP90) Page 5 of 10

Muscatine, Iowa 80-A-191-P2

8. Notification, Reporting, and Recordkeeping (Continued)

F. All data, records, reports, documentation, construction plans, and calculations required under this permit

shall be available at the plant during normal business hours for inspection and copying by federal, state, or

local air pollution regulatory agencies and their authorized representatives, for a minimum of two (2) years

from the date of recording.



### 9. Permit Violations

Knowingly committing a violation of this permit may carry a criminal penalty of up to $10,000 per day fine and 2

years in jail according to Iowa Code Section 455B.146A.



### 10a. BACT Emission Limits

Pollutant lb/day tons/yr Additional

Limits Reference

(567 IAC)

Particulate Matter (PM) NA NA 0.03 lb/MMBtu (1) LAER

Nitrogen Oxides (NO X ) NA NA 0.60 lb/MMBtu (7) BACT

Sulfur Dioxide (SO 2 ) 0.56 lb/MMBtu (5) NA 0.45 lb/MMBtu (4)

92% reduction (6) LAER

Carbon Monoxide (CO) NA 720 (2) 100 ppm (3) BACT

1 Standard is expressed as the average of three (3) runs. Reference EPA permit 80-E-001 of January 24, 1980

2 Standard is a 12-month rolling total, and includes startup, shutdown, and malfunctions. To allow for a shakedown period

for the combustion optimization system, this standard becomes effective 90 boiler operating days after installation of the

overfire air, or July 21, 2008, whichever comes first.

3 Standard is averaged over a calendar day, and does not include startup, shutdown and malfunction. To allow for a

shakedown period for the combustion optimization system, this standard becomes effective 90 boiler operating days after

installation of the overfire air, or July 21, 2008, whichever comes first.

4 From IDNR 12/14/82 “Revised Agreement Establishing Lowest Achievable Air Contaminant Emission Rate and Offsets

for Sulfur Dioxide (SO2)”. Standard is a 30-day rolling average

5 From IDNR 12/14/82 “Revised Agreement Establishing Lowest Achievable Air Contaminant Emission Rate and Offsets

for Sulfur Dioxide (SO2)”. Standard is a maximum daily average.

6 From IDNR 12/14/82 “Revised Agreement Establishing Lowest Achievable Air Contaminant Emission Rate and Offsets

for Sulfur Dioxide (SO2)”. Standard is a 30-day rolling average for the flue gas desulfurization system.

7 For bituminous coal. BACT NOx limits are the NOx emissions specified in NSPS Subpart Da, so limit for subbituminous

coal is 0.50 lb/MMBtu, limit for oil is 0.30 lb/MMBtu, limit for gas is 0.20 lb/MMBtu, and for other fuel types, or if two or

more fuels are combusted simultaneously, the NOx BACT limit shall be the limit specified in 40 CFR 60.44a(a) and/or as

determined by the proration procedures specified in 40 CFR 60.44a(c). Reference EPA permit 80-E-001 of January 24,

1980. Standard is a 30-day rolling average.

### Muscatine Power and Water Unit 9 Boiler (EP90) Page 6 of 10

Muscatine, Iowa 80-A-191-P2



### 10b. Other Emission Limits

Pollutant lb/hr 1 tons/yr 2 Additional Limits Reference

(567 IAC)

Federal Particulate Matter (PM) NA NA 0.03 lb/MMBTU 1, 11 40 CFR 60.42 Da(a)

PM 10 46.68 3 NA NA NAAQS

PM 2.5 43.59 4 NA NA NAAQS

Opacity NA NA 20% 5 40 CFR 60.42 Da(b)

Sulfur Dioxide (SO 2 ) NA NA 70% reduction 6 40 CFR 60.42 Da(a)

Nitrogen Oxides (NO X ) NA NA 0.60 lb/MMBTU 7

65% reduction 8

0.235 lb/MMTU 9 40 CFR 60.42 Da(a)

Volatile Organic Compounds NA NA NA NA

Carbon Monoxide (CO) 329.2 10 NA NA NA

Lead (Pb) NA NA NA NA

(Single HAP) NA NA NA NA

(Total HAP) NA NA NA NA

1 Standard is expressed as the average of three (3) runs.

2 Standard is a 12-month rolling total.

3 The limit for PM 10 emissions is established for air dispersion modeling.

4 The limit for PM 2.5 emissions is established to address the “Finding of Substantial Inadequacy of Implementation Plan;

Call for Iowa SIP Revision” for PM 2.5 published in the Federal Register (76 FR 9706) on February 22, 2011.

5 Except for one 6-minute period per hour of not greater than 27% opacity. Standard is a 6-minute average.

6 When combusting solid or solid-derived fuels, 30% of the potential combustion concentration (70% reduction). When

combusting liquid or gaseous fuels, 0.8 lb/MMBtu and 10% of the potential combustion concentration, or 100% of the

potential combustion concentration (zero percent reduction) when emissions are less than 0.20 lb/MMBtu. If different

fuels are combusted simultaneously, the applicable standard is determined by proration using the formula set forth in 40

CFR 60.43Da(h)(2). Standard is a 30-day rolling average. (40 CFR 60.43Da(g)). After the initial performance test,

compliance with the SO2 emission limitations and percentage reduction requirements under 60.43Da is based on the

average emission rate for 30 successive boiler operating days. A separate performance tests is completed at the end of each

boiler operating day after the initial performance test, and a new 30 day average emission rate for SO2 and a new percent

reduction for SO2 are calculated to show compliance with the standards (40 CFR 60.48Da(e))

. Compliance shall be

demonstrated by following the procedures in 40 CFR 60.48Da(g) and (h)).

7 For bituminous coal. Limit for subbituminous coal is 0.50 lb/MMBtu, limit for oil is 0.30 lb/MMBtu, limit for gas is 0.20

lb/MMBtu, and for other fuel types, or if two or more fuels are combusted simultaneously, the NOx BACT limit shall be

the limit specified in 40 CFR 60.44Da(a) and/or as determined by the proration procedures specified in 40 CFR 60.44a(c).

Standard is a 30-day rolling average. This standard applies at all times except during periods of startup, shutdown or

malfunction (40 CFR 60.48Da(c)). After the initial performance test, compliance with the NOx emission limitations under

60.44Da is based on the average emission rate for 30 successive boiler operating days. A separate performance tests is

completed at the end of each boiler operating day after the initial performance test, and a new 30 day average emission rate

for NOx are calculated to show compliance with the standards (40 CFR 60.48Da(e))

. Compliance shall be demonstrated

by following the procedures in 40 CFR 60.48Da(g) and (h).

8 For solid fuels. For liquid fuels, standard is a 30% reduction of potential combustion concentration. Compliance with the

lb/MMBtu standard constitutes compliance with the percent reduction requirements (40 CFR 60.48a(b)).

9 As requested to remain an insignificant increase for PSD and to meet Acid Rain requirements in 40 CFR 76.6. Standard is

a twelve month rolling average, and includes startup, shutdown and malfunctions. To allow for a shakedown period for the

combustion optimization system, this standard becomes effective 90 boiler operating days after installation of the overfire

air, or July 21, 2008, whichever comes first.

10 Limit used for modeling an insignificant impact for NAAQS and increment in project 07-355.

11 Standard also requires 1% potential combustion concentration (99% reduction) when combusting solid fuel, and 30%

potential combustion concentration (70% reduction) when combusting liquid fuel (40 CFR 60.42Da(a)). Compliance with

the 0.03 lb/MMBtu standard constitutes compliance with the percent reduction requirements (40 CFR 60.48Da(a)). This

standard applies at all times except during periods of startup, shutdown or malfunction (40 CFR 60.48Da(c)).

### Muscatine Power and Water Unit 9 Boiler (EP90) Page 7 of 10

Muscatine, Iowa 80-A-191-P2

11. Emission Point Characteristics

This emission point shall conform to the specifications listed below:

Parameter Value

Stack Height, (ft, from the ground) 300 Feet

Discharge Style Vertical, unobstructed

Stack Opening, (inches, dia.) 126 inches

Exhaust Temperature (  F) 180°F

Exhaust Flowrate (scfm) 430,625 scfm

The temperature and flow rate are intended to be representative and characteristic of the design of the permitted

emission point. The Department recognizes that the temperature and flow rate may vary with changes in the process

and ambient conditions. If it is determined that any of the emission point design characteristics are different than the

values stated above, the owner/operator must notify the Department and obtain a permit amendment, if required.



### 12. Compliance Demonstration(s) and Performance Testing

Pollutant Initial Subsequent Methodology Frequency

PM (federal) No No NA NA

PM (state) No No NA NA

PM 10 No No NA NA

PM 2.5 Yes 1 No Test NA

Opacity Yes 2 Yes COMS Continuous

SO 2 Yes 3 Yes CEMS Continuous

NO X Yes 3 Yes CEMS Continuous

VOC No No NA NA

CO Yes 4 Yes CEMS Continuous

Pb No No NA NA

HAP No No NA NA

1 Stack test for PM 2.5 is required if the results of any PM test (as a 3 run average) ever exceeds 43.59 pounds per hour. The test

stack for PM2.5 shall be conducted within ninety (90) days after the report is received by the Iowa DNR showing the final results

of the PM test.

2 Initial compliance testing completed July 1997. Further initial testing not required at this time.

3 Initial compliance testing completed August 26, 1994. Further initial testing not required at this time.

4 Initial compliance testing required by project 07-355 has been completed.

If subsequent testing is specified above

, the owner shall verify compliance with the emission limitations contained

in Permit Condition 10 according to the frequency noted above.

If testing is required, the owner shall use the test method and run time listed in the table below unless another testing

methodology is approved by the Department prior to testing.

Pollutant Test Run Time Test Method

PM (federal) 1 hour 40 CFR 60, Appendix A, Method 5

PM (state) 1 hour 40 CFR 60, Appendix A, Method 5

40 CFR 51 Appendix M, Method 202

PM 10 1 hour 40 CFR 51, Appendix M, 201A with 202

PM 2.5 1 hour 40 CFR 51, Appendix M, 201A with 202

Opacity 1 hour 40 CFR 60, Appendix A, Method 9

SO 2 1 hour 40 CFR 60, Appendix A, Method 6C

NO X 1 hour 40 CFR 60, Appendix A, Method 7E

VOC 1 hour 40 CFR 60, Appendix A, Method 25A

CO 1 hour 40 CFR 60, Appendix A, Method 10

Pb 1 hour 40 CFR 60, Appendix A, Method 12

Other

### Muscatine Power and Water Unit 9 Boiler (EP90) Page 8 of 10

Muscatine, Iowa 80-A-191-P2

The unit(s) being sampled should be operated in a normal manner at its maximum continuous output as rated by the

equipment manufacturer, or the rate specified by the owner as the maximum production rate at which this unit(s)

will be operated. In cases where compliance is to be demonstrated at less than the maximum continuous output as

rated by the manufacturer, and it is the owner's intent to limit the capacity to that rating, the owner may submit

evidence to the Department that this unit(s) has been physically altered so that capacity cannot be exceeded, or the

Department may require additional testing, continuous monitoring, reports of operating levels, or any other

information deemed necessary by the Department to determine whether this unit(s) is in compliance.

Each emissions compliance test must be approved by the Department. Unless otherwise specified by the

Department, each test shall consist of three (3) separate runs. The arithmetic mean of three (3) acceptable test runs

shall apply for compliance, unless otherwise indicated by the Department.

A pretest meeting shall be held at a mutually agreeable site no less than fifteen (15) days prior to the date of each

test. Representatives from the Department shall attend this meeting, along with the owner and the testing firm, if

any. It shall be the responsibility of the owner to coordinate and schedule the pretest meeting. The owner shall be

responsible for the installation and maintenance of test ports. The Department shall reserve the right to impose

additional, different, or more detailed testing requirements.



### 13. NSPS and NESHAP Applicability

A. This unit is subject to the NSPS standard Subpart Da, Standards of Performance for Electric Utility Steam

Generating Unit for which Construction is Commenced After September 18, 1978

.

B. For information only: This equipment is of the source category affected by the following federal regulation:

National Emission Standards for Hazardous Air Pollutants: Coal- and Oil-Fired Electric Utility Steam

Generating Units (MATS)[40 CFR Part 63, Subpart UUUUU].

C. This unit is considered an affected source under 40 CFR 72, 73, 75, 76, 77 and 78 definitions.

Therefore, this emission unit is subject to the applicable provisions of the Acid Rain Program.



### 14. Operating Limits

Operating limits for these emission units shall be:

A. The owner or operator shall, to the extent practicable, maintain and operate the unit in a manner consistent

with good air pollution control practice for minimizing emissions at all times, including periods of startup,

shutdown and malfunction.



### B. The unit shall only combust coal and/or fuel oil in this unit.



### 15. Operating Condition Monitoring

All records as required by this permit shall be kept on-site for a minimum of two (2) years and shall be available for

inspection by the DNR. Records shall be legible and maintained in an orderly manner. These records shall show

the following:

A. The owner or operator shall monitor emissions from this unit and calculate the annual emissions, in

tons per year on a calendar-year basis, for a period of five years following resumption of regular

operations after the change made in this project (07-355). This information shall be retained by the

owner or operator for a period of ten years after the project (07-355) is completed (IAC 567

33.3(18)”f”(4)).

### Muscatine Power and Water Unit 9 Boiler (EP90) Page 9 of 10

Muscatine, Iowa 80-A-191-P2

B. The owner or operator shall submit a report to the department within 60 days after the end of each year

during which records must be generated under 567-IAC 33.3(18)”f” (4) setting out the unit’s annual

emissions during the calendar year that preceded submission of the report. This shall be for a period

of five years following resumption of regular operations (project 07-355). The owner or operator shall

notify the DNR if the combined total annual emissions of Boiler 8 and Boiler 9, in tons per year,

exceed any of the following:

1. Particulate Matter (PM)

– 327.12 tpy

2. Particulate Matter less than 10 microns (PM10)

– 317.12 tpy

3. Sulfur Dioxide (SO2)

– 3,633.45 tpy

4. Nitrogen Oxides (NOx)

– 4,620.17 tpy

5. Volatile Organic Compounds (VOC)

– 80.46 tpy

C. The owner or operator shall make the information required to be documented and maintained pursuant

to IAC 567-33.3(18)”f” available for review upon request for inspection by the Department or the

general public pursuant to the requirements for Title V operating permits contained in 567-22.107(6).

D. The owner or operator shall maintain a file of computations to show the total hourly emission level for

SO2. The owner shall submit quarterly excess emission reports as specified in IAC 567-25.1(6).



### 16. Continuous Emission Monitoring

General Requirements

–

The owner or operator shall operate, maintain, and quality assure a continuous emission monitoring system (CEMS)

for measuring emissions in the respective units (ppm, lb/hr, etc) as required in Condition 10a or 10b. The CEMS

shall consist of continuous emission monitors, exhaust flow equipment, and data acquisition and handling systems

(DAHS) meeting the design and performance specifications found in 40 CFR Part 75. The CEMS shall be operated

during any period that any fuel is combusted in the boilers.

In conformance with the Acid Rain Program, the owner or operator shall perform all quality assurance activities at

the frequencies described in 40 CFR Part 75, Appendix B. Any calibration gases used to conduct quality assurance

activities shall meet the traceability protocol requirements of 40 CFR 75, Appendix H. The operational

specifications, ongoing system calibration/quality assurance, and recordkeeping for the CEMS shall be done in

accordance with 40 CFR Part 75.

The owner or operator shall also follow all applicable continuous emission monitoring requirements of 40 CFR Part

60, Subpart Da. 40 CFR 60, Appendix F (Quality Assurance Procedures) requirements shall apply where

applicable, and be supplemented with a notice to the Department with the dates of the annual relative accuracy test

audit.

Opacity Requirements

–

The owner or operator shall install, calibrate, maintain and operate a COMS for measuring opacity, and record the

output of the system, as required in 40 CFR 60.49Da(a). The system shall be designed to meet the requirements of

40 CFR Part 60, Appendix B, Performance Specification 1 (PS1). The operational specifications, ongoing system

calibration/quality assurance, and reporting and recordkeeping for the COMS shall be done in accordance with 40

CFR Part 60.

Sulfur Dioxide Requirements

-

The owner or operator shall install, calibrate, maintain and operate a CEMS for measuring sulfur dioxide (SO 2 ), and

record the output of the system, as required in 40 CFR 60.49Da(b). The system shall be designed to meet the

requirements of 40 CFR Part 60, Appendix B, Performance Specification 2 (PS2) and Performance Specification 6

(PS6).

The owner or operator shall periodically review the aggregate hourly emissions average and aggregate annual

emissions data produced by the CEMS. If the review indicates that either may exceed the emission limitations

found in Condition 10, the owner or operator shall take steps to mitigate SO 2 emissions to, at, or below the

applicable limitation.

### Muscatine Power and Water Unit 9 Boiler (EP90) Page 10 of 10

Muscatine, Iowa 80-A-191-P2

The owner or operator shall maintain an on-site record of CEMS-related data for not less than two years from the

origination. The record shall contain all hourly SO 2 and flow rate measurements, any missing data substitution,

subsequent aggregate and averaging calculation, results of quality assurance and averaging calculations, results of

quality assurance activities, and all performance test results. These records shall be made readily available for

inspection by the IDNR, EPA, or any authorized agent of these agencies.

Nitrogen Oxide Requirements

-

The owner or operator shall install, calibrate, maintain, and operate a CEMS for measuring nitrogen oxide (NOx),

and record the output of the system, as required in 40 CFR 60.49Da(c). The system shall be designed to meet the

requirements of 40 CFR Part 60, Appendix B, Performance Specification 2 (PS2) and Performance Specification 6

(PS6).

Carbon Monoxide Requirements

-

The owner or operator shall install, calibrate, maintain, and operate a CEMS for measuring carbon monoxide (CO),

and record the output of the system. The system shall be designed to meet the requirements of 40 CFR Part 60,

Appendix B, Performance Specification 4A (PS4A) and Performance Specification 6 (PS6). The specifications of

40 CFR Part 75, Appendix F (Quality Assurance/Quality Control) shall apply.

The owner or operator shall account for any missing CO data periods using a procedure similar to that outlined in 40

CFR Part 75, Subpart D for SO 2

. Missing data shall be evaluated separately for each component of a CEMS and

include any period of time during boiler operation for which a CEMS component has not operated or otherwise is

not able to provide quality assured data.

40 CFR Part 75, Appendix B, defines the procedures for determining whether data are valid or out of control.



### 17. Description of Terms and Acronyms

acfm Actual cubic feet per minute

Applicant The owner, company official or authorized agent

CFR Code of Federal Regulations

Department Iowa Department of Natural Resources

DNR Iowa Department of Natural Resources

gr/dscf Grains per dry standard cubic foot

HAP Hazardous Air Pollutant(s)

IAC Iowa Administrative Code

MMBtu One million British thermal units

NA Not Applicable

NAAQS National Ambient Air Quality Standards

NO X Nitrogen Oxides

Owner The owner or authorized representative

Permit This document including permit conditions and all submitted application materials

PM 10 Particulate Matter equal to or less than 10 microns in aerodynamic diameter

scfm Standard cubic feet per minute

SIP State Implementation Plan

SO 2 Sulfur Dioxide

VOC Volatile Organic Compound



## END OF PERMIT CONDITIONS