NORTH DAKOTA 

DEPARTMENT of HEALTH 

ENVIRONMENTAL HEALTH SECTION 

Gold Seal Center, 918 E. Divide Ave. 

Bismarck, ND 58501-1947 

701.328.5200 (fax) 

www.ndhealth.gov 

AIR POLLUTION CONTROL 

TITLE V PERMIT TO OPERATE 

Permittee: 

Name: 

Great River Energy 

Address: 

2875 Third Street SW 

Underwood, ND 58576-9596 

Source Location: 

Sec. 8, 9, 16, 17, T146N, R82W 

McLean County, North Dakota 

Expiration Date: 

Permit Number: 

T5-F82006 

Source Name: 

Coal Creek Station 

Source Type: 

Electric Generating Unit, Coal 

September 7, 2019 

Pursuant to Chapter 23-25 of the North Dakota Century Code, and the Air Pollution Control Rules of the State 

of North Dakota, Article 33-15 of the North Dakota Administrative Code (NDAC), and in reliance on 

statements and representations heretofore made by the permittee designated above, a Title V Permit to Operate 

is hereby issued authorizing such permittee to operate the emissions unit(s) at the location designated above. 

This Title V Permit to Operate is subject to all applicable rules and orders now or hereafter in effect of the 

North Dakota Department of Health and to any conditions specified on the following pages. All conditions are 

enforceable by EPA and citizens under the Clean Air Act unless otherwise noted. 

Renewal No.3 (Minor Mod.): 10/21114 

Revision No. 1 (Admin.): 1130/15 

Environmental Health 

Section Chief's Office 

701.328.5150 

Division of 

Air Quality 

701.328.5188 

c;J~ Terry L. 0' lmr, P.E. 

Director 

Division of Air Quality 

Division of 

Municipal Facilities 

701.328.5211 

Printed on recycled paper. · 

Division of 

Waste Management 

701.328.5166 

Division of 

Water Quality 

701.328.5210 
1. 

2. 

3. 

4. 

5. 

6. 

7. 

8. 

9. 

10. 

11. 

12. 

13. 

Emission Unit(s) Identification 

Coal Creek Station 

Title V Permit to Operate 

Table of Contents 

Continuous Emission Monitoring (CEM) Identification 

Restrictions 

Standards 

Emission Unit(s) Limits 

Opacity Limits 

Monitoring Requirements and Conditions 

Recordkeeping Requirements 

Reporting 

Facility Wide Operating Conditions 

General Conditions 

State Enforceable Only Conditions (not Federally 

enforceable) 

Phase II Acid Rain Provisions 

Attachment A - Compliance Assurance 

Monitoring (CAM) Plan (EU 1 and 2) 

Page _l_ of 45 

Permit No. T5-F82006 

Page No. 

3 

5 

5 

6 

8 

14 

15 

22 

27 

28 

35 

41 

42 
1. Emission Unit(s) Identification: 

The emission units regulated by this permit are as follows: 

A. Point Sources: 

Emission 

Emission Unit Description Unit (EU) 

Lignite-fired boiler (6,015 x 106 Btulhr heat 1 

input) (Unit 1) 

Lignite-fired boiler (6,022 x 106 Btulhr heat 2 

input) (Unit 2) 

Auxiliary Boiler No. 91 fired on liquid fuels 3 

(172 x 106 Btulhr heat input) 

Auxiliary Boiler No. 92 fired on liquid fuels 4 

(172 x 106 Btulhr heat input) 

Diesel fuel oil-fired emergency generator 5 

engine (nominal 3,500 hp built pre-2006) 

Diesel fuel oil-fired emergency fire pump 6 

engine (nominal 399 bhpbuilt in 2009) 

Lignite transfer house 7 

Lignite emergency reclaim system 8 

Lignite yard storage silos 9 

Lignite yard storage silos 10 

Crusher building (two crushers each at 1,500 11 

tph) 

Generation building coal hopper 12 

Base ofFalkirk Mining Company mine silo 13 

Generation building coal hopper 14 

Generation building coal hopper 15 

Generation building coal hopper 16 

Generation building coal hopper 17 

Fly ash silo (truck air slide) 20 

Fly ash silo (truck air slide) 21 

Fly ash railroad marketing silo 25 

Fly ash dome 26 

Coal dryer 26 27 

CD26 coal crusher 27a 

Coal dryer crusher building 28 

Coal dryer transfer tower 29 

Auxiliary boiler area 30 

Emission 

Point (EP) 

1 

2 

3 

3 

5 

6 

7 

8 

9 

10 

11 

12 

13 

14 

15 

16 

17 

20a, 20b, & 

20c 

21a, 21b, & 

21c 

25a& 25b 

26a, 26b, 

26c,26d 

27 

36 

37 

38 

Page _1_ of 46 

Permit No. T5-F82006 

Air Pollution 

Control 

E_quipment 

ESP and Wet Scrubber 

ESP and Wet Scrubber 

None 

None 

None 

None 

Bag filter 

Bagfilter 

Bagfilter 

Bagfilter 

Bagfilter 

Bag filter 

Bagfilter 

Bagfilter 

Bagfilter 

Bag filter 

Bagfilter 

Bagfilters 

Bagfilters 

Bagfilters 

Bagfilters 

Bagfilter 

Bagfilter 

Bagfilter 

Bagfilter 
Emission 

Emission Unit Description Unit {EU) 

Coal dryer 11 and associated equipment with a 31 

maximum rated capacity of approximately 138 

tons of coal per hour 

Coal dryer 12 and associated equipment with a 32 

maximum rated capacity of approximately 138 

tons of coal per hour 

Coal dryer 13 and associated equipment with a 33 

maximum rated capacity of approximately 138 

tons of coal:Q_er hour 

Coal dryer 14 and associated equipment with a 34 

maximum rated capacity of approximately 138 

tons of coal per hour 

Coal dryer 21 and associated equipment with a 35 

maximum rated capacity of approximately 13 8 

tons of coal per hour 

Coal dryer 22 and associated equipment with a 36 

maximum rated capacity of approximately 138 

tons of coal per hour 

Coal dryer 23 and associated equipment with a 37 

maximum rated capacity of approximately 138 

tons of coal per hour 

Coal dryer 24 and associated equipment with a 38 

maximum rated capacity of approximately 138 

tons of coal per hour 

Air jig 21 39a 

Air jig 22 39b 

Lignite rail loading silo 40 

Lignite dust collector 98 41 

Lignite rail loading surge hopper 91 42 

Lignite dust collector 99 43 

Fluidized bed pilot dryer 45 

B. Fugitive Emissions Sources: 

1) Cooling towers No. 91, No. 92, and No. 93 

2) Boombelt conveyor (stackout) 

3) Conveyor 909 (stackout) 

4) Scrubber building flyash silo (stackout) 

5) Coal pile maintenance 

6) Coal handling 

Emission 

Point {EP) 

39 

40 

41 

42 

43 

44 

45 

46 

47 

49 

Page _1_ of 46 

Permit No. T5-F82006 

Air Pollution 

Control 

Equipment 

Bagfilter 

Bagfilter 

Bag filter 

Bagfilter 

Bagfilter 

Bagfilter 

Bagfilter 

Bagfilter 

Bagfilter 

Bagfilter 
Page 2._ of 46 

Permit No. T5-F82006 

2. Continuous Emission Monitoring (CEM) Identification: 

Emissions from EU 1 and EU 2 (Units 1 & 2 main stacks) are each measured by the following monitors: 

Pollutant 

Monitored Manufacturer Model 

Opacity Durag D-R290 

so2 Thermo/Electron 43i-ANSCA 

NOx Thermo/Electron 42i-ANMSDCA 

C02 Thermo/Electron 41 Oi-ANPDCA 

Flow Sick-Maihak FLOWSIC 100 

Note: CEMS for PM, HCl and Hg may be added. 

3. Restrictions: 

A. Fuel: 

1) EU 1 and EU 2 shall be operated using lignite coal as the primary fuel. During startup, 

distillate fuel oils, used oil or any combination of these fuels may be utilized. During 

unstable firing conditions or ignition support for placing coal elevations in and out of 

service, distillate fuel oils, used oil or any combination of these fuels may be utilized. 

2) EU 3 and EU 4 shall be operated using only ultra low sulfur diesel fuel (.:::;15 ppm sulfur), 

used oil (see Condition 12.C), or any combination of these fuels. 

3) EU 5 and EU 6 shall be operated using only ultra low sulfur diesel fuel (.:::;15 ppm sulfur). 

4) Used oil and hazardous waste may be burned in EU 1 and EU 2 as outlined in Conditions 

12.B, 12.C, and 12.D. 

Fuels other than those listed above may be burned if approved in advance by the 

Department and compliance with the applicable emission limits is maintained. 

Applicable Requirement: Permit to Construct 

B. Stack Heights: Emissions shall be vented from the following minimum stack heights. 
Minimum Stack 

Emission Point Height {feet) 

36 140 

37 154 

38 230 

39 300 

40 300 

41 300 

42 300 

43 230 

46 110 

47 131 

48 110 

Applicable Requirements: PTC070 14 and PTC070 16 

Applicable 

Requirement 

PTC07016 

PTC07014 

PTC07016 

Page _Q_ of 46 

Permit No. T5-F82006 

C. Auxiliary Boilers Annual Capacity Factor: Beginning on the compliance date ofNDAC 33-15-

22 (40 CFR 63), Subpart DDDDD for existing boilers (January 31, 2016 or as amended), EU 3 

and EU 4 auxiliary boilers shall be limited to an average annual capacity factor of no more than 

10 percent to maintain status as limited use boilers as defined in 40 CFR 63.7575. Subpart 

DDDDD requirements wherever stated in this permit become effective on the above compliance 

date. 

Applicable Requirements: NDAC 33-15-22-03, Subpart DDDDD and NDAC 33-15-14-6.5.b(l) 

4. Standards: The permittee shall comply with all applicable requirements of the following subparts. 

A. NDAC 33-15-12-02, Subpart D - Standards of Performance for Fossil-Fuel-Fired Steam 

Generators for Which Construction Is Commenced After August 17, 1971 (for EU 1 and EU 2). 

Applicable Requirement: NDAC 33-15-12-02, Subpart D 

B. NDAC 33-15-12-02, Subpart Y- Standards of Performance for Coal Preparation and Processing 

Plants (for EU 7 through EU17, EU 28 through EU 30, and EU 39 through EU 45). 

Applicable Requirement: NDAC 33-15-12-02, Subpart Y 

C. 40 CFR 60, Subpart IIII: For the emergency fire pump engine (EU 6), the permittee shall 

comply with all applicable requirements of 40 CFR 60, Subpart IIII - Standards of Performance 

for Stationary Compression Ignition Internal Combustion Engines as incorporated into NDAC 

33-15-12-02, Subpart IIII. 

Note: For engines to be considered emergency stationary RICE under 40 CFR 60, Subpart IIII, 

operations must comply with the applicable hours limits (50 and 100 hours per year) specified in 

40 CFR 60.4211(£). 
Applicable Requirement: NDAC 33-15-12-02, Subpart IIII 

Page .1_ of 46 

Permit No. T5-F82006 

D. 40 CFR 63, Subpart ZZZZ: For the emergency generator and fire pump engines (EU 5 and EU 

6), the permittee shall comply with all applicable requirements of 40 CFR 63, Subpart ZZZZ -

National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal 

Combustion Engines as incorporated into NDAC 33-15-22-03, Subpart ZZZZ. For EU 6 

Subpart ZZZZ requirements include compliance with NDAC 33-15-12-02, Subpart IIII. 

Note: For engines to be considered emergency stationary RICE under 40 CFR 63, Subpart 

ZZZZ, operations must comply with the applicable hours limits (50 and 100 hours per year) 

specified in 40 CFR 63.6640(£). 

Applicable Requirement: NDAC 33-15-22-03, Subpart ZZZZ 

E. Like-Kind Engine Replacement: This permit allows the permittee to replace the existing 

engine(s) with a like-kind engine. Replacement is subject to the following conditions. 

1) The Department must be notified within 10 days after change-out of the engine. 

2) The replacement engine shall operate in the same manner, provide no mcrease m 

throughput and have equal or less emissions than the engine it is replacing. 

3) The date of manufacture of the replacement engine must be included in the notification. 

The facility must comply with any applicable federal standards (e.g. NSPS, NESHAP, 

MACT) triggered by the replacement. 

4) The replacement engine is subject to the same state emission limits as the existing engine 

in addition to any NSPS or MACT emission limit that is applicable. 

Applicable Requirement: NDAC 33-15-14-03.6 

F. 40 CFR 63, Subpart DDDDD: For the auxiliary boilers (EUs 3 and 4), the permittee shall 

comply with all applicable requirements of 40 CFR 63, Subpart DDDDD - National Emission 

Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial, and 

Institutional Boilers and Process Heaters as incorporated into NDAC 33-15-22-03, Subpart 

DDDDD. 

Note: The Subpart DDDDD compliance date for existing boilers is January 31, 2016 or as 

amended by rule. 

Applicable Requirement: NDAC 33-15-22-03, Subpart DDDDD 

G. 40 CFR 63, Subpart UUUUU: For the lignite-fired boilers (EUs 1 and 2), the permittee shall 

comply with all applicable requirements of 40 CFR 63, Subpart UUUUU- National Emission 

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

Units as incorporated into NDAC 33-15-22-03, Subpart UUUUU. 
Page~ of 46 

Permit No. T5-F82006 

Note: The Subpart UUUUU compliance date for existing boilers is April 16, 2015 or as 

amended by rule. 

Applicable Requirement: NDAC 33-15-22-03, Subpart UUUUU 

5. Emission Unit(s) Limits: 

NDAC 

Emission Unit Pollutant/ Emission Applicable 

Description EU EP Parameter Limit* Requirement 

Lignite-fired boiler 1 1 PM 0.10 lb/10(J Btu** & 33-15-12, Subpart D 

(Unit 1) 528lb/hr & PTC Condition 

(3-hr rolling avg.) 

PM 0.03 lb/1 06 Btu 33-15-22-03, 

(effective 4/6/15 or as or Subpart UUUUU 

amended by rule) 0.3lb/MWh 

so2 1.2lb/106 Btu** 33-15-12, Subpart D 

& 6,336 lb/hr & PTC Condition 

(3-hr rolling avg.) 

NOx 5,104lb/hr PTC Condition 

(12-month rolling 

avg.) 

HCl 0.002 lb/1 06 Btu 33-15-22-03, 

(effective 4/16/15 or or Subpart UUUUU 

as amended by rule) 0.02lb/MWh 

or 

S02 Surrogate: 

0.2 lb/1 06 Btu 

or 

1.5lb/MWh 

Hg 4.0 lb/1012 Btu 33-15-22-03, 

(effective 4/16/15 or or Subpart UUUUU 

as amended by rule) 0.04lb/GWh 

Opacity See Condition (Cond.) 33-15-03-02 & 33-

6.B 15-12, Subpart D 
Emission Unit Pollutant/ 

Description EU EP Parameter 

Lignite-fired boiler 2 2 PM 

(Unit 2) 

PM 

(effective 4/16/15 or 

as amended by rule) 

so2 

NOx 

HC1 

(effective 4/16/15 or 

as amended by rule) 

Hg 

(effective 4/16115 or 

as amended by rule) 

Opacity 

Page _2_ of 46 

Permit No. T5-F82006 

NDAC 

Emission Applicable 

Limit* Requirement 

0.10 lb/10° Btu** & 33-15-12, Subpart D 

528lb/hr & PTC Condition 

(3-hr rolling avg.) 

0.03 lb/1 06 Btu 33-15-22-03, 

or Subpart UUUUU 

0.3lb/MWh 

1.2lb/106 Btu** 33-15-12, Subpart D 

& 6,336 lb/hr & PTC Condition 

(3-hr rolling avg.) 

5,104lb/hr PTC Condition 

(12-month rolling 

avg.) 

0.002 lb/1 06 Btu 33-15-22-03, 

or Subpart UUUUU 

0.02lb/MWh 

or 

S02 Surrogate: 

0.2 lb/1 06 Btu 

or 

1.5lb/MWh 

4.0 lb/1 012 Btu 33-15-22-03, 

or Subpart UUUUU 

0.04lb/GWh 

See Cond. 6.B 33-15-03-02 & 33-

15-12, Subpart D 
Emission Unit Pollutant/ 

Description EU EP Parameter 

Auxiliary Boiler No. 91 3 3 PM 

SOz 

NOx 

Opacity 

Annual Capacity 

(effective 1131116 or 

as amended by rule) 

Auxiliary Boiler No. 92 4 3 PM 

SOz 

NOx 

Opacity 

Annual Capacity 

(effective 1131116 or 

as amended by rule) 

Emergency generator 5 5 Opacity 

engine 

NOx 

co 

Emergency fire pump 6 6 Opacity 

engine 

NOx 

co 

Page _lQ_ of 46 

Permit No. T5-F82006 

NDAC 

Emission Applicable 

Limit* Requirement 

0.41 lb/1 0° Btu & 33-15-05-02 & PTC 

4.5lblhr Condition 

3.0 lb/106 Btu 33-15-06 & PTC 

& Condition 

516lblhr 

(3-hr rolling avg.) 

0.7lb/106 Btu PTC Condition 

See Cond. 6.A 33-15-03-02 

See Con d. 3. C 33-15-22-03, 

Subpart DDDDD 

0.41lb/10° Btu & 33-15-03-02 & PTC 

4.5lblhr Condition 

3.0 lb/1 06 Btu 33-15-06 & PTC 

& 516lblhr Condition 

(3-hr rolling avg.) 

0.7lb/106 Btu PTC Condition 

See Cond. 6.A 33-15-03-02 

See Cond. 3.C 33-15-22-03, 

Subpart DDDDD 

See Cond. 6.A 33-15-03-02 

See Cond. 4.D 33-15-22-03, 

Subpart ZZZZ 

See Cond. 4.D 33-15-22-03, 

Subpart ZZZZ 

See Cond. 6.A 33-15-03-02 

See Cond. 4.C 33-15-12-02, 

Subpart IIII 

See Cond. 4.C 33-15-12-02, 

Subpart IIII 
Emission Unit 

Description EU EP 

Lignite transfer house 7 7 

Lignite emergency 8 8 

reclaim system 

Lignite yard storage 9 9 

silos 

Lignite yard storage 10 10 

silos 

Crusher building (two 11 11 

crushers) 

Generation building coal 12 12 

hopper 

Base ofFalkirk Mining 13 13 

Company mine silo 

Generation building coal 14 14 

hopper 

Generation building coal 15 15 

hopper 

Generation building coal 16 16 

hopper 

Pollutant/ 

Parameter 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

Emission 

Limit* 

3lb/hr 

See Cond. 6.C 

3lb/hr 

See Cond. 6.C 

3lb/hr 

See Cond. 6.C 

3lb/hr 

See Cond. 6.C 

3lb/hr 

See Cond. 6. C 

3 lb/hr 

See Cond. 6.C 

3lb/hr 

See Cond. 6.C 

3lb/hr 

See Cond. 6.C 

3lb/hr 

See Cond. 6.C 

3lb/hr 

See Cond. 6.C 

Page _ll_ of 46 

Permit No. T5-F82006 

NDAC 

Applicable 

Requirement 

PTC Condition 

33-15-03-02 & 

33-15-12, Subpart Y 

PTC Condition 

33-15-03-02 & 

33-15-12, Subpart Y 

PTC Condition 

33-15-03-02 & 

33-15-12, Subpart Y 

PTC Condition 

33-15-03-02 & 

33-15-12, Subpart Y 

PTC Condition 

33-15-03-02 & 

33-15-12, Subpart Y 

PTC Condition 

33-15-03-02 & 

33-15-12, Subpart Y 

PTC Condition 

33-15-03-02 & 

33-15-12, Subpart Y 

PTC Condition 

33-15-03-02 & 

33-15-12, Subpart Y 

PTC Condition 

33-15-03-02 & 

33-15-12, Subpart Y 

PTC Condition 

33-15-03-02 & 

33-15-12, Subpart Y 
Emission Unit 

Description EU EP 

Generation building coal 17 17 

hopper 

Fly ash silo 20 20a, 

20b 

&20c 

Fly ash silo 21 21a, 

21b 

& 21c 

Fly ash railroad 25 25a& 

marketing silo 25b 

Fly ash dome 26 26a, 

26b, 

26c, 

26d 

Coal dryer 26 27 27 

CD26 coal crusher 27a 

Coal dryer crusher 28 36 

building 

Coal dryer transfer 29 37 

tower 

Auxiliary boiler area 30 38 

Pollutant/ 

Parameter 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

PM 

Opacity 

PM/PM10 

Opacity 

PM/PM10 

Opacity 

PM/PM10 

Opacity 

Page__l2_of 46 

Permit No. T5-F82006 

NDAC 

Emission Applicable 

Limit* Requirement 

3 lblhr PTC Condition 

See Cond. 6.C 33-15-03-02 & 

33-15-12, Subpart Y 

3 lblhr PTC Condition 

(each emission point) 

See Cond. 6.A 33-15-03-02 

(each emission point) 

3 lblhr PTC Condition 

(each emission point) 

See Cond. 6.A 33-15-03-02 

(each emission point) 

3 lblhr 33-15-14-06.5.b(1) 

(each emission point) 

See Cond. 6.A 33-15-03-02 

(each emission point) 

0.4lblhr 33-15-14-06.5.b(1) 

(Emission Points 26a 

through 26d) 

See Cond. 6.A 33-15-03-02 

(each emission point) 

3.1lblhr PTC 04006 

See Cond. 6.A 33-15-03-02 

0.004 gr/dscf 33-15-15 (BACT) 

& 0.75 lblhr*** 33-15-02-07 

10% 33-15-15 (BACT) 

0.004 gr/dscf 33-15-15 (BACT) 

& 0.59lblhr*** 33-15-02-07 

10% 33-15-15 (BACT) 

0.004 gr/dscf 33-15-15 (BACT) 

& 0.90 lblhr*** 33-15-02-07 

10% 33-15-15 (BACT) 
Emission Unit Pollutant/ Emission 

Description EU EP Parameter Limit* 

Coal dryer 11 31 39 PMIPM10 0.004 gr/dscf 

& 5.3 lblhr*** 

Coal dryer 12 32 

Opacity 10% 

Coal dryer 13 33 40 PMIPMIO 0.004 gr/dscf 

& 5.3 lblhr*** 

Coal dryer 14 34 Opacity 10% 

Coal dryer 21 35 41 PM 7.0 lb.hr 

Coal dryer 22 36 Opacity See Cond. 6.A 

Coal dryer 23 37 42 PM 7.0 lb.hr 

Coal dryer 24 38 Opacity See Cond. 6.A 

Air jig 21 39a 43 PMIPM10 0.004 gr/dscf 

& 1.4lblhr*** 

Air jig 22 39b Opacity 10% 

Lignite rail loading silo 40 44 PM/PM10 0.004 gr/dscf 

& 0.08 lblhr*** 

Opacity 10% 

Lignite dust collector 98 41 45 PM/PM10 0.004 gr/dscf 

& 0.13 lblhr*** 

Opacity 10% 

Lignite rail loading 42 46 PMIPMIO 0.004 gr/dscf 

surge hopper 91 & 0.08 lblhr*** 

Opacity 10% 

Lignite dust collector 99 43 47 PMIPMIO 0.004 gr/dscf 

& 0.75 lblhr*** 

Opacity 10% 

Fluidized bed pilot dryer 45 49 PM/PM10 0.005 gr/dscf 

& 0.30 lblhr*** 

Opacity 10% 

* Emission limits are based on a 1-hour average, unless otherwise noted. 

Page _u_ of 46 

Permit No. T5-F82006 

NDAC 

Applicable 

Requirement 

33-15-15 (BACT) 

33-15-02-07 

33-15-15 (BACT) 

33-15-15 (BACT) 

33-15-02-07 

33-15-15 (BACT) 

PTC07014 & 

33-15-14-03.6 

33-15-03-02 

PTC07014 & 

33-15-14-03.6 

33-15-03-02 

33-15-15 (BACT) 

33-15-02-07 

33-15-15 (BACT) 

33-15-15 (BACT) 

33-15-02-07 

33-15-15 (BACT) 

33-15-15 (BACT) 

33-15-02-07 

33-15-15 (BACT) 

33-15-15 (BACT) 

33-15-02-07 

33-15-15 (BACT) 

33-15-15 (BACT) 

33-15-02-07 

33-15-15 (BACT) 

33-15-15 (BACT) 

33-15-02-07 

33-15-15 (BACT) 
** 

*** 

6. 

This standard does not apply during startup, shutdown and malfunction. 

Most stringent limit applies. 

Page _H_ of 46 

Permit No. T5-F82006 

Opacity Limits: The following are applicable requirements referred to for the various emission units 

listed in Condition 5. 

A. EU 3 through 6, 20 through 27 and EU 35 through 38 - twenty percent (six-minute average), 

except that a maximum of forty percent (six-minute average) is permissible for not more than 

one six-minute period per hour. This standard applies at all times. 

Applicable Requirement: NDAC 33-15-03-02 

B. EU 1 and EU 2- Twenty percent (six-minute average), except that a maximum of twenty-seven 

percent (six-minute average) is permissible for not more than one six-minute period per hour. 

This standard does not apply during startup, shutdown and malfunction, and it will no longer 

apply at all if, and when, the USEP A grants the Great River Energy petition for alternate 

monitoring under 40 CFR 60.42(c) and when the PM CEMS are operational. 

Applicable Requirements: NDAC 33-15-12, Subpart A and Subpart D 

C. EU 7 through EU 17 - Twenty percent opacity (six-minute average) or greater shall not be 

discharged into the atmosphere. This standard does not apply during startup, shutdown and 

malfunction. 

Applicable Requirements: NDAC 33-15-12, Subpart A and Subpart Y 
7. Monitoring Requirements and Conditions: 

A. Requirements 

Monitoring 

Emission Unit Pollutant/ Requirement 

Description EU Parameter (Method) 

Lignite-fired boiler 1 Opacity O&M/CEM 

(Unit 1) 

PM Compliance 

Assurance 

Monitoring 

(CAM)/Emissions 

Test or PM CEM 

so2 CEM 

NOx CEM 

NOx&CO Tune-up 

C02 CEM 

HCl Emissions Test or 

S02 CEM 

Hg Emissions Test or 

HgCEM 

Flow Flow Monitor 

Condition 

Number 

7.B.l, 7.B.2, 7.B.3 

& 7.B.4 

7.B.1, 7.B.7, 

7.B.8, 7.B.l3 

7.B.1, 7.B.3 & 

7.B.4 

7.B.l, 7.B.3 & 

7.B.4 

7.B.6 

7.B.1, 7.B.3 & 

7.B.4 

7.B.7 & 7.B.8 or 

7.B.l 

7.B.7 & 7.B.8 or 

7.B.1 

7.B.1, 7.B.3 & 

7.B.4 

Page __li_ of 46 

Permit No. T5-F82006 

NDAC 

Applicable 

Requirement 

33-15-14-06.5.a.(3)(a), 

33-15-12, Subpart D & 

33-15-21 

40 CFR64, 

33-15-14-06.5.a(3)(a) 

& 33-15-22-03, 

Subpart UUUUU 

33-15-12, Subpart D & 

33-15-21 

33-15-21 

33-15-22-03, Subpart 

uuuuu 

33-15-12, Subpart D & 

33-15-21 

33-15-14-06.5.a(3)(a) 

& 33-15-22-03, 

Subpart UUUUU 

33-15-14-06.5.a(3)(a) 

& 33-15-22-03, 

Subpart UUUUU 

33-15-21 
Monitoring 

Emission Unit Pollutant/ Requirement 

Description EU Parameter (Method) 

Lignite-fired boiler 2 Opacity O&MICEM 

(Unit 2) 

PM CAM/Emissions 

Test or PM CEM 

so2 CEM 

NOx CEM 

NOx&CO Tune-up 

C02 CEM 

HCl Emissions Test or 

S02CEM 

Hg Emissions Test or 

HgCEMS 

Flow Flow Monitor 

Condition 

Number 

7.B.1, 7.B.2, 7.B.3 

& 7.B.4 

7.B.1, 7.B.7, 

7.B.8, 7.B.13 

7.B.l, 7.B.3 & 

7.B.4 

7.B.l, 7.B.3 & 

7.B.4 

7.B.6 

7.B.1, 7.B.3 & 

7.B.4 

7.B.7 & 7.B.8 

7.B.7 & 7.B.8 

7.B.1, 7.B.3 & 

7.B.4 

Page .lQ_ of 46 

Permit No. T5-F82006 

NDAC 

Applicable 

Requirement 

33-15-14-06.5.a.(3)(a), 

33-15-12, Subpart D & 

33-15-21 

40 CFR 64/ 

33-15-14-06.5.a.(3)(a) 

& 33-15-22-03, 

Subpart UUUUU 

33-15-12, Subpart D & 

33-15-21 

33-15-21 

33-15-22-03, Subpart 

uuuuu 

33-15-12, Subpart D & 

33-15-21 

33-15-14-06.5 .a(3)( a) 

& 33-15-22-03, 

Subpart UUUUU 

33-15-14-06.5.a(3)(a) 

& 33-15-22-03, 

Subpart UUUUU 

33-15-21 
Monitoring 

Emission Unit Pollutant/ Requirement 

Description EU Parameter (Method) 

Auxiliary Boiler 3 PM/ Opacity Recordkeeping 

No. 91 

so2 Sulfur Analysis 

NOx Emissions Test or 

Tune-up 

HAP Tune-up 

Hours of Recordkeeping 

Operation 

Annual Recordkeeping 

Capacity 

Factor 

Auxiliary Boiler 4 PM/ Opacity Recordkeeping 

No. 92 

so2 Sulfur Analysis 

NOx Emissions Test or 

Tune-up 

HAP Tune-up 

Hours of Recordkeeping 

Operation 

Annual Recordkeeping 

Capacity 

Factor 

Condition 

Number 

7.B.5 & 7.B.8)b 

7.B.l1 

7.B.9 

7.B.9 

7.B.12 

7.B.14 

7.B.5 & 7.B.8)b 

7.B.ll 

7.B.9 

7.B.9 

7.B.12 

7.B.14 

Page _..11_ of 46 

Permit No. T5-F82006 

NDAC 

Applicable 

Requirement 

33-15-14-06.5.a.(3)(a) 

& 33-15-22-03, 

Subpart DDDDD 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-22-03, Subpart 

DDDDD 

33-15-14-06.5.a.(3)(a) 

33-15-22-03, Subpart 

DDDDD& 

33-15-14-06.5.a(3)( a) 

33-15-14-06.5.a.(3)(a) 

& 33-15-22-03, 

Subpart DDDDD 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-22-03, Subpart 

DDDDD 

33-15-14-06-5.a.(3)(a) 

33-15-22-03, Subpart 

DDDDD& 

33-15-14-06.5.a(3)(a) 
Emission Unit Pollutant/ 

Description EU Parameter 

Emergency 5 Opacity 

generator engine 

NOx 

co 

Hours of 

Operation 

Emergency fire 6 Opacity 

pump engine 

NOx 

co 

Hours of 

Operation 

Lignite transfer 7 PM/ Opacity 

house 

Lignite emergency 8 PM/Opacity 

reclaim system 

Lignite yard storage 9 PM/ Opacity 

silos 

Lignite yard storage 10 PM/ Opacity 

silos 

Crusher building 11 PM/Opacity 

(two crushers) 

Generation building 12 PM/ Opacity 

coal hopper 

Base of Falkirk 13 PM/ Opacity 

Mining Company 

mine silo 

Generation building 14 PM/ Opacity 

coal hopper 

Generation building 15 PM/ Opacity 

coal hopper 

Generation building 16 PM/Opacity 

coal hopper 

Monitoring 

Requirement 

(Method) 

Recordkeeping 

As Required 

As Required 

Recordkeeping 

Recordkeeping 

As Required 

As Required 

Recordkeeping 

O&MNE 

Observations 

(VEO) 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

Condition 

Number 

7.B.5 

4.D 

4.D 

7.B.12 

7.B.5 

4.C 

4.C 

7.B.12 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

Page~of 46 

Permit No. T5-F82006 

NDAC 

Applicable 

Reguirement 

33-15-14-06.5.a.(3)(a) 

33-15-22-03, Subpart 

zzzz 

33-15-22-03, Subpart 

zzzz 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-12-02, Subpart 

IIII 

33-15-12-02, Subpart 

IIII 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5 .a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5 .a.(3)( a) 

33-15-14-06.5.a.(3)( a) 
Emission Unit Pollutant/ 

Description EU Parameter 

Generation building 17 PM/ Opacity 

coal hopper 

Fly ash silo 20 PM/Opacity 

Fly ash silo 21 PM/Opacity 

Fly ash railroad 25 PM/ Opacity 

marketing silo 

Fly ash dome 26 PM/ Opacity 

Coal dryer 26 27 

PM/Opacity 

CD26 coal crusher 27a 

Coal dryer crusher 28 PMIPMro/ 

building Opacity 

Coal dryer transfer 29 PM/PMro/ 

tower Opacity 

Auxiliary boiler 30 PMIPMro/ 

area Opacity 

Coal dryer 11 31 PM/PMro/ 

Coal dryer 12 32 Opacity 

Coal dryer 13 33 PM/PMro/ 

Coal dryer 14 34 Opacity 

Coal dryer 21 35 PM/PMro/ 

Coal dryer 22 36 Opacity 

Coal dryer 23 37 PM/PMro/ 

Coal dryer 24 38 Opacity 

Air jig 21 39a PMIPMro/ 

Air jig 22 39b Opacity 

Lignite rail loading 40 PM/PMro/ 

silo Opacity 

Lignite dust 41 PM/PMro/ 

collector 98 Opacity 

Lignite rail loading 42 PMIPMro/ 

surge hopper 91 Opacity 

Lignite dust 43 PMIPMro/ 

collector 99 Opacity 

Fluidized bed pilot 45 PM/PMro/ 

dryer Opacity 

B. Emission Monitoring Conditions 

Monitoring 

Requirement 

(Method) 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

O&MNEO 

Condition 

Number 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.l0 

7.B.7/7.B.10 

7.B.7/7.B.l0 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.10 

7.B.7/7.B.l0 

7.B.7/7.B.10 

7.B.7/7.B.10 

Page __1.2_ of 46 

Permit No. T5-F82006 

NDAC 

Applicable 

Requirement 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a.(3)(a) 

33-15-14-06.5.a(3)(a) 

33-15-14-06.5.a(3)(a) 

33-15-14-06.5 .a(3)(a) 

33-15-14-06.5.a(3)(a) 

33-15-14-06.5.a(3)(a) 

33-15-14-06.5.a(3)(a) 

33-15-14-06.5.a(3)(a) 

33-15-14-06.5.a(3)(a) 

33-15-14-06.5.a(3)(a) 

33-15-14-06.5.a(3)( a) 

33-15-14-06.5.a(3)(a) 

33-15-14-06.5.a(3)(a) 

33-15-14-06.5.a(3)( a) 

1) The monitoring shall be in accordance with the following applicable requirements of 

Chapter 33-15-06, Chapter 33-15-12, Chapter 33-15-21 and Chapter 33-15-22 of the 
Page 20 of 46 

Permit No. T5-F82006 

North Dakota Air Pollution Control Rules. Emissions are calculated using 40 CFR 75, 

Appendix F and 40 CFR 60, Appendix A. 

a) Section 33-15-06-04 of the North Dakota Air Pollution Control Rules, Monitoring 

Requirements. 

b) 40 CFR 60, Subpart A, Section 60.13, Monitoring Requirements. 

c) 40 CFR 60, Subpart D, Section 60.45, Emission and Fuel Monitoring. 

d) Section 33-15-21-09 of the North Dakota Air Pollution Control Rules, Monitoring 

Requirements. 

e) Upon approval by USEPA of alternate opacity monitoring, install, certify, operate 

and maintain PM CEMS per 40 CFR 60 Appendix B, Performance Specification 

11 and 40 CFR 60 Appendix F, Procedure 2. 

f) Install, certify, operate and maintain Hg CEM per 40 CFR 75 or 40 CFR 63, 

Subpart UUUUU Appendix A (compliance April 16, 2015 or as amended by 

rule). 

2) Within one year of the permit renewal date, the permittee shall conduct a performance 

evaluation of the continuous opacity monitoring system. For the performance evaluation, 

conformance with the specification for calibration error, Section 13.3 Field Audit 

Performance Specifications, Paragraph (2) Calibration Error of 40 CFR 60, Appendix B, 

Performance Specification 1 must be demonstrated. The procedures of Section 8.1, 

Paragraph (3)(ii) Calibration Error Check shall be used to determine conformance with 

the specification for calibration error. 

A second performance evaluation shall take place no sooner than two years or later than 

three years from the date of the first performance evaluation. 

3) The Department may require additional performance audits of the CEM system. 

4) When a failure of a continuous emission monitoring system occurs, an alternative 

method, acceptable to the Department, for measuring or estimating emissions must be 

undertaken as soon as possible. The procedures outlined in 40 CFR 75, Subpart D for 

substitution are considered an acceptable method. Timely repair of the emission 

monitoring system must be made. 

5) For purposes of compliance monitoring, burning of fuel in compliance with Condition 

3.A shall be considered credible evidence of compliance with any applicable opacity, 

particulate and S02 emission limit. However, results from tests conducted in accordance 

with the test methods in 40 CFR 50, 51, 60, 61, or 75 will take precedence over burning 

fuel in compliance with Condition 3.B and 3.C for evidence of compliance or 
Page .11_ of 46 

Permit No. T5-F82006 

noncompliance with any applicable opacity, particulate and so2 emission limit, in the 

event of enforcement action. 

6) Lignite-fired Boiler Tune-up: Conduct a tune-up on each existing lignite-fired boiler (EU 

1 and EU 2) at least each 36 months in accordance with 40 CFR 63, Subpart UUUUU 

(compliance date: April16, 2015 or as amended). 

7) The permittee shall maintain and operate air pollution control equipment in a manner 

consistent with good air pollution control practice for minimizing emissions. The 

manufacturer's recommended Operations and Maintenance (O&M) procedures, or a sitespecific O&M procedure (developed from the manufacturer's recommended O&M 

procedures), shall be followed to assure proper operation and maintenance of the 

equipment. The permittee shall have the O&M procedures available on-site and provide 

the Department with a copy when requested. 

8) a) Within two years of the permit renewal date, the permittee shall conduct an 

emissions test to measure particulate emissions, using EPA Test Methods in 40 

CFR 60, Appendix A. A test shall consist of three runs, with each run at least one 

hour in length. Other test methods may be used provided they are approved in 

advance by the Department. 

b) Conduct performance tests quarterly for units subject to 40 CFR 63, Subpart 

UUUUU (beginning April 16, 2015 or as amended by rule). 

9) An emissions test shall be conducted to measure particulate and NOx emissions when the 

unit(s) have operated more than 500 hours in a calendar year. The emissions test shall be 

conducted using EPA Test Methods in 40 CFR 60, Appendix A. A test shall consist of 

three runs, with each run at least one hour in length. Other test methods may be used 

provided they are approved, in advance, by the Department. An emissions test will not 

be required more than once during the term of the permit. This test requirement will not 

be applicable subsequent to the 40 CFR 63, Subpart DDDDD compliance date. 

Conduct a boiler tune-up once every 24 months per 40 CFR 63, Subpart DDDDD 

(beginning January 31,2016 or as amended by rule). 

1 0) At least once per week in which the emission unit is operated, a company representative 

(need not be certified) shall observe the emission point. If no visible emissions are 

observed, the date and time shall be recorded. 

If visible emissions are observed, the permittee must investigate the problem within eight 

hours. Any problems that are discovered must be corrected as soon as possible. If the 

correction of the emissions is expected to take longer than 24 hours, the permittee shall 

follow procedures as outlined in Condition 10.H. Following corrective maintenance, a 

visible emissions observation shall be made. 
Page 22 of 46 

Permit No. T5-F82006 

All investigations of malfunctions and visible emissions shall be recorded. The permittee 

shall comply with the visible emissions and particulate emission limits and nothing in this 

condition shall be construed as authorizing otherwise. 

11) The sulfur analysis for the fuel may be conducted by the permitted or by the source where 

the fuel is purchased. The permittee shall calculate sulfur dioxide emission rates from the 

sulfur content of the fuel using EPA emission factors or other methods approved by the 

Department. 

12) A log shall be kept of the hours of operation. 

13) The permittee shall conduct the monitoring, recordkeeping and reporting as required by 

the applicable subparts of 40 CFR 64. Monitoring shall be conducted in accordance with 

the Compliance Assurance Monitoring (CAM) Plan in Attachment A of this permit. The 

indicator ranges for emission units subject to CAM are as follows: 

Indicator Indicator 

Emission Unit Monitored Range 

EU 1 (ESP) Opacity :::; 20% 

(Particulate) 

EU 2 (ESP) Opacity :::; 20% 

(Particulate) 

14) Auxiliary Boiler Annual Capacity Factor: The permittee shall monitor and record the 

type and amount of fuel used by the Auxiliary Boilers (EU 3 and EU 4). By the 15th day 

of each January, the permittee shall calculate and record for each limited use boiler the 

annual capacity factor as defined in §63.7575. These records shall be retained by the 

permittee for a period of five years and made available to the Department upon request. 

If the annual capacity factor exceeds 1 0 percent, the permittee shall notify the 

Department within 15 days after making the calculation. (Compliance date: January 31, 

2016 or as amended.) 

8. Recordkeeping Requirements: 

A. The permittee shall maintain compliance monitoring records for all emission units as outlined in 

Table 1 (Monitoring Records), that includes the following information. 

1) The date, place (as defined in the permit) and time of sampling or measurement. 

2) The date(s) testing was performed. 

3) The company, entity, or person that perforn:led the testing. 

4) The testing techniques or methods used. 
5) The results of such testing. 

Page 23 of 46 

Permit No. T5-F82006 

6) The unit load that existed at the time of sampling or measurement. 

7) Records shall be kept as to the type of fuel usage. 

Applicable Requirement: NDAC 33-15-14-06.5.a.(3)(b)[1] 

B. In addition to requirements outlined in Condition 8.A, recordkeeping for EU 1, EU 2 and EU 7 

through EU 17 shall be in accordance with the following applicable requirements of Chapter 33-

15-06, Chapter 33-15-12, Chapter 33-15-14 and Chapter 33-15-21 ofthe North Dakota 

Air Pollution Control Rules: 

1) Section 33-15-06-05 of the North Dakota Air Pollution Control Rules, Reporting and 

Recordkeeping Requirements. 

2) 40 CFR 60, Subpart A, Section 60.7, Notification and Recordkeeping. 

3) Section 33-15-21-09 of the North Dakota Air Pollution Control Rules, Recordkeeping 

Requirements. 

4) 40 CFR 64, Section 64.9 - Reporting and Recordkeeping Requirements, Paragraph (b) 

General Recordkeeping Requirements. 

Applicable Requirements: NDAC 33-15-06, 33-15-12, 33-15-14, and 33-15-21; 40 CFR 64 

Emission Unit Description EU 

Lignite-fired boiler (Unit 1) 1 

Table 1 

Monitoring Records 

Pollutant/ 

Parameter 

Opacity 

PM 

so2 (lb/1 06 Btu) 

so2 (lb/hr) 

NOx&CO 

C02 

Compliance 

Monitoring Record 

CEMData 

CAM Data & Emissions Test Data 

or CEM Data 

CEMData 

CEM Data & Material Balance 

Data 

CEMData& 

Tune-up Records 

CEMData 
Pollutant/ 

Emission Unit Description EU Parameter 

HCl 

Hg 

Flow 

Lignite-fired boiler (Unit 2) 2 Opacity 

PM 

S02 (lb/1 06 Btu) 

802 (lblhr) 

NOx&CO 

C02 

HCl 

Hg 

Flow 

Auxiliary Boiler No: 91 3 PM/ Opacity 

802 

NOx 

HAP 

Hours of Operation 

Annual Capacity 

Factor 

Page 24 of 46 

Permit No. T5-F82006 

Compliance 

Monitoring Record 

CEM Data or Emissions Test Data 

CEMS Data or Emissions Test Data 

Flow Monitor Data 

CEMData 

CAM Data & Emissions Test Data 

orCEM Data 

CEMData 

CEM Data & Material Balance 

Data 

CEMData& 

Tune-up Records 

CEMData 

CEM Data or Emissions Test Data 

CEMS Data or Emissions Test Data 

Flow Monitor Data 

Type of Fuel Usage 

Sulfur Analysis 

Emissions Test Data or 

Tune-up Records 

Tune-up Records 

Hours of Operation Data 

Fuel Records & Calculations 
Emission Unit Description EU 

Auxiliary Boiler No. 92 4 

Emergency generator engine 5 

Emergency fire pump engine 6 

Lignite transfer house 7 

Lignite emergency reclaim system 8 

Lignite yard storage silos 9 

Lignite yard storage silos 10 

Crusher building (two crushers) 11 

Generation building coal hopper 12 

Base of Falkirk Mining Company 13 

mine silo 

Generation building coal hopper 14 

Generation building coal hopper 15 

Generation building coal hopper 16 

Generation building coal hopper 17 

Fly ash silo 20 

Fly ash silo 21 

Fly ash railroad marketing silo 25 

Pollutant/ 

Parameter 

PM/ Opacity 

so2 

NOx 

HAP 

Hours of Operation 

Annual Capacity 

Factor 

Opacity· 

NOx 

co 

Hours of Operation 

Opacity 

NOx 

co 

Hours of Operation 

PM/ Opacity 

PM/ Opacity 

PM/ Opacity 

PM/ Opacity 

PM/ Opacity 

PM/ Opacity 

PM/ Opacity 

PM/ Opacity 

PM/Opacity 

PM/ Opacity 

PM/ Opacity 

PM/ Opacity 

PM/ Opacity 

PM/ Opacity 

Page 25 of 46 

Permit No. T5-F82006 

Compliance 

Monitoring Record 

Type of Fuel Usage 

Sulfur Analysis 

Emissions Test Data or 

Tune-up Records 

Tune-up Records 

Hours of Operation Data 

Fuel Records & Calculations 

Type ofFuel Usage 

Emissions Test Data 

Emissions Test Data 

Hours of Operation Data 

Type ofFuel Usage 

Emissions Test Data 

Emissions Test Data 

Hours of Operation Data 

O&MData&VE 

Observations (VEO) Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 
Emission Unit Description 

Fly ash dome 

Coal dryer 

CD26 coal crusher 

Coal dryer crusher building 

Coal dryer transfer tower 

Auxiliary boiler area 

Coal dryer 11 

Coal dryer 12 

Coal dryer 13 

Coal dryer 14 

Coal dryer 21 

Coal dryer 22 

Coal dryer 23 

Coal dryer 24 

Air jig 21 

Air jig 22 

Lignite rail loading silo 

Lignite dust collector 98 

Lignite rail loading surge hopper 91 

Lignite dust collector 99 

Fluidized bed pilot dryer 

EU 

26 

27 

27a 

28 

29 

30 

31 

32 

33 

34 

35 

36 

37 

38 

39a 

39b 

40 

41 

42 

43 

45 

Pollutant/ 

Parameter 

PM/ Opacity 

PM/ Opacity 

PM/PMio/Opacity 

PM/PM10/0pacity 

PMIPMIO/Opacity 

PM/PM10/0pacity 

PM/PM10/0pacity 

PM/PMio/Opacity 

PM/PM1o/Opacity 

PM/PM1o/Opacity 

PM/PM10/0pacity 

PM/PM10/0pacity 

PM/PM1o/Opacity 

PM/PMio/Opacity 

PM/PM10/0pacity 

Page 26 of 46 

Permit No. T5-F82006 

Compliance 

Monitoring Record 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

O&M Data & VEO Data 

C. The permittee shall retain records of all required compliance monitoring data and support 

information for a period of at least five years from the date of the monitoring sampling, 

measurement, report, or application. Support information includes all calibration and 

maintenance records and all original strip-chart recordings/computer printouts of continuous 

compliance monitoring instrumentation, and copies of all reports required by the permit. 

Applicable Requirement: NDAC 33-15-14-06-5.a.(3)(b)[2] 

9. Reporting: 

A. For EU 1, EU 2 and EU 7 through EU 17, EU 28 through EU 30, and EU 39 through EU 47, 

reporting shall be in accordance with the following applicable requirements of Chapter 33-15-06, 

Chapter 33-15-12, Chapter 33-15-14 and Chapter 33-15-21 of the North Dakota Air Pollution 

Control Rules. 

1) Section 33-15-06-05 of the North Dakota Air Pollution Control Rules, Reporting and 

Recordkeeping Requirements. 
Page 27 of 46 

Permit No. T5-F82006 

2) 40 CFR 60, Subpart A, Section 60.7, Notification and Recordkeeping. 

3) Section 33-15-21-09 of the North Dakota Air Pollution Control Rules, Reporting 

Requirements. 

4) 40 CFR 64, Section 64.9 - Reporting and Recordkeeping Requirements, Paragraph (a) 

General Reporting Requirements. 

5) Quarterly excess emissions reports for EU 1 and EU 2 shall be submitted by the 30th day 

following the end of each calendar quarter. Excess emissions are defined as emissions 

which exceed the emission limits for EU 1 and EU 2 as outlined in Condition 5. Excess 

emissions shall be reported for the following: 

Parameter 

Opacity% 

so2 lb/1 06 Btu 

S02lblhr 

NOx lblhr 

Reporting Period 

( 6-minute average) 

(3-hour rolling average) 

(3-hour rolling average) 

(12-month rolling average) 

Note: Also report appropriate additional parameters if CEMS are added for PM, HCl and 

Hg. 

B. The permittee shall submit a semi-annual monitoring report for all monitoring records required 

under Condition 8 on forms supplied or approved by the Department. All instances of deviations 

from the permit must be identified in the report. A monitoring report shall be submitted within 

45 days after June 30 and December 31 of each year. 

Applicable Requirement: NDAC 33-15-14-06.5.a(3)(c)[1] and [2] 

C. The permittee shall submit an annual compliance certification report within 45 days after 

December 31 of each year on forms supplied or approved by the Department. 

Applicable Requirement: NDAC 33-15-14-06.5.c(5) 

D. For emission units where the method of compliance monitoring is demonstrated by an EPA Test 

Method or a portable analyzer test, the test report shall be submitted to the Department within 60 

days after completion of the test. 

Applicable Requirement: NDCC 33-15-14-06.5.a.(6)(e) 

E. The permittee shall submit an annual emission inventory report on forms supplied or approved 

by the Department. This report shall be submitted by March 15 of each year. Insignificant 

units/activities listed in this permit do not need to be included in the report. 
Page 28 of 46 

Permit No. T5-F82006 

Applicable Requirements: NDAC 33-15-14-06.5.c.(7) and NDAC 33-15-23-04 

10. Facility Wide Operating Conditions: 

A. Ambient Air Quality Standards: 

1) Particulate and gases. The permittee shall not emit air contaminants in such a manner or 

amount that would violate the standards of ambient air quality listed in Table 1 ofNDAC 

33-15-02 at any place beyond the premises on which the source is located. 

2) Radioactive substances. The permittee shall not release into the ambient atr any 

radioactive substances exceeding the concentrations specified in NDAC 33-10. 

3) Other air contaminants. The permittee shall not emit any other air contaminants in 

concentrations that would be injurious to human health or well-being or unreasonably 

interfere with the enjoyment of property or that would injure plant or animal life. 

4) Disclaimer. Nothing in any other part or section of this permit may in any manner be 

construed as authorizing or legalizing the emission of air contaminants in such manner 

that would violate the standards in Paragraphs 1), 2) and 3) of this condition. 

Applicable Requirement: NDAC 33-15-02-04 

B. Fugitive Emissions: The release of fugitive emtsswns shall comply with the applicable 

requirements in NDAC 33-15-17. 

Applicable Requirement: NDAC 33-15-17 

C. Open Burning: The permittee may not cause, conduct, or permit open burning of refuse, trade 

waste, or other combustible material, except as provided for in section 33-15-04-02 and may not 

conduct, cause, or permit the conduct of a salvage operation by open burning. Any permissible 

open burning under NDAC 33-15-04-02 must comply with the requirements of that section. 

Applicable Requirement: NDAC 33-15-04 

D. Asbestos Renovation or Demolition: Any asbestos renovation or demolition at the facility shall 

comply with emission standard for asbestos in NDAC 33-15-13. 

Applicable Requirement: NDAC 33-15-13-02 

E. Requirements for Organic Compounds Gas Disposal: 

1) The owner/operator shall incinerate, flare or treat in an equally effective manner any 

organic compounds, gases and vapors which are generated as wastes as the result of 

storage, refining, or process operations and which contain hydrogen sulfide before being 

released to the ambient air. 
Page 29 of 46 

Permit No. T5-F82006 

2) Each flare must be equipped and operated with an automatic ignitor or a continuous 

burning pilot. 

Applicable Requirement: NDAC 33-15-07-02 

F. Rotating Pumps and Compressors: All rotating pumps and compressors handling volatile 

organic compounds must be equipped and operated with properly maintained seals designed for 

their specific product service and operating conditions. 

Applicable Requirement: NDAC 33-15-07-01.5 

G. Shutdowns/Malfunction/Continuous Emission Monitoring System Failure: 

1) Maintenance Shutdowns. In the case of shutdown of air pollution control equipment for 

necessary scheduled maintenance, the intent to shut down such equipment shall be 

reported to the Department at least twenty-four hours prior to the planned shutdown 

provided that the air contaminating source will be operated while the control equipment 

is not in service. Such prior notice shall include the following: 

a) Identification of the specific facility to be taken out of service as well as its 

location and permit number. 

b) The expected length of time that the air pollution control equipment will be out of 

service. 

c) The nature and estimated quantity of emissions of air pollutants likely to be 

emitted during the shutdown period. 

d) Measures, such as the use of off-shift labor and equipment, that will be taken to 

minimize the length of the shutdown period. 

e) The reasons that it would be impossible or impractical to shutdown the source 

operation during the maintenance period. 

f) Nothing in this subsection shall in any manner be construed as authorizing or 

legalizing the emission of air contaminants in excess of the rate allowed by this 

article or a permit issued pursuant to this article. 

Applicable Requirement: NDAC 33-15-01-13.1 

2) Malfunctions. 

a) When a malfunction in any installation occurs that can be expected to last longer 

than twenty-four hours and cause the emission of air contaminants in violation of 

this article or other applicable rules and regulations, the person responsible for 
Page 30 of 46 

Permit No. T5-F82006 

such installation shall notify the Department of such malfunction as soon as 

possible during normal working hours. The notification must contain a statement 

giving all pertinent facts, including the estimated duration ofthe breakdown. The 

department shall be notified when the condition causing the malfunction has been 

corrected. 

b) Immediate notification to the department is required for any malfunction that 

would threaten health or welfare, or pose an imminent danger. During normal 

working hours the Department can be contacted at 701-328-5188. After hours the 

department can be contacted through the twenty-four-hour state radio emergency 

number 1-800-472-2121. If calling from out of state, the twenty-four-hour 

number is 701-328-9921. 

c) Unavoidable Malfunction. The owner or operator of a source who believes any 

excess emissions resulted from an unavoidable malfunction shall submit a written 

report to the Department which includes evidence that: 

[1] The excess emissions were caused by a sudden, unavoidable breakdown of 

technology that was beyond the reasonable control of the owner or 

operator. 

[2] The excess emissions could not have been avoided by better operation and 

maintenance, did not stem from an activity or event that could have been 

foreseen and avoided, or planned for. 

[3] To the extent practicable, the source maintained and operated the air 

pollution control equipment and process equipment in a manner consistent 

with good practice for minimizing emissions, including minimizing any 

bypass emissions. 

[ 4] Any necessary repairs were made as quickly as practicable, using off-shift 

labor and overtime as needed and possible. 

[5] All practicable steps were taken to minimize the potential impact of the 

excess emissions on ambient air quality. 

[6] The excess emissions are not part of a recurring pattern that may have 

been caused by inadequate operation or maintenance, or inadequate design 

of the malfunctioning equipment. 

The report shall be submitted within thirty days of the end of the calendar 

quarter in which the malfunction occurred or within thirty days of a 

written request by the department, whichever is sooner. 

The burden of proof is on the owner or operator of the source to provide 

sufficient information to demonstrate that an unavoidable equipment 
Page _ll_ of 46 

Permit No. T5-F82006 

malfunction occurred. The Department may elect not to pursue 

enforcement action after considering whether excess emissions resulted 

from an unavoidable equipment malfunction. The Department will 

evaluate, on a case-by-case basis, the information submitted by the owner 

or operator to determine whether to pursue enforcement action. 

Applicable Requirement: NDAC 33-15-01-13.2 

3) Continuous Emission Monitoring System Failures. When a failure of a continuous 

emission monitoring system occurs, an alternative method for measuring or estimating 

emissions must be undertaken as soon as possible. The owner or operator of a source that 

uses an alternative method shall have the burden of demonstrating that the method is 

accurate. Timely repair of the emission monitoring system must be made. The 

provisions of this subsection do not apply to sources that are subject to monitoring 

requirements in Chapter 33-15-21 (40 CPR 75, Acid Rain Program). 

Applicable Requirement: NDAC 33-15-01-13.3 

H. Noncompliance Due to an Emergency: The permittee may seek to establish that 

noncompliance with a technology-based emission limitation under this permit was due to an 

emergency. To do so, the permittee shall demonstrate the affirmative defense of emergency 

through properly signed, contemporaneous operating logs, or other relevant evidence that: 

1) An emergency occurred and that the permittee can identify the cause(s) of the 

emergency; 

2) The permitted facility was at the time being properly operated; 

3) During the period of the emergency the permittee took all reasonable steps to minimize 

levels of emissions that exceeded the emissions standards, or other requirements in this 

permit; and 

4) The permittee submitted notice of the emergency to the Department within one working 

day of the time when emission limitations were exceeded longer than 24-hours due to the 

emergency. This notice must contain a description of the emergency, any steps taken to 

mitigate emissions, and corrective actions taken. Those emergencies not reported within 

one working day, as well as those that were, will be included in the semi-annual report. 

5) In any enforcement proceeding, the permittee seeking to establish the occurrence of an 

emergency has the burden of proof. 

a) Technology-based emission limits are those established on the basis of emission 

reductions achievable with various control measures or process changes (e.g., a 

New Source Performance Standard) rather than those established to attain a health 

based air quality standard. 
Page 32 of 46 

Permit No. T5-F82006 

b) An "emergency" means any situation ansmg from sudden and reasonably 

unforeseeable events beyond the control of this source, including acts of God, 

which requires immediate corrective action to restore normal operation, and that 

causes this source to exceed a technology-based emission limitation under this 

permit, due to unavoidable increases in emissions attributable to the emergency. 

An emergency shall not include noncompliance to the extent caused by 

improperly designed equipment, lack of preventative maintenance, careless or 

improper operation, or operator error. 

Applicable Requirement: NDAC 33-15-14-06.5.g 

I. Air Pollution from Internal Combustion Engines: The permittee shall comply with all 

applicable requirements ofNDAC 33-15-08-01- Internal Combustion Engine Emissions 

Restricted. 

Applicable Requirement: NDAC 33-15-08-01 

J. Prohibition of Air Pollution: 

1) The permittee shall not permit or cause air pollution, as defined in NDAC 33-15-01-04. 

2) Nothing in any other part of this permit or any other regulation relating to air pollution 

shall in any manner be construed as authorizing or legalizing the creation or maintenance 

of air pollution. 

Applicable Requirement: NDAC 33-15-01-15 

K. Performance Tests: 

1) The Department may reasonably require the permittee to make or have made tests, at a 

reasonable time or interval, to determine the emission of air contaminants from any 

source, for the purpose of determining whether the permittee is in violation of any 

standard or to satisfy other requirements ofNDCC 23-25. All tests shall be made and the 

results calculated in accordance with test procedures approved or specified by the 

Department including the North Dakota Department of Health Emission Testing 

Guideline. All tests shall be conducted by reputable, qualified personnel. The 

Department shall be given a copy of the test results in writing and signed by the person 

responsible for the tests. 

2) The Department may conduct tests of emissions of air contaminants from any source. 

Upon request of the Department, the permittee shall provide necessary holes in stacks or 

ducts and such other safe and proper sampling and testing facilities, exclusiye of 

instruments and sensing devices, as may be necessary for proper determination of the 

emission of air contaminants. 

Applicable Requirement: NDAC 33-15-01-12 
Page _ll_ of 46 

Permit No. T5-F82006 

3) Except for sources subject to 40 CFR 63,the permittee shall notify the Department by 

submitting a Proposed Test Plan, or its equivalent, at least 30 calendar days in advance of 

any tests of emissions of air contaminants required by the Department. The permittee 

shall notify the Department at least 60 calendar days in advance of any performance 

testing required under 40 CFR 63. If the permittee is unable to conduct the performance 

test on the scheduled date, the permittee shall notify the Department as soon as 

practicable when conditions warrant, and shall coordinate a new test date with the 

Department. 

Failure to give the proper notification may prevent the Department from observing 

the test. If the Department is unable to observe the test because of improper 

notification, the test results may be rejected. 

Applicable Requirements: NDAC 33-15-14-06.5.a(3)(a), NDAC 33-15-12-02 Subpart A (40 

CFR 60.8), NDAC 33-15-13-01.2 Subpart A (40 CFR 61.13), NDAC 33-15-22-03 Subpart A 

(40 CFR 63.7) 

L. Pesticide Use and Disposal: Any use of a pesticide or disposal of surplus pesticides and empty 

pesticide containers shall comply with the requirements in NDAC 33-15-10. 

Applicable Requirements: NDAC 33-15-10-01 and NDAC 33-15-10-02 

M. Air Pollution Emergency Episodes: When an air pollution emergency episode is declared by 

the Department, the permittee shall comply with the requirements in NDAC 33-15-11. 

Applicable Requirements: NDAC 33-15-11-01 through NDAC 33-15-11-04 

N. Stratospheric Ozone Protection: The permittee shall comply with any applicable standards for 

recycling and emissions reduction pursuant to 40 CFR 82, Subpart F, except as provided for 

MV ACs in Subpart B: 

1) Persons opening appliances for maintenance, service, repair, or disposal must comply 

with the required practices pursuant to Section 82.156. 

2) Equipment used during the maintenance, service, repair, or disposal of appliances must 

comply with the standards for recycling and recovery equipment pursuant to Section 

82.158. 

3) Persons performing maintenance, service, repair, or disposal of appliances must be 

certified by an approved technician certification program pursuant to Section 82.161. 

4) Persons owning commercial or industrial process refrigeration equipment must comply 

with the leak repair requirements pursuant to Section 82.156. 

Applicable Requirement: 40 CFR 82 
Page 34 of 46 

Permit No. T5-F82006 

0. Chemical Accident Prevention: The permittee shall comply with all applicable requirements of 

Chemical Accident Prevention pursuant to 40 CFR 68. The permittee shall comply with the 

requirements of this part no later than the latest of the following dates: 

1) Three years after the date on which a regulated substance is first listed under this part; or 

2) The date on which a regulated substance is first present above a threshold quantity in a 

process. 

Applicable Requirement: 40 CFR 68 

P. Air Pollution Control Equipment: The permittee shall maintain and operate air pollution 

control equipment in a manner consistent with good air pollution control practice for minimizing 

emissions. The manufacturer's recommended Operations and Maintenance (O&M) procedures, 

or a site-specific O&M procedure developed from the manufacturer's recommended O&M 

procedures, shall be followed to assure proper operation and maintenance of the equipment. The 

permittee shall have the O&M procedures available onsite and provide the Department with a 

copy when requested. 

Applicable Requirement: NDAC 33-15-14-06.5.b(1) 

Q. Prevention of Significant Deterioration of Air Quality (40 CFR 52.21 as incorporated by 

NDAC Chapter 33-15-15): If this facility is classified as a major stationary source under the 

Prevention of Significant Deterioration of Air Quality (PSD) rules, a Permit to Construct must be 

obtained from the Department for any project which meets the definition of a "major 

modification" under 40 CFR 52.21 (b )(2). 

If this facility is classified as a major stationary source under the PSD rules and the permittee 

elects to use the method specified in 40 CFR 52.21(b)(41)(ii)(a) through (c) for calculating the 

projected actual emissions of a proposed project, then the permittee shall comply with all 

applicable requirements of 40 CFR 52.21(r)(6). 

Applicable Requirement: NDAC 33-15-15-01.2 

11. General Conditions: 

A. Annual Fee Payment: The permittee shall pay an annual fee, for administering and monitoring 

compliance, which is determined by the actual annual emissions of regulated contaminants from 

the previous calendar year. The Department will send a notice, identifying the amount of the 

annual permit fee, to the permittee of each affected installation. The fee is due within sixty days 

following the date of such notice. Any source that qualifies as a "small business" may petition 

the Department to reduce or exempt any fee required under this section. Failure to pay the fee in 

a timely manner or submit a certification for exemption may cause this Department to initiate 

action to revoke the permit. 
Page ]2_ of 46 

Permit No. T5-F82006 

Applicable Requirements: NDAC 33-15-14-06.5.a(7) and NDAC 33-15-23-04 

B. Permit Renewal and Expiration: This permit shall be effective from the date of its issuance for 

a fixed period of 5 years. The permittee's right to operate this source terminates with the 

expiration of this permit unless a timely and complete renewal application is submitted at least 

six months, but no more than eighteen months, prior to the date of permit expiration. The 

Department shall approve or disapprove the renewal application within sixty days of receipt. 

Unless the Department requests additional information or otherwise notifies the applicant of 

incompleteness, the application shall be deemed complete. For timely and complete renewal 

applications for which the Department has failed to issue or deny the renewal permit before the 

expiration date of the previous permit, all terms and conditions of the permit, including any 

permit shield previously granted shall remain in effect until the renewal permit has been issued 

or denied. The application for renewal shall include the current permit number, description of 

any permit revisions and off-permit changes that occurred during the permit term, and any 

applicable requirements that were promulgated and not incorporated into the permit during the 

permit term. 

Applicable Requirements: NDAC 33-15-14-06.4 and NDAC 33-15-14-06.6 

C. Transfer of Ownership or Operation: This permit may not be transferred except by 

procedures allowed in Chapter 33-15-14 and is to be returned to the Department upon the 

destruction or change of ownership of the source unit(s), or upon expiration, suspension or 

revocation of this permit. A change in ownership or operational control of a source is treated as 

an administrative permit amendment if no other change in the permit is necessary and provided 

that a written agreement containing a specific date for transfer of permit responsibility, coverage, 

and liability between the current and new permittee has been submitted to the Department. 

Applicable Requirement: NDAC 33-15-14-06.6.d 

D. Property Rights: This permit does not convey any property rights of any sort, or any exclusive 

privilege. 

Applicable Requirement: NDAC 33-15-14-06.5.a(6)(d) 

E. Submissions: 

1) Reports, test data, monitoring data, notifications, and requests for renewal shall be 

submitted to: 

North Dakota Department of Health 

Division of Air Quality 

918 E Divide Avenue, 2nd Floor 

Bismarck, ND 58501-1947 

2) Any document submitted shall be certified as being true, accurate, and complete by a 

responsible official. 

Applicable Requirement: NDAC 33-15-14-06.4.d 
Page 36 of 46 

Permit No. T5-F82006 

F. Right of Entry: Any duly authorized officer, employee or agent of the North Dakota 

Department of Health may enter and inspect any property, premise or place listed on this permit 

or where records are kept concerning this permit at any reasonable time for the purpose of 

ascertaining the state of compliance with this permit and the North Dakota Air Pollution Control 

Rules. The Department may conduct tests and take samples of air contaminants, fuel, processing 

material, and other materials which affect or may affect emissions of air contaminants from any 

source. The Department shall have the right to access and copy any records required by the 

Department's rules and to inspect monitoring equipment located on the premises. 

Applicable Requirements: NDAC 33-15-14-06.5.c(2) and NDAC 33-15-01-06 

G. Compliance: The permittee must comply with all conditions of this permit. Any 

noncompliance with a federally-enforceable permit condition constitutes a violation of the 

Federal Clean Air Act. Any noncompliance with any State enforceable condition of this permit 

constitutes a violation ofNDCC Chapter 23-25 and NDAC 33-15. Violation of any condition of 

this permit is grounds for enforcement action, for permit termination, revocation and reissuance 

or modification, or for denial of a permit renewal application. Noncompliance may also be 

grounds for assessment of penalties under the NDCC 23-25. It shall not be a defense for a 

permittee in an enforcement action that it would have been necessary to halt or reduce the 

permitted activity in order to maintain compliance with the conditions of this permit. 

Applicable Requirements: NDAC 33-15-14-06.5.a(6)(a) and NDAC 33-15-14-06.5.a(6)(b) 

H. Duty to Provide Information: The permittee shall furnish to the Department, within a 

reasonable time, any information that the Department may request in writing to determine 

whether cause exists for modifying, revoking and reissuing, or terminating the permit, or to 

determine compliance with the permit. This includes instances where an alteration, repair, 

expansion, or change in method of operation of the source occurs. Upon request, the permittee 

shall also furnish to the Department copies of records that the permittee is required to keep by 

this permit, or for information claimed to be confidential, the permittee may furnish such 

recourse directly to the Department along with a claim of confidentiality. The permittee, upon 

becoming aware that any relevant facts were omitted or incorrect information was submitted in 

the permit application, shall promptly submit such. supplementary facts or corrected information. 

Items that warrant supplemental information submittal include, but are not limited to, changes in 

the ambient air boundary and changes in parameters associated with emission points (i.e., stack 

parameters). The permittee shall also provide additional information as necessary to address any 

requirements that become applicable to the source after the date a complete renewal application 

was submitted but prior to release of a draft permit. 

Applicable Requirements: NDAC 33-15-14-06.5.a(6)(e), NDAC 33-15-14-06.6.b(3) and NDAC 

33-15-14-06.4.b 

I. Reopening for Cause: The Department will reopen and revise this permit as necessary to 

remedy deficiencies in the following circumstances: 

1) Additional applicable requirements under the Federal Clean Air Act become applicable to 

the permittee with a remaining permit term of three or more years. Such a reopening 

shall be completed no later than eighteen months after promulgation of the applicable 
Page 37 of 46 

Permit No. T5-F82006 

requirement. No such reopening is required if the effective date of the requirement is 

later than the expiration date of this permit. 

2) The Department or the United States Environmental Protection Agency determines that 

this permit contains a material mistake or inaccurate statements were made in 

establishing the emissions standards or other terms or conditions of this permit. 

Applicable Requirement: NDAC 33-15-14,.06.6.f(1)(c) 

3) The Department or the United States Environmental Protection Agency determines that 

the permit must be revised or revoked to assure compliance with the applicable 

requirements. 

4) Reopenings shall not be initiated before a notice of intent to reopen is provided to the 

permittee by the Department at least 30 days in advance of the date that this permit is to 

be reopened, except that the Department may provide a shorter time period in the case of 

an emergency. Proceedings to reopen and issue this permit shall follow the same 

procedures as apply to initial permit issuance and shall affect only those parts of this 

permit for which cause to reopen exists. Such reopening shall be made as expeditiously 

as practicable. 

Applicable Requirement: NDAC 33-15-14-06.6.f 

J. Permit Changes: The permit may be modified, revoked, reopened, and reissued or terminated 

for cause. The filing of a request by the permittee for a permit modification, revocation and 

reissuance, or termination, or of a notification of planned changes or anticipated noncompliance 

does not stay any permit condition. 

Applicable Requirement: NDAC 33-15-14-06.5.a(6)(c) 

K. Off-Permit Changes: A permit revision is not required for changes that are not addressed or 

prohibited by this permit, provided the following conditions are met: 

1) No such change may violate any term or condition of this permit. 

2) Each change must comply with all applicable requirements. 

3) Changes under this provision may not include changes or activities subject to any 

requirement under Title IV or that are modifications under any provision of Title I of the 

Federal Clean Air Act. 

4) A Permit to Construct under NDAC 33-15-14-02 has been issued, if required. 

5) Before the permit change is made, the permittee must provide written notice to both the 

Department and Air Program (8P-AR), Office of Partnerships & Regulatory Assistance, 

US EPA Region 8, 1595 Wynkoop Street, Denver, CO 80202-1129, except for changes 

that qualify as insignificant activities in Section 33-15-14-06. This notice shall describe 

each change, the date of the change, any change in emissions, pollutants emitted, and any 

applicable requirement that would apply as a result. 
Page J]_ of 46 

Permit No. T5-F82006 

6) The permittee shall record all changes that result in emissions of any regulated air 

pollutant subject to any applicable requirement not otherwise regulated under this permit, 

and the emissions resulting from those changes. The record shall reside at the permittee's 

facility. 

Applicable Requirement: NDAC 33-15-14-06.6.b(3) 

L. Administrative Permit Amendments: This permit may be revised through an administrative 

permit amendment, if the revision to this permit accomplishes one of the following: 

1) Corrects typographical errors. 

2) Identifies a change in the name, address or phone number of any person identified in this 

permit, or provides a similar minor administrative change at the source. 

3) Requires more frequent monitoring or reporting by the permittee. 

4) Allows for a change in ownership or operational control of the source where the 

Department determines that no other change in the permit is necessary, provided that a 

written agreement containing a specific date for transfer of permit responsibility, 

coverage and liability between the current and new permittee has been submitted to the 

Department. 

5) Incorporates into the Title V permit the requirements from a Permit to Construct when 

the review was substantially equivalent to Title V requirements for permit issuance, 

renewal, reopenings, revisions and permit review by the United States Environmental 

Protection Agency and affected state review, that would be applicable to the change if it 

were subject to review as a permit modification and compliance requirements 

substantially equivalent to Title V requirements for permit content were contained in the 

Permit to Construct. 

6) Incorporates any other type of change which the Administrator of the United States 

Environmental Protection Agency has approved as being an administrative permit 

amendment as part of the Department's approved Title V operating permit program. 

Applicable Requirement: NDAC 33-15-14-06.6.d 

M. Minor Permit Modification: This permit may be revised by a minor permit modification, if the 

proposed permit modification meets the following requirements: 

1) Does not violate any applicable requirement. 

2) Does not involve significant changes to existing monitoring, reporting, or recordkeeping 

requirements in this permit. 

3) Does not require or change a case-by-case determination of an emission limitation or 

other standard, or a source-specific determination for temporary sources of ambient 

impacts, or a visibility or increment analysis. 
Page 39 of 46 

Permit No. T5-F82006 

4) Does not seek to establish or change a permit term or condition for which there is no 

corresponding underlying applicable requirement and that the source has assumed to 

avoid an applicable requirement to which the source would otherwise be subject. Such 

terms and conditions include a federally enforceable emissions cap assumed to avoid 

classification as a modification under any 'provision of Title I of the Federal Clean Air 

Act; and alternative emissions limit approved pursuant to regulations promulgated under 

Section 112(i)(5) of the Federal Clean Air Act. 

5) Are not modifications under NDAC 33-15-12, 33-15-13, and 33-15-15 or any provision 

of Title I of the Federal Clean Air Act. 

6) Are not required to be processed as a significant modification. 

Applicable Requirement: NDAC 33-15-14-06.6.e(1) 

N. Significant Modifications: 

1) Significant modification procedures shall be used for applications requesting permit 

modifications that do not qualify as minor permit modifications or as administrative 

amendments. Every significant change in existing monitoring permit terms or conditions 

and every relaxation of reporting or recor<fkeeping permit terms or conditions shall be 

considered significant. Nothing therein shall be construed to preclude the permittee from 

making changes consistent with this subsection that would render existing permit 

compliance terms and conditions irrelevant. 

2) Significant permit modifications shall meet all Title V requirements, including those for 

applications, public participation, review by affected states, and review by the United 

States Environmental Protection Agency, as they apply to permit issuance and permit 

renewal. The Department shall complete review of significant permit modifications 

within nine months after receipt of a complete application. 

Applicable Requirement: NDAC 33-15-14-06.6.e(3) 

0. Operational Flexibility: The permittee is allowed to make a limited class of changes within the 

permitted facility that contravene the specific terms of this permit without applying for a permit 

revision, provided the changes do not exceed the emissions allowable under this permit, are not 

Title I modifications and a Permit to Construct is not required. This class of changes does not 

include changes that would violate applicable requirements; or changes to federally-enforceable 

permit terms or conditions that are monitoring, recordkeeping, reporting, or compliance 

certification requirements. 

The permittee is required to send a notice to both the Department and Air Program (8P-AR), 

Office of Partnerships & Regulatory Assistance, US EPA Region 8, 1595 Wynkoop Street, 

Denver, CO 80202-1129, at least seven days in advance of any change made under this 

provision. The notice must describe the change, when it will occur and any change in emissions, 

and identify any permit terms or conditions made inapplicable as a result of the change. The 

permittee shall attach each notice to its copy of this permit. Any permit shield provided in this 

permit does not apply to changes made under this provision. 
Applicable Requirement: NDAC 33-15-14-06.6.b(2) 

Page 40 of 46 

Permit No. T5-F82006 

P. Relationship to Other Requirements: Nothing in this permit shall alter or affect the following: 

1) The provisions of Section 303 of the Federal Clean Air Act (emergency orders), 

including the authority of the administrator of the United States Environmental Protection 

Agency under that section. 

2) The liability of an owner or operator of a source for any violation of applicable 

requirements prior to or at the time of permit issuance. 

3) The ability of the United States Environmental Protection Agency to obtain information 

from a source pursuant to Section 114 of th~ Federal Clean Air Act. 

4) Nothing in this permit shall relieve the permittee of the requirement to obtain a Permit to 

Construct. 

Applicable Requirements: NDAC 33-15-14-06.3 and NDAC 33-15-14-06.5.f(3)(a), (b) 

and (d) 

Q. Severability Clause: The provisions of this permit are severable, and if any provision of this 

permit, or the application of any provision of this permit to any circumstance, is held invalid, the 

application of such provision to other circumstances, and the remainder of this permit, shall not 

be affected thereby. 

Applicable Requirement: NDAC 33-15-14-06.5.a(5) 

R. Circumvention: The permittee shall not cause or permit the installation or use of any device of 

any means which conceals or dilutes an emission of air contaminants which would otherwise 

violate this permit. 

Applicable Requirement: NDAC 33-15-01-08 

12. State Enforceable Only Conditions (not Federally enforceable): 

A. General Odor Restriction: The permittee shall not discharge into the ambient air any 

objectionable odorous air contaminant which exceeds the limits established in NDAC 33-15-16. 

Applicable Requirement: NDAC 33-15-16 

B. Combustion of Used Oil Containing PCBs: Burning ofused oil in EU 1 and EU 2 containing 

PCBs is allowed during normal operations subject to the following: 

1) The owner/operator shall file a Notification of Hazardous Waste Activity (EPA Form 

8700-12) with the Department indicating used oil fuel activities. 
Page _±L of 46 

Permit No. T5-F82006 

2) Only oil which contains less than 50 ppm PCB may be burned. Burning of oil which 

contains PCB is only allowed for used oil generated by Great River Energy, its associated 

electric system, or its associated mining facilities. 

3) Soil, rock and other earthen debris contaminated with mineral oil dielectric fluid which 

contains less than 50 ppm PCB may be burned during periods of stable load. 

Applicable Requirement: NDAC 33-15-14-06.5.b(1) 

C. Used Oil Combustion: Burning of used oil in EU 1, EU 2, EU 3 and EU 4 is allowed subject to 

the following: 

1) The burning of used oil shall comply with NDAC Sections 33-24-05-600 through 33-24-

05-689 - Standards for the Management of Used Oil - and other applicable rules, 

regulations, and ordinances. 

2) The annual emission inventory reports required by Condition 9.E shall include the 

amount of specification used oil burned. 

Applicable Requirement: NDAC 33-15-14-06.5.b(1) 

D. Hazardous Waste: The burning of hazardous waste in EU 1 and EU 2 shall comply with 

NDAC Sections 33-24-05-525 through 33-24-05-549- Boilers Industrial Furnaces (BIFs). 

Applicable Requirement: NDAC 33-15-14-06.5.b(l) 

13. Phase II Acid Rain Provisions: 

Affected Source Unit: Coal Creek Station 

ORIS Plant Code: 6030 

Boiler ID: 1 and 2 

This section incorporates the definition of terms in NDAC Chapter 33-15-21 by reference effective 

April1, 2003. 

A. Permit Requirements 

1) The designated representative of each affected source and each affected unit at the source 

shall: 

a) Submit a complete Acid Rain permit application (including a compliance plan) 

under 40 CFR 72 in accordance with the deadlines specified in NDAC 33-15-14-

08.1 and 40 CFR 72.30, including application for permit renewal; and 

b) Submit in a timely manner any supplemental information that the North Dakota 

Department of Health, Division of Air Quality, Air Pollution Control Program 

determines is necessary in order to review an Acid Rain permit application and 

issue or deny an Acid Rain permit. 
Page 42 of 46 

Permit No. T5-F82006 

2) The owners and operators of each affected source and each affected unit at the source 

shall: 

a) Operate the unit in compliance with a complete Acid Rain permit application 

including any application for permit renewal or a superseding Acid Rain permit 

issued by the North Dakota Department of Health, Division of Air Quality, Air 

Pollution Control Program and 

b) Have an Acid Rain permit. 

Applicable Requirement: NDAC 33-15-21-08.1 

B. Monitoring Requirements 

1) The owners and operators and, to the extent applicable, designated representative of each 

affected source and each affected unit at the source shall comply with the monitoring 

requirements as provided in 40 CFR 75 and 76. 

2) The emissions measurements recorded and reported in accordance with 40 CFR 75 shall 

be used to determine compliance by the unit with the Acid Rain emissions limitations and 

emissions reduction requirements for sulfur dioxide and nitrogen oxides under the Acid 

Rain Program. · 

3) The requirements of 40 CFR 75 shall not affect the responsibility of the owners and 

operators to monitor emissions of other pollutants or other emissions characteristics at the 

unit under other applicable requirements of the Federal Clean Air Act and other 

provisions of the operating permit for the source. 

Applicable Requirements: NDAC 33-15-21-08.1, NDAC 33-15-21-09 and 40 CFR 76 

C. Sulfur Dioxide Requirements 

1) The owners and operators of each source and each affected unit at the source shall: 

a) Hold allowances, as of the allowance transfer deadline, in the units compliance 

subaccount (after deductions under 40 CFR 73.34(c)) not less than the total 

annual emissions of sulfur dioxide ·for the previous calendar year from the unit; 

and 

b) Comply with the applicable Acid Rain emissions limitations for sulfur dioxide. 

2) Each ton of sulfur dioxide emitted in excess of the Acid Rain emissions limitations for 

sulfur dioxide shall constitute a separate violation of the Federal Clean Air Act. 

3) Allowances shall be held in, deducted from, or transferred among Allowance Tracking 

System accounts in accordance with the Acid Rain Program. 
Page 43 of 46 

Permit No. T5-F82006 

4) An allowance shall not be deducted in order to comply with the requirements under 

Condition C.(l)(a) of this permit prior to the calendar year for which the allowance was 

allocated. 

5) An allowance allocated by the Administrator under the Acid Rain Program is a limited 

authorization to emit sulfur dioxide in accordance with the Acid Rain Program. No 

provision of the Acid Rain Program, the Acid Rain permit application, this permit, or the 

written exemption under 40 CFR 72.7 and 72.8 and no provision of law shall be 

construed to limit the authority of the United States to terminate or limit such 

authorization. 

6) An allowance allocated by the Administrator under the Acid Rain Program does not 

constitute a property right. 

Applicable Requirements: NDAC 33-15-21-08.1 and 40 CFR 73 

D. Nitrogen Oxides Requirements 

NOx Emission Limitations: The owner or operator shall not discharge, or allow to be discharged, 

emissions ofNOx (annual average basis) to the atmosphere in excess of the following limits: 

Boiler ID 

1 

2 

Emission 

Limitation 

0.40 lb/1 06 Btu 

0.40 lb/1 06 Btu 

The owner/operator shall also comply with the duty under 40 CFR 76.9(d) to reapply for an NOx 

compliance plan prior to expiration of this permit and requirements under 40 CFR 76.13 for 

calculating NOx emissions. 

Applicable Requirements: 40 CFR 76.7(a)(1), 40 CFR 76.9(d), 40 CFR 76.13 

and NDAC 33-15-21-10 

E. Excess Emissions Requirements 

1) The designated representative of an affected unit that has excess emissions of S02 in any 

calendar year shall submit a proposed offset plan, to the Administrator as required under 

40 CFR 77, with a copy to the North Dakota Department of Health, Division of Air 

Quality, Air Pollution Control Program. 

2) The owners and operators of an affected unit that has excess emissions of NOx or S02 in 

any calendar year shall: 

a) Pay to the Administrator without demand the penalty required, and pay to the 

Administrator upon demand the interest on that penalty, as required by 40 CFR 

77; and Comply with the terms of an approved offset plan for S02, as required by 

40 CFR 77. 
Applicable Requirement: NDAC 33-15-21-08.1 

F. Recordkeeping and Reporting Requirements 

Page 44 of 46 

Permit No. T5-F82006 

1) Unless otherwise provided, the owners and operators of the source and each affected unit 

at the source shall keep on-site at the source each of the following documents for a period 

of 5 years from the date the document is created. This period may be extended for cause, 

at any time prior to the end of 5 years, in writing by the Administrator of the U.S. EPA or 

the North Dakota Department of Health, Division of Air Quality, Air Pollution Control 

Program: 

a) The certificate of representation for the designated representative for the source 

and each affected unit at the source and all documents that demonstrate the truth 

of the statements in the certificate of representation, in accordance with 40 CPR 

72.24; provided that the certificate and documents shall be retained on-site at the 

source beyond such 5-year period until such documents are superseded because of 

the submission of a new certificate of representation changing the designated 

representative; 

b) All emissions monitoring information, in accordance with 40 CPR 75; 

c) Copies of all reports, compliance certifications, and other submissions and all 

records made or required under the Acid Rain Program; and, 

d) Copies of all documents used to complete an Acid Rain permit application and 

any other submission under the Acid Rain Program or to demonstrate compliance 

with the requirements of the Acid Rain Program. 

2) The designated representative of an affected source and each affected unit at the source 

shall submit the reports and compliance certifications required under the Acid Rain 

Program, including those under 40 CPR 72, Subpart I, NDAC 33-15-21-08, and 40 CPR 

75. 

Applicable Requirements: NDAC 33-15-21-08.1 and NDAC 33-15-21-09 

G. Liability 

1) Any person who knowingly violates any requirement or prohibition of the Acid Rain 

Program, a complete Acid Rain permit application, this Acid Rain Permit, or a written 

exemption under 40 CPR 72.7 or 72.8, including any requirement for the payment of any 

penalty owed to the United States, shall be subject to enforcement pursuant to Section 

113(c) of the Federal Clean Air Act. 

2) Any person who knowingly makes a false, material statement in any record, submission, 

or report under the Acid Rain Program shall be subject to criminal enforcement pursuant 

to Section 113(c) ofthe Federal Clean Air Act and 18 U.S.C. 1001. 
Page 45 of 46 

Permit No. T5-F82006 

3) No permit revision shall excuse any vioiation of the requirements of the Acid Rain 

Program that occurs prior to the date that the revision takes effect. 

4) Each affected source and each affected unit shall meet the requirements of the Acid Rain 

Program. 

5) Any provision of the Acid Rain Program that applies to an affected source (including a 

provision applicable to the designated represented of an affected source) shall also apply 

to the owners and operators of such source and of the affected units at the source. 

6) Any provision of the Acid Rain Program that applies to an affected unit (including a 

provision applicable to the designated representative of an affected unit) shall also apply 

to the owners and operators of such unit. Except as provided under 40 CFR 72.44 (Phase 

II repowering extension plan) and 40 CFR 76.11 (NOx averaging plans), and except with 

regard to the requirements applicable to units with a common stack under 40 CFR 75 

(including 40 CFR 75.16, 75.17, and 75.18), the owners and operators and the designated 

representative of one affected unit shall not be liable for any violation by any other 

affected unit of which they are not owners or operators or the designated representative 

and that is located at a source of which they are not owners or operators or the designated 

representative. 

7) Each violation of a provision of NDAC 33-15-21-01 through 33-15-21-10 and 40 CFR 

parts 72, 73, 75, 76, 77, and 78 by an affected source or affected unit, or by an owner or 

operator or designated representative of such source or unit, shall be a separate violation 

of the Federal Clean Air Act. 

Applicable Requirements: NDAC 33-15-21-08.1, NDAC 33-15-21-09, and 40 CFR 

73, 76, 77 and 78 

H. Effect on Other Authorities 

No provision of the Acid Rain Program, an Acid Rain permit application, this Acid Rain permit 

condition, or a written exemption under 40 CFR 72.7 or 72.8 shall be construed as: 

1) Except as expressly provided in Title IV of the Federal Clean Air Act, exempting or 

excluding the owners and operators and, to the extent applicable, the designated 

representative of an affected source or affected unit from compliance with any other 

provision of the Federal Clean Air Act, including the provisions of Title I of the Federal 

Clean Air Act relating to applicable National Ambient Air Quality Standards or State 

Implementation Plans; 

2) Limiting the number of allowances a unit can hold; provided, that the number of 

allowances held by the unit shall not affect the source's obligation to comply with any 

other provisions ofthe Federal Clean Air Act, 

3) Requiring a change of any kind in any State law regulating electric utility rates and 

charges, affecting any State law regarding such State regulation, or limiting such State 

regulation, including any prudence review requirements under such State law; 
Page 46 of 46 

Permit No. T5-F82006 

4) Modifying the Federal Power Act or affecting the authority of the Federal Energy 

Regulatory Commission under the Federal Power Act; or, 

5) Interfering with or impairing any program for competitive bidding for power supply in a 

State in which such program is established. 

Applicable Requirement: NDAC 33-15-21-08.1 

I. · Permit Shield 

Each affected unit operating in accordance with this permit which is issued in compliance with 

Title IV of the Federal Clean Air Act, as provided in 40 CFR 72, 73, 75, 77 and 78, and the 

regulations implementing Section 407 of the Federal Clean Air Act, shall be deemed operating in 

compliance with the Acid Rain Program, except as provided in 40 CFR 72.9(g)(6). The permit 

shield does not take effect until the effective date of the acid rain permit. 

Applicable Requirements: NDAC 33-15-21-08.1, NDAC 33-15-21-09, and 40 CFR73, 77 

and 78 

J. Reopening for Cause 

In addition to any reasons for reopening for cause previously stated in this permit, the 

Department will reopen and revise this permit as necessary to remedy deficiencies in the 

following circumstance: If additional requirements, including excess emissions requirements, 

become applicable to an affected source under Title IV of the Federal Clean Air Act or the 

regulations promulgated there under. Upon approval by the administrator of the United States 

Environmental Protection Agency, excess emissions offset plans shall be deemed to be 

incorporated into the permit. 

Applicable Requirements: NDAC 33-15-14-06.6.f(l)(b) and 40 CFR 70.7(f)(l)(ii) 
Attachment A 

Compliance Assurance Monitoring (CAM) Plan 

(EU 1 and 2) 
Attachment A 

Compliance Assurance Monitoring (CAM) 

Protocol for Particulate Mass Emissions 

Coal Creek Station 

Boilers 1 and 2 

Great River Energy 

12300 Elm Creek Blvd. 

Maple Grove, MN 55369-4718 

Revision Date 

January 9, 2014 
COMPLIANCE ASSURANCE MONITORING PROTOCOL 

ELECTROSTATIC PRECIPITATOR (ESP) AND SPRAY TOWER SCRUBBER 

FOR PARTICLE MASS EMISSIONS CONTROL 

I. Background 

A. Emissions Units 

Description/ 

Identification: 

Facility: 

Unit 1:6,015 mmBtulhrlignite-fired boiler 

Unit 2: 6,022 mmBtulhr lignite-fired boiler 

Coal Creek Station 

Underwood, ND 

B. Applicable Regulation, Emissions Limit, and Monitoring Requirements 

Regulations: NDAC § 33-15, Permit to Construct (PTC) 

Emissions Limits (both units): 

Particulate 

Matter (PM): (1) 0.10 lb/mmBtu [NDAC 33-15-12,Subpart D] 

(2) 528 lblhr [PTC Condition 1

] 

Current Monitoring 

Requirements: 

C. Control Technologies 

II. Monitoring Approach 

Continuous Opacity Monitoring (COM) and 

Periodic compliance testing 

(1) Electrostatic precipitator (each unit) 

(2) Spray tower scrubber (each unit) 

The key elements of the monitoring approach, including the indicators to be 

monitored, indicator ranges, and performance criteria are presented in Table 1. 

The primary performance indicator is the measured opacity from the continuous 

opacity monitoring system (COMS) on the stack of each unit. This CAM Plan 

does not apply to units continuously monitoring particulate emissions. 

1 The PTC "lblhr" limit is based on estimated boiler heat input and NDAC 33-15-12,Subpart D "lb/mmBtu" 

limit. 
III. Corrective Action 

The key elements of the corrective action procedures are presented in Table 2. 

Corrective action is designed to discover and correct the problem that is creating 

the opacity increase. Corrective action is initiated before an excursion has 

occurred and continues until the potential excursion condition has been rectified. 

The trigger point that initiates corrective action is consecutive stack opacity 

greater than 20 percent based on a six-minute average, excluding those events 

defined as startup/shutdown and malfunctions. Initiation of corrective action does 

not create a reporting requirement. 

2 
Table 1. Monitoring Approach 

Compliance Indicator 

I. Indicator Stack opacity. 

Measurement Approach The opacity is measured using a Continuous Opacity Monitoring System 

stack of each boiler. 

II. Indicator Range An excursion is defined as a measured stack opacity greater than 20 per

three-hour rolling average, excluding those events defined as startup/shu

malfunctions. An excursion triggers a reporting requirement. 

Corrective action must be initiated when consecutive measured stack op

averages are greater than 20 percent excluding those events defined as s

malfunctions. Corrective action does not trigger a reporting requirement

III. Performance Criteria 

A. Data Representativeness Opacity is related to the size and concentration of particles in the flue ga

mass emissions increase, it can be reasonably expected that stack opacit

Each boiler discharges to a single, dedicated stack. Each stack is equipp

meets the installation and minimum acceptable accuracy requirements o

Performance Specification 1. The COMS is located downstream of the s

and, therefore, reflects the performance of both control devices and scru

operation. 

B. Verification of Operational Not applicable. Monitoring approach uses existing equipment. 

Status 

C. QAIQC Practices and Daily zero and calibration drift check, periodic cleaning of optical surfa

Criteria periodic QA/QC checks as specified in the applicable version of Perform

1. 

D. Monitoring Frequency Continuous. 

Data Collection Procedures The COMS collects a data point every 10 seconds and the datalogger re

minute averages and three-hour rolling averages. 

A Three-hour an average f

3 
Table 2. Corrective Action Procedures Summary 

Description 

I. Initiation of Corrective Action Corrective action shall be initiated when consecutive six-minute 

Procedures exceeds 20 percent. The plant staff that made the discovery shal

the shift team leader, plant environmental coordinator, and air co

II. Time of Completion of Corrective As soon as practically possible. 

Action Procedures 

Ill. Corrective Action Description Figure 1 provides a flow chart summarizing the corrective action 

the ESPs provide the bulk of the particulate emissions removal, 

focus on ESP operation. 

Corrective action will begin with an inspection ofthe COMS. Pl

verify the opacity monitor readings, to the extent possible, in the 

COMS malfunction. If it is determined that the opacity monitor 

plant staff must then verify whether or not saturated flue gas con

stack by observing stack temperature. If saturated stack conditio

must increase scrubber bypass such that stack temperature incre

If saturated stack conditions are not present, corrective action wi

Corrective action will include inspection of one or more ESPs, i

evaluation of the ash removal and rapper systems. Corrective ac

one or more of the following to reduce opacity below the trigger 

(1) Return tripped ESP sections to service 

(2) Increase power levels on remaining, in-service sec

possible) 

(3) Reduce unit load (if absolutely necessary) 

- - - -------------- -- - --------------------

4 
Has opacity 

trigger been 

exceeded for 

Is COMS 

Yes 

Perfonn an inspection of one or more ESPs, 

including an evaluation of the ash removal 

and rapper systems. 

Corrective action may also include one or 

more of the following: 

(1) Returning tripped ESP sections to 

nonnal operation 

(2) Increasing ESP power on remaining inservice sections (to the extent possible) 

(3) Load reduction, if absolutely necessary 

No 

No 

No 

No action required 

RepairCOMS 

Increase scrubber 

bypass (to the extent 

possible) 

Has opacity 

trigger been 

exceeded for 

three or more 

hours? 

Report 

excursion. 

Figure 1. Coal Creek Station CAM Corrective Action Procedures 

5 
MONITORING APPROACH JUSTIFICATION 

I. Background 

Coal Creek is a mine-mouth plant adjacent to the Falkirk Coal Mine in Underwood, ND. 

Units 1 and 2 are tangentially fired boilers that discharge through separate, dedicated 

stacks. Unit 1 has a rated heat input of 6,015 mmBtu/hr. Unit 2 has a rated heat input of 

6,022 mmBtu/hr. Both units bum lignite coal as their primary fuel and Number 2 fuel oil 

for unit start-up and flame stabilization. Both boilers are subject to SIP limits (North 

Dakota Administrative Code§ 33-15-12, Subpart D and Permit to Construct conditions) 

for particulate matter. Units 1 and 2 have particulate mass limits of 0.10 lb/mmBtu and 

528 lb/hr. The units also have a stack opacity limit of 20 percent, excluding periods of 

startup and shutdown. 

Particulate emissions from each boiler are controlled by two ESPs, located downstream 

of the air heater in a side-by-side configuration. Each ESP is six fields deep in the 

direction of gas flow and four sections across. The combined specific collection area for 

the ESPs is 600 fe/1000 acfm. Neither unit has bypass capabilities for the ESPs. 

Each unit is also equipped with a spray tower, flue gas desulfurization system 

downstream of the ESP for the control of S02 emissions. Each scrubber is designed to 

remove up to 90 percent of the S02 from the treated gas. The scrubbers can treat up to 70 

percent ofthe boiler gas flow. The remainder of the gas, which bypasses the absorbers, is 

used for reheating the gas leaving the absorbers and is controlled by bypass damper 

position. Although the primary function of the control device is S02 control, the scrubber 

does provide some additional particulate removal. Scrubber operation is automatically 

controlled based on boiler load and is relatively constant at normal, full load. Stack 

temperature is normally well above saturation. 2 Operating experience has shown that 

during periods of maximum scrubbing, stack temperature is still above saturation. 

Each stack is equipped with an existing Continuous Opacity Monitoring System 

(COMS), as required by NDAC § 33-15-03-02 and§ 33-15-12, Subpart D. Currently, 

both units must be tested annually for compliance with particulate mass emissions limits. 

There are no direct, continuous particulate monitoring requirements on either of the units. 

The most recent particulate compliance test, conducted during September 2002, 

demonstrated a particulate mass emission rate of0.08lb/106 Btu for Unit 1 and 0.05 

lb/1 06 Btu for Unit 2. Recent testing suggests that both units are able to meet their 

particulate mass emissions limits without the operation of the scrubber. 

GRE voluntarily implements a rigorous maintenance program at Coal Creek that is 

designed to maintain optimal performance of the ESPs. The maintenance program 

includes a series of daily, weekly, monthly, quarterly, and annual inspections of the 

equipment. Additional inspections are conducted during major outages. The details of 

these inspections are periodically adjusted based on GRE's engineering judgement ofthe 

2 The stack temperature for Units 1 and 2 during normal operation is between 180 and 190 degrees F. This 

is well above stack saturation. 

6 
mechanical condition of each control device. Examples of the tasks involved with these 

inspections are as follows: 

Daily Inspections - Inspection procedure may include a check of the ash handling 

system operation, verification of rapper and voltage controller operation, and/or 

an inspection of alarm status and shift logs to identify potential operating 

problems. 

Weekly Inspections - Inspection procedure may include checks of the primary 

voltage and current readings, verification of rapper control systems and operation 

of rapper drive motors, and/or checks of the transformer-rectifier coolant levels. 

Monthly Inspections- Inspection procedure may include a check of the penthouse 

air conditioning system. 

Quarterly Inspections - Inspection procedure may include verification of the 

automatic voltage controller cabinet ventilating fan operation, cleaning of the 

control cabinet air filters and/or ventilating fans, and/or verification of ash hopper 

level indicators. 

Annual Inspections- Inspection may include a thorough maintenance routine of 

penthouse air conditioning system. 

Outage Inspections - Inspection procedure may include internal checks for close 

clearances between discharge electrodes and collecting plates, checks of rapper 

hammers for wear and/or breakage, verification of hammer and anvil alignment, 

checks of the rapper drive insulators and drive shafts, and/or checks of the internal 

structure for signs of deterioration or leakage. 

II. Rationale for Selection of Performance Indicators and Indicator Ranges 

The purpose of this section is to provide technical justification in support of a compliance 

assurance protocol based on opacity known as "test and cap." Under a test and cap 

approach, the relationship of stack opacity to particulate mass concentration is 

determined at or very near the opacity limit. If the mass concentration is below the permit 

limit, then two opacity trigger points are set at this level. The first trigger point is the 

threshold at which corrective action is to be performed. This trigger point indicates that 

the control device may not be operating properly and action should be taken to restore 

normal operation. The second trigger point defines an excursion. This trigger point is set 

at the opacity limit as well but has a longer averaging period and causes a reportable 

event under CAM. 

The COMS will be used as the primary indicator for each unit at Coal Creek. The 

selected indicator range will be the existing stack opacity limit of 20 percent. Corrective 

action will be initiated when consecutive six-minute average stack opacity exceeds 20 

percent. As described in Table 2, corrective action begins with an evaluation of the 

7 
occurrence to determine the action required to correct the situation. Consecutive sixminute opacity averages that initiate corrective action do not have to be reported under 

CAM (the second six-minute average would be reported according to the NSPS 

standards). An excursion is defined as a three-hour opacity average of 20 percent or 

higher, excluding startup/shutdown and malfunction events. All excursions will be 

documented and reported on a unit-basis including the associated corrective action. 

Opacity Monitor Theory of Operation 

All opacity monitors operate under a physics principle known as optical extinction. In a 

basic configuration, a beam of light of a specific wavelength is transmitted across a 

particulate-laden fluid flow. A receiver at some distance from the transmitter measures 

the amount of light that is received. Due to reflection and refraction of the light beam by 

the particles within the fluid, the amount of light reaching the receiver will be less than 

the beam's initial intensity. This property is referred to as transmittance and is 

represented by the following equation: 

Opacity is related to transmittance by the following equation: 

0=1-T 

The physics of the opacity meter are based on Lambert's Law, which can be expressed 

mathematically by the following equation: 

Where: 

-SmgmmgX 

0=1-e 4 

0 = opacity of flue gas . 

Savg =specific surface area of the particles (m2/g) 

mavg = particulate mass concentration (g!Nm3

) 

x =optical path length (m) 

For a coal-fired boiler equipped with an ESP operating under normal load, the particle 

size distribution and specific surface area of the particles will remain relatively similar. 

This means that any change in opacity, as a first-order approximation, will be directly 

proportional to the mass concentration. 3 Therefore, while opacity is not a direct 

measurement of particulate mass, it can be used as a surrogate. If opacity is increasing, it 

can be reasonably expected that the particulate mass concentration is also increasing. 

Scrubber Issues 

Although the primary function of the scrubbers at Coal Creek is S02 removal, particulate 

removal is a secondary effect of the scrubbing process. For configurations where a wetimpingement scrubber is downstream of an ESP, like Coal Creek, additional particulate 

3 Parker, K.R., Applied Electrostatic Precipitation 

8 
removal by the scrubber is relatively small because of the device's low collection 

efficiency of fine particles. This is exacerbated by the fine particle size distribution of the 

flue gas exiting the ESP. As a result, under normal operation the ESP will remove most 

of the particulate matter. This is confirmed by previous test data, which suggest that the 

scrubbers at Coal Creek are not required to meet the particulate emissions limit. 4 Because 

of their relative importance to particulate removal, corrective action procedures will focus 

on the ESPs. 

The injection of the lime slurry into the flue gas stream from the scrubbing process 

provides sensible cooling of the flue gas. Gas temperature decreases while relative 

moisture content increases. The flue gas is further cooled in the ductwork leading to the 

stack and within the stack itself. Excessive scrubbing can decrease flue gas temperature 

to the point where the gas becomes saturated. Under these saturated conditions, water 

vapor molecules interfere with the operation of the COMS, thereby producing 

excessively high opacity measurements. Flue gas temperatures suggest that this is not a 

problem for either unit at Coal Creek. Both stacks operate well above saturation during 

normal load. 5 At maximum scrubbing condition, the stacks still operate above saturation. 

Scrubber operation is controlled based on generator load and is relatively constant. As a 

result, stack temperatures are also relatively constant. Given the possibility that saturated 

stack conditions may occasionally cause false excursions, part of the initial corrective 

action procedure is to check for saturated stack conditions and adjust scrubber bypass as 

necessary to increase temperature above saturation. 

The scrubber does not impose any additional restrictions on the application of a test and 

cap monitoring approach. Under §64.4(g) of the CAM rule, sources may apply a single 

monitoring approach to multiple control devices. Use of the existing COMS as the 

compliance indicator for CAM is valid because it reflects the performance of both control 

devices. If the ESP or scrubber fail for any reason, the net effect will be the same - an 

increase in opacity and particulate emissions. Furthermore, the COMS will automatically 

account for the changes in opacity as a result of scrubber bypass operation, thereby 

fulfilling the bypass monitoring requirements of §64.3(a)(2). 

4 A Study ofToxic Emissions from a Coal-Fired Power Plant Utilizing an ESP/Wet FGD System, U.S. 

Department of Energy, 1992. 

5 Flue gas temperature is typically above 180° F during normal operation. 

9 
Opacity and CAM 

Developing an accurate correlation between opacity and particulate mass is difficult, if 

not impossible, because ofthe variability in the process factors that affect the particle 

properties and size distribution. For CAM, however, it is sufficient that the indicator and 

emission rate are related so as to provide a reasonable assurance of compliance. The 

previous section on opacity measurement principles demonstrates this relationship. 

Furthermore, the use of opacity as a CAM indicator for particulate mass, with the existing 

opacity limit as the indicator range, is considered presumptively acceptable under 

§64.3(d), provided there are sufficient data to show that this indicator range is 

appropriate. 

Verification of Opacity/Mass Relationships 

Particulate mass emissions tests were conducted at the stack of each unit to validate the 

selection of the monitoring approach and indicator range. The objective of the testing was 

to derive the opacity/mass relationship for each unit and show that while opacity is 

maintained at or below the current opacity limit, both units also demonstrate a reasonable 

assurance of compliance with the particulate mass limits. Testing was conducted on Units 

1 and 2 beginning June 16, 2003, through June 21, 2003. Additional details on the results 

of the particulate testing can be found in the final test report. 6 

The test program was designed to simulate boiler and control device operation under the 

normal or "baseline" operating condition and under two additional conditions that 

simulated varying degrees of control device failure. Since the ESPs are the primary 

particulate control devices for both units and the most likely cause of any excursions, 

tests simulating control device failures were conducted only for the ESPs. Both scrubbers 

were under normal, steady-state operation for the duration of each test. Any change in 

stack opacity and particulate mass emissions was attributed to the operation of the ESPs. 

The most common types of ESP failure (or cause of reduced performance) are either 

grounded fields or close clearances. In order to simulate these conditions, the ESP of the 

tested unit was "de-tuned" by reducing and/or eliminating power to selected portions of 

the precipitator. This effectively increases the particulate mass loading and opacity at the 

stack. These "de-tuned" tests included a "high-level" test, where the stack opacity was 

close to the 20 percent limit, and a "mid-level" test where the stack opacity is 

approximately halfway between the high-level test and the normal operating duct opacity. 

For each test, boilers were operated at normal full load. This represents the highest level 

of particulate mass emissions and will produce conservative indicator ranges under the 

proposed CAM monitoring approach. Each test consisted of three runs using EPA 

Reference Method 17. Boiler, scrubber and ESP operating data were also taken to 

demonstrate stable, normal load operation during each test. 

6 Compliance Assurance Monitoring Performance Testing, Coal Creek Station, Units 1 and 2, RMB 

Consulting & Research, 9/19/03. 

10 
Unit 1 Results 

Table 1 shows a summary of the test results for Unit 1. For the baseline condition, the 

data show an opacity of two percent and particulate emissions rates of0.003 lb/mmBtu 

and 18 lb/hr. This suggests that Unit 1 operates at less than five percent of its mass limit 

during normal operation. 

Test Condition 

Baseline 

ESP "De-tuned" (Mid) 

ESP "De-tuned" (High) 

Stack, 

Opacity 

2 

12 

17 

Particulate 

Mass Emissions 

[lb/mmbtu] 

0.003 

0.032 

0.038 

Table 3. Unit 1 CAM Test Results 

Particulate 

Mass Emissions 

[lblhr] 

18 

196 

229 

For the "de-tuned" tests, Unit 1 boiler was operating under steady, normal load and the 

ESP power levels where reduced to simulate control device failure. For the "mid-level" 

condition, the data show an opacity of 12 percent and particulate mass emissions rates of 

0.032 lb/mmBtu and 196 lb/hr. For the "high-level" condition, the data show an opacity 

of 17 percent and particulate mass emissions rates of0.038lb/mmBtu and 229lb/hr. 

Figures 2 and 3 show graphs of the opacity/unit mass relationships for Unit 1 including 

the baseline and de-tuned operating conditions. Based on a four-point linear regression, 

the predicted mass emissions rates at 20 percent opacity are 0.049lb/mmBtu and 296 

lb/hr. The data suggest that, under t~is "worst-case" scenario, the particulate mass 

emissions are approximately 50 percent of the mass emissions limits. This suggests a 

relatively large compliance margin for CAM. 

30 --· 

25 

nit I assE nissio s@2 %=C .0491 mmBu 20 

// 

• 15 

// De-tL edC nditio s 

• 10 

/ 

slseline ondit on 

t' 

0.00 0.01 0.02 0.03 0.04 0.05 0.06 0.07 0.08 0.09 0.10 0.11 0.12 0.13 0.14 0.15 

Particulate Mass Emlsstons Rate (lblrmtBtu] 

Figure 2. Unit 1 Opacity/Mass Relationship [lb/mmBtu] 

11 
30 

I 25 

I 

Unit I Ma Emissions @ 2 %= 296lb/hr I 

~ I ! 

/ De-tuned onditions 

~ I 

/ 

20 

15 

10 

/ /'•sel ~e Condition 

100 200 300 500 600 

Partlculale Mass Emissions Rate [lblhr] 

Figure 3. Unit 1 Opacity/Mass Relationship [lb/hr) 

Unit 2 Results 

Table 4 shows a summary of the test results for Unit 2. For the baseline condition, the 

data show an opacity of five percent and particulate emissions rates of 0.004 lb/mmBtu 

and 18 lblhr. This suggests that Unit 2 also operates at less than five percent of its mass 

limit during normal operation. 

Particulate Particulate 

Stack Mass Emissions Mass Emissions 

Test Condition OQaci~ [lb/mmbtu] [lb/hr] 

Baseline 5 0.004 28 

ESP "De-tuned" (Mid) 14 0.023 151 

ESP "De-tuned" (High) 18 0.040 354 

Table 4. Unit 2 CAM Test Results 

For the "de-tuned" tests, Unit 2 boiler was operating under steady, normal load and the 

ESP power levels where reduced to simulate control device failure. For the "mid-level" 

condition, the data show an opacity of 14 percent and particulate mass emissions rates of 

0.023 lb/mmBtu and 151 lblhr. For the "high-level" condition, the data show an opacity 

of 18 percent and particulate mass emissions rates of 0.040 lb/mmBtu and 354 lblhr. 

Figures 4 and 5 show graphs of the opacity/unit mass relationships for Unit 2 including 

the baseline and de-tuned operating conditions. Based on a four-point linear regression, 

the predicted mass emissions rates at 20 percent opacity are 0.040 lb/mmBtu and 341 

lblhr. The data suggest that, under this "worst-case" scenario, the particulate mass 

emissions are less than 50 percent of the "lb/mmbtu" mass emissions limit and less than 

65 percent of the "lblhr" emissions limit. 

12 
30 

25 

nit 2 assE nissio s@2 o/o= .0401 /mmn Btu 

20 

L; ned( pnditi ns 15 

I 10 

I I 

I 

1/ Baseti eCo dition 

0.00 0,01 0.02 0.03 O.G4 0.05 0.06 0.07 0.08 0.09 0.10 0.11 0.12 0.13 0.14 0.15 

ESP Outlet Particulate Mass Concentration JlblmmBtu) 

Figure 4. Unit 2 Opacity/Mass Relationship [lb/mmBtu] 

30 

25 I 

i 

I 

Unit 2M'" Emissions@ 2 % = 341 lb/hr 

20 J 

i / • I De-t ned Conditiops' 

/ I 

• ./.// 

/ I 

/ 

15 

10 

v· e LOOO!tiOO 

I 0 

0 100 200 300 400 500 600 

Particulate Mass Emissions Rate [lb/hr) 

Figure 5. Unit 2 Opacity/Mass Relationship [lb/hr) 

Monitoring Approach Validity 

The test data show that the opacity/mass relationships support the proposed test and cap 

approach using the COMS as the primary indicator with a trigger level of20 percent for 

both corrective action and excursions. In all cases, the opacity/mass relationships 

predicted mass emissions that were below the mass limits of each unit at 20 percent 

opacity. This suggests that the selected indicator and indicator range meet the general 

design criteria outlined in §64.3(a) of the CAM Rule and will be sufficient to demonstrate 

a reasonable assurance of compliance during normal operation of each unit. 

13