# Exhibit 8

## Technical Support Document, Permit Action Number: 03700003

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Date: 4/1/2014 

## TECHNICAL SUPPORT DOCUMENT

For

AIR EMISSION PERMIT NO. 03700003

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This technical support document (TSD) is intended for all parties interested in the permit and to meet the

requirements that have been set forth by the federal and state regulations (40 CFR § 70.7(a)(5) and Minn. R.

7007.0850, subp. 1). The purpose of this document is to provide the legal and factual justification for each applicable

requirement or policy decision considered in the determination to issue the permit.



# 1. General Information

1.1 Applicant and Stationary Source Location:

Table 1. Applicant and Source Address

Applicant/Address Stationary Source/Location

(SIC Code: 4911)

Northern States Power Company, a Minnesota Corporation

414 Nicollet Mall

Minneapolis, MN 55401 Xcel Energy ‐ Black Dog Generating Plant

1400 East Black Dog Road

Burnsville, MN 55337

Dakota County

Contact: Jonathan Amos

Phone: 612

‐ 330

‐ 7628

1.2 Facility Description

The Black Dog Generating Plant (Black Dog) is a steam

‐ electric generating facility. The facility is composed of two

coal

‐ fired boilers and a natural gas

‐ fired combined cycle gas turbine with duct burner. In addition, there are

numerous coal and ash handling equipment that primarily emit Particulate Matter (PM, PM 10 

## , PM 2.5 

## ).

Coal boiler particulate matter emissions are controlled by electrostatic precipitators and coal handling particulate

emissions are controlled by fabric filters. Fugitive emissions are controlled by dust suppression using water spray,

dust suppression chemical spray, or partial enclosures. The gas turbine nitrogen oxide emissions are controlled by dry

low

‐ NO X 

## combustion and selective catalytic reduction. There are also two emergency generators, and the Permittee

is authorized to bring a temporary emergency engine on

‐ site, as needed.

1.3 Description of the Activities Allowed by this Permit Action

At the time of permit issuance, Xcel Energy has stated their intent to discontinue coal combustion at the facility, prior

to the compliance date of the NESHAP for Coal
‐ and Oil

‐ Fired Electric Utility Steam Generating Units. The permit does

not require this discontinuation; if coal combustion is continued, the coal

‐ fired boilers will be subject to the NESHAP

as of the compliance date listed in the standard, and the Permittee will be required to apply for a permit amendment

to incorporate all applicable requirements of the NESHAP. See Section 2.4 of this document for further information

on the applicability of the NESHAP standard, and see Subject Item GP002 of the permit for what is required of the

Permittee.

No other specific changes to the facility were requested or are authorized through this permit action. However two

additional permit actions are incorporated into this permit:

1. A Notice of Compliance (NOC) issued for an August 13, 2008, performance test on Boilers 3 and 4 (EU003 and
EU004) requires a specific “minimum number of fields on line” for CE006/CE007 and CE008/CE009. This was

effective on the date of the NOC, and required to be incorporated into the next permit action, which is this

one.

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## 2. The Permittee submitted an administrative amendment application to extend a performance test deadline for

SV020. The test was originally due before June 30, 2012; an extension until October 30, 2012 was requested.

The request was appropriate and the test was completed in August 2012. Because this action took place

during the term of the previous permit (03700003

‐ 009), nothing is required through this permit, other than to

close out the application.

1.4. Facility Emissions:

Table 2 documents the permitted potential to emit at the time of permit issuance (i.e., including coal combustion).

Table 3 documents the facility classification relative to Part 70, New Source Review, and National Emission Standards

for Hazardous Air Pollutants.

Table 2. Total Facility Potential to Emit Summary

PM

tpy PM 10 

## tpy PM 2.5 

## tpy SO 2 

## tpy NO

x 

## tpy CO

tpy CO 2 

## e

tpy VOC

tpy Single

HAP

tpy All

HAPs

tpy

Total Facility Limited

Potential Emissions 4609 4175 4119 17,480 14,650 1550 3,864,000 71 25 49

Total Facility Actual

Emissions (2012) 254 248 80 2796 6056 450 1.59 x 10 6 

## 24 NR*



## *NR = Not Reported in MN emission inventory.

Table 3. Facility Classification

Classification Major/Affected Source Synthetic Minor/Area Minor/Area

PSD X

Part 70 Permit Program X

Part 63 NESHAP X



## 1.5 Other Changes to Permit

The MPCA has a combined operating and construction permitting program under Minnesota Rules Chapter 7007, and

under Minn. R. 7007.0800, the MPCA has authority to include additional requirements in a permit. Under that

authority, the following changes unrelated to any specific facility modification are also made through this permit

action:

 updated to reflect current MPCA templates and standard citation formatting;

 completed requirements and the requirements for equipment that has been removed have been deleted;

 Subpart Da PM and opacity limits were removed from the requirements of EU027 (duct burners), because

Subpart Da was modified such that a gas fired burner that does not use post

‐ combustions controls for PM is

not subject to those standards (40 CFR § 60.42Da(b)(2) and (f)(1));

 Language regarding non

‐ road engines was added to the permit (see Section 2.11 of this TSD);

 All requirements related to handling and use of petroleum coke were removed from the permit;

 Language allowing temporary replacement of emergency generators has been added to the permit;

 some requirements have been reordered to help with clarity (i.e., similar requirements are grouped, some

items previously at SV level moved to GP to accommodate inclusion of MR and CE as associated items); and

 CAM has been added as discussed in Table 4 of this TSD.

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# 2. Regulatory and/or Statutory Basis

2.1 New Source Review

The facility is an existing major source under New Source Review regulations. No changes are authorized by this

permit.

2.2 Part 70 Permit Program

The facility is a major source under the Part 70 permit program.

2.3 New Source Performance Standards (NSPS)

Boilers

The boilers (EU003 and EU004) were installed prior to 1971, and are therefore not subject to any New Source

Performance Standards. However, the duct burner (EU027), having a rated heat input of greater than 250 MMBtu

hour and installed after 1978, is subject to the requirements of 40 CFR Part 60, Subpart Da —Standards of

Performance for Electric Utility Steam Generating Units

Combustion Turbine

The combustion turbine (EU026) has a heat input at peak load greater than 10 MMBtu/hour and was constructed

after October 3, 1977, making it subject to 40 CFR Part 60, Subpart GG

– Standards of Performance for Stationary Gas

Turbines.

Coal Handling

The yard agglomerator silo (EU007, installed in 1992) was constructed after 1974, making it subject to the opacity

requirements of 40 CFR Part 60, Subpart Y

– Standards of Performance for Coal Preparation and Processing Plants.

Engines/Generators

The two emergency generators (EU024 and EU025) and the fire pump engine (EU028) were all installed prior to the

applicability dates of 40 CFR Part 60, Subparts IIII or JJJJ. The engines and fire pump are not subject to NSPS

requirements.

2.4 National Emission Standards for Hazardous Air Pollutants (NESHAP)

The facility is a major source of HAP.

Engines

EU028 is an existing emergency engine less than 500 hp located at a major source of HAP. As such, it is subject to the

requirements of 40 CFR Part 63, Subpart ZZZZ

– National Emissions Standards for Hazardous Air Pollutants for

Stationary Reciprocating Internal Combustion Engines.

EU024 and EU025 are existing emergency stationary RICE greater than 500 hp located at a major source of HAP, and

therefore are not required to meet the requirements of Subpart ZZZZ or Subpart A (40 CFR § 63.6590(b)(3)(iii)).

However, to qualify as “existing emergency RICE” the engines must operate according to the conditions of 40 CFR §
63.6640(f)(2).

Boilers

EU003 and EU004 are currently coal

‐ fired units. 40 CFR Part 63, Subpart UUUUU

– National Emission Standards for

Hazardous Air Pollutants: Coal
‐ and Oil

‐ Fired Electric Utility Steam Generating Units (also known as MATS) requires
compliance with the standard by April 16, 2015. However, the Permittee has stated that their intent is to discontinue

use of coal so that they are not defined as a coal
‐ or oil

‐ fired EGU as of that date. Therefore, the permit does not

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## include Subpart UUUUU requirements at this time. The facility is only required to submit an initial notification if they

anticipate being subject to the standard. At this time, that is not the case.

2.5 Acid Rain Program

The boilers (EU003 and EU004) and the Combustion Turbine (EU026) are subject to SO 2 

## Acid Rain requirements. As

such, the Permittee is required to maintain records of SO 2 

## emissions, ensuring that SO 2 

## emissions for a given year do

not exceed emissions from the previous year.

The boilers are also subject to the NO X 

## requirements under the Acid Rain program, and are subject to NO X 

## limits.

2.6 National Ambient Air Quality Standards (NAAQS)

The existing permit included an appendix (Appendix B) of modeling parameters for NO X 

## and PM 10 

## modeling that was completed as a condition of the initial Title V permit (permit 03700003

‐ 001, issued 8/13/1999). The modeled

parameters and assumptions and MPCA approval documents are still included in the permit, but were moved to
Appendix D. The original permit language required submittal to the MPCA for any changes that were proposed at the
facility. The permit language was updated to the current template language used when modeled concentrations are

in excess of 90% of the NAAQS, when the permit contains PSD limits for the pollutants in question. This is essentially

the same requirement as in the existing permit. No additional modeling is being required at this time, because no changes triggering preconstruction review are permitted, and the facility intends to discontinue coal combustion by

2015.

2.7 Compliance Assurance Monitoring (CAM)

The table below lists the sources which are subject to CAM, whether the source is a large pollutant specific emission

unit (PSEU), and the monitoring for the applicable pollutants.

Table 4. CAM Summary

PSEU Control CAM Applicability Pollutant Monitoring

EU026 CE032 Selective Catalytic Reduction Large NO X 

## NO X 

## CEMS

EU003 CE006 + CE007 ESPs in series Large PM COMS

EU004 CE008 + CE009 ESPs in series Large PM COMS



## For large pollutant specific emission units, records of the monitored parameter must be made at a minimum of 4

times per hour, or once every 15 minutes. For other PSEUs (not large), records must made at a minimum of once per

24 hours. See Attachment 3 to this document for the facility’s CAM Plans.

2.8 Clean Air Interstate Rule (CAIR) / Transport Rule (TR) NO X 

## Annual Trading Program [also known as the

Cross

‐ State Air Pollution Rule (CSAPR)]

Black Dog was subject to CAIR when it was initially promulgated. However, several actions have taken place resulting

in CAIR no longer being an applicable requirement:

 November 3, 2009

– Applicability of CAIR was stayed in Minnesota as of December 3, 2009, except as

described in 40 CFR § 52.1240(b). (40 CFR §§ 51.123(a)(3), 51.124(a)(2), 51.125(a)(3), 52.35(e))

 August 8, 2011

– 40 CFR §§ 52.1240(c) and 52.1241(c) were promulgated, replacing CAIR with TR/CSAPR.

 December 30, 2011

– Applicability of TR/CSAPR was stayed by the United States Court of Appeals, and EPA

was ordered to go back to CAIR.

The stay of CAIR in Minnesota required sources to hold NO X 

## as NO 2 

## allowances equivalent to their initial allocation.

EPA was to deduct and terminate these allowances. The CAMD records now show that zero CAIR NO X 

## as NO 2

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## allowances are held by Minnesota sources, as allowances have been deducted for program termination. The stay of

CAIR in Minnesota continues to be in effect and therefore, no CAIR or CSAPR applicable requirements remain for this
facility, at this time.

2.9 Minnesota Statutes for Public Utilities Mercury Emission Reduction

Minn. Stat. §§ 216B.68 to 216B.688 establishes a mercury emission reduction goal for “targeted units” located at a “qualifying facility.” By definition, a “targeted unit” is a coal

‐ fired boiler greater than 100 MW located at a “qualifying
facility;” a “qualifying facility” is an electric generating facility having generating capacity greater than 500 MW from

all coal

‐ fired generating units at the facility. The provisions establish a process for achieving a goal of reducing

mercury emissions by 90%. The Black Dog facility is a not “qualifying facility” because the total generating capacity of

all of the coal fired units (EU003 and EU004) is less than 500 MW. Therefore, the mercury reduction statutes do not apply.

2.10 Minnesota State Rules

Portions of the facility are subject to the following Minnesota Standards of Performance:

 Minn. R. 7011.0510 Standards of Performance for Existing Indirect Heating Equipment

 Minn. R. 7011.0715 Standards of Performance for Post

‐ 1969 Industrial Process Equipment

 Minn. R. 7011.1105 Standards of Performance for Certain Coal Handling Facilities

 Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines

2.11 Nonroad Engines

Engines that qualify as “nonroad engines” under 40 CFR § 1068.30 are not considered to be part of the stationary

source. Part of the criteria qualifying an engine as a nonroad engine is that it not be used or intended to be used in a single specific location for 12 or more consecutive months. The key word in this is the word “used,” which means that

a stored engine (i.e., one that is not in use) is not subject to the threshold of being in a single location for 12 months.

This clarification is also made in the permit, and is the reason for including the information from 40 CFR § 1068.31(e)

describing when a nonroad engine becomes a stationary engine subject to permitting.

Table 5. Regulatory Overview of the Facility

Item Applicable Regulations Comments:

GP001 (engines

EU024 and
EU025) Title I limit to avoid 40 CFR §

52.21 Hours of operation limit, set in a previous permit action, for

the 2 engines combined

Limit set on annual NO X 

## emissions, set in a previous permit

action, from the 2 engines combined

Conditions governing replacement of engines with temporary

units

Minn. R. 7011.2300 Minnesota Standards of Performance for Stationary Internal

Combustion Engines

GP002 (boilers

EU003 and
EU004) National Ambient Air Quality

Standards (NAAQS) Limits on PM, SO 2 

## and PM 10 

## , set in a previous permit action,

based on modeling analyses

Minn. R. 7011.0510 Standards of Performance for Existing Indirect Heating

Equipment. Determination of applicable limit from rule:

 the units were constructed in 1953 and 1957;

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## Item Applicable Regulations Comments:

 the facility is located in the metro area;

 the unit capacities are greater than 250 MMBtu/hr; and

 the facility has greater than 250 MMBtu/hr of indirect

heating equipment.

40 CFR Part 76 NO X 

## limits under the facility’s NO X 

## Averaging Plan pursuant to

Acid Rain regulations

40 CFR Part 64 The boilers are subject to CAM for PM and PM 10



## GP007
(combustion

turbine EU026

and duct

burners EU027) 40 CFR § 52.21 Prevention of Significant Deterioration. BACT limits set at a previous permit action for and NO

x 

## , CO, PM 10 

## , and VOC.

Title I limit to avoid 40 CFR

Part 63 Limits on formaldehyde and total HAPs, set through the permit

that originally authorized these units, to avoid the

modification being major under Part 63.

40 CFR Part 75 Permittee is required to measure or calculate annual SO 2 

## emissions under the Acid Rain program. There is no specific

SO 2 

## limit.

40 CFR Part 64 EU026 and EU027 combined are subject to CAM for NO X



## .

GP008 40 CFR Part 72 General requirements for compliance with Acid Rain

provisions.

EU005, EU008,

EU009, EU010,

EU011, EU012,

EU013 NAAQS Limit on PM 10 

## , set in a previous permit action, based on modeling analyses

Minn. R. 7011.1105 Standards of Performance for Certain Coal Handling Facilities.

Facility is located within the Minneapolis

‐ St. Paul Air Quality

Control Region.

EU006 NAAQS Limits on hours of operation and PM 10 

## , set in a previous permit

action, based on modeling analyses

Minn. R. 7011.1105 Standards of Performance for Certain Coal Handling Facilities.

Facility is located within the Minneapolis

‐ St. Paul Air Quality

Control Region.

EU007 NAAQS Limit on PM 10 

## , set in a previous permit action, based on modeling analyses

Minn. R. 7011.1105 Standards of Performance for Certain Coal Handling Facilities.

Facility is located within the Minneapolis

‐ St. Paul Air Quality

Control Region.

40 CFR Part 60, Subpart Y Standards of Performance for Coal Preparation and Processing

Plants. EU007 was installed in 1992, after the NSPS
applicability cutoff date (1974), making it subject to the

opacity requirements of this subpart.

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## Item Applicable Regulations Comments:

EU019 Minn. R. 7011.0715 Standards of Performance for Post

‐ 1969 Industrial Process

Equipment. EU019 was installed in 1976, and is not subject to

any other state or federal standard of performance.

EU026 40 CFR Part 60, Subpart GG Standards of Performance for Stationary Gas Turbines

EU026 is larger than 10 MMBtu/hr, and was constructed after

the applicability cutoff date (1977). NO X 

## and SO 2 

## limits apply.

40 CFR § 52.21 Prevention of Significant Deterioration. Startup and shutdown

restrictions were established as BACT at the time, through a previous permit action.

Title I limit to avoid 40 CFR §

52.21 Fuel restrictions limiting SO 2 

## emissions, set through a previous

permit action, so that the modification was not subject to PSD

for SO 2



## .

EU027 40 CFR Part 60, Subpart Da Standards of Performance for Electric Utility Steam Generating

Units.

EU027 is larger than 250 MMBtu/hr, and was constructed

after the applicability cutoff date of 1978.

40 CFR § 52.21 Prevention of Significant Deterioration.

Limit on operating hours, set through a previous permit action.

SO 2 

## and NO X 

## limits apply.

Title I limit to avoid 40 CFR §

52.21 Fuel restrictions limiting SO 2 

## emissions, set through a previous

permit action, so that the modification was not subject to PSD

for SO 2



## .

EU028 Minn. R. 7011.2300 Minnesota Standards of Performance for Stationary Internal

Combustion Engines

40 CFR Part 63, Subpart ZZZZ National Emissions Standards for Hazardous Air Pollutants for

Stationary Reciprocating Internal Combustion Engines

Title I conditions to avoid 40

CFR § 52.21 Conditions governing replacement of engine with a temporary

unit



# 3. Technical Information

3.1 Calculations of Potential to Emit

Attachment 1 to this TSD contains a summary of the facility’s PTE, as well as detailed spreadsheets and supporting

information prepared by the MPCA and the Permittee. The source of all emissions data is documented in the

spreadsheets.

3.2 Periodic Monitoring and CAM

In accordance with the Clean Air Act, it is the responsibility of the owner or operator of a facility to have sufficient

knowledge of the facility to certify that the facility is in compliance with all applicable requirements.

For CAM, the Permittee submitted a CAM proposal as required by 40 CFR § 64.3. It can be found in Attachment 3 to

this TSD.

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## In evaluating the monitoring included in the permit, the MPCA considers the following:

 The likelihood of violating the applicable requirements;

 Whether add

‐ on controls are necessary to meet the emission limits;

 The variability of emissions over time;

 The type of monitoring, process, maintenance, or control equipment data already available for the emission

unit;

 The technical and economic feasibility of possible periodic monitoring methods; and

 The kind of monitoring found on similar units elsewhere.

The table below summarizes the periodic monitoring requirements for those emission units for which the monitoring
required by the applicable requirement is nonexistent or inadequate or where CAM applies.

Table 6. Periodic Monitoring

Item Requirement (rule basis) Additional

Monitoring Discussion

GP001
(generators

EU024 and
EU025) Operating hours: < 816 hours/year on a 12

‐ month

rolling sum, combined

(Title I to avoid PSD) Daily recordkeeping

of operating hours

Monthly calculation

of 12

‐ month rolling

sum Records of operating hours are required on each day of operation;

Permittee is also required to record

which (if any) of these hours were

for non

‐ emergencies or non

‐ routine

testing or maintenance.

NO X 

## : < 35.5 tpy on a 12

‐ month

rolling sum, combined

(Title I to avoid PSD) Monthly calculation

of the 12

‐ month

rolling sum The calculation is based on the AP

‐
42 emission factor in lb/MMbtu, the

engine capacity, and the hours of

operation (calculated monthly as a

separate condition). This is

conservative, because it assumed

that when the engines are operated,

they are operated at full capacity.

Sulfur content of fuel: < 0.05%
by weight

(Minn. R. 7007.0800) Fuel supplier

certifications

showing sulfur

content of fuel

Opacity: < 20% at operating

temperature (each)

SO 2 

## : < 0.5 lb/MMBtu (each)

(Minn. R. 7011.2300) None The engine PTE, based on AP

‐ 42

emission factors and a limited fuel

sulfur content of 0.05% by weight, is
approximately 0.05 lb/MMBtu.

When low sulfur content fuels are used, opacity is not typically an

issue.

GP002
(boilers

EU003 and
EU004) PM: < 0.4 lb/MMBtu on a 3

‐ hour average, each

(Minn. R. 7011.0510)

PM: < 0.3 lb/MMBtu on a 3

‐ hour average, each Periodic
performance testing

Proper O&M of

control equipment
(CE006, CE007,

CE008, CE009) CE006, CE007, CE008, CE009 are subject to CAM.

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## Item Requirement (rule basis) Additional

Monitoring Discussion

(NAAQS modeling)

PM 10 

## : < 920 lb/hr, combined

(NAAQS modeling) Proper O&M of

control equipment
(CE006, CE007,

CE008, CE009) Calculated PTE based on published

emission factors and operation of

ESPs at permitted control

efficiencies is well below the limit.

Opacity: < 20% on a 6

‐ minute

average, with exceptions

(Minn. R. 7011.0510) COMS

SO 2 

## : < 1.3 lb/MMBtu on a 1

‐ hour average

SO 2 

## : < 3988 lb/hr on a 1

‐ hour

average

(NAAQS modeling)

SO 2 

## : < 3.0 lb/MMBtu on a 3

‐ hour average using solid fuel

SO 2 

## : < 1.6 lb/MMBtu on a 3

‐ hour average using liquid fuel

(Minn. R. 7011.0510) SO 2 

## CEMS

NO X 

## for EU003:

< 0.81 lb/MMBtu and 6133000 MMBtu/year

AND

NO X 

## for EU004:

< 0.81 lb/MMBtu and

12438000 MMBtu/year

OR

Weighted average for the
facility as outlined in the NO X 

## averaging plan

(Acid Rain) NO X 

## CEMS

GP003 (ESPs

CE006,

CE007,

CE008, and
CE009) Opacity: < 20% on an

instantaneous basis

(CAM excursion level) COMS Attached CAM plan (Attachment 3)

demonstrates the relationship

between opacity and PM emissions

and provides justification of

selection of COMS as CAM

PM Control efficiency: >

99.75% Proper O&M,

minimum number ESPs are in series

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## Item Requirement (rule basis) Additional

Monitoring Discussion

PM 10 

## Control efficiency: >

99.75%

PM 2.5 

## Control efficiency: >

99.75%

(Minn. R. 7007.0800) SCA online

Surface collection area (SCA): >
125,760 ft 2 

## for CE006 and

CE007 combined; > 141,144 ft 2



## for CE008 and CE009 combined

(Minn. R. 7017.2025) Continuous

monitoring of SCA,

or sections if they

are equivalent SCA measured during most recent

stack test demonstrating compliance

with PM limits.

GP006
(fabric filters

CE016

– CE021,

CE023

– CE025) PM Control efficiency: > 99%

PM 10 

## Control efficiency: > 93%

PM 2.5 

## Control efficiency: > 54%

(Minn. R. 7007.0800) Proper O&M, visible

emission checks These are low temperature fabric

filters, controlling units which are

not subject to CAM

GP007
(combustion

turbine

EU026 and

duct burners
EU027) NO X 

## : < 4.5 ppm on a 3

‐ hour

block average

NO X 

## : < 100 ppm on a 1

‐ hour

average

(BACT limits) NO X 

## CEMS EU026 and EU027 are subject to

CAM for NO X



## .

NO X 

## : < 305 tpy on a 12

‐ month

rolling sum

(Title I condition to avoid PSD

increment SIL) Monthly calculation Calculation is based on the CEMS

monitoring data.

CO: < 25 ppm on a 3

‐ hour block

average when EU026 and

EU027 are both operating

CO: < 18 ppm on a 3

‐ hour

average when only EU026 is

operating

CO: < 400 tpy on a 12

‐ month

rolling sum

(BACT limits) CO CEMS

Monthly

calculations using

CEMS data Calculation of 12 month rolling sum

is based on the CEMS monitoring

data.

PM 10 

## : 29.4 lb/hr on a 3

‐ hour

average

VOC: < 0.0073 lb/MMBtu

(applies only when EU026 is

operating at or above 70% Performance

Testing

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## Item Requirement (rule basis) Additional

Monitoring Discussion

load)

(BACT limits)

Formaldehyde: < 9.0 tpy on a

12

‐ month rolling sum

Total HAPs: < 24.0 tpy on a 12

‐ month rolling sum

(Title I ) Performance testing
Formaldehyde

emission factor

Monthly

calculations of 12

‐ month sum For all HAP other than
formaldehyde, AP

‐ 42 emission

factors are used.

GP008

(EU003,

EU004,
EU026) SO 2 

## : Comply with applicable

SO 2 

## limitations

(Acid Rain) CEMS for EU003 and

EU004, calculation

for CE026, as required by the

rules The acid rain rules do not specify a limit, but require annual emissions

each year to not exceed those of the

year before.

EU005 (coal
handling) PM 10 

## : < 0.6 lb/hr

(NAAQS modeling) Operation of CE025
(see GP006) PTE of the unit, based on capacity,

control, and AP

‐ 42 emission factors,

is 0.27 lb/hr.

Opacity: < 20%

(Minn. R. 7011.1105(G)) None Controls are required if opacity

exceeds 20%; controls are already in
place

EU006 (coal
handling) PM 10 

## : < 1.0 lb/hr

(NAAQS modeling) Operation of CE023

and CE024 (see

GP006) PTE of the unit, based on capacity,

control, and AP

‐ 42 emission factors,

is approximately 0.03 lb/hr.

Operating Hours: < 12.5 hours/day

(NAAQS modeling) Recordkeeping of

start and stop times

Opacity: < 20%

(Minn. R. 7011.1105(H)) None Controls are required if opacity

exceeds 20%; controls are already in
place

Unload within a partial

enclosure and use fabric filters

(Minn. R. 7011.1105(C)) None Controls are in place

EU007 (coal
handling) Opacity: < 20%

(NSPS Subpart Y) None Initial testing is completed; allowed

PM 10 

## emission rate will not result in

20% opacity

PM 10 

## : < 0.01 gr/dscf

(NAAQS modeling, Minn. R.
7011.1105(G)) Operation of CE021
(see GP006) Limit is equivalent to approximately

0.051 lb/hr, based on air flow

capacity; PTE of the unit, based on capacity, control, and AP

‐ 42

emission factors, is 0.0004 lb/hr.

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Page 12 of 17

Date: 4/1/2014 

## Item Requirement (rule basis) Additional

Monitoring Discussion

EU008 (coal
handling) PM 10 

## : < 0.005 gr/dscf

(NAAQS modeling, Minn. R.
7011.1105(G)) Operation of CE019
(see GP006) Limit is equivalent to approximately

1.7 lb/hr, based on air flow capacity;

PTE of the unit, based on capacity,

control, and AP

‐ 42 emission factors,

is 0.075 lb/hr.

Opacity: < 20%

(Minn. R. 7011.1105(G)) None Allowed PM 10 

## emission rate will not

result in 20% opacity

EU009 (coal
handling) PM 10 

## : < 0.005 gr/dscf

(NAAQS modeling, Minn. R.
7011.1105(G)) Operation of CE020
(see GP006) Limit is equivalent to approximately

0.56 lb/hr, based on air flow

capacity; PTE of the unit, based on capacity, control, and AP

‐ 42

emission factors, is 0.03 lb/hr.

Opacity: < 20%

(Minn. R. 7011.1105(G)) None Allowed PM 10 

## emission rate will not

result in 20% opacity

EU010 (coal
handling) PM 10 

## : < 0.005 gr/dscf

(NAAQS modeling, Minn. R.
7011.1105(G)) Operation of CE020
(see GP006) Limit is equivalent to approximately

0.56 lb/hr, based on air flow

capacity; PTE of the unit, based on capacity, control, and AP

‐ 42

emission factors, is 0.02 lb/hr.

Opacity: < 20%

(Minn. R. 7011.1105(G)) None Allowed PM 10 

## emission rate will not

result in 20% opacity

EU011 (coal
handling) PM 10 

## : < 0.005 gr/dscf

(NAAQS modeling, Minn. R.
7011.1105(G)) Operation of CE016
(see GP006) Limit is equivalent to approximately

1.2 lb/hr, based on air flow capacity;

PTE of the unit, based on capacity,

control, and AP

‐ 42 emission factors,

is 0.05 lb/hr.

Opacity: < 20%

(Minn. R. 7011.1105(G)) None Allowed PM 10 

## emission rate will not

result in 20% opacity

EU012 (coal
handling) PM 10 

## : < 0.005 gr/dscf

(NAAQS modeling, Minn. R.
7011.1105(G)) Operation of CE017
(see GP006) Limit is equivalent to approximately

0.54 lb/hr, based on air flow

capacity; PTE of the unit, based on capacity, control, and AP

‐ 42

emission factors, is 0.02 lb/hr.

Opacity: < 20%

(Minn. R. 7011.1105(G)) None Allowed PM 10 

## emission rate will not

result in 20% opacity

EU013 (coal
handling) PM 10 

## : < 0.005 gr/dscf

(NAAQS modeling, Minn. R.
7011.1105(G)) Operation of CE018
(see GP006) Limit is equivalent to approximately

0.81 lb/hr, based on air flow

capacity; PTE of the unit, based on capacity, control, and AP

‐ 42

emission factors, is 0.02 lb/hr.

## Technical Support Document, Permit Action Number: 03700003

‐ 011

Page 13 of 17

Date: 4/1/2014 

## Item Requirement (rule basis) Additional

Monitoring Discussion

Opacity: < 20%

(Minn. R. 7011.1105(G)) None Allowed PM 10 

## emission rate will not

result in 20% opacity

EU019 (fly

ash silo) PM: Variable with load and

airflow

Opacity: < 20%

(Minn. R. 7011.0715) None Emissions are exhausted through

the ESPs (CE006, CE007, CE008, and
CE009) and are “lost” in the

emissions from the boilers.

EU026
(combustion
turbine) NO X 

## : < 110 ppm on a 4

‐ hour

average

(NSPS Subpart GG) NO X 

## CEMS NO X 

## CEMS is not required by NSPS,

but is in place for other purposes.

Fuel sulfur content: < 0.8

percent by weight

SO 2 

## : < 0.15 percent by volume

(NSPS Subpart GG) Recordkeeping as required by NSPS NSPS requires no additional

monitoring, provided fuel meets the

definition of natural gas, per tariff

sheets and/or certifications from

supplier Fuel sulfur content: < 0.004 gr/dscf

(Title I limit)

Startup hours: < 1.0 hrs/startup

Shutdown hours: < 0.5
hr/shutdown

Startup & Shutdown: < 1250 hours/year on a 12

‐ month

rolling sum

(BACT limits) Recordkeeping

EU027 (duct

burners) SO 2 

## : < 0.2 lb/MMBtu on a 30

‐ day average

(NSPS Subpart Da) None PTE is approximately 0.0006
lb/MMBtu.

NO X 

## : < 1.6 lb/megawatt

‐ hour

on a 30

‐ day average

(NSPS Subpart Da) NO X 

## CEMS

Hours of operation: < 1500 hr/year on a 12

‐ month rolling

sum

(BACT limit) Recordkeeping

## Technical Support Document, Permit Action Number: 03700003

‐ 011

Page 14 of 17

Date: 4/1/2014 

## Item Requirement (rule basis) Additional

Monitoring Discussion

EU028 (Fire

pump engine) Opacity: < 20% opacity at
operating temperature

SO 2 

## : < 0.50 lb/MMBtu heat

input

(Minn. R. 7011.2300) Recordkeeping of

fuel sulfur content SO 2 

## limit is the PTE when using fuel

that meets the sulfur content limit.

Fuel sulfur content: < 0.05

percent by weight

(to meet Minn. R. 7011.2300)

Hours of operation: < 500

hours per year Recordkeeping

EU032 (SCR) NO X 

## : < 4.5 ppm on an

instantaneous basis

(CAM excursion level) NO X 

## CEMS See attached CAM plan (Attachment

3)

3.3 Insignificant Activities

The Black Dog facility includes several operations which are classified as insignificant activities. These are listed in
Appendix B to the permit.

The permit is required to include periodic monitoring for all emissions units, including insignificant activities, per EPA
guidance. The insignificant activities at this Facility are only subject to general applicable requirements. Using the

criteria outlined earlier in this TSD, the following table documents the justification why no additional periodic

monitoring is necessary for the existing insignificant activity categories. See Attachment 1 of this TSD for PTE

information for the insignificant activities.

Table 7. Insignificant Activities

Insignificant Activity General Applicable

Emission limit Discussion

Fuel use: space heaters fueled by

kerosene, natural gas, or propane if

combined total capacity is less than

420,000 Btu/hr. PM < 0.6 or 0.4
lb/MMBtu,

depending on year

constructed

Opacity < 20% with

exceptions

(Minn. R. 7011.0510/0515) For these units, based on the fuels used

and EPA published emissions factors, it is
highly unlikely that it could violate the

applicable requirement. In addition, these

types of units are typically operated and

vented inside a building, so testing for PM

or opacity is not feasible.

Emissions from a laboratory, as

defined in Minn. R. 7007.1300, subp.
3(G) PM, variable

depending on

airflow

Opacity < 20%

(Minn. R. 7011.0710/0715) These are very small, intermittent, bench

‐ top operations that typically do not even

have any emissions. It is highly unlikely

that they could violate the applicable

requirement.

## Technical Support Document, Permit Action Number: 03700003

‐ 011

Page 15 of 17

Date: 4/1/2014 

## Insignificant Activity General Applicable

Emission limit Discussion

Brazing, soldering or welding

equipment PM, variable

depending on

airflow

Opacity < 20%

(Minn. R. 7011.0710/715) For these units, based on EPA published

emissions factors, it is highly unlikely that

they could violate the applicable

requirement. In addition, these units are typically operated and vented inside a building, so testing for PM or opacity is

not feasible.

Individual units with potential

emissions less than 2000 lb/year of

certain pollutants PM, variable

depending on

airflow

Opacity < 20% (with
exceptions)

(Minn. R.
7011.0710/0715 This is loadout of dewatered bottom ash.

Based on the fuels used and EPA
published emissions factors, it is highly

unlikely that they could violate the

applicable requirement.

Infrequent use of spray paint

equipment for routine housekeeping

or plant upkeep activities not

associated with primary production

processes at the stationary source PM, variable

depending on

airflow or process weight rate
Opacity < 20%

(Minn. R. 7011.0710/0715) While spray equipment will have the

potential to emit particulate matter, these

particular activities are those not

associated with production, so they would

be infrequent and usually occur outdoors.

Testing or monitoring is not feasible.

Equipment venting PM/PM 10 

## inside

a building, provided that emissions

from the equipment are:

a). filtered through an air cleaning

system; and

b). vented inside of the building

100% of the time PM, variable

depending on

airflow

Opacity < 20%

(Minn. R.
7011.0715) For these units, it is highly unlikely that

they could violate the applicable

requirement. In addition, these units are

vented inside a building, so testing for PM

or opacity is not feasible.

Individual emissions units at a stationary source, each of which has:

A. Potential emissions of 5.7 pounds

per hour or actual emissions of two

tons per year of carbon monoxide;

B. Potential emissions of 2.28
pounds per hour or actual emissions

of one ton per year for particulate

matter, particulate matter less than

ten microns, nitrogen oxide, sulfur

dioxide, and VOCs;

C. For hazardous air pollutants,

emissions units with: PM, controlled to

minimize fugitive

emissions;

additional controls if
fugitive opacity

exceeds 20%

(Minn. R.
7011.1105) This is a variety of coal unloading and

handling equipment. These are not typically stack emissions. Calculated

emissions based on capacity and

published AP

‐ 42 emission factors would

not be expected to produce significant
fugitive emissions.

PM, variable

depending on

airflow or process weight rate
Opacity < 20%

(Minn. R. Fugitive VOC from oil pumps, valves, and
flanges. Particulate matter is not an expected emission.

## Technical Support Document, Permit Action Number: 03700003

‐ 011

Page 16 of 17

Date: 4/1/2014 

## Insignificant Activity General Applicable

Emission limit Discussion

(1) potential emissions of 25 percent

or less of the hazardous air pollutant

thresholds listed in subp. 5; or

(2) combined HAP actual emissions

of one ton per year unless the

emissions unit emits one or more of

the HAPs listed in this subpart; AND

D. Potential emissions up to 10,000

tons per year or actual emissions up

to 1,000 tons per year of CO 2 

## e. 7011.0710/0715)

3.4 Permit Organization

In general, the permit meets the MPCA Delta Guidance for ordering and grouping of requirements. One area where

this permit deviates slightly from Delta guidance is in the use of appendices. While appendices are fully enforceable

parts of the permit, in general, any requirement that the MPCA thinks should be tracked (e.g., limits, submittals,
etc.), should be in Table A or B. The main reason is that the appendices are word processing sections and are not part

of the tracking system. Violation of the appendices can be enforced, but the computer system will not automatically

generate the necessary enforcement notices or documents. Staff must generate these.

3.5 Comments Received

3.5.1 Public Notice Period: 8/3/13

– 9/3/13

Comments were received from the Permittee during the public notice period. The comments received did result

in the following changes to the draft permit:

 Removed the PM 10 

## testing at the boiler stack. This requirement was erroneously included in the permit to begin with. The potential PM 10 

## emissions, based on boiler capacity, allowed fuel, and pollution control

requirement are significantly less than the emission limit. In addition, the Permittee intends to discontinue

coal combustion. This test was never meant to be included in the permit, as evidenced by the fact that
justification for it did not exist in the technical support document, and the calculations show the potential

emissions to be less than the permit limit.

 Included combustion of non

‐ hazardous cleaning agents in EU003 as well as EU004. This was intended in the

original draft permit, but there was one location where it only said EU004.

 Changed the NSPS Subpart Da requirement for showing compliance with the NO X 

## limit (Permittee is following

a different, equally

‐ acceptable option in the standard than what was listed in the permit).

 Clarified corrective actions required for the selective catalytic reduction unit (CE032).

Because of these changes (notably the removal of the stack test requirement), the permit must be placed on public notice a 2 nd 

## time.

3.5.2 Public Notice Period: 10/4/13

– 11/4/13

EPA 45

‐ day Review Period: 10/4/13

– 11/18/13

No comments were received from the public or EPA during the 2 nd 

## comment period. However, on November 19,

2013 (after the end of EPA’s review period) the Permittee requested that the permit be delayed pending further

discussion on implementation of the non

‐ road engine requirements. The Permittee and MPCA negotiated the

language to come to a mutual agreement; MPCA made changes to the permit and determined that the changes

## Technical Support Document, Permit Action Number: 03700003

‐ 011

Page 17 of 17

Date: 4/1/2014 

## would qualify as a minor amendment. Therefore, the permit need not go through an additional public notice, but

EPA must be given an additional 45 days to review the permit prior to issuance.

In addition, the greenhouse gas calculations were updated to reflect revised emission factors and global warming
potentials published in the November 29, 2013, Federal Register. States were instructed that all permits issued

after 1/1/14 must reflect the revised factors.

3.5.3 EPA 45

‐ day Review Period: 2/14/14

– 3/31/14

No comments were received from EPA during this review period. No additional changes were made to the permit

prior to issuance.



# 4. Permit Fee Assessment

The permit action includes two permit applications, both received after the effective date of the rule (July 1, 2009).

There are no application fees associated with the reissuance of the Part 70 permit. The application fee for the

administrative amendment was paid at the time of application. The permit includes the incorporation of a NESHAP
(Subpart ZZZZ), however this is not a chargeable activity (the standard was not triggered by a modification, it simply

falls under the updates required through the Part 70 reissuance). Thus, there are no additional points/fees associated

with this permit action.



# 5. Conclusion

Based on the information provided by Xcel Energy, the MPCA has reasonable assurance that the proposed operation

of the emission facility, as described in the Air Emission Permit No. 03700003

‐ 011 and this TSD, will not cause or

contribute to a violation of applicable federal regulations and Minnesota Rules.

Staff Members on Permit Team: Toni Volkmeier (permit writer/engineer)

Brent Rohne (enforcement)

Marc Severin (stack testing)

Kira Gillette (peer reviewer)

AQ File No. 202E; DQ 3874 (Title V reissuance), 3912 (administrative amendment), 2385 (reopening, ESP operating
parameters)

Attachments: 1. PTE Summary and Calculation Spreadsheets

2. Facility Description and CD

‐ 01 Forms

3. CAM Plans

4. Public Comments ‐ 1 st 

## Comment Period

# Attachment 1

Calculations and PTE Summary27 December, 2013 09:16

Show: Active and Pending Records 

# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Acetaldehyde

PER 011 EU 003 3.760E-03 1.650E-02 1.650E-02

PER 011 EU 004 6.050E-03 2.650E-02 2.650E-02

PER 011 EU 024 4.000E-04 1.800E-03

PER 011 EU 025 4.000E-04 1.800E-03

PER 002 EU 026 1.500E-01 6.580E-01 6.580E-01 0.000E+00

PER 011 EU 026 8.000E-02 3.359E-01 3.359E-01 0.000E+00

PER 011 EU 028 1.090E-03 2.730E-04 2.730E-04

PER 011 GP 001 1.700E-04

Totals 3.828E-01 3.793E-01 0.000E+00

Acetophenone

PER 011 EU 003 1.410E-03 6.180E-03 6.180E-03

PER 011 EU 004 2.270E-03 9.940E-03 9.940E-03

Totals 1.612E-02 1.612E-02 0.000E+00

Acrolein

PER 011 EU 003 2.230E-03 9.790E-03 9.790E-03

PER 011 EU 004 3.590E-03 1.570E-02 1.570E-02

PER 011 EU 024 1.000E-04 6.000E-04

PER 011 EU 025 1.000E-04 6.000E-04

PER 002 EU 026 1.500E-02 6.000E-02 6.000E-02 0.000E+00

PER 011 EU 026 1.230E-02 5.380E-02 5.380E-02 0.000E+00

PER 011 EU 028 6.590E-05 1.650E-05 1.650E-05

PER 011 GP 001 5.330E-05

Totals 8.051E-02 7.936E-02 0.000E+00

Benzene

PER 011 EU 003 4.590E-03 2.010E-02 2.010E-02

PER 011 EU 004 7.380E-03 3.230E-02 3.230E-02

PER 011 EU 024 1.290E-02 5.630E-02

PER 011 EU 025 1.290E-02 5.630E-02

PER 002 EU 026 2.630E-01 1.150E+00 1.150E+00 0.000E+00

PER 011 EU 026 2.300E-02 1.008E-01 1.008E-01 0.000E+00

PER 002 EU 027 1.100E-03 5.000E-03 5.000E-03 0.000E+00

PER 011 EU 027 4.080E-04 1.790E-03 3.060E-04 0.000E+00

PER 011 EU 028 1.330E-03 3.320E-04 3.320E-04

PER 011 GP 001 5.250E-03

Totals 2.679E-01 1.591E-01 0.000E+00

Page 1 of 2027 December, 2013 09:16

Show: Active and Pending Records 

# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Arsenic compounds

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 6.000E-04 1.597E-01 2.500E-03 1.100E-03

PER 011 EU 003 2.300E-02 1.010E-01 1.010E-01 0.000E+00

PER 001 EU 004 9.000E-04 2.569E-01 4.000E-03 2.000E-03

PER 011 EU 004 3.690E-02 1.620E-01 1.620E-01 0.000E+00

PER 002 EU 026 1.000E-04 4.000E-04 4.000E-04 0.000E+00

PER 011 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 002 EU 027 1.000E-04 4.000E-04 4.000E-04 0.000E+00

PER 011 EU 027 1.170E-04 5.130E-04 8.790E-05 0.000E+00

Totals 2.635E-01 2.631E-01 0.000E+00

Benzyl chloride

PER 011 EU 003 3.290E-04 1.440E-03 1.440E-03

PER 011 EU 004 5.300E-04 2.320E-03 2.320E-03

Totals 3.760E-03 3.760E-03 0.000E+00

Biphenyl

PER 011 EU 003 1.880E-04 8.240E-04 8.240E-04

PER 011 EU 004 3.030E-04 1.330E-03 1.330E-03

Totals 2.154E-03 2.154E-03 0.000E+00

Bis(2-ethylhexyl) phthalate

PER 011 EU 003 4.230E-03 1.850E-02 1.850E-02

PER 011 EU 004 6.810E-03 2.980E-02 2.980E-02

Totals 4.830E-02 4.830E-02 0.000E+00

Bromomethane

PER 011 EU 003 9.580E-03 4.200E-02 4.200E-02

PER 011 EU 004 1.830E-02 8.010E-02 8.010E-02

Totals 1.221E-01 1.221E-01 0.000E+00

1,3-Butadiene

PER 002 EU 026 8.000E-04 4.000E-03 4.000E-03 0.000E+00

PER 011 EU 026 8.250E-04 3.600E-03 3.600E-03 0.000E+00

PER 011 EU 028 2.790E-05 6.960E-06 6.960E-06

Totals 3.607E-03 3.607E-03 0.000E+00

Beryllium

PER 002 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 011 EU 027 5.100E-06 2.230E-05 3.820E-06

Totals 2.230E-05 3.820E-06 0.000E+00

Page 2 of 2027 December, 2013 09:16

Show: Active and Pending Records 

# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Beryllium Compounds

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 1.000E-04 2.470E-02 6.000E-04 3.000E-04

PER 011 EU 003 1.180E-03 5.150E-03 5.150E-03 0.000E+00

PER 001 EU 004 2.000E-04 3.980E-02 9.000E-04 4.000E-04

PER 011 EU 004 1.890E-03 8.290E-03 8.290E-03 0.000E+00

Totals 1.344E-02 1.344E-02 0.000E+00

Carbon disulfide

PER 011 EU 003 1.290E-03 5.670E-03 5.670E-03

PER 011 EU 004 2.080E-03 9.120E-03 9.120E-03

Totals 1.479E-02 1.479E-02 0.000E+00

Carbon Dioxide Equivalent

PER 011 EU 003 2.440E+05 1.068E+06 1.068E+06

PER 011 EU 004 3.995E+05 1.750E+06 1.750E+06

PER 011 EU 024 2.712E+03 1.177E+04

PER 011 EU 025 2.712E+03 1.177E+04

PER 011 EU 026 2.281E+05 9.993E+05 9.993E+05

PER 011 EU 027 6.063E+04 2.656E+05 4.547E+04

PER 011 EU 028 2.331E+02 5.752E+01 5.752E+01

PER 011 GP 001 1.096E+03

Totals 4.106E+06 3.864E+06 0.000E+00

Chlorobenzene

PER 011 EU 003 1.880E-04 8.240E-04 8.240E-04

PER 011 EU 004 3.030E-04 1.330E-03 1.330E-03

Totals 2.154E-03 2.154E-03 0.000E+00

Chloroethane

PER 011 EU 003 2.520E-03 1.100E-02 1.100E-02

PER 011 EU 004 4.800E-03 2.100E-02 2.100E-02

Totals 3.200E-02 3.200E-02 0.000E+00

Chloroform

PER 011 EU 003 9.410E-04 4.120E-03 4.120E-03

PER 011 EU 004 1.510E-03 6.630E-03 6.630E-03

Totals 1.075E-02 1.075E-02 0.000E+00

Cadmium compounds

PER 002 EU 001

PER 002 EU 002

Page 3 of 2027 December, 2013 09:16

Show: Active and Pending Records 

# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Cadmium compounds

PER 001 EU 003 2.500E-03 1.597E-01 1.080E-02 5.100E-03

PER 011 EU 003 2.860E-03 1.250E-02 1.250E-02 0.000E+00

PER 001 EU 004 4.000E-03 2.569E-01 1.740E-02 8.600E-03

PER 011 EU 004 4.600E-03 2.010E-02 2.014E-02 0.000E+00

PER 002 EU 026 1.500E-03 7.000E-03 7.000E-03 0.000E+00

PER 011 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 002 EU 027 6.000E-04 3.000E-03 3.000E-03 0.000E+00

PER 011 EU 027 2.040E-05 8.930E-05 1.530E-05 0.000E+00

Totals 3.269E-02 3.266E-02 0.000E+00

Methane

PER 011 EU 003 2.850E+01 1.249E+02 1.249E+02

PER 011 EU 004 4.588E+01 2.010E+02 2.010E+02

PER 011 EU 024 1.096E-01 4.802E-01

PER 011 EU 025 1.096E-01 4.802E-01

PER 011 EU 026 4.230E+00 1.851E+01 1.851E+01

PER 011 EU 027 1.100E+00 4.920E+00 8.400E-01

PER 011 EU 028 9.400E-03 2.400E-03 2.400E-03

PER 011 GP 001 4.470E-02

Totals 3.503E+02 3.453E+02 0.000E+00

Cyanide compounds

PER 011 EU 003 1.500E-01 6.559E-01 6.559E-01

PER 011 EU 004 2.860E-01 1.250E+00 1.250E+00

Totals 1.906E+00 1.906E+00 0.000E+00

Carbon Monoxide

PER 002 EU 001

PER 002 EU 002

PER 008 EU 003 1.008E+02 4.415E+02 4.415E+02 7.873E+01

PER 011 EU 003 1.008E+02 4.415E+02 4.415E+02 0.000E+00

PER 008 EU 004 1.596E+02 6.990E+02 6.990E+02 1.361E+02

PER 011 EU 004 1.596E+02 6.990E+02 6.990E+02 0.000E+00

PER 008 EU 023 2.010E+00 8.800E+00 5.000E+00

PER 001 EU 024 1.050E+00 4.958E+01 4.620E+00 0.000E+00

PER 011 EU 024 1.045E+01 4.580E+01 0.000E+00 0.000E+00

PER 008 EU 025 1.050E+00 4.958E+01 0.000E+00 0.000E+00

PER 011 EU 025 1.046E+01 4.581E+01 0.000E+00 0.000E+00

Page 4 of 2027 December, 2013 09:16

Show: Active and Pending Records 

# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Carbon Monoxide

PER 008 EU 026 9.132E+01 4.000E+02 4.000E+02 0.000E+00

PER 011 EU 026 4.200E+01 1.840E+02 0.000E+00 0.000E+00

PER 008 EU 027 5.100E+01 2.234E+02 0.000E+00 0.000E+00

PER 011 EU 028 1.354E+00 3.384E-01 3.384E-01

PER 011 GP 001 4.270E+00

PER 011 SV 020 4.000E+02

Totals 1.649E+03 1.550E+03 0.000E+00

Carbon Dioxide

PER 011 EU 003 2.422E+05 1.059E+06 1.059E+06

PER 011 EU 004 3.964E+05 1.736E+06 1.736E+06

PER 011 EU 024 2.703E+03 1.173E+04

PER 011 EU 025 2.703E+03 1.173E+04

PER 011 EU 026 2.279E+05 9.982E+05 9.982E+05

PER 011 EU 027 6.057E+04 2.653E+05 4.543E+04

PER 011 EU 028 2.323E+02 5.772E+01 5.772E+01

PER 011 GP 001 1.092E+03

Totals 4.083E+06 3.841E+06 0.000E+00

Cobalt compounds

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 2.700E-03 1.200E-02 1.200E-02 0.000E+00

PER 011 EU 003 5.600E-03 2.450E-02 2.450E-02 0.000E+00

PER 001 EU 004 4.400E-03 1.930E-02 1.930E-02 0.000E+00

PER 011 EU 004 9.010E-03 3.950E-02 3.950E-02 0.000E+00

PER 002 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 002 EU 027 1.000E-04 4.000E-04 4.000E-04 0.000E+00

PER 011 EU 027 4.080E-05 1.790E-04 3.060E-04 0.000E+00

Totals 6.418E-02 6.431E-02 0.000E+00

Chromium compounds

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 2.600E-03 7.726E-01 1.130E-02 5.300E-03

PER 011 EU 003 1.460E-02 6.380E-02 6.380E-02 0.000E+00

PER 001 EU 004 4.100E-03 1.243E+00 1.810E-02 9.000E-03

PER 011 EU 004 2.340E-02 1.030E-01 1.030E-01 0.000E+00

Page 5 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Chromium compounds

PER 002 EU 026 2.500E-03 1.100E-02 1.100E-02 0.000E+00

PER 011 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 002 EU 027 7.000E-04 3.000E-03 3.000E-03 0.000E+00

PER 011 EU 027 5.610E-04 2.460E-03 4.200E-04 0.000E+00

Totals 1.693E-01 1.672E-01 0.000E+00

Dibenzofuran

PER 011 EU 003 6.820E-04 2.990E-03 2.990E-03

PER 011 EU 004 1.100E-03 4.810E-03 4.810E-03

Totals 7.800E-03 7.800E-03 0.000E+00

Dibutyl phthalate

PER 011 EU 003 1.290E-04 5.670E-04 5.670E-04

PER 011 EU 004 2.080E-04 9.120E-04 9.120E-04

Totals 1.479E-03 1.479E-03 0.000E+00

1,4-Dichlorobenzene

PER 011 EU 003 1.290E-03 5.670E-03 5.670E-03

PER 011 EU 004 2.080E-03 9.120E-03 9.120E-03

PER 002 EU 027 6.000E-04 3.000E-03 3.000E-03 0.000E+00

PER 011 EU 027 0.000E+00 0.000E+00 0.000E+00 0.000E+00

Totals 1.479E-02 1.479E-02 0.000E+00

1,2-Dichloroethane

PER 011 EU 003 2.400E-03 1.050E-02 1.050E-02

PER 011 EU 004 4.570E-03 2.000E-02 2.000E-02

Totals 3.050E-02 3.050E-02 0.000E+00

Dimethyl sulfate

PER 011 EU 003 2.880E-03 1.260E-02 1.260E-02

PER 011 EU 004 5.490E-03 2.400E-02 2.400E-02

Totals 3.660E-02 3.660E-02 0.000E+00

2,4-Dinitrotoluene

PER 011 EU 003 2.350E-04 1.030E-03 1.030E-03

PER 011 EU 004 3.780E-04 1.660E-03 1.660E-03

Totals 2.690E-03 2.690E-03 0.000E+00

Ethylbenzene

PER 011 EU 003 9.410E-04 4.120E-03 4.120E-03

PER 011 EU 004 1.510E-03 6.630E-03 6.630E-03

PER 002 EU 026 4.500E-02 2.000E-01 2.000E-01 0.000E+00

Page 6 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Ethylbenzene

PER 011 EU 026 6.140E-02 2.688E-01 2.688E-01 0.000E+00

Totals 2.796E-01 2.796E-01 0.000E+00

Formaldehyde

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 2.664E-01 1.167E+00 1.167E+00 7.900E-03

PER 011 EU 003 3.060E-03 1.340E-02 1.340E-02 0.000E+00

PER 001 EU 004 4.200E-01 1.840E+00 1.840E+00 1.240E-02

PER 011 EU 004 4.920E-03 2.150E-02 2.150E-02 0.000E+00

PER 001 EU 024 1.000E-04 5.800E-03 5.000E-04 0.000E+00

PER 011 EU 024 1.300E-03 5.700E-03 0.000E+00 0.000E+00

PER 008 EU 025 1.000E-04 5.800E-03 0.000E+00 0.000E+00

PER 011 EU 025 1.300E-03 5.700E-03 0.000E+00 0.000E+00

PER 008 EU 026 2.150E+00 9.420E+00 9.000E+00 0.000E+00

PER 011 EU 026 4.700E-02 2.058E-01 2.058E-01 0.000E+00

PER 002 EU 027 3.750E-02 1.640E-01 1.640E-01 0.000E+00

PER 011 EU 027 1.070E-02 4.670E-02 8.000E-03 0.000E+00

PER 011 EU 028 1.680E-03 4.200E-04 4.200E-04

PER 011 GP 001 5.340E-04

Totals 2.992E-01 2.497E-01 0.000E+00

Hexane

PER 011 EU 003 2.160E+00 9.460E+00 9.460E+00

PER 011 EU 004 3.420E+00 1.498E+01 1.498E+01

PER 002 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 002 EU 027 8.993E-01 3.939E+00 3.939E+00 0.000E+00

PER 011 EU 027 8.993E-01 3.939E+00 6.740E-01 0.000E+00

Totals 2.838E+01 2.511E+01 0.000E+00

Hydrogen fluoride

PER 011 EU 003 1.810E-01 7.927E-01 7.927E-01

PER 011 EU 004 3.450E-01 1.513E+00 1.513E+00

Totals 2.305E+00 2.305E+00 0.000E+00

Methyl methacrylate

PER 011 EU 003 1.290E-03 5.670E-03 5.670E-03

PER 011 EU 004 2.080E-03 9.120E-03 9.120E-03

Totals 1.479E-02 1.479E-02 0.000E+00

Page 7 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Methylhydrazine

PER 011 EU 003 1.020E-02 4.460E-02 4.460E-03

PER 011 EU 004 1.940E-02 8.510E-02 8.510E-02

Totals 1.297E-01 8.956E-02 0.000E+00

Naphthalene

PER 011 EU 003 7.320E-04 3.200E-03 3.200E-03

PER 011 EU 004 1.170E-03 5.140E-03 5.140E-03

PER 011 EU 024 2.200E-03 9.400E-03

PER 011 EU 025 2.200E-03 9.400E-03

PER 002 EU 026 2.630E-01 1.150E+00 1.150E+00 0.000E+00

PER 011 EU 026 2.490E-03 1.090E-02 1.090E-02 0.000E+00

PER 002 EU 027 3.000E-04 1.000E-03 1.000E-03 0.000E+00

PER 011 EU 027 3.050E-04 1.330E-03 2.290E-04 0.000E+00

PER 011 EU 028 1.210E-04 3.020E-05 3.020E-05

PER 011 GP 001 3.870E-04

Totals 3.940E-02 1.989E-02 0.000E+00

HAPs - Total

PER 002 EU 001

PER 002 EU 002

PER 008 EU 003 1.320E+01 5.770E+01 5.770E+01 1.125E+01

PER 011 EU 003 2.180E+00 9.550E+00 9.550E+00 0.000E+00

PER 008 EU 004 8.740E+00 3.830E+01 3.830E+01 1.742E+01

PER 011 EU 004 3.450E+00 1.510E+01 1.510E+01 0.000E+00

PER 008 EU 023 2.000E-02

PER 001 EU 024 2.300E-03 1.099E-01 1.020E-02 0.000E+00

PER 011 EU 024 2.470E-02 1.083E-01 0.000E+00 0.000E+00

PER 008 EU 025 2.300E-03 1.099E-01 0.000E+00 0.000E+00

PER 011 EU 025 2.470E-02 1.083E-01 0.000E+00 0.000E+00

PER 008 EU 026 2.350E+01

PER 011 EU 027 9.180E-01 4.020E+00 6.890E-01

PER 011 EU 028 5.300E-03 1.330E-03 1.330E-03

PER 011 GP 001 1.010E-02

Totals 2.889E+01 4.887E+01 0.000E+00

Mercury

PER 002 EU 026 8.000E-04 4.000E-03 4.000E-03 0.000E+00

PER 011 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

Page 8 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Mercury

PER 002 EU 027 2.000E-04 1.000E-03 1.000E-03 0.000E+00

PER 011 EU 027 4.080E-07 1.790E-06 3.060E-07 0.000E+00

Totals 1.790E-06 3.060E-07 0.000E+00

Mercury Compounds

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 1.360E-02 5.970E-02 5.970E-02 5.800E-03

PER 011 EU 003 6.240E-03 2.730E-02 2.730E-02 0.000E+00

PER 001 EU 004 2.150E-02 9.420E-02 9.420E-02 9.800E-03

PER 011 EU 004 1.080E-02 4.710E-02 4.710E-02 0.000E+00

Totals 7.440E-02 7.440E-02 0.000E+00

Nitrosodimethylamine, NPER 002 EU 026 4.000E-04 2.000E-03 2.000E-03 0.000E+00

PER 011 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

Totals 0.000E+00 0.000E+00 0.000E+00

Nitrosomorpholine, NPER 002 EU 026 4.000E-04 2.000E-03 2.000E-03 0.000E+00

PER 011 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

Totals 0.000E+00 0.000E+00 0.000E+00

Phenol

PER 011 EU 003 3.880E-03 1.700E-02 1.700E-02

PER 011 EU 004 6.240E-03 2.730E-02 2.730E-02

Totals 4.430E-02 4.430E-02 0.000E+00

Propylene oxide

PER 002 EU 026 5.400E-02 2.400E-01 2.400E-01 0.000E+00

PER 011 EU 026 5.560E-02 2.436E-01 2.436E-01 0.000E+00

Totals 2.436E-01 2.436E-01 0.000E+00

Styrene

PER 011 EU 003 8.230E-04 3.610E-03 3.610E-03

PER 011 EU 004 1.320E-03 5.800E-03 5.800E-03

Totals 9.410E-03 9.410E-03 0.000E+00

Tetrachloroethylene

PER 011 EU 003 4.940E-04 2.160E-03 2.160E-03

PER 011 EU 004 7.950E-04 3.480E-03 3.480E-03

Totals 5.640E-03 5.640E-03 0.000E+00

Page 9 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Toluene

PER 011 EU 003 1.220E-02 5.360E-02 5.360E-02

PER 011 EU 004 1.940E-02 8.490E-02 8.490E-02

PER 011 EU 024 4.700E-03 2.040E-02

PER 011 EU 025 4.700E-03 2.040E-02

PER 002 EU 026 2.440E-01 1.070E+00 1.070E+00 0.000E+00

PER 011 EU 026 2.490E-01 1.092E+00 1.092E+00 0.000E+00

PER 002 EU 027 1.700E-03 7.000E-03 7.000E-03 0.000E+00

PER 011 EU 027 5.100E-03 2.230E-02 3.820E-03 0.000E+00

PER 011 EU 028 5.830E-04 1.460E-04 1.460E-04

PER 011 GP 001 1.900E-03

Totals 1.294E+00 1.236E+00 0.000E+00

1,2,4-Trichlorobenzene

PER 011 EU 003 1.760E-03 7.730E-03 7.730E-03

PER 011 EU 004 2.840E-03 1.240E-02 1.240E-02

Totals 2.013E-02 2.013E-02 0.000E+00

1,1,1-Trichloroethane

PER 011 EU 003 7.170E-04 3.140E-03 3.140E-03

PER 011 EU 004 1.150E-03 5.060E-03 5.060E-03

Totals 8.200E-03 8.200E-03 0.000E+00

Vinyl acetate

PER 011 EU 003 3.650E-04 1.600E-03 1.600E-03

PER 011 EU 004 5.870E-04 2.570E-03 2.570E-03

Totals 4.170E-03 4.170E-03 0.000E+00

Vinyl chloride

PER 011 EU 003 8.580E-04 3.760E-03 3.760E-03

PER 011 EU 004 1.380E-03 6.050E-03 6.050E-03

Totals 9.810E-03 9.810E-03 0.000E+00

Xylenes (mixed isomers)

PER 011 EU 003 9.640E-04 4.220E-03 4.220E-03

PER 011 EU 004 1.550E-03 6.800E-03 6.800E-03

PER 011 EU 024 3.200E-03 1.400E-02

PER 011 EU 025 3.200E-03 1.400E-02

PER 002 EU 026 5.100E-02 2.200E-01 2.200E-01 0.000E+00

PER 011 EU 026 1.230E-01 5.375E-01 5.375E-01 0.000E+00

PER 011 EU 028 4.060E-04 1.020E-04 1.020E-04

Page 10 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Xylenes (mixed isomers)

PER 011 GP 001 1.310E-03

Totals 5.766E-01 5.499E-01 0.000E+00

Hydrochloric acid

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 8.580E+01 3.760E+02 3.760E+02 1.118E+01

PER 011 EU 003 1.550E+00 6.799E+00 6.799E+00 0.000E+00

PER 001 EU 004 1.381E+02 6.050E+02 6.050E+02 1.731E+01

PER 011 EU 004 2.490E+00 1.093E+01 1.093E+01 0.000E+00

Totals 1.773E+01 1.773E+01 0.000E+00

Manganese compounds

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 5.600E-03 1.133E+00 2.440E-02 1.120E-02

PER 011 EU 003 6.160E-01 2.698E+00 2.698E+00 0.000E+00

PER 001 EU 004 8.900E-03 1.823E+00 3.920E-02 1.930E-02

PER 011 EU 004 9.910E-01 4.340E+00 4.340E+00 0.000E+00

PER 002 EU 026 3.000E-03 1.000E-02 1.000E-02 0.000E+00

PER 011 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 002 EU 027 2.000E-04 1.000E-03 1.000E-03 0.000E+00

PER 011 EU 027 2.040E-04 8.930E-04 1.530E-04 0.000E+00

Totals 7.039E+00 7.038E+00 0.000E+00

Ethylene dibromide (dibromoeth

PER 011 EU 003 7.190E-05 3.150E-04 3.150E-04

Totals 0.000E+00 0.000E+00 0.000E+00

Nitrous Oxide

PER 011 EU 003 4.150E+00 1.817E+01 1.817E+01

PER 011 EU 004 6.670E+00 2.923E+01 2.923E+01

PER 011 EU 024 2.190E-02 9.600E-02

PER 011 EU 025 2.190E-02 9.600E-02

PER 011 EU 026 4.200E-01 1.850E+00 1.850E+00

PER 011 EU 027 1.000E-01 4.921E-01 8.000E-02

PER 011 EU 028 1.900E-03 4.710E-04 4.710E-04

PER 011 GP 001 8.950E-03

Totals 4.993E+01 4.934E+01 0.000E+00

Page 11 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Isophorone

PER 011 EU 003 1.410E-03 6.180E-03 6.180E-03

PER 011 EU 004 2.270E-03 9.940E-03 9.940E-03

Totals 1.612E-02 1.612E-02 0.000E+00

Methyl chloride (chloromethane

PER 011 EU 003 3.170E-02 1.391E-01 1.391E-01

PER 011 EU 004 6.060E-02 2.653E-01 2.653E-01

Totals 4.044E-01 4.044E-01 0.000E+00

Methyl tert butyl ether

PER 011 EU 003 2.100E-03 9.200E-03 9.200E-03

PER 011 EU 004 4.000E-03 1.750E-02 1.750E-02

Totals 2.670E-02 2.670E-02 0.000E+00

Methylene chloride (dichlorome

PER 011 EU 003 4.230E-03 1.850E-02 1.850E-02

PER 011 EU 004 6.810E-03 2.980E-02 2.980E-02

Totals 4.830E-02 4.830E-02 0.000E+00

Propionaldehyde

PER 011 EU 003 2.230E-03 9.790E-03 9.790E-03

PER 011 EU 004 3.590E-03 1.570E-02 1.570E-02

Totals 2.549E-02 2.549E-02 0.000E+00

Total Polycyclic aromatic hydr

PER 011 EU 026 4.220E-03 1.850E-02 1.850E-02

Totals 1.850E-02 1.850E-02 0.000E+00

Nickel compounds

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 6.100E-03 6.696E-01 2.670E-02 1.250E-02

PER 011 EU 003 3.680E-02 1.612E-01 1.612E-01 0.000E+00

PER 001 EU 004 9.800E-03 1.077E+00 4.300E-02 2.130E-02

PER 011 EU 004 5.920E-02 2.591E-01 2.591E-01 0.000E+00

PER 002 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 002 EU 027 1.100E-03 5.000E-03 5.000E-03 0.000E+00

PER 011 EU 027 1.220E-03 5.360E-03 9.170E-04 0.000E+00

Totals 4.257E-01 4.212E-01 0.000E+00

Nitrogen Oxides

PER 002 EU 001

PER 002 EU 002

Page 12 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Nitrogen Oxides

PER 008 EU 003 1.231E+03 5.396E+03 5.396E+03 2.130E+03

PER 011 EU 003 1.232E+03 5.396E+03 5.396E+03 0.000E+00

PER 008 EU 004 1.982E+03 8.682E+03 8.682E+03 3.683E+03

PER 011 EU 004 1.982E+03 8.682E+03 8.682E+03 0.000E+00

PER 008 EU 023 5.920E+01 2.330E+02 2.330E+02

PER 001 EU 024 8.060E+00 3.789E+02 3.529E+01 0.000E+00

PER 011 EU 024 8.188E+01 3.587E+02 0.000E+00 0.000E+00

PER 008 EU 025 8.060E+00 3.789E+02 0.000E+00 0.000E+00

PER 011 EU 025 8.188E+01 3.587E+02 0.000E+00 0.000E+00

PER 008 EU 026 1.725E+02 7.556E+02 3.000E+02 0.000E+00

PER 011 EU 026 1.725E+02 7.556E+02 0.000E+00 0.000E+00

PER 008 EU 027 5.100E+01 2.234E+02 0.000E+00 0.000E+00

PER 011 EU 028 6.283E+00 1.571E+00 1.571E+00

PER 011 GP 001 3.530E+01

PER 011 SV 020 3.050E+02

Totals 1.601E+04 1.465E+04 0.000E+00

PM < 2.5 micron

PER 011 EU 003 0.000E+00 8.151E+03 0.000E+00

PER 011 EU 004 0.000E+00 1.312E+04 0.000E+00

PER 011 EU 005 4.000E-02 7.100E-01 9.000E-02

PER 011 EU 006 3.270E-02 3.100E-01 7.470E-02

PER 011 EU 007 4.030E-04 3.820E-03 1.770E-03

PER 011 EU 008 7.540E-02 7.100E-01 3.300E-01

PER 011 EU 009 3.270E-02 3.100E-01 1.430E-01

PER 011 EU 010 2.270E-02 2.100E-01 9.930E-02

PER 011 EU 011 5.220E-02 4.900E-01 2.290E-01

PER 011 EU 012 2.270E-02 2.100E-01 9.930E-02

PER 011 EU 013 2.270E-02 2.100E-01 9.930E-02

PER 011 EU 019 1.790E-03

PER 011 EU 024 4.869E-01 2.133E+00

PER 011 EU 025 4.869E-01 2.133E+00

PER 011 EU 026 1.800E+01 7.884E+01 7.884E+01

PER 011 EU 027 1.020E+01 4.464E+01 7.640E+00

PER 011 EU 028 4.417E-01 1.104E-01 1.104E-01

PER 011 FS 003 3.000E-02 1.370E-01 1.370E-01

Page 13 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

PM < 2.5 micron

PER 011 FS 004 1.400E-01 1.020E+00 6.100E-01

PER 011 FS 008 3.000E-02 2.290E-01 1.370E-01

PER 011 FS 009 2.000E-02 1.370E-01 8.200E-02

PER 011 FS 013 1.000E-02 9.000E-02 5.400E-02

PER 011 FS 014 8.000E-02 6.000E-01 3.500E-01

PER 011 FS 015 3.000E-02 1.370E-01 1.370E-01

PER 011 FS 016 8.000E-02 1.370E-01 1.370E-01

PER 011 FS 017 1.000E-02 2.290E-01 5.700E-02

PER 011 GP 001 1.990E-01

PER 011 SV 001 9.200E+02 4.030E+03

Totals 2.140E+04 4.119E+03 0.000E+00

Lead

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 2.000E-02 1.650E+00 8.000E-02 4.000E-02

PER 011 EU 003 1.460E-02 6.380E-02 6.380E-02 0.000E+00

PER 001 EU 004 3.000E-02 2.650E+00 1.300E-01 3.000E-02

PER 011 EU 004 2.340E-02 1.030E-01 1.030E-01 0.000E+00

PER 002 EU 026 3.000E-02 1.300E-01 1.200E-01 0.000E+00

PER 011 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 002 EU 027 3.000E-04 1.000E-03 1.000E-03 0.000E+00

PER 011 EU 027 2.500E-04 1.090E-03 1.870E-04 0.000E+00

Totals 1.679E-01 1.670E-01 0.000E+00

PM < 10 micron

PER 002 EU 001

PER 002 EU 002

PER 008 EU 003 0.000E+00 0.000E+00 0.000E+00 1.320E+00

PER 011 EU 003 0.000E+00 8.151E+03 0.000E+00 0.000E+00

PER 008 EU 004 0.000E+00 0.000E+00 0.000E+00 2.210E+00

PER 011 EU 004 0.000E+00 1.312E+04 0.000E+00 0.000E+00

PER 001 EU 005 3.100E-01 4.270E+00 1.370E+00 0.000E+00

PER 011 EU 005 2.700E-01 4.720E+00 6.100E-01 0.000E+00

PER 008 EU 006 5.381E+01 2.360E+01 4.450E+00 0.000E+00

PER 011 EU 006 3.270E-02 2.050E+00 3.270E-02 0.000E+00

PER 001 EU 007 5.000E-02 1.100E-01 2.300E-01 1.000E-02

Page 14 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

PM < 10 micron

PER 011 EU 007 4.030E-04 2.520E-02 1.770E-03 0.000E+00

PER 001 EU 008 1.710E+00 8.540E+00 7.510E+00 1.000E-02

PER 011 EU 008 7.540E-02 4.720E+00 3.300E-01 0.000E+00

PER 008 EU 009 2.500E-01 8.540E+00 2.440E+00 1.000E-02

PER 011 EU 009 3.270E-02 2.050E+00 1.400E-01 0.000E+00

PER 001 EU 010 1.110E+00 5.694E+01 4.880E+00 7.000E-02

PER 011 EU 010 2.270E-02 1.420E+00 9.930E-02 0.000E+00

PER 001 EU 011 1.240E+00 5.910E+00 5.440E+00 1.000E-02

PER 011 EU 011 5.220E-02 3.270E+00 2.290E-01 0.000E+00

PER 008 EU 012 9.900E-01 5.910E+00 2.370E+00 1.000E-02

PER 011 EU 012 2.270E-02 1.420E+00 9.930E-02 0.000E+00

PER 001 EU 013 8.100E-01 5.910E+00 3.570E+00 0.000E+00

PER 011 EU 013 2.270E-02 1.420E+00 9.930E-02 0.000E+00

PER 008 EU 014 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 015 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 016 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 017 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 018 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 019 0.000E+00 0.000E+00 0.000E+00 1.620E+00

PER 011 EU 019 0.000E+00 1.180E-02 0.000E+00 0.000E+00

PER 008 EU 020 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 021 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 022 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 023 6.600E-01 2.890E+00 1.650E+00

PER 001 EU 024 7.000E-01 3.500E+00 3.300E-01 0.000E+00

PER 011 EU 024 4.869E-01 2.133E+00 0.000E+00 0.000E+00

PER 008 EU 025 7.000E-01 3.500E+00 0.000E+00 0.000E+00

PER 011 EU 025 4.869E-01 2.133E+00 0.000E+00 0.000E+00

PER 008 EU 026 1.850E+01 8.100E+01 2.210E+01 0.000E+00

PER 011 EU 026 0.000E+00 7.884E+01 0.000E+00 0.000E+00

PER 008 EU 027 1.020E+01 4.470E+01 0.000E+00 0.000E+00

PER 011 EU 027 0.000E+00 4.464E+01 0.000E+00 0.000E+00

PER 011 EU 028 4.417E-01 1.104E-01 1.104E-01

PER 008 FS 001 0.000E+00 2.910E+00 1.000E-01 0.000E+00

PER 011 FS 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

Page 15 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

PM < 10 micron

PER 008 FS 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001 FS 003 0.000E+00 9.100E-01 0.000E+00 0.000E+00

PER 011 FS 003 2.100E-01 9.080E-01 9.080E-01 0.000E+00

PER 008 FS 004 0.000E+00 5.600E-01 0.000E+00 0.000E+00

PER 011 FS 004 9.300E-01 6.780E+00 4.070E+00 0.000E+00

PER 008 FS 008 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 011 FS 008 2.100E-01 1.513E+00 9.080E-01 0.000E+00

PER 008 FS 009 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 011 FS 009 1.200E-01 9.080E-01 5.450E-01 0.000E+00

PER 008 FS 010 0.000E+00 3.000E-01 0.000E+00 0.000E+00

PER 011 FS 010 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001 FS 011 0.000E+00 7.600E-01 0.000E+00 0.000E+00

PER 011 FS 011 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001 FS 012 0.000E+00 1.500E-01 0.000E+00 0.000E+00

PER 011 FS 012 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001 FS 013 2.700E-01 2.400E+00 1.200E+00 0.000E+00

PER 011 FS 013 1.300E-01 9.800E-01 5.860E-01 0.000E+00

PER 008 FS 014 4.600E-01 7.300E+00 2.500E+00 0.000E+00

PER 011 FS 014 6.900E-01 5.000E+00 3.030E+00 0.000E+00

PER 008 FS 015 0.000E+00 9.000E-01 0.000E+00 2.900E-01

PER 011 FS 015 2.100E-01 9.080E-01 9.080E-01 0.000E+00

PER 001 FS 016 0.000E+00 2.180E+00 0.000E+00 1.500E-01

PER 011 FS 016 5.000E-01 9.080E-01 9.080E-01 0.000E+00

PER 008 FS 017 0.000E+00 8.000E-01 0.000E+00 6.000E-02

PER 011 FS 017 9.000E-02 1.513E+00 3.780E-01 0.000E+00

PER 011 GP 001 1.990E-01

PER 008 SV 001 9.200E+02 4.030E+03 4.030E+03

PER 011 SV 001 9.200E+02 0.000E+00 4.030E+03

PER 011 SV 020 2.940E+01 1.288E+02

Totals 2.144E+04 4.175E+03 0.000E+00

Polycyclic organic matter

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 2.400E-03 1.070E-02 1.070E-02 5.000E-03

PER 011 EU 003 8.330E-05 4.000E-04 4.000E-04 0.000E+00

Page 16 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Polycyclic organic matter

PER 001 EU 004 3.900E-03 1.720E-02 1.720E-02 8.600E-03

PER 011 EU 004 1.320E-04 5.780E-04 5.780E-04 0.000E+00

PER 002 EU 026 3.380E-01 1.480E+00 1.480E+00 0.000E+00

PER 011 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 002 EU 027 3.400E-04 1.000E-03 1.000E-03 0.000E+00

PER 011 EU 027 4.320E-05 1.890E-04 3.240E-05 0.000E+00

Totals 1.167E-03 1.010E-03 0.000E+00

Total Particulate Matter

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 3.528E+02 2.821E+04 1.545E+03 3.169E+01

PER 011 EU 003 3.960E+02 2.987E+04 1.734E+03 0.000E+00

PER 001 EU 004 5.676E+02 4.538E+04 2.486E+03 4.639E+01

PER 011 EU 004 6.370E+02 4.806E+04 2.790E+03 0.000E+00

PER 001 EU 005 3.100E-01 9.020E+00 1.370E+00 0.000E+00

PER 011 EU 005 5.700E-01 9.980E+00 1.300E+00 0.000E+00

PER 008 EU 006 5.381E+01 2.360E+01 4.450E+00 0.000E+00

PER 011 EU 006 9.890E-03 4.330E+00 2.260E-02 0.000E+00

PER 001 EU 007 5.000E-02 2.200E-01 2.300E-01 2.000E-02

PER 011 EU 007 1.220E-04 5.330E-02 5.330E-04 0.000E+00

PER 001 EU 008 1.710E+00 1.805E+01 7.510E+00 3.000E-02

PER 011 EU 008 2.280E-02 9.980E+00 1.000E-01 0.000E+00

PER 008 EU 009 2.500E-01 1.805E+01 2.440E+00 2.000E-02

PER 011 EU 009 9.890E-03 4.330E+00 4.000E-02 0.000E+00

PER 008 EU 010 1.110E+00 5.690E+00 4.880E+00 1.400E-01

PER 011 EU 010 6.850E-03 3.000E+00 3.000E-02 0.000E+00

PER 001 EU 011 1.240E+00 1.250E+01 5.440E+00 2.000E-02

PER 011 EU 011 1.580E-02 6.910E+00 7.000E-02 0.000E+00

PER 008 EU 012 9.900E-01 1.250E+01 2.370E+00 2.000E-02

PER 011 EU 012 6.850E-03 3.000E+00 3.000E-02 0.000E+00

PER 001 EU 013 8.100E-01 1.250E+01 3.570E+00 1.000E-02

PER 011 EU 013 6.850E-03 3.000E+00 3.000E-02 0.000E+00

PER 008 EU 014 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 015 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 016 0.000E+00 0.000E+00 0.000E+00 0.000E+00

Page 17 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Total Particulate Matter

PER 008 EU 017 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 018 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001 EU 019 0.000E+00 8.448E+02 0.000E+00 1.620E+00

PER 011 EU 019 0.000E+00 2.500E-02 0.000E+00 0.000E+00

PER 008 EU 020 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 021 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 022 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 EU 023 6.600E-01 2.890E+00 1.650E+00

PER 001 EU 024 7.000E-01 3.500E+00 3.300E-01 0.000E+00

PER 011 EU 024 4.869E-01 2.133E+00 0.000E+00 0.000E+00

PER 008 EU 025 7.000E-01 3.500E+00 0.000E+00 0.000E+00

PER 011 EU 025 4.869E-01 2.133E+00 0.000E+00 0.000E+00

PER 008 EU 026 1.850E+01 8.100E+01 1.390E+01 0.000E+00

PER 011 EU 026 9.000E+00 3.942E+01 3.942E+01 0.000E+00

PER 008 EU 027 1.020E+01 4.470E+01 0.000E+00 0.000E+00

PER 011 EU 027 1.020E+01 4.460E+01 7.640E+00 0.000E+00

PER 011 EU 028 4.417E-01 1.104E-01 1.104E-01

PER 008 FS 001 0.000E+00 6.140E+00 2.100E-01 0.000E+00

PER 011 FS 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 FS 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001 FS 003 0.000E+00 1.920E+00 0.000E+00 0.000E+00

PER 011 FS 003 4.400E-01 1.919E+00 1.919E+00 0.000E+00

PER 008 FS 004 0.000E+00 1.120E+00 0.000E+00 0.000E+00

PER 011 FS 004 1.860E+00 1.356E+01 8.130E+00 0.000E+00

PER 008 FS 008 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 011 FS 008 4.400E-01 3.199E+00 1.919E+00 0.000E+00

PER 008 FS 009 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 011 FS 009 2.600E-01 1.919E+00 1.152E+00 0.000E+00

PER 008 FS 010 0.000E+00 6.000E-01 0.000E+00 0.000E+00

PER 011 FS 010 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001 FS 011 0.000E+00 1.600E+00 0.000E+00 0.000E+00

PER 011 FS 011 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 FS 012 0.000E+00 1.900E-01 0.000E+00 0.000E+00

PER 011 FS 012 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 008 FS 013 1.350E+00 1.174E+01 5.500E+00 0.000E+00

Page 18 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Total Particulate Matter

PER 011 FS 013 5.200E-01 3.770E+00 2.265E+00 0.000E+00

PER 008 FS 014 1.300E+00 2.030E+01 1.140E+01 0.000E+00

PER 011 FS 014 3.080E+00 2.250E+01 1.349E+01 0.000E+00

PER 008 FS 015 0.000E+00 1.920E+00 0.000E+00 6.100E-01

PER 011 FS 015 4.400E-01 1.919E+00 1.919E+00 0.000E+00

PER 001 FS 016 0.000E+00 4.610E+00 0.000E+00 3.100E-01

PER 011 FS 016 1.050E+00 1.919E+00 1.919E+00 0.000E+00

PER 008 FS 017 0.000E+00 1.640E+00 0.000E+00 1.300E-01

PER 011 FS 017 1.800E-01 3.199E+00 8.000E-01 0.000E+00

PER 011 GP 001 1.990E-01

Totals 7.812E+04 4.609E+03 0.000E+00

Antimony compounds

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 4.400E-03 1.910E-02 1.910E-02 8.900E-03

PER 011 EU 003 2.290E-03 1.000E-02 1.000E-02 0.000E+00

PER 001 EU 004 7.000E-03 3.070E-02 3.070E-02 1.530E-02

PER 011 EU 004 3.680E-03 1.610E-02 1.610E-02 0.000E+00

Totals 2.610E-02 2.610E-02 0.000E+00

Selenium compounds

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 1.100E-03 1.700E-01 4.800E-03 2.200E-03

PER 011 EU 003 7.790E-02 3.411E-01 3.411E-01 0.000E+00

PER 001 EU 004 1.800E-03 2.735E-01 7.700E-03 3.800E-03

PER 011 EU 004 1.490E-01 6.508E-01 6.508E-01 0.000E+00

PER 002 EU 026 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 002 EU 027 1.000E-05 5.000E-05 5.000E-05 0.000E+00

PER 011 EU 027 1.020E-05 4.460E-05 7.640E-06 0.000E+00

Totals 9.919E-01 9.919E-01 0.000E+00

Sulfur Dioxide

PER 002 EU 001

PER 002 EU 002

PER 001 EU 003 1.529E+03 3.011E+04 6.696E+03 1.568E+03

PER 011 EU 003 0.000E+00 3.011E+04 0.000E+00 0.000E+00

Page 19 of 2027 December, 2013 09:16

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# FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

Retired

By (Action) Added

By (Action) Item Pollutant Actual

Emissions (tons per yr) Limited

Potential (tons per yr) Unrestricted

Potential (tons per yr) Hourly

Potential (lbs per hr) AQD Facility ID: 03700003

Facility Name: Xcel Energy - Black Dog MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194

Sulfur Dioxide

PER 001 EU 004 2.460E+03 4.844E+04 1.077E+04 2.883E+03

PER 011 EU 004 0.000E+00 4.844E+04 0.000E+00 0.000E+00

PER 008 EU 023 6.300E-01 2.760E+00 1.540E+00

PER 001 EU 024 7.900E-01 3.736E+01 3.480E+00 0.000E+00

PER 011 EU 024 8.371E-01 3.667E+00 0.000E+00 0.000E+00

PER 008 EU 025 7.900E-01 3.736E+01 0.000E+00 0.000E+00

PER 011 EU 025 8.371E-01 3.667E+00 0.000E+00 0.000E+00

PER 008 EU 026 2.270E+00 9.900E+00 2.100E+00 0.000E+00

PER 011 EU 026 2.270E+00 9.900E+00 9.920E+00 0.000E+00

PER 008 EU 027 5.900E-01 2.600E+00 0.000E+00 0.000E+00

PER 011 EU 027 3.000E-01 1.313E+00 2.248E-01 0.000E+00

PER 011 EU 028 7.200E-02 1.800E-02 1.800E-02

PER 011 GP 001 3.420E-01

PER 011 SV 001 3.988E+03 1.747E+04

Totals 7.856E+04 1.748E+04 0.000E+00

Volatile Organic Compounds

PER 002 EU 001

PER 002 EU 002

PER 008 EU 003 6.600E+00 2.890E+01 2.890E+01 9.200E+00

PER 008 EU 004 1.046E+01 4.580E+01 4.580E+01 1.580E+01

PER 011 EU 004 1.045E+01 1.510E+01 1.510E+01 0.000E+00

PER 008 EU 023 7.500E-01 3.290E+00 1.900E+00

PER 001 EU 024 1.300E-01 6.090E+00 5.700E-01 0.000E+00

PER 011 EU 024 1.905E+00 8.344E+00 0.000E+00 0.000E+00

PER 008 EU 025 1.300E-01 6.090E+00 0.000E+00 0.000E+00

PER 011 EU 025 1.905E+00 8.344E+00 0.000E+00 0.000E+00

PER 008 EU 026 4.800E+00 2.100E+01 9.600E+00 0.000E+00

PER 011 EU 026 4.800E+00 2.100E+01 2.100E+01 0.000E+00

PER 008 EU 027 1.270E+01 5.560E+01 0.000E+00 0.000E+00

PER 011 EU 027 1.270E+01 5.580E+01 2.790E+00 0.000E+00

PER 011 EU 028 5.129E-01 1.282E-01 1.282E-01

PER 011 GP 001 7.770E-01

Totals 1.409E+02 7.060E+01 9.200E+00

Page 20 of 20Boiler 3 (Bituminous Coal) 1176 MMBtu/hr Bit Coal Ash% 1.15E+01Boiler 3 (Bituminous Coal) 56 tons/hr Bit Coal S% 3.23E+00Boiler 3 (Subbituminous Coal) 980 MMBtu/hr Subbit Coal Ash% 4.64E+00Boiler 3 (Subbituminous Coal) 56 tons/hr Subbit Coal S% 2.10E-01Boiler 3 (Pet Coke) 3.9 tons/hr Pet Coke Ash% 3.00E-01Boiler 3 (Pet Coke) 30 MMBtu/ton burned Pet Coke S% 5.67E+00Boiler 3 (Subbituminous Coal/Coke) 59.9 tons/hrBoiler 3 (Subbituminous Coal/Coke) 1097 MMBtu/hrBoiler 3 (Waste Oil) 0.44 1000 gal/hr Waste oil Ash% 1.00E+00Boiler 3 (Waste Oil) 135 MMBtu/1000 gal burned Waste Oil S% 2.40E-02Boiler 4 (Natural Gas) 1.2 MMCF/hr Waste oil MMBtu/hr 59Boiler 3 (Propane) 0.452 1000 gal/hrBoiler 3 (Propane) 166 MMBtu/hrXcel Energy - Black Dog Generating PlantParticulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficientPotential to EmitShading = Worst Case for Specified Pollutant for Specified UnitEmissionUnit ID Unit NamePollutantMax ProcessRateProcess RateUnitsEmissionFactor Emission FactorUnits Emission Factor SourceEmissionRate(lb/hr)UncontrolledPotential to Emit(ton/yr)PollutionControlEfficiency(%)ControlledPotential toEmit (ton/yr)Limited/ControlledPotential toEmit (ton/yr)Limited/ControlledPTE (lb/hr) Existing Permit LimitEU 003 Boiler 3 (Bituminous Coal) 1,2,4-Trichlorobenzene 1176 MMBtu/hr 1.50E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.76E-03 7.73E-03 7.73E-03 NA 1.76E-03EU 003 Boiler 3 (Bituminous Coal) 1,4-Dichlorobenzene 1176 MMBtu/hr 1.10E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.29E-03 5.67E-03 5.67E-03 NA 1.29E-03EU 003 Boiler 3 (Bituminous Coal) 2,4-Dinitrotoluene 1176 MMBtu/hr 2.00E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)2.35E-04 1.03E-03 1.03E-03 NA 2.35E-04EU 003 Boiler 3 (Bituminous Coal) Acetaldehyde 1176 MMBtu/hr 3.20E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)3.76E-03 1.65E-02 1.65E-02 NA 3.76E-03EU 003 Boiler 3 (Bituminous Coal) Acetophenone 1176 MMBtu/hr 1.20E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.41E-03 6.18E-03 6.18E-03 NA 1.41E-03EU 003 Boiler 3 (Bituminous Coal) Acrolein 1176 MMBtu/hr 1.90E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)2.23E-03 9.79E-03 9.79E-03 NA 2.23E-03EU 003 Boiler 3 (Bituminous Coal) Antimony 56.0 tons/hr 1.80E-05 lb/tonAP-42 Table 1.1-18 (9/98)1.01E-03 4.42E-03 4.42E-03 NA 1.01E-03EU 003 Boiler 3 (Bituminous Coal) Arsenic 56.0 tons/hr 4.10E-04 lb/tonAP-42 Table 1.1-18 (9/98)2.30E-02 1.01E-01 1.01E-01 NA 2.30E-02EU 003 Boiler 3 (Bituminous Coal) Benzene 1176 MMBtu/hr 3.90E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)4.59E-03 2.01E-02 2.01E-02 NA 4.59E-03EU 003 Boiler 3 (Bituminous Coal) Benzyl Chloride 1176 MMBtu/hr 2.80E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)3.29E-04 1.44E-03 1.44E-03 NA 3.29E-04EU 003 Boiler 3 (Bituminous Coal) Beryllium 56.0 tons/hr 2.10E-05 lb/tonAP-42 Table 1.1-18 (9/98)1.18E-03 5.15E-03 5.15E-03 NA 1.18E-03EU 003 Boiler 3 (Bituminous Coal) Biphenyl 1176 MMBtu/hr 1.60E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.88E-04 8.24E-04 8.24E-04 NA 1.88E-04EU 003 Boiler 3 (Bituminous Coal) bis(2-Ethylexyl)phthalate 1176 MMBtu/hr 3.60E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)4.23E-03 1.85E-02 1.85E-02 NA 4.23E-03EU 003 Boiler 3 (Bituminous Coal) Cadmium 56.0 tons/hr 5.10E-05 lb/tonAP-42 Table 1.1-18 (9/98)2.86E-03 1.25E-02 1.25E-02 NA 2.86E-03EU 003 Boiler 3 (Bituminous Coal) Carbon Disulfide 1176 MMBtu/hr 1.10E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.29E-03 5.67E-03 5.67E-03 NA 1.29E-03EU 003 Boiler 3 (Bituminous Coal) Chlorobenzene 1176 MMBtu/hr 1.60E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.88E-04 8.24E-04 8.24E-04 NA 1.88E-04EU 003 Boiler 3 (Bituminous Coal) Chloroform 1176 MMBtu/hr 8.00E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)9.41E-04 4.12E-03 4.12E-03 NA 9.41E-04EU 003 Boiler 3 (Bituminous Coal) Chromium 56.0 tons/hr 2.60E-04 lb/tonAP-42 Table 1.1-18 (9/98)1.46E-02 6.38E-02 6.38E-02 NA 1.46E-02EU 003 Boiler 3 (Bituminous Coal) CO 56.0 tons/hr 5.00E-01 lb/tonAP-42 Table 1.1-3 (9/98)28.00 122.64 122.64 NA 2.80E+01EU 003 Boiler 3 (Bituminous Coal) CO21176 MMBtu/hr 2.06E+02 lb/MMBtu40 CFR 98241838.62 1059253.17 1059253.17 NA 2.42E+05EU 003 Boiler 3 (Bituminous Coal) CO2e 1176 MMBtu/hr 2.07E+02 lb/MMBtu40 CFR 98243787.75 1067790.33 1067790.33 NA 2.44E+05EU 003 Boiler 3 (Bituminous Coal) Cobalt 56.0 tons/hr 1.00E-04 lb/tonAP-42 Table 1.1-18 (9/98)5.60E-03 0.0245 2.45E-02 NA 5.60E-03EU 003 Boiler 3 (Bituminous Coal) Cyanide 56.0 tons/hr 2.50E-03 lb/tonAP-42 Table 1.1-14 (9/98)1.40E-01 6.13E-01 6.13E-01 NA 1.40E-01EU 003 Boiler 3 (Bituminous Coal) DEHP 56.0 tons/hr 7.30E-05 lb/tonAP-42 Table 1.1-14 (9/98)4.09E-03 1.79E-02 1.79E-02 NA 4.09E-03EU 003 Boiler 3 (Bituminous Coal) Dibenzofuran 1176 MMBtu/hr 5.80E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)6.82E-04 2.99E-03 2.99E-03 NA 6.82E-04EU 003 Boiler 3 (Bituminous Coal) Dibutylphthalate 1176 MMBtu/hr 1.10E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.29E-04 5.67E-04 5.67E-04 NA 1.29E-04EU 003 Boiler 3 (Bituminous Coal) Dimethyl Sulfate 56.0 tons/hr 4.80E-05 lb/tonAP-42 Table 1.1-14 (9/98)2.69E-03 1.18E-02 1.18E-02 NA 2.69E-03EU 003 Boiler 3 (Bituminous Coal) Ethyl Benzene 1176 MMBtu/hr 8.00E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)9.41E-04 4.12E-03 4.12E-03 NA 9.41E-04EU 003 Boiler 3 (Bituminous Coal) chloroethane 56.0 tons/hr 4.20E-05 lb/tonAP-42 Table 1.1-14 (9/98)2.35E-03 1.03E-02 1.03E-02 NA 2.35E-03EU 003 Boiler 3 (Bituminous Coal) Ethylene Dibromide 56.0 tons/hr 1.20E-06 lb/tonAP-42 Table 1.1-14 (9/98)6.72E-05 2.94E-04 2.94E-04 NA 6.72E-05EU 003 Boiler 3 (Bituminous Coal) 1,2-dichloroethane 56.0 tons/hr 4.00E-05 lb/tonAP-42 Table 1.1-14 (9/98)2.24E-03 9.81E-03 9.81E-03 NA 2.24E-03EU 003 Boiler 3 (Bituminous Coal) Formaldehyde 1176 MMBtu/hr 2.60E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)3.06E-03 1.34E-02 1.34E-02 NA 3.06E-03EU 003 Boiler 3 (Bituminous Coal) Hexane 56.0 tons/hr 6.70E-05 lb/tonAP-42 Table 1.1-14 (9/98)3.75E-03 1.64E-02 1.64E-02 NA 3.75E-03EU 003 Boiler 3 (Bituminous Coal) Hydrochloric Acid 1176 MMBtu/hr 5.93E-02 lb/10^12 BTUAssume 750 ppm Cl (EPRI PiscesDatabase 08/98) in coal gets converted toHCl and 100% (EPRI Emissions FactorHandbook 4/02) goes to atmosphere.Assume 13000 Btu/lb (1999 PerformanceReport)6.97E-05 3.05E-04 3.05E-04 NA 6.97E-05EU 003 Boiler 3 (Bituminous Coal) Hydrogen Fluoride 1176 MMBtu/hr 5.26E-03 lb/10^12 BTUAssume 65 ppm F (EPRI Pisces Database08/98) in coal gets converted to HF and90% (EPRI Emissions Factor Handbook4/02) goes to atmosphere. Assume 13000Btu/lb (1999 Performance Report)6.19E-06 2.71E-05 2.71E-05 NA 6.19E-06EU 003 Boiler 3 (Bituminous Coal) Isophorone 1176 MMBtu/hr 1.20E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.41E-03 6.18E-03 6.18E-03 NA 1.41E-03EU 003 Boiler 3 (Bituminous Coal) Lead 56.0 tons/hr 2.60E-04 lb/tonAP-42 Table 1.1-18 (9/98)1.46E-02 6.38E-02 6.38E-02 NA 1.46E-02EU 003 Boiler 3 (Bituminous Coal) Manganese 56.0 tons/hr 1.10E-02 lb/tonAP-42 Table 1.1-18 (9/98)6.16E-01 2.6981 2.70E+00 NA 6.16E-01EU 003 Boiler 3 (Bituminous Coal) Mercury 56.0 tons/hr 8.30E-05 lb/tonAP-42 Table 1.1-18 (9/98)4.65E-03 2.04E-02 2.04E-02 NA 4.65E-03EU 003 Boiler 3 (Bituminous Coal) Methane 1176 MMBtu/hr 2.43E-02 lb/MMBtu40 CFR 982.85E+01 124.9119 1.25E+02 NA 2.85E+01EU 003 Boiler 3 (Bituminous Coal) bromomethane 56.0 tons/hr 1.60E-04 lb/tonAP-42 Table 1.1-14 (9/98)8.96E-03 3.92E-02 3.92E-02 NA 8.96E-03EU 003 Boiler 3 (Bituminous Coal) Methyl Chloride 56.0 tons/hr 5.30E-04 lb/tonAP-42 Table 1.1-14 (9/98)2.97E-02 1.30E-01 1.30E-01 NA 2.97E-02Xcel Energy - Black Dog Generating PlantParticulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficientPotential to EmitShading = Worst Case for Specified Pollutant for Specified UnitEmissionUnit ID Unit NamePollutantMax ProcessRateProcess RateUnitsEmissionFactor Emission FactorUnits Emission Factor SourceEmissionRate(lb/hr)UncontrolledPotential to Emit(ton/yr)PollutionControlEfficiency(%)ControlledPotential toEmit (ton/yr)Limited/ControlledPotential toEmit (ton/yr)Limited/ControlledPTE (lb/hr) Existing Permit LimitEU 003 Boiler 3 (Bituminous Coal) 1,1,1-trichlorothane 1176 MMBtu/hr 6.10E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)7.17E-04 3.14E-03 3.14E-03 NA 7.17E-04EU 003 Boiler 3 (Bituminous Coal) Methyl Ethyl Ketone 56.0 tons/hr 3.90E-04 lb/tonAP-42 Table 1.1-14 (9/98)2.18E-02 9.57E-02 9.57E-02 NA 2.18E-02EU 003 Boiler 3 (Bituminous Coal) Methyl Hydrazine 56.0 tons/hr 1.70E-04 lb/tonAP-42 Table 1.1-14 (9/98)9.52E-03 4.17E-02 4.17E-02 NA 9.52E-03EU 003 Boiler 3 (Bituminous Coal) Methyl Methacrylate 1176 MMBtu/hr 1.10E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.29E-03 5.67E-03 5.67E-03 NA 1.29E-03EU 003 Boiler 3 (Bituminous Coal) Methyl tert butyl ether 56.0 tons/hr 3.50E-05 lb/tonAP-42 Table 1.1-14 (9/98)1.96E-03 8.58E-03 8.58E-03 NA 1.96E-03EU 003 Boiler 3 (Bituminous Coal) Methylene Chloride 1176 MMBtu/hr 3.60E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)4.23E-03 1.85E-02 1.85E-02 NA 4.23E-03EU 003 Boiler 3 (Bituminous Coal) Naphthalene 1176 MMBtu/hr 6.20E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)7.29E-04 3.19E-03 3.19E-03 NA 7.29E-04EU 003 Boiler 3 (Bituminous Coal) Nickel 56.0 tons/hr 2.80E-04 lb/tonAP-42 Table 1.1-18 (9/98)1.57E-02 6.87E-02 6.87E-02 NA 1.57E-02EU 003 Boiler 3 (Bituminous Coal) Nitrous oxides 1176 MMBtu/hr 3.53E-03 lb/MMBtu40 CFR 984.15 18.17 18.17 NA 4.15E+00EU 003 Boiler 3 (Bituminous Coal) NOX56.0 tons/hr 2.20E+01 lb/tonAP-42 Table 1.1-3 (9/98)1232.00 5396.16 5396.16 NA 1.23E+03EU 003 Boiler 3 (Bituminous Coal) Phenol 1176 MMBtu/hr 3.30E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)3.88E-03 0.0170 1.70E-02 NA 3.88E-03EU 003 Boiler 3 (Bituminous Coal) PM 56.0 tons/hr 1.15E+02 lb/tonAP-42 Table 1.1-4 (9/98) (10 x 11.5 %Ash)6440.00 28207.20 99.75% 70.52 1,545.26 1.61E+01 0.3 lb/MMBTUEU 003 Boiler 3 (Bituminous Coal) PM1056.0 tons/hr 2.65E+01 lb/tonAP-42 Table 1.1-4 (9/98) (2.3 x 11.5 %Ash)1481.20 6487.66 99.75% 16.22 NA 3.70E+00EU 003 Boiler 3 (Bituminous Coal) PM2.556.0 tons/hr 2.65E+01 lb/tonAssumed same as PM101481.20 6487.66 99.75% 16.22 NA 3.70E+00EU003 Boiler 3 (Bituminous Coal) Condensible PM 1176.0 MMBtu/hr 3.23E-01 lb/MMBtuAP-42 Table 1.1-5 (0.1 x 3.23% sulfur)379.85 1663.73 99.75% 4.16 NA 9.50E-01EU 003 Boiler 3 (Bituminous Coal) POMs 1176 MMBtu/hr 2.08E-06 lb/10^12 BTUAP-42 Table 1.1-17 (9/98)2.45E-09 0.0000 1.07E-08 NA 2.45E-09EU 003 Boiler 3 (Bituminous Coal) Propionaldehyde 1176 MMBtu/hr 1.90E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)2.23E-03 0.0098 9.79E-03 NA 2.23E-03EU 003 Boiler 3 (Bituminous Coal) Selenium 56.0 tons/hr 1.30E-03 lb/tonAP-42 Table 1.1-18 (9/98)7.28E-02 0.3189 3.19E-01 NA 7.28E-02EU 003 Boiler 3 (Bituminous Coal) SO256.0 tons/hr 1.23E+02 lb/tonAP-42 Table 1.1-3 (9/98) (38 x 3.23 % S)6873.44 30105.6672 30105.67 15,452.64 3528.00 3 lb/MMBTUEU 003 Boiler 3 (Bituminous Coal) Styrene 1176 MMBtu/hr 7.00E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)8.23E-04 3.61E-03 3.61E-03 NA 8.23E-04EU 003 Boiler 3 (Bituminous Coal) Tetrachloroethylene 1176 MMBtu/hr 4.20E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)4.94E-04 2.16E-03 2.16E-03 NA 4.94E-04EU 003 Boiler 3 (Bituminous Coal) Toluene 1176 MMBtu/hr 1.70E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)2.00E-03 8.76E-03 8.76E-03 NA 2.00E-03EU 003 Boiler 3 (Bituminous Coal) TOTAL HAPs1.02E+00 4.48 4.48E+00 NA 1.02E+00EU 003 Boiler 3 (Bituminous Coal) Total VOC 56.0 tons/hr 6.00E-02 lb/tonAP-42 Table 1.1-19 (9/98)3.36E+00 14.7168 1.47E+01 NA 3.36E+00EU 003 Boiler 3 (Bituminous Coal) Vinyl Acetate 1176 MMBtu/hr 3.10E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)3.65E-04 1.60E-03 1.60E-03 NA 3.65E-04EU 003 Boiler 3 (Bituminous Coal) Vinyl Chloride 1176 MMBtu/hr 7.30E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)8.58E-04 3.76E-03 3.76E-03 NA 8.58E-04EU 003 Boiler 3 (Bituminous Coal) Xylenes 1176 MMBtu/hr 8.20E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)9.64E-04 4.22E-03 4.22E-03 NA 9.64E-040.00E+00 0.00E+00EU 003 Boiler 3 (Coke) CO2117 MMBtu/hr 2.26E+02 lb/MMBtu40 CFR 982.64E+04 115700 1.16E+05 NA 2.64E+04EU 003 Boiler 3 (Coke) CO2e 117 MMBtu/hr 2.27E+02 lb/MMBtu40 CFR 982.66E+04 116549.0362 1.17E+05 NA 2.66E+040.00E+00 0.00E+00EU 003 Boiler 3 (Natural Gas) Arsenic 1224 MMBtu/hr 2.30E-01 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)2.82E-04 0.0012 1.23E-03 NA 2.82E-04EU 003 Boiler 3 (Natural Gas) Benzene 1224 MMBtu/hr 8.00E-01 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)9.79E-04 0.0043 4.29E-03 NA 9.79E-04EU 003 Boiler 3 (Natural Gas) Beryllium1224 MMBtu/hr 1.00E-02 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)1.22E-05 0.0001 5.36E-05 NA 1.22E-05EU 003 Boiler 3 (Natural Gas) Cadmium 1224 MMBtu/hr 4.00E-02 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)4.90E-05 0.0002 2.14E-04 NA 4.90E-05EU 003 Boiler 3 (Natural Gas) Chromium 1224 MMBtu/hr 1.10E+00 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)1.35E-03 0.0059 5.90E-03 NA 1.35E-03EU 003 Boiler 3 (Natural Gas) CO 1.2 MMCF/hr 8.40E+01 lb/MMCFAP-42 Table 1.4-1 (7/98)100.80 441.50 441.50 NA 100.80EU 003 Boiler 3 (Natural Gas) CO21224 MMBtu/hr 1.17E+02 lb/MMBtu40 CFR 98143178.72 627122.78 627122.78 NA 143178.72EU 003 Boiler 3 (Natural Gas) CO2e 1224 MMBtu/hr 1.17E+02 lb/MMBtu40 CFR 98143326.59 627770.47 627770.47 NA 143326.59EU 003 Boiler 3 (Natural Gas) Cobalt 1224 MMBtu/hr 8.00E-02 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)9.79E-05 0.0004 4.29E-04 NA 9.79E-05EU 003 Boiler 3 (Natural Gas) Formaldehyde 1224 MMBtu/hr 1.75E-04 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)2.14E-07 0.0000 9.38E-07 NA 2.14E-07EU 003 Boiler 3 (Natural Gas) Hexane 1.2 MMCF/hr 1.80E+00 lb/MMCFAP-42 Table 1.4-3 (7/98)2.16E+00 9.4608 9.46E+00 NA 2.16E+00EU 003 Boiler 3 (Natural Gas) Lead 1224 MMBtu/hr 4.00E-01 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)4.90E-04 0.0021 2.14E-03 NA 4.90E-04EU 003 Boiler 3 (Natural Gas) Manganese 1224 MMBtu/hr 4.00E-01 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)4.90E-04 0.0021 2.14E-03 NA 4.90E-04EU 003 Boiler 3 (Natural Gas) Mercury 1224 MMBtu/hr 8.00E-04 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)9.79E-07 0.0000 4.29E-06 NA 9.79E-07EU 003 Boiler 3 (Natural Gas) Methane 1224 MMBtu/hr 2.20E-03 lb/MMBtu40 CFR 982.70E+00 11.8191 1.18E+01 NA 2.70E+00EU 003 Boiler 3 (Natural Gas) Naphthalene 1.2 MMCF/hr 6.10E-04 lb/MMCFAP-42 Table 1.4-3 (7/98)7.32E-04 0.0032 3.21E-03 NA 7.32E-04EU 003 Boiler 3 (Natural Gas) Nickel 1224 MMBtu/hr 2.40E+00 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)2.94E-03 0.0129 1.29E-02 NA 2.94E-03EU 003 Boiler 3 (Natural Gas) Nitrous oxides 1224 MMBtu/hr 2.20E-04 lb/MMBtu40 CFR 982.70E-01 1.1819 1.18E+00 NA 2.70E-01EU 003 Boiler 3 (Natural Gas) NOx1.2 MMCF/hr 2.80E+02 lb/MMCFAP-42 Table 1.4-1 (7/98)3.36E+02 1471.6800 1.47E+03 NA 3.36E+02EU 003 Boiler 3 (Natural Gas) PM 1.2 MMCF/hr 7.60E+00 lb/MMCFAP-42 Table 1.4-2 (7/98)9.12E+00 39.9456 3.99E+01 NA 9.12E+00 0.3 lb/MMBTUEU 003 Boiler 3 (Natural Gas) PM101.2 MMCF/hr 7.60E+00 lb/MMCFAP-42 Table 1.4-2 (7/98)9.12E+00 39.9456 3.99E+01 NA 9.12E+00EU 003 Boiler 3 (Natural Gas) PM2.51.2 MMCF/hr 7.60E+00 lb/MMCF 9.12E+00 39.9456 3.99E+01 NA 9.12E+00EU 003 Boiler 3 (Natural Gas) POMs 1.2 MMCF/hr 6.94E-05 lb/MMCFAP-42 Table 1.4-3 (7/98) - sum of allPOMs listed8.33E-05 0.0004 3.65E-04 NA 8.33E-05EU 003 Boiler 3 (Natural Gas) Selenium 1224 MMBtu/hr 2.00E-02 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)2.45E-05 0.0001 1.07E-04 NA 2.45E-05EU 003 Boiler 3 (Natural Gas) SO21.2 MMCF/hr 6.00E-01 lb/MMCFAP-42 Table 1.4-2 (7/98)7.20E-01 3.1536 3.15E+00 NA 7.20E-01Xcel Energy - Black Dog Generating PlantParticulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficientPotential to EmitShading = Worst Case for Specified Pollutant for Specified UnitEmissionUnit ID Unit NamePollutantMax ProcessRateProcess RateUnitsEmissionFactor Emission FactorUnits Emission Factor SourceEmissionRate(lb/hr)UncontrolledPotential to Emit(ton/yr)PollutionControlEfficiency(%)ControlledPotential toEmit (ton/yr)Limited/ControlledPotential toEmit (ton/yr)Limited/ControlledPTE (lb/hr) Existing Permit LimitEU 003 Boiler 3 (Natural Gas) Toluene 1224 MMBtu/hr 1.00E+01 lb/10^12 BTUEPRI Emissions Factor Handbook Table 3-1 (4/02)1.22E-02 0.0536 5.36E-02 NA 1.22E-02EU 003 Boiler 3 (Natural Gas) TOTAL HAPs2.18E+00 9.55E+00 9.55E+00 NA 2.18E+00EU 003 Boiler 3 (Natural Gas) Total VOC 1.2 MMCF/hr 5.50E+00 lb/MMCFAP-42 Table 1.4-2 (7/98)6.60E+00 28.9080 2.89E+01 NA 6.60E+000.00E+00 0.00E+00EU 003 Boiler 3 (Propane) CO 0.45 1000gal/hr 7.5E+00 lb/10^3 GALAP-42 Table 1.5-1 (7/08)3.39E+00 14.8482 1.48E+01 NA 3.39E+00EU 003 Boiler 3 (Propane) CO258.80 MMBtu/hr 1.39E+02 lb/MMBtu40 CFR 988.15E+03 35696 3.57E+04 NA 8.15E+03EU 003 Boiler 3 (Propane) CO2e 166 MMBtu/hr 1.39E+02 lb/MMBtu40 CFR 982.31E+04 101182.4374 1.01E+05 NA 2.31E+04EU 003 Boiler 3 (Propane) Methane 166 MMBtu/hr 6.61E-03 lb/MMBtu40 CFR 981.10E+00 4.8088 4.81E+00 NA 1.10E+00EU 003 Boiler 3 (Propane) Nitrous oxides 166 MMBtu/hr 1.32E-03 lb/MMBtu40 CFR 982.20E-01 0.9618 9.62E-01 NA 2.20E-01EU 003 Boiler 3 (Propane) NOx0.45 1000gal/hr 1.3E+01 lb/10^3 GALAP-42 Table 1.5-1 (7/08)5.88E+00 25.7369 2.57E+01 NA 5.88E+00EU 003 Boiler 3 (Propane) PM 0.45 1000gal/hr 2.00E-01 lb/10^3 GALAP-42 Table 1.5-1 (7/08), Filterable9.04E-02 0.3960 3.96E-01 NA 9.04E-02EU 003 Boiler 3 (Propane) PM100.45 1000gal/hr 7.00E-01 lb/10^3 GALAP-42 Table 1.5-1 (7/08), Filterable +Condensables3.16E-01 1.3858 1.39E+00 NA 3.16E-01EU 003 Boiler 3 (Propane) PM2.50.45 1000gal/hr 7.00E-01 lb/10^3 GALAP-42 Table 1.5-1 (7/08), Filterable +Condensables3.16E-01 1.3858 1.39E+00 NA 3.16E-01EU 003 Boiler 3 (Propane) SO2[2]0.45 1000gal/hr 8.00E-01 lb/10^3 GALAP-42 Table 1.5-1 (7/08)3.62E-01 1.5838 1.58E+00 NA 3.62E-01EU 003 Boiler 3 (Propane) Total VOC 0.45 1000gal/hr 1.0E+00 lb/10^3 GALAP-42 Table 1.5-1 (7/08)4.52E-01 1.9798 1.98E+00 NA 4.52E-01EU 0030.00E+00 0.00E+00EU 003 Boiler 3 (Subbituminous Coal) CO2980 MMBtu/hr 2.10E+02 lb/MMBtu40 CFR 982.06E+05 900374 9.00E+05 NA 2.06E+05EU 003 Boiler 3 (Subbituminous Coal) CO2e 980 MMBtu/hr 2.11E+02 lb/MMBtu40 CFR 982.07E+05 907488.6019 9.07E+05 NA 2.07E+05EU 003 Boiler 3 (Subbituminous Coal/Coke) 1,2,4-Trichlorobenzene 1097 MMBtu/hr 1.50E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.65E-03 0.0072 7.21E-03 NA 1.65E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) 1,4-Dichlorobenzene 1097 MMBtu/hr 1.10E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.21E-03 0.0053 5.29E-03 NA 1.21E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) 2,4-Dinitrotoluene 1097 MMBtu/hr 2.00E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)2.19E-04 0.0010 9.61E-04 NA 2.19E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Acetaldehyde 1097 MMBtu/hr 3.20E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)3.51E-03 0.0154 1.54E-02 NA 3.51E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Acetophenone 1097 MMBtu/hr 1.20E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.32E-03 0.0058 5.77E-03 NA 1.32E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Acrolein 1097 MMBtu/hr 1.90E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)2.08E-03 0.0091 9.13E-03 NA 2.08E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Antimony 1097 MMBtu/hr 4.09E-02 lb/10^12 BTUAP-42 Table 1.1-16 (9/98)(0.92*(C/A*PM)^0.63)4.49E-05 0.0002 1.97E-04 NA 4.49E-05EU 003 Boiler 3 (Subbituminous Coal/Coke) Arsenic 1097 MMBtu/hr 2.07E+00 lb/10^12 BTUAP-42 Table 1.1-16 (9/98)(3.1*(C/A*PM)^0.85)2.27E-03 0.0099 9.93E-03 NA 2.27E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Benzene 1097 MMBtu/hr 3.90E-06 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)4.28E-09 0.0000 1.87E-08 NA 4.28E-09EU 003 Boiler 3 (Subbituminous Coal/Coke) Benzyl Chloride 1097 MMBtu/hr 2.80E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)3.07E-04 0.0013 1.35E-03 NA 3.07E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Beryllium1097 MMBtu/hr 1.93E-01 lb/10^12 BTUAP-42 Table 1.1-16 (9/98)(1.2*(C/A*PM)^1.1)2.11E-04 0.0009 9.26E-04 NA 2.11E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Biphenyl 1097 MMBtu/hr 1.60E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.76E-04 0.0008 7.69E-04 NA 1.76E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) bis(2-Ethylexyl)phthalate 1097 MMBtu/hr 3.60E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)3.95E-03 0.0173 1.73E-02 NA 3.95E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Cadmium 1097 MMBtu/hr 6.13E-01 lb/10^12 BTUAP-42 Table 1.1-16 (9/98)(3.3*(C/A*PM)^0.5)6.72E-04 0.0029 2.94E-03 NA 6.72E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Carbon Disulfide 1097 MMBtu/hr 1.10E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.21E-03 0.0053 5.29E-03 NA 1.21E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Chlorobenzene 1097 MMBtu/hr 1.60E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.76E-04 0.0008 7.69E-04 NA 1.76E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Chloroform 1097 MMBtu/hr 8.00E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)8.78E-04 0.0038 3.84E-03 NA 8.78E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Chromium 1097 MMBtu/hr 6.54E+00 lb/10^12 BTUAP-42 Table 1.1-16 (9/98)(3.7*(C/A*PM)^0.58)7.18E-03 0.0314 3.14E-02 NA 7.18E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) CO 59.9 tons/hr 5.00E-01 lb/tonAP-42 Table 1.1-3 (9/98)3.00E+01 131.1810 1.31E+02 NA 3.00E+01EU 003 Boiler 3 (Subbituminous Coal/Coke) Cobalt 1097 MMBtu/hr 1.98E+00 lb/10^12 BTUAP-42 Table 1.1-16 (9/98)(1.7*(C/A*PM)^0.69)2.18E-03 0.0095 9.53E-03 NA 2.18E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Cyanide 59.9 tons/hr 2.50E-03 lb/tonAP-42 Table 1.1-14 (9/98)1.50E-01 0.6559 6.56E-01 NA 1.50E-01EU 003 Boiler 3 (Subbituminous Coal/Coke) DEHP 59.9 tons/hr 7.30E-05 lb/tonAP-42 Table 1.1-14 (9/98)4.37E-03 0.0192 1.92E-02 NA 4.37E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Dibenzofuran 1097 MMBtu/hr 5.80E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)6.36E-04 0.0028 2.79E-03 NA 6.36E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Dibutylphthalate 1097 MMBtu/hr 1.10E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.21E-04 0.0005 5.29E-04 NA 1.21E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Dimethyl Sulfate 59.9 tons/hr 4.80E-05 lb/tonAP-42 Table 1.1-14 (9/98)2.88E-03 0.0126 1.26E-02 NA 2.88E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Ethyl Benzene 1097 MMBtu/hr 8.00E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)8.78E-04 0.0038 3.84E-03 NA 8.78E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) chloroethane 59.9 tons/hr 4.20E-05 lb/tonAP-42 Table 1.1-14 (9/98)2.52E-03 0.0110 1.10E-02 NA 2.52E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Ethylene Dibromide 59.9 tons/hr 1.20E-06 lb/tonAP-42 Table 1.1-14 (9/98)7.19E-05 0.0003 3.15E-04 NA 7.19E-05EU 003 Boiler 3 (Subbituminous Coal/Coke) 1,2-dichloroethane 59.9 tons/hr 4.00E-05 lb/tonAP-42 Table 1.1-14 (9/98)2.40E-03 0.0105 1.05E-02 NA 2.40E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Formaldehyde 1097 MMBtu/hr 2.60E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)2.85E-03 0.0125 1.25E-02 NA 2.85E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Hexane 59.9 tons/hr 6.70E-05 lb/tonAP-42 Table 1.1-14 (9/98)4.01E-03 0.0176 1.76E-02 NA 4.01E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Hydrochloric Acid 59.9 tons/hr 6.65E-03 lb/tonEPRI Emission Factor Handbook Table 1-8(4/02), with 16.17 ppm Cl3.98E-01 1.7447 1.74E+00 NA 3.98E-01EU 003 Boiler 3 (Subbituminous Coal/Coke) Hydrogen Fluoride 59.9 tons/hr 3.02E-03 lb/tonEPRI Emission Factor Handbook Table 1-9(4/02), with 25.67 ppm F1.81E-01 0.7927 7.93E-01 NA 1.81E-01EU 003 Boiler 3 (Subbituminous Coal/Coke) Isophorone 1097 MMBtu/hr 1.20E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.32E-03 0.0058 5.77E-03 NA 1.32E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Lead 1097 MMBtu/hr 6.00E+00 lb/10^12 BTUAP-42 Table 1.1-16 (9/98)(3.4*(C/A*PM)^.8)6.58E-03 0.0288 2.88E-02 NA 6.58E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Manganese 1097 MMBtu/hr 1.27E+01 lb/10^12 BTUAP-42 Table 1.1-16 (9/98)(3.8*(C/A*PM)^.6)1.39E-02 0.0609 6.09E-02 NA 1.39E-02Xcel Energy - Black Dog Generating PlantParticulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficientPotential to EmitShading = Worst Case for Specified Pollutant for Specified UnitEmissionUnit ID Unit NamePollutantMax ProcessRateProcess RateUnitsEmissionFactor Emission FactorUnits Emission Factor SourceEmissionRate(lb/hr)UncontrolledPotential to Emit(ton/yr)PollutionControlEfficiency(%)ControlledPotential toEmit (ton/yr)Limited/ControlledPotential toEmit (ton/yr)Limited/ControlledPTE (lb/hr) Existing Permit LimitEU 003 Boiler 3 (Subbituminous Coal/Coke) Mercury 1097 MMBtu/hr 5.69E-06 lb/10^6 BTUBlack Dog Stack Test Data 20046.24E-03 0.0273 2.73E-02 NA 6.24E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Methane 1097 MMBtu/hr 2.43E-02 lb/MMBtu40 CFR 982.66E+01 116.5207 1.17E+02 NA 2.66E+01EU 003 Boiler 3 (Subbituminous Coal/Coke) bromomethane 59.9 tons/hr 1.60E-04 lb/tonAP-42 Table 1.1-14 (9/98)9.58E-03 0.0420 4.20E-02 NA 9.58E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Methyl Chloride 59.9 tons/hr 5.30E-04 lb/tonAP-42 Table 1.1-14 (9/98)3.17E-02 0.1391 1.39E-01 NA 3.17E-02EU 003 Boiler 3 (Subbituminous Coal/Coke) 1,1,1-trichlorothane 1097 MMBtu/hr 6.10E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)6.69E-04 0.0029 2.93E-03 NA 6.69E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Methyl Ethyl Ketone 59.9 tons/hr 3.90E-04 lb/tonAP-42 Table 1.1-14 (9/98)2.34E-02 0.1023 1.02E-01 NA 2.34E-02EU 003 Boiler 3 (Subbituminous Coal/Coke) Methyl Hydrazine 59.9 tons/hr 1.70E-04 lb/tonAP-42 Table 1.1-14 (9/98)1.02E-02 0.0446 4.46E-02 NA 1.02E-02EU 003 Boiler 3 (Subbituminous Coal/Coke) Methyl Methacrylate 1097 MMBtu/hr 1.10E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.21E-03 0.0053 5.29E-03 NA 1.21E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Methyl tert butyl ether 59.9 tons/hr 3.50E-05 lb/tonAP-42 Table 1.1-14 (9/98)2.10E-03 0.0092 9.18E-03 NA 2.10E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Methylene Chloride 1097 MMBtu/hr 3.60E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)3.95E-03 0.0173 1.73E-02 NA 3.95E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Naphthalene 1097 MMBtu/hr 6.20E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)6.80E-04 0.0030 2.98E-03 NA 6.80E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Nickel 1097 MMBtu/hr 6.57E+00 lb/10^12 BTUAP-42 Table 1.1-16 (9/98)(4.4*(C/A*PM)^.48)7.20E-03 0.0315 3.15E-02 NA 7.20E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Nitrous oxides 1097 MMBtu/hr 3.53E-03 lb/MMBtu40 CFR 983.87 16.95 16.95 NA 3.87EU 003 Boiler 3 (Subbituminous Coal/Coke) NOx59.9 tons/hr 1.20E+01 lb/tonAP-42 Table 1.1-3 (9/98)718.80 3148.34 3148.34 NA 718.80EU 003 Boiler 3 (Subbituminous Coal/Coke) Phenol 1097 MMBtu/hr 3.30E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)3.62E-03 0.0159 1.59E-02 NA 3.62E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) PM 59.9 tons/hr 4.64E+01 lb/tonAP-42 Table 1.1-4 (9/98) (10 x 4.64 %Ash)2779.36 12173.60 99.75% 30.43 1,441.46 6.95E+00 0.3 lb/MMBTUEU 003 Boiler 3 (Subbituminous Coal/Coke) PM1059.9 tons/hr 1.07E+01 lb/tonAP-42 Table 1.1-4 (9/98) (2.3 x 4.64 %Ash)639.25 2799.93 99.75% 7.00 NA 1.60E+00EU 003 Boiler 3 (Subbituminous Coal/Coke) PM2.559.9 tons/hr 1.07E+01 lb/tonAssumed same as PM10639.25 2799.93 99.75% 7.00 NA 1.60E+00EU 003 Boiler 3 (Subbituminous Coal/Coke) Condensible PM 980.0 MMBtu/hr 3.23E-01 lb/MMBtuAP-42 Table 1.1-5 (0.1 x 3.23% sulfur)316.54 1386.45 99.75% 3.47 NA 7.91E-01EU 003 Boiler 3 (Subbituminous Coal/Coke) POMs 1097 MMBtu/hr 2.08E-06 lb/10^12 BTUAP-42 Table 1.1-17 (9/98)2.28E-09 0.0000 9.99E-09 NA 2.28E-09EU 003 Boiler 3 (Subbituminous Coal/Coke) Propionaldehyde 1097 MMBtu/hr 1.90E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)2.08E-03 0.0091 9.13E-03 NA 2.08E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) Selenium 59.9 tons/hr1.30E-03lb/tonAP-42 Table 1.1-18 (9/98)7.79E-02 0.3411 3.41E-01 NA 7.79E-02EU 003 Boiler 3 (Subbituminous Coal/Coke) SO259.9 tons/hr 7.35E+00 lb/tonAP-42 Table 1.1-3 (35 x % S) [4]440.27 1928.36 1928.36 14,414.58 4.40E+02 3 lb/MMBTUEU 003 Boiler 3 (Subbituminous Coal/Coke) Styrene 1097 MMBtu/hr 7.00E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)7.68E-04 0.0034 3.36E-03 NA 7.68E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Tetrachloroethylene 1097 MMBtu/hr 4.20E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)4.61E-04 0.0020 2.02E-03 NA 4.61E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Toluene 1097 MMBtu/hr 1.70E+00 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)1.86E-03 0.0082 8.17E-03 NA 1.86E-03EU 003 Boiler 3 (Subbituminous Coal/Coke) TOTAL HAPs9.63E-01 4.22E+00 4.22E+00 NA 9.63E-01EU 003 Boiler 3 (Subbituminous Coal/Coke) Total VOC 59.9 tons/hr 6.00E-02 lb/tonAP-42 Table 1.1-193.59E+00 15.7417 1.57E+01 NA 3.59E+00EU 003 Boiler 3 (Subbituminous Coal/Coke) Vinyl Acetate 1097 MMBtu/hr 3.10E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)3.40E-04 0.0015 1.49E-03 NA 3.40E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Vinyl Chloride 1097 MMBtu/hr 7.30E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)8.01E-04 0.0035 3.51E-03 NA 8.01E-04EU 003 Boiler 3 (Subbituminous Coal/Coke) Xylenes 1097 MMBtu/hr 8.20E-01 lb/10^12 BTUEPRI Emission Factor Handbook Table 1-11 (4/02)9.00E-04 0.0039 3.94E-03 NA 9.00E-04EU 003 Boiler 3 (Waste Oil) Antimony 0.4 MGal/hr 5.25E-03 lb/10^3 GALAP-42 Table 1.3-11 (9/98) Uncontrolled2.29E-03 0.0100 1.00E-02 NA 2.29E-03 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Arsenic 0.4 MGal/hr 1.32E-03 lb/10^3 GALAP-42 Table 1.3-11 (9/98) Uncontrolled5.75E-04 0.0025 2.52E-03 NA 5.75E-04 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Beryllium 0.4 MGal/hr 2.78E-05 lb/10^3 GALAP-42 Table 1.3-11 (9/98) Uncontrolled1.21E-05 0.0001 5.30E-05 NA 1.21E-05 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Cadmium 0.4 MGal/hr 3.98E-04 lb/10^3 GALAP-42 Table 1.3-11 (9/98) Uncontrolled1.73E-04 0.0008 7.59E-04 NA 1.73E-04 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Chromium 0.4 MGal/hr 8.45E-04 lb/10^3 GALAP-42 Table 1.3-11 (9/98) Uncontrolled3.68E-04 0.0016 1.61E-03 NA 3.68E-04 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) CO 0.4 MGal/hr 5.00E+00 lb/10^3 GalAP-42 Table 1.11-2 (10/96)2.18E+00 9.5387 9.54E+00 NA 2.18E+00 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) CO258.80 MMBtu/hr 1.63E+02 lb/MMBtu40 CFR 989.59E+03 42016 4.20E+04 NA 9.59E+03 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) CO2e 58.80 MMBtu/hr 1.64E+02 lb/MMBtu40 CFR 989.63E+03 42159.9341 4.22E+04 NA 9.63E+03 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Cobalt 0.4 MGal/hr 6.02E-03 lb/10^3 GALAP-42 Table 1.3-11 (9/98) Uncontrolled2.62E-03 0.0115 1.15E-02 NA 2.62E-03 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Hydrochloric Acid 0.4 MGal/hr 3.56E+00 lb/10^3 GALAP-42 Table 1.11-3 (66 X .054% Cl)(10/96)1.55E+00 6.7992 6.80E+00 NA 1.55E+00 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Lead 0.4 MGal/hr 1.51E-03 lb/10^3 GALAP-42 Table 1.3-11 (9/98) Uncontrolled6.58E-04 0.0029 2.88E-03 NA 6.58E-04 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Manganese 0.4 MGal/hr 3.00E-03 lb/10^3 GALAP-42 Table 1.3-11 (9/98) Uncontrolled1.31E-03 0.0057 5.72E-03 NA 1.31E-03 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Mercury 0.4 MGal/hr 1.13E-04 lb/10^3 GALAP-42 Table 1.3-11 (9/98) Uncontrolled4.92E-05 0.0002 2.16E-04 NA 4.92E-05 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Methane 58.80 MMBtu/hr 6.61E-03 lb/MMBtu40 CFR 983.89E-01 1.7033 1.70E+00 NA 3.89E-01 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Nickel 0.4 MGal/hr 8.45E-02 lb/10^3 GALAP-42 Table 1.3-11 (9/98) Uncontrolled3.68E-02 0.1612 1.61E-01 NA 3.68E-02 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Nitrous oxides 58.80 MMBtu/hr 1.32E-03 lb/MMBtu40 CFR 987.78E-02 0.3407 3.41E-01 NA 7.78E-02 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) NOx0.4 MGal/hr 1.90E+01 lb/10^3 GalAP-42 Table 1.11-2 (10/96)8.28 36.2469 3.62E+01 NA 8.28E+00 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) PM 0.4 MGal/hr 6.40E+01 lb/10^3 GalAP-42 Table 1.11-1 (64 X 1% Ash) (10/96)[4]27.88 122.0949 99.75% 3.05E-01 NA 6.97E-02 5% of fuel mass or heat value; 0.3 lb/MMBtuEU 003 Boiler 3 (Waste Oil) PM100.4 MGal/hr 5.10E+01 lb/10^3 GalAP-42 Table 1.11-1 (51 X 1 % Ash)(10/96) [4]22.21 97.2944 99.75% 2.43E-01 NA 5.55E-02 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) PM2.50.4 MGal/hr 5.10E+01 lb/10^3 GalAP-42 Table 1.11-1 (51 X 1 % Ash)(10/96) [4]22.21 97.2944 99.75% 2.43E-01 NA 5.55E-02 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Selenium 0.4 MGal/hr 6.83E-04 lb/10^3 GALAP-42 Table 1.3-11 (9/98) Uncontrolled2.97E-04 0.0013 1.30E-03 NA 2.97E-04 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) SO20.4 MGal/hr 5.29E+02 lb/10^3 GalAP-42 Table 1.11-2 (147 X 1 % S) (10/96)[4]230.50 1009.57 1009.57 412.07 9.41E+01 5% of fuel mass or heat value; 1.6 lb/mmbtuEU 003 Boiler 3 (Waste Oil) TOTAL HAPs1.60E+00 7.00E+00 7.00E+00 NA 1.60E+00 5% of fuel mass or heat valueEU 003 Boiler 3 (Waste Oil) Total VOC 0.4 MGal/hr 1.00E+00 lb/10^3 GalAP-42 Table 1.11-3 (10/96)4.36E-01 1.9077 1.91E+00 NA 4.36E-01 5% of fuel mass or heat value[1] See annual emissions inventories.[2] SO2 emission factor in lbs/1000 gal is 0.01 x S; where S is Sulfur content in gr/100 ft3. Propane sulfur content is 8 gr/100 ft3.[3] 4 ignitors/boiler on propane @ 6 PSI rated at 41.5 MMBTU/hr[4] % ash and % sulfur used is 2010-2011 average from Black Dog coal samples.[5] Pollution control efficiencies were based on test data for subbit and bit coal. For all other fuels, control efficiencieswere based on MPCA Table GI 05-A.1 ESP efficiencies for a boiler.[6] In many cases for HAPs, uncontrolled lb/hr stated is actually controlled lb/hr. Uncontrolled rate not always known.EU 004 Boiler 4 (Bituminous Coal) 1892 MMBtu/hr Bit Coal Ash% 1.15E+01Boiler 4 (Bituminous Coal) 90.1 tons/hr Bit Coal S% 3.23E+00Boiler 4 (Subbituminous Coal) 1890 MMBtu/hr Subbit Coal Ash% 4.64E+00Boiler 4 (Subbituminous Coal) 108 tons/hr Subbit Coal S% 2.10E-01Boiler 4 (Pet Coke) 6.3 tons/hr Pet Coke Ash% 3.00E-01Boiler 4 (Pet Coke) 30 MMBtu/ton burned Pet Coke S% 5.67E+00Boiler 4 (Subbituminous Coal/Coke) 114.3 tons/hrBoiler 4 (Subbituminous Coal/Coke) 1890 MMBtu/hrBoiler 4 (Waste Oil) 0.70 1000 gal/hr Waste oil Ash% 1.00E+00Boiler 4 (Waste Oil) 135 MMBtu/1000 gal burned Waste Oil S% 2.40E-02Boiler 4 (Natural Gas) 1.9 MMCF/hrWaste oil MMBtu/hr95Boiler 4 (Propane) 0.452 1000 gal/hrBoiler 4 (Propane) 166 MMBtu/hrXcel Energy - Black Dog Generating PlantParticulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficientPotential to EmitShading = Worst Case for Specified Pollutant for Specified UnitEmissionUnit ID Unit NamePollutantMax ProcessRateProcess RateUnitsEmissionFactor Emission FactorUnits Emission Factor SourceEmissionRate(lb/hr)UncontrolledPotential toEmit(ton/yr)PollutionControlEfficiency(%)ControlledPotential toEmit (ton/yr)Limited/ControlledPotential toEmit (ton/yr)Limited/ControlledPTE (lb/hr) Existing Permit LimitEU 004 Boiler 4 (Bituminous Coal) 1,2,4-Trichlorobenzene 1892 MMBtu/hr 1.50E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11(4/02) 2.84E-03 1.24E-02 1.24E-02 NA 2.84E-03EU 004 Boiler 4 (Bituminous Coal) 1,4-Dichlorobenzene 1892 MMBtu/hr 1.10E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 2.08E-03 9.12E-03 9.12E-03 NA 2.08E-03EU 004 Boiler 4 (Bituminous Coal) 2,4-Dinitrotoluene 1892 MMBtu/hr 2.00E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 3.78E-04 1.66E-03 1.66E-03 NA 3.78E-04EU 004 Boiler 4 (Bituminous Coal) Acetaldehyde 1892 MMBtu/hr 3.20E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 6.05E-03 2.65E-02 2.65E-02 NA 6.05E-03EU 004 Boiler 4 (Bituminous Coal) Acetophenone 1892 MMBtu/hr 1.20E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 2.27E-03 9.94E-03 9.94E-03 NA 2.27E-03EU 004 Boiler 4 (Bituminous Coal) Acrolein 1892 MMBtu/hr 1.90E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 3.59E-031.57E-02 1.57E-02 NA 3.59E-03EU 004 Boiler 4 (Bituminous Coal) Antimony 90.1 tons/hr 1.80E-05 lb/ton AP-42 Table 1.1-18 (9/98) 1.62E-03 7.10E-03 7.10E-03 NA 1.62E-03EU 004 Boiler 4 (Bituminous Coal) Arsenic 90.1 tons/hr 4.10E-04 lb/ton AP-42 Table 1.1-18 (9/98) 3.69E-02 1.62E-01 1.62E-01 NA 3.69E-02EU 004 Boiler 4 (Bituminous Coal) Benzene 1892 MMBtu/hr 3.90E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 7.38E-03 3.23E-02 3.23E-02 NA 7.38E-03EU 004 Boiler 4 (Bituminous Coal) Benzyl Chloride 1892 MMBtu/hr 2.80E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 5.30E-04 2.32E-03 2.32E-03 NA 5.30E-04EU 004 Boiler 4 (Bituminous Coal) Beryllium 90.1 tons/hr 2.10E-05 lb/ton AP-42 Table 1.1-18 (9/98) 1.89E-03 8.29E-03 8.29E-03 NA 1.89E-03EU 004 Boiler 4 (Bituminous Coal) Biphenyl 1892 MMBtu/hr 1.60E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 3.03E-041.33E-03 1.33E-03 NA 3.03E-04EU 004 Boiler 4 (Bituminous Coal) bis(2-Ethylexyl)phthalate 1892 MMBtu/hr 3.60E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 6.81E-03 2.98E-02 2.98E-02 NA 6.81E-03EU 004 Boiler 4 (Bituminous Coal) Cadmium 90.1 tons/hr 5.10E-05 lb/ton AP-42 Table 1.1-18 (9/98) 4.60E-03 2.01E-02 2.01E-02 NA 4.60E-03EU 004 Boiler 4 (Bituminous Coal) Carbon Disulfide 1892 MMBtu/hr 1.10E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02)2.08E-03 9.12E-03 9.12E-03 NA 2.08E-03EU 004 Boiler 4 (Bituminous Coal) Chlorobenzene 1892 MMBtu/hr 1.60E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 3.03E-04 1.33E-03 1.33E-03 NA 3.03E-04EU 004 Boiler 4 (Bituminous Coal) Chloroform 1892 MMBtu/hr 8.00E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.51E-03 6.63E-03 6.63E-03 NA 1.51E-03EU 004 Boiler 4 (Bituminous Coal) Chromium 90.1 tons/hr 2.60E-04 lb/ton AP-42 Table 1.1-18 (9/98) 2.34E-02 1.03E-01 1.03E-01 NA 2.34E-02EU 004 Boiler 4 (Bituminous Coal) CO 90.1 tons/hr 5.00E-01 lb/ton AP-42 Table 1.1-3 (9/98) 45.05 197.32 197.32 NA 4.51E+01EU 004 Boiler 4 (Bituminous Coal) CO21892 MMBtu/hr 2.06E+02 lb/MMBtu 40 CFR 98 389080.51 1704172.62 1704172.62 NA 3.89E+05EU 004 Boiler 4 (Bituminous Coal) CO2e 1892 MMBtu/hr 2.07E+02 lb/MMBtu 40 CFR 98 392216.34 1717907.58 1717907.58 NA 3.92E+05EU 004 Boiler 4 (Bituminous Coal) Cobalt 90.1 tons/hr 1.00E-04 lb/ton AP-42 Table 1.1-18 (9/98) 9.01E-03 0.0395 3.95E-02 NA 9.01E-03EU 004 Boiler 4 (Bituminous Coal) Cyanide 90.1 tons/hr 2.50E-03 lb/ton AP-42 Table 1.1-14 (9/98) 2.25E-01 9.87E-01 9.87E-01 NA 2.25E-01EU 004 Boiler 4 (Bituminous Coal) DEHP 90.1 tons/hr 7.30E-05 lb/ton AP-42 Table 1.1-14 (9/98) 6.58E-03 2.88E-02 2.88E-02 NA 6.58E-03EU 004 Boiler 4 (Bituminous Coal) Dibenzofuran 1892 MMBtu/hr 5.80E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.10E-03 4.81E-03 4.81E-03 NA 1.10E-03EU 004 Boiler 4 (Bituminous Coal) Dibutylphthalate 1892 MMBtu/hr 1.10E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02)2.08E-04 9.12E-04 9.12E-04 NA 2.08E-04EU 004 Boiler 4 (Bituminous Coal) Dimethyl Sulfate 90.1 tons/hr 4.80E-05 lb/ton AP-42 Table 1.1-14 (9/98) 4.32E-03 1.89E-02 1.89E-02 NA 4.32E-03EU 004 Boiler 4 (Bituminous Coal) Ethyl Benzene 1892 MMBtu/hr 8.00E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.51E-03 6.63E-03 6.63E-03 NA 1.51E-03EU 004 Boiler 4 (Bituminous Coal) chloroethane 90.1 tons/hr 4.20E-05 lb/ton AP-42 Table 1.1-14 (9/98) 3.78E-03 1.66E-02 1.66E-02 NA 3.78E-03EU 004 Boiler 4 (Bituminous Coal) Ethylene Dibromide 90.1 tons/hr 1.20E-06 lb/ton AP-42 Table 1.1-14 (9/98) 1.08E-04 4.74E-04 4.74E-04 NA 1.08E-04EU 004 Boiler 4 (Bituminous Coal) 1,2-dichloreothane 90.1 tons/hr 4.00E-05 lb/ton AP-42 Table 1.1-14 (9/98) 3.60E-03 1.58E-02 1.58E-02 NA 3.60E-03EU 004 Boiler 4 (Bituminous Coal) Formaldehyde 1892 MMBtu/hr 2.60E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 4.92E-03 2.15E-02 2.15E-02 NA 4.92E-03EU 004 Boiler 4 (Bituminous Coal) Hexane 90.1 tons/hr 6.70E-05 lb/ton AP-42 Table 1.1-14 (9/98) 6.04E-03 2.64E-02 2.64E-02 NA 6.04E-03EU 004 Boiler 4 (Bituminous Coal) Hydrochloric Acid 1892 MMBtu/hr 5.93E-02 lb/10^12 BTUAssume 750 ppm Cl (EPRI Pisces Database 08/98)in coal gets converted to HCl and 100% (EPRIEmissions Factor Handbook 4/02) goes toatmosphere. Assume 13000 Btu/lb (1999Performance Report)1.12E-04 4.91E-04 4.91E-04 NA 1.12E-04EU 004 Boiler 4 (Bituminous Coal) Hydrogen Fluoride 1892 MMBtu/hr 5.26E-03 lb/10^12 BTUAssume 65 ppm F (EPRI Pisces Database 08/98) incoal gets converted to HF and 90% (EPRI EmissionsFactor Handbook 4/02) goes to atmosphere.Assume 13000 Btu/lb (1999 Performance Report)9.96E-06 4.36E-05 4.36E-05 NA 9.96E-06EU 004 Boiler 4 (Bituminous Coal) Isophorone 1892 MMBtu/hr 1.20E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 2.27E-03 9.94E-03 9.94E-03 NA 2.27E-03EU 004 Boiler 4 (Bituminous Coal) Lead 90.1 tons/hr 2.60E-04 lb/ton AP-42 Table 1.1-18 (9/98) 2.34E-02 1.03E-01 1.03E-01 NA 2.34E-02EU 004 Boiler 4 (Bituminous Coal) Manganese 90.1 tons/hr 1.10E-02 lb/ton AP-42 Table 1.1-18 (9/98) 9.91E-01 4.3410 4.34E+00 NA 9.91E-01EU 004 Boiler 4 (Bituminous Coal) Mercury 90.1 tons/hr 8.30E-05 lb/ton AP-42 Table 1.1-18 (9/98) 7.48E-03 3.28E-02 3.28E-02 NA 7.48E-03EU 004 Boiler 4 (Bituminous Coal) Methane 1892 MMBtu/hr 2.43E-02 lb/MMBtu 40 CFR 98 4.59E+01 200.9638 2.01E+02 NA 4.59E+01EU 004 Boiler 4 (Bituminous Coal) bromomethane 90.1 tons/hr 1.60E-04 lb/ton AP-42 Table 1.1-14 (9/98) 1.44E-02 6.31E-02 6.31E-02 NA 1.44E-02EU 004 Boiler 4 (Bituminous Coal) Methyl Chloride 90.1 tons/hr 5.30E-04 lb/ton AP-42 Table 1.1-14 (9/98) 4.78E-02 2.09E-01 2.09E-01 NA 4.78E-02EU 004 Boiler 4 (Bituminous Coal) 1,1,1-trichloroethane 1892 MMBtu/hr 6.10E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.15E-03 5.06E-03 5.06E-03 NA 1.15E-03EU 004 Boiler 4 (Bituminous Coal) Methyl Ethyl Ketone 90.1 tons/hr 3.90E-04 lb/ton AP-42 Table 1.1-14 (9/98) 3.51E-02 1.54E-01 1.54E-01 NA3.51E-02EU 004 Boiler 4 (Bituminous Coal) Methyl Hydrazine 90.1 tons/hr 1.70E-04 lb/ton AP-42 Table 1.1-14 (9/98) 1.53E-02 6.71E-02 6.71E-02 NA 1.53E-02EU 004 Boiler 4 (Bituminous Coal) Methyl Methacrylate 1892 MMBtu/hr 1.10E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 2.08E-03 9.12E-03 9.12E-03 NA 2.08E-03EU 004 Boiler 4 (Bituminous Coal) Methyl tert butyl ether 90.1 tons/hr 3.50E-05 lb/ton AP-42 Table 1.1-14 (9/98) 3.15E-03 1.38E-02 1.38E-02 NA 3.15E-03EU 004 Boiler 4 (Bituminous Coal) Methylene Chloride 1892 MMBtu/hr 3.60E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 6.81E-03 2.98E-02 2.98E-02 NA 6.81E-03EU 004 Boiler 4 (Bituminous Coal) Naphthalene 1892 MMBtu/hr 6.20E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.17E-03 5.14E-03 5.14E-03 NA 1.17E-03EU 004 Boiler 4 (Bituminous Coal) Nickel 90.1 tons/hr 2.80E-04 lb/ton AP-42 Table 1.1-18 (9/98) 2.52E-02 1.10E-01 1.10E-01 NA 2.52E-02EU 004 Boiler 4 (Bituminous Coal) Nitrous oxides 1892 MMBtu/hr 3.53E-03 lb/MMBtu 40 CFR 98 6.67 29.23 29.23 NA 6.67E+00EU 004 Boiler 4 (Bituminous Coal) NOX90.1 tons/hr 2.20E+01 lb/ton AP-42 Table 1.1-3 (9/98) 1982.20 8682.04 8682.04 NA 1.98E+03EU 004 Boiler 4 (Bituminous Coal) Phenol 1892 MMBtu/hr 3.30E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 6.24E-03 0.0273 2.73E-02 NA 6.24E-03EU 004 Boiler 4 (Bituminous Coal) PM 90.1 tons/hr 1.15E+02 lb/ton AP-42 Table 1.1-4 (9/98) (10 x 11.5 % Ash) 10361.50 45383.37 99.75% 113.46 2,486.09 2.59E+01 0.3 lb/MMBTUEU 004 Boiler 4 (Bituminous Coal) PM1090.1 tons/hr 2.65E+01 lb/ton AP-42 Table 1.1-4 (9/98) (2.3 x 11.5 % Ash) 2383.15 10438.18 99.75% 26.10 NA 5.96E+00EU 004 Boiler 4 (Bituminous Coal) PM2.590.1 tons/hr 2.65E+01 lb/ton Assumed same as PM10 2383.15 10438.18 99.75% 26.10 NA 5.96E+00Boiler 4 (Bituminous Coal) Condensible PM 1892.0 MMBtu/hr 3.23E-01 lb/MMBtu AP-42 Table 1.1-5 (0.1 x 3.23% sulfur) 611.12 2676.69 99.75%6.69 NA 1.53E+00EU 004 Boiler 4 (Bituminous Coal) POMs 1892 MMBtu/hr 2.08E-06 lb/10^12 BTU AP-42 Table 1.1-17 (9/98) 3.94E-09 0.0000 1.72E-08 NA 3.94E-09EU 004 Boiler 4 (Bituminous Coal) Propionaldehyde 1892 MMBtu/hr 1.90E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 3.59E-03 0.0157 1.57E-02 NA 3.59E-03EU 004 Boiler 4 (Bituminous Coal) Selenium 90.1 tons/hr 1.30E-03 lb/ton AP-42 Table 1.1-18 (9/98) 1.17E-01 0.5130 5.13E-01 NA 1.17E-01EU 004 Boiler 4 (Bituminous Coal) SO290.1 tons/hr 1.23E+02 lb/ton AP-42 Table 1.1-3 (9/98) (38 x 3.23 % S) 11058.87 48437.8681 48437.87 24,860.88 5676.00 3 lb/MMBTUEU 004 Boiler 4 (Bituminous Coal) Styrene 1892 MMBtu/hr 7.00E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.32E-03 5.80E-03 5.80E-03 NA 1.32E-03EU 004 Boiler 4 (Bituminous Coal) Tetrachloroethylene 1892 MMBtu/hr 4.20E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 7.95E-04 3.48E-03 3.48E-03 NA 7.95E-04Xcel Energy - Black Dog Generating PlantParticulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficientPotential to EmitShading = Worst Case for Specified Pollutant for Specified UnitEmissionUnit ID Unit NamePollutantMax ProcessRateProcess RateUnitsEmissionFactor Emission FactorUnits Emission Factor SourceEmissionRate(lb/hr)UncontrolledPotential toEmit(ton/yr)PollutionControlEfficiency(%)ControlledPotential toEmit (ton/yr)Limited/ControlledPotential toEmit (ton/yr)Limited/ControlledPTE (lb/hr) Existing Permit LimitEU 004 Boiler 4 (Bituminous Coal) Toluene 1892 MMBtu/hr 1.70E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 3.22E-03 1.41E-02 1.41E-02 NA 3.22E-03EU 004 Boiler 4 (Bituminous Coal) TOTAL HAPs1.65E+00 7.21 7.21E+00 NA 1.65E+00EU 004 Boiler 4 (Bituminous Coal) Total VOC 90.1 tons/hr 6.00E-02 lb/ton AP-42 Table 1.1-19 (9/98) 5.41E+00 23.6783 2.37E+01 NA 5.41E+00EU 004 Boiler 4 (Bituminous Coal) Vinyl Acetate 1892 MMBtu/hr 3.10E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 5.87E-04 2.57E-03 2.57E-03 NA 5.87E-04EU 004 Boiler 4 (Bituminous Coal) Vinyl Chloride 1892 MMBtu/hr 7.30E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.38E-03 6.05E-03 6.05E-03 NA 1.38E-03EU 004 Boiler 4 (Bituminous Coal) Xylenes 1892 MMBtu/hr 8.20E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.55E-03 6.80E-03 6.80E-03 NA 1.55E-030.00E+00 0.00E+00EU 004 Boiler 4 (Coke) CO2189 MMBtu/hr 2.26E+02 lb/MMBtu 40 CFR 98 4.27E+04 186899 1.87E+05 NA 4.27E+04EU 003 Boiler 4 (Coke) CO2e 189 MMBtu/hr 2.27E+02 lb/MMBtu 40 CFR 98 4.30E+04 188271.5201 1.88E+05 NA 4.30E+040.00E+00 0.00E+00EU 004 Boiler 4 (Natural Gas) Arsenic 1938 MMBtu/hr 2.30E-01 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 4.46E-04 0.0020 1.95E-03 NA 4.46E-04EU 004 Boiler 4 (Natural Gas) Benzene 1938 MMBtu/hr 8.00E-01 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 1.55E-03 0.0068 6.79E-03 NA 1.55E-03EU 004 Boiler 4 (Natural Gas) Beryllium1938 MMBtu/hr 1.00E-02 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 1.94E-05 0.0001 8.49E-05 NA 1.94E-05EU 004 Boiler 4 (Natural Gas) Cadmium 1938 MMBtu/hr 4.00E-02 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 7.75E-05 0.0003 3.40E-04 NA 7.75E-05EU 004 Boiler 4 (Natural Gas) Chromium 1938 MMBtu/hr 1.10E+00 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 2.13E-03 0.0093 9.34E-03 NA 2.13E-03EU 004 Boiler 4 (Natural Gas) CO 1.9 MMCF/hr 8.40E+01 lb/MMCF AP-42 Table 1.4-1 (7/98) 1.60E+02 699.0480 6.99E+02 NA 1.60E+02EU 004 Boiler 4 (Natural Gas) CO21938 MMBtu/hr 1.17E+02 lb/MMBtu 40 CFR 98 2.27E+05 992944 9.93E+05 NA 2.27E+05EU 004 Boiler 4 (Natural Gas) CO2e 1938 MMBtu/hr 1.17E+02 lb/MMBtu 40 CFR 98 2.27E+05 993969.9087 9.94E+05 NA 2.27E+05EU 004 Boiler 4 (Natural Gas) Cobalt 1938 MMBtu/hr 8.00E-02 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 1.55E-04 0.00076.79E-04 NA 1.55E-04EU 004 Boiler 4 (Natural Gas) Formaldehyde 1938 MMBtu/hr 1.75E-04 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 3.39E-070.0000 1.49E-06 NA 3.39E-07EU 004 Boiler 4 (Natural Gas) Hexane 1.9 MMCF/hr 1.80E+00 lb/MMCF AP-42 Table 1.4-3 (7/98) 3.42E+00 14.9796 1.50E+01 NA 3.42E+00EU 004 Boiler 4 (Natural Gas) Lead 1938 MMBtu/hr 4.00E-01 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 7.75E-04 0.0034 3.40E-03 NA 7.75E-04EU 004 Boiler 4 (Natural Gas) Manganese 1938 MMBtu/hr 4.00E-01 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 7.75E-04 0.0034 3.40E-03 NA 7.75E-04EU 004 Boiler 4 (Natural Gas) Mercury 1938 MMBtu/hr 8.00E-04 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 1.55E-06 0.0000 6.79E-06 NA 1.55E-06EU 004 Boiler 4 (Natural Gas) Methane 1938 MMBtu/hr 2.20E-03 lb/MMBtu 40 CFR 98 4.27E+00 18.7136 1.87E+01 NA 4.27E+00EU 004 Boiler 4 (Natural Gas) Naphthalene 1.9 MMCF/hr 6.10E-04 lb/MMCF AP-42 Table 1.4-3 (7/98) 1.16E-03 0.0051 5.08E-03 NA 1.16E-03EU 004 Boiler 4 (Natural Gas) Nickel 1938 MMBtu/hr 2.40E+00 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 4.65E-03 0.02042.04E-02 NA 4.65E-03EU 004 Boiler 4 (Natural Gas) Nitrous oxides 1938 MMBtu/hr 2.20E-04 lb/MMBtu 40 CFR 98 4.27E-01 1.8714 1.87E+00 NA 4.27E-01EU 004 Boiler 4 (Natural Gas) NOx1.9 MMCF/hr 2.80E+02 lb/MMCF AP-42 Table 1.4-1 (7/98) 5.32E+02 2330.1600 2.33E+03 NA 5.32E+02EU 004 Boiler 4 (Natural Gas) PM 1.9 MMCF/hr 7.60E+00 lb/MMCF AP-42 Table 1.4-2 (7/98) 1.44E+01 63.2472 6.32E+01 NA 1.44E+01 0.3 lb/MMBTUEU 004 Boiler 4 (Natural Gas) PM101.9 MMCF/hr 7.60E+00 lb/MMCF AP-42 Table 1.4-2 (7/98) 1.44E+01 63.2472 6.32E+01 NA 1.44E+01EU 004 Boiler 4 (Natural Gas) PM2.51.9 MMCF/hr 7.60E+00 lb/MMCF 1.44E+01 63.2472 6.32E+01 NA 1.44E+01EU 004 Boiler 4 (Natural Gas) POMs 1.9 MMCF/hr 6.94E-05 lb/MMCF AP-42 Table 1.4-3 (7/98) - sum of all POMs listed 1.32E-04 0.0006 5.78E-04 NA 1.32E-04EU 004 Boiler 4 (Natural Gas) Selenium 1938 MMBtu/hr 2.00E-02 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 3.88E-05 0.0002 1.70E-04 NA 3.88E-05EU 004 Boiler 4 (Natural Gas) SO21.9 MMCF/hr 6.00E-01 lb/MMCF AP-42 Table 1.4-2 (7/98) 1.14E+00 4.9932 4.99E+00 NA 1.14E+00 3 lb/MMBTUEU 004 Boiler 4 (Natural Gas) Toluene 1938 MMBtu/hr 1.00E+01 lb/10^12 BTU EPRI Emissions Factor Handbook Table 3-1 (4/02) 1.94E-02 0.0849 8.49E-02 NA 1.94E-02EU 004 Boiler 4 (Natural Gas) TOTAL HAPs3.45E+00 1.51E+01 1.51E+01 NA 3.45E+00EU 004 Boiler 4 (Natural Gas) Total VOC 1.9 MMCF/hr 5.50E+00 lb/MMCF AP-42 Table 1.4-2 (7/98) 1.05E+01 45.7710 4.58E+01 NA 1.05E+010.00E+00 0.00E+00EU 004 Boiler 4 (Propane) CO 0.45 1000gal/hr 7.5E+00 lb/10^3 GAL AP-42 Table 1.5-1 (7/08) 3.39E+00 14.8482 1.48E+01 NA 3.39E+00EU 004 Boiler 4 (Propane) CO294.60 MMBtu/hr 1.39E+02 lb/MMBtu 40 CFR 98 1.31E+04 57430 5.74E+04 NA 1.31E+04EU 004 Boiler 4 (Propane) CO2e 166 MMBtu/hr 1.39E+02 lb/MMBtu 40 CFR 98 2.31E+04 101182.4374 1.01E+05 NA 2.31E+04EU 004 Boiler 4 (Propane) Methane 166 MMBtu/hr 6.61E-03 lb/MMBtu 40 CFR 98 1.10E+00 4.8088 4.81E+00 NA 1.10E+00EU 004 Boiler 4 (Propane) Nitrous oxides 166 MMBtu/hr 1.32E-03 lb/MMBtu 40 CFR 98 2.20E-01 0.9618 9.62E-01 NA 2.20E-01EU 004 Boiler 4 (Propane) NOx0.45 1000gal/hr 1.3E+01 lb/10^3 GAL AP-42 Table 1.5-1 (7/08) 5.88E+00 25.7369 2.57E+01 NA 5.88E+00EU 004 Boiler 4 (Propane) PM 0.45 1000gal/hr 2.00E-01 lb/10^3 GAL AP-42 Table 1.5-1 (7/08), Filterable 9.04E-02 0.3960 3.96E-01 NA 9.04E-02EU 004 Boiler 4 (Propane) PM100.45 1000gal/hr 7.00E-01 lb/10^3 GAL AP-42 Table 1.5-1 (7/08), Filterable + Condensables 3.16E-01 1.3858 1.39E+00 NA 3.16E-01EU 004 Boiler 4 (Propane) PM2.50.45 1000gal/hr 7.00E-01 lb/10^3 GAL AP-42 Table 1.5-1 (7/08), Filterable + Condensables 3.16E-01 1.3858 1.39E+00 NA 3.16E-01EU 004 Boiler 4 (Propane) SO2[2]0.45 1000gal/hr 8.00E-01 lb/10^3 GAL AP-42 Table 1.5-1 (7/08) 3.62E-01 1.5838 1.58E+00 NA 3.62E-01EU 004 Boiler 4 (Propane) Total VOC 0.45 1000gal/hr 1.0E+00 lb/10^3 GAL AP-42 Table 1.5-1 (7/08) 4.52E-01 1.9798 1.98E+00 NA 4.52E-010.00E+00 0.00E+00EU 004 Boiler 4 (Subbituminous Coal) CO21890 MMBtu/hr 2.10E+02 lb/MMBtu 40 CFR 98 396446.61 1736436 1.74E+06 NA 3.96E+05EU 004 Boiler 4 (Subbituminous Coal) CO2e 1890 MMBtu/hr 2.11E+02 lb/MMBtu 40 CFR 98 399579.13 1750156.5893 1.75E+06 NA 4.00E+05EU 004 Boiler 4 (Subbituminous Coal/Coke) 1,2,4-Trichlorobenzene 1890 MMBtu/hr 1.50E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 2.84E-03 0.0124 1.24E-02 NA 2.84E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) 1,4-Dichlorobenzene 1890 MMBtu/hr 1.10E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table1-11 (4/02) 2.08E-03 0.0091 9.11E-03 NA 2.08E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) 2,4-Dinitrotoluene 1890 MMBtu/hr 2.00E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 3.78E-04 0.0017 1.66E-03 NA 3.78E-04EU 004 Boiler 4 (Subbituminous Coal/Coke) Acetaldehyde 1890 MMBtu/hr 3.20E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 6.05E-03 0.0265 2.65E-02 NA 6.05E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Acetophenone 1890 MMBtu/hr 1.20E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 2.27E-03 0.0099 9.93E-03 NA 2.27E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Acrolein 1890 MMBtu/hr 1.90E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02)3.59E-03 0.0157 1.57E-02 NA 3.59E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Antimony 1890 MMBtu/hr 4.09E-02 lb/10^12 BTU AP-42 Table 1.1-16 (9/98) (0.92*(C/A*PM)^0.63) 7.73E-05 0.0003 3.39E-04 NA 7.73E-05EU 004 Boiler 4 (Subbituminous Coal/Coke) Arsenic 1890 MMBtu/hr 2.07E+00 lb/10^12 BTU AP-42 Table 1.1-16 (9/98) (3.1*(C/A*PM)^0.85) 3.91E-03 0.0171 1.71E-02 NA 3.91E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Benzene 1890 MMBtu/hr 3.90E-06 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 7.37E-09 0.0000 3.23E-08 NA 7.37E-09EU 004 Boiler 4 (Subbituminous Coal/Coke) Benzyl Chloride 1890 MMBtu/hr 2.80E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11(4/02) 5.29E-04 0.0023 2.32E-03 NA 5.29E-04EU 004 Boiler 4 (Subbituminous Coal/Coke) Beryllium1890 MMBtu/hr 1.93E-01 lb/10^12 BTU AP-42 Table 1.1-16 (9/98) (1.2*(C/A*PM)^1.1) 3.64E-04 0.0016 1.60E-03 NA 3.64E-04EU 004 Boiler 4 (Subbituminous Coal/Coke) Biphenyl 1890 MMBtu/hr 1.60E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02)3.02E-04 0.0013 1.32E-03 NA 3.02E-04EU 004 Boiler 4 (Subbituminous Coal/Coke) bis(2-Ethylexyl)phthalate 1890 MMBtu/hr 3.60E+00 lb/10^12 BTU EPRI Emission Factor HandbookTable 1-11 (4/02) 6.80E-03 0.0298 2.98E-02 NA 6.80E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Cadmium 1890 MMBtu/hr 6.13E-01 lb/10^12 BTU AP-42 Table 1.1-16 (9/98) (3.3*(C/A*PM)^0.5) 1.16E-03 0.0051 5.07E-03 NA 1.16E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Carbon Disulfide 1890 MMBtu/hr 1.10E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 2.08E-03 0.0091 9.11E-03 NA 2.08E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Chlorobenzene 1890 MMBtu/hr 1.60E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 3.02E-04 0.0013 1.32E-03 NA 3.02E-04EU 004 Boiler 4 (Subbituminous Coal/Coke) Chloroform 1890 MMBtu/hr 8.00E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.51E-03 0.0066 6.62E-03 NA 1.51E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Chromium 1890 MMBtu/hr 6.54E+00 lb/10^12 BTU AP-42 Table 1.1-16 (9/98) (3.7*(C/A*PM)^0.58) 1.24E-02 0.0542 5.42E-02 NA 1.24E-02EU 004 Boiler 4 (Subbituminous Coal/Coke) CO 114.3 tons/hr 5.00E-01 lb/ton AP-42 Table 1.1-3 (9/98) 5.72E+01 250.3170 2.50E+02 NA 5.72E+01EU 004 Boiler 4 (Subbituminous Coal/Coke) Cobalt 1890 MMBtu/hr 1.98E+00 lb/10^12 BTU AP-42 Table 1.1-16 (9/98) (1.7*(C/A*PM)^0.69) 3.75E-03 0.0164 1.64E-02 NA 3.75E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Cyanide 114.3 tons/hr 2.50E-03 lb/ton AP-42 Table 1.1-14 (9/98) 2.86E-01 1.2516 1.25E+00 NA 2.86E-01EU 004 Boiler 4 (Subbituminous Coal/Coke) DEHP 114.3 tons/hr 7.30E-05 lb/ton AP-42 Table 1.1-14 (9/98) 8.34E-03 0.0365 3.65E-02 NA 8.34E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Dibenzofuran 1890 MMBtu/hr 5.80E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.10E-03 0.0048 4.80E-03 NA 1.10E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Dibutylphthalate 1890 MMBtu/hr 1.10E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 2.08E-04 0.0009 9.11E-04 NA 2.08E-04EU 004 Boiler 4 (Subbituminous Coal/Coke) Dimethyl Sulfate 114.3 tons/hr 4.80E-05 lb/ton AP-42 Table 1.1-14 (9/98) 5.49E-03 0.0240 2.40E-02 NA 5.49E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Ethyl Benzene 1890 MMBtu/hr 8.00E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.51E-03 0.0066 6.62E-03 NA 1.51E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) chloroethane 114.3 tons/hr 4.20E-05 lb/ton AP-42 Table 1.1-14 (9/98) 4.80E-03 0.0210 2.10E-02 NA4.80E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Ethylene Dibromide 114.3 tons/hr 1.20E-06 lb/ton AP-42 Table 1.1-14 (9/98) 1.37E-04 0.0006 6.01E-04 NA 1.37E-04EU 004 Boiler 4 (Subbituminous Coal/Coke) 1,2-dichloreothane 114.3 tons/hr 4.00E-05 lb/ton AP-42 Table 1.1-14 (9/98) 4.57E-03 0.0200 2.00E-02 NA 4.57E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Formaldehyde 1890 MMBtu/hr 2.60E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 4.91E-03 0.0215 2.15E-02 NA 4.91E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Hexane 114.3 tons/hr 6.70E-05 lb/ton AP-42 Table 1.1-14 (9/98) 7.66E-03 0.0335 3.35E-02 NA 7.66E-03Xcel Energy - Black Dog Generating PlantParticulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficientPotential to EmitShading = Worst Case for Specified Pollutant for Specified UnitEmissionUnit ID Unit NamePollutantMax ProcessRateProcess RateUnitsEmissionFactor Emission FactorUnits Emission Factor SourceEmissionRate(lb/hr)UncontrolledPotential toEmit(ton/yr)PollutionControlEfficiency(%)ControlledPotential toEmit (ton/yr)Limited/ControlledPotential toEmit (ton/yr)Limited/ControlledPTE (lb/hr) Existing Permit LimitEU 004 Boiler 4 (Subbituminous Coal/Coke) Hydrochloric Acid 114.3 tons/hr 6.65E-03 lb/tonEPRI Emission Factor Handbook Table 1-8 (4/02),with 16.17 ppm Cl7.60E-01 3.3292 3.33E+00 NA 7.60E-01EU 004 Boiler 4 (Subbituminous Coal/Coke) Hydrogen Fluoride 114.3 tons/hr 3.02E-03 lb/tonEPRI Emission Factor Handbook Table 1-9 (4/02),with 25.67 ppm F3.45E-01 1.5127 1.51E+00 NA 3.45E-01EU 004 Boiler 4 (Subbituminous Coal/Coke) Isophorone 1890 MMBtu/hr 1.20E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 2.27E-03 0.0099 9.93E-03 NA 2.27E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Lead 1890 MMBtu/hr 6.00E+00 lb/10^12 BTU AP-42 Table 1.1-16 (9/98) (3.4*(C/A*PM)^.8) 1.13E-020.0497 4.97E-02 NA 1.13E-02EU 004 Boiler 4 (Subbituminous Coal/Coke) Manganese 1890 MMBtu/hr 1.27E+01 lb/10^12 BTU AP-42 Table 1.1-16 (9/98) (3.8*(C/A*PM)^.6) 2.39E-02 0.1049 1.05E-01 NA 2.39E-02EU 004 Boiler 4 (Subbituminous Coal/Coke) Mercury 1890 MMBtu/hr 5.69E-06 lb/10^6 BTU Black Dog Stack Test Data 2004 1.08E-02 0.0471 4.71E-02 NA 1.08E-02EU 004 Boiler 4 (Subbituminous Coal/Coke) Methane 1890 MMBtu/hr 2.43E-02 lb/MMBtu 40 CFR 98 4.58E+01 200.7513 2.01E+02 NA 4.58E+01EU 004 Boiler 4 (Subbituminous Coal/Coke) bromomethane 114.3 tons/hr 1.60E-04 lb/ton AP-42 Table 1.1-14 (9/98) 1.83E-02 0.0801 8.01E-02 NA1.83E-02EU 004 Boiler 4 (Subbituminous Coal/Coke) Methyl Chloride 114.3 tons/hr 5.30E-04 lb/ton AP-42 Table 1.1-14 (9/98) 6.06E-02 0.2653 2.65E-01 NA 6.06E-02EU 004 Boiler 4 (Subbituminous Coal/Coke) 1,1,1-trichloroethane 1890 MMBtu/hr 6.10E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.15E-03 0.0050 5.05E-03 NA 1.15E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Methyl Ethyl Ketone 114.3 tons/hr 3.90E-04 lb/ton AP-42 Table 1.1-14 (9/98) 4.46E-02 0.1952 1.95E-01 NA 4.46E-02EU 004 Boiler 4 (Subbituminous Coal/Coke) Methyl Hydrazine 114.3 tons/hr 1.70E-04 lb/ton AP-42 Table 1.1-14 (9/98) 1.94E-02 0.0851 8.51E-02 NA 1.94E-02EU 004 Boiler 4 (Subbituminous Coal/Coke) Methyl Methacrylate 1890 MMBtu/hr 1.10E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table1-11 (4/02) 2.08E-03 0.0091 9.11E-03 NA 2.08E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Methyl tert butyl ether 114.3 tons/hr 3.50E-05 lb/ton AP-42 Table 1.1-14 (9/98) 4.00E-03 0.0175 1.75E-02 NA 4.00E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Methylene Chloride 1890 MMBtu/hr 3.60E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 6.80E-03 0.0298 2.98E-02 NA 6.80E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Naphthalene 1890 MMBtu/hr 6.20E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.17E-03 0.0051 5.13E-03 NA 1.17E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Nickel 1890 MMBtu/hr 6.57E+00 lb/10^12 BTU AP-42 Table 1.1-16 (9/98) (4.4*(C/A*PM)^.48) 1.24E-02 0.0543 5.43E-02 NA 1.24E-02EU 004 Boiler 4 (Subbituminous Coal/Coke) Nitrous oxides 1890 MMBtu/hr 3.53E-03 lb/MMBtu 40 CFR 98 6.67 29.20 29.20 NA 6.67EU 004 Boiler 4 (Subbituminous Coal/Coke) NOx114.3 tons/hr 1.20E+01 lb/ton AP-42 Table 1.1-3 (9/98) 1371.60 6007.61 6007.61 NA 1371.60EU 004 Boiler 4 (Subbituminous Coal/Coke) Phenol 1890 MMBtu/hr 3.30E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 6.24E-03 0.0273 2.73E-02 NA 6.24E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) PM 114.3 tons/hr 4.64E+01 lb/ton AP-42 Table 1.1-4 (9/98) (10 x 4.64 % Ash) 5303.52 23229.42 99.75% 58.07 2,483.46 1.33E+01 0.3 lb/MMBTUEU 004 Boiler 4 (Subbituminous Coal/Coke) PM10114.3 tons/hr 1.07E+01 lb/ton AP-42 Table 1.1-4 (9/98) (2.3 x 4.64 % Ash) 1219.81 5342.77 99.75% 13.36 NA 3.05E+00EU 004 Boiler 4 (Subbituminous Coal/Coke) PM2.5114.3 tons/hr 1.07E+01 lb/ton Assumed same as PM10 1219.81 5342.77 99.75% 13.36 NA 3.05E+00Boiler 4 (Subbituminous Coal/Coke) Condensible PM 1890.0 MMBtu/hr 3.23E-01 lb/MMBtu AP-42 Table 1.1-5 (0.1 x 3.23% sulfur) 610.47 2673.86 99.75% 6.68 NA 1.53E+00EU 004 Boiler 4 (Subbituminous Coal/Coke) POMs 1890 MMBtu/hr 2.08E-06 lb/10^12 BTU AP-42 Table 1.1-17 (9/98) 3.93E-09 0.0000 1.72E-08 NA 3.93E-09EU 004 Boiler 4 (Subbituminous Coal/Coke) Propionaldehyde 1890 MMBtu/hr 1.90E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11(4/02) 3.59E-03 0.0157 1.57E-02 NA 3.59E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Selenium 114.3 tons/hr1.30E-03lb/ton AP-42 Table 1.1-18 (9/98) 1.49E-01 0.6508 6.51E-01 NA 1.49E-01EU 004 Boiler 4 (Subbituminous Coal/Coke) SO2114.3 tons/hr 7.35E+00 lb/ton AP-42 Table 1.1-3 (35 x % S) [4] 840.11 3679.66 3679.66 24,834.60 8.40E+02 3 lb/MMBTUEU 004 Boiler 4 (Subbituminous Coal/Coke) Styrene 1890 MMBtu/hr 7.00E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.32E-03 0.0058 5.79E-03 NA 1.32E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Tetrachloroethylene 1890 MMBtu/hr 4.20E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table1-11 (4/02) 7.94E-04 0.0035 3.48E-03 NA 7.94E-04EU 004 Boiler 4 (Subbituminous Coal/Coke) Toluene 1890 MMBtu/hr 1.70E+00 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 3.21E-03 0.0141 1.41E-02 NA 3.21E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) TOTAL HAPs1.82E+00 7.98E+00 7.98E+00 NA 1.82E+00EU 004 Boiler 4 (Subbituminous Coal/Coke) Total VOC 114.3 tons/hr 6.00E-02 lb/ton AP-42 Table 1.1-19 6.86E+00 30.0380 3.00E+01 NA 6.86E+00EU 004 Boiler 4 (Subbituminous Coal/Coke) Vinyl Acetate 1890 MMBtu/hr 3.10E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 5.86E-04 0.0026 2.57E-03 NA 5.86E-04EU 004 Boiler 4 (Subbituminous Coal/Coke) Vinyl Chloride 1890 MMBtu/hr 7.30E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11(4/02) 1.38E-03 0.0060 6.04E-03 NA 1.38E-03EU 004 Boiler 4 (Subbituminous Coal/Coke) Xylenes 1890 MMBtu/hr 8.20E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 1.55E-03 0.0068 6.79E-03 NA 1.55E-03EU 004 Boiler 4 (Waste Oil) Antimony 0.7 MGal/hr 5.25E-03 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 3.68E-03 0.0161 1.61E-02 NA 3.68E-03 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Arsenic 0.7 MGal/hr 1.32E-03 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 9.25E-04 0.0041 4.05E-03 NA 9.25E-04 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Beryllium 0.7 MGal/hr 2.78E-05 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 1.95E-05 0.0001 8.53E-05 NA 1.95E-05 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Cadmium 0.7 MGal/hr 3.98E-04 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 2.79E-04 0.0012 1.22E-03 NA 2.79E-04 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Chromium 0.7 MGal/hr 8.45E-04 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 5.92E-04 0.0026 2.59E-03 NA 5.92E-04 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) CO 0.7 MGal/hr 5.00E+00 lb/10^3 Gal AP-42 Table 1.11-2 (10/96) 3.50E+00 15.3462 1.53E+01 NA 3.50E+00 5% of fuelmass or heat valueEU 004 Boiler 4 (Waste Oil) CO294.60 MMBtu/hr 1.63E+02 lb/MMBtu 40 CFR 98 1.54E+04 67597 6.76E+04 NA 1.54E+04 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) CO2e 94.60 MMBtu/hr 1.64E+02 lb/MMBtu 40 CFR 98 1.55E+04 67828.7376 6.78E+04 NA 1.55E+04 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Cobalt 0.7 MGal/hr 6.02E-03 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 4.22E-03 0.0185 1.85E-02 NA 4.22E-03 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Hydrochloric Acid 0.7 MGal/hr 3.56E+00 lb/10^3 GAL AP-42 Table 1.11-3 (66 X .054% Cl) (10/96) 2.50E+00 10.9388 1.09E+01 NA 2.50E+00 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Lead 0.7 MGal/hr 1.51E-03 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 1.06E-03 0.0046 4.63E-03 NA 1.06E-03 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Manganese 0.7 MGal/hr 3.00E-03 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 2.10E-03 0.0092 9.21E-03 NA 2.10E-03 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Mercury 0.7 MGal/hr 1.13E-04 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 7.92E-05 0.0003 3.47E-04 NA 7.92E-05 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Methane 94.60 MMBtu/hr 6.61E-03 lb/MMBtu 40 CFR 98 6.26E-01 2.7404 2.74E+00 NA 6.26E-01 5% of fuel mass or heatvalueEU 004 Boiler 4 (Waste Oil) Nickel 0.7 MGal/hr 8.45E-02 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 5.92E-02 0.2594 2.59E-01 NA 5.92E-02 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Nitrous oxides 94.60 MMBtu/hr 1.32E-03 lb/MMBtu 40 CFR 98 1.25E-01 0.5481 5.48E-01 NA 1.25E-01 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) NOx0.7 MGal/hr 1.90E+01 lb/10^3 Gal AP-42 Table 1.11-2 (10/96) 13.31 58.3156 5.83E+01 NA 1.33E+01 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) PM 0.7 MGal/hr 6.40E+01 lb/10^3 Gal AP-42 Table 1.11-1 (64 X 1% Ash) (10/96) [4] 44.85 196.4316 99.75% 4.91E-01 NA 1.12E-01 5% of fuel mass or heat value; 0.3 lb/MMBtuEU 004 Boiler 4 (Waste Oil) PM100.7 MGal/hr 5.10E+01 lb/10^3 Gal AP-42 Table 1.11-1 (51 X 1 % Ash) (10/96) [4] 35.74 156.5315 99.75% 3.91E-01 NA 8.93E-02 5% of fuel massor heat valueBoiler 4 (Waste Oil) PM2.50.7 MGal/hr 5.10E+01 lb/10^3 Gal AP-42 Table 1.11-1 (51 X 1 % Ash) (10/96) [4] 35.74 156.5315 99.75% 3.91E-01 NA 8.93E-02 5% of fuel massor heat valueEU 004 Boiler 4 (Waste Oil) Selenium 0.7 MGal/hr 6.83E-04 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 4.79E-04 0.0021 2.10E-03 NA 4.79E-04 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) SO20.7 MGal/hr 5.29E+02 lb/10^3 Gal AP-42 Table 1.11-2 (147 X 1 % S) (10/96) [4] 370.83 1624.24 1624.24 662.96 1.51E+02 5% of fuel mass orheat value; 1.6 lb/mmbtuEU 004 Boiler 4 (Waste Oil) TOTAL HAPs2.57E+00 1.13E+01 1.13E+01 NA 2.57E+00 5% of fuel mass or heat valueEU 004 Boiler 4 (Waste Oil) Total VOC 0.7 MGal/hr 1.00E+00 lb/10^3 Gal AP-42 Table 1.11-3 (10/96) 7.01E-01 3.0692 3.07E+00 NA 7.01E-01 5% offuel mass or heat value[1] See annual emissions inventories.[2] SO2 emission factor in lbs/1000 gal is 0.01 x S; where S is Sulfur content in gr/100 ft3. Propane sulfur content is 8 gr/100 ft3.[3] 4 ignitors/boiler on propane @ 6 PSI rated at 41.5 MMBTU/hr[4] % ash and % sulfur used is 2010-2011 average from Black Dog coal samples.[5] Pollution control efficiencies were based on test data for subbit and bit coal. For all other fuels, control efficiencieswere based on MPCA Table GI 05-A.1 ESP efficiencies for a boiler.[6] In many cases for HAPs, uncontrolled lb/hr stated is actually controlled lb/hr. Uncontrolled rate not always known.Group/Combined Limits

Unit Name Pollutant Max Process

Rate Process Rate

Units SV001 Limit Emission Factor Units Emission

Rate
(lb/hr) Limited

Potential to
Emit (ton/yr)

GP002 PM 10 9.20E+02 lb/hr 920.00 4029.60 12.14 lb/hr calculated
920 lb/hr for GP002 PM10 is the limiting limit

GP002 SO 2 3068.0 MMBtu/hr 1.30E+00 lb/MMBtu 3988 17469 Assume PM2.5 is the same

GP002 SO 2 3.99E+03 lb/hr 3988.00 17467.44EU 024Emergency Engine Generator (Diesel)121.000gal/hrEmergency Engine Generator (Diesel)16.577MMBtu/hrEmergency Engine Generator (Diesel)2598 HPEU 025Emergency Engine Generator (Diesel)121.000gal/hrEmergency Engine Generator (Diesel)16.577MMBtu/hrEU028Fire Pump1.425MMBtu/hrFire Pump208 HPXcel Energy - Black Dog Generating PlantPotential to EmitEmissionUnit ID Unit NamePollutantMaxProcessRateProcess RateUnitsEmissionFactor EmissionFactor Units Emission Factor SourceEmissionRate(lb/hr)UncontrolledPotential toEmit(ton/yr)PollutionControlEfficiency(%)ControlledPotential toEmit (ton/yr)LimitedPotential toEmit(ton/yr) lb/mmbtu Existing Permit LimitEU 024 Emergency Engine Generator (Diese CO 16.58MMBtu/hr1.05E+01 lb/hrManufacturer's Data10.458345.80740 45.80744.2670EU 024 Emergency Engine Generator (Diesel) NOx16.58 MMBtu/hr 8.19E+01 lb/hr Manufacturer's Data 81.8849 358.6558 0 358.6558 35.3000EU 024 Emergency Engine Generator (Diese PM 16.58MMBtu/hr4.87E-01 lb/hrManufacturer's Data0.48692.13250 2.13250.1986EU 024 Emergency Engine Generator (Diese PM1016.58MMBtu/hr4.87E-01 lb/hrManufacturer's Data0.48692.13250 2.13250.1986EU 024 Emergency Engine Generator (Diese PM2.516.58MMBtu/hr4.87E-01 lb/hrAssumed same as PM100.48692.13250 2.13250.1986EU 024 Emergency Engine Generator (Diese SO216.58MMBtu/hr5.05E-02lb/MMBtuAP-42 3.4-1 0.8371 3.66670 3.66670.34160.05EU 024 Emergency Engine Generator (Diese Total VOC16.58MMBtu/hr1.91E+00lb/hrManufacturer's Data1.9051 8.34440 8.34440.7773EU 024 Emergency Engine Generator (Diese CO216.58MMBtu/hr1.61E+02lb/MMBtu 40 CFR 982676.969211725.12500 11725.12501092.2034EU 024 Emergency Engine Generator (Diese Methane16.58MMBtu/hr6.61E-03lb/MMBtu 40 CFR 980.10960.48020 0.48020.0447EU 024 Emergency Engine Generator (Diese Nitrous oxides16.58MMBtu/hr1.32E-03lb/MMBtu 40 CFR 980.02190.09600 0.09600.0089EU 024 Emergency Engine Generator (Diese CO2e 16.58MMBtu/hr1.62E+02lb/MMBtu 40 CFR 982686.244511765.75070 11765.75071095.9877EU 024 Emergency Engine Generator (DieseAcetaldehyde16.58MMBtu/hr2.52E-05lb/MMBtuAP-42 Table 3.4-3 (10/96)0.00040.001800.00180.0002EU 024 Emergency Engine Generator (DieseAcrolien16.58MMBtu/hr7.88E-06lb/MMBtuAP-42 Table 3.4-3 (10/96)0.0001 0.000600.00060.0001EU 024 Emergency Engine Generator (Diese Benzene16.58MMBtu/hr7.76E-04lb/MMBtuAP-42 Table 3.4-3 (10/96)0.01290.056300.05630.0052EU 024 Emergency Engine Generator (Diese Formaldehyde16.58MMBtu/hr7.89E-05lb/MMBtuAP-42 Table 3.4-3 (10/96)0.00130.005700.00570.0005EU 024 Emergency Engine Generator (Diese Naphthalene16.58MMBtu/hr1.30E-04lb/MMBtuAP-42 Table 3.4-4 (10/96)0.00220.009400.00940.0009EU 024 Emergency Engine Generator (Diese Toluene16.58MMBtu/hr2.81E-04lb/MMBtuAP-42 Table 3.4-3 (10/96)0.00470.020400.02040.0019EU 024 Emergency Engine Generator (Diese Xylenes16.58MMBtu/hr1.93E-04lb/MMBtuAP-42 Table 3.4-3 (10/96)0.00320.014000.01400.0013EU 024 Emergency Engine Generator (Diese TOTAL HAPs0.02470.108300.10830.0101EU 025 Emergency Engine Generator (Diese CO 16.58MMBtu/hrNA NA Manufacturer's Data10.458345.8074045.80744.2670EU 025 Emergency Engine Generator (Diesel)NOx16.58 MMBtu/hr NA NA Manufacturer's Data81.8849358.65580358.6558 35.3000EU 025 Emergency Engine Generator (Diese PM 16.58MMBtu/hrNA NA Manufacturer's Data0.48692.132502.13250.1986EU 025 Emergency Engine Generator (DiesePM1016.58MMBtu/hrNA NA Manufacturer's Data0.48692.132502.13250.1986EU 025 Emergency Engine Generator (DiesePM2.516.58MMBtu/hrNA NAAssumed same as PM100.48692.132502.13250.1986EU 025 Emergency Engine Generator (Diesel)SO216.58 MMBtu/hr5.05E-02 lb/MMBtu AP-42 3.4-1 0.83713.666703.6667 0.34160.05EU 025 Emergency Engine Generator (Diese Total VOC16.58MMBtu/hrNA NA Manufacturer's Data1.90518.344408.34440.7773EU 025Emergency Engine Generator (Diese CO216.58MMBtu/hr1.61E+02lb/MMBtu 40 CFR 982676.969211725.12500 11725.12501092.2034EU 025Emergency Engine Generator (Diese Methane16.58MMBtu/hr6.61E-03lb/MMBtu 40 CFR 980.10960.48020 0.48020.0447EU 025Emergency Engine Generator (Diese Nitrous oxides16.58MMBtu/hr1.32E-03lb/MMBtu 40 CFR 980.02190.09600 0.09600.0089EU 025Emergency Engine Generator (Diese CO2e 16.58MMBtu/hr1.62E+02lb/MMBtu 40 CFR 982686.244511765.75070 11765.75071095.9877EU 025 Emergency Engine Generator (DieseAcetaldehyde16.58MMBtu/hr2.52E-05lb/MMBtuAP-42 Table 3.4-3 (10/96)0.00040.001800.00180.0002EU 025 Emergency Engine Generator (DieseAcrolien16.58MMBtu/hr7.88E-06lb/MMBtuAP-42 Table 3.4-3 (10/96)0.0001 0.000600.00060.0001EU 025 Emergency Engine Generator (Diese Benzene16.58MMBtu/hr7.76E-04lb/MMBtuAP-42 Table 3.4-3 (10/96)0.01290.056300.05630.0052EU 025 Emergency Engine Generator (Diese Formaldehyde16.58MMBtu/hr7.89E-05lb/MMBtuAP-42 Table 3.4-3 (10/96)0.00130.005700.00570.0005EU 025 Emergency Engine Generator (Diese Naphthalene16.58MMBtu/hr1.30E-04lb/MMBtuAP-42 Table 3.4-4 (10/96)0.00220.009400.00940.0009EU 025 Emergency Engine Generator (Diese Toluene16.58MMBtu/hr2.81E-04lb/MMBtuAP-42 Table 3.4-3 (10/96)0.00470.020400.02040.0019EU 025 Emergency Engine Generator (Diese Xylenes16.58MMBtu/hr1.93E-04lb/MMBtuAP-42 Table 3.4-3 (10/96)0.00320.014000.01400.0013EU 025 Emergency Engine Generator (Diese TOTAL HAPs0.02470.108300.10830.0101EU028Fire Pump (Diesel)CO 1.42 MMBTU/hr9.50E-01 lb/MMBtuAP-42 Table3.3-1 (10/96)1.35360.33840 0.3384Can assume 500 hrs/yeaEU028Fire Pump (Diesel)NOx1.42 MMBTU/hr4.41E+00lb/MMBtuAP-42 Table3.3-1 (10/96)6.28341.57080 1.5708Can assume 500 hrs/yeaEU028Fire Pump (Diesel)PM 1.42 MMBTU/hr3.10E-01 lb/MMBtuAP-42 Table3.3-1(10/96)0.44170.11040 0.1104Can assume 500 hrs/yeaEU028Fire Pump (Diesel)PM101.42 MMBTU/hr3.10E-01 lb/MMBtuAP-42 Table3.3-1(10/96)0.44170.11040 0.1104Can assume 500 hrs/yeaEU028Fire Pump (Diesel)PM2.51.42 MMBTU/hr3.10E-01 lb/MMBtuAssumed same as PM100.44170.11040 0.1104Can assume 500 hrs/yeaEU028Fire Pump (Diesel)SO21.42 MMBTU/hr5.05E-02lb/MMBtuAP-42 3.4-1 0.07200.01800 0.01805.05E-02Can assume 500 hrs/yeaEU028Fire Pump (Diesel)Total VOC1.42 MMBTU/hr3.60E-01 lb/MMBtuAP-42 Table3.3-1(10/96)0.51290.12820 0.1282Can assume 500 hrs/yeaEU028Fire Pump (Diesel)CO21.42 MMBtu/hr1.61E+02lb/MMBtu 40 CFR 98230.086657.52170 57.5217Can assume 500 hrs/yeaEU028Fire Pump (Diesel)Methane1.42 MMBtu/hr6.61E-03lb/MMBtu 40 CFR 980.00940.00240 0.0024Can assume 500 hrs/yeaEU028Fire Pump (Diesel)Nitrous oxides1.42 MMBtu/hr1.32E-03lb/MMBtu 40 CFR 980.00194.71E-040 0.0005Can assume 500 hrs/yeaEU028Fire Pump (Diesel)CO2e 1.42 MMBtu/hr1.62E+02lb/MMBtu 40 CFR 98230.883857.72100 57.7210Can assume 500 hrs/yeaEU028Fire Pump (Diesel)Acetaldehyde1.42 MMBTU/hr7.67E-04lb/MMBtuAP-42 Table3.3-2 (10/96)1.09E-032.73E-040 0.0003Can assume 500 hrs/yeaEU028Fire Pump (Diesel)Acrolien1.42 MMBTU/hr4.63E-05lb/MMBtuAP-42 Table3.3-2 (10/96)6.59E-051.65E-050 0.0000Can assume 500 hrs/yeaEU028Fire Pump (Diesel)1,3-Butadiene1.42 MMBTU/hr1.96E-05lb/MMBtuAP-42 Table3.3-2 (10/96)2.79E-056.96E-060 0.0000Can assume 500 hrs/yeaEU028Fire Pump (Diesel)Benzene1.42 MMBTU/hr9.33E-04lb/MMBtuAP-42 Table3.3-2 (10/96)1.33E-033.32E-040 0.0003Can assume 500 hrs/yeaEU028Fire Pump (Diesel)Formaldehyde1.42 MMBTU/hr1.18E-03lb/MMBtuAP-42 Table3.3-2 (10/96)1.68E-034.20E-040 0.0004Can assume 500 hrs/yeaEU028Fire Pump (Diesel)Naphthalene1.42 MMBTU/hr8.48E-05lb/MMBtuAP-42 Table3.3-2 (10/96)1.21E-043.02E-050 0.0000Can assume 500 hrs/yeaEU028Fire Pump (Diesel)Toluene1.42 MMBTU/hr4.09E-04lb/MMBtuAP-42 Table3.3-2 (10/96)5.83E-041.46E-040 0.0001 Can assume 500 hrs/yeaEU028Fire Pump (Diesel)Xylenes1.42 MMBTU/hr2.85E-04lb/MMBtuAP-42 Table3.3-2 (10/96)4.06E-041.02E-040 0.0001 Can assume 500 hrs/yeaEU028Fire Pump (Diesel)Total HAPs0.00531.33E-030 0.0013Can assume 500 hrs/yeaGP001CO4.27 816 hours per year EU024 & EU025 combinedGP001 NOx35.3035.3 tpy EU024 & EU025 combinedGP001PM1.99E-01 816 hours per year EU024 & EU025 combinedGP001 PM101.99E-01 816 hours per year EU024 & EU025 combinedGP001 PM2.51.99E-01 816 hours per year EU024 & EU025 combinedGP001 SO23.42E-01 816 hours per year EU024 & EU025 combinedGP001Total VOC7.77E-01 816 hours per year EU024 & EU025 combinedGP001 CO21092.20816 hours per year EU024 & EU025 combinedGP001 Methane4.47E-02816 hours per year EU024 & EU025 combinedGP001 Nitrous oxides8.95E-03816 hours per year EU024 & EU025 combinedGP001 CO2e1095.99816 hours per year EU024 & EU025 combinedGP001Acetaldehyde1.70E-04816 hours per year EU024 & EU025 combinedGP001Acrolien5.33E-05816 hours per year EU024 & EU025 combinedGP001Benzene5.25E-03816 hours per year EU024 & EU025 combinedGP001Formaldehyde5.34E-04816 hours per year EU024 & EU025 combinedGP001Naphthalene8.79E-04816 hours per year EU024 & EU025 combinedGP001Toluene1.90E-03816 hours per year EU024 & EU025 combinedGP001Xylenes1.31E-03816 hours per year EU024 & EU025 combinedGP001TOTAL HAPs1.01E-02816 hours per year EU024 & EU025 combinedEU 026 Combustion Turbine (NG) 1.88 MMCF/hrCombustion Turbine (NG) 1020.00 Btu/cfCombustion Turbine (NG) 1917.46 MMBtu/hrCombustion Turbine (NG) 83960.00 lb/hrXcel Energy - Black Dog Generating PlantPotential to Emit0.0034EmissionUnit ID Unit NamePollutantMaxProcessRateProcess RateUnitsEmissionFactor Emission FactorUnits Emission Factor SourceEmissionRate(lb/hr)UncontrolledPotential toEmit(ton/yr)PollutionControlEfficiency(%)ControlledPotential toEmit(ton/yr)LimitedPotential toEmit(ton/yr) Existing Permit LimitcontrolledhourlyEU 026 Combustion Turbine (NG) CO 1917.46 MMBtu/hr 4.20E+01 lb/hr Manufacturer 42.00 183.9600 183.9600 400 400 tons/yr [3]EU 026 Combustion Turbine (NG) NOX1917.46 MMBtu/hr 1.73E+02 lb/hr Manufacturer 172.50 755.5500 82 132.7501 300 300 tons/yr [2] 30.30825EU 026 Combustion Turbine (NG) PM 1917.46 MMBtu/hr 9.0E+00 lb/hr Manufacturer (lb/hr) 9.00 39.4200 39.4200 NAEU 026 Combustion Turbine (NG) PM101917.46 MMBtu/hr 1.80E+01 lb/hr Manufacturer (lb/hr) 18.00 78.8400 78.8400 128.77 29.4 lb/hrEU 026 Combustion Turbine (NG) PM2.51917.46 MMBtu/hr 1.80E+01 lb/hr Assumed same as PM1018.00 78.8400 78.8400 128.77 29.4 lb/hrEU 026 Combustion Turbine (NG) SO21917.46 MMBtu/hr 2.27E+00 lb/hr Manufacturer (lb/hr) 2.27 9.9280 9.9280 NAEU 026 Combustion Turbine (NG) Total VOC 1917.46 MMBtu/hr 4.8E+00 lb/hr Manufacturer 4.80 21.0240 21.0240 NAEU 026 Combustion Turbine (NG) CO21917.46 MMBtu/hr 1.2E+02 lb/mmBtu CEMS 227909.29 998243 998243 NAEU 026 Combustion Turbine (NG) Methane 1917.46 MMBtu/hr 2.2E-03 lb/mmBtu 40 CFR 98 4.23 18.5153 18.5153 NAEU 026 Combustion Turbine (NG) Nitrous oxides 1917.46 MMBtu/hr 2.2E-04 lb/mmBtu 40 CFR 98 0.42 1.8515 1.8515 NAEU 026 Combustion Turbine (NG) CO2e 1917.46 MMBtu/hr 1.19E+02 lb/mmBtu CEMS & 40 CFR 98 228140.94 999257 999257 NAEU 026 Combustion Turbine (NG) Acetaldehyde 1917.46 MMBtu/hr 4.00E-05 lb/mmBtu AP-42 Table 3.1-3 (4/00) 0.08 0.3359 0.3359 NAEU 026 Combustion Turbine (NG) Acrolein 1917.46 MMBtu/hr 6.40E-06 lb/mmBtu AP-42 Table 3.1-3 (4/00) 1.23E-02 0.0538 0.0538 NAEU 026 Combustion Turbine (NG) Benzene 1917.46 MMBtu/hr 1.20E-05 lb/mmBtu AP-42 Table 3.1-3 (4/00) 2.30E-02 0.1008 0.1008 NAEU 026 Combustion Turbine (NG) 1,3 Butadiene 1917.46 MMBtu/hr 4.30E-07 lb/mmBtu AP-42 Table 3.1-3 (4/00) 8.25E-04 0.0036 0.0036 NAEU 026 Combustion Turbine (NG) Ethylbenzene 1917.46 MMBtu/hr 3.20E-05 lb/mmBtu AP-42 Table 3.1-3 (4/00) 6.14E-02 0.2688 0.2688 NAEU 026 Combustion Turbine (NG) Formaldehyde 1917.46 MMBtu/hr 2.45E-05 lb/mmBtu Test Results from 6/27/02 4.70E-02 0.2058 0.2058 NA 9 tpyEU 026 Combustion Turbine (NG) Naphthalene 1917.46 MMBtu/hr 1.30E-06 lb/mmBtu AP-42 Table 3.1-3 (4/00) 2.49E-03 0.0109 0.0109 NAEU 026 Combustion Turbine (NG) PAHs 1917.46 MMBtu/hr 2.20E-06 lb/mmBtu AP-42 Table 3.1-3 (4/00) 4.22E-03 0.0185 0.0185 NAEU 026 Combustion Turbine (NG) Propylene Oxide 1917.46 MMBtu/hr 2.90E-05 lb/mmBtu AP-42 Table 3.1-3 (4/00) 5.56E-02 0.2436 0.2436 NAEU 026 Combustion Turbine (NG) Toluene 1917.46 MMBtu/hr 1.30E-04 lb/mmBtu AP-42 Table 3.1-3 (4/00) 2.49E-01 1.0918 1.0918 NAEU 026 Combustion Turbine (NG) Xylenes 1917.46 MMBtu/hr 6.40E-05 lb/mmBtu AP-42 Table 3.1-3 (4/00) 1.23E-01 0.5375 0.5375 NATotal HAP6.55E-01 2.87 2.87 24 tpy[1] See annual emissions inventories.[2] The total annual potential NOx emissions are equal to the combined EU026 and EU027 annual NOx emissions cap.[3] The total annual potential CO emissions are equal to the combined EU026 and EU027 annual CO emissions cap.SV020 Permit Limited Potential to Emitcontrolledlb/hrLimited TpyCO 400.00NOX305.00PM1029.40 128.77Total VOC 17.72 77.60 pte is less than this - combined lb/hr = 17.54Formaldehyde 9.00 pte is less than this - combined tpy = 0.21TOTAL HAPs 24.00 pte is less than this - combined tpy = 3.56EU 027 Supplemental Duct Firing Burners (NG) 0.5 MMCF/hrSupplemental Duct Firing Burners (NG) 1020.0 Btu/cfSupplemental Duct Firing Burners (NG) 509.6 MMBTU/hrXcel Energy - Black Dog Generating PlantPotential to EmitEmissionUnit ID Unit NamePollutantMaxProcessRateProcessRateUnitsEmissionFactor Emission FactorUnits Emission Factor SourceEmission Rate(lb/hr)UncontrolledPotential toEmit(ton/yr)PollutionControlEfficiency (%)ControlledPotential toEmit (ton/yr)LimitedPotential toEmit(ton/yr) Existing Permit LimitEU 027 Supplemental Duct Firing Burners (NG) CO 509.6 MMBtu/hr1.00E-01 lb/mmBtu Manufacturer's Data 5.10E+01 223.2048 223 38 400 tons/yr [3], 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) NOX509.6 MMBtu/hr1.00E-01 lb/mmBtu Manufacturer's Data 5.10E+01 223.2048 82 39.2171 300 300 tons/yr [2], 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) PM 509.6 MMBtu/hr2.00E-02 lb/mmBtu Manufacturer's Data 1.02E+01 44.6410 44.6410 7.6440 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) PM10509.6 MMBtu/hr2.00E-02 lb/mmBtu Manufacturer's Data 1.02E+01 44.6410 44.6410 7.6440 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) PM2.5509.6 MMBtu/hr2.00E-02 lb/mmBtuAssumed same as PM10 1.02E+01 44.6410 44.6410 7.6440 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) SO20.5 MMCF/hr6.00E-01 lb/MMCFAP-42 1.4-2 (7/98)3.00E-01 1.3130 1.3130 0.2248 1500 hrs/yr5.88E-04EU 027 Supplemental Duct Firing Burners (NG) Total VOC 509.6 MMBtu/hr 2.50E-02 lb/mmBtu Manufacturer's Data 1.27E+01 55.8012 55.8012 2.79011500 hrs/yr; SV020 limit of0.0073 lb/mmBtu.EU 027 Supplemental Duct Firing Burners (NG) CO2509.6 MMBtu/hr1.19E+02 lb/mmBtu CEMS 6.06E+04 265301 265301 45428.29 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Methane 509.6 MMBtu/hr2.20E-03 lb/mmBtu 40 CFR 98 1.12E+00 4.9208 4.9208 0.84 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Nitrous oxides 509.6 MMBtu/hr2.20E-04 lb/mmBtu 40 CFR 98 1.12E-01 0.4921 0.4921 0.08 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) CO2e 509.6 MMBtu/hr1.19E+02 lb/mmBtu CEMS & 40 CFR 98 6.06E+04 265571 265571 45474.46 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Benzene 509.6 MMBtu/hr8.00E-01 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 4.08E-04 1.79E-03 1.79E-03 3.06E-04 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG)Arsenic 509.6 MMBtu/hr2.30E-01 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 1.17E-04 5.13E-04 5.13E-04 8.79E-05 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Cobalt509.6 MMBtu/hr8.00E-02 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 4.08E-05 1.79E-04 1.79E-04 3.06E-05 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Beryllium 509.6 MMBtu/hr1.00E-02 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 5.10E-06 2.23E-05 2.23E-05 3.82E-06 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Cadmium 509.6 MMBtu/hr4.00E-02 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 2.04E-05 8.93E-05 8.93E-05 1.53E-05 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Manganese 509.6 MMBtu/hr4.00E-01 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 2.04E-04 8.93E-04 8.93E-04 1.53E-04 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Mercury509.6 MMBtu/hr8.00E-04 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 4.08E-07 1.79E-06 1.79E-06 3.06E-07 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Nickel 509.6 MMBtu/hr2.40E+00 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 1.22E-03 5.36E-03 5.36E-03 9.17E-04 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Chromium 509.6 MMBtu/hr1.10E+00 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 5.61E-04 2.46E-03 2.46E-03 4.20E-04 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Formaldehyde 509.6 MMBtu/hr2.09E-05 lb/mmBtu Test Data from 6/27/02 1.07E-02 4.67E-02 4.67E-02 8.00E-03 1500 hrs/yr; 9 tpy SV020 limitEU 027 Supplemental Duct Firing Burners (NG) Hexane 0.5 MMCF/hr1.80E+00 lb/MMCFAP-42 Table 1.4-3 (7/98) 8.99E-01 3.94E+00 3.94E+00 6.74E-01 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Lead 0.5 MMCF/hr5.00E-04 lb/MMCF EPRI Emissions Factor Handbook Table 3-1 (4/02) 2.50E-04 1.09E-03 1.09E-03 1.87E-04 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Naphthalene 0.5 MMCF/hr6.10E-04 lb/MMCFAP-42 Table 1.4-3 (7/98) 3.05E-04 1.33E-03 1.33E-03 2.29E-04 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) POMs 0.5 MMCF/hr8.65E-05 lb/MMCFAP-42 Table 1.4-3 (7/98) - sum of all POMs listed 4.32E-05 1.89E-04 1.89E-04 3.24E-05 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Toluene 509.6 MMBtu/hr1.00E+01 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 5.10E-03 2.23E-02 2.23E-02 3.82E-03 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) Selenium 509.6 MMBtu/hr2.00E-02 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 1.02E-05 4.46E-05 4.46E-05 7.64E-06 1500 hrs/yrEU 027 Supplemental Duct Firing Burners (NG) TOTAL HAPs9.18E-01 4.02E+00 4.02E+00 6.89E-01 1500 hrs/yr[2] The total annual potential NOx emissions are equal to the combined EU026 and EU027 annual NOx emissions cap.[3] The total annual potential CO emissions are equal to the combined EU026 and EU027 annual CO emissions cap.Xcel Energy - Black Dog Generating PlantCoal Storage PilesEquation: Wind Erosion Storage PilesSource: AP-42 13.2.5 - Industrial Wind Erosion and PM-10 Air Quality Modeling Analysis, April 1998E = 1.7 (s/1.5)*(365-p/235)*(f/15) lb/day/acreE = Emission Factor (lbs/day/acre)s = silt/fines content (coal, 2.2% from AP-42 Table 13.2.4-1 (11/06)p = mean number of days with 0.01" or more precipitation (110 days, from AP-42 Table 13.2.1-1, 1/11)f = % of time mean unobstructed wind speed exceeds 12 mph at mean pile height = 28.4% (Minneapolis-St.Paul Data, U of M Ag.Exp.Station, "Climate of Minnesota" ,1983)PM10 emissions factor is calculated by multiplying PM emissions factor by 0.5 (AP-42 13.2.5-3)PM2.5 emissions factor is calculated by multiplying PM emissions factor by 0.075 (AP-42 13.2.5-3)s p f E PM) E (PM10) E (PM2.5)2.2 110 28.4 5.12 2.56 0.38Maximum Pollution Maximum Limited LimitedEmissions Emissions Uncontrolled Control Controlled Controlled ControlledParticulate Sources Factor Rate Emissions Efficiency Emissions Emissions Emissions(lb/day/acre) (lb/day) (tons/yr) (%) (tons/yr) (tons/yr) (lb/hr)AcresCoal Storage Pile A (Erosion) PM 5.12 10.24 1.87 40.0 1.12 1.122 22 Acres PM102.56 5.12 0.93 40.0 0.56 0.561 2PM2.50.38 0.77 0.14 40.0 0.08 0.084 2Coal Storage Pile B (Erosion) PM 5.12 25.61 4.67 40.0 2.80 2.805 55 Acres PM102.56 12.81 2.34 40.0 1.40 1.402 5PM2.50.38 1.92 0.35 40.0 0.21 0.210 5Coal Storage Pile C (Erosion) PM 5.12 20.49 3.74 40.0 2.24 2.244 44 Acres PM102.56 10.24 1.87 40.0 1.12 1.122 4PM2.50.38 1.54 0.28 40.0 0.17 0.168 4Coal Storage Pile D (Erosion) PM 5.12 17.93 3.27 40.0 1.96 1.963 3.54 Acres PM102.56 8.96 1.64 40.0 0.98 0.982 3.5PM2.50.38 1.34 0.25 40.0 0.15 0.147 3.5FS004 Coal Storage Piles (ALL) - Erosion PM 13.56 8.13 8.13 1.86PM106.78 4.07 4.07 0.93PM2.51.02 0.61 0.61 0.14Ash HaulingEquation: Particulate Emissions from Unpaved Roads, Truck Traffic (Ash Hauling)Source: AP-42 13.2.2 Unpaved Roads (11/06)E = k (s/12)a(W/3)bE = size-specific emission factor (lb/VMT)k = particle size multiplier (PM = 4.9, PM10= 1.5, PM2.5= 0.15) from Table 13.2.2-2s = surface material silt content ( 5.1% from AP-42 Table 13.2.2-1, 11/06)W = average vehicle weight = 28.5 tons (16 tons empty and 41 tons loaded)S = mean vehicle speed (mph) = 5 mphBasis - Emission Factor Determination: W s S PM lb/VMT PM10lb/VMT PM2.5VMT Miles/day Lb/day PM Lb/day PM10Lb/day PM2.528.5 5.1 5 7.41 2.27 0.23 0.77 5.709 1.748 0.17528.5 5.1 5 7.41 2.27 0.23 0.77 5.709 1.748 0.175Total: 1.540 11.417 3.495 0.350Equation: Particulate Emissions from Paved Roads, Truck Traffic (Ash Hauling)Source: AP-42 13.2.1 - Paved Roads (1/11)E = k (sL)^0.91*(W)^1.02E = particulate emission factor (lb/VMT)k = particle size multiplier (0.011 for PM, for PM100.0022 and 0.00054 for PM2.5)sL = road surface silt loading (g/m2) = 12 (Table 13.2.1-3, for concete batching)W = average vehicle weight = 28.5 tons (16 tons empty and 41 tons loaded)Basis - Emission Factor Determination: sL W PM lb/VMT PM10lb/VMT PM2.5lb/VMT Miles/day Lb/day PM Lb/day PM10Lb/day PM2.512 28.5 3.22 0.64 0.05 1.44 4.632 0.926 0.07312 28.5 3.22 0.64 0.05 1.44 4.632 0.926 0.073Total: 2.880 9.264 1.853 0.146AssumedMaximum Pollution Maximum Limited LimitedEmissions Uncontrolled Control Controlled Controlled ControlledRate Emissions Efficiency Emissions Emissions EmissionsSummary of Fly Ash and Bottom Ash HaulingParticulate Sources (lb/VMT) (lb/day) (tons/yr) (%) (tons/yr) (tons/yr) (lb/hr)FS013, Ash Hauling TrafficPM see basis tables 20.68 3.77 40 2.3 2.265 0.52PM10see basis tables 5.35 0.98 40 0.6 0.586 0.13PM2.5see basis tables 0.50 0.09 40 0.1 0.054 0.01Particulate Emission Calculations1) Ash Trucks (Unpaved Roads)2) Bottom Ash Trucks (Unpaved Roads)1) Fly Ash Trucks (Paved Roads)2) Fly Ash Trucks (Paved Roads)Misc PM SourcesEquation: Continuous and Batch Drop UnloadingSource: AP-42 13.2.4 - Aggregate handling of storage piles (11/06)E = emission factor lb/tonE = k(0.0032) (U/5)^1.3k = particle size multiplier (PM = 0.74, PM10= 0.35, PM2.50.053), AP-42 13.2.4-4(M/2)^1.4 U = mean wind speed (9.5 mph from Table 22 of the UofM Ag. Exp. Station "Climate of Minnesota" 1983; 5 mph for partially enclosed bottom ash loading).M = material moisture content (coal = 4.5%; mean from from AP-42 Table 13.2.4-1, coal fired power plant)M = material moisture content (ash = assumed 4.5% for flyash; 15% for dewatered bottom ash)Coal E (PM) = 0.74(0.0032)*(9.5/5)^1.3/((4.5/2)^1.4) = 1.75E-03 lb/ton Bottom Ash E (PM) = 0.74(0.0032)*(5/5)^1.3/((15/2)^1.4) = 1.41E-04 lb/tonCoal E (PM10) = 0.35(0.0032)*(9.5/5)^1.3/((4.5/2)^1.4) = 8.29E-04 lb/ton Bottom Ash E (PM10) = 0.35(0.0032)*(5/5)^1.3/((15/2)^1.4) = 6.67E-05 lb/tonCoal E (PM2.5) = 0.053(0.0032)*(9.5/5)^1.3/((4.5/2)^1.4) = 1.26E-04 lb/ton Bottom Ash E (PM2.5) = 0.053(0.0032)*(5/5)^1.3/((15/2)^1.4) = 1.01E-05 lb/tonFly Ash E (PM) = 0.74(0.0032)*(9.5/5)^1.3/((4.5/2)^1.4) = 1.75E-03 lb/ton Dumper Unloading Building E (PM) = 0.74(0.0032)*(9.5/5)^1.3/((4.5/2)^1.4) = 1.75E-03 lb/tonFly Ash E (PM10) = 0.35(0.0032)*(9.5/5)^1.3/((4.5/2)^1.4) = 8.29E-04 lb/ton Dumper Unloading Building E (PM10) = 0.35(0.0032)*(9.5/5)^1.3/((4.5/2)^1.4) = 8.29E-04 lb/tonFly Ash E (PM2.5) = 0.053(0.0032)*(9.5/5)^1.3/((4.5/2)^1.4) = 1.26E-04 lb/ton Dumper Unloading Building E (PM2.5) = 0.053(0.0032)*(9.5/5)^1.3/((4.5/2)^1.4) = 1.26E-04 lb/tonMaximum Pollution Maximum LimitedEmission Emission Uncontrolled Control Controlled ControlledFactor Rate Emissions Efficiency Emissions Emissions Primary Capacity Rate Secondary Capacity Rate(lb/ton) (lb/Unit time) (Unit time) (tons/yr) (%) (tons/yr) (tons/yr) (lb/hr) (tons/unit time) (unit time) (tons/unit time) (unit time)FS003, Emergency Reclaim Hopper PM 1.7527E-03 10.5162 day 1.919 0 1.919 1.919 0.44 6000 day 6000 dayPM108.2898E-04 4.9739 day 0.908 0 0.908 0.908 0.21 6000 day 6000 dayPM2.51.2553E-04 0.7532 day 0.137 0 0.137 0.137 0.03 6000 day 6000 dayFS008, Coal Outstacking PM 1.7527E-03 17.5269 day 3.199 40 1.919 1.919 0.44 10000 dayPM108.2898E-04 8.2898 day 1.513 40 0.908 0.908 0.21 10000 dayPM2.51.2553E-04 1.2553 day 0.229 40 0.137 0.137 0.03 10000 dayFS009, Coal Reclaim PM 1.7527E-03 10.5162 day 1.919 40 1.152 1.152 0.26 6000 dayPM108.2898E-04 4.9739 day 0.908 40 0.545 0.545 0.12 6000 dayPM2.51.2553E-04 0.7532 day 0.137 40 0.082 0.082 0.02 6000 dayFS015, Coal Conveyors 7, 7B & 7C PM 1.7527E-03 10.5162 day 1.919 0 1.919 1.919 0.44 6000 dayPM108.2898E-04 4.9739 day 0.908 0 0.908 0.908 0.21 6000 dayPM2.51.2553E-04 0.7532 day 0.137 0 0.137 0.137 0.03 6000 dayFS016, Coal Conveyor 8 PM 1.7527E-03 1.0516 hour 1.919 0 1.919 1.919 1.05 600 hour 6000 day(1 transfer point); (600 lb/hr; 6,000 tons/day) PM108.2898E-04 0.4974 hour 0.908 0 0.908 0.908 0.50 600 hour 6000 dayPM2.51.2553E-04 0.0753 hour 0.137 0 0.137 0.137 0.08 600 hour 6000 dayFS017, Dumper Unloading Building PM 1.7527E-03 17.5269 day 3.199 75 0.800 0.800 0.18 10000 dayPM108.2898E-04 8.2898 day 1.513 75 0.378 0.378 0.09 10000 dayPM2.51.2553E-04 1.2553 day 0.229 75 0.057 0.057 0.01 10000 dayISA,3&4 Fly Ash LoadoutPM 1.7527E-03 1.4898 day 0.272 75 0.068 0.068 0.02 850 dayPM108.2898E-04 0.7046 day 0.129 75 0.032 0.032 0.01 850 dayPM2.51.2553E-04 0.1067 day 0.019 75 0.005 0.005 0.00 850 dayISA, 200 Ton Stacking Hopper LoadoutPM 1.7527E-03 17.5269 day 3.199 0 3.199 3.199 0.73 10000 dayPM108.2898E-04 8.2898 day 1.513 0 1.513 1.513 0.35 10000 dayPM2.51.2553E-04 1.2553 day 0.229 0 0.229 0.229 0.05 10000 dayISA, Breaker Bldg Reject ChutesPM 1.7527E-03 0.0009 day 1.60E-04 0.00 1.60E-04 1.60E-04 3.65E-05 0.5 day(Rocks, poor quality coal) PM108.2898E-04 0.0004 day 7.56E-05 0.00 7.56E-05 7.56E-05 1.73E-05 0.5 dayPM2.51.2553E-04 0.0001 day 1.15E-05 0.00 1.15E-05 1.15E-05 2.62E-06 0.5 dayISA, Pri. Maint. Vac. - Breaker Bldg ChutePM 1.7527E-03 0.0009 day 1.60E-04 0.00 1.60E-04 1.60E-04 3.65E-05 0.5 dayPM108.2898E-04 0.0004 day 7.56E-05 0.00 7.56E-05 7.56E-05 1.73E-05 0.5 dayPM2.51.2553E-04 0.0001 day 1.15E-05 0.00 1.15E-05 1.15E-05 2.62E-06 0.5 dayISA, 3&4 Bottom Ash (Dewatered) LoadoutPM 1.4102E-04 1.2692 year 6.35E-04 0.00 6.35E-04 6.35E-04 1.45E-04 9000 year(Ash Pond Activity) PM106.6701E-05 0.6003 year 3.00E-04 0.00 3.00E-04 3.00E-04 6.85E-05 9000 yearPM2.51.0100E-05 0.0909 year 4.55E-05 0.00 4.55E-05 4.55E-05 1.04E-05 9000 yearIn addition, there are 2 more coal handling sources for which calculations were not provided: the dumper building cleanout chute, which is assumed to have emissions similar to the breaker building chutes;and unloading coal from vactor truck, which is assumed to have emissions similar to the stacking hopper loadout.Coal Yard TrafficEquation: Scraper Travel Model (Coal Yard)Source: AP-42 11.9 Western Surface Coal Mining (9/88, 10/98) and Dispersion Modeling 1998Basis, Miles Traveled:80 railcars/day @ 106 tons/car = 8480 tpd. 8480 tpd / 33 ton/load = 257 tripsPM: E = (2.7^-05)*(s^1.3)*(W^2.4)73% of coal pile distance 0.55 mi RT plus .4 mi Reclaim; 27% of coal travel distance 0.35 mi RT plus .65 mi Reclaim.PM10: E = 0.6*(6.2^06)*(s^1.4)*(W^2.5)For coal outstacking: 257 trips/day X .55 miles RT X 73% = 103 miles/day . Plus, 257 trips/day X 0.35 mile RT X 27% = 24 miles/day. Total = 103 + 24 = 127 miles/dayPM2.5: E = 0.026*(2.7^-05)*(s^1.3)*(W^2.4)For coal reclaim: 257 trips/day X .4 miles RT X 73% = 75 miles/day . Plus, 257 trips/day X 0.65 mile RT X 27% = 45 miles/day. Total = 75 + 45 = 120 miles/dayE = Emission Factor (lb/VMT)Assume maximum activity would be outstacking every other day, all day and reclaim on opposite days, all day. Thus, 182 days/year outstacking and 182 days/year reclaim.s = silt content (coal, 2.2% from AP-42 Table 13.2.4-1)W = mean vehicle wt (tons) - Average 48 tons (32 tons empty and 65 tons loaded)Scraper Traffic E (PM) = 0.816 lb/VMTScraper Traffic E (PM10) = 0.179 lb/VMTScraper Traffic E (PM2.5) = 0.021 lb/VMTMaximum Pollution Maximum LimitedEmissions Uncontrolled Control Controlled ControlledRate Emissions Efficiency Emissions EmissionsParticulate Sources (lb/VMT) (lb/day) (tons/yr) (%) (tons/yr) (tons/yr) VMT/yearFS014, Coal Yard Traffic (Scrapers; Outstacking) PM 8.16E-01 103.6 9.4 40 5.7 5.7 23,114PM101.79E-01 22.7 2.1 40 1.2 1.2 23,114PM2.52.12E-02 2.7 0.2 40 0.1 0.1 23,114FS014, Coal Yard Traffic (Scrapers; Reclaim) PM 8.16E-01 98.4 9.0 40 5.4 5.4 21,964PM101.79E-01 21.6 2.0 40 1.2 1.2 21,964PM2.52.12E-02 2.6 0.2 40 0.1 0.1 21,964SubtotalsPM 202.0 18.4 11.0 11.0Permit LimitsPM1044.4 4.0 2.4 2.4PM2.55.3 0.5 0.3 0.3Equation: Bulldozer Traffic (Coal Pile Grooming)Source: AP-42 11.9-2 Western Surface Coal Mining (9/88, 10/98)Bulldozer TrafficPM: E = 78.4*(s^1.2)/(M^1.3) E = Emission factor lb/hrPM10: E = 0.75*18.6*(s^1.5)/(M^1.4) s = silt content (coal, 2.2% from AP-42 Table 13.2.4-1)PM2.5: E = 0.022*78.4*(s^1.2)/(M^1.3) M = material moisture content (4.5%; mean from from AP-42 Table 13.2.4-1, coal fired power plant)Bulldozer Traffic E (PM) = 28.579 lb/hrBulldozer Traffic E (PM10) = 5.543 lb/hrBulldozer Traffic E (PM2.5) = 0.629 lb/hrGrader TrafficPM: E = 0.040*(S^2.5)PM10: E = 0.6*0.051*(S^2.0)PM2.5: E = 0.031*0.040*(S^2.5)Grader Traffic E (PM) = 5.373 lb/VMTS = vehicle speed = 7.1 mph from AP-42 11.9-3 Grader Traffic E (PM10) = 1.543 lb/VMTGrader Traffic E (PM2.5) = 0.167 lb/VMTWater Wagon, Front-end Loaders (assume Vehicle Traffic equation)PM: E = 5.79/(M^4.0) GraderTraffic E (PM) = 0.014 lb/VMTPM10: E = 0.6 * 3.72/(M^4.3) Grader Traffic E (PM10) = 0.003 lb/VMTPM2.5: E = 0.017*5.79/(M^4.0) Grader Traffic E (PM2.5) = 0.000 lb/VMTE = Emission factor lb/VMTM = moisture content = 4.5% (AP-42, Table 13.2-4-1)Maximum Pollution Maximum LimitedEmissions Uncontrolled Controlled Controlled ControlledRate Emissions Efficiency Emissions EmissionsParticulate Sources (lb/unit - hrs or VMT) (lb/year) (tons/yr) (%) (tons/yr) (tons/yr)FS014, Coal Yard Traffic PM 2.86E+01 3,572.37 1.79 40 1.07 1.07 125 hrs/yrBulldozer PM105.54E+00 692.82 0.35 40 0.21 0.21 125 hrs/yrPM2.56.29E-01 78.59 0.04 40 0.02 0.02 125 hrs/yrFS014, Coal Yard Traffic PM 5.37E+00 4,566.93 2.28 40 1.37 1.37 850 VMT (170 hrs/yr)Grading PM101.54E+00 1,311.16 0.66 40 0.39 0.39 850 VMT (170 hrs/yr)PM2.51.67E-01 141.57 0.07 40 0.04 0.04 850 VMT (170 hrs/yr)FS014, Coal Yard Traffic PM 1.41E-02 49.42 0.02 40 0.01 0.01 3500 VMT (170 hrs/yr)Miscellaneous Traffic PM103.47E-03 12.13 0.01 40 0.00 0.00 3500 VMT (170 hrs/yr)PM2.52.40E-04 0.84 0.00 40 0.00 0.00 3500 VMT (170 hrs/yr)Maximum Pollution Maximum LimitedEmissions Uncontrolled Control Controlled ControlledRate Emissions Efficiency Emissions EmissionsParticulate Sources (lb/day) (lb/year) (tons/yr) (%) (tons/yr) (tons/yr) (lb/hr)FS014, Coal Yard Traffic (Combined Total) PM 224.4 81,924 22.5 40 13.49 13.5 3.08(scrapers+bulldozer+grading+misc.) PM1049.9 18,205 5.0 40 3.03 3.0 0.69PM2.55.9 2,138 0.6 40 0.35 0.4 0.08

### Xcel Energy - Black Dog Generating Plant

Greenhouse Gases

Parameter Rate (lb/mmBtu) CO 2 

### e Rate (lb/mmBtu) Data Source

CO 2 

### - subbit. coal 209.76 209.76 CEMS

CO 2 

### - petroleum coke 225.77 225.77 40 CFR 98

CO 2 

### - bit um. coa l 205.65 205.65 40 CFR 98

CO 2 

### - natural gas 116.98 116.98 40 CFR 98

CO 2 

### - propane 138.60 138.60 40 CFR 98

CO 2 

### - EU026 & EU027 118.86 118.86 CEMS

CO 2 

### - No. 2 oil 161.49 161.49 40 CFR 98

CO 2 

### - Waste oil as lubricants 163.14 163.14 40 CFR 98

Methane - all coal & coke 0.0243 0.6063 40 CFR 98 Methane - natural gas 0.0022 0.0551 40 CFR 98 Methane - Petroleum including propan e 0.0066 0.1653 40 CFR 98

Nitrous oxide - all coal & coke 0.0035 1.0512 40 CFR 98 Nitrous oxide - natural ga s 0.0002 0.0657 40 CFR 98 Nitrous oxide - Petroleum including propan e 0.0013 0.3942 40 CFR 98

CO 2 

### e totals by fuel CO 2 

### e Rate (lb/mmBtu) Data Source

CO 2 

### e total - subbit. coal 211.42 CEMS & 40 CFR 98

CO 2 

### e total - coke 227.43 40 CFR 98

CO 2 

### e total - bit. coal 207.30 40 CFR 98

CO 2 

### e total - natural gas 117.10 40 CFR 98

CO 2 

### e total - propane 139.16 40 CFR 98

CO 2 

### e total - No. 2 oil 162.05 40 CFR 98

CO 2 

### e total - Waste oil as lubricants 163.70 40 CFR 98

CO 2 

### e t o t a l - EU026 & EU027 118.98 CEMS & 40 CFR 98 Greenhouse Gases2012 Emission Inventory TotalsSOURCE_ID SOURCE_NAME PERMIT_TYPE NAICS_CODE INVENTORY_YEAR EMISSION_UNIT_CODE03700003 Xcel Energy - Black Dog R 221112 2012 TONAMMONIA CO CO2 LEAD MERCURY0.4839605 450.35377 1579706.637 0.022018779 0.037100074METHANE NITROUS OXID NOX PM10FIL PM25FIL PMCON PMFIL160.1948539 23.19054859 6056.456 168.717233 0.51548624 79.1190151 174.648254SO2 VOC2796.400193 24.10660914CO2e = 1590259.799PM 253.7672695PM10 247.8362481PM2.5 79.63450134

# Attachment 2

Facility Description & CD-01

FormsMINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog22 July, 2013 14:15FACILITY DESCRIPTION: STACK/VENTS (SV)ID No.Discharge DirectionFlow Rate/TemperatureInformation SourceExit GasTemperatureat Top(oF)DesignFlow Rateat Top(ACFM)Width(feet)Diameteror Length(feet)Inside DimensionsHeight ofOpeningFromGround(feet)AddedBy(Action)RetiredBy(Action)OperatorIDfor ItemOperators DescriptionStack/VentStatus1SV 001Up, No CapTest347215950122.5600PER 008Stack 1Main Stack for Boilers 3 and 4Active2SV 002HorizontalManufacturer7035003314PER 008Stack 7Stacking Hopper (EU 005) StackActive3SV 003Up, No CapManufacturer7068000630PER 008Stack 6Dumper Building (EU 006) StackActive4SV 004Up, No CapManufacturer706001274PER 008Stack 23Yard Agglomerator (EU 007) StackActive5SV 005Up, No CapManufacturer7040000325PER 008Stack 21Breaker Bldg. (EU 008) StackActive6SV 006Up, No CapManufacturer7026000325PER 008Stack 22Breaker Bldg. (EU 009 and EU 010) StackActive7SV 007Up, No CapManufacturer70290003155PER 008Stack 18Tripper Area (EU 011) StackActive8SV 008Up, No CapManufacturer70126003155PER 008Stack 19Unit 3 Coal Silos (EU 012)Active9SV 009Up, No CapManufacturer70190003175PER 008Stack 20Unit 4 Coal Silos (EU 013)Active10SV 010Up, No CapManufacturer70750.8101PER 008Retired11SV 011HorizontalManufacturer70750.8133PER 008Retired12SV 012HorizontalManufacturer70750.8133PER 008Retired13SV 013HorizontalManufacturer25027501.883PER 008Retired14SV 014Up, No CapManufacturer350360.2529PER 008Stack 17Fly Ash Collection System (EU 018) StackRetired15SV 015HorizontalManufacturer25047121.232PER 008Stack 11Fly Ash Storage Silo (EU 020) StackRetired16SV 016HorizontalManufacturer2501900.712PER 008Stack 12Fly Ash Collection System (EU 021) StackActive17SV 017PER 008Stack 24Temp. Emergency Engine (EU 023) StackActive18SV 017PER 011Stack 24Never installed - Temp. Emergency Engine (EU 023) StackRemoved19SV 018Up, With CapManufacturer891141101.3340PER 008Emergency Engine Generator (EU 024) StackActive20SV 018Up, No CapManufacturer891141101.3340PER 011Emergency Engine Generator (EU 024) StackActive21SV 019Up, With CapManufacturer891141101.3340PER 008Emergency Engine Generator (EU 025) StackActive22SV 019Up, No CapManufacturer891141101.3340PER 011Emergency Engine Generator (EU 025) StackActive23SV 020Up, No CapManufacturer181106418918230PER 006Combustion Turbine w/DLN & SCR; Duct Burners w/SCRActive24SV 021HorizontalManufacturer9911610.00.3325PER 011Fire PumpActivePage 1 of 1MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog22 July, 2013 14:15FACILITY DESCRIPTION:CONTROL EQUIPMENT (CE)ID No.AddedBy(Action)RetiredBy(Action)OperatorIDfor ItemControlEquip.TypeControl Equipment DescriptionModelControlEquip.StatusManufacturerPollutantsControlledAfterburnerCombustionParametersCaptureEfficiency(%)Destruction/CollectionEfficiency(%)1CE 001PER 008010Electrostatic Precipitator - High EfficiencyType 6 Group 30RemovedResearch CottrellPM10PM10010099.1599.152CE 002PER 008010Electrostatic Precipitator - High Efficiency30(996)2X28-12RemovedBelco/GEPM10PM10010099.1599.153CE 003PER 008007Centrifugal Collector - High Efficiency12 VMU/198-11RetiredJoy EnvironmentalPM10099.34CE 004PER 008010Electrostatic Precipitator - High EfficiencyType 6 Group 30RetiredResearch CottrellPM10PM10010099.399.35CE 005PER 008010Electrostatic Precipitator - High Efficiency30(996)2X34-12RemovedBelco/GEPM10PM10010099.399.36CE 006EIS 014010Electrostatic Precipitator - High EfficiencyType 6 Group 16ActiveResearch CottrellHAPsPM10PM0100100095957CE 006PER 011010Electrostatic Precipitator - High EfficiencyType 6 Group 16ActiveResearch CottrellHAPsPM2.5PM10PM010010010009595958CE 007EIS 014010Electrostatic Precipitator - High Efficiency30(996)2X38-12ActiveBelco/GEHAPsPM10PM0100100095959CE 007PER 011010Electrostatic Precipitator - High Efficiency30(996)2X38-12ActiveBelco/GEHAPsPM2.5PM10PM0100100100095959510CE 008EIS 014010Electrostatic Precipitator - High EfficiencyType 4 Group 31ActiveResearch CottrellHAPsPM10PM01001000959511CE 008PER 011010Electrostatic Precipitator - High EfficiencyType 4 Group 31ActiveResearch CottrellHAPsPM2.5PM10PM0100100100095959512CE 009EIS 014010Electrostatic Precipitator - High Efficiency30(996)4X24-12ActiveBelco/GEHAPsPM10PM01001000959513CE 009PER 011010Electrostatic Precipitator - High Efficiency30(996)4X24-12ActiveBelco/GEHAPsPM2.5PM10PM0100100100095959514CE 010PER 008007Centrifugal Collector - High EfficiencyT-42RetiredAllen Sherman HoffPM10099.715CE 011PER 001007Centrifugal Collector - High EfficiencyA-9150-11ActiveAllen Sherman HoffPM10PM10010099.799.7Page 1 of 4MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog22 July, 2013 14:15FACILITY DESCRIPTION:CONTROL EQUIPMENT (CE)ID No.AddedBy(Action)RetiredBy(Action)OperatorIDfor ItemControlEquip.TypeControl Equipment DescriptionModelControlEquip.StatusManufacturerPollutantsControlledAfterburnerCombustionParametersCaptureEfficiency(%)Destruction/CollectionEfficiency(%)16CE 011PER 011007Centrifugal Collector - High EfficiencyA-9150-11RetiredAllen Sherman HoffPM10PM10010099.799.717CE 012PER 008018Fabric Filter - Low Temperature, i.e., T<180 Degrees F100-S-10RetiredMikropulPM1009918CE 013PER 008018Fabric Filter - Low Temperature, i.e., T<180 Degrees F55-8-18RetiredMikropulPM10099.719CE 014PER 008018Fabric Filter - Low Temperature, i.e., T<180 Degrees F495-8-20RetiredMikropulPM1009920CE 015PER 001018Fabric Filter - Low Temperature, i.e., T<180 Degrees F19-8-408ActiveMikro-PulsairePM10PM10010099.799.721CE 015PER 011018Fabric Filter - Low Temperature, i.e., T<180 Degrees F19-8-408RetiredMikro-PulsairePM10PM10010099.799.722CE 016PER 001018Fabric Filter - Low Temperature, i.e., T<180 Degrees F544-RF8ActiveAir-Cure EnvironmentalIncPM10PM100100999923CE 016PER 011018Fabric Filter - Low Temperature, i.e., T<180 Degrees F544-RF8ActiveAir-Cure EnvironmentalIncPM2.5PM10PM10PM1001001001005499939924CE 017PER 001018Fabric Filter - Low Temperature, i.e., T<180 Degrees F484-RF8ActiveAir-Cure EnvironmentalIncPM10PM100100999925CE 017PER 011018Fabric Filter - Low Temperature, i.e., T<180 Degrees F484-RF8ActiveAir-Cure EnvironmentalIncPM2.5PM10PM10PM1001001001005499939926CE 018PER 001018Fabric Filter - Low Temperature, i.e., T<180 Degrees F376-RF8ActiveAir-Cure EnvironmentalIncPM10PM100100999927CE 018PER 011018Fabric Filter - Low Temperature, i.e., T<180 Degrees F376-RF8ActiveAir-Cure EnvironmentalIncPM2.5PM10PM10PM1001001001005499939928CE 019PER 001018Fabric Filter - Low Temperature, i.e., T<180 Degrees F676-RF8ActiveAir-Cure EnvironmentalIncPM10PM100100999929CE 019PER 011018Fabric Filter - Low Temperature, i.e., T<180 Degrees F676-RF8ActiveAir-Cure EnvironmentalIncPM2.5PM10PM10PM1001001001005499939930CE 020PER 001018Fabric Filter - Low Temperature, i.e., T<180 Degrees F484-RF8ActiveAir-Cure EnvironmentalIncPM1009931CE 020PER 011018Fabric Filter - Low Temperature, i.e., T<180 Degrees F484-RF8ActiveAir-Cure EnvironmentalIncPM2.5PM10PM10010010054939932CE 021PER 001018Fabric Filter - Low Temperature, i.e., T<180 Degrees F24RFS8ActiveAir-Cure EnvironmentalIncPM10099Page 2 of 4MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog22 July, 2013 14:15FACILITY DESCRIPTION:CONTROL EQUIPMENT (CE)ID No.AddedBy(Action)RetiredBy(Action)OperatorIDfor ItemControlEquip.TypeControl Equipment DescriptionModelControlEquip.StatusManufacturerPollutantsControlledAfterburnerCombustionParametersCaptureEfficiency(%)Destruction/CollectionEfficiency(%)33CE 021PER 011018Fabric Filter - Low Temperature, i.e., T<180 Degrees F24RFS8ActiveAir-Cure EnvironmentalIncPM2.5PM10PM10010010054939934CE 022PER 008018Fabric Filter - Low Temperature, i.e., T<180 Degrees FDLMV-10/10WRetiredDCE VokesPM10099.935CE 023PER 001018Fabric Filter - Low Temperature, i.e., T<180 Degrees F120 MCF 361ActiveMAC Equipment CoPM10PM100100999936CE 023PER 011018Fabric Filter - Low Temperature, i.e., T<180 Degrees F120 MCF 361ActiveMAC Equipment CoPM2.5PM10PM10PM1001001001005499939937CE 024PER 001018Fabric Filter - Low Temperature, i.e., T<180 Degrees F120 MCF 361ActiveMAC Equipment CoPM10PM100100999938CE 024PER 011018Fabric Filter - Low Temperature, i.e., T<180 Degrees F120 MCF 361ActiveMAC Equipment CoPM2.5PM10PM10PM1001001001005499939939CE 025PER 001018Fabric Filter - Low Temperature, i.e., T<180 Degrees F96AVS 36ActiveMAC Equipment CoPM10PM100100999940CE 025PER 011018Fabric Filter - Low Temperature, i.e., T<180 Degrees F96AVS 36ActiveMAC Equipment CoPM2.5PM10PM10PM1001001001005499939941CE 026PER 008018Fabric Filter - Low Temperature, i.e., T<180 Degrees FDLMV-15/15WRetiredDCE VokesPM10099.942CE 027PER 008018Fabric Filter - Low Temperature, i.e., T<180 Degrees FDLMV-10/10WRetiredDCE VokesPM10099.943CE 028EIS 014061Dust Suppression by Water SprayNAActiveNAPM10PM100100404044CE 028PER 011061Dust Suppression by Water SprayNARetiredNAPM10PM100100404045CE 029EIS 014061Dust Suppression by Water SprayNAActiveNAPM10PM100100404046CE 029PER 011061Dust Suppression by Water SprayNAActiveNAPM2.5PM10PM10010010040404047CE 030PER 001099OtherNAActiveNAPM10PM00777748CE 030PER 011099OtherNARetiredNAPM10PM00777749CE 031EIS 014099OtherNAActiveNAPM10PM1001009999Page 3 of 4MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog22 July, 2013 14:15FACILITY DESCRIPTION:CONTROL EQUIPMENT (CE)ID No.AddedBy(Action)RetiredBy(Action)OperatorIDfor ItemControlEquip.TypeControl Equipment DescriptionModelControlEquip.StatusManufacturerPollutantsControlledAfterburnerCombustionParametersCaptureEfficiency(%)Destruction/CollectionEfficiency(%)50CE 031PER 011099OtherNARetiredNAPM10PM100100999951CE 032PER 006099Selective Catalytic ReductionActiveNOx10082.452CE 032PER 011099Selective Catalytic ReductionNAActiveBabcock-HitachiNOx10082.453CE 033PER 006099Dry-Low NOx combustionActive54CE 033PER 011099Dry-Low NOx combustionNAActiveSiemens55CE 034PER 008008Centrifugal Collector - Medium EfficiencyB-60ActiveAllen-Sherman-HoffPM10PM100100505056CE 034PER 011008Centrifugal Collector - Medium EfficiencyB-60RetiredAllen-Sherman-HoffPM10PM100100505057CE 035PER 008018Fabric Filter - Low Temperature, i.e., T<180 Degrees F84-CTBC-38 IIActiveFlex-CleanPM10PM100100999958CE 035PER 011018Fabric Filter - Low Temperature, i.e., T<180 Degrees F84-CTBC-38 IIRetiredFlex-CleanPM10PM1001009999Page 4 of 4ST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name:MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROAD22 July, 2013 14:15FACILITY DESCRIPTION: EMISSION UNIT (EU)MaxFuelInput(mil Btu)Xcel Energy - Black DogRetiredBy(Action)Operator DescriptionID No.EmissionUnitStatusAddedBy(Action)ControlEquip.ID No(s).Stack/VentID No(s).OperatorIDfor ItemInsignificantActivitySICManufacturerModelNumberMax.DesignCapacityMaximumDesignCapacityMaterials Units nUnits d9101Boiler 1 - retired, to beremovedEU 001 RemovedPER 008CE 002SV 001 (M)Elect Energy4911Combustion Engineerin734881Mw13232Boiler 2 - retired from servicein placeEU 002 RetiredPER 008CE 004SV 001 (M)Elect Energy4911Foster Wheeler2-43-4814137Mw11763Boiler 3EU 003ActivePER 001CE 006CE 007SV 001 (M)Elect Energy4911Babcock and WilcoxRB-218120Mw18924Boiler 4EU 004ActivePER 001CE 008CE 009SV 001 (M)Elect Energy4911Babcock and WilcoxRB-343186Mw5200 Ton Stacking HopperEU 005ActivePER 001CE 025CE 031SV 002 (M)Hr4911NANA1300Ton6200 Ton Stacking HopperEU 005ActivePER 011CE 025SV 002 (M)Hr4911NANA1300Ton7Dumper Unloading BldgEU 006ActivePER 001CE 023CE 024SV 003 (M)Hr4911NANA1300Ton8Yard Agglomerator SiloEU 007ActivePER 001CE 021SV 004 (M)Day4911Air-CureNA16Ton9Breaker Building (CoalConveying)EU 008ActivePER 008CE 019SV 005 (M)Hr4911BradfordNA1300Ton10Transfer TowerEU 009ActivePER 008CE 020SV 006 (M)Hr4911BradfordNA1300Ton11Breakers (Crushing)EU 010ActivePER 008CE 020SV 006 (M)Hr4911BradfordNA1300Ton12Tripper Area (Conveyors Dand F)EU 011ActivePER 008CE 016SV 007 (M)Hr4911LinkNA900Ton13Coal SilosEU 012ActivePER 008CE 017SV 008 (M)Hr4911NANA900Ton14Unit 3 Coal SiloEU 012ActivePER 011CE 017SV 008 (M)Hr4911NANA900Ton15Unit 4 Coal SiloEU 013ActivePER 008CE 018SV 009 (M)Hr4911NANA900Ton16Unit 2 Sorbent Storage SiloEU 014 RetiredPER 008SV 010 (M)Hr4911Chicago Bridge & IronNA25Ton17Unit 2 Sorbent Day Bin 21EU 015 RetiredPER 008SV 011 (M)Hr4911Macawber8/12 Denseveyor12Ton18Unit 2 Sorbent Day Bin 22EU 016 RetiredPER 008SV 012 (M)Hr4911Macawber8/12 Denseveyor12Ton19Unit 2 Spent Bed StorageEU 017 RetiredPER 008SV 013 (M)Hr4911Allen Sherman HoffNA30Ton20Units 3 and 4 SecondaryPrecip. Fly Ash CollectionSystem VentingEU 018 RetiredPER 008CE 015Hr4911Allen Sherman Hoff (JoNA21600Ft3Page 1 of 2 (a)22 July, 2013 14:15FACILITY DESCRIPTION: EMISSION UNIT (EU)ID No.ElevatorTypeBottleneckPct.Fuel/SpaceHeatFiring MethodAddedBy(Action)RemovalDateInitialStartupDateCommenceConst.DateEmissionUnitStatus1EU 0011PER 00812/01/200009/17/195205/01/1949Pulverized Coal: Dry Bottom (Tangential)Removed2EU 0020PER 00811/29/195412/31/1952Atmospheric Fluidized Bed CombustionRetired3EU 0031PER 00108/28/195512/31/1953Pulverized Coal: Dry BottomActive4EU 0041PER 00110/03/196012/31/1957Pulverized Coal: Dry BottomActive5EU 005PER 00112/31/196401/01/1964Active6EU 005PER 01112/31/196401/01/1964Active7EU 006PER 00112/31/195201/01/1950Active8EU 007PER 00108/01/199201/01/1992Active9EU 008PER 00812/31/195012/31/1950Active10EU 009PER 00808/01/195208/01/1950Active11EU 010Group of SourcesPER 00812/31/195212/31/1949Active12EU 011Group of SourcesPER 00812/31/195212/31/1949Active13EU 012Group of SourcesPER 00812/31/195212/31/1949Active14EU 012Group of SourcesPER 01112/31/195212/31/1949Active15EU 013Group of SourcesPER 00812/31/196012/31/1958Active16EU 014PER 00803/31/198606/30/1985Retired17EU 015PER 00803/31/198606/30/1985Retired18EU 016PER 00803/31/198606/30/1985Retired19EU 017PER 00806/30/198607/31/1985Retired20EU 018PER 00812/31/197612/31/1976RetiredPage 1 of 2 (b)ST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name:MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROAD22 July, 2013 14:15FACILITY DESCRIPTION: EMISSION UNIT (EU)MaxFuelInput(mil Btu)Xcel Energy - Black DogRetiredBy(Action)Operator DescriptionID No.EmissionUnitStatusAddedBy(Action)ControlEquip.ID No(s).Stack/VentID No(s).OperatorIDfor ItemInsignificantActivitySICManufacturerModelNumberMax.DesignCapacityMaximumDesignCapacityMaterials Units nUnits d21Units 3 and 4 Fly Ash SiloVentEU 019ActivePER 002CE 004CE 005CE 006CE 007CE 008CE 009SV 001 (M)Hr4911United ConveyorNA90000Ft322Units 3 and 4 Fly Ash SiloVentEU 019ActivePER 011CE 006CE 007CE 008CE 009SV 001 (M)Hr4911United ConveyorNA90000Ft323No. 2 Fly Ash Storage SiloEU 020 RetiredPER 008SV 015 (M)Hr4911Chicago Bridge & IronNA30Ton24No. 2 Fly Ash CollectionSystemEU 021 RetiredPER 008CE 013SV 016 (M)Hr4911Allen Sherman Hoff1876-0230Ton25Spent Sorbent ScreeningEU 022 RetiredPER 002SV 015 (M)Hr4911Eriez MfgG2B10Ton26Temporary Emergency EngineEU 023ActivePER 001SV 017 (M)Energy4911NANA300Hp27(never installed) TemporaryEmergency EngineEU 023 RemovedPER 011Energy4911NANA300Hp16.8128Emergency Engine GeneratorEEG-61001EU 024ActivePER 008SV 018 (M)Energy4911Caterpillar3516TA2598Hp16.8129Emergency Engine GeneratorEEG-61002EU 025ActivePER 008SV 019 (M)Energy4911Caterpillar3516TA2598Hp191730Combustion Turbine (Dry LowNOx Combustors & SelectiveCatalytic Reduction)EU 026ActivePER 006CE 032CE 033SV 020 (M)Elect Energy4911Siemens/Westinghouse501F183.5Mw51031Duct Burners (SelectiveCatalytic Reduction)EU 027ActivePER 008CE 032SV 020 (M)Hr4911Deltak CorpDino 5564/72510Mmbtu1.4832Fire PumpEU 028ActivePER 011SV 021 (M)HrElect Energy4911Cummins6BTA5.9F1208HpPage 2 of 2 (a)22 July, 2013 14:15FACILITY DESCRIPTION: EMISSION UNIT (EU)ID No.ElevatorTypeBottleneckPct.Fuel/SpaceHeatFiring MethodAddedBy(Action)RemovalDateInitialStartupDateCommenceConst.DateEmissionUnitStatus21EU 019PER 00212/31/197612/31/1976Active22EU 019PER 01112/31/197612/31/1976Active23EU 020PER 00812/31/200506/30/198612/31/1985Retired24EU 021PER 00812/31/200506/30/198612/31/1985Retired25EU 022PER 00209/30/198609/30/1986Retired26EU 023PER 001Active27EU 023PER 01103/20/2012Removed28EU 024PER 00810/11/199605/01/1996Active29EU 025PER 00810/11/199605/01/1996Active30EU 026PER 00606/21/200103/21/2001Active31EU 027PER 00806/21/200103/21/2001Active32EU 028PER 01101/01/199901/01/1999ActivePage 2 of 2 (b)MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog22 July, 2013 14:16FACILITY DESCRIPTION: FUGITIVE SOURCES (FS)ID No.Fugitive Source DescriptionYearInstalledYearRemovedAddedBy(Action)RetiredBy(Action)InsignificantActivityOperatorIDfor ItemPollutant(s)EmittedControlEquip.ID No(s).FugitiveSourceStatus1FS 001PER 008PMPM10Barge UnloadingActive2FS 0011992PER 011PMPM10Barge UnloadingRemoved3FS 002PER 008PMCoal Conveyors 6 and 7ARetired4FS 003EIS 001PMPM10Emergency Reclaim HopperActive5FS 003PER 011PMPM10PM2.5Emergency Reclaim HopperActive6FS 004EIS 001PMPM10CE 029All Coal Storage Piles (Erosion)Active7FS 004PER 011PMPM10PM2.5CE 029All Coal Storage Piles (Erosion)Active8FS 008EIS 001PMPM10CE 029Coal OutstackingActive9FS 008PER 011PMPM10PM2.5CE 029Coal OutstackingActive10FS 009EIS 001PMPM10CE 029Coal ReclaimActive11FS 009PER 011PMPM10PM2.5CE 029Coal ReclaimActive12FS 010EIS 001PMPM10CE 029Petroleum Coke Storage (Erosion)Active13FS 0102013PER 011PMPM10Petroleum Coke Storage (Erosion)Removed14FS 011EIS 001PMPM10Petroleum Coke UnloadingActive15FS 0112013PER 011PMPM10Petroleum Coke UnloadingRemoved16FS 012EIS 001PMPM10CE 029Petroleum Coke ReclaimActive17FS 0122013PER 011PMPM10Petroleum Coke ReclaimRemoved18FS 013EIS 001PMPM10CE 029Ash Hauling TrafficActivePage 1 of 2MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog22 July, 2013 14:16FACILITY DESCRIPTION: FUGITIVE SOURCES (FS)ID No.Fugitive Source DescriptionYearInstalledYearRemovedAddedBy(Action)RetiredBy(Action)InsignificantActivityOperatorIDfor ItemPollutant(s)EmittedControlEquip.ID No(s).FugitiveSourceStatus19FS 013PER 011PMPM10PM2.5CE 029Ash Hauling TrafficActive20FS 014EIS 001PMPM10CE 029Coal Yard TrafficActive21FS 014PER 011PMPM10PM2.5CE 029Coal Yard TrafficActive22FS 015EIS 001PMPM10Coal Conveyors 7,7B,7CActive23FS 015PER 011PMPM10PM2.5Coal Conveyors 7,7B,7CActive24FS 016EIS 001PMPM10Coal Conveyor 8Active25FS 016PER 011PMPM10PM2.5Coal Conveyor 8Active26FS 017EIS 001PMPM10CE 031Dumper Unloading Bldg (fugitives from unloading railcar/scraper)Active27FS 017PER 011PMPM10PM2.5CE 031Dumper Unloading Bldg (fugitives from unloading railcar/scraper)ActivePage 2 of 2MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194Show:Action:AQD Facility ID:Facility Name:Active and Pending RecordsPER 01103700003Xcel Energy - Black DogFACILITY DESCRIPTION: GROUPS (GP)22 July, 2013 14:14ID No.AddedBy(Action)RetiredBy(Action)Includein EIOperatorIDfor ItemGroup DescriptionGroup ItemsGroupStatus1GP 001PER 008Emergency Engine GeneratorsEU 024, EU 025, SV 018, SV 019Active2GP 002PER 008Boilers and Associated Control EquipmentCE 006, CE 007, CE 008, CE 009, EU 003, EU 004, EU 019, SV 001Active3GP 002PER 011Boilers and Associated Control EquipmentCE 006, CE 007, CE 008, CE 009, EU 003, EU 004, MR 006, MR 013, MR 014,MR 015, MR 016, SV 001Active4GP 003PER 008Electrostatic Precipitator RequirementsCE 006, CE 007, CE 008, CE 009Active5GP 004PER 008Main Stack (SV 001) CEMSMR 006, MR 013, MR 014, MR 015, SV 001Active6GP 004PER 011CEMS Required by Acid Rain RegulationsMR 006, MR 013, MR 014, MR 015Active7GP 005PER 008Combustion Turbine/Duct Burner Stack MonitorsMR 010, MR 011, MR 012, SV 020Active8GP 005PER 011CEMS Required by Acid Rain and NSPS RegulationsMR 017, MR 018Active9GP 006PER 008Fabric Filter RequirementsCE 016, CE 017, CE 018, CE 019, CE 020, CE 021, CE 023, CE 024, CE 025Active10GP 007PER 011Combustion Turbine/Duct Burner Combined RequirmentsCE 032, CE 033, EU 026, EU 027, MR 017, MR 018, MR 019, SV 020Active11GP 008PER 011Acid Rain Affected SourcesEU 003, EU 004, EU 026ActivePage 1 of 1MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog22 July, 2013 14:16FACILITY DESCRIPTION: CONTINUOUS MONITORS (MR)ParametersMonitoredSerial NumberID No.Model NumberManufacturerOperatorIDfor ItemMonitoredItem(ID No(s).)RetiredBy(Action)AddedBy(Action)Monitor DescriptionMonitorStatus11251050UMR 001SM-8100Lear Siegler (N)PER 008Removed2401-0564MR 002401Dynatron (N)PER 008Removed34693MR 003AR-30C2AZAnaradPER 008Removed44694MR 004AR-880AnaradPER 008Removed54695MR 005AR-23AnaradPER 008Removed6Air Flow399MR 006GFM-7-NSEMRCSV 001PER 008Air Flow MonitorActive7739MR 007RM-41Lear SieglerPER 008Removed81251052UMR 008SM-8100Lear Siegler (S)PER 008Removed9401-0563MR 009401Dynatron (S)PER 008Removed10NOx42CLS-72158-370MR 01042C-LSTECOSV 020PER 008Unit 5/2 NOx Dual RangeActive11NOx42CLS-72158-370MR 01042C-LSTECOPER 011Unit 5/2 NOx Dual RangeRemoved12O2A611024-004-112MR 011BA3000BuhlerSV 020PER 008Unit 5/2 O2Active13O2A611024-004-112MR 011BA3000BuhlerPER 011Unit 5/2 O2Removed14CO48CTL-709990-367MR 01248C-TLTECOSV 020PER 008Unit 5 CO - High and LowActive15CO48CTL-709990-367MR 01248C-TLTECOPER 011Unit 5 CO - High and LowRemoved16SO20436609951MR 01343CTECOSV 001PER 008Boilers 3 & 4 SO2 MonitorActive17NOx74090-375MR 01442CTECOSV 001PER 008Boilers 3 & 4 NOx MonitorActive18CO20502810444MR 01541CHLTECOSV 001PER 008Boilers 3 & 4 CO2 MonitorActive19Opacity9995384MR 016Mark IILand CombustionSV 001PER 008Boilers 3 & 4 Opacity MonitorActive20NOx1032745661MR 01742i-LSThermo Fisher ScientificSV 020PER 011Unit 5/2 NOx Dual Range MonitorActive21O201440DIV02/4173MR 0181440DServomexSV 020PER 011Unit 5/2 O2 MonitorActive22CO1032745662MR 01948iThemo Fisher ScientificSV 020PER 011Unit 5/2 CO Dual Range MonitorActivePage 1 of 1 (a)22 July, 2013 14:16FACILITY DESCRIPTION: CONTINUOUS MONITORS (MR)ID No.AddedBy(Action)SpanValueSystemFullScaleValueBypassCapability?RemovalDateInstallationDateOpticalPathLengthRatioMonitorStatus1MR 001 PER 008No12/01/2000Removed2MR 002 PER 008No12/01/2000Removed3MR 003 PER 008No06/01/2005Removed4MR 004 PER 008No06/01/2005Removed5MR 005 PER 008No06/01/2005Removed6MR 006 PER 0083 3No01/01/1995Active7MR 007 PER 008No09/01/1999Removed8MR 008 PER 008No12/01/2000Removed9MR 009 PER 008No12/01/2000Removed10MR 010 PER 00820 75No06/30/2002Active11MR 010 PER 01120 75No05/05/201106/30/2002Removed12MR 011 PER 00820 25No06/30/2002Active13MR 011 PER 01120 25No05/05/201106/30/2002Removed14MR 012 PER 00850 4000No05/01/2002Active15MR 012 PER 01150 4000No05/05/201105/01/2002Removed16MR 013 PER 008300 300No07/01/2005Active17MR 014 PER 008800 800No07/01/2005Active18MR 015 PER 00820 20No07/01/2005Active19MR 016 PER 00880 100No09/01/19990.95Active20MR 017 PER 011100 100No05/05/2011Active21MR 018 PER 01125 25No05/05/2011Active22MR 019 PER 0112000 2000No05/05/2011ActivePage 1 of 1 (b)MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY22 July, 2013 14:16520 LAFAYETTE ROADST. PAUL, MN 55155-4194FACILITY DESCRIPTION: DATAACQUISITION SYSTEMS (DA)Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black DogID No.RemovalDateInstallationDateData StorageMediumSerial NumberManufacturerModel NumberDASStatusOperatorIDfor ItemData Acquisition System DescriptionRetiredBy(Action)AddedBy(Action)1DA 00106/01/2005Other1250047Lear SieglerUnicon 700RemovedPER 0082DA 00207/01/2005OtherPM1636Environmental SystemsESC DAHSActiveUnits 3 & 4PER 0083DA 00306/01/2002OtherPM1636Environmental SystemsESC DAHSActiveUnits 5PER 0084DA 00404/15/2018ElectronicA0900Environmental SystemsCStack VisionActiveUnits 3 & 4PER 0115DA 00504/15/2008Electronic0698Environmental SystemsCStackVisionActiveUnit 5PER 011Page 1 of 1MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog22 July, 2013 14:1622 July, 2013 14:16FACILITY DESCRIPTION: CONTINUOUS MONITORING SYSTEMS (CM)ID No.AddedBy(Action)RetiredBy(Action)MonitorID No(s).DASID No(s).OperatorIDfor ItemCMS DescriptionParameterMonth/YearInstalledMonth/YearRemovedCert.DateCert.BasisCMSStatus1CM 001PER 008MR 003MR 005Boilers 1-4: 1.2 lbs SO2/mmBtu, SV001, 1-hr ave., When EU002 isoperatingSulfur Dioxide 12/200010/14/1994 40CFR75Removed2CM 002PER 008MR 003MR 005Boilers 1-4: 1.3 lbs SO2/mmBtu, SV001, 1-hr ave., When EU002 isnot operatingSulfur Dioxide 12/200010/14/1994 40CFR75Removed3CM 003PER 008MR 003MR 006Boilers 1-4: 6759 lbs SO2/hr, SV001, 1-hr ave.Sulfur Dioxide 06/200510/14/1994 40CFR75Removed4CM 004PER 008MR 007 Units 1-4: 20% Opacity, SV001, 1-min ave.Opacity 07/199910/14/1994 40CFR60Removed5CM 005PER 008MR 014MR 015DA 002 Boilers 3 & 4 NOx lb/MM BtuNitrogen Oxides 06/200506/24/2005 40CFR75Active6CM 006PER 008MR 010MR 011DA 003 Unit 5 NOx ppmNitrogen Oxides 05/200206/30/2002 40CFR60Active7CM 007PER 008MR 011MR 012DA 003 Unit 5 CO ppmCarbon Monoxide 05/200206/30/2002 40CFR60Active8CM 008PER 008MR 016 DA 002 Boilers 3 & 4 OpacityOpacity 09/199910/06/1999 40CFR60Active9CM 009PER 008MR 013MR 015DA 002 Boilers 3 & 4 SO2 lb/MM BtuSulfur Dioxide 06/200506/24/2005 40CFR75Active10CM 010PER 008MR 013MR 016DA 002 Boilers 3 & 4 SO2 lb/hrSulfur Dioxide 06/200506/24/2005 40CFR75Active11CM 011PER 011MR 017MR 018DA 005 Unit 5 NOx ppmNitrogen Oxides 05/201106/11/2011 40CFR60Active12CM 012PER 011MR 018MR 019DA 005 Unit 5 CO ppmCarbon Monoxide 05/201106/11/2011 40CFR60ActivePage 1 of 1MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black DogRetiredBy(Action)AddedBy(Action)ID No.OperatorIDfor ItemRoof HeightfromGround(feet)Length(feet)Width(feet)Description/CommentFACILITY DESCRIPTION: BUILDINGS (BG)22 July, 2013 14:17BuildingStatus1 PER 011428297150BG 001001Plant-includes 40' width for secondary ESPActive2 PER 011836022BG 002002Maintenance BuildingActive3 PER 011584875BG 003003Breaker BuildingActive4 PER 011655535BG 004004Dumper BuildingActive5 PER 011804026BG 005005Train Storage GarageActive6 PER 0111923217BG 006006WarehouseActive7 PER 011621612.5BG 007007Substation Control BuildingActive8 PER 0111055135BG 008008Screen HouseActive9 PER 0111005929BG 009009Stock RoomActive10 PER 011385039BG 010010Gas Compressor BuildingActive11 PER 011222828BG 011011ActivePage 1 of 1MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 1 of 64

Subject Item: Total Facility

NC/

CA Type Citation Requirement

CD hdr SOURCE-SPECIFIC REQUIREMENTS 1.0

CD Minn. R. 7007.0800, subp. 2 Permit Appendices: This permit contains appendices as listed in the permit Table of Contents. The Permittee shall comply with all requirements contained in

A ppendices B, C, and E.

Modeling parameters in Appendix D are included for reference only as described

elsewhere in Table A. 2.0

CD Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 The parameters used in PM10 modeling dated April 28, 1998, and NOX modeling dated March 2002 are listed in Appendix D of this permit. The parameters describe the operation of the facility at maximum permitted capacity.

For any changes that affect any modeled parameter or emission rate documented in Appendix D, or are an addition to information documented in Appendix D, a Remodeling Submittal requirement is triggered. This includes changes that do not require a permit amendment as well as changes that require any type of permit

amendment. 3.0

CD Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 Remodeling Submittal: The Permittee must submit to the MPCA for approval any revisions of the parameters documented in Appendix D and must wait for a written approval before making such changes (see page 1 of Table B of this permit for MPCA mailing information). For changes that don't require a moderate or major amendment, written approval of the modeling may be given before permit issuance; however, the approval applies only to the modeling and not to any other changes. The information submitted must include, for stack and vent sources, source emission rate, location, height, diameters, exit velocity, exit temperature, discharge direction, use of rain caps or rain hats, and, if applicable, locations and dimensions of nearby buildings. For non-stack/vent sources, this includes the source emission rate, location, size and shape, release height, and, if applicable, any emission rate
scalars, and the initial lateral dimensions and initial vertical dimensions and adjacent building heights. 4.0

CD Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 The plume dispersion characteristics due to the revisions of the parameters documented in Appendix D must be equivalent to or better than the dispersion characteristics modeled April 1998 (PM10) or March 2002 (NOX). The Permittee shall demonstrate this equivalency in the proposal. If the information does not demonstrate equivalent or better dispersion characteristics, or if a conclusion cannot readily be made about the dispersion, the Permittee must submit full remodeling. 5.0

CD Minn. R. 7011.1105 (I) Operating practices: Clean up all coal spilled on roads or access areas as soon as practicable using methods that minimize the amount of dust suspended. 6.0

CD Minn. R. 7011.1105 (A)(1) A ccess areas, roads, parking facilities:

Install asphalt or concrete surfaces or chemical agents on all active truck haul roads of the coal handling facility when the coal throughput by truck is 200,000 tons or greater. All paved roads and areas shall be cleaned to minimize the discharge to the atmosphere of fugitive particulate emissions. Such cleaning shall be accomplished in a manner which minimizes resuspension of particulate matter.

A ccess areas surrounding coal stockpiles and parking facilities which are located within a coal handling facility shall be treated with water, oils, or chemical agents. 7.0

CD hdr DETERMINING IF A PROJECT/MODIFICATION IS SUBJECT TO NEW SOURCE

REVIEW 8.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 2 of 64

CD Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.0800, subp. 2 These requirements apply if a reasonable possibility (RP) as defined in 40 CFR Section 52.21(r)(6)(vi) exists that a proposed project, analyzed using the actual-to-projected-actual (ATPA) test (either by itself or as part of the hybrid test at Section 52.21(a)(2)(iv)(f)) and found to not be part of a major modification, may result in a significant emissions increase (SEI). If the ATPA test is not used for the project, or if there is no RP that the proposed project could result in a SEI, these requirements do not apply to that project. The Permittee is only subject to the Preconstruction Documentation requirement for a project where a RP occurs only within the meaning of Section 52.2(r)(6)(vi)(a).

Even though a particular modification is not subject to New Source Review (NSR), or where there isn't a RP that a proposed project could result in a SEI, a permit amendment, recordkeeping, or notification may still be required by Minn. R.

7007.1150 - 7007.1500. 9.0

CD Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.1200, subp. 4; Minn. R. 7007.0800, subps. 4 & 5 Preconstruction Documentation -- Before beginning actual construction on a project, the Permittee shall document the following:

1. Project description 2. Identification of any emission unit (EU) whose emissions of an NSR pollutant

could be affected 3. Pre-change potential emissions of any affected existing EU, and the projected post-change potential emissions of any affected existing or new EU. 4. A description of the applicability test used to determine that the project is not a major modification for any regulated NSR pollutant, including the baseline actual emissions, the projected actual emissions, the amount of emissions excluded due

to increases not associated with the modification and that the EU could have accommodated during the baseline period, an explanation of why the amounts were excluded, and any creditable contemporaneous increases and decreases that

were considered in the determination.

The Permittee shall maintain records of this documentation. 10.0

CD Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 4 & 5 The Permittee shall monitor the actual emissions of any regulated NSR pollutant that could increase as a result of the project and that were analyzed using the

A TPA test, and the potential emissions of any regulated NSR pollutant that could increase as a result of the project and that were analyzed using potential emissions in the hybrid test. The Permittee shall calculate and maintain a record of the sum of the actual and potential (if the hybrid test was used in the analysis) emissions of the regulated pollutant, in tons per year on a calendar year basis, for a period of 5 years following resumption of regular operations after the change, or for a period of 10 years following resumption of regular operations after the change if the project increases the design capacity of or potential to emit of any unit associated with the project. 11.0

CD Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 4 & 5 The Permittee must submit a report to the Agency if the annual summed (actual, plus potential if used in hybrid test) emissions differ from the preconstruction projection and exceed the baseline actual emissions by a significant amount as listed at 40 CFR Section 52.21(b)(23). Such report shall be submitted to the

A gency within 60 days after the end of the year in which the exceedances occur. The report shall contain:

a. The name and ID number of the facility, and the name and telephone number of the facility contact person b. The annual emissions (actual, plus potential if any part of the project was analyzed using the hybrid test) for each pollutant for which the preconstruction projection and significant emissions increase are exceeded. c. Any other information, such as an explanation as to why the summed emissions differ from the preconstruction projection. 12.0

CD Title I Condition: 40 CFR Section 52.21(r)(6)(ii); Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 4 & 5 Before beginning actual construction of any project which includes any electric utility steam generating unit (EUSGU), the Permittee shall submit a copy of the preconstruction documentation (items 1-4 under Preconstruction Documentation, above) to the Agency. 13.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 3 of 64

CD Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 4 & 5 For any project which includes any EUSGU, the Permittee must submit an annual report to the Agency, within 60 days after the end of the calendar year. The report

shall contain:

a. The name and ID number of the facility, and the name and telephone number of the facility contact person b. The quantified annual emissions analyzed using the ATPA test, plus the potential emissions associated with the same project analyzed as part of a hybrid

test. c. Any other information, such as an explanation as to why the summed emissions differ from the preconstruction projection, if that is the case. 14.0

CD Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 4 & 5 For any project which does not include any EUSGU, the Permittee must submit a report to the Agency if the annual summed (actual, plus potential used in hybrid test) emissions differ from the preconstruction projection and exceed the baseline actual emissions by a significant amount as listed at 40 CFR Section 52.21(b)(23). Such report shall be submitted to the Agency within 60 days after the end of the year in which the exceedances occur. The report shall contain:

a. The name and ID number of the facility, and the name and telephone number of the facility contact person b. The annual emissions (actual, plus potential if any part of the project was analyzed using the hybrid test) for each pollutant for which the preconstruction projection and significant emissions rate is exceeded. c. Any other information, such as an explanation as to why the summed emissions differ from the preconstruction projection. 15.0

CD hdr OPERATIONAL REQUIREMENTS 16.0

CD 40 CFR pt. 50; Minn. Stat. Section
116.07, subds. 4a & 9; Minn. R. 7007.0100, subps. 7A, 7L & 7M; Minn. R. 7007.0800, subps. 1, 2 &
4; Minn. R. 7009.0010-7009.0080. The Permittee shall comply with National Primary and Secondary Ambient Air Quality Standards, 40 CFR pt. 50, and the Minnesota Ambient Air Quality Standards, Minn. R. 7009.0010 to 7009.0080. Compliance shall be demonstrated upon written request by the MPCA. 17.0

CD Minn. R. 7011.0020 Circumvention: Do not install or use a device or means that conceals or dilutes emissions, which would otherwise violate a federal or state air pollution control rule, without reducing the total amount of pollutant emitted. 18.0

CD Minn. R. 7007.0800, subp. 2; Minn. R. 7007.0800, subp. 16(J) A ir Pollution Control Equipment: Operate all pollution control equipment whenever the corresponding process equipment and emission units are operated, unless

otherwise noted in Table A. 19.0

CD Minn. R. 7007.0800, subp. 14 and Minn. R. 7007.0800, subp. 16(J) Operation and Maintenance Plan: Retain at the stationary source an operation and maintenance plan for all air pollution control equipment. At a minimum, the O & M plan shall identify all air pollution control equipment and control practices and shall include a preventative maintenance program for the equipment and practices, a description of (the minimum but not necessarily the only) corrective actions to be taken to restore the equipment and practices to proper operation to meet applicable permit conditions, a description of the employee training program for proper operation and maintenance of the control equipment and practices, and the records kept to demonstrate plan implementation. 20.0

CD Minn. R. 7019.1000, subp. 4 Operation Changes: In any shutdown, breakdown, or deviation the Permittee shall immediately take all practical steps to modify operations to reduce the emission of any regulated air pollutant. The Commissioner may require feasible and practical modifications in the operation to reduce emissions of air pollutants. No emissions units that have an unreasonable shutdown or breakdown frequency of process or control equipment shall be permitted to operate. 21.0

CD Minn. R. 7011.0150 Fugitive Emissions: Do not cause or permit the handling, use, transporting, or storage of any material in a manner which may allow avoidable amounts of particulate matter to become airborne. Comply with all other requirements listed in

Minn. R. 7011.0150. 22.0

CD Minn. R. 7030.0010 - 7030.0080 Noise: The Permittee shall comply with the noise standards set forth in Minn. R. 7030.0010 to 7030.0080 at all times during the operation of any emission units. This is a state only requirement and is not enforceable by the EPA Administrator or

citizens under the Clean Air Act. 23.0

CD Minn. R. 7007.0800, subp. 9(A) Inspections: The Permittee shall comply with the inspection procedures and requirements as found in Minn. R. 7007.0800, subp. 9(A). 24.0

CD Minn. R. 7007.0800, subp. 16 The Permittee shall comply with the General Conditions listed in Minn. R. 7007.0800, subp. 16. 25.0

CD hdr PERFORMANCE TESTING 26.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 4 of 64

CD Minn. R. ch. 7017 Performance Testing: Conduct all performance tests in accordance with Minn. R. ch. 7017 unless otherwise noted in Tables A, B, and/or C. 27.0

CD Minn. R. 7017.2018; Minn. R. 7017.2030, subps. 1-4, Minn. R. 7017.2035, subps. 1-2 Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Tables A and B of the permit. See Table B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance Tes t Performance Test Plan: due 30 days before each Performance Test Performance Test Pre-test Meeting: due 7 days before each Performance Test Performance Test Report: due 45 days after each Performance Test Performance Test Report - Microfiche Copy: due 105 days after each Performance

Test

The Notification, Test Plan, and Test Report may be submitted in alternative format as allowed by Minn. R. 7017.2018. 28.0

CD Minn. R. 7017.2025 Limits set as a result of a performance test (conducted before or after permit issuance) apply until superseded as specified by Minn. R. 7017.2025 following formal review of a subsequent performance test on the same unit and completion of permit reopening and reissuance. If limits serve to cause more stringent operating conditions, resulting changes to facility operation need to be made immediately. If limits serve to relax current operating conditions, resulting changes to facility operation must not be made prior to issuance of permit amendment with new limit incorporated. 29.0

CD hdr MONITORING REQUIREMENTS 30.0

CD Minn. R. 7007.0800, subp. 4(D) Monitoring Equipment Calibration: Annually calibrate all required monitoring equipment (any requirements applying to continuous emission monitors are listed separately in this permit). 31.0

CD Minn. R. 7007.0800, subp. 4(D) Operation of Monitoring Equipment: Unless otherwise noted in Tables A, B, and/or C, monitoring a process or control equipment connected to that process is not necessary during periods when the process is shutdown, or during checks of the monitoring systems, such as calibration checks and zero and span adjustments. If monitoring records are required, they should reflect any such periods of process shutdown or checks of the monitoring system. 32.0

CD hdr RECORDKEEPING 33.0

CD Minn. R. 7007.0800, subp. 5(C) Recordkeeping: Retain all records at the stationary source for a period of five (5) years from the date of monitoring, sample, measurement, or report. Records which
must be retained at this location include all calibration and maintenance records, all original recordings for continuous monitoring instrumentation, and copies of all reports required by the permit. Records must conform to the requirements listed in Minn. R. 7007.0800, subp. 5(A). 34.0

CD Minn. R. 7007.0800, subp. 5(B) Recordkeeping: Maintain records describing any insignificant modifications (as required by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms (as required by Minn. R. 7007.1350, subp. 2), including records of the emissions resulting from those changes. 35.0

CD Minn. R. 7007.1200, subp. 4 If the Permittee determines that no permit amendment or notification is required prior to making a change, the Permittee must retain records of all calculations required under Minn. R. 7007.1200. These records shall be kept for a period of five years from the date the change was made or until permit reissuance, whichever is longer. The records shall be kept at the stationary source for the current calendar year of operation and may be kept at the stationary source or office of the stationary source for all other years. The records may be maintained in either electronic or paper format. 36.0

CD hdr REPORTING/SUBMITTALS 37.0

CD Minn. Stat. Section 116.07, subd. 4a; Minn. R. 7007.0800, subp. 2 Fugitive Emissions Control Plan: The Permittee shall submit to the Commissioner and implement a fugitive emissions control plan within 60 days of the date of permit issuance. The plan shall identify all fugitive emission sources, primary and contingent control measures, and record keeping. The Permittee shall follow the actions and record keeping specified in the control plan. If the Commissioner determines the Permittee is out of compliance with Minn. R. 7011.0150 or the fugitive emission control plan, then the Permittee may be required to amend the control plan and/or to install and operate particulate matter ambient monitors. 38.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 5 of 64

CD Minn. R. 7019.1000, subp. 3 Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of a planned shutdown of any control equipment or process equipment if the shutdown would cause any increase in the emissions of any regulated air pollutant. If the owner or operator does not have advance knowledge of the shutdown, notification shall be made to the Commissioner as soon as possible after the shutdown. However, notification is not required in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000, subp. 3.

A t the time of notification, the owner or operator shall inform the Commissioner of the cause of the shutdown and the estimated duration. The owner or operator shall notify the Commissioner when the shutdown is over. 39.0

CD Minn. R. 7019.1000, subp. 2 Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdown of more than one hour duration of any control equipment or process equipment if the breakdown causes any increase in the emissions of any regulated air pollutant. The 24-hour time period starts when the breakdown was discovered or reasonably should have been discovered by the owner or operator. However, notification is not required in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000, subp. 2.

A t the time of notification or as soon as possible thereafter, the owner or operator

shall inform the Commissioner of the cause of the breakdown and the estimated duration. The owner or operator shall notify the Commissioner when the

breakdown is over. 40.0

CD Minn. R. 7019.1000, subp. 1 Notification of Deviations Endangering Human Health or the Environment: As soon as possible after discovery, notify the Commissioner or the state duty officer, either orally or by facsimile, of any deviation from permit conditions which could endanger

human health or the environment. 41.0

CD Minn. R. 7019.1000, subp. 1 Notification of Deviations Endangering Human Health or the Environment Report: Within 2 working days of discovery, notify the Commissioner in writing of any deviation from permit conditions which could endanger human health or the environment. Include the following information in this written description: 1. the cause of the deviation; 2. the exact dates of the period of the deviation, if the deviation has been corrected ; 3. whether or not the deviation has been corrected; 4. the anticipated time by which the deviation is expected to be corrected, if not yet
corrected; and 5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of the

deviation. 42.0

S/A Minn. R. 7007.0800, subp. 6(A)(2) Semiannual Deviations Report: due 30 days after end of each calendar half-year following Permit Issuance. The first semiannual report submitted by the Permittee shall cover the calendar half-year in which the permit is issued. The first report of each calendar year covers January 1 - June 30. The second report of each calendar year covers July 1 - December 31. If no deviations have occured, the Permittee shall submit the report stating no deviations. 43.0

S/A 40 CFR Section 75.64; 40 CFR Section 60.7(c); Minn. R. 7017.1110, subps. 1 & 2; MInn. R. 7007.0800, subp. 2 Excess Emissions/Downtime Reports (EER's): due 30 days after end of each calendar quarter following Permit Issuance (Submit Deviations Reporting Form DRF-1 as amended). The EER shall indicate all periods of monitor bypass and all periods of exceedances of the limit including exceedances allowed by an applicable standard, i.e. during startup, shutdown, and malfunctions. 44.0

CD Minn. R. 7007.1150 - 7007.1500; Minn. R. 7007.0400, subp. 3 A pplication for Permit Amendment: If a permit amendment is needed, submit an application in accordance with the requirements of Minn. R. 7007.1150 through Minn. R. 7007.1500. Submittal dates vary, depending on the type of amendment

needed.

Upon adoption of a new or amended federal applicable requirement and if there are more than 3 years remaining in the permit term, the Permittee shall file an application for a permit amendment within 9 months of promulgation of the applicable requirement, pursuant to Minn. R. 7007.0400, subp. 3. 45.0

S/A Minn. R. 7007.0400, subp. 2 A pplication for Permit Reissuance: due 180 days before expiration of Existing

Permit 46.0

CD Minn. R. 7007.1400, subp. 1(H) Extension Requests: The Permittee may apply for an Administrative Amendment to extend a deadline in a permit by no more than 120 days, provided the proposed deadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H). 47.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 6 of 64

S/A Minn. R. 7007.0800, subp. 6(C) Compliance Certification: due 31 days after end of each calendar year following Permit Issuance (for the previous calendar year). To be submitted on a form approved by the Commissioner, both to the Commissioner and to the US EPA regional office in Chicago. This report covers all deviations experienced during the calendar year. 48.0

CD Minn. R. 7019.3000 - 7019.3100 Emission Inventory Report: due on or before April 1 of each calendar year following permit issuance. To be submitted on a form approved by the

Commissioner. 49.0

CD Minn. R. 7002.0005 - 7002.0095 Emission Fees: due 60 days after receipt of an MPCA bill. 50.0

CD 40 CFR pt. 68 The Permittee must submit a Risk Management Plan (RMP) under 40 CFR pt. 68. Each owner or operator of a stationary source, at which a regulated substance is present above a threshold quantity in a process, shall design and implement an accidental release prevention program. An initial RMP must be submitted no later than the latest of the following dates: 1) June 21, 1999; 2) Three years after the date on which a regulated substance is first listed under 40 CFR Section 68.130; or 3) The date on which a regulated substance is first present above a threshold quantity in a process. A full update and resubmission of the RMP is required at least once every five years. The five-year anniversary date is reset whenever the facility fully updates and resubmits the RMP. Submit RMPs to the Risk Management Plan Reporting Center, P.O. Box 1515, Lanham-Seabrook, Maryland 20703-1515. RMP information may be obtained at http://www.epa.gov/swercepp or by calling 1-800-424-9346. 51.0

CD hdr NONROAD ENGINES 52.0

CD 40 CFR Section 1068.30, definition of Nonroad Engine The Permittee shall not have engines that meet Section (1)(iii) under the definition of Nonroad Engine at 40 CFR Section 1068.30 in one location within the stationary source for more than 12 consecutive months. A location is any single site at a building, structure, facility, or installation.

A ny engine, or engines, that replaces an engine at a location and that is intended to perform the same or similar function as the engine it replaced will be included in calculating the consecutive time period. 53.0

CD 40 CFR Section 1068.101(b)(3) For a nonroad engine that is excluded from any requirements of 40 CFR Part 1068 because it is a stationary engine, the Permittee may not move it or install it in any mobile equipment, except as allowed by the provisions of 40 CFR Part 1068. The Permittee may not circumvent or attempt to circumvent the residence-time requirements of section (2)(iii) of the Nonroad Engine definition at 40 CFR Section

1068.30. 54.0

CD 40 CFR Section 1068.30, section (1)(iii) of the definition of Nonroad Engines; Minn. R. 7007.0800, subps. 4 and 5 The Permittee shall conduct an inventory of all engines on-site that meet section (1)(iii) under the definition of Nonroad Engine at 40 CFR Section 1068.30, once each calendar quarter; inventories shall not take place in consecutive months. This applies to nonroad engines that are owned by the Permittee, or rented and operated by the Permittee, or brought onsite and operated by a vendor or contractor. The inventory shall include the following:

1. Date that the nonroad engine is inventoried

2. Identification number

3. Function of the nonroad engine (e.g., compressor, welder)

4. Location of the engine within the stationary source

5. Statement that the nonroad engine has not been located in a single location for
12 consecutive months, and movement between locations has not been for purposes of circumvention of residence time requirements of section (2)(iii) of the Nonroad Engine definition at 40 CFR Section 1068.30. 55.0MINNESOTA POLLUTION CONTROL AGENCY

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Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 7 of 64

CD 40 CFR Section 1068.31(e) A nonroad engine ceases to be a nonroad engine and becomes a new stationary engine if:

1. At any time, it meets the criteria specified in section (2)(iii) under the definition of Nonroad Engine under 40 CFR Section 1068.30. For example, a portable generator engine ceases to be a nonroad engine if it is used or will be used in a single specific location for 12 months or longer. If the Administrator or the Permitting Authority determines that an engine will be or has been used in a single specific location or 12 months or longer, it ceased to be a nonroad engine when it was placed in that location.

OR

2. It is otherwise regulated by a federal New Source Performance Standard promulgated under section 111 of the Clean Air Act (42 U.S.C 7411). 56.0MINNESOTA POLLUTION CONTROL AGENCY

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Subject Item: GP 001 Emergency Engine Generators

Associated Items: EU 024 Emergency Engine Generator EEG-61001

EU 025 Emergency Engine Generator EEG-61002

SV 018 Emergency Engine Generator (EU 024) Stack

SV 019 Emergency Engine Generator (EU 025) Stack

NC/

CA Type Citation Requirement

CD hdr THE FOLLOWING LIMITS APPLY TO THE TWO GENERATORS COMBINED 1.0

LIMIT Title I Condition: To avoid classification as major

modification under 40 CFR

Section 52.21 and Minn. R.

7007.3000 Operating Hours: less than or equal to 816 hours/year using 12-month Rolling Sum (operating hours of EU024 and EU025 combined) 2.0

LIMIT Title I Condition: To avoid classification as major

modification under 40 CFR

Section 52.21 and Minn. R.

7007.3000 Nitrogen Oxides: less than or equal to 35.3 tons/year using 12-month Rolling Sum (NOx emissions from EU024 and EU025 combined) 3.0

CD hdr THE FOLLOWING LIMITS AND REQUIREMENTS APPLY TO EACH

EMERGENCY ENGINE GENERATOR INDIVIDUALLY 4.0

LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20 percent opacity once operating temperatures have

been attained. 5.0

LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input . The potential to emit from each unit is 0.05 lb/MMBtu due to equipment design and allowable fuel. 6.0

LIMIT Minn. R. 7007.0800, subp. 2 Fuel type is limited to distillate fuel oil with a maximum Sulfur Content of Fuel: less than or equal to 0.050 percent by weight 7.0

CD 40 CFR Section 63.6640(f)(2);

Minn. R. 7011.8150 Each engine must be operated according to the following requirements, or the engine will not be considered an emergency engine under 40 CFR Part 63 Subpart ZZZZ, and will be required to meet all Subpart ZZZZ requirements for non-emergency engines.

(i) There is no time limit on engine use in emergency situations.

(ii) The engine may be operated for the purpose of mantenance checks and readiness testing, provided that the tests are recommended by the manufacturer, the vendor, or the insurance company associated with the engine. Required testing of such units should be minimized, but there is no time limit on engine use in emergency situations and for routine testing and maintenance.

(iii) The engine may be operated for an additional 50 hours per year in non-emergency situations. The 50 hours cannot be used for peak shaving or to generate income for a facility to supply power to an electric grid or otherwise supply power as part of a financial arrangement with another entity. 8.0

CD hdr RECORDKEEPING 9.0

CD Minn. R. 7007.0800, subp. 5 Fuel Supplier Certification: The Permittee shall obtain supplier certification that the sulfur content does not exceed 0.050 % by weight. The certification shall be a single certification from the fuel oil supplier guaranteeing a maximum sulfur content in all fuel oil deliveries thereafter. The single certification shall also state that the supplier will notify the Permittee in writing on the date of delivery of fuel oil with a sulfur content exceeding the guaranteed maximum, that the fuel oil sulfur content exceeds the guaranteed maximum value.

The Permittee may instead choose to test the oil in the storage tank following each shipment, according to current ASTM or EPA methods and keep records of lab analyses of sulfur content. 10.0

CD Title I Condition: To avoid classification as major

modification under 40 CFR

Section 52.21 and Minn. R.

7007.3000 Daily Recordkeeping - Operating Hours. For each engine, on each day that the engine is operated, record the number of hours operated. 11.0MINNESOTA POLLUTION CONTROL AGENCY

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CD Minn. R. 7007.0800, subp. 4 and 5 Daily Recordkeeping: Each day that the engine is operated, record the number of operating hours that were non-emergency and were not routine testing and

maintenance. 12.0

CD Minn. R. 7007.0800, subp. 4 and 5 Monthly Recordkeeping -- Operating Hours. By the 20th day of each month, the Permittee shall calculate and record the following:

1) The total Operating Hours for the previous calendar month using the daily

records.

2) The 12 month rolling sum Operating Hours for the previous 12 month period ("OO" in the equation below) by summing the monthly Operating Hours data for the previous 12 months.

3) The total non-emergency, non-routine testing and maintenance hours operated during the previous calendar month.

4) The total non-emergency, non-routine testing and maintenance hours operated during the previous 12 calendar months. 13.0

CD Minn. R. 7007.0800, subp. 4 and 5 Monthly Recordkeeping -- Nitrogen Oxides. By the 20th day of each month, the Permittee shall calculate and record the 12-month rolling sum Nitrogen Oxides using the following equation:

NOX = OO x EF x 16.58 x 0.0005

Where:

NOX = the 12-month rolling sum NOX emissions (tons/year)

OO = the 12-month rolling sum operating hours, calculated as described above (hours/year) .

EF = the most current emission factor published in AP-42 (4.41 lb/MMBtu at the time of permit issuance)

16.58 = engine capacity (MMBtu/hour)

0.0005 = 1 ton/2000 lb 14.0

CD hdr TEMPORARY REPLACEMENT 15.0

CD Title I Condition: To avoid classification as major

modification under 40 CFR

Section 52.21 and Minn. R. 7007.3000; 40 CFR Section 60.4200(e). Minn. R. 7005.0100 subp. 35a; 7007.1200 subp. 3;
7007.1450; 7007.1250 and

7007.0800 Temporary replacement conditions: The Permittee may temporarily replace listed emission units in GP001, provided the following conditions are met:

1) The potential emissions of the replacement unit (assuming all enforceable limits imposed through this permit, and aggregated if more than one engine is simultaneously replaced; see EU028) are less than all of the following: 25 tpy PM, 15 tpy PM < 10 microns, 10 tpy PM < 2.5 microns, 40 tpy VOC, 40 tpy SO2, 40 tpy NOx, 100 tpy CO, 75000 tpy CO2e;

2) The permitee must calculate the allowable potential to emit of each temporary replacement engine assuming operating conditions that are enforceable by this permit. For pollutants not specifically limited by a permit or rule, the permitee may use emission factors generated based on the temporary replacement engine manufacturer's performance tests;

3) The capacity of the replacement unit is less than or equal to the unit it replaces; 16.0MINNESOTA POLLUTION CONTROL AGENCY

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CD Title I Condition: To avoid classification as major

modification under 40 CFR

Section 52.21 and Minn. R. 7007.3000; 40 CFR Section 60.4200(e). Minn. R. 7005.0100 subp. 35a; 7007.1200 subp. 3;
7007.1450; 7007.1250 and

7007.0800 Continued from above:

4) The project can only be the temporary replacement of internal combustion engines for the purpose of providing emergency electrical power at the facility;

5) Emissions and operating hours are tracked and calculated as specified in this permit;

6) The replacement engine may only replace a permanent engine that is temporarily out of service for less than one year;

7) The replacement engine must meet the conditions for temporary replacement units under 40 CFR Section 60.4200(e);

8) Prior to making such a change, the permittee shall apply for and obtain the appropriate permit amendment. The permittee is not required to complete emission calculations described in Minn. R. 7007.1200 subp. 2. A permit will still be needed regardless of the emissions increase if the change will be subject to a new applicable requirement or requires revisions to the limits or monitoring and recordkeeping in this permit. 17.0

CD Title I Condition: To avoid classification as major

modification under 40 CFR

Section 52.21 and Minn. R.

7007.3000 The replacement engine may not be operated at the same time as the permanent unit it is replacing, except for up to 8 hours during start-up and shutdown transition periods. 18.0

CD Title I Condition: To avoid classification as a major

modification under 40 CFR

Section 52.21 and Minn. R.
7007.3000; Minn. R. 7007.0800, subp. 5; Minn. R. 7007.1200, subp. 4 If the replacement engine does not require a permit amendment, the Permittee shall keep the following records on site for each replacement engine not requiring a permit amendment: - Records required by Minn. R. 7007.1200, subp. 4; - The dates the temporary engine was installed, started operation, and was
removed; - Filled form GI05B for each replacement engine with an assigned consecutive
emission unit number; - A unique identification for the unit, such as make, model, and serial number; - Rated capacity and type of engine; - Dates and hours of operation of the engine; - A statement of all periods of operation during which the permanent engine being temporarily replaced is not also operating; and - Calculations of the potential to emit of the engine and emission changes pursuant to Minn. R. 7007.1200 subpart 3. 19.0

CD Minn. R. 7007.0800, subp. 5; Minn. R. 7007.1200, subp. 4 The Permittee shall notify the MPCA if the replacement engine is operated simultaneously with the permanent engine being temporarily replaced, except as allowed by this permit. Make verbal notification within 2 days, and written notification with the semi-annual deviations report. 20.0MINNESOTA POLLUTION CONTROL AGENCY

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 11 of 64

Subject Item: GP 002 Boilers and Associated Control Equipment

Associated Items: CE 006 Electrostatic Prec ipitator - High Efficiency

CE 007 Electrostatic Prec ipitator - High Efficiency

CE 008 Electrostatic Prec ipitator - High Efficiency

CE 009 Electrostatic Prec ipitator - High Efficiency

EU 003 Boiler 3

EU 004 Boiler 4

MR 006 Air Flow Monitor

MR 013 Boilers 3 & 4 SO2 Monitor

MR 014 Boilers 3 & 4 NOx Monitor

MR 015 Boilers 3 & 4 CO2 Monitor

MR 016 Boilers 3 & 4 Opacity Monitor

SV 001 Main Stack for Boilers 3 and 4

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS THAT APPLY TO SV001 (Combined emissions from EU003 and EU004) 1.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 Sulfur Dioxide: less than or equal to 1.3 lbs/million Btu heat input using 1-Hour

A verage . 2.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 Sulfur Dioxide: less than or equal to 3988 lbs/hour using 1-Hour Average . 3.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 PM < 10 micron: less than or equal to 920 lbs/hour using 3-hour Average 4.0

CD hdr EMISSION LIMITS THAT APPLY TO EU003 & EU004 INDIVIDUALLY 5.0

LIMIT Minn. R. 7011.0510, subp. 1 Total Particulate Matter: less than or equal to 0.4 lbs/million Btu heat input using 3-hour Average 6.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 Total Particulate Matter: less than or equal to 0.3 lbs/million Btu heat input using 3-hour Average 7.0

LIMIT Minn. R. 7011.0510, subp. 2 Opacity: less than or equal to 20 percent opacity using 6-minute Average except that a maximum of 60 percent opacity shall be allowable for one six minute period in any 60-minute period. 8.0

LIMIT Minn. R. 7011.0510, subp. 1 Sulfur Dioxide: less than or equal to 3.0 lbs/million Btu heat input using 3-hour

A verage when burning solid fuels. 9.0

LIMIT Minn. R. 7011.0510, subp. 1 Sulfur Dioxide: less than or equal to 1.6 lbs/million Btu heat input using 3-hour

A verage when burning liquid fuel 10.0MINNESOTA POLLUTION CONTROL AGENCY

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CD 40 CFR Section 76.11; Minn. R.

7011.0553 NOx Averaging Plan For Unit 3 (EU003) (2010-2014)

Beginning January 1, 2010 either: Maintain an annual average NOx emission rate of 0.81 lbs/MMBtu and limit the annual heat input to less than or equal to 6,133,000 MMBtu per year.

OR Maintain a Btu-weighted annual average emission rate in lbs/MMBtu, averaged over the units specified in the NOx averaging plan, that is less than or equal to the Btu-weighted annual average emission rate averaged over the same units had they each been operated during the same period of time in compliance with the applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units covered in the plan are:

Plant Boiler ID#

A llen S. King 1 Black Dog 3,4 Sherburne County 1,2,3 11.0

CD 40 CFR Section 76.11; Minn. R.

7011.0553 NOx Averaging Plan For Unit 4 (EU004) (2010-2014)

Beginning January 1, 2010 either: Maintain an annual average NOx emission rate of 0.81 lbs/MMBtu and limit the annual heat input to less than or equal to 12,138,000 MMBtu per year.

OR Maintain a Btu-weighted annual average emission rate in lbs/MMBtu, averaged over the units specified in the NOx averaging plan, that is less than or equal to the Btu-weighted annual average emission rate averaged over the same units had they each been operated during the same period of time in compliance with the applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units covered in the plan are:

Plant Boiler ID#

A llen S. King 1 Black Dog 3,4 Sherburne County 1,2,3 12.0

CD hdr OPERATIONAL REQUIREMENTS 13.0

CD Minn. R. 7007.0800, subp. 2 A llowed fuel types for EU003 and EU004: bituminous coal, subbituminous coal, distillate fuel oil, natural gas, propane, used oil, non-hazardous spill cleanup materials, non-hazardous boiler cleaning agents. 14.0

CD Minn. R. 7007.0800, subp. 2;

Minn. R. ch. 7045 Combust used oil in accordance with used oil regulations in Minn. R. ch. 7045. Limit to 5% of total fuel mass on an hourly basis. 15.0

CD Minn. R. 7007.0800, subp. 2 Combustion of boiler chemical cleaning agents limited to: 8.5 gpm per 100,000 lbs/hr steam flow. Cleaning waste shall be introduced EU003 or EU004 only when the boiler is operating at a minimum of 75 percent of rated capacity. 16.0

CD hdr CONTROL EQUIPMENT REQUIREMENTS (See Subject Item GP003 for specific operating requirements) 17.0

CD Minn. R. 7007.0800, subps. 2 and

14 The Permittee shall operate and maintain each ESP (CE006/CE007 and/or CE008/CE009) at any time that the process equipment controlled by the ESP is in operation, except when the boilers is burning only natural gas. The Permittee shall document periods of non-operation of the control equipment.

EU003 is controlled by CE006 & CE007 (in series) EU004 is controlled by CE008 & CE009 (in series) 18.0

CD hdr MONITORING REQUIREMENTS (see also Subject Item GP008) 19.0

CD 40 CFR Section 75.10(a); Minn. R.

7017.1006 Emissions Monitoring: The owner or operator shall use a NOX CEMS to measure

NOX emissions from SV001.

A dditional monitoring requirements can be found at Subject Item GP004 and in Table B of this permit. 20.0

CD 40 CFR Section 75.10(a); Minn. R.

7017.1006 Emissions Monitoring: The owner or operator shall use a SO2 CEMS to measure

SO2 emissions from SV001.

A dditional monitoring requirements can be found at Subject Item GP004 and in Table B of this permit. 21.0MINNESOTA POLLUTION CONTROL AGENCY

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CD Minn. R. 7017.1006 Emissions Monitoring: The owner or operator shall use a COMS to measure Opacity from SV001.

A dditional monitoring requirements are also located at Subject Item MR016 at in Table B of this permit. 22.0

CD hdr RECORDKEEPING REQUIREMENTS (see also Subject Item GP008) 23.0

CD Minn. R. 7007.0800, subp. 5 Recordkeeping of Boiler Cleaning Agent combustion: the Permittee shall keep records for all cleaning agent combustion including:

- date of combustion

- total quantity (gallons)

- origin of cleaning agent

- cleaning agent feed rate (in gallons per minute (gpm))

- operating capacity of the boiler during cleaning agent combustion (pounds of steam per hour)

- cleaning agent combustion rate (gpm/100000 lb per hour of steam) 24.0

CD Minn. R. 7007.0800, subp. 5 Recordkeeping of Boiler Used Oil combustion: The Permittee shall keep records for all used oil combustion including:

- date of combustion

- total quantity (mass)

- origin of used oil

- used oil feed rate (mass per hour)

- total mass of fuel (including used oil) combusted in the boiler during used oil combustion (mass per hour)

- used oil combustion rate (percent of total fuel mass per hour) 25.0

CD Minn. R. 7007.0800, subp. 5 Beginning with calendar year 2015, or the calendar year in which the Compliance Date for Existing EGU pursuant to 40 CFR part 63, Subpart UUUUU (40 CFR Section 63.9984) falls:

Maintain records of the amount of coal combusted in each boiler (EU003 and EU004) as a percentage of the annual heat input for the calendar year.

Maintain records of the amount of oil combusted in each boiler (EU003 and EU004) as a percentage of the annual heat input for the calendar year. 26.0

CD hdr TESTING REQUIREMENTS 27.0

S/A Minn. R. 7017.2020, subp. 1 Performance Test: due before end of each 60 months starting 09/30/2003 to measure front-half particulate matter emissions. The tests shall be conducted at an

interval not to exceed 60 months between test dates. 28.0

CD Minn. R. 7007.0800, subp. 2. Boiler Alternative Operating Conditions for Performance Testing:

A lternative Operating Conditions during testing are defined as 90% to 100% of the boiler's maximum normal (continuous) operating load or the maximum permitted operating rate, whichever is lower. The basis for this number must be included in the test plan. If testing is conducted at the alternative operating condition established, an operating limit will not be established as a result of performance testing.

In no case will the new operating rate limit be higher than allowed by an existing permit condition. 29.0MINNESOTA POLLUTION CONTROL AGENCY

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CD Minn. R. 7007.0800, subp. 2. Boiler Operating Conditions Not Meeting the Alternative Operating Conditions During Performance Testing:

If performance testing is not conducted at or above the established alternative operating condition, then the boiler operating rate will be limited on an 8-hour block average based on the following:

(1) If the results of the performance test are greater than 90% of any applicable emission limit for which emissions are measured, then boiler operation will be limited to the tested operating rate.

(2) If results are less than or equal to 90% of all applicable emission limits for which emissions are measured, boiler operation will be limited to 110% of the tested operating rate.

In no case will the new operating rate limit be higher than allowed by an existing permit condition. 30.0

CD hdr NESHAP REQUIREMENTS 31.0

CD 40 CFR Section 63.9981 EU003 and EU004 will be subject to NESHAP Subpart UUUUU as of the compliance date of the standard only if they are classified as a coal- or oil-fired

EGU as defined in 40 CFR Section 63.10042:

Coal-fired EGU means an electric utility steam generating unit meeting the definition of fossil fuel-fired that burns coal for more than 10.0 percent of the average annual heat input during any 3 consecutive calendar years or for more than 15.0 percent of the annual heat input during any one calendar year.

Oil-fired EGU means an electric utility steam generating unit meeting the definition of fossil fuel-fired that is not a coal-fired electric utility steam generating unit and that burns oil for more than 10.0 percent of the average annual heat input during any 3 consecutive calendar years or for more than 15.0 percent of the annual heat input during any one calendar year.

Fossil fuel-fired means an EGU that is capable of combusting more than 25 MW of

fossil fuels. 32.0

CD 40 CFR Section 63.9983(b) A ny electric utility steam generating unit that is not a coal- or oil-fired EGU and combusts natural gas for more than 10.0 percent of the average annual heat input during any 3 calendar years or for more than 15.0 percent of the annual heat input during any calendar year is not subject to NESHAP Subpart UUUUU. 33.0

CD 40 CFR Section 63.9984(b) If EU003 or EU004 is in operation and meets the definition of a coal- or oil-fired EGU as of the compliance date listed in 40 CFR Section 63.9984(b), then the boiler must be in compliance with Subpart UUUUU as of that date.

A s of the issuance date of permit action 13700003-011, the compliance date is

A ugust 16, 2015. 34.0

CD Minn. R. 7007.0600; Minn. R. 7007.0800, subp. 2 In the application for permit reissuance, the Permittee indicated that the facility will not include coal-fired or oil-fired EGU on the compliance date listed in 40 CFR Section 63.9984(b). 35.0MINNESOTA POLLUTION CONTROL AGENCY

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Subject Item: GP 003 Electrostatic Precipitator Requirements

Associated Items: CE 006 Electrostatic Prec ipitator - High Efficiency

CE 007 Electrostatic Prec ipitator - High Efficiency

CE 008 Electrostatic Prec ipitator - High Efficiency

CE 009 Electrostatic Prec ipitator - High Efficiency

NC/

CA Type Citation Requirement

LIMIT Minn. R. 7007.0800, subp. 2 The Permittee shall operate and maintain CE006 and CE007 such that they achieve an overall combined control efficiency for Total Particulate Matter: greater than or equal to 99.75 percent control efficiency 1.0

LIMIT Minn. R. 7007.0800, subp. 2 The Permittee shall operate and maintain CE006 and CE007 such that they achieve an overall combined control efficiency for PM < 10 micron: greater than or equal to 99.75 percent control efficiency 2.0

LIMIT Minn. R. 7007.0800, subp. 2 The Permittee shall operate and maintain CE006 and CE007 such that they achieve an overall combined control efficiency for PM < 2.5 micron: greater than or equal to 99.75 percent control efficiency 3.0

CD Minn. R. 7007.0800, subps. 2 and 14; Minn. R. 7017.2025, subp. 3 CE006 and CE007 Minimum Surface Collection Area (SCA): greater than or equal to 125,760 square feet (Unit 3 primary and secondary combined), unless a new minimum SCA is required to be set pursuant to Minn. R. 7017.2025, subp. 3. If a new minimum SCA is required to be set, it will be based on the SCA in service during the most recent MPCA approved performance test where compliance for

Total Particulate Matter emissions was demonstrated.

If the sections in the ESPs are physically and electrically equivalent, the Permittee can meet this requirement by operating the ESP with no less than the number of sections that were operating during the most-recent MPCA approved performance test where compliance for Total Particulate Matter emissions was demonstrated. 4.0

LIMIT Minn. R. 7007.0800, subp. 2 The Permittee shall operate and maintain CE008 and CE009 such that they achieve an overall combined control efficiency for Total Particulate Matter: greater than or equal to 99.75 percent control efficiency 5.0

LIMIT Minn. R. 7007.0800, subp. 2 The Permittee shall operate and maintain CE008 and CE009 such that they achieve an overall combined control efficiency for PM < 10 micron: greater than or equal to 99.75 percent control efficiency 6.0

LIMIT Minn. R. 7007.0800, subp. 2 The Permittee shall operate and maintain CE008 and CE009 such that they achieve an overall combined control efficiency for PM < 2.5 micron: greater than or equal to 99.75 percent control efficiency 7.0

CD Minn. R. 7007.0800, subps. 2 and 14; Minn. R. 7017.2025, subp. 3 CE008 and CE009 Minimum Surface Collection Area (SCA): greater than or equal to 141,144 square feet (Unit 4 primary and secondary combined), unless a new minimum SCA is required to be set pursuant to Minn. R. 7017.2025, subp. 3. If a new minimum SCA is required to be set, it will be based on the SCA in service during the most recent MPCA approved performance test where compliance for

Total Particulate Matter emissions was demonstrated.

If the sections in the ESPs are physically and electrically equivalent, the Permittee can meet this requirement by operating the ESP with no less than the number of sections that were operating during the most-recent MPCA approved performance test where compliance for Total Particulate Matter emissions was demonstrated. 8.0

CD 40 CFR Section 64.7(a); Minn.R.
7017.0200; Minn. R. 7007.0800, subp. 2 ESP Monitoring: The opacity at SV001 as measured by COMS (MR016) shall be used to assess proper operation of the ESPs. 9.0

CD hdr THE FOLLOWING REQUIREMENTS APPLY TO EACH ELECTROSTATIC

PRECIPITATOR INDIVIDUALLY 10.0

CD Minn. R. 7007.0800, subps. 2 and

14 The Permittee shall operate and maintain each ESP (CE006/CE007 and/or CE008/CE009) at any time that the process equipment controlled by the ESP is in operation, except when the boilers is burning only natural gas. The Permittee shall document periods of non-operation of the control equipment.

EU003 is controlled by CE006 & CE007 (in series) EU004 is controlled by CE008 & CE009 (in series) EU019 is controlled by CE006 & CE007 (in series) and CE008 & CE009 (in series) 11.0MINNESOTA POLLUTION CONTROL AGENCY

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CD Minn. R. 7007.0800, subp. 14 Operation and Maintenance of ESP: The Permittee shall operate and maintain the ESP in accordance with the Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and review by MPCA staff. 12.0

CD Minn. R. 7007.0800, subps. 4 and

5 Daily Recordkeeping: Each day that the associated boiler (EU003 or EU004, as applicable) is operating:

- Continuously monitor the ESP sections (or SCA if sections are not equivalent) in

service.

- Record the ESP sections in service, and verify that the minimum SCA is online.

Records shall indicate periods of operation on only natural gas. 13.0

CD 40 CFR Section 64.3(b)(4)(ii);

Minn. R. 7017. 0200 Continuous Monitoring: The Permittee shall continuously, or at a minimum once every 15 minutes, monitor the opacity of the SV001 exhaust.

See Subject Item MR016 and Table B for specific COMS operating requirements. 14.0

LIMIT 40 CFR Section 64.3; Minn. R.

7017.0200 Opacity: less than or equal to 20 percent opacity using 6-minute Average , as measured by COMS in SV001. Opacity in excess of this limit shall be considered an excursion under 40 CFR Section 64.6(c)(2). 15.0

CD 40 CFR Section 64.7(b); Minn. R.

7017.0200 Monitoring Equipment: The necessary monitoring equipment must be installed, in use, and properly maintained, including maintaining the necessary parts for routine repairs of the monitoring equipment, whenever operation of the monitored control equipment is required. 16.0

CD 40 CFR Section 64.3; Minn. R.

7017.0200 Periodic Inspections: At least once per calendar quarter, or more frequently if required by the manufacturer, the Permittee shall inspect the control equipment components that are subject to wear or plugging, for example: bearings, belts, hoses, fans, nozzles, orifices, and ducts. The Permittee shall maintain a written record of the inspection and any corrective actions taken resulting from the inspection. 17.0

CD 40 CFR Section 64.3; Minn. R.

7017.0200 A nnual Inspections: At least once per calendar year, or more frequently if required by the manufacturer, the Permittee shall inspect the control equipment components not covered by the quarterly inspections. This includes, but is not limited to, components that are not subject to wear or plugging including structural components, housings, and hoods. The Permittee shall maintain a written record of the inspection and any corrective actions taken resulting from the inspection. 18.0

CD 40 CFR Section 64.7(d); Minn. R.

7017.0200 Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur: - the monitored opacity exceeds 20% using a 6-minute block average; or - the minimum SCA is not met; or - the ESP or any of its components are found during the inspections to need repair. Corrective actions shall return operation to within the permitted range and/or include completion of necessary repairs identified during the inspection, as applicable. Corrective actions include, but are not limited to, those outlined in the O & M Plan for the ESP. The Permittee shall keep a record of the type and date of any corrective action taken for the ESP. 19.0

CD 40 CFR Section 64.7(e); Minn. R.

7017.0200 Documentation of Need for Improved Monitoring: If the Permittee fails to achieve compliance with an emission limitation or standard for which the monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing opacity which is considered an excursion, the Permittee shall promptly notify the MPCA and, if necessary, submit a permit amendment application to address the necessary monitor changes. 20.0

CD 40 CFR Section 64.9(a)(2); Minn.

R. 7017.0200 A s required by 40 CFR Section 64.9(a)(2), for the Semi-Annual Deviations Report or Deviations Reporting Form (DRF 1) listed in Table B of this permit and/or the Notification of Deviations Endangering Human Health and the Environment listed earlier in Table A of this permit, as applicable, the Permittee shall include the following related to the monitoring identified as required by 40 CFR pt. 64: 1) Summary information on the number, duration, and cause of excursions or exceedances, as applicable, and the corrective action taken; and 2) Summary
information on the number, duration, and cause for monitor downtime incidents. 21.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 17 of 64

CD 40 CFR Section 64.9(b); Minn. R.

7017.0200 The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions taken, and other supporting information required to be maintained. The Permittee may maintain records on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable recordkeeping requirements. 22.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 18 of 64

Subject Item: GP 004 CEMS Required by Acid Rain Regulations

Associated Items: MR 006 Air Flow Monitor

MR 013 Boilers 3 & 4 SO2 Monitor

MR 014 Boilers 3 & 4 NOx Monitor

MR 015 Boilers 3 & 4 CO2 Monitor

NC/

CA Type Citation Requirement

CD hdr A dditional monitoring requirements are located in Table B. 1.0

CD hdr The CEMS requirements listed below outline the typical standards of 40 CFR Pt. 75 when combined with Minn. R. Additional monitoring requirements may also apply to the Facility based on the standard and it is the responsibility of the Facility to meet all applicable requirements. 2.0

CD Minn. R. 7017.1040, subp. 1 Installation Notification: due 60 days before installing the continuous emissions monitoring system. The notification shall include plans and drawings of the system. 3.0

CD 40 CFR Section 75.20; 40 CFR pt. 75, Appendix A, Section 6 CEMS Certification: The owner or operator shall ensure that each CEMS required by this part meets the initial certification requirements of this section and shall ensure that all applicable initial certification tests under paragraph (c) of this section are completed by the deadlines specified in 40 CFR Section 75.4 and prior to use in the Acid Rain Program. In addition, whenever the owner or operator installs a continuous emission or opacity monitoring system in order to meet the requirements of Sections 75.11 through 75.18, where no continuous emission or opacity monitoring system was previously installed, initial certification is required. Certify all CEMS required by the Acid Rain Program in accordance with 40 CFR pt. 75, Appendix A, Section 6. 4.0

CD 40 CFR Section 75.61; Minn. R. 7017.1060, subps. 1-3; Minn. R. 7017.1080, subps. 1-4 CEMS Certification Test Plan: due 30 days before CEMS Certification Test CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test CEMS Certification Test Report: due 45 days after CEMS Certification Test CEMS Certification Test Report Microfiche Copy: due 105 days after CEMS

Certification Test The Notification, Test Plan, and Test Report may be submitted in alternate format as allowed by Minn. R. 7017.1120, subp. 2 5.0

CD 40 CFR Sections 75.20(a)(2), 75.60(b)(1), & 75.63 Certification Application: The owner or operator shall apply for certification of each continuous emission or opacity monitoring system used under the Acid Rain Program. The owner or operator shall submit the certification application in accordance with 40 CFR Section 75.60 and each complete certification application shall include the information specified in Section 75.63. 6.0

CD Minn. R. 7017.1090 Continuous Operation: CEMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. A CEMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment. 7.0

CD 40 CFR Section 75.10(d)(1); Minn. R. 7017.1160, subps. 1 and 2 Monitoring Data: Hourly averages shall be computed using at least one data point in each fifteen minute quadrant of an hour, where the unit combusted fuel during that quadrant of an hour. Not withstanding this requirement, an hourly average may be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant of an hour) if data is unavailable as a result of the performance of calibration, quality assurance, or preventive maintenance activities pursuant to 40 CFR Section 75.21 and appendix B of pt. 75, or backups of data from the data acquisition and handling system, or recertification, pursuant to Section 75.20. The owner or operator shall use all valid measurements or data points collected during an hour to calculate the hourly averages. All data points collected during an hour shall be, to the extent practicable, evenly spaced over the hour. 8.0

CD 40 CFR Section 75.21 CEMS QA/QC: The owner or operator of an affected facility shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75,

A ppendix B as amended. 9.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 19 of 64

CD 40 CFR pt. 75, Appendix B, Section 1; Minn. R. 7017.1210, subp. 1 QA Plan: Develop and implement a written plan that describes in detail (or that refers to separate documents containing) complete, step-by-step procedures and operations of the activities outlined in 40 CFR pt. 75, Appendix B, Section 1.1. Upon request from regulatory authorities, the source shall make all procedures, maintenance records, and ancillary supporting documentation from the manufacturer (e.g., software coefficients and troubleshooting diagrams) available for review during an audit. Electronic storage of the information in the QA/QC plan is permissible, provided that the information can be made available in hardcopy upon request during an audit. 10.0

CD 40 CFR pt. 75, Appendix B,

Section 2.1 Daily Calibration Error (CE) Test: Conduct daily CE testing of each gas monitoring system according to the procedures in Section 6.3.1 of 40 CFR pt. 75, Appendix A and of each flow monitoring system according to the procedures in Section 6.3.2 of 40 CFR pt. 75, Appendix A. 11.0

CD 40 CFR pt. 75, Appendix B, Sections 2.2.1 & 2.2.2; Minn. R.

7017.1020 Linearity and Leak Check Test (Acid Rain Program): due before the end of each QA operating quarter (calendar quarter in which there are at least 168 unit operating hours) following Permit Issuance in accordance with procedures in 40 CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2. Perform a leak check at least once during each QA operating quarter and no less than 30 days apart. 12.0

CD 40 CFR pt. 75, Appendix B, Section 2.3.1; Minn. R. 7017.1020 CEMS Relative Accuracy Test Audit (RATA): Due semianually following Permit Issuance, i.e., once every two successive QA operating quarters (calendar quarter in which there are at least 168 unit operating hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be performed annually (i.e., once every four successive QA operating quarters, rather than once every two successive QA operating quarters) if any of the conditions listed in 40 CFR pt. 75, Appendix B, Sections 2.3.1.2(a) through 2.3.1.2(i) are met. 13.0

CD Minn. R. 7017.1180, subp. 2 RATA Notification: due 30 days before CEMS Relative Accuracy Test Audit (RATA). 14.0

CD Minn. R 7017.1130; 40 CFR

Section 75.57 Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. 15.0

CD 40 CFR Section 75.64; Minn. R. 7017.1110, subps. 1 & 2 Quarterly Reports: Electronically report the data and information in 40 CFR Section 75.64 (a), (b), and (c) to the Administrator quarterly. 16.0MINNESOTA POLLUTION CONTROL AGENCY

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 20 of 64

Subject Item: GP 005 CEMS Required by Acid Rain and NSPS Regulations

Associated Items: MR 017 Unit 5/2 NOx Dual Range Monitor

MR 018 Unit 5/2 O2 Monitor

NC/

CA Type Citation Requirement

CD hdr A dditional monitoring requirements are located in Table B. 1.0

CD hdr The CEMS requirements listed below outline the typical standards of 40 CFR pt. 60 and pt. 75 when combined with Minn. R. Additional monitoring requirements may also apply to the Facility based on this combination of standards and it is the responsibility of the Facility to meet all applicable requirements. 2.0

CD 40 CFR Section 60.13(e); Minn. R. 7017.1090, subp. 1 Continuous Operation: CEMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. A CEMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment. Acceptable monitor downtime includes reasonable periods as listed in Items A, B, C and D of Minn. R. 7017.1090, subp. 2. 3.0

CD Minn. R. 7017.1040, subp. 1 Installation Notification: due 60 days before installing the continuous emissions monitoring system. The notification shall include plans and drawings of the system. 4.0

CD 40 CFR pt. 75.10(d)(1); 40 CFR Section 60.13(e)(2) CEMS Monitor Design: Each CEMS shall be designed to complete a minimum of one cycle of sampling, analyzing, and data recording in each 15-minute period. 5.0

CD 40 CFR Section 60.13(b); Minn. R. 7017.1050, subp. 1 CEMS Certification Test: due 120 days after the first calendar quarter following CEMS Installation. (This requirement is as stringent as that of Minn. R. 7017.1050, subp. 1 requiring testing within 90 days after the due date of the first excess emissions report required for the CEMS.) 6.0

CD 40 CFR Section 75.20; 40 CFR pt. 75, Appendix A, subp. 6 CEMS Certification: The owner or operator shall ensure that each CEMS or COMS required by this part meets the initial certification requirements of this section and shall ensure that all applicable initial certification tests under paragraph (c) of this section are completed by the deadlines specified in 40 CFR Section 75.4 and prior to use in the Acid Rain Program. In addition, whenever the owner or operator installs a continuous emission or opacity monitoring system in order to meet the requirements of Sections 75.11 through 75.18, where no continuous emission or opacity monitoring system was previously installed, initial certification is required. Certify all CEMS required by the Acid Rain Program in accordance with 40 CFR pt. 75, Appendix A, Section 6. (Note 40 CFR Part 60 has a standard regarding this requirement as well) 7.0

CD 40 CFR Section 75.61; 40 CFR Section 60.7(a)(5); Minn. R. 7017.1060, subps. 1-3; Minn. R. 7017.1080, subps. 1-4 CEMS Certification Test Plan: due 30 days before CEMS Certification Test CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test CEMS Certification Test Report: due 45 days after CEMS Certification Test CEMS Certification Test Report - Microfiche Copy: due 105 days after CEMS

Certification Test The Notification, Test Plan, and Test Report may be submitted in alternate format as allowed by Minn. R. 7017.1120, subp. 2 8.0

CD 40 CFR Sections 75.20(a)(2), 75.60(b)(1), & 75.63 Certification Application: The owner or operator shall apply for certification of each continuous emission or opacity monitoring system used under the Acid Rain Program. The owner or operator shall submit the certification application in accordance with 40 CFR Section 75.60 and each complete certification application shall include the information specified in 40 CFR Section 75.63. 9.0

CD 40 CFR pt. 60, Appendix F; 40 CFR Section 60.13(a) CEMS QA/QC: The owner or operator of an affected facility is subject to the performance specifications listed in 40 CFR pt. 60, Appendix B and shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 60, Appendix F as amended and maintain a written QA/QC program available in a form suitable for inspection. (Note 40 CFR Part 75 has a standard regarding this requirement as well) 10.0

CD 40 CFR Section 75.21 CEMS QA/QC: The owner or operator of an affected facility shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75,

A ppendix B as amended. (Note 40 CFR Part 60 has a standard regarding this requirement as well) 11.0MINNESOTA POLLUTION CONTROL AGENCY

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# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 21 of 64

CD 40 CFR Section 75.10(d)(1) 40 CFR Pt. 75 Monitoring Data: Hourly averages shall be computed using at least one data point in each fifteen minute quadrant of an hour, where the unit combusted fuel during that quadrant of an hour. Notwithstanding this requirement, an hourly average may be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant of an hour) if data are unavailable as a result of the performance of calibration, quality assurance, or preventive maintenance activities pursuant to 40 CFR Section 75.21 and pt. 75, Appendix B, or backups of data from the data acquisition and handling system, or recertification, pursuant to Section 75.20. The owner or operator shall use all valid measurements or data points collected during an hour to calculate the hourly averages. All data points collected during an hour shall be, to the extent practicable, evenly spaced over the hour. (Note 40 CFR pt. 60 has a standard regarding this requirement) 12.0

CD 40 CFR Section 60.13(h); Minn. R. 7017.1160, subps. 1 and 2 NSPS Monitoring Data: Reduce all NSPS-required continuous monitoring systems other than COMS data to 1-hour averages, in accordance with 40 CFR Section 60.13(h). (Note 40 CFR pt. 75 has a standard regarding this requirement as well) 13.0

CD 40 CFR pt. 60, Appendix F, Section 4.1; 40 CFR Section 60.13(d)(1); Minn. R. 7017.1170, subp. 3 CEMS Daily Calibration Drift Test: Check the zero (low level value between 0 and 20 percent of span value) and span (50 to 100 percent of span value) calibration drifts at least once daily. The zero and span must, at a minimum, be adjusted whenever the drift exceeds two times the limit specified in 40 CFR pt. 60, Appendix B. 40 CFR pt. 60, Appendix F, Section 4.3.1 shall be used to determine out-of-control periods for CEMS. (Note: 40 CFR pt. 75 has a standard regarding this requirement as well.) 14.0

CD 40 CFR pt. 75, Appendix B,

Section 2.1 Daily Calibration Error (CE) Test: Conduct daily CE testing of each gas monitoring system according to the procedures in Section 6.3.1 of 40 CFR pt. 75, Appendix A and of each flow monitoring system according to the procedures in Section 6.3.2 of

A ppendix A. (Note 40 CFR pt. 60 has a standard regarding this requirement as well.) 15.0

CD 40 CFR pt. 60, Appendix F, Section 5.1.2; Minn. R. 7017.1170, subp. 4 CEMS 40 CFR Pt. 60 Cylinder Gas Audit (CGA): Due before the end of each three out of four calendar quarters following Permit Issuance but no more than three quarters in succession. A CGA is not required during any calendar quarter in which a RATA was performed. 16.0

CD 40 CFR pt. 75, Appendix B, Sections 2.2.1 & 2.2.2; Minn. R.

7017.1020 40 CFR pt. 75 Linearity and Leak Check Test: due before the end of each QA operating quarter (calendar quarter in which there are at least 168 unit operating hours) following Permit Issuance in accordance with procedures in 40 CFR pt. 75,

A ppendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2. Perform a leak check at least once during each QA operating quarter and no less than 30 days
apart. 17.0

CD 40 CFR pt. 60, Appendix F, Section 5.1.1; Minn. R. 7017.1170, subp. 5 40 CFR pt. 60 CEMS Relative Accuracy Test Audit (RATA): due before end of every one of four calendar quarters following Permit Issuance. (Note 40 CFR pt. 75 has a standard regarding this requirement as well.) 18.0

CD 40 CFR pt. 75, Appendix B, Section 2.3.1; Minn. R. 7017.1170, subp. 5 40 CFR pt. 75 CEMS Relative Accuracy Test Audit (RATA): Due before the end of each calendar half-year following Permit Issuance, i.e. once every two successive QA operating quarters (calendar quarters in which there are at least 168 unit operating hours). Conduct a RATA on all CEMS required by the Acid Rain Program in accordance with 40 CFR pt. 75, Appendix B. RATAs may be performed annually, i.e. once every four successive QA operating quarters, rather than once every two successive QA operating quarters if any of the conditions listed in 40 CFR pt. 75,

A ppendix B, Sections 2.3.1.2(a) through 2.3.1.2(i) are met. (Note 40 CFR pt. 60 has a standard regarding this requirement as well.) 19.0

CD Minn. R. 7017.1180, subp. 2 RATA Notification: due 30 days before CEMS Relative Accuracy Test Audit (RATA). 20.0

CD 40 CFR Section 75.57; 40 CFR Section 60.7(f); Minn. R.

7017.1130 Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. (Note: This requirement is the most stringent of all standards cited.) 21.0

CD 40 CFR Section 75.64; Minn. R. 7017.1110, subps. 1 & 2 Quarterly Reports: Electronically report the data and information in 40 CFR Section 75.64 (a), (b), and (c) to the Administrator quarterly. 22.0MINNESOTA POLLUTION CONTROL AGENCY

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 22 of 64

Subject Item: GP 006 Fabric Filter Requirements

Associated Items: CE 016 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 017 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 019 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 020 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 021 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 023 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 024 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 025 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

NC/

CA Type Citation Requirement

CD hdr THE FOLLOWING REQUIREMENTS APPLY TO EACH FABRIC FILTER

INDIVIDUALLY 1.0

CD hdr CONTROL EFFICIENCY REQUIREMENTS 2.0

LIMIT Minn. R. 7007.0800, subp. 2 The Permittee shall operate and maintain the control equipment such that it achieves an overall control efficiency for Total Particulate Matter: greater than or equal to 99 percent control efficiency 3.0

LIMIT Minn. R. 7007.0800, subp. 2 The Permittee shall operate and maintain the control equipment such that it achieves an overall control efficiency for PM < 10 micron: greater than or equal to 93 percent control efficiency 4.0

LIMIT Minn. R. 7007.0800, subp. 2 The Permittee shall operate and maintain the control equipment such that it achieves an overall control efficiency for PM < 2.5 micron: greater than or equal to 54 percent control efficiency 5.0

CD hdr MONITORING AND RECORDKEEPING 6.0

CD Minn. R. 7007.0800, subp. 4 Check for visible emissions (during daylight hours) from each fabric filter stack (SV007 for CE016; SV008 for CE017, SV009 for CE 018; SV005 for CE019; SV006 for CE020; SV004 for CE021; SV003 for CE023/CE024; and SV002 for SV025) once during every calendar week of operation. 7.0

CD Minn. R. 7007.0800, subps. 4 and

5 Recordkeeping of Visible Emissions. The Permittee shall record the time and date of each visible emission inspection, and whether or not any visible emissions were

observed. 8.0

CD Minn. R. 7007.0800, subps. 2 and

14 Solid fuel handling equipment shall not be vented to the atmosphere when emissions are not controlled by a fabric filter. Some emission units controlled by equipment in this group are physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. (See Subject Items EU005, EU007, EU008, EU009, EU010, EU011, EU012, and EU013.) 9.0

CD Minn. R. 7007.0800, subps. 4, 5

and 14 Periodic Inspections: At least once per calendar quarter, or more frequently as required by the manufacturing specifications, the Permittee shall inspect the control equipment components. The Permittee shall maintain a written record of these inspections. 10.0

CD Minn. R. 7007.0800, subps. 4, 5,

and 14 Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur:
- visible emissions are observed; or - the fabric filter or any of its components are found during the inspections to need repair. Corrective actions shall eliminate visible emissions, and/or include completion of necessary repairs identified during the inspection, as applicable. Corrective actions include, but are not limited to, those outlined in the O & M Plan for the fabric filter. The Permittee shall keep a record of the type and date of any corrective action

taken for each filter. 11.0

CD Minn. R. 7007.0800, subp. 14 The Permittee shall operate and maintain each fabric filter in accordance with the Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA staff. 12.0MINNESOTA POLLUTION CONTROL AGENCY

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Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 23 of 64

Subject Item: GP 007 Combustion Turbine/Duct Burner Combined Requirments

Associated Items: CE 032 Selective Catalytic Reduction

CE 033 Dry-Low NOx combustion

EU 026 Combustion Turbine (Dry Low NOx Co mbustors & Selective Catalytic Reduction)

EU 027 Duct Burners (Selective Catalytic Reduction)

MR 017 Unit 5/2 NOx Dual Range Monitor

MR 018 Unit 5/2 O2 Monitor

MR 019 Unit 5/2 CO Dual Range Monitor

SV 020 Combustion Turbine w/DLN & SCR; Duct Burners w/SCR

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS (See also Subject Items EU026 and EU027 for additional applicable requirements) 1.0

LIMIT Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 Nitrogen Oxides: less than or equal to 4.5 parts per million using 3-hour Block

A verage by volume on a dry basis at 15% oxygen. This limit applies at all times under all operating conditions, except during startup, shutdown, and malfunction.

Each calendar day is composed of eight consecutive 3-hour time blocks starting at midnight. Each 3-hour block average is determined by averaging all 1-minute averages during operation other than startup, shutdown, or malfunction, to determine the 15-minute average. The 15-minute averages are averaged to produce a 1-hour average, and the 1-hour averages are used to calculate the 3-hour block average. 2.0

LIMIT Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 Nitrogen Oxides: less than or equal to 100 parts per million using 1-Hour Average by volume on a dry basis at 15% oxygen. This limit applies only during startup, shutdown, and malfunction. If the startup process ends with a failed start, then a NOx ppmvd concentration limit does not apply. However, NOx mass emissions (lb/hr) during a failed start are included in the 12-month rolling sum NOx emissions

calculations. 3.0

LIMIT Title I Condition: To avoid the PSD increment significant impact level under 40 CFR Section 52.21;

Minn. R. 7007.3000 Nitrogen Oxides: less than or equal to 305 tons/year using 12-month Rolling Sum . This limit applies at all times under all operating conditions, including startup, shutdown, and malfunction. 4.0

LIMIT Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 Carbon Monoxide: less than or equal to 25 parts per million by volume on a dry basis at 15% oxygen using a 3-hour block average, during operation of EU 026 (combustion turbine) except during startup, shutdown, or malfunction, and EU 027 is in operation during the same 3-hour time block.

Each calendar day is composed of eight consecutive 3-hour time blocks starting at midnight. Each 3-hour block average is determined by averaging all 1-minute averages during operation other than startup, shutdown, or malfunction, to determine the 15-minute average. The 15-minute averages are averaged to produce a 1-hour average, and the 1-hour averages are used to calculate the 3-hour block average. 5.0

LIMIT Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 Carbon Monoxide: less than or equal to 18 parts per million by volume on a dry basis at 15% oxygen using a 3-hour block average, during operation of EU 026 (combustion turbine) except during startup, shutdown, or malfunction, and EU 027 is not in operation during the same 3-hour time block.

Each calendar day is composed of eight consecutive 3-hour time blocks starting at midnight. Each 3-hour block average is determined by averaging all 1-minute averages during operation other than startup, shutdown, or malfunction, to determine the 15-minute average. The 15-minute averages are averaged to produce a 1-hour average, and the 1-hour averages are used to calculate the 3-hour block average. 6.0

LIMIT Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 Carbon Monoxide: less than or equal to 400 tons/year using 12-month Rolling Sum . This limit applies at all times under all operating conditions, except during startup

and shutdown. 7.0MINNESOTA POLLUTION CONTROL AGENCY

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 24 of 64

LIMIT Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 PM < 10 micron: less than or equal to 29.4 lbs/hour using 3-hour Average . This limit applies at all times under all operating conditions, except during startup, shutdown, or malfunction. 8.0

LIMIT Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 Volatile Organic Compounds: less than or equal to 0.0073 lbs/million Btu heat input when EU026 (combustion turbine) is operating at or above 70% load, with or without EU027 in operation.

When EU027 is operating simultaneously with EU026, the limit is equal to 17.7 lb/hr; the calculated potential to emit of EU026 and EU027 combined is approximately 17.5 lb/hr.

When only EU026 is operating, the limit is equal to 14.0 lb/hr; the calculated potential to emit of EU026 is approximately 4.8 lb/hr. 9.0

LIMIT Title I Condition: To avoid classification as a major source

under 40 CFR Section 63.2 and

Minn. R. 7007.0200 Formaldehyde: less than or equal to 9.0 tons/year using 12-month Rolling Sum . This limit applies at all times under all operating conditions, including startup and

shutdown. 10.0

LIMIT Title I Condition: To avoid classification as a major source

under 40 CFR Section 63.2 and

Minn. R. 7007.0200 HAPs - Total: less than or equal to 24.0 tons/year using 12-month Rolling Sum . This limit applies at all times under all operating conditions, including during startup

and shutdown. 11.0

CD Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 Startup, Shutdown, and Malfunction have the same meanings as in 40 CFR Section 60.2; see Subject Item EU026 for further startup/shutdown definitions for the combustion turbine. For any emission limit not applicable during startup and shutdown, that limit does not apply:

1. during the initial 180 minutes after fuel combustion commences in the combustion turbine if the steam turbine-generator was offline for less than 12 hours; 2. during the initial 300 minutes after fuel combustion commences in the combustion turbine if the steam turbine-generator was offline for 12 to 60 hours; 3. during the initial 480 minutes after fuel combustion commences in the combustion turbine if the steam turbine-generator was offline for more than 60
hours; 4. during the final 120 minutes of turbine fuel combustion.

Steam turbine-generator online operation of less than 60 minutes duration shall be considered offline for startup determination purposes and is not included in items 1,
2, and 3 above. 12.0

CD hdr CONTROL REQUIREMENTS (see also Subject Item CE032) 13.0

CD Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R. 7007.3000; To avoid the PSD increment significant impact level under 40 CFR Section 52.21; Minn. R. 7007.0800, subps. 2 and

14 The Permittee shall operate and maintain CE032 at all times that EU026 and/or EU027 is in operation. The Permittee shall document periods of non-operation of the control equipment. 14.0

CD hdr MONITORING AND RECORDKEEPING REQUIREMENTS (see also Subject Item GP005) 15.0

CD 40 CFR Section 75.10; Minn. R. 7007.0800, subp. 4 Measure or calculate SO2 and CO2 emission rates for EU026 and EU027 in

accordance with 40 CFR Section 75. 16.0

CD Title I Condition: To avoid the PSD increment significant impact level under 40 CFR Section 52.21; Minn. R. 7007.3000; 40 CFR Section 60.334(c); 40 CFR Section 72.9(b); Minn. R.
7017.1006; Minn. R. 7017.1010, subp. 1; Minn. R. 7011.2350;

Minn. R. 7011.0560 Emissions Monitoring: The owner or operator shall use a NOX CEMS to measure NOX emissions from SV020. Additional monitoring requirements are also located at Subject Item GP005. 17.0

CD Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 Emissions Monitoring: The owner or operator shall use a CO CEMS to measure CO emissions from SV020. Additional monitoring requirements are also located at Subject Item GP005. 18.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 25 of 64

CD Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.
7007.3000; Minn. R. 7007.0800, subp. 4 Operating Load and Operating Conditions Monitoring: Continuously monitor (at the same frequency as the CO monitor sampling rate) and record the heat input (mmBtu/hr) for EU026 and EU027 using the method specified at 40 CFR Part 75,

A ppendix F.

Calculate and record the average hourly operating load as a percent of maximum possible load for the specific compressor inlet conditions.

Monitor and record the times and duration of any "off normal" operating condition (startup, shutdown, or malfunction) defined above.

Record the start and stop time of all steam turbine-generator on-line and off-line operation. 19.0

CD Minn. R. 7007.0800, subps. 4 and

5 By the 15th day of each month, calculate and record monthly NOX emissions and the annual 12-month rolling sum. The rolling sum shall be calculated by adding the current month's emission totals with those for the previous 11 months. 20.0

CD Minn. R. 7007.0800, subps. 4 and

5 By the 15th day of each month, calculate and record monthly CO emissions and the annual 12-month rolling sum. The rolling sum shall be calculated by adding the current month's emission totals with those for the previous 11 months. 21.0

CD Minn. R. 7007.0800, subps. 4 and

5 By the 15th day of each month, calculate and record monthly and annual 12 month rolling sum formaldehyde and total HAPs emissions using emission factors from the latest stack test results. Prior to emissions testing, and for HAPs that are not stack tested, emission factors from the latest AP-42 section addressing emissions from combustion turbines and gas fired boilers shall be used.

A fter establishing emission factors for formaldehyde at four load levels, the factor (lbs/mmBtu) established for the gas turbine (EU 026) operating between one of the three test loads shall be used for all gas turbine operation below the next higher test load range (i.e. factor established at 30-40% load shall be used for all loads under 50% of full load). The combined (EU 026 and EU 027) emission factor established at 90-100% of full load shall be used for all operation, combined or not, greater than or equal to 90% of full load. 22.0

CD Minn. R. 7007.0800, subps. 4 and

5 The calculation and record keeping requirement listed above shall not apply to SV 020 if the agency approved performance test for formaldehyde emissions proves that the formaldehyde emission rate is less than or equal to 2.0 lbs/hr at all four test

ranges. 23.0

CD hdr PERFORMANCE TESTING 24.0

S/A Title I Condition: 40 CFR Section

52.21 BACT Limit and Minn. R.
7007.3000; Minn. R. 7017.2020, subp. 1 Performance Test: due before end of each 60 months starting 07/02/2002 to

measure PM10 emissions. 25.0

S/A Title I Condition: 40 CFR Section

52.21 BACT Limit and Minn. R.
7007.3000; Minn. R. 7017.2020, subp. 1 Performance Test: due before end of each 60 months starting 07/02/2002 to

measure VOC emissions. 26.0

CD Title I Condition: To avoid classification as a major source

under 40 CFR Section 63.2 and
Minn. R. 7007.0200; Minn. R. 7007.0800, subp. 4 Formaldehyde Emission Factor/Rate Testing: Emission factors and rates shall be determined by using Agency approved stack test methods at the following loads and operating conditions with the SCR system online:

1. EU 026 operating at 30 to 40 percent of full load. 2. EU 026 operating at 50 to 60 percent of full load. 3. EU 026 operating at 70 to 80 percent of full load. 4. EU 026 and EU 027 combined operating at 90 to 100 percent of full load.

A t the time of issuance of PER011, the formaldehyde emission factors based on the tests completed July 2, 2002 (100%, 70%, and 50% loads) and November 11, 2002, (40% load) are as follows:

100% load: 0.045 lb/hr

70% load: 0.038 lb/hr

50% load: 0.223 lb/hr

40% load: 15.1 lb/hr 27.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 26 of 64

CD Title I Condition: To avoid classification as a major source

under 40 CFR Section 63.2 and
Minn. R. 7007.0200; Minn. R. 7007.0800, subp. 4 Testing Frequency to Update Formaldehyde Emission Factors:

Within 60 days of calculating 12-month rolling sum formaldehyde emissions of greater than 8.9 tons, perform a stack test to redevelop emission factors for formaldehyde emissions over the previously tested load ranges. 28.0

CD hdr RECORDKEEPING 29.0

CD Minn. R. 7007.0800, subp. 5 Recordkeeping: Maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of the facility including malfunction of the air pollution control equipment or any periods during which a continuous monitoring system or monitoring device is inoperative. 30.0

CD Minn. R. 7017.1130 Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. 31.0

CD hdr SUBMITTALS AND REPORTS 32.0

CD Minn. R. 7007.0800, subp. 2; 40 CFR Section 60.7, Section 60.49a and Section 60.334(j) Excess emissions and monitoring system performance reports shall include the information required in 40 CFR Section 60.7(c) and (d), Section 60.49a and Section 60.334(j). MPCA Forms DRF-1 and DRF-2 may be used to meet this requirement. 33.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 27 of 64

Subject Item: GP 008 Acid Rain Affected Sources

Associated Items: EU 003 Boiler 3

EU 004 Boiler 4

EU 026 Combustion Turbine (Dry Low NOx Co mbustors & Selective Catalytic Reduction)

NC/

CA Type Citation Requirement

CD hdr A CID RAIN REQUIREMENTS (see also Appendix E) 1.0

CD 40 CFR Section 72.9(c)(1)(ii); 40 CFR Section 72.9(g)(4) Comply with the applicable Acid Rain emissions limitation for sulfur dioxide. 2.0

CD 40 CFR Section 72.9(c)(1)(i); 40 CFR Section 72.9(g)(4) Hold allowances as of the allowance transfer deadline, in the unit's compliance subaccount, not less than the total annual emissions of sulfur dioxide for the previous calendar year. Allowances shall be held in, deducted from, or transferred among Allowance Tracking System accounts in accordance with the Acid Rain Program. 3.0

CD 40 CFR Section 72.9(e) If a unit has excess emissions, the designated representative shall submit a proposed offset plan in accordance with 40 CFR Section 72.9(e). 4.0

CD 40 CFR Section 72.21; 40 CFR

Section 72.22 Certify Acid Rain Program submittals. Each submission under the Acid Rain Program shall be submitted, signed, and certified by the designated representative or the alternative designated representative for all sources on behalf of which the

submission is made in accordance with 40 CFR Section 72.21. 5.0

CD 40 CFR Section 72.9(f)(1) Keep on site or readily accessible at another site each of the following documents for a period of 5 years from the date the document is created: - The certificate of representation, - All emission monitoring information, - Copies of all reports, compliance certifications, and other submissions or records made under the Acid Rain Program, and - Copies of all documents used to complete an acid rain permit application. 6.0

CD 40 CFR Section 72.30(c) A pply for Acid Rain Program Permit reissuance: The designated representative shall submit a complete Acid Rain permit application for each source with an affected unit at least 6 months prior to the expiration of an existing Acid Rain Permit in accordance with 40 CFR Section 72.30(c). 7.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 28 of 64

Subject Item: SV 006 Breaker Bldg. (EU 009 and EU 010) Stack

Associated Items: EU 009 Transfer Tower

EU 010 Breakers (Crushing)

NC/

CA Type Citation Requirement

CD Minn. R. 7007.0800, subp. 4 Check for visible emissions from the SV 006 control equipment (DC-952/CE 020). This must be done once per calendar week, if EU009 and/or EU010 is operated during that calendar week. This must be done during daylight hours, while EU009 and/or EU010 is operating. 1.0

CD Minn. R. 7007.0800, subp. 5 The Pemittee shall record each the date and time of each visible emission check,

and whether visible emissions were observed. 2.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 29 of 64

Subject Item: EU 005 200 Ton Stacking Hopper

Associated Items: CE 025 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 002 Stacking Hopper (EU 005) Stack

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS 1.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 PM < 10 micron: less than or equal to 0.6 lbs/hour . Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.27 lbs/hour. 2.0

LIMIT Minn. R. 7011.1105 (G) If exhaust gases from any enclosed coal handling facility exceed 20 percent opacity, then the owner or operator of such facility shall select and implement one of the following further controls: (1) install exhaust air system and control exhaust gases so that particulate emissions in such gases do not exceed 0.020 gr/dscf; (2) control exhaust gases using dust suppression methods so that particulate emissions do not exhibit Opacity: greater than or equal to 20 percent opacity 3.0

CD hdr CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) 4.0

CD Minn. R. 7007.0800, subps. 2 and

14 EU005 shall not be vented to the atmosphere when emissions are not controlled by CE025. EU005 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. 5.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 30 of 64

Subject Item: EU 006 Dumper Unloading Bldg

Associated Items: CE 023 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 024 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 003 Dumper Building (EU 006) Stack

NC/

CA Type Citation Requirement

CD hdr EMISSION AND OPERATING LIMITS 1.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 PM < 10 micron: less than or equal to 1.0 lbs/hour . Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.03 lbs/hour. 2.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 Operating Hours: less than or equal to 12.5 hours/day 3.0

LIMIT Minn. R. 7011.1105 (H) Total Particulate Matter: greater than or equal to 0.020 grains/dry standard cubic foot , or Opacity: less than or equal to 20% opacity, from unloading railcars. Railcars must be unloaded within a permanent structure. 4.0

CD Minn. R. 7011.1105 (C) Truck and Hauler Unloading Stations: Control fugitive particulate emissions from the unloading of truck or haulers by dust suppression methods so that emissions from such sources are minimized. Control emissions by unloading reclaimed coal within a partial enclosure and with fabric filters. 5.0

CD Minn. R. 7007.0800, subp. 5 Recordkeeping: Record the train dumping start and stop times during every day of coal throughput operation. 6.0

CD hdr CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) 7.0

CD Minn. R. 7007.0800, subps. 2 and

14 The Permittee shall operate and maintain CE023 and CE024 at all times that EU006 is in operation. 8.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 31 of 64

Subject Item: EU 007 Yard Agglomerator Silo

Associated Items: CE 021 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 004 Yard Agglomerator (EU 007) Stack

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS 1.0

LIMIT 40 CFR Section 60.252(c); Minn.

R. 7011.1150 Opacity: less than 20 percent opacity 2.0

LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.01 grains/dry standard cubic foot 3.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 PM < 10 micron: less than or equal to 0.01 grains/dry standard cubic foot , equivalent to approximately 0.051 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.0004 lbs/hour. 4.0

CD hdr CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) 5.0

CD Minn. R. 7007.0800, subps. 2 and

14 EU007 shall not be vented to the atmosphere when emissions are not controlled by CE021. EU007 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. 6.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 32 of 64

Subject Item: EU 008 Breaker Building (Coal Conveying)

Associated Items: CE 019 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 005 Breaker Bldg. (EU 008) Stack

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS 1.0

LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity 2.0

LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot 3.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 1.7 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.075 lbs/hour. 4.0

CD hdr CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) 5.0

CD Minn. R. 7007.0800, subps. 2 and

14 EU008 shall not be vented to the atmosphere when emissions are not controlled by CE019. EU008 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. 6.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 33 of 64

Subject Item: EU 009 Transfer Tower

Associated Items: CE 020 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 006 Breaker Bldg. (EU 009 and EU 010) Stack

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS 1.0

LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity 2.0

LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot 3.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 0.56 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.03 lbs/hour. 4.0

CD hdr CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) 5.0

CD Minn. R. 7007.0800, subps. 2 and

14 EU009 shall not be vented to the atmosphere when emissions are not controlled by CE020. EU009 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. 6.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 34 of 64

Subject Item: EU 010 Breakers (Crushing)

Associated Items: CE 020 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 006 Breaker Bldg. (EU 009 and EU 010) Stack

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS 1.0

LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity 2.0

LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot 3.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 0.56 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.02 lbs/hour. 4.0

CD hdr CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) 5.0

CD Minn. R. 7007.0800, subps. 2 and

14 The Permittee shall operate and maintain CE020 at all times that EU010 is in operation. The Permittee shall document periods of non-operation of the control equipment.

EU010 shall not be vented to the atmosphere when emissions are not controlled by CE020. EU010 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. 6.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 35 of 64

Subject Item: EU 011 Tripper Area (Conveyors D and F)

Associated Items: CE 016 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 007 Tripper Area (EU 011) Stack

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS 1.0

LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity 2.0

LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot 3.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 1.2 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.05 lbs/hour. 4.0

CD hdr CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) 5.0

CD Minn. R. 7007.0800, subps. 2 and

14 EU011 shall not be vented to the atmosphere when emissions are not controlled by CE016. EU011 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. 6.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 36 of 64

Subject Item: EU 012 Unit 3 Coal Silo

Associated Items: CE 017 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 008 Unit 3 Coal Silos (EU 012)

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS 1.0

LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity 2.0

LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot 3.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 0.54 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.02 lbs/hour. 4.0

CD hdr CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) 5.0

CD Minn. R. 7007.0800, subps. 2 and

14 EU012 shall not be vented to the atmosphere when emissions are not controlled by CE017. EU012 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. 6.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 37 of 64

Subject Item: EU 013 Unit 4 Coal Silo

Associated Items: CE 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 009 Unit 4 Coal Silos (EU 013)

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS 1.0

LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity 2.0

LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot 3.0

LIMIT Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 0.81 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.02 lbs/hour. 4.0

CD hdr CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) 5.0

CD Minn. R. 7007.0800, subps. 2 and

14 EU013 shall not be vented to the atmosphere when emissions are not controlled by CE018. EU013 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. 6.0MINNESOTA POLLUTION CONTROL AGENCY

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# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 38 of 64

Subject Item: EU 019 Units 3 and 4 Fly Ash Silo Vent

Associated Items: CE 006 Electrostatic Prec ipitator - High Efficiency

CE 007 Electrostatic Prec ipitator - High Efficiency

CE 008 Electrostatic Prec ipitator - High Efficiency

CE 009 Electrostatic Prec ipitator - High Efficiency

SV 001 Main Stack for Boilers 3 and 4

NC/

CA Type Citation Requirement

LIMIT Minn. R. 7011.0715, subp. 1(A) Total Particulate Matter: less than or equal to 0.30 grains/dry standard cubic foot of exhaust gas unless required to further reduce emissions to comply with the less stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735. EU019 is controlled by control equipment which has a collection efficiency of 99.7 percent by weight. EU019 is considered to be in compliance with this requirement. 1.0

LIMIT Minn. R. 7011.0715, subp. 1(B) Opacity: less than or equal to 20 percent opacity 2.0MINNESOTA POLLUTION CONTROL AGENCY

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 39 of 64

Subject Item: EU 026 Combustion Turbine (Dry Low NOx Combustors & Selective Catalytic Reduction)

Associated Items: CE 032 Selective Catalytic Reduction

CE 033 Dry-Low NOx combustion

GP 007 Combustion Turbine/Duct Burner Combined Requirments

GP 008 Acid Rain Affected Sources

SV 020 Combustion Turbine w/DLN & SCR; Duct Burners w/SCR

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS 1.0

LIMIT 40 CFR Sections 60.332(a)(1) and 60.334(j)(1)(iii)(A); Minn. R.

7011.2350 Nitrogen Oxides: less than or equal to 110 parts per million using a 4-hour rolling average by volume at 15% O2 on a dry basis and assuming a fuel-bound content of zero. Applies at all times except during startup, shutdown, or malfunction. Startup for purposes of this limit shall not exceed 1 hour. Shutdown for purposes of this

limit shall not exceed 30 minutes. 2.0

LIMIT 40 CFR Section 60.333(a); Minn.

R. 7011.2350 Sulfur Dioxide: less than or equal to 0.15 percent by volume at 15 percent oxygen and on a dry basis. 3.0

CD hdr OPERATIONAL REQUIREMENTS 4.0

CD Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 Startup and Shutdown: Not to exceed 1250 hours per year on a 12-month rolling

sum basis. 5.0

CD Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 EU026 Startup and Shutdown: In addition to the definition in 40 CFR Section 60.2, startup is defined as all EU026 operation at less than 70% capacity (for the specific combustion turbine compressor inlet conditions during operation) prior to initially attaining 70% load. EU026 startup ends no later than 15 minutes after EU026 first attains 70% load after startup commences.

In addition to the definition in 40 CFR Section 60.2, shutdown is defined as all EU026 operation at less than 70% load that is part of the process that terminates EU026 fuel combustion until the next EU026 startup. Shutdown does not include temporary operating loads below 70% for up to 15 consecutive minutes, due to external factors such as changes in compressor inlet conditions.

(continued below) 6.0

CD Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 EU026 Startup and Shutdown (continued from above):

The CEMS data acquisition and handling system monitors EU026 load (using a signal provided by the combustion turbine generator control system) and indicates whether EU026 is operating in normal mode or startup/shutdown mode. The percent load signal is also used by the CEMS to determine whether emissions data is categorized as normal emissions data or startup/shutdown emissions data. 7.0

LIMIT Title I Condition: To avoid classification as a major

modification under 40 CFR

Section 52.21 and Minn. R.

7007.3000 Sulfur Content of Fuel: less than or equal to 0.004 grains/dry standard cubic foot using 12-month Rolling Average 8.0

LIMIT 40 CFR 60.333(b); Minn. R.

7011.2350 Sulfur Content of Fuel: less than or equal to 0.8 percent by weight 9.0

CD Title I Condition: To avoid classification as a major

modification under 40 CFR

Section 52.21 and Minn. R.

7007.3000 Fuel usage is limited to pipeline quality natural gas. 10.0

CD hdr MONITORING, TESTING, RECORDKEEPING AND REPORTING REQUIREMENTS (see also Subject Item GP007) 11.0MINNESOTA POLLUTION CONTROL AGENCY

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 40 of 64

CD 40 CFR Section 60.334(h)(3);

Minn. R. 7011.2350 The Permittee need not monitor the total sulfur content of the gaseous fuel combusted in the turbine, if the gaseous fuel is demonstrated to meet the definition of natural gas in 40 CFR Section 60.331(u). The Permittee shall use one of the following sources of information to make the required demonstration:

(i) The gas quality characteristics in a current, valid purchase contract, tariff sheet or transportation contract for the gaseous fuel, specifying that the maximum total sulfur content of the fuel is 20.0 grains/100 scf or less; or

(ii) Representative fuel sampling data which show that the sulfur content of the gaseous fuel does not exceed 20 grains/100 scf. At a minimum, the amount of fuel sampling data specified in section 2.3.1.4 or 2.3.2.4 of appendix D to 40 CFR part 75 is required. 12.0

CD Minn. R. 7007.0800, subp. 5 Maintain records of the demonstration that the gaseous fuel used meets the definition of natural gas in 40 CFR Section 60.31(u). 13.0

CD Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.
7007.3000; Minn. R. 7007.0800, subps. 4 and 5 Daily Startup and Shutdown Operating Hours Monitoring and Recordkeeping: Once each day the Permittee shall calculate and record EU 026 startup and shutdown operating hours for the previous calendar day.

Startup and shutdown operating hours shall be determined using the electronic data produced by instrumentation that instantaneously measures EU 026 gross electric power output. 14.0

CD Minn. R. 7007.0800, subps. 4 and

5 Monthly Startup and Shutdown Operating Hours Monitoring and Recordkeeping: By the 15th day of each month, the Permittee shall calculate and record the total EU 026 startup and shutdown operating hours for the previous month and for the previous 12-month period. 15.0MINNESOTA POLLUTION CONTROL AGENCY

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 41 of 64

Subject Item: EU 027 Duct Burners (Selective Catalytic Reduction)

Associated Items: CE 032 Selective Catalytic Reduction

GP 007 Combustion Turbine/Duct Burner Combined Requirments

SV 020 Combustion Turbine w/DLN & SCR; Duct Burners w/SCR

NC/

CA Type Citation Requirement

CD hdr EMISSION LIMITS 1.0

LIMIT 40 CFR Section 60.43Da(b)(2); 40 CFR Section 60.43Da(g); 40 CFR Section 60.48Da(a); Minn. R.

7011.0560 Sulfur Dioxide: less than or equal to 0.20 lbs/million Btu heat input using 30-day Rolling Average . This limit applies at all times except during periods of startup, shudown, or malfunction. Potential emissions based on combustion of natural gas at equipment capacity is approximately 0.0006 lb/MMBtu. 2.0

LIMIT 40 CFR Section 60.44Da(d)(1); 40 CFR Section 6.48Da(a); Minn. R.

7011.0560 Nitrogen Oxides: less than or equal to 1.6 lbs/megawatt-hour using 30-day Rolling

A verage (gross energy output). This limit applies at all times except during periods of startup, shudown, or malfunction. 3.0

CD hdr OPERATIONAL REQUIREMENTS 4.0

LIMIT Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 Operating Hours: less than or equal to 1500 hours/year using 12-month Rolling

Sum 5.0

LIMIT Title I Condition: To avoid classification as a major

modification under 40 CFR

Section 52.21 and Minn. R.

7007.3000 Sulfur Content of Fuel: less than or equal to 0.004 grains/dry standard cubic foot using 12-month Rolling Average 6.0

CD Title I Condition: To avoid classification as a major

modification under 40 CFR

Section 52.21 and Minn. R.

7007.3000 Fuel usage is limited to pipeline quality natural gas. 7.0

CD hdr MONITORING, TESTING, RECORDKEEPING AND REPORTING REQUIREMENTS (see also Subject Item GP007) 8.0

CD Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R.

7007.3000 Daily Recordkeeping. On each day of operation, the Permittee shall calculate, record, and maintain the EU027 operating hours. 9.0

CD Minn. R. 7007.0800, subps. 4 and

5 Monthly Recordkeeping -- Hours of operation

By the 15th of the month, the Permittee shall calculate and record the following:

1) The total hours of operation for the previous calendar month using the daily
records; and

3) The 12-month rolling sum of operating hours for the previous 12-month period by summing the monthly operating hours for the previous 12 months. 10.0

CD 40 CFR Section 60.48Da(k)(2)(iv);

Minn. R. 7011.0560 The Permittee shall determine the mass rate (lb/h) of NOX emissions by installing, operating, and maintaining continuous fuel flowmeters following the appropriate measurements procedures specified in appendix D of 40 CFR Part 75. The emission rate (E) of NOX shall be computed using the following equation:

E = (ER x H) / O

Where:

E = Emission rate of NOX from the duct burner, in lb/MWh gross energy output

ER = Average hourly emission rate of NOX exiting the steam generating unit heat input calculated using appropriate F factor as described in Method 19 of appendix

A of 40 CFR Part 60, in lb/MMBtu

H = Average hourly heat input rate of entire combined cycle unit, in MMBtu/h

O = Average hourly gross energy output from entire combined cycle unit, in MW 11.0MINNESOTA POLLUTION CONTROL AGENCY

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ST. PAUL, MN 55155-4194 

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# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 42 of 64

Subject Item: EU 028 Fire Pump

Associated Items: SV 021 Fire Pump

NC/

CA Type Citation Requirement

CD hdr EMISSION AND OPERATING LIMITS 1.0

LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20 percent opacity once operating temperatures have

been attained. 2.0

LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input . The potential to emit from the unit is 0.05 lb/MMBtu due to equipment design and allowable fuel. 3.0

LIMIT Minn. R. 7007.0800, subps. 4 & 5 Sulfur Content of Fuel: less than or equal to 0.050 percent by weight 4.0

CD Minn. R. 7005.0100, subp. 35a Fuel type: Distillate fuel oil only, by design 5.0

CD Minn. R. 7007.0800, subps. 4 & 5 Fuel Supplier Certification: The Permittee shall obtain supplier certification that the sulfur content does not exceed 0.050 % by weight. The certification shall be a single certification from the fuel oil supplier guaranteeing a maximum sulfur content in all fuel oil deliveries thereafter. The single certification shall also state that the supplier will notify the Permittee in writing on the date of delivery of fuel oil with a sulfur content exceeding the guaranteed maximum, that the fuel oil sulfur content exceeds the guaranteed maximum value.

The Permittee may instead choose to test the oil in the storage tank following each shipment, according to current ASTM or EPA methods and keep records of lab analyses of sulfur content. 6.0

CD Minn. R. 7007.0800, subps. 4 & 5 Hours of Operation: The Permittee shall maintain documentation on site that the unit is an emergency generator by design that qualifies under the U.S. EPA memorandum entitled "Calculating Potential to Emit (PTE) for Emergency Generators" dated September 6, 1995, limiting operation to 500 hours per year. 7.0

CD hdr NESHAP SUBPART ZZZZ REQUIREMENTS 8.0

CD 40 CFR Section 63.6595(a)(1);

Minn. R. 7011.8150 The Permittee shall comply with the applicable parts of Subpart ZZZZ by May 3,

2013. 9.0

CD 40 CFR Section 63.6605(b); Minn.

R. 7011.8150 The Permittee shall at all times operate and maintain the engine, including any associated air pollution control equipment or monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require any further efforts to reduce emissions if levels required by Subpart ZZZZ have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the

source. 10.0

CD 40 CFR Section 63.6602; 40 CFR 63 Subpart ZZZZ Table 2C; Minn.

R. 7011.8150 The Permittee shall meet the following requirements:

a. Change oil and filter every 500 hours of operation or annually, whichever comes
first;

b. Inspect air cleaner every 1,000 hours of operation or annually, whichever comes first;

c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace as necessary. 11.0

CD 40 CFR Section 63.6602; 40 CFR Section 63.6625(h); 40 CFR 63 Subpart ZZZZ Table 2C; Minn. R.

7011.8150 During periods of startup, the Permittee shall minimize the engine's time spent at idle and minimize the engine's startup time at startup to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the non-startup emission limits apply. 12.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 43 of 64

CD 40 CFR Section 63.6625(i); 40 CFR 63 Subpart ZZZZ Table 2C;

Minn. R. 7011.8150 The Permittee has the option of utilizing an oil analysis program in order to extend the specified oil change requirement in Table 2C to Subpart ZZZZ. The oil analysis must be performed at the same frequency specified in Table 2C. The analysis program must at a minimum analyze the Total Base Number, viscosity, and percent water content. The condemning numbers for these paramenters are as follows: Total Base Number is less than 30 percent of the Total Base Number of the oil when new; viscosity of the oil has changed by more than 20 percent from the viscosity of the oil when new; or percent water content (by volume) is greater than 0.5. If none of the condemning values are exceeded, the Permittee is not required to change the oil.

(continued below) 13.0

CD 40 CFR Section 63.6625(i); 40 CFR 63 Subpart ZZZZ Table 2C;

Minn. R. 7011.8150 (continued from above)

If any of the condemning limits are exceeded, the Permittee shall change the oil within 2 days of receiving the results of the analysis; if the engine is not in operation when the results are received, the Permittee shall change the oil within 2 days or before commencing operation, whichever is later. The Permittee shall keep records of the parameters that are analyzed as part of the program, the results of the analysis, and the oil changes for the engine. The analysis program must be part of the maintenance plan for the engine. 14.0

CD 40 CFR Section 63.6625(e); Minn.

R. 7011.8150 The Permittee shall operate and maintain the engine and after-treatment control devide (if any) according to the manufacturer's emission-related written instructions or develop a maintenance plan which must provide to the extent practicable for the maintenance and operation of the engine in a manner consist with good air pollution control practice for minimizing emissions. 15.0

CD 40 CFR Section 63.6625(f); Minn.

R. 7011.8150 The Permittee shall install a non-resettable hour meter if one is not already

installed. 16.0

CD 40 CFR Section 63.6640(a); Minn.

R. 7011.8150 The Permittee shall be in continuous compliance with the applicable requirements of Table 2C to Subpart ZZZZ. 17.0

CD 40 CFR Section 63.6640(b); Minn.

R. 7011.8150 The Permittee shall report each instance in which the applicable operating limitation was not met. These instances are deviations from the operating limitations in Subpart ZZZZ. These deviations shall be reported according to the requirements of 40 CFR Section 63.6650. 18.0

CD 40 CFR Section 63.6640(f)(1);

Minn. R. 7011.8150 The Permittee shall operate the emergency engine according to the requirements in items (i) through (iii) below. Any operation other than emergency operation, maintenance and testing, and operation in non-emergency situations for 50 hours per year, as described in items (i) through (iii), is prohibited. If the engines is not operated according to the requirements in items (i) through (iii), the engine will not be considered an emergency engine under this subpart and will need to meet all requirements for non-emergency engines.

(continued below) 19.0

CD 40 CFR Section 63.6640(f)(1);

Minn. R. 7011.8150 (continued from above)

(i) There is no time limit on the use of emergency stationary RICE in emergency

situations.

(ii) The Permitee may operate the emergency engine for the purpose of maintenance checks and readiness testing, provided that the tests are recommended by Federal, State or local government, the manufacturer, the vendor, or the insurance company associated with the engine. Maintenance checks and readiness testing of such units is limited to 100 hours per year. The Permittee may petition the Administrator for approval of additional hours to be used for maintenance checks and readiness testing, but a petition is not required if the owner or operator maintains records indicating that Federal, State, or local standards require maintenance and testing of emergency RICE beyond 100 hours

per year.

(continued below) 20.0MINNESOTA POLLUTION CONTROL AGENCY

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 44 of 64

CD 40 CFR Section 63.6640(f)(1);

Minn. R. 7011.8150 (continued from above)

iii) The Permittee may operate the emergency engine up to 50 hours per year in non-emergency situations, but those 50 hours are counted towards the 100 hours per year provided for maintenance and testing. The 50 hours per year for non-emergency situations cannot be used for peak shaving or to generate income for a facility to supply power to an electric grid or otherwise supply power as part of a financial arrangement with another entity; except that the Permittee may operate the emergency engine for a maximum of 15 hours per year as part of a demand response program if the regional transmission organization or equivalent balancing authority and transmission operator has determined there are emergency conditions that could lead to a potential electrical blackout, such as unusually low frequency, equipment overload, capacity or energy deficiency, or unacceptable voltage level.

(continued below) 21.0

CD 40 CFR Section 63.6640(f)(1);

Minn. R. 7011.8150 (continued from above)

The engine may not be operated for more than 30 minutes prior to the time when the emergency condition is expected to occur, and the engine operation must be terminated immediately after the facility is notified that the emergency condition is no longer imminent. The 15 hours per year of demand response operation are counted as part of the 50 hours of operation per year provided for non-emergency situations. The supply of emergency power to another entity or entities pursuant to financial arrangement is not limited by this paragraph (f)(1)(iii), as long as the power provided by the financial arrangement is limited to emergency power. 22.0

CD 40 CFR Section 63.6655(e); Minn.

R. 7011.8150 The Permittee shall keep records of the maintenance conducted on the stationary RICE in order to demonstrate that the engine and after-treatment control device (if any) was operated and maintained according to the maintenance plan. 23.0

CD Minn. R. 7007.0800, subp. 5 The Permittee shall keep records of all engine operating hours, and record whether the use was emergency operation, maintenance and testing, or non-emergency operation. 24.0

CD 40 CFR Section 63.6660(a)-(c);

Minn. R. 7011.8150 Records shall be in a form suitable and readily available for expeditious review according to 40 CFR Section 63.10(b)(1).

Each record shall be kept for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. Each record shall be accessible in hard copy or electronic form. 25.0

CD 40 CFR Section 63.6665; Minn. R.

7011.8150 The following parts of the General Provisions apply: 63.1, 63.2, 63.3, 63.4, 63.5, 63.6(a), 63.6(c)(1)-(2), 63.6(f)(2)-(3), 63.6(g)(1)-(3), 63.6(i), 63.6(j), 63.7(a)(3), 63.8(a)(1), 63.8(b)(1), 63.9(a), 63.10(a), 63.10(b)(1), 63.10(b)(2)(vi)-(xii), 63.10(b)(2)(xiv), 63.10(b)(3), 63.12, 63.13, 63.14, 63.15. 26.0

CD 40 CFR Section 63.6640(e); Minn.

R. 7011.8150 The Permittee shall report each instance in which the applicable General
Provisions, listed above, were not met. 27.0

CD hdr. TEMPORARY REPLACEMENT 28.0

CD Title I Condition: To avoid classification as major

modification under 40 CFR

Section 52.21 and Minn. R. 7007.3000; 40 CFR Section 60.4200(e). Minn. R. 7005.0100 subp. 35a; 7007.1200 subp. 3;
7007.1450; 7007.1250 and

7007.0800. Temporary replacement conditions: The Permittee may temporarily replace EU028, provided the following conditions

are met: 1) The potential emissions of the replacement unit (assuming all enforceable limits imposed through this permit, and aggregated if more than one engine and/or boiler is simultaneously replaced; see GP001) are less than all of the following: 25 tpy PM, 15 tpy PM < 10 microns, 10 tpy PM < 2.5 microns, 40 tpy VOC, 40 tpy SO2, 40 tpy NOx, 100 tpy CO, 75000 tpy CO2e;

2) The permitee must calculate the allowable potential to emit of each temporary replacement engine assuming operating conditions that are enforceable by this permit. For pollutants not specifically limited by a permit or rule, the permitee may use emission factors generated based on the temporary replacement engine manufacturer's performance tests.

3) The capacity of the replacement unit is less than or equal to the capacity of
EU028; 29.0MINNESOTA POLLUTION CONTROL AGENCY

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Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 45 of 64

CD Title I Condition: To avoid classification as major

modification under 40 CFR

Section 52.21 and Minn. R. 7007.3000; 40 CFR Section 60.4200(e). Minn. R. 7005.0100 subp. 35a; 7007.1200 subp. 3;
7007.1450; 7007.1250 and

7007.0800. Continued from above:

4) The project can only be the temporary replacement of the internal combustion engine for the purpose of providing emergency electrical power at the facility;

5) Emissions and operating hours are tracked and calculated as specified in this permit;

6) The replacement engine may only replace EU028 when EU028 is temporarily out of service for less than one year;

7) The equipment must meet all other requirements for EU028 OR the replacement engine may not be on site for more than 1 year and must meet the conditions for temporary replacement units under 40 CFR Section 60.4200(e); and 30.0

CD Title I Condition: To avoid classification as major

modification under 40 CFR

Section 52.21 and Minn. R. 7007.3000; 40 CFR Section 60.4200(e). Minn. R. 7005.0100 subp. 35a; 7007.1200 subp. 3;
7007.1450; 7007.1250 and

7007.0800. Continued from above:

8) Prior to making such a change, the permittee shall apply for and obtain the appropriate permit amendment as applicable. The permittee is not required to complete emission calculations described in Minn. R. 7007.1200 subp. 2. A permit will still be needed regardless of the emissions increase if the change will be subject to a new applicable requirement or requires revisions to the limits or monitoring and recordkeeping in this permit. 31.0

CD Title I Condition: To avoid classification as major

modification under 40 CFR

Section 52.21 and Minn. R.

7007.3000 The replacement engine may not be operated at the same time as EU028, except for up to 8 hours during start-up and shutdown transition periods. 32.0

CD Title I Condition: To avoid classification as a major

modification under 40 CFR

Section 52.21 and Minn. R.
7007.3000; Minn. R. 7007.0800, subp. 5; Minn. R. 7007.1200, subp. 4 If the replacement engine does not require a permit amendment, the Permittee shall keep the following records on site for each replacement engine: - Records required by Minn. R. 7007.1200, subp. 4; - The dates the temporary engine was installed, started operation, and was
removed; - Filled form GI05B for each replacement engine with an assigned consecutive
emission unit number; - A unique identification for the unit, such as make, model, and serial number; - Rated capacity and type of engine; - Dates and hours of operation of the engine; - A statement of all periods of operation during which EU028 is not also operating;

and - Calculations of the potential to emit of the engine and emission changes pursuant to Minn. R. 7007.1200 subpart 3. 33.0

CD Minn. R. 7007.0800, subp. 5; Minn. R. 7007.1200, subp. 4 The Permittee shall notify the MPCA if the replacement engine is operated simultaneously with EU028, except as allowed by this permit. Make verbal notification within 2 days, and written notification with the semi-annual deviations
report. 34.0MINNESOTA POLLUTION CONTROL AGENCY

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# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 46 of 64

Subject Item: CE 032 Selective Catalytic Reduction

Associated Items: EU 026 Combustion Turbine (Dry Low NOx Co mbustors & Selective Catalytic Reduction)

EU 027 Duct Burners (Selective Catalytic Reduction)

GP 007 Combustion Turbine/Duct Burner Combined Requirments

NC/

CA Type Citation Requirement

CD hdr A . OPERATING REQUIREMENTS 1.0

CD Title I Condition: 40 CFR Section 52.21(j) (BACT); Minn. R.
7007.3000; Minn. R. 7007.0800, subps. 2 and 14 Operate and maintain CE032 at all times that EU026 and EU027 are in operation except during times of start-up, shutdown, or malfunction (as defined in EU026 and EU027).

A t all times, the Permittee shall maintain documentation of the operation of CE032, and have it available for review at the stationary source. 2.0

CD 40 CFR Section 64.7(b); Minn. R.
7017.0200; Minn. R. 7007.0800, subp. 14 The Permittee shall operate and maintain the SCR in accordance with the Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA staff. 3.0

CD 40 CFR Section 64.7(a); Minn.R.
7017.0200; Minn. R. 7007.0800, subp. 2 SCR Monitoring: The total NOx as NO2 CEMS (MR017) shall be used to assess proper operation of the SCR 4.0

LIMIT 40 CFR Section 64.3; Minn. R.

7017.0200 Nitrogen Oxides: less than or equal to 4.5 parts per billion on an instantaneous

basis. NOX emissions in excess of this threshold shall be considered an excursion under 40 CFR Section 64.6(c)(2), for purposes of the NOX limits under EU026, EU027, and SV020. This applies for all types and qualities of fuel burned. 5.0

CD 40 CFR Section and 64.7(b);
Minn. R. 7017.0200; Minn. R. 7007.0800, subp. 4 Monitoring Equipment: The Permittee shall install and maintain the necessary monitoring equipment for measuring and recording ammonia injection rate as required by this permit. The monitoring equipment must be installed, in use, and properly maintained when the SCR is in operation. 6.0

CD hdr B. MONITORING AND RECORDKEEPING REQUIREMENTS 7.0

CD CFR Section 64.3(b)(4)(ii); Minn.

R. 7017.0200 Continuous Monitoring: The permitee shall monitor continuously, or at a minimum once every 15 minutes, monitor the total NOx as NO2 emissions in the exhaust.

See Subject Item GP005 and Table B for specific CEMs operating requirements. 8.0

CD 40 CFR Section 64.3; Minn. R.
7017.0200; Minn. R. 7007.0800, subps. 4, 5 & 14 Periodic Inspections: At least semiannually, or more frequently as required by the manufacturing specifications, the Permittee shall inspect the control equipment components. The Permittee shall maintain a written record of these inspections. 9.0

CD 40 CFR Section 64.7(d); Minn. R.
7017.0200; Minn. R. 7007.0800, subps. 4, 5, & 14 Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur:

- The alarm is triggered for instantaneous NOX emissions of 4.5 ppm, outside of startup or shutdown; or - The SCR or any of its components are found during the inspections to need repair.

Corrective actions shall return NOX emissions to within the permitted range, and/or include completion of necessary repairs identified during the inspection, as applicable. Corrective actions include, but are not limited to, those outlined in the O&M Plan for the SCR. The Permittee shall keep a record of the type and date of any corrective action taken for the SCR. 10.0

CD 40 CFR Section 64.7(e); Minn. R.
7017.0200; Minn. R. 7017.0200 Documentation of Need for Improved Monitoring: If the Permittee fails to achieve compliance with an emission limitation or standard for which the monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing ammonia injection rate, the Permittee shall promptly notify the MPCA and, if necessary, submit a permit amendment application to address the necessary monitoring changes. 11.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

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# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 47 of 64

CD 40 CFR Section 64.9(a)(2); Minn.

R. 7017.0200 A s required by 40 CFR Section 64.9(a)(2), for the Semi-Annual Deviations Report listed in Table B of this permit and/or the Notification of Deviations Endangering Human Health and the Environment listed earlier in Table A of this permit, as applicable, the Permittee shall include the following related to the monitoring identified as required by 40 CFR pt. 64: 1) Summary information on the number, duration, and cause of excursions or exceedances, as applicable, and the corrective action taken; and 2) Summary information on the number, duration, and

cause for monitor downtime incidents. 12.0

CD 40 CFR Section 64.9(b); Minn. R.

7017.0200 The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions taken, and other supporting information required to be maintained. The Permittee may maintain records on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable recordkeeping requirements. 13.0MINNESOTA POLLUTION CONTROL AGENCY

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# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 48 of 64

Subject Item: FS 003 Emergency Reclaim Hopper

NC/

CA Type Citation Requirement

LIMIT Minn. R. 7011.1105 (F) Control fugitive particulate emissions by dust suppression methods on such operations so that fugitive particulate emissions are minimized. In the alternative, use an underground bottom feed (plow) of coal to an underground conveyor system provided the exhaust gases from the enclosed spaces do not contain Total Particulate Matter: less than or equal to 0.02 grains/dry standard cubic foot 1.0MINNESOTA POLLUTION CONTROL AGENCY

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# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 49 of 64

Subject Item: FS 004 All Coal Storage Piles (Erosion)

Associated Items: CE 029 Dust Suppression by Water Spray

NC/

CA Type Citation Requirement

LIMIT Minn. R. 7011.1105 (F) Stockpiles, Stockpile Construction, and Reclaiming: (1) Control fugitive particulate emissions by dust suppression methods on such operations so that fugitive particulate emissions are minimized. (2) In the alternative, use an underground bottom feed (plow) of coal to an underground conveyor system provided the exhaust gases from the enclosed spaces do not contain Total Particulate Matter: less than or equal to 0.02 grains/dry standard cubic foot 1.0

CD Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 Coal Pile Area: The total area of all coal piles shall be less than or equal to 14.5

acres. 2.0MINNESOTA POLLUTION CONTROL AGENCY

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# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 50 of 64

Subject Item: FS 013 Ash Hauling Traffic

Associated Items: CE 029 Dust Suppression by Water Spray

NC/

CA Type Citation Requirement

CD Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 Control dust by watering, such that fugitive particulate matter emissions are

minimized. 1.0

CD Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.
R. 7009.0010-7009.0080; Minn. R.
7011.0150; Minn. R. 7007.0800, subp. 2 The Permittee shall minimize or eliminate fugitive emissions from all paved surfaces. If fugitive emissions from paved surfaces are observed, the Permittee shall record the date that fugitive dust was observed, what corrective actions were
taken, when the corrective actions were taken, and whether the corrective actions eliminated the fugitive dust. 2.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

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# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 51 of 64

Subject Item: FS 014 Coal Yard Traffic

Associated Items: CE 029 Dust Suppression by Water Spray

NC/

CA Type Citation Requirement

CD Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn.

R. 7009.0010-7009.0080 Control dust by watering, such that fugitive particulate matter emissions are

minimized. 1.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 52 of 64

Subject Item: FS 015 Coal Conveyors 7,7B,7C

NC/

CA Type Citation Requirement

LIMIT Minn. R. 7011.1105 (G) If exhaust gases from any enclosed coal handling facility exceed 20 percent opacity, either install an exhaust air system and control exhaust gases so that particulate emissions do not exceed 0.020 gr/dscf, or control exhaust gases using dust suppression methods so that particulate emissions do not exhibit Opacity: greater than 20 percent opacity 1.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 53 of 64

Subject Item: FS 016 Coal Conveyor 8

NC/

CA Type Citation Requirement

LIMIT Minn. R. 7011.1105 (G) If exhaust gases from any enclosed coal handling facility exceed 20 percent opacity, either install an exhaust air system and control exhaust gases so that particulate emissions do not exceed 0.020 gr/dscf, or control exhaust gases using dust suppression methods so that particulate emissions do not exhibit Opacity: greater than 20 percent opacity 1.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 54 of 64

Subject Item: FS 017 Dumper Unloading Bldg (fugitives from unloading railcar/scraper)

NC/

CA Type Citation Requirement

LIMIT Minn. R. 7011.1105 (H) Unload railcars only within a permanent building or structure. If exhaust gases from such building or structure exceed 20 percent opacity, then the owner or operator shall either install an exhaust air system and limit particulate emissions to 0.020 gr/dscf or control exhaust gases using dust suppression methods so that particulate emissions do not exhibit Opacity: greater than 20 percent opacity 1.0

CD Minn. R. 7011.1105 (C) Truck and Hauler Unloading Stations: Control fugitive particulate emissions from the unloading of truck or haulers by dust suppression methods so that emissions from such sources are minimized. Control emissions by unloading reclaimed coal within a partial enclosure and with fabric filters. 2.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

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# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 55 of 64

Subject Item: MR 006 Air Flow Monitor

Associated Items: GP 002 Boilers and Associated Control Equipment

GP 004 CEMS Required by Acid Rain Regulations

SV 001 Main Stack for Boilers 3 and 4

NC/

CA Type Citation Requirement

S/A Minn. R. 7017.1180, subp. 3 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which the CEMS RATA was

conducted. 1.0

S/A Minn. R. 7017.1180, subp. 4 Linearity Test Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which a Linearity Test was conducted. 2.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 56 of 64

Subject Item: MR 013 Boilers 3 & 4 SO2 Monitor

Associated Items: CM 009 Boilers 3 & 4 SO2 lb/MM Btu

CM 010 Boilers 3 & 4 SO2 lb/hr

GP 002 Boilers and Associated Control Equipment

GP 004 CEMS Required by Acid Rain Regulations

SV 001 Main Stack for Boilers 3 and 4

NC/

CA Type Citation Requirement

S/A Minn. R. 7017.1180, subp. 3 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which the CEMS RATA was

conducted. 1.0

S/A Minn. R. 7017.1180, subp. 4 Linearity Test Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which a Linearity Test was conducted. 2.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 57 of 64

Subject Item: MR 014 Boilers 3 & 4 NOx Monitor

Associated Items: CM 005 Boilers 3 & 4 NOx lb/MM Btu

GP 002 Boilers and Associated Control Equipment

GP 004 CEMS Required by Acid Rain Regulations

SV 001 Main Stack for Boilers 3 and 4

NC/

CA Type Citation Requirement

S/A Minn. R. 7017.1180, subp. 3 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which the CEMS RATA was

conducted. 1.0

S/A Minn. R. 7017.1180, subp. 4 Linearity Test Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which a Linearity Test was conducted. 2.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 58 of 64

Subject Item: MR 015 Boilers 3 & 4 CO2 Monitor

Associated Items: CM 005 Boilers 3 & 4 NOx lb/MM Btu

CM 009 Boilers 3 & 4 SO2 lb/MM Btu

GP 002 Boilers and Associated Control Equipment

GP 004 CEMS Required by Acid Rain Regulations

SV 001 Main Stack for Boilers 3 and 4

NC/

CA Type Citation Requirement

S/A Minn. R. 7017.1180, subp. 3 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which the CEMS RATA was

conducted. 1.0

S/A Minn. R. 7017.1180, subp. 4 Linearity Test Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which a Linearity Test was conducted. 2.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 59 of 64

Subject Item: MR 016 Boilers 3 & 4 Opacity Monitor

Associated Items: CM 008 Boilers 3 & 4 Opacity

CM 010 Boilers 3 & 4 SO2 lb/hr

GP 002 Boilers and Associated Control Equipment

SV 001 Main Stack for Boilers 3 and 4

NC/

CA Type Citation Requirement

CD hdr A dditional monitoring requirements are located in Table B. 1.0

CD Minn. R. 7017.1006 Emissions Monitoring: The owner or operator shall use a COMS to measure Opacity from SV001. 2.0

CD Minn. R. 7017.1200, subps. 1, 2 &

3 Monitoring Data: All COMS data must be reduced to six-minute averages. A six minute average is valid only if it contains data from at least five minutes within the averaging period. COMS data shall be reduced and calculated as outlined in Minn. R. 7017.1200, subp. 3. 3.0

CD Minn. R. 7017.1040, subp. 1 Installation Notification: due 60 days before COMS installation. The notification shall include plans and drawings of the system. 4.0

CD Minn. R. 7017.1050, subp. 1 COMS Certification Test: due 120 days after the first calendar quarter following COMS Installation. (This requirement is as stringent as that of Minn. R. 7017.1050, subp. 1 requiring testing within 90 days after the due date of the first excess emissions report required for the COMS) 5.0

CD Minn. R. 7017.1060, subps. 1-3; Minn. R. 7017.1080, subps. 1-4 COMS Certification Test Plan: due 30 days before COMS Certification Test COMS Certification Test Pretest Meeting: due 7 days before COMS Certification

Test COMS Certification Test Report: due 45 days after COMS Certification Test COMS Certification Test Report - Microfiche Copy: due 105 days after COMS

Certification Test The Notification, Test Plan, and Test Report may be submitted in alternate format as allowed by Minn. R. 7017.1120, subp. 2 6.0

CD Minn. R. 7017.1090, subp. 1 Continuous Operation: COMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. A COMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment.

A cceptable monitor downtime includes reasonable periods as listed in Items A, B, C and D of Minn. R. 7017.1090, subp. 2. 7.0

CD Minn. R. 7017.1210, subp. 1 QA Plan: Develop and implement a written quality assurance plan that covers each COMS. The plan shall be on site and available for inspection within 30 days after monitor certification. The plan shall contain all of the information required by Minn. R. 7017.1210, subp. 1. The plan shall include the manufacturer's spare parts list for each COMS and require that those parts be kept at the facility or readily available from another of the Permittee's facilities, unless the Commissioner gives written approval to exclude specific spare parts from the list. 8.0

CD Minn. R. 7017.1210, subp. 2 COMS Daily Calibration Drift Test: The owner or operator of a COMS shall conduct a daily zero and upscale calibration drift assessment and adjustments according to the requirements of 40 CFR pt. 60.13(d)(2). The zero and upscale calibration levels must be determined by using the span value specified in the applicable requirement. If the applicable requirement does not specify a span value, a span value of 60, 70, or 80 percent opacity must be used unless an alternative span value is approved by the commissioner. 9.0

CD Minn. R. 7017.1210, subp. 3 COMS Calibration Error Audit: due before the end of each calendar half-year following Permit Issuance. Audits are to be at least three months apart but no more than eight months apart except that a calibration error audit need not be conducted during any semiannual period in which the emission unit operated less than 24 hours. The calibration error audit shall be conducted according to the procedures in 40 CFR pt. 60, Appendix B, PS. 1. 10.0

CD Minn. R. 7017.1210, subp. 4 COMS Attenuator Calibration: The Permittee shall semiannually have an independent testing company conduct calibrations of each of the neutral density filters used in the calibration error audit according to the procedure in 40 CFR pt. 60, Appendix B. 11.0MINNESOTA POLLUTION CONTROL AGENCY

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# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 60 of 64

S/A Minn. R. 7017.1220 COMS Calibration Error Audit Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which the COMS calibration error audit was completed. 12.0

CD Minn. R. 7017.1130 Recordkeeping: The owner or operator must retain records of all COMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. 13.0MINNESOTA POLLUTION CONTROL AGENCY

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520 LAFAY ETTE ROAD

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# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 61 of 64

Subject Item: MR 017 Unit 5/2 NOx Dual Range Monitor

Associated Items: CM 011 Unit 5 NOx ppm

GP 005 CEMS Required by Acid Rain and NSPS Regulations

GP 007 Combustion Turbine/Duct Burner Combined Requirments

SV 020 Combustion Turbine w/DLN & SCR; Duct Burners w/SCR

NC/

CA Type Citation Requirement

S/A Minn. R. 7017.1180, subp. 3 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which the CEMS RATA was

conducted. 1.0

S/A Minn. R. 7017.1180, subp. 4 Linearity Test Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which a Linearity Test was conducted. 2.0

S/A Minn. R. 7017.1180, subp.1 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which a CGA was conducted. 3.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 62 of 64

Subject Item: MR 018 Unit 5/2 O2 Monitor

Associated Items: CM 011 Unit 5 NOx ppm

CM 012 Unit 5 CO ppm

GP 005 CEMS Required by Acid Rain and NSPS Regulations

GP 007 Combustion Turbine/Duct Burner Combined Requirments

SV 020 Combustion Turbine w/DLN & SCR; Duct Burners w/SCR

NC/

CA Type Citation Requirement

S/A Minn. R. 7017.1180, subp. 3 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which the CEMS RATA was

conducted. 1.0

S/A Minn. R. 7017.1180, subp. 4 Linearity Test Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which a Linearity Test was conducted. 2.0

S/A Minn. R. 7017.1180, subp.1 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which a CGA was conducted. 3.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

ST. PAUL, MN 55155-4194 

# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 63 of 64

Subject Item: MR 019 Unit 5/2 CO Dual Range Monitor

Associated Items: CM 012 Unit 5 CO ppm

GP 007 Combustion Turbine/Duct Burner Combined Requirments

SV 020 Combustion Turbine w/DLN & SCR; Duct Burners w/SCR

NC/

CA Type Citation Requirement

CD hdr A dditional monitoring requirements are located in Table B. 1.0

CD Minn. R. 7017.1040, subp. 1 Installation Notification: due 60 days before installing the continuous emissions monitoring system. The notification shall include plans and drawings of the system. 2.0

CD Minn. R. 7017.1050, subp. 1 CEMS Certification Test: due 120 days after the first calendar quarter following CEMS Installation. (This requirement is as stringent as that of Minn. R. 7017.1050, subp. 1 requiring testing within 90 days after the due date of the first excess emissions report required for the CEMS or COMS.) 3.0

CD Minn. R. 7017.1060, subps. 1-3; Minn. R. 7017.1080, subps. 1-4 CEMS Certification Test Plan: due 30 days before CEMS Certification Test CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test CEMS Certification Test Report: due 45 days after CEMS Certification Test CEMS Certification Test Report - Microfiche Copy: due 105 days after CEMS

Certification Test The Notification, Test Plan, and Test Report may be submitted in alternate format as allowed by Minn. R. 7017.1120, subp. 2 4.0

CD Minn. R. 7017.1090 Continuous Operation: CEMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. A CEMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment. 5.0

CD Minn. R. 7017.1160, subps. 1 and

2 Monitoring Data: All data points collected by a CEMS shall be used to calculate individual hourly emission averages unless another applicable requirement requires more frequent averaging. In order for an hour of data to be considered, it must contain the following minimum number of data points:

A . four data points, equally spaced, if the emission unit operated during the entire
hour; B. two data points, at least 15 minutes apart, during periods of monitor calibration
or routine maintenance; C. one data point if the emission unit operated for 15 minutes or less during the

hour. 6.0

CD Minn. R. 7017.1170, subp. 2 QA Plan: Develop and implement a written quality assurance plan that covers each CEMS. The plan shall be on site and available for inspection within 30 days after monitor certification. The plan shall contain all of the information required by 40 CFR pt. 60, Appendix F, Section 3. The plan shall include the manufacturer's spare parts list for each CEMS and require that those parts be kept at the facility or readily available from another of the Permittee's facilities, unless the Commissioner gives written approval to exclude specific spare parts from the list. 7.0

CD Minn. R. 7017.1170, subp. 3 Requirement: CEMS Daily Calibration Drift (CD) Test: The CD shall be quantified and recorded at zero (low-level) and upscale (high-level) gas concentrations at least once daily according to the procedures listed in Minn. R. 7017.1170, subp. 3(A) and (B) and 40 CFR Section 60.13(d)(1) for each pollutant concentration, each diluent monitor, and for each monitor range. The CEMS shall be adjusted whenever the CD exceeds twice the specification of 40 CFR pt. 60, Appendix B. If no span value is specified in the applicable requirement or in a compliance document, the Permittee shall use a span value equivalent to 1.5 times the emission limit. 40 CFR pt. 60, Appendix F, shall be used to determine out-of-control periods for CEMS. Follow the procedures in 40 CFR pt. 60, Appendix F. 8.0

CD Minn. R. 7017.1170, subp. 4 Cylinder Gas Audit (CGA): due before end of each calendar half-year following Permit Issuance, except that a CGA is not required during any calendar half year in which a RATA was performed. The initial CGA must be performed within 180 days following certification of the CEMS. The CGAs shall be conducted at least three months apart but no more than eight months apart. A CGA shall be conducted according to the procedures in 40 CFR pt. 60, Appendix F, Section 5.1.2. If the monitored emission unit was operated for less than 24 hours during the calendar half year, a CGA is not required for that calendar half year. 9.0MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAY ETTE ROAD

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# COMPLIANCE PLAN 

# CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011 27 Jan, 2014 15:11 Page 64 of 64

S/A Minn. R. 7017.1180, subp. 1 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which a CGA was conducted. 10.0

CD Minn. R. 7017.1170, subp. 5 CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar year following Permit Issuance. A RATA is not required in any calendar year if a RATA conducted in the previous year demonstrated a relative accuracy value of less than 15 percent or if the associated emissions unit operated less than 48 hours during the calendar year. If the exception is used, the next RATA shall be conducted during the first half of the following calendar year. RATAs shall be conducted at least 3 months apart and according to 40 CFR pt. 60, Appendix F, Section 5.1.1. 11.0

CD Minn. R. 7017.1180, subp. 2 Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS Relative Accuracy Test Audit (RATA). 12.0

S/A Minn. R. 7017.1180, subp. 3 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter following Permit Issuance in which the CEMS RATA was

conducted. 13.0

CD Minn. R. 7017.1130 Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. 14.0

# Attachment 3

CAM Plans

# Compliance Assurance Monitoring (CAM) Plan

Background

Emissions Unit

Description:

AQ Facility ID#:
Facility:

Applicable Emission Unit:

Burners 

# Natural gas-f-uced combined cycle combustion

Turbine and duct burners

03700009 Black Dog Generating Plant Burnsville, MN

EU026 Combustion Turbine & EU027 Duct

CE032 Selective Catalytic Reduction (SCR) CE033 Dry-low NOx Combustion

B. Applicable Regulation, Emission Limit, and Monitoring Requirements

Regulation: Permit; Title I Condition to avoid PSD

increment SIL; Title I BACT Minn. R. 7007.0800, subp. 4



# Emission Limits: Nitrogen Oxides (NOx):

Limit 

# Basis 

# 4.Sppmv 3-hour block average, excluding startup,

shutdown, and maI£unction 100 ppmv l-hour average during starmp,

shutdmvn, and malfunction 305 tons/yr 

# 12-month rolling sum, including all time

periods

Monitoring Requirements: NOx CEMS

C. Control Technology

Dry-low NOx Combustion Selective Catalytic Reduction

# Monitoring Approach Justification

III. Backggound

The PSEU is a nat~ttal gas fired combined-cycle combustion turbine (EU026) and associated natural gas fired duct burners (EU027). The unit is equipped with dr), lo~v NOx combustors (CE033) and a selective catalytic reduction system (SCR)
(CE032).

IV. Rationale for Selecting Performance Indicators



# Direct measurement of NOx concentrations in the flue gas stream is the most direct single indicator of SCR performance.

Per 40 CFR 64.3(d)(2)(iv), a CEMS that satisfies the requirements of 40 CFR Part 75 is deemed to satisfy the general design and performance criteria for CAM.

Per the Technical Guidance Document: Compliance Assurance Monitorin~ MRI Project No. 4701-05, Appendix B, Janua{y 2005, further justification for CEMS use is not required. Also, indicator ranges do not need to be specified for CEMS that provide
data in nnits of the applicable emission standard because the level of the standard is the level at which an excess emission occurs. The use of CEMS that provide results in units of the standard for the pollutant of interest and meet the criteria presented in 40 CFR 64.3(d)(2) is presumptively acceptable CAM. The NO x CEMS measures

NO x as ppmv.

# Compliance Assurance Monitoring (CAM) Plan

I. Background

a. Emissions Unit

Description: Coal-fired electric utility boilers AQ Facility ID#: 03700003 Facility: Black Dog Generating Plant Burnsville, MN Applicable Emission Unit: EU003 Boiler 3

EU004 Boiler 4 CE006 Electrostatic Precipitator – High Eff. CE007 Electrostatic Precipitator – High Eff. CE008 Electrostatic Precipitator – High Eff. CE009 Electrostatic Precipitator – High Eff.

b. Applicable Regulation, Emission Limit, and Monitoring Requirements

Regulation: Permit; NAAQS

Minn. R. 7011.0510 Emission Limits: Total Particulate Matter (PM) Particulate Matter < 10 microns (PM 10



# )

Limit Basis

0.4 lb PM/MMBtu Method 5 test

0.3 lb PM/MMBtu Method 5 test

920 lbs PM 10



# /hr

Monitoring Requirements: COMS

c. Control Technology

Electrostatic PrecipitatorsII.Monitoring ApproachI. Primary IndicatorMeasurement ApproachOpacityOpacity is measured continuously using a continuous opacity monitoring system (COMS)per the requirements of Minn. R. 7017.II. Indicator Range Each unit has an opacity limit ofless than 20 percent, 6-minute average, except that amaximum of 60 percent opacity shall be allowable for one six minute period in any 60-minute period. An excursion is defined as anopacity reading above 20 percent using a sixminute block average. An excursion triggerscorrective action and recordkeeping of thoseactions.III. Performance CriteriaA. Data RepresentativenessOpacity is measured in the common stack serving both coal fired boiler emission units. TheCOMS meets the requirements of Minn. R. 7017.B. Verification of Operational StatusThe COMS was installed and certified following the requirements of PerformanceSpecification 1, found in 40 CFR 60, Appendix B.C. QA/QC Practices and CriteriaThe COMS operates in conjunction with a quality assurance plan according to 40 CFR Part60, and follows all calibration and maintenancerequirements in that part.D. Monitoring FrequencyOpacity is monitored continuously, recorded at ten-second intervals, and reduced to theappropriate averages for reportingData Collection ProceduresData recorded digitally in the COMS DAHSAveraging period 6-minute blockI. Secondary IndicatorMeasurement ApproachSpecific collection area (SCA).The electrical charging of the plateswithin the electrostatic precipitators(ESP) are monitored on a continuous basis. The area of the charged plates indicates thecontrol effectiveness of the overall control system.II. Indicator Range The minimum SCA determined duringthe most recent total particulate matter stack test.III. Performance CriteriaA. Data RepresentativenessThe SCA is a measure of the total area of plate surface available for control of particulatematter. Many of the sections in the ESP are functionally equivalent, and so the number ofsections in service can be recorded in lieu of the SCA for equivalent sections. See tablesbelow for details.B. Verification of Operational StatusThe ESP sections in service are monitored on a continuous basis. Operator alarms aretriggered if any precipitator transformer/rectifier trips occur. The ESP sections in serviceare recorded daily, and the minimum SCA is verified for the operating day.C. QA/QC Practices and CriteriaThe ESPs are operated and maintained according to the provisions in the facility’sOperations and Maintenance (O & M) Plan.D. Monitoring FrequencyDailyData Collection ProceduresThe ESP sections in service are recorded daily on written log sheets and the minimum SCAis verified for the operating day.Averaging period DailyBlack Dog Required ESP MinimumSurface Collection Area (SCA)Results based on 8/13/2008 stack testsUnit 3 Primary Unit 3 Secondary Unit 3Total31Inlet31Center31Outlet32Inlet32Center32OutletTotal 31Inlet33Center35Outlet32Inlet34Center36OutletTotalSCA sq. ft 8,640 8,640 8,640 8,6408,640 8,640 51,840 18,240 18,240 18,240 18,240 18,240 18,240 109,440 161,280In/Out ofserviceIn Out In In Out In InOut In In In InSCA inserviceduring test8,640 0 8,640 8,640 0 8,64034,560 18,240 0 18,240 18,240 18,240 18,240 91,200 125,760Unit 4 Primary Unit 4 Secondary Unit 4Total41-42Inlet41Center41Outlet42Center42OutletTotal 41Inlet43Center45Outlet42Inlet44Center46OutletTotalSCA sq. ft 12,972 6,486 6,486 6,486 6,486 38,916 23,040 23,040 23,040 23,040 23,040 23,040 138,240 177,156In/Out of service In Out In Out In In InIn Out In InSCA in serviceduring test12,972 0 6,486 0 6,486 25,944 23,040 23,040 23,040 023,040 23,040 115,200 141,144I. Tertiary IndicatorMeasurement ApproachPeriodic InspectionsInspection of all control equipment components, including those subject to wear orplugging.II. Indicator Range ESP components must operate as designed, per the facility’s O & M plan.III. Performance CriteriaA. Data RepresentativenessAll components of the pollution control equipment are inspected on an annual basis fordegradation, wear, corrosion, plugging, or other improper operation.B. Verification of Operational StatusRecords are maintained of all inspections and any corrective actions taken as a result of theinspections.C. QA/QC Practices and CriteriaN/AD. Monitoring FrequencyComponents subject to wear or plugging: quarterlyAll other components: annuallyData Collection ProceduresPhysical inspection of control equipment components.Averaging period N/A

# Monitoring Approach Justification

III. Background

The facility has two coal-fired electric utility boilers, EU003 and EU004, which are controlled by four electrostatic precipitators (ESPs), CE006 to CE009. The exhaust from the two boilers vents through a common stack, SV001.

IV. Rationale for Selecting Performance Indicators and Indicator Ranges

The figure below indicates the results of PM stack testing conducted on the unit, consisting of 30 test runs completed between 1998 and 2008. The data is too

scattered to determine the exact relati onship between PM emissions and opacity when plotted directly. However, when each data point is plotted as a fraction of the opacity limit versus the fraction of the PM lim it, it is shown that the unit will exceed the opacity limit well before reaching the PM limit. Based on this, the unit will be emitting at less than 25% of the PM limi t in the event opacity excursions at the proposed level occur.

It is reasonable to monitor the opacity at the stack level as CAM for the separate units. It is highly unlikely that a superbl y performing unit would be able to “make up” for a poorly performing unit to a de gree large enough to see an impact. The most recent stack testing was conducted with both units on line. The test plan included a provision that a single test with both units was acceptable as long as the

measured PM value was less than half of the PM limit. If the measured value exceeded 50 percent of the limit, each unit would be retested individually.

Therefore, the Permittee will use the COMS for the boilers as a surrogate for
PM emissions, in order to meet CAM.Black Dog 3/4 - Opacity/PM Limit Relationship0%10%20%30%40%50%60%70%80%90%100%0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100%% of opacity limit

% of PM limitOpacitylimitedPM limited region

# Attachment 4

Public Comments
(from 1 st 

# comment period)1 

# Volkmeier, Toni (MPCA)

From: Amos, Jonathan M <Jonathan.M.Amos@xcelenergy.com>

Sent: Monday, August 12, 2013 4:02 PM

To: Volkmeier, Toni (MPCA)

Cc: Chelstrom, John K; Rosvold, Richard A
Subject: Comments on Black Dog Permit

Attachments: Public notice permit comments.doc

Toni,

Attached are comments on the draft air permit for the Black Dog plant, currently on public notice. There are several items that require attention before the permit is finalized.

If you have questions on this or wish to di scuss these further, please let me know.

P.S. I am going to be out of the office from 8/13 to 8/20. Please contact Rick Ro svold at 612-330-7879, or Richard.a.rosvold@xcelenergy.com , during my absence.

Thank you,

Jonathan Amos, P.E. Xcel Energy Senior Environmental Analyst 414 Nicollet Mall (MP 4), Minneapolis, MN 55401

P: 612.330.7682 F: 612.330.5905

E: jonathan.m.amos 

# @xcelenergy.com

________________________________________________ 

## XCELENERGY.COM

Please consider the environment before printing this email.

# August 12, 2013

Toni Volkmeier Minnesota Pollution Control Agency 520 Lafayette Road
St. Paul, MN 55155-4194

Dear Toni,

Xcel Energy would like to offer the following comments on the draft air permit No. 03700003-011, for the Black Dog Generating Plant, which was placed on public notice on August 3, 2013.

1. Page A-7, eighth and ninth items. Thes e are emergency generators that are run primarily for maintenance and testi ng. As such, daily recordkeeping for these units is unnecessary and burdensom e. Monthly recordkeeping would be sufficient to ensure compliance with the underlying regulations. The Xcel Energy – Allen S. King Plant (Permit No. 1630005-012) has a pair of engines that are identical in size and purpose to the two engines installed at Black Dog. The King Plant was recently issued a new permit, dated 6/20/2013, that only requires monthly recordkeeping for these engines (page A-9). We maintain that monthly recordkeeping is sufficient to ensure compliance for these engines, and that they should not be treated differently from the engines at the King Plant.

2. Page A-11, fourth item. The facility would like the option of evaporating non-hazardous boiler cleaning agents in either EU003 or EU004. At this time, we are likely to see better destructio n and evaporation performance in EU004. Language should be change to “Cleani ng waste shall be introduced into EU003 or EU004 when the boiler is opera ting at a minimum of 75 percent of rated capacity.” This item was noted as changed in the email response of 7/23/2013, but appears unchanged in the public notice version of the permit.

3. Page A-12, fourth item. We do not understand the purpose of requiring a

PM 10 

# test, and believe it is unnecessary. The only limit for PM 10 

# on this stack is the 920 lb/hr limit using a 3-hour aver age. This limit was established based on dispersion modeling. Th e last test of these units for PM, which only includes the filterable portion of PM, resulted in an emission rate of around 57 lb/hr. These boilers were operating n ear full capacity during the test, and

several ESP sections were shut down to simulate a worst-case scenario for emissions. These units could not ph ysically produce enough condensable particulate matter to approach anywhere near the limit. In addition, we have committed to stop burning coal in thes e units by the MATS compliance date, which is less than two years away. Based on this, PM 10 

# should not be required. This item was noted as re moved in the email response of 7/23/2013, but appears unchanged in the public notice version of the permit.

# 4. Page A-22, ninth item. This item rela tes to the NSPS Subpart Da standard that applies to the duct burners. The facility demonstrates compliance with this regulation using the procedure in 40 CFR 60, Section 48Da(k)(2)(iv), Equation 4. As such, this is an inco rrect citation, and the term should be removed from the permit.

5. Page A-44, item 8. First sentence un der the two bulleted items. Please change this term to read, “Corrective actions shall return the ammonia injection to within normal operating range , ...” There is not a permitted limit for ammonia injection. This item was noted as changed in the email response of 7/23/2013, but appears unchanged in the public notice version of the permit.

If you have any questions on this information, or wish to discuss any of these items, please contact me at 612- 330-7682, or via email at jonathan.m.amos@xcelenergy.com

.

Thank you,

Jonathan Amos, PE Senior Environmental Analyst1 

# Volkmeier, Toni (MPCA)

From: Volkmeier, Toni (MPCA)

Sent: Thursday, September 05, 2013 1:21 PM

To: 'Amos, Jonathan M'
Subject: RE: Comments on Black Dog Permit

Attachments: new table a.pdf; Response to Pu blic notice permit comments.doc



## Jonathan

– Attached is MPCA’s response to your comments, and a revised Table A. Please review these documents. I would like to

discuss all of your concerns (those in the comment letter and any others not yet documented) prior to putting the draft

permit on public notice again.

Thanks.



# Toni Volkmeier
Supervisor, Air Quality Permits Unit 3 Air Quality Permits Section

Industrial Division 651-757-2802 (voice) 651-296-8717 (fax)

toni.volkmeier@state.mn.us

From: Amos, Jonathan M [ mailto:Jonathan.M.Amos@xcelenergy.com ]

Sent: Monday, August 12, 2013 4:02 PM

To: Volkmeier, Toni (MPCA)

Cc: Chelstrom, John K; Rosvold, Richard A Subject: Comments on Black Dog Permit

Toni,

Attached are comments on the draft air permit for the Black Dog plant, currently on public notice. There are several items that require attention before the permit is finalized.

If you have questions on this or wish to di scuss these further, please let me know.

P.S. I am going to be out of the office from 8/13 to 8/20. Please contact Rick Ro svold at 612-330-7879, or Richard.a.rosvold@xcelenergy.com , during my absence.

Thank you,

Jonathan Amos, P.E. Xcel Energy Senior Environmental Analyst 414 Nicollet Mall (MP 4), Minneapolis, MN 55401

P: 612.330.7682 F: 612.330.5905

E: jonathan.m.amos 

# @xcelenergy.com

________________________________________________ 

## XCELENERGY.COM

Please consider the environment before printing this email.

## September 5, 2013 sent by email

Jonathan Amos

Senior Environmental Analyst

Northern States Power Company

414 Nicollet Mall MP4
Minneapolis, MN 55337

Dear Mr. Amos:

Thank you for your comments on Draft Air Emissions Permit No.03700003

‐ 011. Below are your comments, with

MPCA responses.

1. Page A

‐ 7, eighth and ninth items. These are emergency generators that are run primarily for maintenance

and testing. As such, daily recordkeeping for these units is unnecessary and burdensome. Monthly

recordkeeping would be sufficient to ensure compliance with the underlying regulations. The Xcel Energy

– Allen S. King Plant (Permit No. 1630005

‐ 012) has a pair of engines that are identical in size and purpose to

the two engines installed at Black Dog. The King Plant was recently issued a new permit, dated 6/20/2013,

that only requires monthly recordkeeping for these engines (page A

‐ 9). We maintain that monthly

recordkeeping is sufficient to ensure compliance for these engines, and that they should not be treated
differently from the engines at the King Plant.

MPCA Response: No changes will be made to the requirements in question. The requirement is that “on each day

that the engine is operated, record the number of hours operated.” Note that it is not necessary to record hours on days that the engine is not operated. No changes were made to the second requirement (requiring records of

whether the hours were non

‐ routine maintenance or non

‐ emergency on each day that the engine is operated). Some

form of daily recordkeeping is the default requirement when keeping records used to demonstrate compliance with a

limit. It is unfortunate that this was not caught in the other permit you reference. I have made a note in that file that

the error should be corrected the next time the permit is opened for modification or reissuance.

2. Page A

‐ 11, fourth item. The facility would like the option of evaporating non

‐ hazardous boiler cleaning

agents in either EU003 or EU004. At this time, we are likely to see better destruction and evaporation
performance in EU004. Language should be change to “Cleaning waste shall be introduced into EU003 or

EU004 when the boiler is operating at a minimum of 75 percent of rated capacity.” This item was noted as changed in the email response of 7/23/2013, but appears unchanged in the public notice version of the

permit.

MPCA Response: This change has been made. Note that in the email response of 7/23/2013, the only item noted as changed was the one called out in the initial comments (“Allowed fuel types.....”). It appears that not all occurrences

of the error were cited in the initial comments, or sought out by me when responding to the comments.

3. Page A

‐ 12, fourth item. We do not understand the purpose of requiring a PM 10 

## test, and believe it is

unnecessary. The only limit for PM 10 

## on this stack is the 920 lb/hr limit using a 3

‐ hour average. This limit was

established based on dispersion modeling. The last test of these units for PM, which only includes the

filterable portion of PM, resulted in an emission rate of around 57 lb/hr. These boilers were operating near

full capacity during the test, and several ESP sections were shut down to simulate a worst

‐ case scenario for

emissions. These units could not physically produce enough condensable particulate matter to approach

anywhere near the limit. In addition, we have committed to stop burning coal in these units by the MATS
compliance date, which is less than two years away. Based on this, PM 10 

## should not be required. This item

was noted as removed in the email response of 7/23/2013, but appears unchanged in the public notice

version of the permit.

MPCA Response: This test was supposed to be removed and was not. It is now removed.

## 4. Page A

‐ 22, ninth item. This item relates to the NSPS Subpart Da standard that applies to the duct burners.

The facility demonstrates compliance with this regulation using the procedure in 40 CFR 60, Section
48Da(k)(2)(iv), Equation 4. As such, this is an incorrect citation, and the term should be removed from the

permit.

MPCA Response: The term was removed from the permit. The following term was added to the requirements under

Subject Item EU027:

The Permittee shall determine the mass rate (lb/h) of NO X 

## emissions by installing, operating, and maintaining continuous fuel

flowmeters following the appropriate measurements procedures
specified in appendix D of 40 CFR Part 75. The emission rate (E) of

NO X 

## shall be computed using the following equation:

E = (ER x H) / O

Where:

E = Emission rate of NO X 

## from the duct burner, lb/MWh gross

energy output;

ER = Average hourly emission rate of NO X 

## exiting the steam
generating unit heat input calculated using appropriate

F factor as described in Method 19 of appendix A of this

of 40 CFR Part 60, lb/MMBtu;

H = Average hourly heat input rate of entire combined cycle unit,
MMBtu/h; and

O = Average hourly gross energy output from entire combined

cycle unit, MW 40 CFR Section
60.48Da(k)(2)(iv); Minn. R.

7011.0560

5. Page A

‐ 44, item 8. First sentence under the two bulleted items. Please change this term to read, “Corrective

actions shall return the ammonia injection to within normal operating range, ...” There is not a permitted

limit for ammonia injection. This item was noted as changed in the email response of 7/23/2013, but

appears unchanged in the public notice version of the permit.

MPCA Response: Corrective actions are to return monitoring parameters (in this case CAM required indicators) to

the ranges as indicated in the permit and/or CAM plan. Ammonia injection rate is not an indicator per the submitted

CAM plan, and an operating range is not cited in the permit. As such, the reference to ammonia injection was

removed (this was the change that was made prior to public notice of the permit). The most correct form of this

requirement would be to say “Corrective actions shall return the NOX emissions to within the permitted range, and/or....”and not to discuss the ammonia injection rate, unless you wish to add an ammonia injection rate/range to

the permit.

If you have any questions on this information, or wish to discuss any of these items, please contact me at 651

‐ 757

‐ 2802, or via email at toni.volkmeier@state.mn.us

.

Thank you,

Toni Volkmeier

Supervisor, Permit Unit 3

Air Quality Permits Section

Industrial Division

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-1

Table A contains limits and other requirements with which your facility must comply. The limits are located in the first colum n of the table (What To do). The limits can be emission limits or operational limits. This column also contains the actions that y ou must take and the records you must keep to show that you are complying with the limits. The second column of Table A (Why to do it) lists the regulatory basis for these limits. Appendices included as conditions of your permit are listed in Table A under tota l facility requirements.

Subject Item: Total Facility

What to do Why to do it

SOURCE-SPECIFIC REQUIREMENTS hdr

Permit Appendices: This permit contains appendices as listed in the permit Table of Contents. The Permittee shall comply with all requirements contained in

A ppendices B, C, and E.

Modeling parameters in Appendix D are included for reference only as described

elsewhere in Table A. Minn. R. 7007.0800, subp. 2

The parameters used in PM10 modeling dated April 28, 1998, and NOX modeling dated March 2002 are listed in Appendix D of this permit. The parameters describe the operation of the facility at maximum permitted capacity.

For any changes that affect any modeled parameter or emission rate documented in Appendix D, or are an addition to information documented in Appendix D, a Remodeling Submittal requirement is triggered. This includes changes that do not require a permit amendment as well as changes that require any type of permit

amendment. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

Remodeling Submittal: The Permittee must submit to the MPCA for approval any revisions of the parameters documented in Appendix D and must wait for a written approval before making such changes (see page 1 of Table B of this permit for MPCA mailing information). For changes that don't require a moderate or major amendment, written approval of the modeling may be given before permit issuance; however, the approval applies only to the modeling and not to any other changes. The information submitted must include, for stack and vent sources, source emission rate, location, height, diameters, exit velocity, exit temperature, discharge direction, use of rain caps or rain hats, and, if applicable, locations and dimensions of nearby buildings. For non-stack/vent sources, this includes the source emission rate, location, size and shape, release height, and, if applicable, any emission rate
scalars, and the initial lateral dimensions and initial vertical dimensions and adjacent building heights. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

The plume dispersion characteristics due to the revisions of the parameters documented in Appendix D must be equivalent to or better than the dispersion characteristics modeled April 1998 (PM10) or March 2002 (NOX). The Permittee shall demonstrate this equivalency in the proposal. If the information does not demonstrate equivalent or better dispersion characteristics, or if a conclusion cannot readily be made about the dispersion, the Permittee must submit full remodeling. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

Operating practices: Clean up all coal spilled on roads or access areas as soon as practicable using methods that minimize the amount of dust suspended. Minn. R. 7011.1105 (I)

A ccess areas, roads, parking facilities:

Install asphalt or concrete surfaces or chemical agents on all active truck haul roads of the coal handling facility when the coal throughput by truck is 200,000 tons or greater. All paved roads and areas shall be cleaned to minimize the discharge to the atmosphere of fugitive particulate emissions. Such cleaning shall be accomplished in a manner which minimizes resuspension of particulate matter.

A ccess areas surrounding coal stockpiles and parking facilities which are located within a coal handling facility shall be treated with water, oils, or chemical agents. Minn. R. 7011.1105 (A)(1)

DETERMINING IF A PROJECT/MODIFICATION IS SUBJECT TO NEW SOURCE

REVIEW hdr

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-2

These requirements apply if a reasonable possibility (RP) as defined in 40 CFR Section 52.21(r)(6)(vi) exists that a proposed project, analyzed using the actual-to-projected-actual (ATPA) test (either by itself or as part of the hybrid test at Section 52.21(a)(2)(iv)(f)) and found to not be part of a major modification, may result in a significant emissions increase (SEI). If the ATPA test is not used for the project, or if there is no RP that the proposed project could result in a SEI, these requirements do not apply to that project. The Permittee is only subject to the Preconstruction Documentation requirement for a project where a RP occurs only within the meaning of Section 52.2(r)(6)(vi)(a).

Even though a particular modification is not subject to New Source Review (NSR), or where there isn't a RP that a proposed project could result in a SEI, a permit amendment, recordkeeping, or notification may still be required by Minn. R.

7007.1150 - 7007.1500. Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.0800, subp. 2

Preconstruction Documentation -- Before beginning actual construction on a project, the Permittee shall document the following:

1. Project description 2. Identification of any emission unit (EU) whose emissions of an NSR pollutant

could be affected 3. Pre-change potential emissions of any affected existing EU, and the projected post-change potential emissions of any affected existing or new EU. 4. A description of the applicability test used to determine that the project is not a major modification for any regulated NSR pollutant, including the baseline actual emissions, the projected actual emissions, the amount of emissions excluded due

to increases not associated with the modification and that the EU could have accommodated during the baseline period, an explanation of why the amounts were excluded, and any creditable contemporaneous increases and decreases that

were considered in the determination.

The Permittee shall maintain records of this documentation. Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.1200, subp. 4; Minn. R. 7007.0800, subps. 4 & 5

The Permittee shall monitor the actual emissions of any regulated NSR pollutant that could increase as a result of the project and that were analyzed using the

A TPA test, and the potential emissions of any regulated NSR pollutant that could increase as a result of the project and that were analyzed using potential emissions in the hybrid test. The Permittee shall calculate and maintain a record of the sum of the actual and potential (if the hybrid test was used in the analysis) emissions of the regulated pollutant, in tons per year on a calendar year basis, for a period of 5 years following resumption of regular operations after the change, or for a period of 10 years following resumption of regular operations after the change if the project increases the design capacity of or potential to emit of any unit associated with the project. Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 4 & 5

The Permittee must submit a report to the Agency if the annual summed (actual, plus potential if used in hybrid test) emissions differ from the preconstruction projection and exceed the baseline actual emissions by a significant amount as listed at 40 CFR Section 52.21(b)(23). Such report shall be submitted to the

A gency within 60 days after the end of the year in which the exceedances occur. The report shall contain:

a. The name and ID number of the facility, and the name and telephone number of the facility contact person b. The annual emissions (actual, plus potential if any part of the project was analyzed using the hybrid test) for each pollutant for which the preconstruction projection and significant emissions increase are exceeded. c. Any other information, such as an explanation as to why the summed emissions differ from the preconstruction projection. Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 4 & 5

Before beginning actual construction of any project which includes any electric utility steam generating unit (EUSGU), the Permittee shall submit a copy of the preconstruction documentation (items 1-4 under Preconstruction Documentation, above) to the Agency. Title I Condition: 40 CFR Section 52.21(r)(6)(ii); Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 4 & 5

For any project which includes any EUSGU, the Permittee must submit an annual report to the Agency, within 60 days after the end of the calendar year. The report

shall contain:

a. The name and ID number of the facility, and the name and telephone number of the facility contact person b. The quantified annual emissions analyzed using the ATPA test, plus the potential emissions associated with the same project analyzed as part of a hybrid

test. c. Any other information, such as an explanation as to why the summed emissions differ from the preconstruction projection, if that is the case. Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 4 & 5

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-3

For any project which does not include any EUSGU, the Permittee must submit a report to the Agency if the annual summed (actual, plus potential used in hybrid test) emissions differ from the preconstruction projection and exceed the baseline actual emissions by a significant amount as listed at 40 CFR Section 52.21(b)(23). Such report shall be submitted to the Agency within 60 days after the end of the year in which the exceedances occur. The report shall contain:

a. The name and ID number of the facility, and the name and telephone number of the facility contact person b. The annual emissions (actual, plus potential if any part of the project was analyzed using the hybrid test) for each pollutant for which the preconstruction projection and significant emissions rate is exceeded. c. Any other information, such as an explanation as to why the summed emissions differ from the preconstruction projection. Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 4 & 5

OPERATIONAL REQUIREMENTS hdr

The Permittee shall comply with National Primary and Secondary Ambient Air Quality Standards, 40 CFR pt. 50, and the Minnesota Ambient Air Quality Standards, Minn. R. 7009.0010 to 7009.0080. Compliance shall be demonstrated upon written request by the MPCA. 40 CFR pt. 50; Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subps. 7A, 7L & 7M; Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080.

Circumvention: Do not install or use a device or means that conceals or dilutes emissions, which would otherwise violate a federal or state air pollution control rule, without reducing the total amount of pollutant emitted. Minn. R. 7011.0020

A ir Pollution Control Equipment: Operate all pollution control equipment whenever the corresponding process equipment and emission units are operated, unless

otherwise noted in Table A. Minn. R. 7007.0800, subp. 2; Minn. R. 7007.0800, subp. 16(J)

Operation and Maintenance Plan: Retain at the stationary source an operation and maintenance plan for all air pollution control equipment. At a minimum, the O & M plan shall identify all air pollution control equipment and control practices and shall include a preventative maintenance program for the equipment and practices, a description of (the minimum but not necessarily the only) corrective actions to be taken to restore the equipment and practices to proper operation to meet applicable permit conditions, a description of the employee training program for proper operation and maintenance of the control equipment and practices, and the records kept to demonstrate plan implementation. Minn. R. 7007.0800, subp. 14 and Minn. R. 7007.0800, subp. 16(J)

Operation Changes: In any shutdown, breakdown, or deviation the Permittee shall immediately take all practical steps to modify operations to reduce the emission of any regulated air pollutant. The Commissioner may require feasible and practical modifications in the operation to reduce emissions of air pollutants. No emissions units that have an unreasonable shutdown or breakdown frequency of process or control equipment shall be permitted to operate. Minn. R. 7019.1000, subp. 4

Fugitive Emissions: Do not cause or permit the handling, use, transporting, or storage of any material in a manner which may allow avoidable amounts of particulate matter to become airborne. Comply with all other requirements listed in

Minn. R. 7011.0150. Minn. R. 7011.0150

Noise: The Permittee shall comply with the noise standards set forth in Minn. R. 7030.0010 to 7030.0080 at all times during the operation of any emission units. This is a state only requirement and is not enforceable by the EPA Administrator or

citizens under the Clean Air Act. Minn. R. 7030.0010 - 7030.0080

Inspections: The Permittee shall comply with the inspection procedures and requirements as found in Minn. R. 7007.0800, subp. 9(A). Minn. R. 7007.0800, subp. 9(A)

The Permittee shall comply with the General Conditions listed in Minn. R. 7007.0800, subp. 16. Minn. R. 7007.0800, subp. 16

PERFORMANCE TESTING hdr

Performance Testing: Conduct all performance tests in accordance with Minn. R. ch. 7017 unless otherwise noted in Tables A, B, and/or C. Minn. R. ch. 7017

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-4

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Tables A and B of the permit. See Table B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance Tes t Performance Test Plan: due 30 days before each Performance Test Performance Test Pre-test Meeting: due 7 days before each Performance Test Performance Test Report: due 45 days after each Performance Test Performance Test Report - Microfiche Copy: due 105 days after each Performance

Test

The Notification, Test Plan, and Test Report may be submitted in alternative format as allowed by Minn. R. 7017.2018. Minn. R. 7017.2018; Minn. R. 7017.2030, subps. 1-4, Minn. R. 7017.2035, subps. 1-2

Limits set as a result of a performance test (conducted before or after permit issuance) apply until superseded as specified by Minn. R. 7017.2025 following formal review of a subsequent performance test on the same unit and completion of permit reopening and reissuance. If limits serve to cause more stringent operating conditions, resulting changes to facility operation need to be made immediately. If limits serve to relax current operating conditions, resulting changes to facility operation must not be made prior to issuance of permit amendment with new limit incorporated. Minn. R. 7017.2025

MONITORING REQUIREMENTS hdr

Monitoring Equipment Calibration: Annually calibrate all required monitoring equipment (any requirements applying to continuous emission monitors are listed separately in this permit). Minn. R. 7007.0800, subp. 4(D)

Operation of Monitoring Equipment: Unless otherwise noted in Tables A, B, and/or C, monitoring a process or control equipment connected to that process is not necessary during periods when the process is shutdown, or during checks of the monitoring systems, such as calibration checks and zero and span adjustments. If monitoring records are required, they should reflect any such periods of process shutdown or checks of the monitoring system. Minn. R. 7007.0800, subp. 4(D)

RECORDKEEPING hdr

Recordkeeping: Retain all records at the stationary source for a period of five (5) years from the date of monitoring, sample, measurement, or report. Records which
must be retained at this location include all calibration and maintenance records, all original recordings for continuous monitoring instrumentation, and copies of all reports required by the permit. Records must conform to the requirements listed in Minn. R. 7007.0800, subp. 5(A). Minn. R. 7007.0800, subp. 5(C)

Recordkeeping: Maintain records describing any insignificant modifications (as required by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms (as required by Minn. R. 7007.1350, subp. 2), including records of the emissions resulting from those changes. Minn. R. 7007.0800, subp. 5(B)

If the Permittee determines that no permit amendment or notification is required prior to making a change, the Permittee must retain records of all calculations required under Minn. R. 7007.1200. These records shall be kept for a period of five years from the date the change was made or until permit reissuance, whichever is longer. The records shall be kept at the stationary source for the current calendar year of operation and may be kept at the stationary source or office of the stationary source for all other years. The records may be maintained in either electronic or paper format. Minn. R. 7007.1200, subp. 4

REPORTING/SUBMITTALS hdr

Fugitive Emissions Control Plan: The Permittee shall submit to the Commissioner and implement a fugitive emissions control plan within 60 days of the date of permit issuance. The plan shall identify all fugitive emission sources, primary and contingent control measures, and record keeping. The Permittee shall follow the actions and record keeping specified in the control plan. If the Commissioner determines the Permittee is out of compliance with Minn. R. 7011.0150 or the fugitive emission control plan, then the Permittee may be required to amend the control plan and/or to install and operate particulate matter ambient monitors. Minn. Stat. Section 116.07, subd. 4a; Minn. R. 7007.0800, subp. 2

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-5

Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of a planned shutdown of any control equipment or process equipment if the shutdown would cause any increase in the emissions of any regulated air pollutant. If the owner or operator does not have advance knowledge of the shutdown, notification shall be made to the Commissioner as soon as possible after the shutdown. However, notification is not required in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000, subp. 3.

A t the time of notification, the owner or operator shall inform the Commissioner of the cause of the shutdown and the estimated duration. The owner or operator shall notify the Commissioner when the shutdown is over. Minn. R. 7019.1000, subp. 3

Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdown of more than one hour duration of any control equipment or process equipment if the breakdown causes any increase in the emissions of any regulated air pollutant. The 24-hour time period starts when the breakdown was discovered or reasonably should have been discovered by the owner or operator. However, notification is not required in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000, subp. 2.

A t the time of notification or as soon as possible thereafter, the owner or operator

shall inform the Commissioner of the cause of the breakdown and the estimated duration. The owner or operator shall notify the Commissioner when the

breakdown is over. Minn. R. 7019.1000, subp. 2

Notification of Deviations Endangering Human Health or the Environment: As soon as possible after discovery, notify the Commissioner or the state duty officer, either orally or by facsimile, of any deviation from permit conditions which could endanger

human health or the environment. Minn. R. 7019.1000, subp. 1

Notification of Deviations Endangering Human Health or the Environment Report: Within 2 working days of discovery, notify the Commissioner in writing of any deviation from permit conditions which could endanger human health or the environment. Include the following information in this written description: 1. the cause of the deviation; 2. the exact dates of the period of the deviation, if the deviation has been corrected ; 3. whether or not the deviation has been corrected; 4. the anticipated time by which the deviation is expected to be corrected, if not yet
corrected; and 5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of the

deviation. Minn. R. 7019.1000, subp. 1

A pplication for Permit Amendment: If a permit amendment is needed, submit an application in accordance with the requirements of Minn. R. 7007.1150 through Minn. R. 7007.1500. Submittal dates vary, depending on the type of amendment

needed.

Upon adoption of a new or amended federal applicable requirement and if there are more than 3 years remaining in the permit term, the Permittee shall file an application for a permit amendment within 9 months of promulgation of the applicable requirement, pursuant to Minn. R. 7007.0400, subp. 3. Minn. R. 7007.1150 - 7007.1500; Minn. R. 7007.0400, subp. 3

Extension Requests: The Permittee may apply for an Administrative Amendment to extend a deadline in a permit by no more than 120 days, provided the proposed deadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H). Minn. R. 7007.1400, subp. 1(H)

Emission Inventory Report: due on or before April 1 of each calendar year following permit issuance. To be submitted on a form approved by the

Commissioner. Minn. R. 7019.3000 - 7019.3100

Emission Fees: due 60 days after receipt of an MPCA bill. Minn. R. 7002.0005 - 7002.0095

The Permittee must submit a Risk Management Plan (RMP) under 40 CFR pt. 68. Each owner or operator of a stationary source, at which a regulated substance is present above a threshold quantity in a process, shall design and implement an accidental release prevention program. An initial RMP must be submitted no later than the latest of the following dates: 1) June 21, 1999; 2) Three years after the date on which a regulated substance is first listed under 40 CFR Section 68.130; or 3) The date on which a regulated substance is first present above a threshold quantity in a process. A full update and resubmission of the RMP is required at least once every five years. The five-year anniversary date is reset whenever the facility fully updates and resubmits the RMP. Submit RMPs to the Risk Management Plan Reporting Center, P.O. Box 1515, Lanham-Seabrook, Maryland 20703-1515. RMP information may be obtained at http://www.epa.gov/swercepp or by calling 1-800-424-9346. 40 CFR pt. 68

NONROAD ENGINES hdr

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-6

The Permittee shall keep the following records for each nonroad engine that meets the definition of "nonroad engine" at 40 CFR Section 1068.30, "Nonroad engines" (1)(iii). This applies to this category of nonroad engines that is owned by the Permittee, or rented and operated by the permittee, or brought onsite under a

non-seasonal contract:

1) Date that the nonroad engine is brought onsite. 2) Date that the nonroad engine is taken offsite and/or moved to a different location. 3) Identification number. 4) Rated capacity of the nonroad engine. 5) The model year and date of manufacture (as defined by the applicable nonroad engine rule). 6) Which nonroad provision that the nonroad engine is certified under. 7) Rental company information. 8) Function of the nonroad engine.

While on site, each engine shall be labeled in such way that it can be determined that it is a nonroad engine and not one of the permitted engines covered by this air permit. 40 CFR Section 1068.30, "Nonroad engines", (2)(iii); Minn. R. 7007.0800, subps. 4 and 5

For the purpose of this permit, a nonroad engine seasonal contract is a binding agreement to have a third party operate a nonroad engine onsite for seasonal

activities and that will remain onsite for no more than 9 consecutive months.

Each seasonal contract engine and associated equipment onsite that meets the definition of "nonroad engine" at 40 CFR Section 1068.30, "Nonroad engines" (1)(iii), must be labeled with an identification that can be traced to the seasonal

contract.

The permittee must keep at the facility, a copy of the seasonal contract which

identifies:

1) The type of contract engines and associated equipment. 2) The purpose of contract engines and associated equipment. 3) The required schedule of operation for the contract engines and associated equipment. The residence-time requirements of paragraph (2)(iii) of the nonroad engine definition in 40 CFR Section 1068.30 apply to seasonal contract equipment. Minn. R. 7007.0800, subps. 4 and 5

The Permittee shall not bring nonroad engines that meet the definition of nonroad engine at 40 CFR Section 1068.30, "Nonroad engines", (1)(iii) onsite for periodic operation for more than 12 consecutive months.

The Permittee shall not have nonroad engines that meet the definition of nonroad engine at 40 CFR Section 1068.30, "Nonroad engines", (1)(iii) in one location within the stationary source for more than 12 consecutive months. A location is any single site at a building, structure, facility, or installation.

A ny engine, or engines, that replaces an engine at a location and that is intended to perform the same or similar function as the engine it replaced will be included in calculating the consecutive time period. 40 CFR Section 1068.30, "Nonroad engines", (2)(iii)

For a nonroad engine that is excluded from any requirements of 40 CFR Part 1068 because it is a stationary engine, the Permittee may not move it or install it in any mobile equipment, except as allowed by the provisions of 40 CFR Part 1068. The Permittee may not circumvent or attempt to circumvent the residence-time requirements of paragraph (2)(iii) of the nonroad engine definition in 40 CFR

Section 1068.30. 40 CFR Section 1068.101(b)(3)

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-7

Subject Item: GP 001 Emergency Engine Generators

Associated Items: EU 024 Emergency Engine Generator EEG-61001

EU 025 Emergency Engine Generator EEG-61002

SV 018 Emergency Engine Generator (EU 024) Stack

SV 019 Emergency Engine Generator (EU 025) Stack

What to do Why to do it

THE FOLLOWING LIMITS APPLY TO THE TWO GENERATORS COMBINED hdr

Operating Hours: less than or equal to 816 hours/year using 12-month Rolling Sum (operating hours of EU024 and EU025 combined) Title I Condition: To avoid classification as major

modification under 40 CFR Section 52.21 and Minn. R.

7007.3000

Nitrogen Oxides: less than or equal to 35.3 tons/year using 12-month Rolling Sum (NOx emissions from EU024 and EU025 combined) Title I Condition: To avoid classification as major

modification under 40 CFR Section 52.21 and Minn. R.

7007.3000

THE FOLLOWING LIMITS AND REQUIREMENTS APPLY TO EACH

EMERGENCY ENGINE GENERATOR INDIVIDUALLY hdr

Opacity: less than or equal to 20 percent opacity once operating temperatures have

been attained. Minn. R. 7011.2300, subp. 1

Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input . The potential to emit from each unit is 0.05 lb/MMBtu due to equipment design and allowable fuel. Minn. R. 7011.2300, subp. 2

Fuel type is limited to distillate fuel oil with a maximum Sulfur Content of Fuel: less than or equal to 0.050 percent by weight Minn. R. 7007.0800, subp. 2

Each engine must be operated according to the following requirements, or the engine will not be considered an emergency engine under 40 CFR Part 63 Subpart ZZZZ, and will be required to meet all Subpart ZZZZ requirements for non-emergency engines.

(i) There is no time limit on engine use in emergency situations.

(ii) The engine may be operated for the purpose of mantenance checks and readiness testing, provided that the tests are recommended by the manufacturer, the vendor, or the insurance company associated with the engine. Required testing of such units should be minimized, but there is no time limit on engine use in emergency situations and for routine testing and maintenance.

(iii) The engine may be operated for an additional 50 hours per year in non-emergency situations. The 50 hours cannot be used for peak shaving or to generate income for a facility to supply power to an electric grid or otherwise supply power as part of a financial arrangement with another entity. 40 CFR Section 63.6640(f)(2); Minn. R. 7011.8150

RECORDKEEPING hdr

Fuel Supplier Certification: The Permittee shall obtain supplier certification that the sulfur content does not exceed 0.050 % by weight. The certification shall be a single certification from the fuel oil supplier guaranteeing a maximum sulfur content in all fuel oil deliveries thereafter. The single certification shall also state that the supplier will notify the Permittee in writing on the date of delivery of fuel oil with a sulfur content exceeding the guaranteed maximum, that the fuel oil sulfur content exceeds the guaranteed maximum value.

The Permittee may instead choose to test the oil in the storage tank following each shipment, according to current ASTM or EPA methods and keep records of lab analyses of sulfur content. Minn. R. 7007.0800, subp. 5

Daily Recordkeeping - Operating Hours. For each engine, on each day that the engine is operated, record the number of hours operated. Title I Condition: To avoid classification as major

modification under 40 CFR Section 52.21 and Minn. R.

7007.3000

Daily Recordkeeping: Each day that the engine is operated, record the number of operating hours that were non-emergency and were not routine testing and

maintenance. Minn. R. 7007.0800, subp. 4 and 5

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-8

Monthly Recordkeeping -- Operating Hours. By the 20th day of each month, the Permittee shall calculate and record the following:

1) The total Operating Hours for the previous calendar month using the daily

records.

2) The 12 month rolling sum Operating Hours for the previous 12 month period ("OO" in the equation below) by summing the monthly Operating Hours data for the previous 12 months.

3) The total non-emergency, non-routine testing and maintenance hours operated during the previous calendar month.

4) The total non-emergency, non-routine testing and maintenance hours operated during the previous 12 calendar months. Minn. R. 7007.0800, subp. 4 and 5

Monthly Recordkeeping -- Nitrogen Oxides. By the 20th day of each month, the Permittee shall calculate and record the 12-month rolling sum Nitrogen Oxides using the following equation:

NOX = OO x EF x 16.58 x 0.0005

Where:

NOX = the 12-month rolling sum NOX emissions (tons/year)

OO = the 12-month rolling sum operating hours, calculated as described above (hours/year) .

EF = the most current emission factor published in AP-42 (4.41 lb/MMBtu at the time of permit issuance)

16.58 = engine capacity (MMBtu/hour)

0.0005 = 1 ton/2000 lb Minn. R. 7007.0800, subp. 4 and 5

TEMPORARY REPLACEMENT hdr

Temporary replacement conditions: The Permittee may temporarily replace listed emission units in GP001, provided the following conditions are met:

1) The potential emissions of the replacement unit (assuming all enforceable limits imposed through this permit, and aggregated if more than one engine is simultaneously replaced; see EU028) are less than all of the following: 25 tpy PM, 15 tpy PM < 10 microns, 10 tpy PM < 2.5 microns, 40 tpy VOC, 40 tpy SO2, 40 tpy NOx, 100 tpy CO, 75000 tpy CO2e;

2) The permitee must calculate the allowable potential to emit of each temporary replacement engine assuming operating conditions that are enforceable by this permit. For pollutants not specifically limited by a permit or rule, the permitee may use emission factors generated based on the temporary replacement engine manufacturer's performance tests;

3) The capacity of the replacement unit is less than or equal to the unit it replaces; Title I Condition: To avoid classification as major

modification under 40 CFR Section 52.21 and Minn. R. 7007.3000; 40 CFR Section 60.4200(e). Minn. R. 7005.0100 subp. 35a; 7007.1200 subp. 3; 7007.1450;

7007.1250 and 7007.0800

Continued from above:

4) The project can only be the temporary replacement of internal combustion engines for the purpose of providing emergency electrical power at the facility;

5) Emissions and operating hours are tracked and calculated as specified in this permit;

6) The replacement engine may only replace a permanent engine that is temporarily out of service for less than one year;

7) The replacement engine must meet the conditions for temporary replacement units under 40 CFR Section 60.4200(e);

8) Prior to making such a change, the permittee shall apply for and obtain the appropriate permit amendment. The permittee is not required to complete emission calculations described in Minn. R. 7007.1200 subp. 2. A permit will still be needed regardless of the emissions increase if the change will be subject to a new applicable requirement or requires revisions to the limits or monitoring and recordkeeping in this permit. Title I Condition: To avoid classification as major

modification under 40 CFR Section 52.21 and Minn. R. 7007.3000; 40 CFR Section 60.4200(e). Minn. R. 7005.0100 subp. 35a; 7007.1200 subp. 3; 7007.1450;

7007.1250 and 7007.0800

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-9

The replacement engine may not be operated at the same time as the permanent unit it is replacing, except for up to 8 hours during start-up and shutdown transition periods. Title I Condition: To avoid classification as major

modification under 40 CFR Section 52.21 and Minn. R.

7007.3000

If the replacement engine does not require a permit amendment, the Permittee shall keep the following records on site for each replacement engine not requiring a permit amendment: - Records required by Minn. R. 7007.1200, subp. 4; - The dates the temporary engine was installed, started operation, and was
removed; - Filled form GI05B for each replacement engine with an assigned consecutive
emission unit number; - A unique identification for the unit, such as make, model, and serial number; - Rated capacity and type of engine; - Dates and hours of operation of the engine; - A statement of all periods of operation during which the permanent engine being temporarily replaced is not also operating; and - Calculations of the potential to emit of the engine and emission changes pursuant to Minn. R. 7007.1200 subpart 3. Title I Condition: To avoid classification as a major

modification under 40 CFR Section 52.21 and Minn. R. 7007.3000; Minn. R. 7007.0800, subp. 5; Minn. R. 7007.1200, subp. 4

The Permittee shall notify the MPCA if the replacement engine is operated simultaneously with the permanent engine being temporarily replaced, except as allowed by this permit. Make verbal notification within 2 days, and written notification with the semi-annual deviations report. Minn. R. 7007.0800, subp. 5; Minn. R. 7007.1200, subp. 4

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-10

Subject Item: GP 002 Boilers and Associated Control Equipment

Associated Items: CE 006 Electrostatic Prec ipitator - High Efficiency

CE 007 Electrostatic Prec ipitator - High Efficiency

CE 008 Electrostatic Prec ipitator - High Efficiency

CE 009 Electrostatic Prec ipitator - High Efficiency

EU 003 Boiler 3

EU 004 Boiler 4

MR 006 Air Flow Monitor

MR 013 Boilers 3 & 4 SO2 Monitor

MR 014 Boilers 3 & 4 NOx Monitor

MR 015 Boilers 3 & 4 CO2 Monitor

MR 016 Boilers 3 & 4 Opacity Monitor

SV 001 Main Stack for Boilers 3 and 4

What to do Why to do it

EMISSION LIMITS THAT APPLY TO SV001 (Combined emissions from EU003 and EU004) hdr

Sulfur Dioxide: less than or equal to 1.3 lbs/million Btu heat input using 1-Hour

A verage . Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

Sulfur Dioxide: less than or equal to 3988 lbs/hour using 1-Hour Average . Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

PM < 10 micron: less than or equal to 920 lbs/hour using 3-hour Average Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

EMISSION LIMITS THAT APPLY TO EU003 & EU004 INDIVIDUALLY hdr

Total Particulate Matter: less than or equal to 0.4 lbs/million Btu heat input using 3-hour Average Minn. R. 7011.0510, subp. 1

Total Particulate Matter: less than or equal to 0.3 lbs/million Btu heat input using 3-hour Average Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

Opacity: less than or equal to 20 percent opacity using 6-minute Average except that a maximum of 60 percent opacity shall be allowable for one six minute period in any 60-minute period. Minn. R. 7011.0510, subp. 2

Sulfur Dioxide: less than or equal to 3.0 lbs/million Btu heat input using 3-hour

A verage when burning solid fuels. Minn. R. 7011.0510, subp. 1

Sulfur Dioxide: less than or equal to 1.6 lbs/million Btu heat input using 3-hour

A verage when burning liquid fuel Minn. R. 7011.0510, subp. 1

NOx Averaging Plan For Unit 3 (EU003) (2010-2014)

Beginning January 1, 2010 either: Maintain an annual average NOx emission rate of 0.81 lbs/MMBtu and limit the annual heat input to less than or equal to 6,133,000 MMBtu per year.

OR Maintain a Btu-weighted annual average emission rate in lbs/MMBtu, averaged over the units specified in the NOx averaging plan, that is less than or equal to the Btu-weighted annual average emission rate averaged over the same units had they each been operated during the same period of time in compliance with the applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units covered in the plan are:

Plant Boiler ID#

A llen S. King 1 Black Dog 3,4 Sherburne County 1,2,3 40 CFR Section 76.11; Minn. R. 7011.0553

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-11

NOx Averaging Plan For Unit 4 (EU004) (2010-2014)

Beginning January 1, 2010 either: Maintain an annual average NOx emission rate of 0.81 lbs/MMBtu and limit the annual heat input to less than or equal to 12,138,000 MMBtu per year.

OR Maintain a Btu-weighted annual average emission rate in lbs/MMBtu, averaged over the units specified in the NOx averaging plan, that is less than or equal to the Btu-weighted annual average emission rate averaged over the same units had they each been operated during the same period of time in compliance with the applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units covered in the plan are:

Plant Boiler ID#

A llen S. King 1 Black Dog 3,4 Sherburne County 1,2,3 40 CFR Section 76.11; Minn. R. 7011.0553

OPERATIONAL REQUIREMENTS hdr

A llowed fuel types for EU003 and EU004: bituminous coal, subbituminous coal, distillate fuel oil, natural gas, propane, used oil, non-hazardous spill cleanup materials, non-hazardous boiler cleaning agents. Minn. R. 7007.0800, subp. 2

Combust used oil in accordance with used oil regulations in Minn. R. ch. 7045. Limit to 5% of total fuel mass on an hourly basis. Minn. R. 7007.0800, subp. 2; Minn. R. ch. 7045

Combustion of boiler chemical cleaning agents limited to: 8.5 gpm per 100,000 lbs/hr steam flow. Cleaning waste shall be introduced EU003 or EU004 only when the boiler is operating at a minimum of 75 percent of rated capacity. Minn. R. 7007.0800, subp. 2

CONTROL EQUIPMENT REQUIREMENTS (See Subject Item GP003 for specific operating requirements) hdr

The Permittee shall operate and maintain each ESP (CE006/CE007 and/or CE008/CE009) at any time that the process equipment controlled by the ESP is in operation, except when the boilers is burning only natural gas. The Permittee shall document periods of non-operation of the control equipment.

EU003 is controlled by CE006 & CE007 (in series) EU004 is controlled by CE008 & CE009 (in series) Minn. R. 7007.0800, subps. 2 and 14

MONITORING REQUIREMENTS (see also Subject Item GP008) hdr

Emissions Monitoring: The owner or operator shall use a NOX CEMS to measure

NOX emissions from SV001.

A dditional monitoring requirements can be found at Subject Item GP004 and in Table B of this permit. 40 CFR Section 75.10(a); Minn. R. 7017.1006

Emissions Monitoring: The owner or operator shall use a SO2 CEMS to measure

SO2 emissions from SV001.

A dditional monitoring requirements can be found at Subject Item GP004 and in Table B of this permit. 40 CFR Section 75.10(a); Minn. R. 7017.1006

Emissions Monitoring: The owner or operator shall use a COMS to measure Opacity from SV001.

A dditional monitoring requirements are also located at Subject Item MR016 at in Table B of this permit. Minn. R. 7017.1006

RECORDKEEPING REQUIREMENTS (see also Subject Item GP008) hdr

Recordkeeping of Boiler Cleaning Agent combustion: the Permittee shall keep records for all cleaning agent combustion including:

- date of combustion

- total quantity (gallons)

- origin of cleaning agent

- cleaning agent feed rate (in gallons per minute (gpm))

- operating capacity of the boiler during cleaning agent combustion (pounds of steam per hour)

- cleaning agent combustion rate (gpm/100000 lb per hour of steam) Minn. R. 7007.0800, subp. 5

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-12

Recordkeeping of Boiler Used Oil combustion: The Permittee shall keep records for all used oil combustion including:

- date of combustion

- total quantity (mass)

- origin of used oil

- used oil feed rate (mass per hour)

- total mass of fuel (including used oil) combusted in the boiler during used oil combustion (mass per hour)

- used oil combustion rate (percent of total fuel mass per hour) Minn. R. 7007.0800, subp. 5

Beginning with calendar year 2015, or the calendar year in which the Compliance Date for Existing EGU pursuant to 40 CFR part 63, Subpart UUUUU (40 CFR Section 63.9984) falls:

Maintain records of the amount of coal combusted in each boiler (EU003 and EU004) as a percentage of the annual heat input for the calendar year.

Maintain records of the amount of oil combusted in each boiler (EU003 and EU004) as a percentage of the annual heat input for the calendar year. Minn. R. 7007.0800, subp. 5

TESTING REQUIREMENTS hdr

Performance Test: due before end of each 60 months starting 09/30/2003 to measure front-half particulate matter emissions. The tests shall be conducted at an

interval not to exceed 60 months between test dates. Minn. R. 7017.2020, subp. 1

Boiler Alternative Operating Conditions for Performance Testing:

A lternative Operating Conditions during testing are defined as 90% to 100% of the boiler's maximum normal (continuous) operating load or the maximum permitted operating rate, whichever is lower. The basis for this number must be included in the test plan. If testing is conducted at the alternative operating condition established, an operating limit will not be established as a result of performance testing.

In no case will the new operating rate limit be higher than allowed by an existing permit condition. Minn. R. 7007.0800, subp. 2.

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions During Performance Testing:

If performance testing is not conducted at or above the established alternative operating condition, then the boiler operating rate will be limited on an 8-hour block average based on the following:

(1) If the results of the performance test are greater than 90% of any applicable emission limit for which emissions are measured, then boiler operation will be limited to the tested operating rate.

(2) If results are less than or equal to 90% of all applicable emission limits for which emissions are measured, boiler operation will be limited to 110% of the tested operating rate.

In no case will the new operating rate limit be higher than allowed by an existing permit condition. Minn. R. 7007.0800, subp. 2.

NESHAP REQUIREMENTS hdr

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-13

EU003 and EU004 will be subject to NESHAP Subpart UUUUU as of the compliance date of the standard only if they are classified as a coal- or oil-fired

EGU as defined in 40 CFR Section 63.10042:

Coal-fired EGU means an electric utility steam generating unit meeting the definition of fossil fuel-fired that burns coal for more than 10.0 percent of the average annual heat input during any 3 consecutive calendar years or for more than 15.0 percent of the annual heat input during any one calendar year.

Oil-fired EGU means an electric utility steam generating unit meeting the definition of fossil fuel-fired that is not a coal-fired electric utility steam generating unit and that burns oil for more than 10.0 percent of the average annual heat input during any 3 consecutive calendar years or for more than 15.0 percent of the annual heat input during any one calendar year.

Fossil fuel-fired means an EGU that is capable of combusting more than 25 MW of

fossil fuels. 40 CFR Section 63.9981

A ny electric utility steam generating unit that is not a coal- or oil-fired EGU and combusts natural gas for more than 10.0 percent of the average annual heat input during any 3 calendar years or for more than 15.0 percent of the annual heat input during any calendar year is not subject to NESHAP Subpart UUUUU. 40 CFR Section 63.9983(b)

If EU003 or EU004 is in operation and meets the definition of a coal- or oil-fired EGU as of the compliance date listed in 40 CFR Section 63.9984(b), then the boiler must be in compliance with Subpart UUUUU as of that date.

A s of the issuance date of permit action 13700003-011, the compliance date is

A ugust 16, 2015. 40 CFR Section 63.9984(b)

In the application for permit reissuance, the Permittee indicated that the facility will not include coal-fired or oil-fired EGU on the compliance date listed in 40 CFR Section 63.9984(b). Minn. R. 7007.0600; Minn. R. 7007.0800, subp. 2

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-14

Subject Item: GP 003 Electrostatic Precipitator Requirements

Associated Items: CE 006 Electrostatic Prec ipitator - High Efficiency

CE 007 Electrostatic Prec ipitator - High Efficiency

CE 008 Electrostatic Prec ipitator - High Efficiency

CE 009 Electrostatic Prec ipitator - High Efficiency

What to do Why to do it

The Permittee shall operate and maintain CE006 and CE007 such that they achieve an overall combined control efficiency for Total Particulate Matter: greater than or equal to 99.75 percent control efficiency Minn. R. 7007.0800, subp. 2

The Permittee shall operate and maintain CE006 and CE007 such that they achieve an overall combined control efficiency for PM < 10 micron: greater than or equal to 99.75 percent control efficiency Minn. R. 7007.0800, subp. 2

The Permittee shall operate and maintain CE006 and CE007 such that they achieve an overall combined control efficiency for PM < 2.5 micron: greater than or equal to 99.75 percent control efficiency Minn. R. 7007.0800, subp. 2

CE006 and CE007 Minimum Surface Collection Area (SCA): greater than or equal to 125,760 square feet (Unit 3 primary and secondary combined), unless a new minimum SCA is required to be set pursuant to Minn. R. 7017.2025, subp. 3. If a new minimum SCA is required to be set, it will be based on the SCA in service during the most recent MPCA approved performance test where compliance for

Total Particulate Matter emissions was demonstrated.

If the sections in the ESPs are physically and electrically equivalent, the Permittee can meet this requirement by operating the ESP with no less than the number of sections that were operating during the most-recent MPCA approved performance test where compliance for Total Particulate Matter emissions was demonstrated. Minn. R. 7007.0800, subps. 2 and 14; Minn. R. 7017.2025, subp. 3

The Permittee shall operate and maintain CE008 and CE009 such that they achieve an overall combined control efficiency for Total Particulate Matter: greater than or equal to 99.75 percent control efficiency Minn. R. 7007.0800, subp. 2

The Permittee shall operate and maintain CE008 and CE009 such that they achieve an overall combined control efficiency for PM < 10 micron: greater than or equal to 99.75 percent control efficiency Minn. R. 7007.0800, subp. 2

The Permittee shall operate and maintain CE008 and CE009 such that they achieve an overall combined control efficiency for PM < 2.5 micron: greater than or equal to 99.75 percent control efficiency Minn. R. 7007.0800, subp. 2

CE008 and CE009 Minimum Surface Collection Area (SCA): greater than or equal to 141,144 square feet (Unit 4 primary and secondary combined), unless a new minimum SCA is required to be set pursuant to Minn. R. 7017.2025, subp. 3. If a new minimum SCA is required to be set, it will be based on the SCA in service during the most recent MPCA approved performance test where compliance for

Total Particulate Matter emissions was demonstrated.

If the sections in the ESPs are physically and electrically equivalent, the Permittee can meet this requirement by operating the ESP with no less than the number of sections that were operating during the most-recent MPCA approved performance test where compliance for Total Particulate Matter emissions was demonstrated. Minn. R. 7007.0800, subps. 2 and 14; Minn. R. 7017.2025, subp. 3

ESP Monitoring: The opacity at SV001 as measured by COMS (MR016) shall be used to assess proper operation of the ESPs. 40 CFR Section 64.7(a); Minn.R. 7017.0200; Minn. R. 7007.0800, subp. 2

THE FOLLOWING REQUIREMENTS APPLY TO EACH ELECTROSTATIC

PRECIPITATOR INDIVIDUALLY hdr

The Permittee shall operate and maintain each ESP (CE006/CE007 and/or CE008/CE009) at any time that the process equipment controlled by the ESP is in operation, except when the boilers is burning only natural gas. The Permittee shall document periods of non-operation of the control equipment.

EU003 is controlled by CE006 & CE007 (in series) EU004 is controlled by CE008 & CE009 (in series) EU019 is controlled by CE006 & CE007 (in series) and CE008 & CE009 (in series) Minn. R. 7007.0800, subps. 2 and 14

Operation and Maintenance of ESP: The Permittee shall operate and maintain the ESP in accordance with the Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and review by MPCA staff. Minn. R. 7007.0800, subp. 14

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-15

Daily Recordkeeping: Each day that the associated boiler (EU003 or EU004, as applicable) is operating:

- Continuously monitor the ESP sections (or SCA if sections are not equivalent) in

service.

- Record the ESP sections in service, and verify that the minimum SCA is online.

Records shall indicate periods of operation on only natural gas. Minn. R. 7007.0800, subps. 4 and 5

Continuous Monitoring: The Permittee shall continuously, or at a minimum once every 15 minutes, monitor the opacity of the SV001 exhaust.

See Subject Item MR016 and Table B for specific COMS operating requirements. 40 CFR Section 64.3(b)(4)(ii); Minn. R. 7017. 0200

Opacity: less than or equal to 20 percent opacity using 6-minute Average , as measured by COMS in SV001. Opacity in excess of this limit shall be considered an excursion under 40 CFR Section 64.6(c)(2). 40 CFR Section 64.3; Minn. R. 7017.0200

Monitoring Equipment: The necessary monitoring equipment must be installed, in use, and properly maintained, including maintaining the necessary parts for routine repairs of the monitoring equipment, whenever operation of the monitored control equipment is required. 40 CFR Section 64.7(b); Minn. R. 7017.0200

Periodic Inspections: At least once per calendar quarter, or more frequently if required by the manufacturer, the Permittee shall inspect the control equipment components that are subject to wear or plugging, for example: bearings, belts, hoses, fans, nozzles, orifices, and ducts. The Permittee shall maintain a written record of the inspection and any corrective actions taken resulting from the inspection. 40 CFR Section 64.3; Minn. R. 7017.0200

A nnual Inspections: At least once per calendar year, or more frequently if required by the manufacturer, the Permittee shall inspect the control equipment components not covered by the quarterly inspections. This includes, but is not limited to, components that are not subject to wear or plugging including structural components, housings, and hoods. The Permittee shall maintain a written record of the inspection and any corrective actions taken resulting from the inspection. 40 CFR Section 64.3; Minn. R. 7017.0200

Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur: - the monitored opacity exceeds 20% using a 6-minute block average; or - the minimum SCA is not met; or - the ESP or any of its components are found during the inspections to need repair. Corrective actions shall return operation to within the permitted range and/or include completion of necessary repairs identified during the inspection, as applicable. Corrective actions include, but are not limited to, those outlined in the O & M Plan for the ESP. The Permittee shall keep a record of the type and date of any corrective action taken for the ESP. 40 CFR Section 64.7(d); Minn. R. 7017.0200

Documentation of Need for Improved Monitoring: If the Permittee fails to achieve compliance with an emission limitation or standard for which the monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing opacity which is considered an excursion, the Permittee shall promptly notify the MPCA and, if necessary, submit a permit amendment application to address the necessary monitor changes. 40 CFR Section 64.7(e); Minn. R. 7017.0200

A s required by 40 CFR Section 64.9(a)(2), for the Semi-Annual Deviations Report or Deviations Reporting Form (DRF 1) listed in Table B of this permit and/or the Notification of Deviations Endangering Human Health and the Environment listed earlier in Table A of this permit, as applicable, the Permittee shall include the following related to the monitoring identified as required by 40 CFR pt. 64: 1) Summary information on the number, duration, and cause of excursions or exceedances, as applicable, and the corrective action taken; and 2) Summary
information on the number, duration, and cause for monitor downtime incidents. 40 CFR Section 64.9(a)(2); Minn. R. 7017.0200

The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions taken, and other supporting information required to be maintained. The Permittee may maintain records on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable recordkeeping requirements. 40 CFR Section 64.9(b); Minn. R. 7017.0200

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-16

Subject Item: GP 004 CEMS Required by Acid Rain Regulations

Associated Items: MR 006 Air Flow Monitor

MR 013 Boilers 3 & 4 SO2 Monitor

MR 014 Boilers 3 & 4 NOx Monitor

MR 015 Boilers 3 & 4 CO2 Monitor

What to do Why to do it

A dditional monitoring requirements are located in Table B. hdr

The CEMS requirements listed below outline the typical standards of 40 CFR Pt. 75 when combined with Minn. R. Additional monitoring requirements may also apply to the Facility based on the standard and it is the responsibility of the Facility to meet all applicable requirements. hdr

Installation Notification: due 60 days before installing the continuous emissions monitoring system. The notification shall include plans and drawings of the system. Minn. R. 7017.1040, subp. 1

CEMS Certification: The owner or operator shall ensure that each CEMS required by this part meets the initial certification requirements of this section and shall ensure that all applicable initial certification tests under paragraph (c) of this section are completed by the deadlines specified in 40 CFR Section 75.4 and prior to use in the Acid Rain Program. In addition, whenever the owner or operator installs a continuous emission or opacity monitoring system in order to meet the requirements of Sections 75.11 through 75.18, where no continuous emission or opacity monitoring system was previously installed, initial certification is required. Certify all CEMS required by the Acid Rain Program in accordance with 40 CFR pt. 75, Appendix A, Section 6. 40 CFR Section 75.20; 40 CFR pt. 75, Appendix A,

Section 6

CEMS Certification Test Plan: due 30 days before CEMS Certification Test CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test CEMS Certification Test Report: due 45 days after CEMS Certification Test CEMS Certification Test Report Microfiche Copy: due 105 days after CEMS

Certification Test The Notification, Test Plan, and Test Report may be submitted in alternate format as allowed by Minn. R. 7017.1120, subp. 2 40 CFR Section 75.61; Minn. R. 7017.1060, subps. 1-3; Minn. R. 7017.1080, subps. 1-4

Certification Application: The owner or operator shall apply for certification of each continuous emission or opacity monitoring system used under the Acid Rain Program. The owner or operator shall submit the certification application in accordance with 40 CFR Section 75.60 and each complete certification application shall include the information specified in Section 75.63. 40 CFR Sections 75.20(a)(2), 75.60(b)(1), & 75.63

Continuous Operation: CEMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. A CEMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment. Minn. R. 7017.1090

Monitoring Data: Hourly averages shall be computed using at least one data point in each fifteen minute quadrant of an hour, where the unit combusted fuel during that quadrant of an hour. Not withstanding this requirement, an hourly average may be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant of an hour) if data is unavailable as a result of the performance of calibration, quality assurance, or preventive maintenance activities pursuant to 40 CFR Section 75.21 and appendix B of pt. 75, or backups of data from the data acquisition and handling system, or recertification, pursuant to Section 75.20. The owner or operator shall use all valid measurements or data points collected during an hour to calculate the hourly averages. All data points collected during an hour shall be, to the extent practicable, evenly spaced over the hour. 40 CFR Section 75.10(d)(1); Minn. R. 7017.1160, subps. 1 and 2

CEMS QA/QC: The owner or operator of an affected facility shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75,

A ppendix B as amended. 40 CFR Section 75.21

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-17

QA Plan: Develop and implement a written plan that describes in detail (or that refers to separate documents containing) complete, step-by-step procedures and operations of the activities outlined in 40 CFR pt. 75, Appendix B, Section 1.1. Upon request from regulatory authorities, the source shall make all procedures, maintenance records, and ancillary supporting documentation from the manufacturer (e.g., software coefficients and troubleshooting diagrams) available for review during an audit. Electronic storage of the information in the QA/QC plan is permissible, provided that the information can be made available in hardcopy upon request during an audit. 40 CFR pt. 75, Appendix B, Section 1; Minn. R. 7017.1210, subp. 1

Daily Calibration Error (CE) Test: Conduct daily CE testing of each gas monitoring system according to the procedures in Section 6.3.1 of 40 CFR pt. 75, Appendix A and of each flow monitoring system according to the procedures in Section 6.3.2 of 40 CFR pt. 75, Appendix A. 40 CFR pt. 75, Appendix B, Section 2.1

Linearity and Leak Check Test (Acid Rain Program): due before the end of each QA operating quarter (calendar quarter in which there are at least 168 unit operating hours) following Permit Issuance in accordance with procedures in 40 CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2. Perform a leak check at least once during each QA operating quarter and no less than 30 days apart. 40 CFR pt. 75, Appendix B, Sections 2.2.1 & 2.2.2;

Minn. R. 7017.1020

CEMS Relative Accuracy Test Audit (RATA): Due semianually following Permit Issuance, i.e., once every two successive QA operating quarters (calendar quarter in which there are at least 168 unit operating hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be performed annually (i.e., once every four successive QA operating quarters, rather than once every two successive QA operating quarters) if any of the conditions listed in 40 CFR pt. 75, Appendix B, Sections 2.3.1.2(a) through 2.3.1.2(i) are met. 40 CFR pt. 75, Appendix B, Section 2.3.1; Minn. R.

7017.1020

RATA Notification: due 30 days before CEMS Relative Accuracy Test Audit (RATA). Minn. R. 7017.1180, subp. 2

Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. Minn. R 7017.1130; 40 CFR Section 75.57

Quarterly Reports: Electronically report the data and information in 40 CFR Section 75.64 (a), (b), and (c) to the Administrator quarterly. 40 CFR Section 75.64; Minn. R. 7017.1110, subps. 1 &

2

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-18

Subject Item: GP 005 CEMS Required by Acid Rain and NSPS Regulations

Associated Items: MR 017 Unit 5/2 NOx Dual Range Monitor

MR 018 Unit 5/2 O2 Monitor

What to do Why to do it

A dditional monitoring requirements are located in Table B. hdr

The CEMS requirements listed below outline the typical standards of 40 CFR pt. 60 and pt. 75 when combined with Minn. R. Additional monitoring requirements may also apply to the Facility based on this combination of standards and it is the responsibility of the Facility to meet all applicable requirements. hdr

Continuous Operation: CEMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. A CEMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment. Acceptable monitor downtime includes reasonable periods as listed in Items A, B, C and D of Minn. R. 7017.1090, subp. 2. 40 CFR Section 60.13(e); Minn. R. 7017.1090, subp. 1

Installation Notification: due 60 days before installing the continuous emissions monitoring system. The notification shall include plans and drawings of the system. Minn. R. 7017.1040, subp. 1

CEMS Monitor Design: Each CEMS shall be designed to complete a minimum of one cycle of sampling, analyzing, and data recording in each 15-minute period. 40 CFR pt. 75.10(d)(1); 40 CFR Section 60.13(e)(2)

CEMS Certification Test: due 120 days after the first calendar quarter following CEMS Installation. (This requirement is as stringent as that of Minn. R. 7017.1050, subp. 1 requiring testing within 90 days after the due date of the first excess emissions report required for the CEMS.) 40 CFR Section 60.13(b); Minn. R. 7017.1050, subp. 1

CEMS Certification: The owner or operator shall ensure that each CEMS or COMS required by this part meets the initial certification requirements of this section and shall ensure that all applicable initial certification tests under paragraph (c) of this section are completed by the deadlines specified in 40 CFR Section 75.4 and prior to use in the Acid Rain Program. In addition, whenever the owner or operator installs a continuous emission or opacity monitoring system in order to meet the requirements of Sections 75.11 through 75.18, where no continuous emission or opacity monitoring system was previously installed, initial certification is required. Certify all CEMS required by the Acid Rain Program in accordance with 40 CFR pt. 75, Appendix A, Section 6. (Note 40 CFR Part 60 has a standard regarding this requirement as well) 40 CFR Section 75.20; 40 CFR pt. 75, Appendix A, subp. 6

CEMS Certification Test Plan: due 30 days before CEMS Certification Test CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test CEMS Certification Test Report: due 45 days after CEMS Certification Test CEMS Certification Test Report - Microfiche Copy: due 105 days after CEMS

Certification Test The Notification, Test Plan, and Test Report may be submitted in alternate format as allowed by Minn. R. 7017.1120, subp. 2 40 CFR Section 75.61; 40 CFR Section 60.7(a)(5); Minn. R. 7017.1060, subps. 1-3; Minn. R. 7017.1080, subps. 1-4

Certification Application: The owner or operator shall apply for certification of each continuous emission or opacity monitoring system used under the Acid Rain Program. The owner or operator shall submit the certification application in accordance with 40 CFR Section 75.60 and each complete certification application shall include the information specified in 40 CFR Section 75.63. 40 CFR Sections 75.20(a)(2), 75.60(b)(1), & 75.63

CEMS QA/QC: The owner or operator of an affected facility is subject to the performance specifications listed in 40 CFR pt. 60, Appendix B and shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 60, Appendix F as amended and maintain a written QA/QC program available in a form suitable for inspection. (Note 40 CFR Part 75 has a standard regarding this requirement as well) 40 CFR pt. 60, Appendix F; 40 CFR Section 60.13(a)

CEMS QA/QC: The owner or operator of an affected facility shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75,

A ppendix B as amended. (Note 40 CFR Part 60 has a standard regarding this requirement as well) 40 CFR Section 75.21

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-19

40 CFR Pt. 75 Monitoring Data: Hourly averages shall be computed using at least one data point in each fifteen minute quadrant of an hour, where the unit combusted fuel during that quadrant of an hour. Notwithstanding this requirement, an hourly average may be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant of an hour) if data are unavailable as a result of the performance of calibration, quality assurance, or preventive maintenance activities pursuant to 40 CFR Section 75.21 and pt. 75, Appendix B, or backups of data from the data acquisition and handling system, or recertification, pursuant to Section 75.20. The owner or operator shall use all valid measurements or data points collected during an hour to calculate the hourly averages. All data points collected during an hour shall be, to the extent practicable, evenly spaced over the hour. (Note 40 CFR pt. 60 has a standard regarding this requirement) 40 CFR Section 75.10(d)(1)

NSPS Monitoring Data: Reduce all NSPS-required continuous monitoring systems other than COMS data to 1-hour averages, in accordance with 40 CFR Section 60.13(h). (Note 40 CFR pt. 75 has a standard regarding this requirement as well) 40 CFR Section 60.13(h); Minn. R. 7017.1160, subps.

1 and 2

CEMS Daily Calibration Drift Test: Check the zero (low level value between 0 and 20 percent of span value) and span (50 to 100 percent of span value) calibration drifts at least once daily. The zero and span must, at a minimum, be adjusted whenever the drift exceeds two times the limit specified in 40 CFR pt. 60, Appendix B. 40 CFR pt. 60, Appendix F, Section 4.3.1 shall be used to determine out-of-control periods for CEMS. (Note: 40 CFR pt. 75 has a standard regarding this requirement as well.) 40 CFR pt. 60, Appendix F, Section 4.1; 40 CFR Section 60.13(d)(1); Minn. R. 7017.1170, subp. 3

Daily Calibration Error (CE) Test: Conduct daily CE testing of each gas monitoring system according to the procedures in Section 6.3.1 of 40 CFR pt. 75, Appendix A and of each flow monitoring system according to the procedures in Section 6.3.2 of

A ppendix A. (Note 40 CFR pt. 60 has a standard regarding this requirement as well.) 40 CFR pt. 75, Appendix B, Section 2.1

CEMS 40 CFR Pt. 60 Cylinder Gas Audit (CGA): Due before the end of each three out of four calendar quarters following Permit Issuance but no more than three quarters in succession. A CGA is not required during any calendar quarter in which a RATA was performed. 40 CFR pt. 60, Appendix F, Section 5.1.2; Minn. R. 7017.1170, subp. 4

40 CFR pt. 75 Linearity and Leak Check Test: due before the end of each QA operating quarter (calendar quarter in which there are at least 168 unit operating hours) following Permit Issuance in accordance with procedures in 40 CFR pt. 75,

A ppendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2. Perform a leak check at least once during each QA operating quarter and no less than 30 days
apart. 40 CFR pt. 75, Appendix B, Sections 2.2.1 & 2.2.2;

Minn. R. 7017.1020

40 CFR pt. 60 CEMS Relative Accuracy Test Audit (RATA): due before end of every one of four calendar quarters following Permit Issuance. (Note 40 CFR pt. 75 has a standard regarding this requirement as well.) 40 CFR pt. 60, Appendix F, Section 5.1.1; Minn. R. 7017.1170, subp. 5

40 CFR pt. 75 CEMS Relative Accuracy Test Audit (RATA): Due before the end of each calendar half-year following Permit Issuance, i.e. once every two successive QA operating quarters (calendar quarters in which there are at least 168 unit operating hours). Conduct a RATA on all CEMS required by the Acid Rain Program in accordance with 40 CFR pt. 75, Appendix B. RATAs may be performed annually, i.e. once every four successive QA operating quarters, rather than once every two successive QA operating quarters if any of the conditions listed in 40 CFR pt. 75,

A ppendix B, Sections 2.3.1.2(a) through 2.3.1.2(i) are met. (Note 40 CFR pt. 60 has a standard regarding this requirement as well.) 40 CFR pt. 75, Appendix B, Section 2.3.1; Minn. R. 7017.1170, subp. 5

RATA Notification: due 30 days before CEMS Relative Accuracy Test Audit (RATA). Minn. R. 7017.1180, subp. 2

Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. (Note: This requirement is the most stringent of all standards cited.) 40 CFR Section 75.57; 40 CFR Section 60.7(f); Minn.

R. 7017.1130

Quarterly Reports: Electronically report the data and information in 40 CFR Section 75.64 (a), (b), and (c) to the Administrator quarterly. 40 CFR Section 75.64; Minn. R. 7017.1110, subps. 1 &

2

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-20

Subject Item: GP 006 Fabric Filter Requirements

Associated Items: CE 016 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 017 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 019 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 020 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 021 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 023 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 024 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 025 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

What to do Why to do it

THE FOLLOWING REQUIREMENTS APPLY TO EACH FABRIC FILTER

INDIVIDUALLY hdr

CONTROL EFFICIENCY REQUIREMENTS hdr

The Permittee shall operate and maintain the control equipment such that it achieves an overall control efficiency for Total Particulate Matter: greater than or equal to 99 percent control efficiency Minn. R. 7007.0800, subp. 2

The Permittee shall operate and maintain the control equipment such that it achieves an overall control efficiency for PM < 10 micron: greater than or equal to 93 percent control efficiency Minn. R. 7007.0800, subp. 2

The Permittee shall operate and maintain the control equipment such that it achieves an overall control efficiency for PM < 2.5 micron: greater than or equal to 54 percent control efficiency Minn. R. 7007.0800, subp. 2

MONITORING AND RECORDKEEPING hdr

Check for visible emissions (during daylight hours) from each fabric filter stack (SV007 for CE016; SV008 for CE017, SV009 for CE 018; SV005 for CE019; SV006 for CE020; SV004 for CE021; SV003 for CE023/CE024; and SV002 for SV025) once during every calendar week of operation. Minn. R. 7007.0800, subp. 4

Recordkeeping of Visible Emissions. The Permittee shall record the time and date of each visible emission inspection, and whether or not any visible emissions were

observed. Minn. R. 7007.0800, subps. 4 and 5

Solid fuel handling equipment shall not be vented to the atmosphere when emissions are not controlled by a fabric filter. Some emission units controlled by equipment in this group are physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. (See Subject Items EU005, EU007, EU008, EU009, EU010, EU011, EU012, and EU013.) Minn. R. 7007.0800, subps. 2 and 14

Periodic Inspections: At least once per calendar quarter, or more frequently as required by the manufacturing specifications, the Permittee shall inspect the control equipment components. The Permittee shall maintain a written record of these inspections. Minn. R. 7007.0800, subps. 4, 5 and 14

Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur:
- visible emissions are observed; or - the fabric filter or any of its components are found during the inspections to need repair. Corrective actions shall eliminate visible emissions, and/or include completion of necessary repairs identified during the inspection, as applicable. Corrective actions include, but are not limited to, those outlined in the O & M Plan for the fabric filter. The Permittee shall keep a record of the type and date of any corrective action

taken for each filter. Minn. R. 7007.0800, subps. 4, 5, and 14

The Permittee shall operate and maintain each fabric filter in accordance with the Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA staff. Minn. R. 7007.0800, subp. 14

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-21

Subject Item: GP 007 Combustion Turbine/Duct Burner Combined Requirments

Associated Items: CE 032 Selective Catalytic Reduction

CE 033 Dry-Low NOx combustion

EU 026 Combustion Turbine (Dry Low NOx Co mbustors & Selective Catalytic Reduction)

EU 027 Duct Burners (Selective Catalytic Reduction)

MR 017 Unit 5/2 NOx Dual Range Monitor

MR 018 Unit 5/2 O2 Monitor

MR 019 Unit 5/2 CO Dual Range Monitor

SV 020 Combustion Turbine w/DLN & SCR; Duct Burners w/SCR

What to do Why to do it

EMISSION LIMITS (See also Subject Items EU026 and EU027 for additional applicable requirements) hdr

Nitrogen Oxides: less than or equal to 4.5 parts per million using 3-hour Block

A verage by volume on a dry basis at 15% oxygen. This limit applies at all times under all operating conditions, except during startup, shutdown, and malfunction.

Each calendar day is composed of eight consecutive 3-hour time blocks starting at midnight. Each 3-hour block average is determined by averaging all 1-minute averages during operation other than startup, shutdown, or malfunction, to determine the 15-minute average. The 15-minute averages are averaged to produce a 1-hour average, and the 1-hour averages are used to calculate the 3-hour block average. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

Nitrogen Oxides: less than or equal to 100 parts per million using 1-Hour Average by volume on a dry basis at 15% oxygen. This limit applies only during startup, shutdown, and malfunction. If the startup process ends with a failed start, then a NOx ppmvd concentration limit does not apply. However, NOx mass emissions (lb/hr) during a failed start are included in the 12-month rolling sum NOx emissions

calculations. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

Nitrogen Oxides: less than or equal to 305 tons/year using 12-month Rolling Sum . This limit applies at all times under all operating conditions, including startup, shutdown, and malfunction. Title I Condition: To avoid the PSD increment significant impact level under 40 CFR Section 52.21;

Minn. R. 7007.3000

Carbon Monoxide: less than or equal to 25 parts per million by volume on a dry basis at 15% oxygen using a 3-hour block average, during operation of EU 026 (combustion turbine) except during startup, shutdown, or malfunction, and EU 027 is in operation during the same 3-hour time block.

Each calendar day is composed of eight consecutive 3-hour time blocks starting at midnight. Each 3-hour block average is determined by averaging all 1-minute averages during operation other than startup, shutdown, or malfunction, to determine the 15-minute average. The 15-minute averages are averaged to produce a 1-hour average, and the 1-hour averages are used to calculate the 3-hour block average. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

Carbon Monoxide: less than or equal to 18 parts per million by volume on a dry basis at 15% oxygen using a 3-hour block average, during operation of EU 026 (combustion turbine) except during startup, shutdown, or malfunction, and EU 027 is not in operation during the same 3-hour time block.

Each calendar day is composed of eight consecutive 3-hour time blocks starting at midnight. Each 3-hour block average is determined by averaging all 1-minute averages during operation other than startup, shutdown, or malfunction, to determine the 15-minute average. The 15-minute averages are averaged to produce a 1-hour average, and the 1-hour averages are used to calculate the 3-hour block average. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

Carbon Monoxide: less than or equal to 400 tons/year using 12-month Rolling Sum . This limit applies at all times under all operating conditions, except during startup

and shutdown. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

PM < 10 micron: less than or equal to 29.4 lbs/hour using 3-hour Average . This limit applies at all times under all operating conditions, except during startup, shutdown, or malfunction. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-22

Volatile Organic Compounds: less than or equal to 0.0073 lbs/million Btu heat input when EU026 (combustion turbine) is operating at or above 70% load, with or without EU027 in operation.

When EU027 is operating simultaneously with EU026, the limit is equal to 17.7 lb/hr; the calculated potential to emit of EU026 and EU027 combined is approximately 17.5 lb/hr.

When only EU026 is operating, the limit is equal to 14.0 lb/hr; the calculated potential to emit of EU026 is approximately 4.8 lb/hr. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

Formaldehyde: less than or equal to 9.0 tons/year using 12-month Rolling Sum . This limit applies at all times under all operating conditions, including startup and

shutdown. Title I Condition: To avoid classification as a major

source under 40 CFR Section 63.2 and Minn. R.

7007.0200

HAPs - Total: less than or equal to 24.0 tons/year using 12-month Rolling Sum . This limit applies at all times under all operating conditions, including during startup

and shutdown. Title I Condition: To avoid classification as a major

source under 40 CFR Section 63.2 and Minn. R.

7007.0200

Startup, Shutdown, and Malfunction have the same meanings as in 40 CFR Section 60.2; see Subject Item EU026 for further startup/shutdown definitions for the combustion turbine. For any emission limit not applicable during startup and shutdown, that limit does not apply:

1. during the initial 180 minutes after fuel combustion commences in the combustion turbine if the steam turbine-generator was offline for less than 12 hours; 2. during the initial 300 minutes after fuel combustion commences in the combustion turbine if the steam turbine-generator was offline for 12 to 60 hours; 3. during the initial 480 minutes after fuel combustion commences in the combustion turbine if the steam turbine-generator was offline for more than 60
hours; 4. during the final 120 minutes of turbine fuel combustion.

Steam turbine-generator online operation of less than 60 minutes duration shall be considered offline for startup determination purposes and is not included in items 1,
2, and 3 above. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

CONTROL REQUIREMENTS (see also Subject Item CE032) hdr

The Permittee shall operate and maintain CE032 at all times that EU026 and/or EU027 is in operation. The Permittee shall document periods of non-operation of the control equipment. Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R. 7007.3000; To avoid the PSD increment significant impact level under 40 CFR Section 52.21; Minn. R. 7007.0800, subps. 2 and 14

MONITORING AND RECORDKEEPING REQUIREMENTS (see also Subject Item GP005) hdr

Measure or calculate SO2 and CO2 emission rates for EU026 and EU027 in

accordance with 40 CFR Section 75. 40 CFR Section 75.10; Minn. R. 7007.0800, subp. 4

Emissions Monitoring: The owner or operator shall use a NOX CEMS to measure NOX emissions from SV020. Additional monitoring requirements are also located at Subject Item GP005. Title I Condition: To avoid the PSD increment significant impact level under 40 CFR Section 52.21; Minn. R. 7007.3000; 40 CFR Section 60.334(c); 40 CFR Section 72.9(b); Minn. R. 7017.1006; Minn. R. 7017.1010, subp. 1; Minn. R. 7011.2350; Minn. R.

7011.0560

Emissions Monitoring: The owner or operator shall use a CO CEMS to measure CO emissions from SV020. Additional monitoring requirements are also located at Subject Item GP005. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

Operating Load and Operating Conditions Monitoring: Continuously monitor (at the same frequency as the CO monitor sampling rate) and record the heat input (mmBtu/hr) for EU026 and EU027 using the method specified at 40 CFR Part 75,

A ppendix F.

Calculate and record the average hourly operating load as a percent of maximum possible load for the specific compressor inlet conditions.

Monitor and record the times and duration of any "off normal" operating condition (startup, shutdown, or malfunction) defined above.

Record the start and stop time of all steam turbine-generator on-line and off-line operation. Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R. 7007.3000; Minn. R. 7007.0800, subp. 4

By the 15th day of each month, calculate and record monthly NOX emissions and the annual 12-month rolling sum. The rolling sum shall be calculated by adding the current month's emission totals with those for the previous 11 months. Minn. R. 7007.0800, subps. 4 and 5

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-23

By the 15th day of each month, calculate and record monthly CO emissions and the annual 12-month rolling sum. The rolling sum shall be calculated by adding the current month's emission totals with those for the previous 11 months. Minn. R. 7007.0800, subps. 4 and 5

By the 15th day of each month, calculate and record monthly and annual 12 month rolling sum formaldehyde and total HAPs emissions using emission factors from the latest stack test results. Prior to emissions testing, and for HAPs that are not stack tested, emission factors from the latest AP-42 section addressing emissions from combustion turbines and gas fired boilers shall be used.

A fter establishing emission factors for formaldehyde at four load levels, the factor (lbs/mmBtu) established for the gas turbine (EU 026) operating between one of the three test loads shall be used for all gas turbine operation below the next higher test load range (i.e. factor established at 30-40% load shall be used for all loads under 50% of full load). The combined (EU 026 and EU 027) emission factor established at 90-100% of full load shall be used for all operation, combined or not, greater than or equal to 90% of full load. Minn. R. 7007.0800, subps. 4 and 5

The calculation and record keeping requirement listed above shall not apply to SV 020 if the agency approved performance test for formaldehyde emissions proves that the formaldehyde emission rate is less than or equal to 2.0 lbs/hr at all four test

ranges. Minn. R. 7007.0800, subps. 4 and 5

PERFORMANCE TESTING hdr

Performance Test: due before end of each 60 months starting 07/02/2002 to

measure PM10 emissions. Title I Condition: 40 CFR Section 52.21 BACT Limit and Minn. R. 7007.3000; Minn. R. 7017.2020, subp. 1

Performance Test: due before end of each 60 months starting 07/02/2002 to

measure VOC emissions. Title I Condition: 40 CFR Section 52.21 BACT Limit and Minn. R. 7007.3000; Minn. R. 7017.2020, subp. 1

Formaldehyde Emission Factor/Rate Testing: Emission factors and rates shall be determined by using Agency approved stack test methods at the following loads and operating conditions with the SCR system online:

1. EU 026 operating at 30 to 40 percent of full load. 2. EU 026 operating at 50 to 60 percent of full load. 3. EU 026 operating at 70 to 80 percent of full load. 4. EU 026 and EU 027 combined operating at 90 to 100 percent of full load.

A t the time of issuance of PER011, the formaldehyde emission factors based on the tests completed July 2, 2002 (100%, 70%, and 50% loads) and November 11, 2002, (40% load) are as follows:

100% load: 0.045 lb/hr

70% load: 0.038 lb/hr

50% load: 0.223 lb/hr

40% load: 15.1 lb/hr Title I Condition: To avoid classification as a major

source under 40 CFR Section 63.2 and Minn. R. 7007.0200; Minn. R. 7007.0800, subp. 4

Testing Frequency to Update Formaldehyde Emission Factors:

Within 60 days of calculating 12-month rolling sum formaldehyde emissions of greater than 8.9 tons, perform a stack test to redevelop emission factors for formaldehyde emissions over the previously tested load ranges. Title I Condition: To avoid classification as a major

source under 40 CFR Section 63.2 and Minn. R. 7007.0200; Minn. R. 7007.0800, subp. 4

RECORDKEEPING hdr

Recordkeeping: Maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of the facility including malfunction of the air pollution control equipment or any periods during which a continuous monitoring system or monitoring device is inoperative. Minn. R. 7007.0800, subp. 5

Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. Minn. R. 7017.1130

SUBMITTALS AND REPORTS hdr

Excess emissions and monitoring system performance reports shall include the information required in 40 CFR Section 60.7(c) and (d), Section 60.49a and Section 60.334(j). MPCA Forms DRF-1 and DRF-2 may be used to meet this requirement. Minn. R. 7007.0800, subp. 2; 40 CFR Section 60.7, Section 60.49a and Section 60.334(j)

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-24

Subject Item: GP 008 Acid Rain Affected Sources

Associated Items: EU 003 Boiler 3

EU 004 Boiler 4

EU 026 Combustion Turbine (Dry Low NOx Co mbustors & Selective Catalytic Reduction)

What to do Why to do it

A CID RAIN REQUIREMENTS (see also Appendix E) hdr

Comply with the applicable Acid Rain emissions limitation for sulfur dioxide. 40 CFR Section 72.9(c)(1)(ii); 40 CFR Section 72.9(g)(4)

Hold allowances as of the allowance transfer deadline, in the unit's compliance subaccount, not less than the total annual emissions of sulfur dioxide for the previous calendar year. Allowances shall be held in, deducted from, or transferred among Allowance Tracking System accounts in accordance with the Acid Rain Program. 40 CFR Section 72.9(c)(1)(i); 40 CFR Section 72.9(g)(4)

If a unit has excess emissions, the designated representative shall submit a proposed offset plan in accordance with 40 CFR Section 72.9(e). 40 CFR Section 72.9(e)

Certify Acid Rain Program submittals. Each submission under the Acid Rain Program shall be submitted, signed, and certified by the designated representative or the alternative designated representative for all sources on behalf of which the

submission is made in accordance with 40 CFR Section 72.21. 40 CFR Section 72.21; 40 CFR Section 72.22

Keep on site or readily accessible at another site each of the following documents for a period of 5 years from the date the document is created: - The certificate of representation, - All emission monitoring information, - Copies of all reports, compliance certifications, and other submissions or records made under the Acid Rain Program, and - Copies of all documents used to complete an acid rain permit application. 40 CFR Section 72.9(f)(1)

A pply for Acid Rain Program Permit reissuance: The designated representative shall submit a complete Acid Rain permit application for each source with an affected unit at least 6 months prior to the expiration of an existing Acid Rain Permit in accordance with 40 CFR Section 72.30(c). 40 CFR Section 72.30(c)

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-25

Subject Item: SV 006 Breaker Bldg. (EU 009 and EU 010) Stack

Associated Items: EU 009 Transfer Tower

EU 010 Breakers (Crushing)

What to do Why to do it

Check for visible emissions from the SV 006 control equipment (DC-952/CE 020). This must be done once per calendar week, if EU009 and/or EU010 is operated during that calendar week. This must be done during daylight hours, while EU009 and/or EU010 is operating. Minn. R. 7007.0800, subp. 4

The Pemittee shall record each the date and time of each visible emission check,

and whether visible emissions were observed. Minn. R. 7007.0800, subp. 5

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-26

Subject Item: EU 005 200 Ton Stacking Hopper

Associated Items: CE 025 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 002 Stacking Hopper (EU 005) Stack

What to do Why to do it

EMISSION LIMITS hdr

PM < 10 micron: less than or equal to 0.6 lbs/hour . Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.27 lbs/hour. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

If exhaust gases from any enclosed coal handling facility exceed 20 percent opacity, then the owner or operator of such facility shall select and implement one of the following further controls: (1) install exhaust air system and control exhaust gases so that particulate emissions in such gases do not exceed 0.020 gr/dscf; (2) control exhaust gases using dust suppression methods so that particulate emissions do not exhibit Opacity: greater than or equal to 20 percent opacity Minn. R. 7011.1105 (G)

CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) hdr

EU005 shall not be vented to the atmosphere when emissions are not controlled by CE025. EU005 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. Minn. R. 7007.0800, subps. 2 and 14

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-27

Subject Item: EU 006 Dumper Unloading Bldg

Associated Items: CE 023 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 024 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 003 Dumper Building (EU 006) Stack

What to do Why to do it

EMISSION AND OPERATING LIMITS hdr

PM < 10 micron: less than or equal to 1.0 lbs/hour . Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.03 lbs/hour. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

Operating Hours: less than or equal to 12.5 hours/day Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

Total Particulate Matter: greater than or equal to 0.020 grains/dry standard cubic foot , or Opacity: less than or equal to 20% opacity, from unloading railcars. Railcars must be unloaded within a permanent structure. Minn. R. 7011.1105 (H)

Truck and Hauler Unloading Stations: Control fugitive particulate emissions from the unloading of truck or haulers by dust suppression methods so that emissions from such sources are minimized. Control emissions by unloading reclaimed coal within a partial enclosure and with fabric filters. Minn. R. 7011.1105 (C)

Recordkeeping: Record the train dumping start and stop times during every day of coal throughput operation. Minn. R. 7007.0800, subp. 5

CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) hdr

The Permittee shall operate and maintain CE023 and CE024 at all times that EU006 is in operation. Minn. R. 7007.0800, subps. 2 and 14

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-28

Subject Item: EU 007 Yard Agglomerator Silo

Associated Items: CE 021 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 004 Yard Agglomerator (EU 007) Stack

What to do Why to do it

EMISSION LIMITS hdr

Opacity: less than 20 percent opacity 40 CFR Section 60.252(c); Minn. R. 7011.1150

PM < 10 micron: less than or equal to 0.01 grains/dry standard cubic foot Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.01 grains/dry standard cubic foot , equivalent to approximately 0.051 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.0004 lbs/hour. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) hdr

EU007 shall not be vented to the atmosphere when emissions are not controlled by CE021. EU007 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. Minn. R. 7007.0800, subps. 2 and 14

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-29

Subject Item: EU 008 Breaker Building (Coal Conveying)

Associated Items: CE 019 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 005 Breaker Bldg. (EU 008) Stack

What to do Why to do it

EMISSION LIMITS hdr

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 1.7 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.075 lbs/hour. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) hdr

EU008 shall not be vented to the atmosphere when emissions are not controlled by CE019. EU008 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. Minn. R. 7007.0800, subps. 2 and 14

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-30

Subject Item: EU 009 Transfer Tower

Associated Items: CE 020 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 006 Breaker Bldg. (EU 009 and EU 010) Stack

What to do Why to do it

EMISSION LIMITS hdr

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 0.56 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.03 lbs/hour. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) hdr

EU009 shall not be vented to the atmosphere when emissions are not controlled by CE020. EU009 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. Minn. R. 7007.0800, subps. 2 and 14

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-31

Subject Item: EU 010 Breakers (Crushing)

Associated Items: CE 020 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 006 Breaker Bldg. (EU 009 and EU 010) Stack

What to do Why to do it

EMISSION LIMITS hdr

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 0.56 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.02 lbs/hour. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) hdr

The Permittee shall operate and maintain CE020 at all times that EU010 is in operation. The Permittee shall document periods of non-operation of the control equipment.

EU010 shall not be vented to the atmosphere when emissions are not controlled by CE020. EU010 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. Minn. R. 7007.0800, subps. 2 and 14

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-32

Subject Item: EU 011 Tripper Area (Conveyors D and F)

Associated Items: CE 016 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 007 Tripper Area (EU 011) Stack

What to do Why to do it

EMISSION LIMITS hdr

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 1.2 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.05 lbs/hour. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) hdr

EU011 shall not be vented to the atmosphere when emissions are not controlled by CE016. EU011 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. Minn. R. 7007.0800, subps. 2 and 14

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-33

Subject Item: EU 012 Unit 3 Coal Silo

Associated Items: CE 017 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 008 Unit 3 Coal Silos (EU 012)

What to do Why to do it

EMISSION LIMITS hdr

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 0.54 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.02 lbs/hour. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) hdr

EU012 shall not be vented to the atmosphere when emissions are not controlled by CE017. EU012 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. Minn. R. 7007.0800, subps. 2 and 14

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-34

Subject Item: EU 013 Unit 4 Coal Silo

Associated Items: CE 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 009 Unit 4 Coal Silos (EU 013)

What to do Why to do it

EMISSION LIMITS hdr

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot Minn. R. 7011.1105 (G)

PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot , equivalent to approximately 0.81 lb/hour based on maximum air flow. Potential emissions of this unit, based on unit capacity, AP-42 emission factors, and proper operation of control equipment, is approximately 0.02 lbs/hour. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

CONTROL REQUIREMENTS (see Subject Item GP006 for specific operating requirements) hdr

EU013 shall not be vented to the atmosphere when emissions are not controlled by CE018. EU013 is physically capable of operating without venting to the atmosphere, and therefore can operate when control equipment is not operational. Minn. R. 7007.0800, subps. 2 and 14

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-35

Subject Item: EU 019 Units 3 and 4 Fly Ash Silo Vent

Associated Items: CE 006 Electrostatic Prec ipitator - High Efficiency

CE 007 Electrostatic Prec ipitator - High Efficiency

CE 008 Electrostatic Prec ipitator - High Efficiency

CE 009 Electrostatic Prec ipitator - High Efficiency

SV 001 Main Stack for Boilers 3 and 4

What to do Why to do it

Total Particulate Matter: less than or equal to 0.30 grains/dry standard cubic foot of exhaust gas unless required to further reduce emissions to comply with the less stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735. EU019 is controlled by control equipment which has a collection efficiency of 99.7 percent by weight. EU019 is considered to be in compliance with this requirement. Minn. R. 7011.0715, subp. 1(A)

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.0715, subp. 1(B)

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-36

Subject Item: EU 026 Combustion Turbine (Dry Low NOx Combustors & Selective Catalytic Reduction)

Associated Items: CE 032 Selective Catalytic Reduction

CE 033 Dry-Low NOx combustion

GP 007 Combustion Turbine/Duct Burner Combined Requirments

GP 008 Acid Rain Affected Sources

SV 020 Combustion Turbine w/DLN & SCR; Duct Burners w/SCR

What to do Why to do it

EMISSION LIMITS hdr

Nitrogen Oxides: less than or equal to 110 parts per million using a 4-hour rolling average by volume at 15% O2 on a dry basis and assuming a fuel-bound content of zero. Applies at all times except during startup, shutdown, or malfunction. Startup for purposes of this limit shall not exceed 1 hour. Shutdown for purposes of this

limit shall not exceed 30 minutes. 40 CFR Sections 60.332(a)(1) and 60.334(j)(1)(iii)(A);

Minn. R. 7011.2350

Sulfur Dioxide: less than or equal to 0.15 percent by volume at 15 percent oxygen and on a dry basis. 40 CFR Section 60.333(a); Minn. R. 7011.2350

OPERATIONAL REQUIREMENTS hdr

Startup and Shutdown: Not to exceed 1250 hours per year on a 12-month rolling

sum basis. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

EU026 Startup and Shutdown: In addition to the definition in 40 CFR Section 60.2, startup is defined as all EU026 operation at less than 70% capacity (for the specific combustion turbine compressor inlet conditions during operation) prior to initially attaining 70% load. EU026 startup ends no later than 15 minutes after EU026 first attains 70% load after startup commences.

In addition to the definition in 40 CFR Section 60.2, shutdown is defined as all EU026 operation at less than 70% load that is part of the process that terminates EU026 fuel combustion until the next EU026 startup. Shutdown does not include temporary operating loads below 70% for up to 15 consecutive minutes, due to external factors such as changes in compressor inlet conditions.

(continued below) Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

EU026 Startup and Shutdown (continued from above):

The CEMS data acquisition and handling system monitors EU026 load (using a signal provided by the combustion turbine generator control system) and indicates whether EU026 is operating in normal mode or startup/shutdown mode. The percent load signal is also used by the CEMS to determine whether emissions data is categorized as normal emissions data or startup/shutdown emissions data. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

Sulfur Content of Fuel: less than or equal to 0.004 grains/dry standard cubic foot using 12-month Rolling Average Title I Condition: To avoid classification as a major

modification under 40 CFR Section 52.21 and Minn. R.

7007.3000

Sulfur Content of Fuel: less than or equal to 0.8 percent by weight 40 CFR 60.333(b); Minn. R. 7011.2350

Fuel usage is limited to pipeline quality natural gas. Title I Condition: To avoid classification as a major

modification under 40 CFR Section 52.21 and Minn. R.

7007.3000

MONITORING, TESTING, RECORDKEEPING AND REPORTING REQUIREMENTS (see also Subject Item GP007) hdr

The Permittee need not monitor the total sulfur content of the gaseous fuel combusted in the turbine, if the gaseous fuel is demonstrated to meet the definition of natural gas in 40 CFR Section 60.331(u). The Permittee shall use one of the following sources of information to make the required demonstration:

(i) The gas quality characteristics in a current, valid purchase contract, tariff sheet or transportation contract for the gaseous fuel, specifying that the maximum total sulfur content of the fuel is 20.0 grains/100 scf or less; or

(ii) Representative fuel sampling data which show that the sulfur content of the gaseous fuel does not exceed 20 grains/100 scf. At a minimum, the amount of fuel sampling data specified in section 2.3.1.4 or 2.3.2.4 of appendix D to 40 CFR part 75 is required. 40 CFR Section 60.334(h)(3); Minn. R. 7011.2350

Maintain records of the demonstration that the gaseous fuel used meets the definition of natural gas in 40 CFR Section 60.31(u). Minn. R. 7007.0800, subp. 5

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-37

Daily Startup and Shutdown Operating Hours Monitoring and Recordkeeping: Once each day the Permittee shall calculate and record EU 026 startup and shutdown operating hours for the previous calendar day.

Startup and shutdown operating hours shall be determined using the electronic data produced by instrumentation that instantaneously measures EU 026 gross electric power output. Title I Condition: 40 CFR Section 52.21(j) (BACT) and Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 4 and

5

Monthly Startup and Shutdown Operating Hours Monitoring and Recordkeeping: By the 15th day of each month, the Permittee shall calculate and record the total EU 026 startup and shutdown operating hours for the previous month and for the previous 12-month period. Minn. R. 7007.0800, subps. 4 and 5

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-38

Subject Item: EU 027 Duct Burners (Selective Catalytic Reduction)

Associated Items: CE 032 Selective Catalytic Reduction

GP 007 Combustion Turbine/Duct Burner Combined Requirments

SV 020 Combustion Turbine w/DLN & SCR; Duct Burners w/SCR

What to do Why to do it

EMISSION LIMITS hdr

Sulfur Dioxide: less than or equal to 0.20 lbs/million Btu heat input using 30-day Rolling Average . This limit applies at all times except during periods of startup, shudown, or malfunction. Potential emissions based on combustion of natural gas at equipment capacity is approximately 0.0006 lb/MMBtu. 40 CFR Section 60.43Da(b)(2); 40 CFR Section 60.43Da(g); 40 CFR Section 60.48Da(a); Minn. R.

7011.0560

Nitrogen Oxides: less than or equal to 1.6 lbs/megawatt-hour using 30-day Rolling

A verage (gross energy output). This limit applies at all times except during periods of startup, shudown, or malfunction. 40 CFR Section 60.44Da(d)(1); 40 CFR Section 6.48Da(a); Minn. R. 7011.0560

OPERATIONAL REQUIREMENTS hdr

Operating Hours: less than or equal to 1500 hours/year using 12-month Rolling

Sum Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

Sulfur Content of Fuel: less than or equal to 0.004 grains/dry standard cubic foot using 12-month Rolling Average Title I Condition: To avoid classification as a major

modification under 40 CFR Section 52.21 and Minn. R.

7007.3000

Fuel usage is limited to pipeline quality natural gas. Title I Condition: To avoid classification as a major

modification under 40 CFR Section 52.21 and Minn. R.

7007.3000

MONITORING, TESTING, RECORDKEEPING AND REPORTING REQUIREMENTS (see also Subject Item GP007) hdr

Daily Recordkeeping. On each day of operation, the Permittee shall calculate, record, and maintain the EU027 operating hours. Title I Condition: 40 CFR Section 52.21(j) (BACT) and

Minn. R. 7007.3000

Monthly Recordkeeping -- Hours of operation

By the 15th of the month, the Permittee shall calculate and record the following:

1) The total hours of operation for the previous calendar month using the daily
records; and

3) The 12-month rolling sum of operating hours for the previous 12-month period by summing the monthly operating hours for the previous 12 months. Minn. R. 7007.0800, subps. 4 and 5

The Permittee shall determine the mass rate (lb/h) of NOX emissions by installing, operating, and maintaining continuous fuel flowmeters following the appropriate measurements procedures specified in appendix D of 40 CFR Part 75. The emission rate (E) of NOX shall be computed using the following equation:

E = (ER x H) / O

Where:

E = Emission rate of NOX from the duct burner, in lb/MWh gross energy output

ER = Average hourly emission rate of NOX exiting the steam generating unit heat input calculated using appropriate F factor as described in Method 19 of appendix

A of 40 CFR Part 60, in lb/MMBtu

H = Average hourly heat input rate of entire combined cycle unit, in MMBtu/h

O = Average hourly gross energy output from entire combined cycle unit, in MW 40 CFR Section 60.48Da(k)(2)(iv); Minn. R. 7011.0560

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-39

Subject Item: EU 028 Fire Pump

Associated Items: SV 021 Fire Pump

What to do Why to do it

EMISSION AND OPERATING LIMITS hdr

Opacity: less than or equal to 20 percent opacity once operating temperatures have

been attained. Minn. R. 7011.2300, subp. 1

Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input . The potential to emit from the unit is 0.05 lb/MMBtu due to equipment design and allowable fuel. Minn. R. 7011.2300, subp. 2

Sulfur Content of Fuel: less than or equal to 0.050 percent by weight Minn. R. 7007.0800, subps. 4 & 5

Fuel type: Distillate fuel oil only, by design Minn. R. 7005.0100, subp. 35a

Fuel Supplier Certification: The Permittee shall obtain supplier certification that the sulfur content does not exceed 0.050 % by weight. The certification shall be a single certification from the fuel oil supplier guaranteeing a maximum sulfur content in all fuel oil deliveries thereafter. The single certification shall also state that the supplier will notify the Permittee in writing on the date of delivery of fuel oil with a sulfur content exceeding the guaranteed maximum, that the fuel oil sulfur content exceeds the guaranteed maximum value.

The Permittee may instead choose to test the oil in the storage tank following each shipment, according to current ASTM or EPA methods and keep records of lab analyses of sulfur content. Minn. R. 7007.0800, subps. 4 & 5

Hours of Operation: The Permittee shall maintain documentation on site that the unit is an emergency generator by design that qualifies under the U.S. EPA memorandum entitled "Calculating Potential to Emit (PTE) for Emergency Generators" dated September 6, 1995, limiting operation to 500 hours per year. Minn. R. 7007.0800, subps. 4 & 5

NESHAP SUBPART ZZZZ REQUIREMENTS hdr

The Permittee shall comply with the applicable parts of Subpart ZZZZ by May 3,

2013. 40 CFR Section 63.6595(a)(1); Minn. R. 7011.8150

The Permittee shall at all times operate and maintain the engine, including any associated air pollution control equipment or monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require any further efforts to reduce emissions if levels required by Subpart ZZZZ have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the

source. 40 CFR Section 63.6605(b); Minn. R. 7011.8150

The Permittee shall meet the following requirements:

a. Change oil and filter every 500 hours of operation or annually, whichever comes
first;

b. Inspect air cleaner every 1,000 hours of operation or annually, whichever comes first;

c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace as necessary. 40 CFR Section 63.6602; 40 CFR 63 Subpart ZZZZ Table 2C; Minn. R. 7011.8150

During periods of startup, the Permittee shall minimize the engine's time spent at idle and minimize the engine's startup time at startup to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the non-startup emission limits apply. 40 CFR Section 63.6602; 40 CFR Section 63.6625(h); 40 CFR 63 Subpart ZZZZ Table 2C; Minn. R.

7011.8150

The Permittee has the option of utilizing an oil analysis program in order to extend the specified oil change requirement in Table 2C to Subpart ZZZZ. The oil analysis must be performed at the same frequency specified in Table 2C. The analysis program must at a minimum analyze the Total Base Number, viscosity, and percent water content. The condemning numbers for these paramenters are as follows: Total Base Number is less than 30 percent of the Total Base Number of the oil when new; viscosity of the oil has changed by more than 20 percent from the viscosity of the oil when new; or percent water content (by volume) is greater than 0.5. If none of the condemning values are exceeded, the Permittee is not required to change the oil.

(continued below) 40 CFR Section 63.6625(i); 40 CFR 63 Subpart ZZZZ Table 2C; Minn. R. 7011.8150

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-40

(continued from above)

If any of the condemning limits are exceeded, the Permittee shall change the oil within 2 days of receiving the results of the analysis; if the engine is not in operation when the results are received, the Permittee shall change the oil within 2 days or before commencing operation, whichever is later. The Permittee shall keep records of the parameters that are analyzed as part of the program, the results of the analysis, and the oil changes for the engine. The analysis program must be part of the maintenance plan for the engine. 40 CFR Section 63.6625(i); 40 CFR 63 Subpart ZZZZ Table 2C; Minn. R. 7011.8150

The Permittee shall operate and maintain the engine and after-treatment control devide (if any) according to the manufacturer's emission-related written instructions or develop a maintenance plan which must provide to the extent practicable for the maintenance and operation of the engine in a manner consist with good air pollution control practice for minimizing emissions. 40 CFR Section 63.6625(e); Minn. R. 7011.8150

The Permittee shall install a non-resettable hour meter if one is not already

installed. 40 CFR Section 63.6625(f); Minn. R. 7011.8150

The Permittee shall be in continuous compliance with the applicable requirements of Table 2C to Subpart ZZZZ. 40 CFR Section 63.6640(a); Minn. R. 7011.8150

The Permittee shall report each instance in which the applicable operating limitation was not met. These instances are deviations from the operating limitations in Subpart ZZZZ. These deviations shall be reported according to the requirements of 40 CFR Section 63.6650. 40 CFR Section 63.6640(b); Minn. R. 7011.8150

The Permittee shall operate the emergency engine according to the requirements in items (i) through (iii) below. Any operation other than emergency operation, maintenance and testing, and operation in non-emergency situations for 50 hours per year, as described in items (i) through (iii), is prohibited. If the engines is not operated according to the requirements in items (i) through (iii), the engine will not be considered an emergency engine under this subpart and will need to meet all requirements for non-emergency engines.

(continued below) 40 CFR Section 63.6640(f)(1); Minn. R. 7011.8150

(continued from above)

(i) There is no time limit on the use of emergency stationary RICE in emergency

situations.

(ii) The Permitee may operate the emergency engine for the purpose of maintenance checks and readiness testing, provided that the tests are recommended by Federal, State or local government, the manufacturer, the vendor, or the insurance company associated with the engine. Maintenance checks and readiness testing of such units is limited to 100 hours per year. The Permittee may petition the Administrator for approval of additional hours to be used for maintenance checks and readiness testing, but a petition is not required if the owner or operator maintains records indicating that Federal, State, or local standards require maintenance and testing of emergency RICE beyond 100 hours

per year.

(continued below) 40 CFR Section 63.6640(f)(1); Minn. R. 7011.8150

(continued from above)

iii) The Permittee may operate the emergency engine up to 50 hours per year in non-emergency situations, but those 50 hours are counted towards the 100 hours per year provided for maintenance and testing. The 50 hours per year for non-emergency situations cannot be used for peak shaving or to generate income for a facility to supply power to an electric grid or otherwise supply power as part of a financial arrangement with another entity; except that the Permittee may operate the emergency engine for a maximum of 15 hours per year as part of a demand response program if the regional transmission organization or equivalent balancing authority and transmission operator has determined there are emergency conditions that could lead to a potential electrical blackout, such as unusually low frequency, equipment overload, capacity or energy deficiency, or unacceptable voltage level.

(continued below) 40 CFR Section 63.6640(f)(1); Minn. R. 7011.8150

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-41

(continued from above)

The engine may not be operated for more than 30 minutes prior to the time when the emergency condition is expected to occur, and the engine operation must be terminated immediately after the facility is notified that the emergency condition is no longer imminent. The 15 hours per year of demand response operation are counted as part of the 50 hours of operation per year provided for non-emergency situations. The supply of emergency power to another entity or entities pursuant to financial arrangement is not limited by this paragraph (f)(1)(iii), as long as the power provided by the financial arrangement is limited to emergency power. 40 CFR Section 63.6640(f)(1); Minn. R. 7011.8150

The Permittee shall keep records of the maintenance conducted on the stationary RICE in order to demonstrate that the engine and after-treatment control device (if any) was operated and maintained according to the maintenance plan. 40 CFR Section 63.6655(e); Minn. R. 7011.8150

The Permittee shall keep records of all engine operating hours, and record whether the use was emergency operation, maintenance and testing, or non-emergency operation. Minn. R. 7007.0800, subp. 5

Records shall be in a form suitable and readily available for expeditious review according to 40 CFR Section 63.10(b)(1).

Each record shall be kept for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. Each record shall be accessible in hard copy or electronic form. 40 CFR Section 63.6660(a)-(c); Minn. R. 7011.8150

The following parts of the General Provisions apply: 63.1, 63.2, 63.3, 63.4, 63.5, 63.6(a), 63.6(c)(1)-(2), 63.6(f)(2)-(3), 63.6(g)(1)-(3), 63.6(i), 63.6(j), 63.7(a)(3), 63.8(a)(1), 63.8(b)(1), 63.9(a), 63.10(a), 63.10(b)(1), 63.10(b)(2)(vi)-(xii), 63.10(b)(2)(xiv), 63.10(b)(3), 63.12, 63.13, 63.14, 63.15. 40 CFR Section 63.6665; Minn. R. 7011.8150

The Permittee shall report each instance in which the applicable General
Provisions, listed above, were not met. 40 CFR Section 63.6640(e); Minn. R. 7011.8150

TEMPORARY REPLACEMENT hdr.

Temporary replacement conditions: The Permittee may temporarily replace EU028, provided the following conditions

are met: 1) The potential emissions of the replacement unit (assuming all enforceable limits imposed through this permit, and aggregated if more than one engine and/or boiler is simultaneously replaced; see GP001) are less than all of the following: 25 tpy PM, 15 tpy PM < 10 microns, 10 tpy PM < 2.5 microns, 40 tpy VOC, 40 tpy SO2, 40 tpy NOx, 100 tpy CO, 75000 tpy CO2e;

2) The permitee must calculate the allowable potential to emit of each temporary replacement engine assuming operating conditions that are enforceable by this permit. For pollutants not specifically limited by a permit or rule, the permitee may use emission factors generated based on the temporary replacement engine manufacturer's performance tests.

3) The capacity of the replacement unit is less than or equal to the capacity of
EU028; Title I Condition: To avoid classification as major

modification under 40 CFR Section 52.21 and Minn. R. 7007.3000; 40 CFR Section 60.4200(e). Minn. R. 7005.0100 subp. 35a; 7007.1200 subp. 3; 7007.1450;

7007.1250 and 7007.0800.

Continued from above:

4) The project can only be the temporary replacement of the internal combustion engine for the purpose of providing emergency electrical power at the facility;

5) Emissions and operating hours are tracked and calculated as specified in this permit;

6) The replacement engine may only replace EU028 when EU028 is temporarily out of service for less than one year;

7) The equipment must meet all other requirements for EU028 OR the replacement engine may not be on site for more than 1 year and must meet the conditions for temporary replacement units under 40 CFR Section 60.4200(e); and Title I Condition: To avoid classification as major

modification under 40 CFR Section 52.21 and Minn. R. 7007.3000; 40 CFR Section 60.4200(e). Minn. R. 7005.0100 subp. 35a; 7007.1200 subp. 3; 7007.1450;

7007.1250 and 7007.0800.

Continued from above:

8) Prior to making such a change, the permittee shall apply for and obtain the appropriate permit amendment as applicable. The permittee is not required to complete emission calculations described in Minn. R. 7007.1200 subp. 2. A permit will still be needed regardless of the emissions increase if the change will be subject to a new applicable requirement or requires revisions to the limits or monitoring and recordkeeping in this permit. Title I Condition: To avoid classification as major

modification under 40 CFR Section 52.21 and Minn. R. 7007.3000; 40 CFR Section 60.4200(e). Minn. R. 7005.0100 subp. 35a; 7007.1200 subp. 3; 7007.1450;

7007.1250 and 7007.0800.

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-42

The replacement engine may not be operated at the same time as EU028, except for up to 8 hours during start-up and shutdown transition periods. Title I Condition: To avoid classification as major

modification under 40 CFR Section 52.21 and Minn. R.

7007.3000

If the replacement engine does not require a permit amendment, the Permittee shall keep the following records on site for each replacement engine: - Records required by Minn. R. 7007.1200, subp. 4; - The dates the temporary engine was installed, started operation, and was
removed; - Filled form GI05B for each replacement engine with an assigned consecutive
emission unit number; - A unique identification for the unit, such as make, model, and serial number; - Rated capacity and type of engine; - Dates and hours of operation of the engine; - A statement of all periods of operation during which EU028 is not also operating;

and - Calculations of the potential to emit of the engine and emission changes pursuant to Minn. R. 7007.1200 subpart 3. Title I Condition: To avoid classification as a major

modification under 40 CFR Section 52.21 and Minn. R. 7007.3000; Minn. R. 7007.0800, subp. 5; Minn. R. 7007.1200, subp. 4

The Permittee shall notify the MPCA if the replacement engine is operated simultaneously with EU028, except as allowed by this permit. Make verbal notification within 2 days, and written notification with the semi-annual deviations
report. Minn. R. 7007.0800, subp. 5; Minn. R. 7007.1200, subp. 4

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-43

Subject Item: CE 032 Selective Catalytic Reduction

Associated Items: EU 026 Combustion Turbine (Dry Low NOx Co mbustors & Selective Catalytic Reduction)

EU 027 Duct Burners (Selective Catalytic Reduction)

GP 007 Combustion Turbine/Duct Burner Combined Requirments

What to do Why to do it

A . OPERATING REQUIREMENTS hdr

Operate and maintain CE032 at all times that EU026 and EU027 are in operation except during times of start-up, shutdown, or malfunction (as defined in EU026 and EU027).

A t all times, the Permittee shall maintain documentation of the operation of CE032, and have it available for review at the stationary source. Title I Condition: 40 CFR Section 52.21(j) (BACT); Minn. R. 7007.3000; Minn. R. 7007.0800, subps. 2 and

14

The Permittee shall operate and maintain the SCR in accordance with the Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA staff. 40 CFR Section 64.7(b); Minn. R. 7017.0200; Minn. R. 7007.0800, subp. 14

SCR Monitoring: The total NOx as NO2 CEMS (MR017) shall be used to assess proper operation of the SCR 40 CFR Section 64.7(a); Minn.R. 7017.0200; Minn. R. 7007.0800, subp. 2

Nitrogen Oxides: less than or equal to 4.5 parts per billion on an instantaneous

basis. NOX emissions in excess of this threshold shall be considered an excursion under 40 CFR Section 64.6(c)(2), for purposes of the NOX limits under EU026, EU027, and SV020. This applies for all types and qualities of fuel burned. 40 CFR Section 64.3; Minn. R. 7017.0200

Monitoring Equipment: The Permittee shall install and maintain the necessary monitoring equipment for measuring and recording ammonia injection rate as required by this permit. The monitoring equipment must be installed, in use, and properly maintained when the SCR is in operation. 40 CFR Section and 64.7(b); Minn. R. 7017.0200; Minn. R. 7007.0800, subp. 4

B. MONITORING AND RECORDKEEPING REQUIREMENTS hdr

Continuous Monitoring: The permitee shall monitor continuously, or at a minimum once every 15 minutes, monitor the total NOx as NO2 emissions in the exhaust.

See Subject Item GP005 and Table B for specific CEMs operating requirements. CFR Section 64.3(b)(4)(ii); Minn. R. 7017.0200

Periodic Inspections: At least semiannually, or more frequently as required by the manufacturing specifications, the Permittee shall inspect the control equipment components. The Permittee shall maintain a written record of these inspections. 40 CFR Section 64.3; Minn. R. 7017.0200; Minn. R. 7007.0800, subps. 4, 5 & 14

Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur:

- The alarm is triggered for instantaneous NOX emissions of 4.5 ppm, outside of startup or shutdown; or - The SCR or any of its components are found during the inspections to need repair.

Corrective actions shall return NOX emissions to within the permitted range, and/or include completion of necessary repairs identified during the inspection, as applicable. Corrective actions include, but are not limited to, those outlined in the O&M Plan for the SCR. The Permittee shall keep a record of the type and date of any corrective action taken for the SCR. 40 CFR Section 64.7(d); Minn. R. 7017.0200; Minn. R. 7007.0800, subps. 4, 5, & 14

Documentation of Need for Improved Monitoring: If the Permittee fails to achieve compliance with an emission limitation or standard for which the monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing ammonia injection rate, the Permittee shall promptly notify the MPCA and, if necessary, submit a permit amendment application to address the necessary monitoring changes. 40 CFR Section 64.7(e); Minn. R. 7017.0200; Minn. R.

7017.0200

A s required by 40 CFR Section 64.9(a)(2), for the Semi-Annual Deviations Report listed in Table B of this permit and/or the Notification of Deviations Endangering Human Health and the Environment listed earlier in Table A of this permit, as applicable, the Permittee shall include the following related to the monitoring identified as required by 40 CFR pt. 64: 1) Summary information on the number, duration, and cause of excursions or exceedances, as applicable, and the corrective action taken; and 2) Summary information on the number, duration, and

cause for monitor downtime incidents. 40 CFR Section 64.9(a)(2); Minn. R. 7017.0200

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-44

The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions taken, and other supporting information required to be maintained. The Permittee may maintain records on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable recordkeeping requirements. 40 CFR Section 64.9(b); Minn. R. 7017.0200

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-45

Subject Item: FS 003 Emergency Reclaim Hopper

What to do Why to do it

Control fugitive particulate emissions by dust suppression methods on such operations so that fugitive particulate emissions are minimized. In the alternative, use an underground bottom feed (plow) of coal to an underground conveyor system provided the exhaust gases from the enclosed spaces do not contain Total Particulate Matter: less than or equal to 0.02 grains/dry standard cubic foot Minn. R. 7011.1105 (F)

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-46

Subject Item: FS 004 All Coal Storage Piles (Erosion)

Associated Items: CE 029 Dust Suppression by Water Spray

What to do Why to do it

Stockpiles, Stockpile Construction, and Reclaiming: (1) Control fugitive particulate emissions by dust suppression methods on such operations so that fugitive particulate emissions are minimized. (2) In the alternative, use an underground bottom feed (plow) of coal to an underground conveyor system provided the exhaust gases from the enclosed spaces do not contain Total Particulate Matter: less than or equal to 0.02 grains/dry standard cubic foot Minn. R. 7011.1105 (F)

Coal Pile Area: The total area of all coal piles shall be less than or equal to 14.5

acres. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-47

Subject Item: FS 013 Ash Hauling Traffic

Associated Items: CE 029 Dust Suppression by Water Spray

What to do Why to do it

Control dust by watering, such that fugitive particulate matter emissions are

minimized. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

The Permittee shall minimize or eliminate fugitive emissions from all paved surfaces. If fugitive emissions from paved surfaces are observed, the Permittee shall record the date that fugitive dust was observed, what corrective actions were
taken, when the corrective actions were taken, and whether the corrective actions eliminated the fugitive dust. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.
7009.0010-7009.0080; Minn. R. 7011.0150; Minn. R. 7007.0800, subp. 2

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-48

Subject Item: FS 014 Coal Yard Traffic

Associated Items: CE 029 Dust Suppression by Water Spray

What to do Why to do it

Control dust by watering, such that fugitive particulate matter emissions are

minimized. Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-49

Subject Item: FS 015 Coal Conveyors 7,7B,7C

What to do Why to do it

If exhaust gases from any enclosed coal handling facility exceed 20 percent opacity, either install an exhaust air system and control exhaust gases so that particulate emissions do not exceed 0.020 gr/dscf, or control exhaust gases using dust suppression methods so that particulate emissions do not exhibit Opacity: greater than 20 percent opacity Minn. R. 7011.1105 (G)

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-50

Subject Item: FS 016 Coal Conveyor 8

What to do Why to do it

If exhaust gases from any enclosed coal handling facility exceed 20 percent opacity, either install an exhaust air system and control exhaust gases so that particulate emissions do not exceed 0.020 gr/dscf, or control exhaust gases using dust suppression methods so that particulate emissions do not exhibit Opacity: greater than 20 percent opacity Minn. R. 7011.1105 (G)

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-51

Subject Item: FS 017 Dumper Unloading Bldg (fugitives from unloading railcar/scraper)

What to do Why to do it

Unload railcars only within a permanent building or structure. If exhaust gases from such building or structure exceed 20 percent opacity, then the owner or operator shall either install an exhaust air system and limit particulate emissions to 0.020 gr/dscf or control exhaust gases using dust suppression methods so that particulate emissions do not exhibit Opacity: greater than 20 percent opacity Minn. R. 7011.1105 (H)

Truck and Hauler Unloading Stations: Control fugitive particulate emissions from the unloading of truck or haulers by dust suppression methods so that emissions from such sources are minimized. Control emissions by unloading reclaimed coal within a partial enclosure and with fabric filters. Minn. R. 7011.1105 (C)

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-52

Subject Item: MR 016 Boilers 3 & 4 Opacity Monitor

Associated Items: CM 008 Boilers 3 & 4 Opacity

CM 010 Boilers 3 & 4 SO2 lb/hr

GP 002 Boilers and Associated Control Equipment

SV 001 Main Stack for Boilers 3 and 4

What to do Why to do it

A dditional monitoring requirements are located in Table B. hdr

Emissions Monitoring: The owner or operator shall use a COMS to measure Opacity from SV001. Minn. R. 7017.1006

Monitoring Data: All COMS data must be reduced to six-minute averages. A six minute average is valid only if it contains data from at least five minutes within the averaging period. COMS data shall be reduced and calculated as outlined in Minn. R. 7017.1200, subp. 3. Minn. R. 7017.1200, subps. 1, 2 & 3

Installation Notification: due 60 days before COMS installation. The notification shall include plans and drawings of the system. Minn. R. 7017.1040, subp. 1

COMS Certification Test: due 120 days after the first calendar quarter following COMS Installation. (This requirement is as stringent as that of Minn. R. 7017.1050, subp. 1 requiring testing within 90 days after the due date of the first excess emissions report required for the COMS) Minn. R. 7017.1050, subp. 1

COMS Certification Test Plan: due 30 days before COMS Certification Test COMS Certification Test Pretest Meeting: due 7 days before COMS Certification

Test COMS Certification Test Report: due 45 days after COMS Certification Test COMS Certification Test Report - Microfiche Copy: due 105 days after COMS

Certification Test The Notification, Test Plan, and Test Report may be submitted in alternate format as allowed by Minn. R. 7017.1120, subp. 2 Minn. R. 7017.1060, subps. 1-3; Minn. R. 7017.1080, subps. 1-4

Continuous Operation: COMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. A COMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment.

A cceptable monitor downtime includes reasonable periods as listed in Items A, B, C and D of Minn. R. 7017.1090, subp. 2. Minn. R. 7017.1090, subp. 1

QA Plan: Develop and implement a written quality assurance plan that covers each COMS. The plan shall be on site and available for inspection within 30 days after monitor certification. The plan shall contain all of the information required by Minn. R. 7017.1210, subp. 1. The plan shall include the manufacturer's spare parts list for each COMS and require that those parts be kept at the facility or readily available from another of the Permittee's facilities, unless the Commissioner gives written approval to exclude specific spare parts from the list. Minn. R. 7017.1210, subp. 1

COMS Daily Calibration Drift Test: The owner or operator of a COMS shall conduct a daily zero and upscale calibration drift assessment and adjustments according to the requirements of 40 CFR pt. 60.13(d)(2). The zero and upscale calibration levels must be determined by using the span value specified in the applicable requirement. If the applicable requirement does not specify a span value, a span value of 60, 70, or 80 percent opacity must be used unless an alternative span value is approved by the commissioner. Minn. R. 7017.1210, subp. 2

COMS Calibration Error Audit: due before the end of each calendar half-year following Permit Issuance. Audits are to be at least three months apart but no more than eight months apart except that a calibration error audit need not be conducted during any semiannual period in which the emission unit operated less than 24 hours. The calibration error audit shall be conducted according to the procedures in 40 CFR pt. 60, Appendix B, PS. 1. Minn. R. 7017.1210, subp. 3

COMS Attenuator Calibration: The Permittee shall semiannually have an independent testing company conduct calibrations of each of the neutral density filters used in the calibration error audit according to the procedure in 40 CFR pt. 60, Appendix B. Minn. R. 7017.1210, subp. 4

Recordkeeping: The owner or operator must retain records of all COMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. Minn. R. 7017.1130

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-53

Subject Item: MR 019 Unit 5/2 CO Dual Range Monitor

Associated Items: CM 012 Unit 5 CO ppm

GP 007 Combustion Turbine/Duct Burner Combined Requirments

SV 020 Combustion Turbine w/DLN & SCR; Duct Burners w/SCR

What to do Why to do it

A dditional monitoring requirements are located in Table B. hdr

Installation Notification: due 60 days before installing the continuous emissions monitoring system. The notification shall include plans and drawings of the system. Minn. R. 7017.1040, subp. 1

CEMS Certification Test: due 120 days after the first calendar quarter following CEMS Installation. (This requirement is as stringent as that of Minn. R. 7017.1050, subp. 1 requiring testing within 90 days after the due date of the first excess emissions report required for the CEMS or COMS.) Minn. R. 7017.1050, subp. 1

CEMS Certification Test Plan: due 30 days before CEMS Certification Test CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test CEMS Certification Test Report: due 45 days after CEMS Certification Test CEMS Certification Test Report - Microfiche Copy: due 105 days after CEMS

Certification Test The Notification, Test Plan, and Test Report may be submitted in alternate format as allowed by Minn. R. 7017.1120, subp. 2 Minn. R. 7017.1060, subps. 1-3; Minn. R. 7017.1080, subps. 1-4

Continuous Operation: CEMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. A CEMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment. Minn. R. 7017.1090

Monitoring Data: All data points collected by a CEMS shall be used to calculate individual hourly emission averages unless another applicable requirement requires more frequent averaging. In order for an hour of data to be considered, it must contain the following minimum number of data points:

A . four data points, equally spaced, if the emission unit operated during the entire
hour; B. two data points, at least 15 minutes apart, during periods of monitor calibration
or routine maintenance; C. one data point if the emission unit operated for 15 minutes or less during the

hour. Minn. R. 7017.1160, subps. 1 and 2

QA Plan: Develop and implement a written quality assurance plan that covers each CEMS. The plan shall be on site and available for inspection within 30 days after monitor certification. The plan shall contain all of the information required by 40 CFR pt. 60, Appendix F, Section 3. The plan shall include the manufacturer's spare parts list for each CEMS and require that those parts be kept at the facility or readily available from another of the Permittee's facilities, unless the Commissioner gives written approval to exclude specific spare parts from the list. Minn. R. 7017.1170, subp. 2

Requirement: CEMS Daily Calibration Drift (CD) Test: The CD shall be quantified and recorded at zero (low-level) and upscale (high-level) gas concentrations at least once daily according to the procedures listed in Minn. R. 7017.1170, subp. 3(A) and (B) and 40 CFR Section 60.13(d)(1) for each pollutant concentration, each diluent monitor, and for each monitor range. The CEMS shall be adjusted whenever the CD exceeds twice the specification of 40 CFR pt. 60, Appendix B. If no span value is specified in the applicable requirement or in a compliance document, the Permittee shall use a span value equivalent to 1.5 times the emission limit. 40 CFR pt. 60, Appendix F, shall be used to determine out-of-control periods for CEMS. Follow the procedures in 40 CFR pt. 60, Appendix F. Minn. R. 7017.1170, subp. 3

Cylinder Gas Audit (CGA): due before end of each calendar half-year following Permit Issuance, except that a CGA is not required during any calendar half year in which a RATA was performed. The initial CGA must be performed within 180 days following certification of the CEMS. The CGAs shall be conducted at least three months apart but no more than eight months apart. A CGA shall be conducted according to the procedures in 40 CFR pt. 60, Appendix F, Section 5.1.2. If the monitored emission unit was operated for less than 24 hours during the calendar half year, a CGA is not required for that calendar half year. Minn. R. 7017.1170, subp. 4

## TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011 Facility Name:

Permit Number: 09/05/13 A-54

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar year following Permit Issuance. A RATA is not required in any calendar year if a RATA conducted in the previous year demonstrated a relative accuracy value of less than 15 percent or if the associated emissions unit operated less than 48 hours during the calendar year. If the exception is used, the next RATA shall be conducted during the first half of the following calendar year. RATAs shall be conducted at least 3 months apart and according to 40 CFR pt. 60, Appendix F, Section 5.1.1. Minn. R. 7017.1170, subp. 5

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS Relative Accuracy Test Audit (RATA). Minn. R. 7017.1180, subp. 2

Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. Minn. R. 7017.1130