Exhibit 8

























































































Technical Support Document, Permit Action Number: 03700003‐011

Page 1 of 17

Date:  4/1/2014

TECHNICAL SUPPORT DOCUMENT

For

AIR EMISSION PERMIT NO. 03700003‐011

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, PM10, PM2.5).   

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‐NOX 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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Date:  4/1/2014

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

PM10

tpy

PM2.5

tpy

SO2

tpy

NOx

tpy

CO

tpy

CO2e

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 106 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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Date:  4/1/2014

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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Date:  4/1/2014

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 SO2 Acid Rain requirements. As

such, the Permittee is required to maintain records of SO2 emissions, ensuring that SO2 emissions for a given year do

not exceed emissions from the previous year.

The boilers are also subject to the NOX requirements under the Acid Rain program, and are subject to NOX limits.

2.6 National Ambient Air Quality Standards (NAAQS)

The existing permit included an appendix (Appendix B) of modeling parameters for NOX and PM10 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 NOX NOX 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) NOX 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 NOX as NO2 allowances equivalent to their initial allocation.  

EPA was to deduct and terminate these allowances.  The CAMD records now show that zero CAIR NOX as NO2
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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 NOX 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, SO2 and PM10, 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 NOX limits under the facility’s NOX Averaging Plan pursuant to

Acid Rain regulations

40 CFR Part 64 The boilers are subject to CAM for PM and PM10

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 NOx, CO, PM10, 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 SO2

emissions under the Acid Rain program. There is no specific

SO2 limit.

40 CFR Part 64 EU026 and EU027 combined are subject to CAM for NOX.

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

provisions.

EU005, EU008,

EU009, EU010,

EU011, EU012,

EU013

NAAQS   Limit on PM10, 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 PM10, 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 PM10, 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). NOX and SO2 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 SO2 emissions, set through a previous

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

for SO2.

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.  

SO2 and NOX limits apply.

Title I limit to avoid 40 CFR §

52.21

Fuel restrictions limiting SO2 emissions, set through a previous

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

for SO2.

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.

NOX: < 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)  

SO2: < 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)

PM10: < 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   

SO2: < 1.3 lb/MMBtu on a 1‐

hour average

SO2: < 3988 lb/hr on a 1‐hour

average

(NAAQS modeling)

SO2: < 3.0 lb/MMBtu on a 3‐

hour average using solid fuel

SO2: < 1.6 lb/MMBtu on a 3‐

hour average using liquid fuel

(Minn. R. 7011.0510)

SO2 CEMS  

NOX for EU003:  

< 0.81 lb/MMBtu and 6133000

MMBtu/year

AND

NOX for EU004:

< 0.81 lb/MMBtu and

12438000 MMBtu/year

OR

Weighted average for the

facility as outlined in the NOX

averaging plan

(Acid Rain)

NOX 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

PM10 Control efficiency: >

99.75%

PM2.5 Control efficiency: >

99.75%

(Minn. R. 7007.0800)

SCA online

Surface collection area (SCA): >

125,760 ft2 for CE006 and

CE007 combined; > 141,144 ft2

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%

PM10 Control efficiency: > 93%

PM2.5 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)

NOX: < 4.5 ppm on a 3‐hour

block average

NOX: < 100 ppm on a 1‐hour

average

(BACT limits)

NOX CEMS EU026 and EU027 are subject to

CAM for NOX.   

NOX: < 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.

PM10:  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)

SO2: Comply with applicable

SO2 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)

PM10: < 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)

PM10: < 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

PM10 emission rate will not result in

20% opacity

PM10: < 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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Item Requirement (rule basis) Additional

Monitoring

Discussion

EU008 (coal

handling)

PM10: < 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 PM10 emission rate will not

result in 20% opacity

EU009 (coal

handling)

PM10: < 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 PM10 emission rate will not

result in 20% opacity

EU010 (coal

handling)

PM10: < 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 PM10 emission rate will not

result in 20% opacity

EU011 (coal

handling)

PM10: < 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 PM10 emission rate will not

result in 20% opacity

EU012 (coal

handling)

PM10: < 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 PM10 emission rate will not

result in 20% opacity

EU013 (coal

handling)

PM10: < 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 PM10 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)

NOX: < 110 ppm on a 4‐hour

average

(NSPS Subpart GG)

NOX CEMS NOX CEMS is not required by NSPS,

but is in place for other purposes.

Fuel sulfur content: < 0.8

percent by weight

SO2: < 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)

SO2: < 0.2 lb/MMBtu on a 30‐

day average

(NSPS Subpart Da)

None PTE is approximately 0.0006

lb/MMBtu.

NOX: < 1.6 lb/megawatt‐hour

on a 30‐day average

(NSPS Subpart Da)

NOX 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

SO2: < 0.50 lb/MMBtu heat

input

(Minn. R. 7011.2300)

Recordkeeping of

fuel sulfur content

SO2 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) NOX: < 4.5 ppm on an

instantaneous basis

(CAM excursion level)

NOX 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/PM10 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 CO2e.

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 PM10 testing at the boiler stack.  This requirement was erroneously included in the permit to

begin with. The potential PM10 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 NOX 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 2nd 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 2nd 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  ‐ 1st Comment Period
Attachment 1 

Calculations and PTE Summary 
27 December, 2013 09:16

Show: Active and Pending Records

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Acetaldehyde 

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

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

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

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

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

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

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

GP 001 PER 011 1.700E-04

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

Acetophenone 

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

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

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

Acrolein 

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

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

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

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

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

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

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

GP 001 PER 011 5.330E-05

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

Benzene 

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

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

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

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

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

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

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

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

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

GP 001 PER 011 5.250E-03

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

Page 1 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Arsenic compounds 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

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

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

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

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

Benzyl chloride 

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

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

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

Biphenyl 

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

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

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

Bis(2-ethylhexyl) phthalate 

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

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

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

Bromomethane 

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

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

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

1,3-Butadiene 

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

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

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

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

Beryllium 

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

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

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

Page 2 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Beryllium Compounds 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

Carbon disulfide 

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

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

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

Carbon Dioxide Equivalent 

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

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

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

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

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

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

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

GP 001 PER 011 1.096E+03

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

Chlorobenzene 

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

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

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

Chloroethane 

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

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

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

Chloroform 

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

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

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

Cadmium compounds 

EU 001 PER 002

EU 002 PER 002

Page 3 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Cadmium compounds 

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

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

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

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

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

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

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

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

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

Methane 

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

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

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

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

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

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

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

GP 001 PER 011 4.470E-02

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

Cyanide compounds 

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

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

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

Carbon Monoxide 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

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

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

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

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

Page 4 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Carbon Monoxide 

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

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

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

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

GP 001 PER 011 4.270E+00

SV 020 PER 011 4.000E+02

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

Carbon Dioxide 

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

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

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

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

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

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

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

GP 001 PER 011 1.092E+03

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

Cobalt compounds 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

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

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

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

Chromium compounds 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

Page 5 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Chromium compounds 

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

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

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

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

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

Dibenzofuran 

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

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

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

Dibutyl phthalate 

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

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

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

1,4-Dichlorobenzene 

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

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

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

EU 027 PER 011 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 

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

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

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

Dimethyl sulfate 

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

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

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

2,4-Dinitrotoluene 

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

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

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

Ethylbenzene 

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

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

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

Page 6 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Ethylbenzene 

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

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

Formaldehyde 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

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

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

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

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

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

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

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

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

GP 001 PER 011 5.340E-04

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

Hexane 

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

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

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

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

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

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

Hydrogen fluoride 

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

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

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

Methyl methacrylate 

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

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

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

Page 7 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Methylhydrazine 

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

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

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

Naphthalene 

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

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

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

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

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

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

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

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

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

GP 001 PER 011 3.870E-04

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

HAPs - Total 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

EU 023 PER 008 2.000E-02

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

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

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

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

EU 026 PER 008 2.350E+01

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

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

GP 001 PER 011 1.010E-02

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

Mercury 

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

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

Page 8 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Mercury 

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

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

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

Mercury Compounds 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

Nitrosodimethylamine, NEU 026 PER 002 4.000E-04 2.000E-03 2.000E-03 0.000E+00

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

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

Nitrosomorpholine, NEU 026 PER 002 4.000E-04 2.000E-03 2.000E-03 0.000E+00

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

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

Phenol 

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

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

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

Propylene oxide 

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

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

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

Styrene 

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

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

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

Tetrachloroethylene 

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

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

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

Page 9 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Toluene 

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

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

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

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

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

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

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

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

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

GP 001 PER 011 1.900E-03

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

1,2,4-Trichlorobenzene 

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

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

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

1,1,1-Trichloroethane 

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

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

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

Vinyl acetate 

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

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

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

Vinyl chloride 

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

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

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

Xylenes (mixed isomers) 

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

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

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

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

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

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

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

Page 10 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Xylenes (mixed isomers) 

GP 001 PER 011 1.310E-03

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

Hydrochloric acid 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

Manganese compounds 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

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

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

EU 027 PER 011 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

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

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

Nitrous Oxide 

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

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

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

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

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

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

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

GP 001 PER 011 8.950E-03

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

Page 11 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Isophorone 

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

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

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

Methyl chloride (chloromethane

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

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

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

Methyl tert butyl ether 

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

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

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

Methylene chloride (dichlorome

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

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

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

Propionaldehyde 

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

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

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

Total Polycyclic aromatic hydr

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

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

Nickel compounds 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

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

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

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

Nitrogen Oxides 

EU 001 PER 002

EU 002 PER 002

Page 12 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Nitrogen Oxides 

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

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

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

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

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

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

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

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

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

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

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

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

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

GP 001 PER 011 3.530E+01

SV 020 PER 011 3.050E+02

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

PM < 2.5 micron 

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

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

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

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

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

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

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

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

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

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

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

EU 019 PER 011 1.790E-03

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

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

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

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

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

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

Page 13 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

PM < 2.5 micron 

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

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

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

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

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

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

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

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

GP 001 PER 011 1.990E-01

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

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

Lead 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

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

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

EU 027 PER 011 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 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

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

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

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

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

Page 14 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

PM < 10 micron 

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

Page 15 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

PM < 10 micron 

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

GP 001 PER 011 1.990E-01

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

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

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

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

Polycyclic organic matter 

EU 001 PER 002

EU 002 PER 002

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

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

Page 16 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Polycyclic organic matter 

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

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

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

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

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

EU 027 PER 011 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 

EU 001 PER 002

EU 002 PER 002

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

Page 17 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Total Particulate Matter 

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

Page 18 of 20
27 December, 2013 09:16

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Total Particulate Matter 

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

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

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

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

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

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

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

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

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

GP 001 PER 011 1.990E-01

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

Antimony compounds 

EU 001 PER 002

EU 002 PER 002

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

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

EU 004 PER 001 7.000E-03 3.070E-02 3.070E-02 1.530E-02

EU 004 PER 011 3.680E-03 1.610E-02 1.610E-02 0.000E+00

Totals 2.610E-02 2.610E-02 0.000E+00

Selenium compounds 

EU 001 PER 002

EU 002 PER 002

EU 003 PER 001 1.100E-03 1.700E-01 4.800E-03 2.200E-03

EU 003 PER 011 7.790E-02 3.411E-01 3.411E-01 0.000E+00

EU 004 PER 001 1.800E-03 2.735E-01 7.700E-03 3.800E-03

EU 004 PER 011 1.490E-01 6.508E-01 6.508E-01 0.000E+00

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

EU 027 PER 002 1.000E-05 5.000E-05 5.000E-05 0.000E+00

EU 027 PER 011 1.020E-05 4.460E-05 7.640E-06 0.000E+00

Totals 9.919E-01 9.919E-01 0.000E+00

Sulfur Dioxide 

EU 001 PER 002

EU 002 PER 002

EU 003 PER 001 1.529E+03 3.011E+04 6.696E+03 1.568E+03

EU 003 PER 011 0.000E+00 3.011E+04 0.000E+00 0.000E+00

Page 19 of 20
27 December, 2013 09:16

Show: Active and Pending Records

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

Retired

By

(Action)

Added

By

(Action)

Pollutant Item 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 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194

Sulfur Dioxide 

EU 004 PER 001 2.460E+03 4.844E+04 1.077E+04 2.883E+03

EU 004 PER 011 0.000E+00 4.844E+04 0.000E+00 0.000E+00

EU 023 PER 008 6.300E-01 2.760E+00 1.540E+00

EU 024 PER 001 7.900E-01 3.736E+01 3.480E+00 0.000E+00

EU 024 PER 011 8.371E-01 3.667E+00 0.000E+00 0.000E+00

EU 025 PER 008 7.900E-01 3.736E+01 0.000E+00 0.000E+00

EU 025 PER 011 8.371E-01 3.667E+00 0.000E+00 0.000E+00

EU 026 PER 008 2.270E+00 9.900E+00 2.100E+00 0.000E+00

EU 026 PER 011 2.270E+00 9.900E+00 9.920E+00 0.000E+00

EU 027 PER 008 5.900E-01 2.600E+00 0.000E+00 0.000E+00

EU 027 PER 011 3.000E-01 1.313E+00 2.248E-01 0.000E+00

EU 028 PER 011 7.200E-02 1.800E-02 1.800E-02

GP 001 PER 011 3.420E-01

SV 001 PER 011 3.988E+03 1.747E+04

Totals 7.856E+04 1.748E+04 0.000E+00

Volatile Organic Compounds 

EU 001 PER 002

EU 002 PER 002

EU 003 PER 008 6.600E+00 2.890E+01 2.890E+01 9.200E+00

EU 004 PER 008 1.046E+01 4.580E+01 4.580E+01 1.580E+01

EU 004 PER 011 1.045E+01 1.510E+01 1.510E+01 0.000E+00

EU 023 PER 008 7.500E-01 3.290E+00 1.900E+00

EU 024 PER 001 1.300E-01 6.090E+00 5.700E-01 0.000E+00

EU 024 PER 011 1.905E+00 8.344E+00 0.000E+00 0.000E+00

EU 025 PER 008 1.300E-01 6.090E+00 0.000E+00 0.000E+00

EU 025 PER 011 1.905E+00 8.344E+00 0.000E+00 0.000E+00

EU 026 PER 008 4.800E+00 2.100E+01 9.600E+00 0.000E+00

EU 026 PER 011 4.800E+00 2.100E+01 2.100E+01 0.000E+00

EU 027 PER 008 1.270E+01 5.560E+01 0.000E+00 0.000E+00

EU 027 PER 011 1.270E+01 5.580E+01 2.790E+00 0.000E+00

EU 028 PER 011 5.129E-01 1.282E-01 1.282E-01

GP 001 PER 011 7.770E-01

Totals 1.409E+02 7.060E+01 9.200E+00

Page 20 of 20
Boiler 3 (Bituminous Coal) 1176 MMBtu/hr Bit Coal Ash% 1.15E+01

Boiler 3 (Bituminous Coal) 56 tons/hr Bit Coal S% 3.23E+00

Boiler 3 (Subbituminous Coal) 980 MMBtu/hr Subbit Coal Ash% 4.64E+00

Boiler 3 (Subbituminous Coal) 56 tons/hr Subbit Coal S% 2.10E-01

Boiler 3 (Pet Coke) 3.9 tons/hr Pet Coke Ash% 3.00E-01

Boiler 3 (Pet Coke) 30 MMBtu/ton burned Pet Coke S% 5.67E+00

Boiler 3 (Subbituminous Coal/Coke) 59.9 tons/hrBoiler 3 (Subbituminous Coal/Coke) 1097 MMBtu/hr

Boiler 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-02

Boiler 4 (Natural Gas) 1.2 MMCF/hr Waste oil MMBtu/hr 59

Boiler 3 (Propane) 0.452 1000 gal/hr

Boiler 3 (Propane) 166 MMBtu/hr

Xcel Energy - Black Dog Generating Plant Particulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficient

Potential to Emit Shading = Worst Case for Specified Pollutant for Specified Unit

Emission 

Unit ID Unit Name Pollutant

Max Process

 Rate

Process Rate

 Units

Emission

 Factor Emission Factor 

Units Emission Factor Source

Emission 

Rate

 (lb/hr)

Uncontrolled 

Potential to Emit

 (ton/yr) 

Pollution 

Control 

Efficiency 

(%) 

Controlled 

Potential to 

Emit (ton/yr)

Limited

Controll

Potential 

Emit (ton

EU 003 Boiler 3 (Bituminous Coal) 1,2,4-Trichlorobenzene 1176 MMBtu/hr 1.50E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.76E-03 7.73E-03 7.73E-03 

EU 003 Boiler 3 (Bituminous Coal) 1,4-Dichlorobenzene 1176 MMBtu/hr 1.10E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.29E-03 5.67E-03 5.67E-03 

EU 003 Boiler 3 (Bituminous Coal) 2,4-Dinitrotoluene 1176 MMBtu/hr 2.00E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 2.35E-04 1.03E-03 1.03E-03 

EU 003 Boiler 3 (Bituminous Coal) Acetaldehyde 1176 MMBtu/hr 3.20E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 3.76E-03 1.65E-02 1.65E-02 

EU 003 Boiler 3 (Bituminous Coal) Acetophenone 1176 MMBtu/hr 1.20E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.41E-03 6.18E-03 6.18E-03 

EU 003 Boiler 3 (Bituminous Coal) Acrolein 1176 MMBtu/hr 1.90E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 2.23E-03 9.79E-03 9.79E-03 

EU 003 Boiler 3 (Bituminous Coal) Antimony 56.0 tons/hr 1.80E-05 lb/ton AP-42 Table 1.1-18 (9/98) 1.01E-03 4.42E-03 4.42E-03 

EU 003 Boiler 3 (Bituminous Coal) Arsenic 56.0 tons/hr 4.10E-04 lb/ton AP-42 Table 1.1-18 (9/98) 2.30E-02 1.01E-01 1.01E-01 EU 003 Boiler 3 (Bituminous Coal) Benzene 1176 MMBtu/hr 3.90E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 4.59E-03 2.01E-02 2.01E-02 

EU 003 Boiler 3 (Bituminous Coal) Benzyl Chloride 1176 MMBtu/hr 2.80E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 3.29E-04 1.44E-03 1.44E-03 

EU 003 Boiler 3 (Bituminous Coal) Beryllium 56.0 tons/hr 2.10E-05 lb/ton AP-42 Table 1.1-18 (9/98) 1.18E-03 5.15E-03 5.15E-03 EU 003 Boiler 3 (Bituminous Coal) Biphenyl 1176 MMBtu/hr 1.60E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.88E-04 8.24E-04 8.24E-04 

EU 003 Boiler 3 (Bituminous Coal) bis(2-Ethylexyl)phthalate 1176 MMBtu/hr 3.60E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 4.23E-03 1.85E-02 1.85E-02 

EU 003 Boiler 3 (Bituminous Coal) Cadmium 56.0 tons/hr 5.10E-05 lb/ton AP-42 Table 1.1-18 (9/98) 2.86E-03 1.25E-02 1.25E-02 EU 003 Boiler 3 (Bituminous Coal) Carbon Disulfide 1176 MMBtu/hr 1.10E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.29E-03 5.67E-03 5.67E-03 

EU 003 Boiler 3 (Bituminous Coal) Chlorobenzene 1176 MMBtu/hr 1.60E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.88E-04 8.24E-04 8.24E-04 

EU 003 Boiler 3 (Bituminous Coal) Chloroform 1176 MMBtu/hr 8.00E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 9.41E-04 4.12E-03 4.12E-03 

EU 003 Boiler 3 (Bituminous Coal) Chromium 56.0 tons/hr 2.60E-04 lb/ton AP-42 Table 1.1-18 (9/98) 1.46E-02 6.38E-02 6.38E-02 EU 003 Boiler 3 (Bituminous Coal) CO 56.0 tons/hr 5.00E-01 lb/ton AP-42 Table 1.1-3 (9/98) 28.00 122.64 122.64 

EU 003 Boiler 3 (Bituminous Coal) CO2 1176 MMBtu/hr 2.06E+02 lb/MMBtu 40 CFR 98 241838.62 1059253.17 1059253.17 

EU 003 Boiler 3 (Bituminous Coal) CO2e 1176 MMBtu/hr 2.07E+02 lb/MMBtu 40 CFR 98 243787.75 1067790.33 1067790.33 

EU 003 Boiler 3 (Bituminous Coal) Cobalt 56.0 tons/hr 1.00E-04 lb/ton AP-42 Table 1.1-18 (9/98) 5.60E-03 0.0245 2.45E-02 

EU 003 Boiler 3 (Bituminous Coal) Cyanide 56.0 tons/hr 2.50E-03 lb/ton AP-42 Table 1.1-14 (9/98) 1.40E-01 6.13E-01 6.13E-01 EU 003 Boiler 3 (Bituminous Coal) DEHP 56.0 tons/hr 7.30E-05 lb/ton AP-42 Table 1.1-14 (9/98) 4.09E-03 1.79E-02 1.79E-02 EU 003 Boiler 3 (Bituminous Coal) Dibenzofuran 1176 MMBtu/hr 5.80E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 6.82E-04 2.99E-03 2.99E-03 

EU 003 Boiler 3 (Bituminous Coal) Dibutylphthalate 1176 MMBtu/hr 1.10E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.29E-04 5.67E-04 5.67E-04 

EU 003 Boiler 3 (Bituminous Coal) Dimethyl Sulfate 56.0 tons/hr 4.80E-05 lb/ton AP-42 Table 1.1-14 (9/98) 2.69E-03 1.18E-02 1.18E-02 EU 003 Boiler 3 (Bituminous Coal) Ethyl Benzene 1176 MMBtu/hr 8.00E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 9.41E-04 4.12E-03 4.12E-03 

EU 003 Boiler 3 (Bituminous Coal) chloroethane 56.0 tons/hr 4.20E-05 lb/ton AP-42 Table 1.1-14 (9/98) 2.35E-03 1.03E-02 1.03E-02 EU 003 Boiler 3 (Bituminous Coal) Ethylene Dibromide 56.0 tons/hr 1.20E-06 lb/ton AP-42 Table 1.1-14 (9/98) 6.72E-05 2.94E-04 2.94E-04 EU 003 Boiler 3 (Bituminous Coal) 1,2-dichloroethane 56.0 tons/hr 4.00E-05 lb/ton AP-42 Table 1.1-14 (9/98) 2.24E-03 9.81E-03 9.81E-03 EU 003 Boiler 3 (Bituminous Coal) Formaldehyde 1176 MMBtu/hr 2.60E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 3.06E-03 1.34E-02 1.34E-02 

EU 003 Boiler 3 (Bituminous Coal) Hexane 56.0 tons/hr 6.70E-05 lb/ton AP-42 Table 1.1-14 (9/98) 3.75E-03 1.64E-02 1.64E-02 EU 003 Boiler 3 (Bituminous Coal) Hydrochloric Acid 1176 MMBtu/hr 5.93E-02 lb/10^12 BTU

Assume 750 ppm Cl (EPRI Pisces 

Database 08/98) in coal gets converted to 

HCl and 100% (EPRI Emissions Factor 

Handbook 4/02) goes to atmosphere. 

Assume 13000 Btu/lb (1999 Performance 

Report) 6.97E-05 3.05E-04 3.05E-04 

EU 003 Boiler 3 (Bituminous Coal) Hydrogen Fluoride 1176 MMBtu/hr 5.26E-03 lb/10^12 BTU

Assume 65 ppm F (EPRI Pisces Database 

08/98) in coal gets converted to HF and 

90% (EPRI Emissions Factor Handbook 

4/02) goes to atmosphere. Assume 13000 

Btu/lb (1999 Performance Report) 6.19E-06 2.71E-05 2.71E-05 

EU 003 Boiler 3 (Bituminous Coal) Isophorone 1176 MMBtu/hr 1.20E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.41E-03 6.18E-03 6.18E-03 

EU 003 Boiler 3 (Bituminous Coal) Lead 56.0 tons/hr 2.60E-04 lb/ton AP-42 Table 1.1-18 (9/98) 1.46E-02 6.38E-02 6.38E-02 

EU 003 Boiler 3 (Bituminous Coal) Manganese 56.0 tons/hr 1.10E-02 lb/ton AP-42 Table 1.1-18 (9/98) 6.16E-01 2.6981 2.70E+00 EU 003 Boiler 3 (Bituminous Coal) Mercury 56.0 tons/hr 8.30E-05 lb/ton AP-42 Table 1.1-18 (9/98) 4.65E-03 2.04E-02 2.04E-02 EU 003 Boiler 3 (Bituminous Coal) Methane 1176 MMBtu/hr 2.43E-02 lb/MMBtu 40 CFR 98 2.85E+01 124.9119 1.25E+02 

EU 003 Boiler 3 (Bituminous Coal) bromomethane 56.0 tons/hr 1.60E-04 lb/ton AP-42 Table 1.1-14 (9/98) 8.96E-03 3.92E-02 3.92E-02 

EU 003 Boiler 3 (Bituminous Coal) Methyl Chloride 56.0 tons/hr 5.30E-04 lb/ton AP-42 Table 1.1-14 (9/98) 2.97E-02 1.30E-01 1.30E-01 
Xcel Energy - Black Dog Generating Plant Particulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficient

Potential to Emit Shading = Worst Case for Specified Pollutant for Specified Unit

Emission 

Unit ID Unit Name Pollutant

Max Process

 Rate

Process Rate

 Units

Emission

 Factor Emission Factor 

Units Emission Factor Source

Emission 

Rate

 (lb/hr)

Uncontrolled 

Potential to Emit

 (ton/yr) 

Pollution 

Control 

Efficiency 

(%) 

Controlled 

Potential to 

Emit (ton/yr)

Limited

Controll

Potential 

Emit (ton

EU 003 Boiler 3 (Bituminous Coal) 1,1,1-trichlorothane 1176 MMBtu/hr 6.10E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 7.17E-04 3.14E-03 3.14E-03 

EU 003 Boiler 3 (Bituminous Coal) Methyl Ethyl Ketone 56.0 tons/hr 3.90E-04 lb/ton AP-42 Table 1.1-14 (9/98) 2.18E-02 9.57E-02 9.57E-02 

EU 003 Boiler 3 (Bituminous Coal) Methyl Hydrazine 56.0 tons/hr 1.70E-04 lb/ton AP-42 Table 1.1-14 (9/98) 9.52E-03 4.17E-02 4.17E-02 EU 003 Boiler 3 (Bituminous Coal) Methyl Methacrylate 1176 MMBtu/hr 1.10E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.29E-03 5.67E-03 5.67E-03 

EU 003 Boiler 3 (Bituminous Coal) Methyl tert butyl ether 56.0 tons/hr 3.50E-05 lb/ton AP-42 Table 1.1-14 (9/98) 1.96E-03 8.58E-03 8.58E-03 EU 003 Boiler 3 (Bituminous Coal) Methylene Chloride 1176 MMBtu/hr 3.60E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 4.23E-03 1.85E-02 1.85E-02 

EU 003 Boiler 3 (Bituminous Coal) Naphthalene 1176 MMBtu/hr 6.20E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 7.29E-04 3.19E-03 3.19E-03 

EU 003 Boiler 3 (Bituminous Coal) Nickel 56.0 tons/hr 2.80E-04 lb/ton AP-42 Table 1.1-18 (9/98) 1.57E-02 6.87E-02 6.87E-02 EU 003 Boiler 3 (Bituminous Coal) Nitrous oxides 1176 MMBtu/hr 3.53E-03 lb/MMBtu 40 CFR 98 4.15 18.17 18.17 

EU 003 Boiler 3 (Bituminous Coal) NOX 56.0 tons/hr 2.20E+01 lb/ton AP-42 Table 1.1-3 (9/98) 1232.00 5396.16 5396.16 

EU 003 Boiler 3 (Bituminous Coal) Phenol 1176 MMBtu/hr 3.30E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 3.88E-03 0.0170 1.70E-02 

EU 003 Boiler 3 (Bituminous Coal) PM 56.0 tons/hr 1.15E+02 lb/ton

AP-42 Table 1.1-4 (9/98) (10 x 11.5 % 

Ash) 6440.00 28207.20 99.75% 70.52 1,54

EU 003 Boiler 3 (Bituminous Coal) PM10 56.0 tons/hr 2.65E+01 lb/ton

AP-42 Table 1.1-4 (9/98) (2.3 x 11.5 % 

Ash) 1481.20 6487.66 99.75% 16.22 

EU 003 Boiler 3 (Bituminous Coal) PM2.5 56.0 tons/hr 2.65E+01 lb/ton Assumed same as PM10 1481.20 6487.66 99.75% 16.22 

EU003 Boiler 3 (Bituminous Coal) Condensible PM 1176.0 MMBtu/hr 3.23E-01 lb/MMBtu AP-42 Table 1.1-5 (0.1 x 3.23% sulfur) 379.85 1663.73 99.75% 4.16 

EU 003 Boiler 3 (Bituminous Coal) POMs 1176 MMBtu/hr 2.08E-06 lb/10^12 BTU AP-42 Table 1.1-17 (9/98) 2.45E-09 0.0000 1.07E-08 

EU 003 Boiler 3 (Bituminous Coal) Propionaldehyde 1176 MMBtu/hr 1.90E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 2.23E-03 0.0098 9.79E-03 

EU 003 Boiler 3 (Bituminous Coal) Selenium 56.0 tons/hr 1.30E-03 lb/ton AP-42 Table 1.1-18 (9/98) 7.28E-02 0.3189 3.19E-01 EU 003 Boiler 3 (Bituminous Coal) SO2 56.0 tons/hr 1.23E+02 lb/ton AP-42 Table 1.1-3 (9/98) (38 x 3.23 % S) 6873.44 30105.6672 30105.67 15,45

EU 003 Boiler 3 (Bituminous Coal) Styrene 1176 MMBtu/hr 7.00E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 8.23E-04 3.61E-03 3.61E-03 

EU 003 Boiler 3 (Bituminous Coal) Tetrachloroethylene 1176 MMBtu/hr 4.20E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 4.94E-04 2.16E-03 2.16E-03 

EU 003 Boiler 3 (Bituminous Coal) Toluene 1176 MMBtu/hr 1.70E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 2.00E-03 8.76E-03 8.76E-03 

EU 003 Boiler 3 (Bituminous Coal) TOTAL HAPs 1.02E+00 4.48 4.48E+00 EU 003 Boiler 3 (Bituminous Coal) Total VOC 56.0 tons/hr 6.00E-02 lb/ton AP-42 Table 1.1-19 (9/98) 3.36E+00 14.7168 1.47E+01 

EU 003 Boiler 3 (Bituminous Coal) Vinyl Acetate 1176 MMBtu/hr 3.10E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 3.65E-04 1.60E-03 1.60E-03 

EU 003 Boiler 3 (Bituminous Coal) Vinyl Chloride 1176 MMBtu/hr 7.30E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 8.58E-04 3.76E-03 3.76E-03 

EU 003 Boiler 3 (Bituminous Coal) Xylenes 1176 MMBtu/hr 8.20E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 9.64E-04 4.22E-03 4.22E-03 

0.00E+00 

EU 003 Boiler 3 (Coke) CO2 117 MMBtu/hr 2.26E+02 lb/MMBtu 40 CFR 98 2.64E+04 115700 1.16E+05 

EU 003 Boiler 3 (Coke) CO2e 117 MMBtu/hr 2.27E+02 lb/MMBtu 40 CFR 98 2.66E+04 116549.0362 1.17E+05 

0.00E+00 

EU 003 Boiler 3 (Natural Gas) Arsenic 1224 MMBtu/hr 2.30E-01 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 2.82E-04 0.0012 1.23E-03 

EU 003 Boiler 3 (Natural Gas) Benzene 1224 MMBtu/hr 8.00E-01 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 9.79E-04 0.0043 4.29E-03 

EU 003 Boiler 3 (Natural Gas) Beryllium 1224 MMBtu/hr 1.00E-02 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 1.22E-05 0.0001 5.36E-05 

EU 003 Boiler 3 (Natural Gas) Cadmium 1224 MMBtu/hr 4.00E-02 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 4.90E-05 0.0002 2.14E-04 

EU 003 Boiler 3 (Natural Gas) Chromium 1224 MMBtu/hr 1.10E+00 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 1.35E-03 0.0059 5.90E-03 

EU 003 Boiler 3 (Natural Gas) CO 1.2 MMCF/hr 8.40E+01 lb/MMCF AP-42 Table 1.4-1 (7/98) 100.80 441.50 441.50 

EU 003 Boiler 3 (Natural Gas) CO2 1224 MMBtu/hr 1.17E+02 lb/MMBtu 40 CFR 98 143178.72 627122.78 627122.78 

EU 003 Boiler 3 (Natural Gas) CO2e 1224 MMBtu/hr 1.17E+02 lb/MMBtu 40 CFR 98 143326.59 627770.47 627770.47 

EU 003 Boiler 3 (Natural Gas) Cobalt 1224 MMBtu/hr 8.00E-02 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 9.79E-05 0.0004 4.29E-04 

EU 003 Boiler 3 (Natural Gas) Formaldehyde 1224 MMBtu/hr 1.75E-04 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 2.14E-07 0.0000 9.38E-07 

EU 003 Boiler 3 (Natural Gas) Hexane 1.2 MMCF/hr 1.80E+00 lb/MMCF AP-42 Table 1.4-3 (7/98) 2.16E+00 9.4608 9.46E+00 

EU 003 Boiler 3 (Natural Gas) Lead 1224 MMBtu/hr 4.00E-01 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 4.90E-04 0.0021 2.14E-03 

EU 003 Boiler 3 (Natural Gas) Manganese 1224 MMBtu/hr 4.00E-01 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 4.90E-04 0.0021 2.14E-03 

EU 003 Boiler 3 (Natural Gas) Mercury 1224 MMBtu/hr 8.00E-04 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 9.79E-07 0.0000 4.29E-06 

EU 003 Boiler 3 (Natural Gas) Methane 1224 MMBtu/hr 2.20E-03 lb/MMBtu 40 CFR 98 2.70E+00 11.8191 1.18E+01 

EU 003 Boiler 3 (Natural Gas) Naphthalene 1.2 MMCF/hr 6.10E-04 lb/MMCF AP-42 Table 1.4-3 (7/98) 7.32E-04 0.0032 3.21E-03 

EU 003 Boiler 3 (Natural Gas) Nickel 1224 MMBtu/hr 2.40E+00 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 2.94E-03 0.0129 1.29E-02 

EU 003 Boiler 3 (Natural Gas) Nitrous oxides 1224 MMBtu/hr 2.20E-04 lb/MMBtu 40 CFR 98 2.70E-01 1.1819 1.18E+00 

EU 003 Boiler 3 (Natural Gas) NOx 1.2 MMCF/hr 2.80E+02 lb/MMCF AP-42 Table 1.4-1 (7/98) 3.36E+02 1471.6800 1.47E+03 

EU 003 Boiler 3 (Natural Gas) PM 1.2 MMCF/hr 7.60E+00 lb/MMCF AP-42 Table 1.4-2 (7/98) 9.12E+00 39.9456 3.99E+01 EU 003 Boiler 3 (Natural Gas) PM10 1.2 MMCF/hr 7.60E+00 lb/MMCF AP-42 Table 1.4-2 (7/98) 9.12E+00 39.9456 3.99E+01 EU 003 Boiler 3 (Natural Gas) PM2.5 1.2 MMCF/hr 7.60E+00 lb/MMCF 9.12E+00 39.9456 3.99E+01 

EU 003 Boiler 3 (Natural Gas) POMs 1.2 MMCF/hr 6.94E-05 lb/MMCF

AP-42 Table 1.4-3 (7/98) - sum of all 

POMs listed 8.33E-05 0.0004 3.65E-04 

EU 003 Boiler 3 (Natural Gas) Selenium 1224 MMBtu/hr 2.00E-02 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 2.45E-05 0.0001 1.07E-04 

EU 003 Boiler 3 (Natural Gas) SO2 1.2 MMCF/hr 6.00E-01 lb/MMCF AP-42 Table 1.4-2 (7/98) 7.20E-01 3.1536 3.15E+00 
Xcel Energy - Black Dog Generating Plant Particulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficient

Potential to Emit Shading = Worst Case for Specified Pollutant for Specified Unit

Emission 

Unit ID Unit Name Pollutant

Max Process

 Rate

Process Rate

 Units

Emission

 Factor Emission Factor 

Units Emission Factor Source

Emission 

Rate

 (lb/hr)

Uncontrolled 

Potential to Emit

 (ton/yr) 

Pollution 

Control 

Efficiency 

(%) 

Controlled 

Potential to 

Emit (ton/yr)

Limited

Controll

Potential 

Emit (ton

EU 003 Boiler 3 (Natural Gas) Toluene 1224 MMBtu/hr 1.00E+01 lb/10^12 BTU

EPRI Emissions Factor Handbook Table 3-

1 (4/02) 1.22E-02 0.0536 5.36E-02 

EU 003 Boiler 3 (Natural Gas) TOTAL HAPs 2.18E+00 9.55E+00 9.55E+00 EU 003 Boiler 3 (Natural Gas) Total VOC 1.2 MMCF/hr 5.50E+00 lb/MMCF AP-42 Table 1.4-2 (7/98) 6.60E+00 28.9080 2.89E+01 

0.00E+00 

EU 003 Boiler 3 (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 

EU 003 Boiler 3 (Propane) CO2 58.80 MMBtu/hr 1.39E+02 lb/MMBtu 40 CFR 98 8.15E+03 35696 3.57E+04 

EU 003 Boiler 3 (Propane) CO2e 166 MMBtu/hr 1.39E+02 lb/MMBtu 40 CFR 98 2.31E+04 101182.4374 1.01E+05 

EU 003 Boiler 3 (Propane) Methane 166 MMBtu/hr 6.61E-03 lb/MMBtu 40 CFR 98 1.10E+00 4.8088 4.81E+00 

EU 003 Boiler 3 (Propane) Nitrous oxides 166 MMBtu/hr 1.32E-03 lb/MMBtu 40 CFR 98 2.20E-01 0.9618 9.62E-01 

EU 003 Boiler 3 (Propane) NOx 0.45 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 

EU 003 Boiler 3 (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 

EU 003 Boiler 3 (Propane) PM10 0.45 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 

EU 003 Boiler 3 (Propane) PM2.5 0.45 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 

EU 003 Boiler 3 (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 

EU 003 Boiler 3 (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 EU 003 0.00E+00 EU 003 Boiler 3 (Subbituminous Coal) CO2 980 MMBtu/hr 2.10E+02 lb/MMBtu 40 CFR 98 2.06E+05 900374 9.00E+05 

EU 003 Boiler 3 (Subbituminous Coal) CO2e 980 MMBtu/hr 2.11E+02 lb/MMBtu 40 CFR 98 2.07E+05 907488.6019 9.07E+05 

EU 003 Boiler 3 (Subbituminous Coal/Coke) 1,2,4-Trichlorobenzene 1097 MMBtu/hr 1.50E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.65E-03 0.0072 7.21E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) 1,4-Dichlorobenzene 1097 MMBtu/hr 1.10E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.21E-03 0.0053 5.29E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) 2,4-Dinitrotoluene 1097 MMBtu/hr 2.00E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 2.19E-04 0.0010 9.61E-04 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Acetaldehyde 1097 MMBtu/hr 3.20E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 3.51E-03 0.0154 1.54E-02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Acetophenone 1097 MMBtu/hr 1.20E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.32E-03 0.0058 5.77E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Acrolein 1097 MMBtu/hr 1.90E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 2.08E-03 0.0091 9.13E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Antimony 1097 MMBtu/hr 4.09E-02 lb/10^12 BTU

AP-42 Table 1.1-16 (9/98) 

(0.92*(C/A*PM)^0.63) 4.49E-05 0.0002 1.97E-04 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Arsenic 1097 MMBtu/hr 2.07E+00 lb/10^12 BTU

AP-42 Table 1.1-16 (9/98) 

(3.1*(C/A*PM)^0.85) 2.27E-03 0.0099 9.93E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Benzene 1097 MMBtu/hr 3.90E-06 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 4.28E-09 0.0000 1.87E-08 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Benzyl Chloride 1097 MMBtu/hr 2.80E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 3.07E-04 0.0013 1.35E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Beryllium 1097 MMBtu/hr 1.93E-01 lb/10^12 BTU

AP-42 Table 1.1-16 (9/98) 

(1.2*(C/A*PM)^1.1) 2.11E-04 0.0009 9.26E-04 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Biphenyl 1097 MMBtu/hr 1.60E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.76E-04 0.0008 7.69E-04 

EU 003 Boiler 3 (Subbituminous Coal/Coke) bis(2-Ethylexyl)phthalate 1097 MMBtu/hr 3.60E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 3.95E-03 0.0173 1.73E-02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Cadmium 1097 MMBtu/hr 6.13E-01 lb/10^12 BTU

AP-42 Table 1.1-16 (9/98) 

(3.3*(C/A*PM)^0.5) 6.72E-04 0.0029 2.94E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Carbon Disulfide 1097 MMBtu/hr 1.10E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.21E-03 0.0053 5.29E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Chlorobenzene 1097 MMBtu/hr 1.60E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.76E-04 0.0008 7.69E-04 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Chloroform 1097 MMBtu/hr 8.00E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 8.78E-04 0.0038 3.84E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Chromium 1097 MMBtu/hr 6.54E+00 lb/10^12 BTU

AP-42 Table 1.1-16 (9/98) 

(3.7*(C/A*PM)^0.58) 7.18E-03 0.0314 3.14E-02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) CO 59.9 tons/hr 5.00E-01 lb/ton AP-42 Table 1.1-3 (9/98) 3.00E+01 131.1810 1.31E+02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Cobalt 1097 MMBtu/hr 1.98E+00 lb/10^12 BTU

AP-42 Table 1.1-16 (9/98) 

(1.7*(C/A*PM)^0.69) 2.18E-03 0.0095 9.53E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Cyanide 59.9 tons/hr 2.50E-03 lb/ton AP-42 Table 1.1-14 (9/98) 1.50E-01 0.6559 6.56E-01 

EU 003 Boiler 3 (Subbituminous Coal/Coke) DEHP 59.9 tons/hr 7.30E-05 lb/ton AP-42 Table 1.1-14 (9/98) 4.37E-03 0.0192 1.92E-02 EU 003 Boiler 3 (Subbituminous Coal/Coke) Dibenzofuran 1097 MMBtu/hr 5.80E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 6.36E-04 0.0028 2.79E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Dibutylphthalate 1097 MMBtu/hr 1.10E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.21E-04 0.0005 5.29E-04 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Dimethyl Sulfate 59.9 tons/hr 4.80E-05 lb/ton AP-42 Table 1.1-14 (9/98) 2.88E-03 0.0126 1.26E-02 EU 003 Boiler 3 (Subbituminous Coal/Coke) Ethyl Benzene 1097 MMBtu/hr 8.00E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 8.78E-04 0.0038 3.84E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) chloroethane 59.9 tons/hr 4.20E-05 lb/ton AP-42 Table 1.1-14 (9/98) 2.52E-03 0.0110 1.10E-02 EU 003 Boiler 3 (Subbituminous Coal/Coke) Ethylene Dibromide 59.9 tons/hr 1.20E-06 lb/ton AP-42 Table 1.1-14 (9/98) 7.19E-05 0.0003 3.15E-04 EU 003 Boiler 3 (Subbituminous Coal/Coke) 1,2-dichloroethane 59.9 tons/hr 4.00E-05 lb/ton AP-42 Table 1.1-14 (9/98) 2.40E-03 0.0105 1.05E-02 EU 003 Boiler 3 (Subbituminous Coal/Coke) Formaldehyde 1097 MMBtu/hr 2.60E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 2.85E-03 0.0125 1.25E-02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Hexane 59.9 tons/hr 6.70E-05 lb/ton AP-42 Table 1.1-14 (9/98) 4.01E-03 0.0176 1.76E-02 EU 003 Boiler 3 (Subbituminous Coal/Coke) Hydrochloric Acid 59.9 tons/hr 6.65E-03 lb/ton

EPRI Emission Factor Handbook Table 1-8 

(4/02), with 16.17 ppm Cl 3.98E-01 1.7447 1.74E+00 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Hydrogen Fluoride 59.9 tons/hr 3.02E-03 lb/ton

EPRI Emission Factor Handbook Table 1-9 

(4/02), with 25.67 ppm F 1.81E-01 0.7927 7.93E-01 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Isophorone 1097 MMBtu/hr 1.20E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.32E-03 0.0058 5.77E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Lead 1097 MMBtu/hr 6.00E+00 lb/10^12 BTU

AP-42 Table 1.1-16 (9/98) 

(3.4*(C/A*PM)^.8) 6.58E-03 0.0288 2.88E-02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Manganese 1097 MMBtu/hr 1.27E+01 lb/10^12 BTU

AP-42 Table 1.1-16 (9/98) 

(3.8*(C/A*PM)^.6) 1.39E-02 0.0609 6.09E-02 
Xcel Energy - Black Dog Generating Plant Particulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficient

Potential to Emit Shading = Worst Case for Specified Pollutant for Specified Unit

Emission 

Unit ID Unit Name Pollutant

Max Process

 Rate

Process Rate

 Units

Emission

 Factor Emission Factor 

Units Emission Factor Source

Emission 

Rate

 (lb/hr)

Uncontrolled 

Potential to Emit

 (ton/yr) 

Pollution 

Control 

Efficiency 

(%) 

Controlled 

Potential to 

Emit (ton/yr)

Limited

Controll

Potential 

Emit (ton

EU 003 Boiler 3 (Subbituminous Coal/Coke) Mercury 1097 MMBtu/hr 5.69E-06 lb/10^6 BTU Black Dog Stack Test Data 2004 6.24E-03 0.0273 2.73E-02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Methane 1097 MMBtu/hr 2.43E-02 lb/MMBtu 40 CFR 98 2.66E+01 116.5207 1.17E+02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) bromomethane 59.9 tons/hr 1.60E-04 lb/ton AP-42 Table 1.1-14 (9/98) 9.58E-03 0.0420 4.20E-02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Methyl Chloride 59.9 tons/hr 5.30E-04 lb/ton AP-42 Table 1.1-14 (9/98) 3.17E-02 0.1391 1.39E-01 EU 003 Boiler 3 (Subbituminous Coal/Coke) 1,1,1-trichlorothane 1097 MMBtu/hr 6.10E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 6.69E-04 0.0029 2.93E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Methyl Ethyl Ketone 59.9 tons/hr 3.90E-04 lb/ton AP-42 Table 1.1-14 (9/98) 2.34E-02 0.1023 1.02E-01 EU 003 Boiler 3 (Subbituminous Coal/Coke) Methyl Hydrazine 59.9 tons/hr 1.70E-04 lb/ton AP-42 Table 1.1-14 (9/98) 1.02E-02 0.0446 4.46E-02 EU 003 Boiler 3 (Subbituminous Coal/Coke) Methyl Methacrylate 1097 MMBtu/hr 1.10E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.21E-03 0.0053 5.29E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Methyl tert butyl ether 59.9 tons/hr 3.50E-05 lb/ton AP-42 Table 1.1-14 (9/98) 2.10E-03 0.0092 9.18E-03 EU 003 Boiler 3 (Subbituminous Coal/Coke) Methylene Chloride 1097 MMBtu/hr 3.60E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 3.95E-03 0.0173 1.73E-02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Naphthalene 1097 MMBtu/hr 6.20E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 6.80E-04 0.0030 2.98E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Nickel 1097 MMBtu/hr 6.57E+00 lb/10^12 BTU

AP-42 Table 1.1-16 (9/98) 

(4.4*(C/A*PM)^.48) 7.20E-03 0.0315 3.15E-02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Nitrous oxides 1097 MMBtu/hr 3.53E-03 lb/MMBtu 40 CFR 98 3.87 16.95 16.95 

EU 003 Boiler 3 (Subbituminous Coal/Coke) NOx 59.9 tons/hr 1.20E+01 lb/ton AP-42 Table 1.1-3 (9/98) 718.80 3148.34 3148.34 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Phenol 1097 MMBtu/hr 3.30E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 3.62E-03 0.0159 1.59E-02 

EU 003 Boiler 3 (Subbituminous Coal/Coke) PM 59.9 tons/hr 4.64E+01 lb/ton

AP-42 Table 1.1-4 (9/98) (10 x 4.64 % 

Ash) 2779.36 12173.60 99.75% 30.43 1,44

EU 003 Boiler 3 (Subbituminous Coal/Coke) PM10 59.9 tons/hr 1.07E+01 lb/ton

AP-42 Table 1.1-4 (9/98) (2.3 x 4.64 % 

Ash) 639.25 2799.93 99.75% 7.00 

EU 003 Boiler 3 (Subbituminous Coal/Coke) PM2.5 59.9 tons/hr 1.07E+01 lb/ton Assumed same as PM10 639.25 2799.93 99.75% 7.00 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Condensible PM 980.0 MMBtu/hr 3.23E-01 lb/MMBtu AP-42 Table 1.1-5 (0.1 x 3.23% sulfur) 316.54 1386.45 99.75% 3.47 

EU 003 Boiler 3 (Subbituminous Coal/Coke) POMs 1097 MMBtu/hr 2.08E-06 lb/10^12 BTU AP-42 Table 1.1-17 (9/98) 2.28E-09 0.0000 9.99E-09 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Propionaldehyde 1097 MMBtu/hr 1.90E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 2.08E-03 0.0091 9.13E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Selenium 59.9 tons/hr 1.30E-03 lb/ton AP-42 Table 1.1-18 (9/98) 7.79E-02 0.3411 3.41E-01 EU 003 Boiler 3 (Subbituminous Coal/Coke) SO2 59.9 tons/hr 7.35E+00 lb/ton AP-42 Table 1.1-3 (35 x % S) [4] 440.27 1928.36 1928.36 14,41

EU 003 Boiler 3 (Subbituminous Coal/Coke) Styrene 1097 MMBtu/hr 7.00E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 7.68E-04 0.0034 3.36E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Tetrachloroethylene 1097 MMBtu/hr 4.20E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 4.61E-04 0.0020 2.02E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Toluene 1097 MMBtu/hr 1.70E+00 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 1.86E-03 0.0082 8.17E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) TOTAL HAPs 9.63E-01 4.22E+00 4.22E+00 EU 003 Boiler 3 (Subbituminous Coal/Coke) Total VOC 59.9 tons/hr 6.00E-02 lb/ton AP-42 Table 1.1-19 3.59E+00 15.7417 1.57E+01 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Vinyl Acetate 1097 MMBtu/hr 3.10E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 3.40E-04 0.0015 1.49E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Vinyl Chloride 1097 MMBtu/hr 7.30E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 8.01E-04 0.0035 3.51E-03 

EU 003 Boiler 3 (Subbituminous Coal/Coke) Xylenes 1097 MMBtu/hr 8.20E-01 lb/10^12 BTU

EPRI Emission Factor Handbook Table 1-

11 (4/02) 9.00E-04 0.0039 3.94E-03 

EU 003 Boiler 3 (Waste Oil) Antimony 0.4 MGal/hr 5.25E-03 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 2.29E-03 0.0100 1.00E-02 

EU 003 Boiler 3 (Waste Oil) Arsenic 0.4 MGal/hr 1.32E-03 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 5.75E-04 0.0025 2.52E-03 EU 003 Boiler 3 (Waste Oil) Beryllium 0.4 MGal/hr 2.78E-05 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 1.21E-05 0.0001 5.30E-05 EU 003 Boiler 3 (Waste Oil) Cadmium 0.4 MGal/hr 3.98E-04 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 1.73E-04 0.0008 7.59E-04 EU 003 Boiler 3 (Waste Oil) Chromium 0.4 MGal/hr 8.45E-04 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 3.68E-04 0.0016 1.61E-03 EU 003 Boiler 3 (Waste Oil) CO 0.4 MGal/hr 5.00E+00 lb/10^3 Gal AP-42 Table 1.11-2 (10/96) 2.18E+00 9.5387 9.54E+00 

EU 003 Boiler 3 (Waste Oil) CO2 58.80 MMBtu/hr 1.63E+02 lb/MMBtu 40 CFR 98 9.59E+03 42016 4.20E+04 

EU 003 Boiler 3 (Waste Oil) CO2e 58.80 MMBtu/hr 1.64E+02 lb/MMBtu 40 CFR 98 9.63E+03 42159.9341 4.22E+04 

EU 003 Boiler 3 (Waste Oil) Cobalt 0.4 MGal/hr 6.02E-03 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 2.62E-03 0.0115 1.15E-02 

EU 003 Boiler 3 (Waste Oil) Hydrochloric Acid 0.4 MGal/hr 3.56E+00 lb/10^3 GAL

AP-42 Table 1.11-3 (66 X .054% Cl) 

(10/96) 1.55E+00 6.7992 6.80E+00 

EU 003 Boiler 3 (Waste Oil) Lead 0.4 MGal/hr 1.51E-03 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 6.58E-04 0.0029 2.88E-03 

EU 003 Boiler 3 (Waste Oil) Manganese 0.4 MGal/hr 3.00E-03 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 1.31E-03 0.0057 5.72E-03 EU 003 Boiler 3 (Waste Oil) Mercury 0.4 MGal/hr 1.13E-04 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 4.92E-05 0.0002 2.16E-04 EU 003 Boiler 3 (Waste Oil) Methane 58.80 MMBtu/hr 6.61E-03 lb/MMBtu 40 CFR 98 3.89E-01 1.7033 1.70E+00 EU 003 Boiler 3 (Waste Oil) Nickel 0.4 MGal/hr 8.45E-02 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 3.68E-02 0.1612 1.61E-01 EU 003 Boiler 3 (Waste Oil) Nitrous oxides 58.80 MMBtu/hr 1.32E-03 lb/MMBtu 40 CFR 98 7.78E-02 0.3407 3.41E-01 EU 003 Boiler 3 (Waste Oil) NOx 0.4 MGal/hr 1.90E+01 lb/10^3 Gal AP-42 Table 1.11-2 (10/96) 8.28 36.2469 3.62E+01 

EU 003 Boiler 3 (Waste Oil) PM 0.4 MGal/hr 6.40E+01 lb/10^3 Gal

AP-42 Table 1.11-1 (64 X 1% Ash) (10/96) 

[4] 27.88 122.0949 99.75% 3.05E-01 

EU 003 Boiler 3 (Waste Oil) PM10 0.4 MGal/hr 5.10E+01 lb/10^3 Gal

AP-42 Table 1.11-1 (51 X 1 % Ash) 

(10/96) [4] 22.21 97.2944 99.75% 2.43E-01 

EU 003 Boiler 3 (Waste Oil) PM2.5 0.4 MGal/hr 5.10E+01 lb/10^3 Gal

AP-42 Table 1.11-1 (51 X 1 % Ash) 

(10/96) [4] 22.21 97.2944 99.75% 2.43E-01 

EU 003 Boiler 3 (Waste Oil) Selenium 0.4 MGal/hr 6.83E-04 lb/10^3 GAL AP-42 Table 1.3-11 (9/98) Uncontrolled 2.97E-04 0.0013 1.30E-03 

EU 003 Boiler 3 (Waste Oil) SO2 0.4 MGal/hr 5.29E+02 lb/10^3 Gal

AP-42 Table 1.11-2 (147 X 1 % S) (10/96) 

[4] 230.50 1009.57 1009.57 41

EU 003 Boiler 3 (Waste Oil) TOTAL HAPs 1.60E+00 7.00E+00 7.00E+00 EU 003 Boiler 3 (Waste Oil) Total VOC 0.4 MGal/hr 1.00E+00 lb/10^3 Gal AP-42 Table 1.11-3 (10/96) 4.36E-01 1.9077 1.91E+00 

[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 efficiencies were 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+01

Boiler 4 (Bituminous Coal) 90.1 tons/hr Bit Coal S% 3.23E+00

Boiler 4 (Subbituminous Coal) 1890 MMBtu/hr Subbit Coal Ash% 4.64E+00Boiler 4 (Subbituminous Coal) 108 tons/hr Subbit Coal S% 2.10E-01

Boiler 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+00

Boiler 4 (Subbituminous Coal/Coke) 114.3 tons/hrBoiler 4 (Subbituminous Coal/Coke) 1890 MMBtu/hr

Boiler 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-02

Boiler 4 (Natural Gas) 1.9 MMCF/hr Waste oil MMBtu/hr 95

Boiler 4 (Propane) 0.452 1000 gal/hrBoiler 4 (Propane) 166 MMBtu/hr

Xcel Energy - Black Dog Generating Plant Particulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficient

Potential to Emit Shading = Worst Case for Specified Pollutant for Specified Unit

Emission 

Unit ID Unit Name Pollutant

Max Process

 Rate

Process Rate

 Units

Emission

 Factor Emission Factor 

Units Emission Factor Source

Emission 

Rate

 (lb/hr)

Uncontrolled 

Potential to 

Emit

 (ton/yr) 

Pollution 

Control 

Efficiency 

(%) 

Controlled 

Potential to 

Emit (ton/yr)

Limited/ 

Controlled 

Potential to 

Emit (ton/yr

EU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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-03 1.57E-02 1.57E-02 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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-04 1.33E-03 1.33E-03 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 004 Boiler 4 (Bituminous Coal) CO2 1892 MMBtu/hr 2.06E+02 lb/MMBtu 40 CFR 98 389080.51 1704172.62 1704172.62 N

EU 004 Boiler 4 (Bituminous Coal) CO2e 1892 MMBtu/hr 2.07E+02 lb/MMBtu 40 CFR 98 392216.34 1717907.58 1717907.58 N

EU 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 NEU 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 NEU 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 NEU 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 N

EU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 004 Boiler 4 (Bituminous Coal) Hydrochloric Acid 1892 MMBtu/hr 5.93E-02 lb/10^12 BTU

Assume 750 ppm Cl (EPRI Pisces Database 08/98) 

in coal gets converted to HCl and 100% (EPRI 

Emissions Factor Handbook 4/02) goes to 

atmosphere. Assume 13000 Btu/lb (1999 

Performance Report) 1.12E-04 4.91E-04 4.91E-04 N

EU 004 Boiler 4 (Bituminous Coal) Hydrogen Fluoride 1892 MMBtu/hr 5.26E-03 lb/10^12 BTU

Assume 65 ppm F (EPRI Pisces Database 08/98) in 

coal gets converted to HF and 90% (EPRI Emissions 

Factor Handbook 4/02) goes to atmosphere. 

Assume 13000 Btu/lb (1999 Performance Report) 9.96E-06 4.36E-05 4.36E-05 N

EU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 004 Boiler 4 (Bituminous Coal) Nitrous oxides 1892 MMBtu/hr 3.53E-03 lb/MMBtu 40 CFR 98 6.67 29.23 29.23 NEU 004 Boiler 4 (Bituminous Coal) NOX 90.1 tons/hr 2.20E+01 lb/ton AP-42 Table 1.1-3 (9/98) 1982.20 8682.04 8682.04 N

EU 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 N

EU 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 2,486.0EU 004 Boiler 4 (Bituminous Coal) PM10 90.1 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 N

EU 004 Boiler 4 (Bituminous Coal) PM2.5 90.1 tons/hr 2.65E+01 lb/ton Assumed same as PM10 2383.15 10438.18 99.75% 26.10 N

Boiler 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 N

EU 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 NEU 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 NEU 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 NEU 004 Boiler 4 (Bituminous Coal) SO2 90.1 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 24,860.8

EU 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 N

EU 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 N
Xcel Energy - Black Dog Generating Plant Particulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficient

Potential to Emit Shading = Worst Case for Specified Pollutant for Specified Unit

Emission 

Unit ID Unit Name Pollutant

Max Process

 Rate

Process Rate

 Units

Emission

 Factor Emission Factor 

Units Emission Factor Source

Emission 

Rate

 (lb/hr)

Uncontrolled 

Potential to 

Emit

 (ton/yr) 

Pollution 

Control 

Efficiency 

(%) 

Controlled 

Potential to 

Emit (ton/yr)

Limited/ 

Controlled 

Potential to 

Emit (ton/yr

EU 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 NEU 004 Boiler 4 (Bituminous Coal) TOTAL HAPs 1.65E+00 7.21 7.21E+00 NEU 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 NEU 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 NEU 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 NEU 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 N

0.00E+00 

EU 004 Boiler 4 (Coke) CO2 189 MMBtu/hr 2.26E+02 lb/MMBtu 40 CFR 98 4.27E+04 186899 1.87E+05 N

EU 003 Boiler 4 (Coke) CO2e 189 MMBtu/hr 2.27E+02 lb/MMBtu 40 CFR 98 4.30E+04 188271.5201 1.88E+05 N

0.00E+00 

EU 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 NEU 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 NEU 004 Boiler 4 (Natural Gas) Beryllium 1938 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 NEU 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 NEU 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 NEU 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 NEU 004 Boiler 4 (Natural Gas) CO2 1938 MMBtu/hr 1.17E+02 lb/MMBtu 40 CFR 98 2.27E+05 992944 9.93E+05 N

EU 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 N

EU 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 0.0007 6.79E-04 N

EU 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-07 0.0000 1.49E-06 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 0.0204 2.04E-02 NEU 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 NEU 004 Boiler 4 (Natural Gas) NOx 1.9 MMCF/hr 2.80E+02 lb/MMCF AP-42 Table 1.4-1 (7/98) 5.32E+02 2330.1600 2.33E+03 N

EU 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 NEU 004 Boiler 4 (Natural Gas) PM10 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 NEU 004 Boiler 4 (Natural Gas) PM2.5 1.9 MMCF/hr 7.60E+00 lb/MMCF 1.44E+01 63.2472 6.32E+01 NEU 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 N

EU 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 NEU 004 Boiler 4 (Natural Gas) SO2 1.9 MMCF/hr 6.00E-01 lb/MMCF AP-42 Table 1.4-2 (7/98) 1.14E+00 4.9932 4.99E+00 N

EU 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 N

EU 004 Boiler 4 (Natural Gas) TOTAL HAPs 3.45E+00 1.51E+01 1.51E+01 NEU 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 N

0.00E+00 

EU 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 NEU 004 Boiler 4 (Propane) CO2 94.60 MMBtu/hr 1.39E+02 lb/MMBtu 40 CFR 98 1.31E+04 57430 5.74E+04 N

EU 004 Boiler 4 (Propane) CO2e 166 MMBtu/hr 1.39E+02 lb/MMBtu 40 CFR 98 2.31E+04 101182.4374 1.01E+05 N

EU 004 Boiler 4 (Propane) Methane 166 MMBtu/hr 6.61E-03 lb/MMBtu 40 CFR 98 1.10E+00 4.8088 4.81E+00 NEU 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 NEU 004 Boiler 4 (Propane) NOx 0.45 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 N

EU 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 NEU 004 Boiler 4 (Propane) PM10 0.45 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 NEU 004 Boiler 4 (Propane) PM2.5 0.45 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 NEU 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 NEU 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 N

0.00E+00 

EU 004 Boiler 4 (Subbituminous Coal) CO2 1890 MMBtu/hr 2.10E+02 lb/MMBtu 40 CFR 98 396446.61 1736436 1.74E+06 N

EU 004 Boiler 4 (Subbituminous Coal) CO2e 1890 MMBtu/hr 2.11E+02 lb/MMBtu 40 CFR 98 399579.13 1750156.5893 1.75E+06 N

EU 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 N

EU 004 Boiler 4 (Subbituminous Coal/Coke) 1,4-Dichlorobenzene 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 004 Boiler 4 (Subbituminous Coal/Coke) Beryllium 1890 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 N

EU 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 N

EU 004 Boiler 4 (Subbituminous Coal/Coke) bis(2-Ethylexyl)phthalate 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 N
Xcel Energy - Black Dog Generating Plant Particulate control: each boiler is controlled by 2 ESPs in series. Each is 95% efficient

Potential to Emit Shading = Worst Case for Specified Pollutant for Specified Unit

Emission 

Unit ID Unit Name Pollutant

Max Process

 Rate

Process Rate

 Units

Emission

 Factor Emission Factor 

Units Emission Factor Source

Emission 

Rate

 (lb/hr)

Uncontrolled 

Potential to 

Emit

 (ton/yr) 

Pollution 

Control 

Efficiency 

(%) 

Controlled 

Potential to 

Emit (ton/yr)

Limited/ 

Controlled 

Potential to 

Emit (ton/yr

EU 004 Boiler 4 (Subbituminous Coal/Coke) Hydrochloric Acid 114.3 tons/hr 6.65E-03 lb/ton

EPRI Emission Factor Handbook Table 1-8 (4/02), 

with 16.17 ppm Cl 7.60E-01 3.3292 3.33E+00 N

EU 004 Boiler 4 (Subbituminous Coal/Coke) Hydrogen Fluoride 114.3 tons/hr 3.02E-03 lb/ton

EPRI Emission Factor Handbook Table 1-9 (4/02), 

with 25.67 ppm F 3.45E-01 1.5127 1.51E+00 N

EU 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 NEU 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-02 0.0497 4.97E-02 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 004 Boiler 4 (Subbituminous Coal/Coke) Methyl Methacrylate 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 004 Boiler 4 (Subbituminous Coal/Coke) NOx 114.3 tons/hr 1.20E+01 lb/ton AP-42 Table 1.1-3 (9/98) 1371.60 6007.61 6007.61 N

EU 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 NEU 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 2,483.4EU 004 Boiler 4 (Subbituminous Coal/Coke) PM10 114.3 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 NEU 004 Boiler 4 (Subbituminous Coal/Coke) PM2.5 114.3 tons/hr 1.07E+01 lb/ton Assumed same as PM10 1219.81 5342.77 99.75% 13.36 N

Boiler 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 N

EU 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 NEU 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 NEU 004 Boiler 4 (Subbituminous Coal/Coke) Selenium 114.3 tons/hr 1.30E-03 lb/ton AP-42 Table 1.1-18 (9/98) 1.49E-01 0.6508 6.51E-01 NEU 004 Boiler 4 (Subbituminous Coal/Coke) SO2 114.3 tons/hr 7.35E+00 lb/ton AP-42 Table 1.1-3 (35 x % S) [4] 840.11 3679.66 3679.66 24,834.6

EU 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 NEU 004 Boiler 4 (Subbituminous Coal/Coke) Tetrachloroethylene 1890 MMBtu/hr 4.20E-01 lb/10^12 BTU EPRI Emission Factor Handbook Table 1-11 (4/02) 7.94E-04 0.0035 3.48E-03 NEU 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 NEU 004 Boiler 4 (Subbituminous Coal/Coke) TOTAL HAPs 1.82E+00 7.98E+00 7.98E+00 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 004 Boiler 4 (Waste Oil) CO2 94.60 MMBtu/hr 1.63E+02 lb/MMBtu 40 CFR 98 1.54E+04 67597 6.76E+04 NEU 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 N

EU 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 N

EU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 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 NEU 004 Boiler 4 (Waste Oil) NOx 0.7 MGal/hr 1.90E+01 lb/10^3 Gal AP-42 Table 1.11-2 (10/96) 13.31 58.3156 5.83E+01 N

EU 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 N

EU 004 Boiler 4 (Waste Oil) PM10 0.7 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 N

Boiler 4 (Waste Oil) PM2.5 0.7 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 N

EU 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 NEU 004 Boiler 4 (Waste Oil) SO2 0.7 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 1624.24 662.9

EU 004 Boiler 4 (Waste Oil) TOTAL HAPs 2.57E+00 1.13E+01 1.13E+01 NEU 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 N

[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 efficiencies were 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 PM10 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 SO2 3068.0 MMBtu/hr 1.30E+00 lb/MMBtu 3988 17469 Assume PM2.5 is the same

GP002 SO2 3.99E+03 lb/hr 3988.00 17467.44
EU 024 Emergency Engine Generator (Diesel) 121.000 gal/hr

Emergency Engine Generator (Diesel) 16.577 MMBtu/hrEmergency Engine Generator (Diesel) 2598 HP

EU 025 Emergency Engine Generator (Diesel) 121.000 gal/hr

Emergency Engine Generator (Diesel) 16.577 MMBtu/hr

EU028 Fire Pump 1.425 MMBtu/hr

Fire Pump 208 HP

Xcel Energy - Black Dog Generating Plant

Potential to Emit

Emission 

Unit ID Unit Name Pollutant

Max 

Process

 Rate

Process Rate

 Units

Emission

 Factor Emission 

Factor Units Emission Factor Source

Emission 

Rate

 (lb/hr)

Uncontrolled 

Potential to 

Emit

 (ton/yr)

Pollution 

Control 

Efficiency 

(%)

Controlled 

Potential to 

Emit (ton/yr)

Limited 

Potential to 

Emit 

(ton/yr) lb/mmbtu Existing Permit Limit

EU 024 Emergency Engine Generator (Diese CO 16.58 MMBtu/hr 1.05E+01 lb/hr Manufacturer's Data 10.4583 45.8074 0 45.8074 4.2670

EU 024 Emergency Engine Generator (Diesel) NOx 16.58 MMBtu/hr 8.19E+01 lb/hr Manufacturer's Data 81.8849 358.6558 0 358.6558 35.3000

EU 024 Emergency Engine Generator (Diese PM 16.58 MMBtu/hr 4.87E-01 lb/hr Manufacturer's Data 0.4869 2.1325 0 2.1325 0.1986

EU 024 Emergency Engine Generator (Diese PM10 16.58 MMBtu/hr 4.87E-01 lb/hr Manufacturer's Data 0.4869 2.1325 0 2.1325 0.1986EU 024 Emergency Engine Generator (Diese PM2.5 16.58 MMBtu/hr 4.87E-01 lb/hr Assumed same as PM10 0.4869 2.1325 0 2.1325 0.1986EU 024 Emergency Engine Generator (Diese SO2 16.58 MMBtu/hr 5.05E-02 lb/MMBtu AP-42 3.4-1 0.8371 3.6667 0 3.6667 0.3416 0.05

EU 024 Emergency Engine Generator (Diese Total VOC 16.58 MMBtu/hr 1.91E+00 lb/hr Manufacturer's Data 1.9051 8.3444 0 8.3444 0.7773

EU 024 Emergency Engine Generator (Diese CO2 16.58 MMBtu/hr 1.61E+02 lb/MMBtu 40 CFR 98 2676.9692 11725.1250 0 11725.1250 1092.2034EU 024 Emergency Engine Generator (Diese Methane 16.58 MMBtu/hr 6.61E-03 lb/MMBtu 40 CFR 98 0.1096 0.4802 0 0.4802 0.0447EU 024 Emergency Engine Generator (Diese Nitrous oxides 16.58 MMBtu/hr 1.32E-03 lb/MMBtu 40 CFR 98 0.0219 0.0960 0 0.0960 0.0089EU 024 Emergency Engine Generator (Diese CO2e 16.58 MMBtu/hr 1.62E+02 lb/MMBtu 40 CFR 98 2686.2445 11765.7507 0 11765.7507 1095.9877

EU 024 Emergency Engine Generator (Diese Acetaldehyde 16.58 MMBtu/hr 2.52E-05 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0004 0.0018 0 0.0018 0.0002EU 024 Emergency Engine Generator (Diese Acrolien 16.58 MMBtu/hr 7.88E-06 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0001 0.0006 0 0.0006 0.0001

EU 024 Emergency Engine Generator (Diese Benzene 16.58 MMBtu/hr 7.76E-04 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0129 0.0563 0 0.0563 0.0052

EU 024 Emergency Engine Generator (Diese Formaldehyde 16.58 MMBtu/hr 7.89E-05 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0013 0.0057 0 0.0057 0.0005EU 024 Emergency Engine Generator (Diese Naphthalene 16.58 MMBtu/hr 1.30E-04 lb/MMBtu AP-42 Table 3.4-4 (10/96) 0.0022 0.0094 0 0.0094 0.0009EU 024 Emergency Engine Generator (Diese Toluene 16.58 MMBtu/hr 2.81E-04 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0047 0.0204 0 0.0204 0.0019EU 024 Emergency Engine Generator (Diese Xylenes 16.58 MMBtu/hr 1.93E-04 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0032 0.0140 0 0.0140 0.0013EU 024 Emergency Engine Generator (Diese TOTAL HAPs 0.0247 0.1083 0 0.1083 0.0101

EU 025 Emergency Engine Generator (Diese CO 16.58 MMBtu/hr NA NA Manufacturer's Data 10.4583 45.8074 0 45.8074 4.2670

EU 025 Emergency Engine Generator (Diesel) NOx 16.58 MMBtu/hr NA NA Manufacturer's Data 81.8849 358.6558 0 358.6558 35.3000

EU 025 Emergency Engine Generator (Diese PM 16.58 MMBtu/hr NA NA Manufacturer's Data 0.4869 2.1325 0 2.1325 0.1986

EU 025 Emergency Engine Generator (Diese PM10 16.58 MMBtu/hr NA NA Manufacturer's Data 0.4869 2.1325 0 2.1325 0.1986EU 025 Emergency Engine Generator (Diese PM2.5 16.58 MMBtu/hr NA NA Assumed same as PM10 0.4869 2.1325 0 2.1325 0.1986EU 025 Emergency Engine Generator (Diesel) SO2 16.58 MMBtu/hr 5.05E-02 lb/MMBtu AP-42 3.4-1 0.8371 3.6667 0 3.6667 0.3416 0.05

EU 025 Emergency Engine Generator (Diese Total VOC 16.58 MMBtu/hr NA NA Manufacturer's Data 1.9051 8.3444 0 8.3444 0.7773

EU 025 Emergency Engine Generator (Diese CO2 16.58 MMBtu/hr 1.61E+02 lb/MMBtu 40 CFR 98 2676.9692 11725.1250 0 11725.1250 1092.2034EU 025 Emergency Engine Generator (Diese Methane 16.58 MMBtu/hr 6.61E-03 lb/MMBtu 40 CFR 98 0.1096 0.4802 0 0.4802 0.0447EU 025 Emergency Engine Generator (Diese Nitrous oxides 16.58 MMBtu/hr 1.32E-03 lb/MMBtu 40 CFR 98 0.0219 0.0960 0 0.0960 0.0089EU 025 Emergency Engine Generator (Diese CO2e 16.58 MMBtu/hr 1.62E+02 lb/MMBtu 40 CFR 98 2686.2445 11765.7507 0 11765.7507 1095.9877EU 025 Emergency Engine Generator (Diese Acetaldehyde 16.58 MMBtu/hr 2.52E-05 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0004 0.0018 0 0.0018 0.0002EU 025 Emergency Engine Generator (Diese Acrolien 16.58 MMBtu/hr 7.88E-06 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0001 0.0006 0 0.0006 0.0001

EU 025 Emergency Engine Generator (Diese Benzene 16.58 MMBtu/hr 7.76E-04 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0129 0.0563 0 0.0563 0.0052

EU 025 Emergency Engine Generator (Diese Formaldehyde 16.58 MMBtu/hr 7.89E-05 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0013 0.0057 0 0.0057 0.0005EU 025 Emergency Engine Generator (Diese Naphthalene 16.58 MMBtu/hr 1.30E-04 lb/MMBtu AP-42 Table 3.4-4 (10/96) 0.0022 0.0094 0 0.0094 0.0009EU 025 Emergency Engine Generator (Diese Toluene 16.58 MMBtu/hr 2.81E-04 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0047 0.0204 0 0.0204 0.0019EU 025 Emergency Engine Generator (Diese Xylenes 16.58 MMBtu/hr 1.93E-04 lb/MMBtu AP-42 Table 3.4-3 (10/96) 0.0032 0.0140 0 0.0140 0.0013EU 025 Emergency Engine Generator (Diese TOTAL HAPs 0.0247 0.1083 0 0.1083 0.0101

EU028 Fire Pump (Diesel) CO 1.42 MMBTU/hr 9.50E-01 lb/MMBtu AP-42 Table3.3-1 (10/96) 1.3536 0.3384 0 0.3384 Can assume 500 hrs/yea

EU028 Fire Pump (Diesel) NOx 1.42 MMBTU/hr 4.41E+00 lb/MMBtu AP-42 Table3.3-1 (10/96) 6.2834 1.5708 0 1.5708 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) PM 1.42 MMBTU/hr 3.10E-01 lb/MMBtu AP-42 Table3.3-1(10/96) 0.4417 0.1104 0 0.1104 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) PM10 1.42 MMBTU/hr 3.10E-01 lb/MMBtu AP-42 Table3.3-1(10/96) 0.4417 0.1104 0 0.1104 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) PM2.5 1.42 MMBTU/hr 3.10E-01 lb/MMBtu Assumed same as PM10 0.4417 0.1104 0 0.1104 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) SO2 1.42 MMBTU/hr 5.05E-02 lb/MMBtu AP-42 3.4-1 0.0720 0.0180 0 0.0180 5.05E-02 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) Total VOC 1.42 MMBTU/hr 3.60E-01 lb/MMBtu AP-42 Table3.3-1(10/96) 0.5129 0.1282 0 0.1282 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) CO2 1.42 MMBtu/hr 1.61E+02 lb/MMBtu 40 CFR 98 230.0866 57.5217 0 57.5217 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) Methane 1.42 MMBtu/hr 6.61E-03 lb/MMBtu 40 CFR 98 0.0094 0.0024 0 0.0024 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) Nitrous oxides 1.42 MMBtu/hr 1.32E-03 lb/MMBtu 40 CFR 98 0.0019 4.71E-04 0 0.0005 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) CO2e 1.42 MMBtu/hr 1.62E+02 lb/MMBtu 40 CFR 98 230.8838 57.7210 0 57.7210 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) Acetaldehyde 1.42 MMBTU/hr 7.67E-04 lb/MMBtu AP-42 Table3.3-2 (10/96) 1.09E-03 2.73E-04 0 0.0003 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) Acrolien 1.42 MMBTU/hr 4.63E-05 lb/MMBtu AP-42 Table3.3-2 (10/96) 6.59E-05 1.65E-05 0 0.0000 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) 1,3-Butadiene 1.42 MMBTU/hr 1.96E-05 lb/MMBtu AP-42 Table3.3-2 (10/96) 2.79E-05 6.96E-06 0 0.0000 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) Benzene 1.42 MMBTU/hr 9.33E-04 lb/MMBtu AP-42 Table3.3-2 (10/96) 1.33E-03 3.32E-04 0 0.0003 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) Formaldehyde 1.42 MMBTU/hr 1.18E-03 lb/MMBtu AP-42 Table3.3-2 (10/96) 1.68E-03 4.20E-04 0 0.0004 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) Naphthalene 1.42 MMBTU/hr 8.48E-05 lb/MMBtu AP-42 Table3.3-2 (10/96) 1.21E-04 3.02E-05 0 0.0000 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) Toluene 1.42 MMBTU/hr 4.09E-04 lb/MMBtu AP-42 Table3.3-2 (10/96) 5.83E-04 1.46E-04 0 0.0001 Can assume 500 hrs/yea

EU028 Fire Pump (Diesel) Xylenes 1.42 MMBTU/hr 2.85E-04 lb/MMBtu AP-42 Table3.3-2 (10/96) 4.06E-04 1.02E-04 0 0.0001 Can assume 500 hrs/yeaEU028 Fire Pump (Diesel) Total HAPs 0.0053 1.33E-03 0 0.0013 Can assume 500 hrs/yea

GP001 CO 4.27 816 hours per year EU024 & EU025 combined

GP001 NOx 35.30 35.3 tpy EU024 & EU025 combinedGP001 PM 1.99E-01 816 hours per year EU024 & EU025 combinedGP001 PM10 1.99E-01 816 hours per year EU024 & EU025 combinedGP001 PM2.5 1.99E-01 816 hours per year EU024 & EU025 combinedGP001 SO2 3.42E-01 816 hours per year EU024 & EU025 combinedGP001 Total VOC 7.77E-01 816 hours per year EU024 & EU025 combinedGP001 CO2 1092.20 816 hours per year EU024 & EU025 combinedGP001 Methane 4.47E-02 816 hours per year EU024 & EU025 combinedGP001 Nitrous oxides 8.95E-03 816 hours per year EU024 & EU025 combinedGP001 CO2e 1095.99 816 hours per year EU024 & EU025 combinedGP001 Acetaldehyde 1.70E-04 816 hours per year EU024 & EU025 combinedGP001 Acrolien 5.33E-05 816 hours per year EU024 & EU025 combinedGP001 Benzene 5.25E-03 816 hours per year EU024 & EU025 combinedGP001 Formaldehyde 5.34E-04 816 hours per year EU024 & EU025 combinedGP001 Naphthalene 8.79E-04 816 hours per year EU024 & EU025 combinedGP001 Toluene 1.90E-03 816 hours per year EU024 & EU025 combinedGP001 Xylenes 1.31E-03 816 hours per year EU024 & EU025 combinedGP001 TOTAL HAPs 1.01E-02 816 hours per year EU024 & EU025 combined
EU 026 Combustion Turbine (NG) 1.88 MMCF/hr

Combustion Turbine (NG) 1020.00 Btu/cfCombustion Turbine (NG) 1917.46 MMBtu/hrCombustion Turbine (NG) 83960.00 lb/hr

Xcel Energy - Black Dog Generating Plant

Potential to Emit 0.0034

Emission 

Unit ID Unit Name Pollutant

Max 

Process

 Rate

Process Rate

 Units

Emission

 Factor Emission Factor 

Units Emission Factor Source

Emission 

Rate

 (lb/hr)

Uncontrolled 

Potential to 

Emit

 (ton/yr)

Pollution 

Control 

Efficiency 

(%)

Controlled 

Potential to 

Emit 

(ton/yr)

Limi

Potent

Em

(ton/

EU 026 Combustion Turbine (NG) CO 1917.46 MMBtu/hr 4.20E+01 lb/hr Manufacturer 42.00 183.9600 183.9600 EU 026 Combustion Turbine (NG) NOX 1917.46 MMBtu/hr 1.73E+02 lb/hr Manufacturer 172.50 755.5500 82 132.7501 

EU 026 Combustion Turbine (NG) PM 1917.46 MMBtu/hr 9.0E+00 lb/hr Manufacturer (lb/hr) 9.00 39.4200 39.4200 EU 026 Combustion Turbine (NG) PM10 1917.46 MMBtu/hr 1.80E+01 lb/hr Manufacturer (lb/hr) 18.00 78.8400 78.8400 1EU 026 Combustion Turbine (NG) PM2.5 1917.46 MMBtu/hr 1.80E+01 lb/hr Assumed same as PM10 18.00 78.8400 78.8400 1

EU 026 Combustion Turbine (NG) SO2 1917.46 MMBtu/hr 2.27E+00 lb/hr Manufacturer (lb/hr) 2.27 9.9280 9.9280 

EU 026 Combustion Turbine (NG) Total VOC 1917.46 MMBtu/hr 4.8E+00 lb/hr Manufacturer 4.80 21.0240 21.0240 EU 026 Combustion Turbine (NG) CO2 1917.46 MMBtu/hr 1.2E+02 lb/mmBtu CEMS 227909.29 998243 998243 EU 026 Combustion Turbine (NG) Methane 1917.46 MMBtu/hr 2.2E-03 lb/mmBtu 40 CFR 98 4.23 18.5153 18.5153 EU 026 Combustion Turbine (NG) Nitrous oxides 1917.46 MMBtu/hr 2.2E-04 lb/mmBtu 40 CFR 98 0.42 1.8515 1.8515 EU 026 Combustion Turbine (NG) CO2e 1917.46 MMBtu/hr 1.19E+02 lb/mmBtu CEMS & 40 CFR 98 228140.94 999257 999257 

EU 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 EU 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 EU 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 EU 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 EU 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 EU 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 EU 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 EU 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 EU 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 EU 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 EU 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 

Total HAP 6.55E-01 2.87 2.87 

[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 Emit

controlled 

lb/hr Limited Tpy

CO 400.00NOX 305.00

PM10 29.40 128.77

Total 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 = 3.56
EU 027 Supplemental Duct Firing Burners (NG) 0.5 MMCF/hr

Supplemental Duct Firing Burners (NG) 1020.0 Btu/cfSupplemental Duct Firing Burners (NG) 509.6 MMBTU/hr

Xcel Energy - Black Dog Generating Plant

Potential to Emit

Emission 

Unit ID Unit Name Pollutant

Max 

Process

 Rate

Process 

Rate

 Units

Emission

 Factor Emission Factor 

Units Emission Factor Source

Emission Rate

 (lb/hr)

Uncontrolled 

Potential to 

Emit

 (ton/yr)

Pollution 

Control 

Efficiency (%)

Controlled 

Potential to 

Emit (ton/yr)

EU 027 Supplemental Duct Firing Burners (NG) CO 509.6 MMBtu/hr 1.00E-01 lb/mmBtu Manufacturer's Data 5.10E+01 223.2048 223 

EU 027 Supplemental Duct Firing Burners (NG) NOX 509.6 MMBtu/hr 1.00E-01 lb/mmBtu Manufacturer's Data 5.10E+01 223.2048 82 39.2171 EU 027 Supplemental Duct Firing Burners (NG) PM 509.6 MMBtu/hr 2.00E-02 lb/mmBtu Manufacturer's Data 1.02E+01 44.6410 44.6410 EU 027 Supplemental Duct Firing Burners (NG) PM10 509.6 MMBtu/hr 2.00E-02 lb/mmBtu Manufacturer's Data 1.02E+01 44.6410 44.6410 EU 027 Supplemental Duct Firing Burners (NG) PM2.5 509.6 MMBtu/hr 2.00E-02 lb/mmBtu Assumed same as PM10 1.02E+01 44.6410 44.6410 EU 027 Supplemental Duct Firing Burners (NG) SO2 0.5 MMCF/hr 6.00E-01 lb/MMCF AP-42 1.4-2 (7/98) 3.00E-01 1.3130 1.3130 

EU 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 

EU 027 Supplemental Duct Firing Burners (NG) CO2 509.6 MMBtu/hr 1.19E+02 lb/mmBtu CEMS 6.06E+04 265301 265301 

EU 027 Supplemental Duct Firing Burners (NG) Methane 509.6 MMBtu/hr 2.20E-03 lb/mmBtu 40 CFR 98 1.12E+00 4.9208 4.9208 EU 027 Supplemental Duct Firing Burners (NG) Nitrous oxides 509.6 MMBtu/hr 2.20E-04 lb/mmBtu 40 CFR 98 1.12E-01 0.4921 0.4921 EU 027 Supplemental Duct Firing Burners (NG) CO2e 509.6 MMBtu/hr 1.19E+02 lb/mmBtu CEMS & 40 CFR 98 6.06E+04 265571 265571 EU 027 Supplemental Duct Firing Burners (NG) Benzene 509.6 MMBtu/hr 8.00E-01 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 4.08E-04 1.79E-03 1.79E-03 EU 027 Supplemental Duct Firing Burners (NG) Arsenic 509.6 MMBtu/hr 2.30E-01 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 1.17E-04 5.13E-04 5.13E-04 EU 027 Supplemental Duct Firing Burners (NG) Cobalt 509.6 MMBtu/hr 8.00E-02 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 4.08E-05 1.79E-04 1.79E-04 EU 027 Supplemental Duct Firing Burners (NG) Beryllium 509.6 MMBtu/hr 1.00E-02 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 5.10E-06 2.23E-05 2.23E-05 EU 027 Supplemental Duct Firing Burners (NG) Cadmium 509.6 MMBtu/hr 4.00E-02 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 2.04E-05 8.93E-05 8.93E-05 EU 027 Supplemental Duct Firing Burners (NG) Manganese 509.6 MMBtu/hr 4.00E-01 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 2.04E-04 8.93E-04 8.93E-04 EU 027 Supplemental Duct Firing Burners (NG) Mercury 509.6 MMBtu/hr 8.00E-04 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 4.08E-07 1.79E-06 1.79E-06 EU 027 Supplemental Duct Firing Burners (NG) Nickel 509.6 MMBtu/hr 2.40E+00 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 1.22E-03 5.36E-03 5.36E-03 EU 027 Supplemental Duct Firing Burners (NG) Chromium 509.6 MMBtu/hr 1.10E+00 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 5.61E-04 2.46E-03 2.46E-03 EU 027 Supplemental Duct Firing Burners (NG) Formaldehyde 509.6 MMBtu/hr 2.09E-05 lb/mmBtu Test Data from 6/27/02 1.07E-02 4.67E-02 4.67E-02 EU 027 Supplemental Duct Firing Burners (NG) Hexane 0.5 MMCF/hr 1.80E+00 lb/MMCF AP-42 Table 1.4-3 (7/98) 8.99E-01 3.94E+00 3.94E+00 EU 027 Supplemental Duct Firing Burners (NG) Lead 0.5 MMCF/hr 5.00E-04 lb/MMCF EPRI Emissions Factor Handbook Table 3-1 (4/02) 2.50E-04 1.09E-03 1.09E-03 EU 027 Supplemental Duct Firing Burners (NG) Naphthalene 0.5 MMCF/hr 6.10E-04 lb/MMCF AP-42 Table 1.4-3 (7/98) 3.05E-04 1.33E-03 1.33E-03 EU 027 Supplemental Duct Firing Burners (NG) POMs 0.5 MMCF/hr 8.65E-05 lb/MMCF AP-42 Table 1.4-3 (7/98) - sum of all POMs listed 4.32E-05 1.89E-04 1.89E-04 EU 027 Supplemental Duct Firing Burners (NG) Toluene 509.6 MMBtu/hr 1.00E+01 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 5.10E-03 2.23E-02 2.23E-02 EU 027 Supplemental Duct Firing Burners (NG) Selenium 509.6 MMBtu/hr 2.00E-02 lb/10^12 Btu EPRI Emissions Factor Handbook Table 3-1 (4/02) 1.02E-05 4.46E-05 4.46E-05 EU 027 Supplemental Duct Firing Burners (NG) TOTAL HAPs 9.18E-01 4.02E+00 4.02E+00 

[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 Plant

Coal Storage Piles

Equation: Wind Erosion Storage PilesSource: AP-42 13.2.5 - Industrial Wind Erosion and PM-10 Air Quality Modeling Analysis, April 1998

E = 1.7 (s/1.5)*(365-p/235)*(f/15) lb/day/acre

E = 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 0.38

Maximum Pollution Maximum Limited Limited

Emissions Emissions Uncontrolled Control Controlled Controlled Controlled

Particulate Sources Factor Rate Emissions Efficiency Emissions Emissions Emissions

(lb/day/acre) (lb/day) (tons/yr) (%) (tons/yr) (tons/yr) (lb/hr) Acres

Coal Storage Pile A (Erosion) PM 5.12 10.24 1.87 40.0 1.12 1.122 22 Acres PM10 2.56 5.12 0.93 40.0 0.56 0.561 2

PM2.5 0.38 0.77 0.14 40.0 0.08 0.084 2

Coal Storage Pile B (Erosion) PM 5.12 25.61 4.67 40.0 2.80 2.805 55 Acres PM10 2.56 12.81 2.34 40.0 1.40 1.402 5

PM2.5 0.38 1.92 0.35 40.0 0.21 0.210 5

Coal Storage Pile C (Erosion) PM 5.12 20.49 3.74 40.0 2.24 2.244 44 Acres PM10 2.56 10.24 1.87 40.0 1.12 1.122 4

PM2.5 0.38 1.54 0.28 40.0 0.17 0.168 4

Coal Storage Pile D (Erosion) PM 5.12 17.93 3.27 40.0 1.96 1.963 3.54 Acres PM10 2.56 8.96 1.64 40.0 0.98 0.982 3.5

PM2.5 0.38 1.34 0.25 40.0 0.15 0.147 3.5

FS004 Coal Storage Piles (ALL) - Erosion PM 13.56 8.13 8.13 1.86

PM10 6.78 4.07 4.07 0.93

PM2.5 1.02 0.61 0.61 0.14

Ash Hauling

Equation: 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)b

E = size-specific emission factor (lb/VMT)k = particle size multiplier (PM = 4.9, PM10 = 1.5, PM2.5 = 0.15) from Table 13.2.2-2

s = 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 PM10 lb/VMT PM2.5 VMT Miles/day Lb/da

28.5 5.1 5 7.41 2.27 0.23 0.77 5.728.5 5.1 5 7.41 2.27 0.23 0.77 5.7

Total: 1.540 11.4

Equation: 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 PM10 0.0022 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 PM10 lb/VMT PM2.5 lb/VMT Miles/day Lb/day PM Lb/day 

12 28.5 3.22 0.64 0.05 1.44 4.632 0.912 28.5 3.22 0.64 0.05 1.44 4.632 0.9

Total: 2.880 9.264 1.8

Assumed

Maximum Pollution Maximum Limited Limited

Emissions Uncontrolled Control Controlled Controlled Controlled

Rate Emissions Efficiency Emissions Emissions Emissions

Summary of Fly Ash and Bottom Ash Hauling Particulate Sources (lb/VMT) (lb/day) (tons/yr) (%) (tons/yr) (tons/yr) (lb/hr)FS013, Ash Hauling Traffic PM see basis tables 20.68 3.77 40 2.3 2.265 0.52

PM10 see basis tables 5.35 0.98 40 0.6 0.586 0.13

PM2.5 see basis tables 0.50 0.09 40 0.1 0.054 0.01

Particulate Emission Calculations

1) Ash Trucks (Unpaved Roads)2) Bottom Ash Trucks (Unpaved Roads)1) Fly Ash Trucks (Paved Roads)2) Fly Ash Trucks (Paved Roads)
Misc PM Sources

Equation: Continuous and Batch Drop Unloading Source: AP-42 13.2.4 - Aggregate handling of storage piles (11/06)

E = emission factor lb/ton

E = k(0.0032) (U/5)^1.3 k = particle size multiplier (PM = 0.74, PM10 = 0.35, PM2.5 0.053), 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) 

Coal 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) 

Coal 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) 

Fly 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) 

Fly 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) 

Fly 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) 

Maximum Pollution Maximum Limited

Emission Emission Uncontrolled Control Controlled Controlled

Factor Rate Emissions Efficiency Emissions Emissions Primary Capacity Rate Secondar

(lb/ton) (lb/Unit time) (Unit time) (tons/yr) (%) (tons/yr) (tons/yr) (lb/hr) (tons/unit time) (unit time) (tons/unit 

FS003, Emergency Reclaim Hopper PM 1.7527E-03 10.5162 day 1.919 0 1.919 1.919 0.44 6000 day 600

PM10 8.2898E-04 4.9739 day 0.908 0 0.908 0.908 0.21 6000 day 600

PM2.5 1.2553E-04 0.7532 day 0.137 0 0.137 0.137 0.03 6000 day 600

FS008, Coal Outstacking PM 1.7527E-03 17.5269 day 3.199 40 1.919 1.919 0.44 10000 day

PM10 8.2898E-04 8.2898 day 1.513 40 0.908 0.908 0.21 10000 day

PM2.5 1.2553E-04 1.2553 day 0.229 40 0.137 0.137 0.03 10000 day

FS009, Coal Reclaim PM 1.7527E-03 10.5162 day 1.919 40 1.152 1.152 0.26 6000 day

PM10 8.2898E-04 4.9739 day 0.908 40 0.545 0.545 0.12 6000 day

PM2.5 1.2553E-04 0.7532 day 0.137 40 0.082 0.082 0.02 6000 day

FS015, Coal Conveyors 7, 7B & 7C PM 1.7527E-03 10.5162 day 1.919 0 1.919 1.919 0.44 6000 day

PM10 8.2898E-04 4.9739 day 0.908 0 0.908 0.908 0.21 6000 day

PM2.5 1.2553E-04 0.7532 day 0.137 0 0.137 0.137 0.03 6000 day

FS016, Coal Conveyor 8 PM 1.7527E-03 1.0516 hour 1.919 0 1.919 1.919 1.05 600 hour 600(1 transfer point); (600 lb/hr; 6,000 tons/day) PM10 8.2898E-04 0.4974 hour 0.908 0 0.908 0.908 0.50 600 hour 600

PM2.5 1.2553E-04 0.0753 hour 0.137 0 0.137 0.137 0.08 600 hour 600

FS017, Dumper Unloading Building PM 1.7527E-03 17.5269 day 3.199 75 0.800 0.800 0.18 10000 day

PM10 8.2898E-04 8.2898 day 1.513 75 0.378 0.378 0.09 10000 day

PM2.5 1.2553E-04 1.2553 day 0.229 75 0.057 0.057 0.01 10000 day

ISA, 3&4 Fly Ash Loadout PM 1.7527E-03 1.4898 day 0.272 75 0.068 0.068 0.02 850 day

PM10 8.2898E-04 0.7046 day 0.129 75 0.032 0.032 0.01 850 day

PM2.5 1.2553E-04 0.1067 day 0.019 75 0.005 0.005 0.00 850 day

ISA, 200 Ton Stacking Hopper Loadout PM 1.7527E-03 17.5269 day 3.199 0 3.199 3.199 0.73 10000 day

PM10 8.2898E-04 8.2898 day 1.513 0 1.513 1.513 0.35 10000 day

PM2.5 1.2553E-04 1.2553 day 0.229 0 0.229 0.229 0.05 10000 day

ISA, Breaker Bldg Reject Chutes PM 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) PM10 8.2898E-04 0.0004 day 7.56E-05 0.00 7.56E-05 7.56E-05 1.73E-05 0.5 day

PM2.5 1.2553E-04 0.0001 day 1.15E-05 0.00 1.15E-05 1.15E-05 2.62E-06 0.5 day

ISA, Pri. Maint. Vac. - Breaker Bldg Chute PM 1.7527E-03 0.0009 day 1.60E-04 0.00 1.60E-04 1.60E-04 3.65E-05 0.5 day

PM10 8.2898E-04 0.0004 day 7.56E-05 0.00 7.56E-05 7.56E-05 1.73E-05 0.5 day

PM2.5 1.2553E-04 0.0001 day 1.15E-05 0.00 1.15E-05 1.15E-05 2.62E-06 0.5 day

ISA, 3&4 Bottom Ash (Dewatered) Loadout PM 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) PM10 6.6701E-05 0.6003 year 3.00E-04 0.00 3.00E-04 3.00E-04 6.85E-05 9000 year

PM2.5 1.0100E-05 0.0909 year 4.55E-05 0.00 4.55E-05 4.55E-05 1.04E-05 9000 year

In 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 Traffic

Equation: Scraper Travel Model (Coal Yard)Source: AP-42 11.9 Western Surface Coal Mining (9/88, 10/98) and Dispersion Modeling 1998

Basis, Miles Traveled:80 railcars/day @ 106 tons/car = 8480 tpd. 8480 tpd / 33 ton/load = 257 trips

PM: 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/daPM2.5: 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 reclaims = 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/VMT

Scraper Traffic E (PM2.5) = 0.021 lb/VMT

Maximum Pollution Maximum Limited

Emissions Uncontrolled Control Controlled Controlled

Rate Emissions Efficiency Emissions Emissions

Particulate Sources (lb/VMT) (lb/day) (tons/yr) (%) (tons/yr) (tons/yr) VMT/year

FS014, Coal Yard Traffic (Scrapers; Outstacking) PM 8.16E-01 103.6 9.4 40 5.7 5.7 23,114

PM10 1.79E-01 22.7 2.1 40 1.2 1.2 23,114

PM2.5 2.12E-02 2.7 0.2 40 0.1 0.1 23,114

FS014, Coal Yard Traffic (Scrapers; Reclaim) PM 8.16E-01 98.4 9.0 40 5.4 5.4 21,964

PM10 1.79E-01 21.6 2.0 40 1.2 1.2 21,964

PM2.5 2.12E-02 2.6 0.2 40 0.1 0.1 21,964

Subtotals PM 202.0 18.4 11.0 11.0
PM10 44.4 4.0 2.4 2.4

PM2.5 5.3 0.5 0.3 0.3

Equation: Bulldozer Traffic (Coal Pile Grooming)Source: AP-42 11.9-2 Western Surface Coal Mining (9/88, 10/98)Bulldozer Traffic PM: E = 78.4*(s^1.2)/(M^1.3) E = Emission factor lb/hr

PM10: 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/hr

Bulldozer Traffic E (PM2.5) = 0.629 lb/hr

Grader Traffic PM: 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/VMT

S = vehicle speed = 7.1 mph from AP-42 11.9-3 Grader Traffic E (PM10) = 1.543 lb/VMT

Grader Traffic E (PM2.5) = 0.167 lb/VMT

Water 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/VMT

PM2.5: E = 0.017*5.79/(M^4.0) Grader Traffic E (PM2.5) = 0.000 lb/VMT

E = Emission factor lb/VMTM = moisture content = 4.5% (AP-42, Table 13.2-4-1)

Maximum Pollution Maximum Limited

Emissions Uncontrolled Controlled Controlled Controlled

Rate Emissions Efficiency Emissions Emissions

Particulate 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 PM10 5.54E+00 692.82 0.35 40 0.21 0.21 125 hrs/yr

PM2.5 6.29E-01 78.59 0.04 40 0.02 0.02 125 hrs/yr

FS014, Coal Yard Traffic PM 5.37E+00 4,566.93 2.28 40 1.37 1.37 850 VMT (170 hrs/yr)Grading PM10 1.54E+00 1,311.16 0.66 40 0.39 0.39 850 VMT (170 hrs/yr)

PM2.5 1.67E-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 PM10 3.47E-03 12.13 0.01 40 0.00 0.00 3500 VMT (170 hrs/yr)

PM2.5 2.40E-04 0.84 0.00 40 0.00 0.00 3500 VMT (170 hrs/yr)

Maximum Pollution Maximum Limited

Emissions Uncontrolled Control Controlled Controlled

Rate Emissions Efficiency Emissions Emissions

Particulate 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.) PM10 49.9 18,205 5.0 40 3.03 3.0 0.69

PM2.5 5.9 2,138 0.6 40 0.35 0.4 0.08
Xcel Energy - Black Dog Generating Plant

Greenhouse Gases

Parameter Rate (lb/mmBtu) CO2e Rate (lb/mmBtu) Data Source

CO2 - subbit. coal 209.76 209.76 CEMS

CO2 - petroleum coke 225.77 225.77 40 CFR 98

CO2 - bitum. coal 205.65 205.65 40 CFR 98

CO2 - natural gas 116.98 116.98 40 CFR 98

CO2 - propane 138.60 138.60 40 CFR 98

CO2 - EU026 & EU027 118.86 118.86 CEMS

CO2 - No. 2 oil 161.49 161.49 40 CFR 98

CO2 - 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 propane 0.0066 0.1653 40 CFR 98

Nitrous oxide - all coal & coke 0.0035 1.0512 40 CFR 98

Nitrous oxide - natural gas 0.0002 0.0657 40 CFR 98

Nitrous oxide - Petroleum including propane 0.0013 0.3942 40 CFR 98

CO2e totals by fuel CO2e Rate (lb/mmBtu) Data Source

CO2e total - subbit. coal 211.42 CEMS & 40 CFR 98

CO2e total - coke 227.43 40 CFR 98

CO2e total - bit. coal 207.30 40 CFR 98

CO2e total - natural gas 117.10 40 CFR 98

CO2e total - propane 139.16 40 CFR 98

CO2e total - No. 2 oil 162.05 40 CFR 98

CO2e total - Waste oil as lubricants 163.70 40 CFR 98

CO2e total - EU026 & EU027 118.98 CEMS & 40 CFR 98

Greenhouse Gases
2012 Emission Inventory Totals

SOURCE_ID SOURCE_NAME PERMIT_TYPE NAICS_CODE INVENTORY_YEAR EMISSION_UNIT_CODE03700003 Xcel Energy - Black Dog R 221112 2012 TON

AMMONIA CO CO2 LEAD MERCURY

0.4839605 450.35377 1579706.637 0.022018779 0.037100074

METHANE NITROUS OXID NOX PM10FIL PM25FIL PMCON 

160.1948539 23.19054859 6056.456 168.717233 0.51548624 79.1190151 

SO2 VOC

2796.400193 24.10660914

CO2e = 1590259.799PM 253.7672695PM10 247.8362481PM2.5 79.63450134
Attachment 2 

Facility Description & CD-01 

Forms 
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog

FACILITY DESCR

ID No. 

Exit 

Tempe

at T

(oF

Design

Flow Rate

at Top

(ACFM)

Width

(feet)

Diameter

or Length

(feet)

Height of Inside Dimensions

Opening

From

Ground

(feet)

Added

By

(Action)

Retired

By

(Action)

Operator

ID

for Item

Stack/ Operators Description

Vent

Status

1 SV 001 Active PER 008 Stack 1 Main Stack for Boilers 3 and 4 600 22.5 2159501 2 SV 002 Active PER 008 Stack 7 Stacking Hopper (EU 005) Stack 14 3 3 3500 3 SV 003 Active PER 008 Stack 6 Dumper Building (EU 006) Stack 30 6 68000 4 SV 004 Active PER 008 Stack 23 Yard Agglomerator (EU 007) Stack 74 2 1 600 5 SV 005 Active PER 008 Stack 21 Breaker Bldg. (EU 008) Stack 25 3 40000 6 SV 006 Active PER 008 Stack 22 Breaker Bldg. (EU 009 and EU 010) Stack 25 3 26000 7 SV 007 Active PER 008 Stack 18 Tripper Area (EU 011) Stack 155 3 29000 8 SV 008 Active PER 008 Stack 19 Unit 3 Coal Silos (EU 012) 155 3 12600 9 SV 009 Active PER 008 Stack 20 Unit 4 Coal Silos (EU 013) 175 3 19000 

10 SV 010 Retired PER 008 101 .8 750 

11 SV 011 Retired PER 008 133 .8 750 

12 SV 012 Retired PER 008 133 .8 750 13 SV 013 Retired PER 008 83 1.8 2750 14 SV 014 Retired PER 008 Stack 17 Fly Ash Collection System (EU 018) Stack 29 .25 360 15 SV 015 Retired PER 008 Stack 11 Fly Ash Storage Silo (EU 020) Stack 32 1.2 4712 16 SV 016 Active PER 008 Stack 12 Fly Ash Collection System (EU 021) Stack 12 .7 1900 17 SV 017 Active PER 008 Stack 24 Temp. Emergency Engine (EU 023) Stack18 SV 017 Removed PER 011 Stack 24 Never installed - Temp. Emergency Engine (EU 023) Stack19 SV 018 Active PER 008 Emergency Engine Generator (EU 024) Stack 40 1.33 14110 20 SV 018 Active PER 011 Emergency Engine Generator (EU 024) Stack 40 1.33 14110 21 SV 019 Active PER 008 Emergency Engine Generator (EU 025) Stack 40 1.33 14110 22 SV 019 Active PER 011 Emergency Engine Generator (EU 025) Stack 40 1.33 14110 23 SV 020 Active PER 006 Combustion Turbine w/DLN & SCR; Duct Burners w/SCR 230 18 1064189 24 SV 021 Active PER 011 Fire Pump 25 0.33 1610.0 
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog

FACILITY DESCRIPTION: C

ID No. Added

By

(Action)

Retired

By

(Action)

Operator

ID

for Item

Control

Equip.

Type

Control Control Equipment Description Model

Equip.Status

Manufacturer Poll

Con

1 CE 001 Removed PER 008 010 Electrostatic Precipitator - High Efficiency Research Cottrell Type 6 Group 30 PM10

PM

2 CE 002 Removed PER 008 010 Electrostatic Precipitator - High Efficiency Belco/GE 30(996)2X28-12 PM10

PM

3 CE 003 Retired PER 008 007 Centrifugal Collector - High Efficiency Joy Environmental 12 VMU/198-11 PM 4 CE 004 Retired PER 008 010 Electrostatic Precipitator - High Efficiency Research Cottrell Type 6 Group 30 PM10

PM

5 CE 005 Removed PER 008 010 Electrostatic Precipitator - High Efficiency Belco/GE 30(996)2X34-12 PM10

PM

6 CE 006 Active EIS 014 010 Electrostatic Precipitator - High Efficiency Research Cottrell Type 6 Group 16 HAPs

PM10PM

7 CE 006 Active PER 011 010 Electrostatic Precipitator - High Efficiency Research Cottrell Type 6 Group 16 HAPs

PM2.5PM10PM

8 CE 007 Active EIS 014 010 Electrostatic Precipitator - High Efficiency Belco/GE 30(996)2X38-12 HAPs

PM10PM

9 CE 007 Active PER 011 010 Electrostatic Precipitator - High Efficiency Belco/GE 30(996)2X38-12 HAPs

PM2.5PM10PM

10 CE 008 Active EIS 014 010 Electrostatic Precipitator - High Efficiency Research Cottrell Type 4 Group 31 HAPs

PM10PM

11 CE 008 Active PER 011 010 Electrostatic Precipitator - High Efficiency Research Cottrell Type 4 Group 31 HAPs

PM2.5PM10PM

12 CE 009 Active EIS 014 010 Electrostatic Precipitator - High Efficiency Belco/GE 30(996)4X24-12 HAPs

PM10PM

13 CE 009 Active PER 011 010 Electrostatic Precipitator - High Efficiency Belco/GE 30(996)4X24-12 HAPs

PM2.5PM10PM

14 CE 010 Retired PER 008 007 Centrifugal Collector - High Efficiency Allen Sherman Hoff T-42 PM 15 CE 011 Active PER 001 007 Centrifugal Collector - High Efficiency Allen Sherman Hoff A-9150-11 PM10

PM
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog

FACILITY DESCRIPTION: C

ID No. Added

By

(Action)

Retired

By

(Action)

Operator

ID

for Item

Control

Equip.

Type

Control Control Equipment Description Model

Equip.Status

Manufacturer Poll

Con

16 CE 011 Retired PER 011 007 Centrifugal Collector - High Efficiency Allen Sherman Hoff A-9150-11 PM10

PM

17 CE 012 Retired PER 008 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Mikropul 100-S-10 PM 18 CE 013 Retired PER 008 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Mikropul 55-8-18 PM 19 CE 014 Retired PER 008 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Mikropul 495-8-20 PM 20 CE 015 Active PER 001 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Mikro-Pulsaire 19-8-408 PM10

PM

21 CE 015 Retired PER 011 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Mikro-Pulsaire 19-8-408 PM10

PM

22 CE 016 Active PER 001 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 544-RF8

Inc

PM10PM

23 CE 016 Active PER 011 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 544-RF8

Inc

PM2.5PM10PM10PM

24 CE 017 Active PER 001 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 484-RF8

Inc

PM10PM

25 CE 017 Active PER 011 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 484-RF8

Inc

PM2.5PM10PM10PM

26 CE 018 Active PER 001 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 376-RF8

Inc

PM10PM

27 CE 018 Active PER 011 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 376-RF8

Inc

PM2.5PM10PM10PM

28 CE 019 Active PER 001 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 676-RF8

Inc

PM10PM

29 CE 019 Active PER 011 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 676-RF8

Inc

PM2.5PM10PM10PM

30 CE 020 Active PER 001 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 484-RF8

Inc

PM 

31 CE 020 Active PER 011 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 484-RF8

Inc

PM2.5PM10PM

32 CE 021 Active PER 001 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 24RFS8

Inc

PM 
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog

FACILITY DESCRIPTION: C

ID No. Added

By

(Action)

Retired

By

(Action)

Operator

ID

for Item

Control

Equip.

Type

Control Control Equipment Description Model

Equip.Status

Manufacturer Poll

Con

33 CE 021 Active PER 011 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Air-Cure Environmental 24RFS8

Inc

PM2.5PM10PM

34 CE 022 Retired PER 008 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F DCE Vokes DLMV-10/10W PM 35 CE 023 Active PER 001 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F MAC Equipment Co 120 MCF 361 PM10

PM

36 CE 023 Active PER 011 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F MAC Equipment Co 120 MCF 361 PM2.5

PM10PM10PM

37 CE 024 Active PER 001 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F MAC Equipment Co 120 MCF 361 PM10

PM

38 CE 024 Active PER 011 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F MAC Equipment Co 120 MCF 361 PM2.5

PM10PM10PM

39 CE 025 Active PER 001 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F MAC Equipment Co 96AVS 36 PM10

PM

40 CE 025 Active PER 011 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F MAC Equipment Co 96AVS 36 PM2.5

PM10PM10PM

41 CE 026 Retired PER 008 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F DCE Vokes DLMV-15/15W PM 42 CE 027 Retired PER 008 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F DCE Vokes DLMV-10/10W PM 43 CE 028 Active EIS 014 061 Dust Suppression by Water Spray NA NA PM10

PM

44 CE 028 Retired PER 011 061 Dust Suppression by Water Spray NA NA PM10

PM

45 CE 029 Active EIS 014 061 Dust Suppression by Water Spray NA NA PM10

PM

46 CE 029 Active PER 011 061 Dust Suppression by Water Spray NA NA PM2.5

PM10PM

47 CE 030 Active PER 001 099 Other NA NA PM10

PM

48 CE 030 Retired PER 011 099 Other NA NA PM10

PM

49 CE 031 Active EIS 014 099 Other NA NA PM10

PM
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog

FACILITY DESCRIPTION: C

ID No. Added

By

(Action)

Retired

By

(Action)

Operator

ID

for Item

Control

Equip.

Type

Control Control Equipment Description Model

Equip.Status

Manufacturer Poll

Con

50 CE 031 Retired PER 011 099 Other NA NA PM10

PM

51 CE 032 Active PER 006 099 Selective Catalytic Reduction NOx 52 CE 032 Active PER 011 099 Selective Catalytic Reduction Babcock-Hitachi NA NOx 53 CE 033 Active PER 006 099 Dry-Low NOx combustion54 CE 033 Active PER 011 099 Dry-Low NOx combustion Siemens NA55 CE 034 Active PER 008 008 Centrifugal Collector - Medium Efficiency Allen-Sherman-Hoff B-60 PM10

PM

56 CE 034 Retired PER 011 008 Centrifugal Collector - Medium Efficiency Allen-Sherman-Hoff B-60 PM10

PM

57 CE 035 Active PER 008 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Flex-Clean 84-CTBC-38 II PM10

PM

58 CE 035 Retired PER 011 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F Flex-Clean 84-CTBC-38 II PM10

PM
ST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name:

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROAD

FACILITY DESCRIP

Xcel Energy - Black Dog

Retired

By

(Action)

ID No. Emission Operator Description

Unit

Status

Added

By

(Action)

Control

Equip.

ID No(s).

Stack/

Vent

ID No(s).

Operator

ID

for Item

Insignificant

Activity

Manufacturer Model SIC

Number

D

C

1 Boiler 1 - retired, to be 

removed

EU 001 Removed PER 008 SV 001 (M) CE 002 Combustion Engineerin 7348 4911 

2 Boiler 2 - retired from service 

in place

EU 002 Retired PER 008 SV 001 (M) CE 004 Foster Wheeler 2-43-4814 4911 

3 EU 003 Active PER 001 CE 006 Boiler 3 

CE 007

SV 001 (M) Babcock and Wilcox RB-218 4911 

4 EU 004 Active PER 001 CE 008 Boiler 4 

CE 009

SV 001 (M) Babcock and Wilcox RB-343 4911 

5 EU 005 Active PER 001 CE 025 200 Ton Stacking Hopper

CE 031

SV 002 (M) NA NA 4911 

6 EU 005 Active PER 011 SV 002 (M) CE 025 200 Ton Stacking Hopper NA NA 4911 7 EU 006 Active PER 001 CE 023 Dumper Unloading Bldg

CE 024

SV 003 (M) NA NA 4911 

8 EU 007 Active PER 001 SV 004 (M) CE 021 Yard Agglomerator Silo Air-Cure NA 4911 9 Breaker Building (Coal

Conveying)

EU 008 Active PER 008 SV 005 (M) CE 019 Bradford NA 4911 

10 EU 009 Active PER 008 SV 006 (M) CE 020 Transfer Tower Bradford NA 4911 

11 EU 010 Active PER 008 SV 006 (M) CE 020 Breakers (Crushing) Bradford NA 4911 

12 Tripper Area (Conveyors D

and F)

EU 011 Active PER 008 SV 007 (M) CE 016 Link NA 4911 

13 EU 012 Active PER 008 SV 008 (M) CE 017 Coal Silos NA NA 4911 14 EU 012 Active PER 011 SV 008 (M) CE 017 Unit 3 Coal Silo NA NA 4911 15 EU 013 Active PER 008 SV 009 (M) CE 018 Unit 4 Coal Silo NA NA 4911 16 EU 014 Retired PER 008 SV 010 (M) Unit 2 Sorbent Storage Silo Chicago Bridge & Iron NA 4911 17 EU 015 Retired PER 008 SV 011 (M) Unit 2 Sorbent Day Bin 21 Macawber 8/12 Denseveyor 4911 18 EU 016 Retired PER 008 SV 012 (M) Unit 2 Sorbent Day Bin 22 Macawber 8/12 Denseveyor 4911 19 EU 017 Retired PER 008 SV 013 (M) Unit 2 Spent Bed Storage Allen Sherman Hoff NA 4911 20 Units 3 and 4 Secondary

Precip. Fly Ash CollectionSystem Venting

EU 018 Retired PER 008 CE 015 Allen Sherman Hoff (Jo NA 4911 
22 July, 2013 14:15

FACILITY DESCRIPTION: EMISSION UNIT (EU)

ID No. Eleva

Typ

Pct. Bottleneck

Fuel/

Space

Heat

Added Firing Method

By

(Action)

Removal

Date

Initial

Startup

Date

Commence

Const.

Date

Emission

Unit

Status

1 EU 001 Removed PER 008 05/01/1949 09/17/1952 12/01/2000 Pulverized Coal: Dry Bottom (Tangential) 12 EU 002 Retired PER 008 12/31/1952 11/29/1954 Atmospheric Fluidized Bed Combustion 03 EU 003 Active PER 001 12/31/1953 08/28/1955 Pulverized Coal: Dry Bottom 14 EU 004 Active PER 001 12/31/1957 10/03/1960 Pulverized Coal: Dry Bottom 15 EU 005 Active PER 001 01/01/1964 12/31/19646 EU 005 Active PER 011 01/01/1964 12/31/19647 EU 006 Active PER 001 01/01/1950 12/31/19528 EU 007 Active PER 001 01/01/1992 08/01/19929 EU 008 Active PER 008 12/31/1950 12/31/1950

10 EU 009 Active PER 008 08/01/1950 08/01/1952

11 EU 010 Active PER 008 12/31/1949 12/31/1952 Group of Sources

12 EU 011 Active PER 008 12/31/1949 12/31/1952 Group of Sources13 EU 012 Active PER 008 12/31/1949 12/31/1952 Group of Sources14 EU 012 Active PER 011 12/31/1949 12/31/1952 Group of Sources15 EU 013 Active PER 008 12/31/1958 12/31/1960 Group of Sources16 EU 014 Retired PER 008 06/30/1985 03/31/198617 EU 015 Retired PER 008 06/30/1985 03/31/198618 EU 016 Retired PER 008 06/30/1985 03/31/198619 EU 017 Retired PER 008 07/31/1985 06/30/198620 EU 018 Retired PER 008 12/31/1976 12/31/1976

Page 1 of 2 (b)
ST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name:

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROAD

FACILITY DESCRIP

Xcel Energy - Black Dog

Retired

By

(Action)

ID No. Emission Operator Description

Unit

Status

Added

By

(Action)

Control

Equip.

ID No(s).

Stack/

Vent

ID No(s).

Operator

ID

for Item

Insignificant

Activity

Manufacturer Model SIC

Number

D

C

21 Units 3 and 4 Fly Ash Silo

Vent

EU 019 Active PER 002 CE 004

CE 005CE 006CE 007CE 008CE 009

SV 001 (M) United Conveyor NA 4911 

22 Units 3 and 4 Fly Ash Silo

Vent

EU 019 Active PER 011 CE 006

CE 007CE 008CE 009

SV 001 (M) United Conveyor NA 4911 

23 EU 020 Retired PER 008 SV 015 (M) No. 2 Fly Ash Storage Silo Chicago Bridge & Iron NA 4911 24 No. 2 Fly Ash Collection

System

EU 021 Retired PER 008 SV 016 (M) CE 013 Allen Sherman Hoff 1876-02 4911 

25 EU 022 Retired PER 002 SV 015 (M) Spent Sorbent Screening Eriez Mfg G2B 4911 26 EU 023 Active PER 001 SV 017 (M) Temporary Emergency Engine NA NA 4911 27 (never installed) Temporary

Emergency Engine

EU 023 Removed PER 011 NA NA 4911 

28 Emergency Engine Generator 

EEG-61001

EU 024 Active PER 008 SV 018 (M) Caterpillar 3516TA 4911 

29 Emergency Engine Generator 

EEG-61002

EU 025 Active PER 008 SV 019 (M) Caterpillar 3516TA 4911 

30 Combustion Turbine (Dry Low 

NOx Combustors & SelectiveCatalytic Reduction)

EU 026 Active PER 006 CE 032

CE 033

SV 020 (M) Siemens/Westinghouse 501F 4911 

31 Duct Burners (Selective 

Catalytic Reduction)

EU 027 Active PER 008 SV 020 (M) CE 032 Deltak Corp Dino 5564/72 4911 

32 EU 028 Active PER 011 SV 021 (M) Fire Pump Cummins 6BTA5.9F1 4911 
22 July, 2013 14:15

FACILITY DESCRIPTION: EMISSION UNIT (EU)

ID No. Eleva

Typ

Pct. Bottleneck

Fuel/

Space

Heat

Added Firing Method

By

(Action)

Removal

Date

Initial

Startup

Date

Commence

Const.

Date

Emission

Unit

Status

21 EU 019 Active PER 002 12/31/1976 12/31/197622 EU 019 Active PER 011 12/31/1976 12/31/197623 EU 020 Retired PER 008 12/31/1985 06/30/1986 12/31/200524 EU 021 Retired PER 008 12/31/1985 06/30/1986 12/31/200525 EU 022 Retired PER 002 09/30/1986 09/30/198626 EU 023 Active PER 00127 EU 023 Removed PER 011 03/20/201228 EU 024 Active PER 008 05/01/1996 10/11/199629 EU 025 Active PER 008 05/01/1996 10/11/199630 EU 026 Active PER 006 03/21/2001 06/21/200131 EU 027 Active PER 008 03/21/2001 06/21/200132 EU 028 Active PER 011 01/01/1999 01/01/1999

Page 2 of 2 (b)
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog

FACILITY DESCRIPTIO

ID No. Fugitive Source Description 

Added

By

(Action)

Retired

By

(Action)

Insignificant

Activity

Operator

ID

for Item

Pollutant(s)

Emitted

Control

Equip.

ID No(s).

Fugitive

Source

Status

1 FS 001 PER 008 PM

PM10

Active Barge Unloading

2 FS 001 PER 011 PM 

PM10

Removed Barge Unloading

3 FS 002 Retired PER 008 PM Coal Conveyors 6 and 7A4 FS 003 EIS 001 PM

PM10

Active Emergency Reclaim Hopper

5 FS 003 PER 011 PM

PM10PM2.5

Active Emergency Reclaim Hopper

6 FS 004 EIS 001 PM

PM10

Active CE 029 All Coal Storage Piles (Erosion)

7 FS 004 PER 011 PM

PM10PM2.5

Active CE 029 All Coal Storage Piles (Erosion)

8 FS 008 EIS 001 PM

PM10

Active CE 029 Coal Outstacking

9 FS 008 PER 011 PM

PM10PM2.5

Active CE 029 Coal Outstacking

10 FS 009 EIS 001 PM

PM10

Active CE 029 Coal Reclaim

11 FS 009 PER 011 PM

PM10PM2.5

Active CE 029 Coal Reclaim

12 FS 010 EIS 001 PM

PM10

Active CE 029 Petroleum Coke Storage (Erosion)

13 FS 010 PER 011 PM 

PM10

Removed Petroleum Coke Storage (Erosion)

14 FS 011 EIS 001 PM

PM10

Active Petroleum Coke Unloading

15 FS 011 PER 011 PM 

PM10

Removed Petroleum Coke Unloading

16 FS 012 EIS 001 PM

PM10

Active CE 029 Petroleum Coke Reclaim

17 FS 012 PER 011 PM 

PM10

Removed Petroleum Coke Reclaim

18 FS 013 EIS 001 PM

PM10

Active CE 029 Ash Hauling Traffic
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog

FACILITY DESCRIPTIO

ID No. Fugitive Source Description 

Added

By

(Action)

Retired

By

(Action)

Insignificant

Activity

Operator

ID

for Item

Pollutant(s)

Emitted

Control

Equip.

ID No(s).

Fugitive

Source

Status

19 FS 013 PER 011 PM

PM10PM2.5

Active CE 029 Ash Hauling Traffic

20 FS 014 EIS 001 PM

PM10

Active CE 029 Coal Yard Traffic

21 FS 014 PER 011 PM

PM10PM2.5

Active CE 029 Coal Yard Traffic

22 FS 015 EIS 001 PM

PM10

Active Coal Conveyors 7,7B,7C

23 FS 015 PER 011 PM

PM10PM2.5

Active Coal Conveyors 7,7B,7C

24 FS 016 EIS 001 PM

PM10

Active Coal Conveyor 8

25 FS 016 PER 011 PM

PM10PM2.5

Active Coal Conveyor 8

26 FS 017 EIS 001 PM

PM10

Active CE 031 Dumper Unloading Bldg (fugitives from unloading railcar/scraper)

27 FS 017 PER 011 PM

PM10PM2.5

Active CE 031 Dumper Unloading Bldg (fugitives from unloading railcar/scraper)
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show:Action:AQD Facility ID:Facility Name:

Active and Pending RecordsPER 01103700003Xcel Energy - Black Dog

FACILITY DE

ID No. Added

By

(Action)

Retired

By

(Action)

Include

in EI

Operator

ID

for Item

Group Group Description 

Status

1 GP 001 Active PER 008 Emergency Engine Generators EU 024, EU 025, SV 018, SV 02 GP 002 Active PER 008 Boilers and Associated Control Equipment CE 006, CE 007, CE 008, CE 03 GP 002 PER 011 Boilers and Associated Control Equipment CE 006, CE 007, CE 008, CE 0

MR 015, MR 016, SV 001

Active

4 GP 003 Active PER 008 Electrostatic Precipitator Requirements CE 006, CE 007, CE 008, CE 05 GP 004 Active PER 008 Main Stack (SV 001) CEMS MR 006, MR 013, MR 014, MR 6 GP 004 Active PER 011 CEMS Required by Acid Rain Regulations MR 006, MR 013, MR 014, MR 7 GP 005 Active PER 008 Combustion Turbine/Duct Burner Stack Monitors MR 010, MR 011, MR 012, SV 8 GP 005 Active PER 011 CEMS Required by Acid Rain and NSPS Regulations MR 017, MR 0189 GP 006 Active PER 008 Fabric Filter Requirements CE 016, CE 017, CE 018, CE 0

10 GP 007 Active PER 011 Combustion Turbine/Duct Burner Combined Requirments CE 032, CE 033, EU 026, EU 0

11 GP 008 Active PER 011 Acid Rain Affected Sources EU 003, EU 004, EU 026
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog

FACILITY DESCRIPTION: CON

ID No. Operator Manufacturer Model Number

ID

for Item

Monitored

Item

(ID No(s).)

Retired

By

(Action)

Added

By

(Action)

Monitor Monitor Description

Status

1 MR 001 Removed PER 008 Lear Siegler (N) SM-8100 1252 MR 002 Removed PER 008 Dynatron (N) 401 4013 MR 003 Removed PER 008 Anarad AR-30C2AZ 4694 MR 004 Removed PER 008 Anarad AR-880 4695 MR 005 Removed PER 008 Anarad AR-23 4696 MR 006 Active PER 008 SV 001 Air Flow Monitor EMRC GFM-7-NS 399 7 MR 007 Removed PER 008 Lear Siegler RM-41 7398 MR 008 Removed PER 008 Lear Siegler (S) SM-8100 1259 MR 009 Removed PER 008 Dynatron (S) 401 401

10 MR 010 A PER 008 SV 020 Unit 5/2 NOx Dual Range TECO 42C-LS 42C

ctive

11 MR 010 Removed PER 011 Unit 5/2 NOx Dual Range TECO 42C-LS 42C

12 MR 011 A PER 008 SV 020 Unit 5/2 O2 Buhler BA3000 A61

ctive

13 MR 011 Removed PER 011 Unit 5/2 O2 Buhler BA3000 A6114 MR 012 Active PER 008 SV 020 Unit 5 CO - High and Low TECO 48C-TL 48C15 MR 012 Removed PER 011 Unit 5 CO - High and Low TECO 48C-TL 48C16 MR 013 A PER 008 SV 001 Boilers 3 & 4 SO2 Monitor TECO 43C 043

ctive

17 MR 014 A PER 008 SV 001 Boilers 3 & 4 NOx Monitor TECO 42C 740

ctive

18 MR 015 A PER 008 SV 001 Boilers 3 & 4 CO2 Monitor TECO 41CHL 050

ctive

19 MR 016 A PER 008 SV 001 Boilers 3 & 4 Opacity Monitor Land Combustion Mark II 999

ctive

20 MR 017 A PER 011 SV 020 Unit 5/2 NOx Dual Range Monitor Thermo Fisher Scientific 42i-LS 103

ctive

21 MR 018 A PER 011 SV 020 Unit 5/2 O2 Monitor Servomex 1440D 014

ctive

22 MR 019 Active PER 011 SV 020 Unit 5/2 CO Dual Range Monitor Themo Fisher Scientific 48i 103
22 July, 2013 14:16

FACILITY DESCRIPTION: CONTINUOUS MONITORS (MR)

ID No. Added

By

(Action)

Span

Value

System

FullScale

Value

Bypass

Capability?

Removal

Date

Installation

Date

Optical

Path

Length

Ratio

Monitor

Status

1 MR 001 PER 008 Removed No 12/01/20002 MR 002 PER 008 Removed No 12/01/20003 MR 003 PER 008 Removed No 06/01/20054 MR 004 PER 008 Removed No 06/01/20055 MR 005 PER 008 Removed No 06/01/20056 MR 006 PER 008 Active 3 3 No 01/01/19957 MR 007 PER 008 Removed No 09/01/19998 MR 008 PER 008 Removed No 12/01/20009 MR 009 PER 008 Removed No 12/01/2000

10 MR 010 PER 008 Active 20 75 No 06/30/2002

11 MR 010 PER 011 Removed 20 75 No 06/30/2002 05/05/2011

12 MR 011 PER 008 Active 20 25 No 06/30/200213 MR 011 PER 011 Removed 20 25 No 06/30/2002 05/05/201114 MR 012 PER 008 Active 50 4000 No 05/01/200215 MR 012 PER 011 Removed 50 4000 No 05/01/2002 05/05/201116 MR 013 PER 008 Active 300 300 No 07/01/200517 MR 014 PER 008 Active 800 800 No 07/01/200518 MR 015 PER 008 Active 20 20 No 07/01/200519 MR 016 PER 008 Active 80 100 No 0.95 09/01/199920 MR 017 PER 011 Active 100 100 No 05/05/201121 MR 018 PER 011 Active 25 25 No 05/05/201122 MR 019 PER 011 Active 2000 2000 No 05/05/2011

Page 1 of 1 (b)
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY 520 LAFAYETTE ROADST. PAUL, MN 55155-4194 FACILITY DESCRIPTION: DATA A

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog

ID No. 

DAS Manufacturer Model Number Serial Num

Status

Operator

ID

for Item

Retired Data Acquisition System Description

By

(Action) 

Added

By

(Action) 

1 DA 001 Removed PER 008 Lear Siegler Unicon 700 1250047 2 DA 002 Active PER 008 Units 3 & 4 Environmental Systems ESC DAHS PM1636 3 DA 003 Active PER 008 Units 5 Environmental Systems ESC DAHS PM1636 4 DA 004 Active PER 011 Units 3 & 4 Environmental Systems C Stack Vision A0900 5 DA 005 Active PER 011 Unit 5 Environmental Systems C StackVision 0698 
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog

22 July, 2013 14:16 

FACILITY DESCRIPTION: CONTINUOUS MO

ID No. Added

By

(Action)

Retired

By

(Action)

Monitor

ID No(s).

DAS

ID No(s).

Operator

ID

for Item

CMS Description Parameter 

CMS

Status

1 CM 001 PER 008 MR 003

MR 005

Boilers 1-4: 1.2 lbs SO2/mmBtu, SV001, 1-hr ave., When EU002 isoperating

Removed Sulfur Dioxide 

2 CM 002 PER 008 MR 003

MR 005

Boilers 1-4: 1.3 lbs SO2/mmBtu, SV001, 1-hr ave., When EU002 isnot operating

Removed Sulfur Dioxide 

3 CM 003 PER 008 MR 003

MR 006

Removed Boilers 1-4: 6759 lbs SO2/hr, SV001, 1-hr ave. Sulfur Dioxide 

4 CM 004 Removed PER 008 MR 007 Units 1-4: 20% Opacity, SV001, 1-min ave. Opacity 5 CM 005 PER 008 MR 014

MR 015

Active DA 002 Boilers 3 & 4 NOx lb/MM Btu Nitrogen Oxides 

6 CM 006 PER 008 MR 010

MR 011

Active DA 003 Unit 5 NOx ppm Nitrogen Oxides 

7 CM 007 PER 008 MR 011

MR 012

Active DA 003 Unit 5 CO ppm Carbon Monoxide 

8 CM 008 Active PER 008 MR 016 DA 002 Boilers 3 & 4 Opacity Opacity 9 CM 009 PER 008 MR 013

MR 015

Active DA 002 Boilers 3 & 4 SO2 lb/MM Btu Sulfur Dioxide 

10 CM 010 PER 008 MR 013

MR 016

Active DA 002 Boilers 3 & 4 SO2 lb/hr Sulfur Dioxide 

11 CM 011 PER 011 MR 017

MR 018

Active DA 005 Unit 5 NOx ppm Nitrogen Oxides 

12 CM 012 PER 011 MR 018

MR 019

Active DA 005 Unit 5 CO ppm Carbon Monoxide 
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show: Active and Pending RecordsAction: PER 011AQD Facility ID: 03700003Facility Name: Xcel Energy - Black Dog

Retired

By

(Action)

Added

By

(Action)

ID No. Operator

ID

for Item

Roof Height

from 

Ground

(feet)

Length

(feet)

Width

(feet)

Description/Comment

FACILITY DESCRIPTION: BUILD

22 

1 PER 011 BG 001 001 428 297 150 Plant-includes 40' width for secondary ESP 2 PER 011 BG 002 002 83 60 22 Maintenance Building 3 PER 011 BG 003 003 58 48 75 Breaker Building 4 PER 011 BG 004 004 65 55 35 Dumper Building 5 PER 011 BG 005 005 80 40 26 Train Storage Garage 6 PER 011 BG 006 006 192 32 17 Warehouse 7 PER 011 BG 007 007 62 16 12.5 Substation Control Building 8 PER 011 BG 008 008 105 51 35 Screen House 9 PER 011 BG 009 009 100 59 29 Stock Room 

10 PER 011 BG 010 010 38 50 39 Gas Compressor Building 

11 PER 011 BG 011 011 22 28 28 
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 1 of 64 27 Jan, 2014 15:11

Subject Item: Total Facility

NC/

CA

Type Citation Requirement

1.0 CD hdr SOURCE-SPECIFIC REQUIREMENTS

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

Appendices 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) Access 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.

Access 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

8.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 2 of 64 27 Jan, 2014 15:11

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

ATPA 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

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 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.

13.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 3 of 64 27 Jan, 2014 15:11

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

16.0 CD hdr OPERATIONAL REQUIREMENTS

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)

Air 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

26.0 CD hdr PERFORMANCE TESTING
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 4 of 64 27 Jan, 2014 15:11

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 Test

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

30.0 CD hdr MONITORING REQUIREMENTS

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

33.0 CD hdr RECORDKEEPING

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

37.0 CD hdr REPORTING/SUBMITTALS

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.

38.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 5 of 64 27 Jan, 2014 15:11

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.

At 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.

At 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

Application 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 Application 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).

47.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 6 of 64 27 Jan, 2014 15:11

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

50.0 CD Minn. R. 7002.0005 - 7002.0095 Emission Fees: due 60 days after receipt of an MPCA bill.

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

52.0 CD hdr NONROAD ENGINES

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.

Any 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.

55.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 7 of 64 27 Jan, 2014 15:11

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).

56.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 8 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr THE FOLLOWING LIMITS APPLY TO THE TWO GENERATORS COMBINED

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

9.0 CD hdr RECORDKEEPING

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.

11.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 9 of 64 27 Jan, 2014 15:11

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

15.0 CD hdr TEMPORARY REPLACEMENT

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;

16.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 10 of 64 27 Jan, 2014 15:11

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.

20.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 11 of 64 27 Jan, 2014 15:11

Subject Item: GP 002 Boilers and Associated Control Equipment

Associated Items: CE 006 Electrostatic Precipitator - High Efficiency

CE 007 Electrostatic Precipitator - High Efficiency

CE 008 Electrostatic Precipitator - High Efficiency

CE 009 Electrostatic Precipitator - 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

Average .

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

3.0 Sulfur Dioxide: less than or equal to 3988 lbs/hour using 1-Hour Average .

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

4.0 PM < 10 micron: less than or equal to 920 lbs/hour using 3-hour Average

5.0 CD hdr EMISSION LIMITS THAT APPLY TO EU003 & EU004 INDIVIDUALLY

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

Average 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

Average when burning liquid fuel

10.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 12 of 64 27 Jan, 2014 15:11

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#

Allen 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#

Allen S. King 1

Black Dog 3,4

Sherburne County 1,2,3

12.0

13.0 CD hdr OPERATIONAL REQUIREMENTS

CD Minn. R. 7007.0800, subp. 2 Allowed 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

19.0 CD hdr MONITORING REQUIREMENTS (see also Subject Item GP008)

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.

Additional 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.

Additional monitoring requirements can be found at Subject Item GP004 and in

Table B of this permit.

21.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 13 of 64 27 Jan, 2014 15:11

CD Minn. R. 7017.1006 Emissions Monitoring: The owner or operator shall use a COMS to measure

Opacity from SV001.

Additional monitoring requirements are also located at Subject Item MR016 at in

Table B of this permit.

22.0

23.0 CD hdr RECORDKEEPING REQUIREMENTS (see also Subject Item GP008)

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

27.0 CD hdr TESTING REQUIREMENTS

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:

Alternative 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.

29.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 14 of 64 27 Jan, 2014 15:11

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

31.0 CD hdr NESHAP REQUIREMENTS

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) Any 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.

As of the issuance date of permit action 13700003-011, the compliance date is

August 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).

35.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 15 of 64 27 Jan, 2014 15:11

Subject Item: GP 003 Electrostatic Precipitator Requirements

Associated Items: CE 006 Electrostatic Precipitator - High Efficiency

CE 007 Electrostatic Precipitator - High Efficiency

CE 008 Electrostatic Precipitator - High Efficiency

CE 009 Electrostatic Precipitator - 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)

11.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 16 of 64 27 Jan, 2014 15:11

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

Annual 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

As 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.

21.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 17 of 64 27 Jan, 2014 15:11

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.

22.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 18 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr Additional monitoring requirements are located in Table B.

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,

Appendix B as amended.

9.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 19 of 64 27 Jan, 2014 15:11

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.

16.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 20 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr Additional monitoring requirements are located in Table B.

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,

Appendix B as amended.

(Note 40 CFR Part 60 has a standard regarding this requirement as well)

11.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 21 of 64 27 Jan, 2014 15:11

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

Appendix 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,

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.

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,

Appendix 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.

22.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 22 of 64 27 Jan, 2014 15:11

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

2.0 CD hdr CONTROL EFFICIENCY REQUIREMENTS

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

6.0 CD hdr MONITORING AND RECORDKEEPING

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.

12.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 23 of 64 27 Jan, 2014 15:11

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 Combustors & 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

Average 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.

7.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 24 of 64 27 Jan, 2014 15:11

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

13.0 CD hdr CONTROL REQUIREMENTS (see also Subject Item CE032)

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.

18.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 25 of 64 27 Jan, 2014 15:11

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,

Appendix 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.

After 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

24.0 CD hdr PERFORMANCE TESTING

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.

At 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

27.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 26 of 64 27 Jan, 2014 15:11

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

29.0 CD hdr RECORDKEEPING

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

32.0 CD hdr SUBMITTALS AND REPORTS

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.

33.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 27 of 64 27 Jan, 2014 15:11

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 Combustors & Selective Catalytic Reduction)

NC/

CA

Type Citation Requirement

1.0 CD hdr ACID RAIN REQUIREMENTS (see also Appendix E)

CD 40 CFR Section 72.9(c)(1)(ii); 40

CFR Section 72.9(g)(4)

2.0 Comply with the applicable Acid Rain emissions limitation for sulfur dioxide.

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) Apply 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).

7.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 28 of 64 27 Jan, 2014 15:11

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.

2.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 29 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr EMISSION LIMITS

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.

5.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 30 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr EMISSION AND OPERATING LIMITS

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

3.0 Operating Hours: less than or equal to 12.5 hours/day

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.

8.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 31 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr EMISSION LIMITS

LIMIT 40 CFR Section 60.252(c); Minn.

R. 7011.1150

2.0 Opacity: less than 20 percent opacity

3.0 LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.01 grains/dry standard cubic foot

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.

6.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 32 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr EMISSION LIMITS

2.0 LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity

3.0 LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot

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.

6.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 33 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr EMISSION LIMITS

2.0 LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity

3.0 LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot

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.

6.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 34 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr EMISSION LIMITS

2.0 LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity

3.0 LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot

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.

6.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 35 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr EMISSION LIMITS

2.0 LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity

3.0 LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot

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.

6.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 36 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr EMISSION LIMITS

2.0 LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity

3.0 LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot

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.

6.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 37 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr EMISSION LIMITS

2.0 LIMIT Minn. R. 7011.1105 (G) Opacity: less than or equal to 20 percent opacity

3.0 LIMIT Minn. R. 7011.1105 (G) PM < 10 micron: less than or equal to 0.005 grains/dry standard cubic foot

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.

6.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 38 of 64 27 Jan, 2014 15:11

Subject Item: EU 019 Units 3 and 4 Fly Ash Silo Vent

Associated Items: CE 006 Electrostatic Precipitator - High Efficiency

CE 007 Electrostatic Precipitator - High Efficiency

CE 008 Electrostatic Precipitator - High Efficiency

CE 009 Electrostatic Precipitator - 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

2.0 LIMIT Minn. R. 7011.0715, subp. 1(B) Opacity: less than or equal to 20 percent opacity
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 39 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr EMISSION LIMITS

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

4.0 CD hdr OPERATIONAL REQUIREMENTS

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

9.0 Sulfur Content of Fuel: less than or equal to 0.8 percent by weight

CD Title I Condition: To avoid

classification as a major

modification under 40 CFR

Section 52.21 and Minn. R.

7007.3000

10.0 Fuel usage is limited to pipeline quality natural gas.

CD hdr MONITORING, TESTING, RECORDKEEPING AND REPORTING

REQUIREMENTS (see also Subject Item GP007)

11.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 40 of 64 27 Jan, 2014 15:11

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.

15.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 41 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr EMISSION LIMITS

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

Average (gross energy output). This limit applies at all times except during periods

of startup, shudown, or malfunction.

3.0

4.0 CD hdr OPERATIONAL REQUIREMENTS

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

7.0 Fuel usage is limited to pipeline quality natural gas.

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

11.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 42 of 64 27 Jan, 2014 15:11

Subject Item: EU 028 Fire Pump

Associated Items: SV 021 Fire Pump

NC/

CA

Type Citation Requirement

1.0 CD hdr EMISSION AND OPERATING LIMITS

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

4.0 LIMIT Minn. R. 7007.0800, subps. 4 & 5 Sulfur Content of Fuel: less than or equal to 0.050 percent by weight

5.0 CD Minn. R. 7005.0100, subp. 35a Fuel type: Distillate fuel oil only, by design

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

8.0 CD hdr NESHAP SUBPART ZZZZ REQUIREMENTS

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.

12.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 43 of 64 27 Jan, 2014 15:11

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)

20.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 44 of 64 27 Jan, 2014 15:11

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

28.0 CD hdr. TEMPORARY REPLACEMENT

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;

29.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 45 of 64 27 Jan, 2014 15:11

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.

34.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 46 of 64 27 Jan, 2014 15:11

Subject Item: CE 032 Selective Catalytic Reduction

Associated Items: EU 026 Combustion Turbine (Dry Low NOx Combustors & Selective Catalytic Reduction)

EU 027 Duct Burners (Selective Catalytic Reduction)

GP 007 Combustion Turbine/Duct Burner Combined Requirments

NC/

CA

Type Citation Requirement

1.0 CD hdr A. OPERATING REQUIREMENTS

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).

At 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

7.0 CD hdr B. MONITORING AND RECORDKEEPING REQUIREMENTS

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.

11.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 47 of 64 27 Jan, 2014 15:11

CD 40 CFR Section 64.9(a)(2); Minn.

R. 7017.0200

As 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.

13.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 48 of 64 27 Jan, 2014 15:11

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

1.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 49 of 64 27 Jan, 2014 15:11

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.

2.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 50 of 64 27 Jan, 2014 15:11

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.

2.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 51 of 64 27 Jan, 2014 15:11

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.

1.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 52 of 64 27 Jan, 2014 15:11

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

1.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 53 of 64 27 Jan, 2014 15:11

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

1.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 54 of 64 27 Jan, 2014 15:11

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.

2.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 55 of 64 27 Jan, 2014 15:11

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.

2.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 56 of 64 27 Jan, 2014 15:11

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.

2.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 57 of 64 27 Jan, 2014 15:11

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.

2.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 58 of 64 27 Jan, 2014 15:11

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.

2.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 59 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr Additional monitoring requirements are located in Table B.

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.

Acceptable 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.

11.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 60 of 64 27 Jan, 2014 15:11

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.

13.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 61 of 64 27 Jan, 2014 15:11

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.

3.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 62 of 64 27 Jan, 2014 15:11

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.

3.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 63 of 64 27 Jan, 2014 15:11

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

1.0 CD hdr Additional monitoring requirements are located in Table B.

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.

9.0
MINNESOTA POLLUTION CONTROL AGENCY

AIR QUALITY

520 LAFAYETTE ROAD

ST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Xcel Energy - Black Dog

Permit Number: 03700003 - 011

Page 64 of 64 27 Jan, 2014 15:11

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 NOx CEMS measures

NOx 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 (PM10) 

Limit Basis 

0.4 lb PM/MMBtu Method 5 test 

0.3 lb PM/MMBtu Method 5 test 

920 lbs PM10/hr 

Monitoring Requirements: COMS 

c. Control Technology 

Electrostatic Precipitators 
II. Monitoring Approach 

I. Primary Indicator  Measurement Approach 

Opacity Opacity is measured continuously using a continuous opacity monitoper the requirements of Minn. R. 7017. 

II. Indicator Range Each unit has an opacity limit of less than 20 percent, 6-minute avera

maximum of 60 percent opacity shall be allowable for one six minute minute period. An excursion is defined as an opacity reading above minute block average. An excursion triggers corrective action and re

actions. 

III. Performance Criteria  A. Data Representativeness 

Opacity is measured in the common stack serving both coal fired boCOMS meets the requirements of Minn. R. 7017. 

 B. Verification of Operational Status The COMS was installed and certified following the requirements of 

Specification 1, found in 40 CFR 60, Appendix B. 

 C. QA/QC Practices and Criteria The COMS operates in conjunction with a quality assurance plan acc

60, and follows all calibration and maintenance requirements in that 

 D. Monitoring Frequency Opacity is monitored continuously, recorded at ten-second intervals, 

appropriate averages for reporting 

 Data Collection Procedures Data recorded digitally in the COMS DAHS  Averaging period 6-minute block 
I. Secondary Indicator 

 Measurement Approach 

Specific collection area (SCA). 

The electrical charging of the plates within the electrostatic precipita

(ESP) are monitored on a continuous basis. The area of the charged control effectiveness of the overall control system. 

II. Indicator Range The minimum SCA determined during the most recent total particulIII. Performance Criteria  A. Data Representativeness The SCA is a measure of the total area of plate surface available for c

matter. Many of the sections in the ESP are functionally equivalent, sections in service can be recorded in lieu of the SCA for equivalent below for details. 

 B. Verification of Operational Status The ESP sections in service are monitored on a continuous basis. O

triggered if any precipitator transformer/rectifier trips occur. The ESare recorded daily, and the minimum SCA is verified for the operatin

 C. QA/QC Practices and Criteria The ESPs are operated and maintained according to the provisions in 

Operations and Maintenance (O & M) Plan. 

 D. Monitoring Frequency Daily  Data Collection Procedures The ESP sections in service are recorded daily on written log sheets a

is verified for the operating day. 

 Averaging period Daily 
Black Dog Required ESP Minimum Surface Collection Area (SCA) 

Results based on 8/13/2008 stack tests  Unit 3 Primary Unit 3 Secondary  31 

Inlet 

31 

Center 

31 

Outlet 

32 

Inlet 

32 

Center 

32 

Outlet 

Total 31 

Inlet 

33 

Center 

35 

Outlet 

32 

Inlet 

34 

Center 

SCA sq. ft 8,640 8,640 8,640 8,640 8,640 8,640 51,840 18,240 18,240 18,240 18,240 18,240 In/Out of service 

In Out In In Out In In Out In In In 

SCA in service during test 

8,640 0 8,640 8,640 0 8,640 34,560 18,240 0 18,240 18,240 18,240 

 Unit 4 Primary Unit 4 Secondary  41-42 

Inlet 

41 

Center 

41 

Outlet 

42 

Center 

42 

Outlet 

Total 41 

Inlet 

43 

Center 

45 

Outlet 

42 

Inlet 

44 

Center 

O

SCA sq. ft 12,972 6,486 6,486 6,486 6,486 38,916 23,040 23,040 23,040 23,040 23,040 23In/Out of service In Out In Out In In In In Out In SCA in service during test 12,972 0 6,486 0 6,486 25,944 23,040 23,040 23,040 0 23,040 23
I. Tertiary Indicator 

 Measurement Approach 

Periodic Inspections Inspection of all control equipment components, including those subplugging. 

II. Indicator Range ESP components must operate as designed, per the facility’s O & M III. Performance Criteria  A. Data Representativeness All components of the pollution control equipment are inspected on 

degradation, wear, corrosion, plugging, or other improper operation. 

 B. Verification of Operational Status Records are maintained of all inspections and any corrective actions 

inspections. 

 C. QA/QC Practices and Criteria N/A  D. Monitoring Frequency Components subject to wear or plugging: quarterly 

All other components: annually 

 Data Collection Procedures Physical 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 relationship 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 limit, 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 limit 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 superbly performing unit would be able to “make 

up” for a poorly performing unit to a degree 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 Relationship

0%

10%20%30%40%50%60%70%80%90%

100%

0% 10% 20% 30% 40% 50% 60% 70% 80% 

% of opacity limit

% of PM limit Opacity limited 

PM limited region
Attachment 4 

Public Comments 

(from 1st 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 discuss 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 Rosvold 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. 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. 

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. 

3. Page A-12, fourth item. We do not understand the purpose of requiring a 

PM10 test, and believe it is unnecessary. The only limit for PM10 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, PM10 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. 
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. 

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. 

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 Analyst 
1

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 Public 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 discuss 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 Rosvold 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 PM10 test, and believe it is

unnecessary.  The only limit for PM10 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, PM10 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 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, 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 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:

A-1 09/05/13

Table A contains limits and other requirements with which your facility must comply. The limits are located in the first column of

the table (What To do). The limits can be emission limits or operational limits. This column also contains the actions that you 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 total 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

Appendices 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)

Access 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.

Access 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:

A-2 09/05/13

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

ATPA 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

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 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:

A-3 09/05/13

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

Air 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:

A-4 09/05/13

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 Test

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:

A-5 09/05/13

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.

At 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.

At 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

Application 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:

A-6 09/05/13

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.

Any 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:

A-7 09/05/13

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:

A-8 09/05/13

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:

A-9 09/05/13

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:

A-10 09/05/13

Subject Item: GP 002 Boilers and Associated Control Equipment

Associated Items: CE 006 Electrostatic Precipitator - High Efficiency

CE 007 Electrostatic Precipitator - High Efficiency

CE 008 Electrostatic Precipitator - High Efficiency

CE 009 Electrostatic Precipitator - 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

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

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

Average 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

Average 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#

Allen 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:

A-11 09/05/13

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#

Allen S. King 1

Black Dog 3,4

Sherburne County 1,2,3

40 CFR Section 76.11; Minn. R. 7011.0553

OPERATIONAL REQUIREMENTS hdr

Allowed 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.

Additional 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.

Additional 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.

Additional 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:

A-12 09/05/13

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:

Alternative 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:

A-13 09/05/13

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

Any 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.

As of the issuance date of permit action 13700003-011, the compliance date is

August 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:

A-14 09/05/13

Subject Item: GP 003 Electrostatic Precipitator Requirements

Associated Items: CE 006 Electrostatic Precipitator - High Efficiency

CE 007 Electrostatic Precipitator - High Efficiency

CE 008 Electrostatic Precipitator - High Efficiency

CE 009 Electrostatic Precipitator - 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:

A-15 09/05/13

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

Annual 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

As 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:

A-16 09/05/13

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

Additional 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,

Appendix B as amended.

40 CFR Section 75.21
TABLE A: LIMITS AND OTHER REQUIREMENTS

Xcel Energy - Black Dog

03700003 - 011

Facility Name:

Permit Number:

A-17 09/05/13

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:

A-18 09/05/13

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

Additional 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,

Appendix 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:

A-19 09/05/13

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

Appendix 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,

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

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,

Appendix 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:

A-20 09/05/13

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:

A-21 09/05/13

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 Combustors & 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

Average 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:

A-22 09/05/13

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,

Appendix 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:

A-23 09/05/13

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.

After 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.

At 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:

A-24 09/05/13

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 Combustors & Selective Catalytic Reduction)

What to do Why to do it

ACID 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)

Apply 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:

A-25 09/05/13

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:

A-26 09/05/13

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:

A-27 09/05/13

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:

A-28 09/05/13

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:

A-29 09/05/13

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:

A-30 09/05/13

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:

A-31 09/05/13

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:

A-32 09/05/13

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:

A-33 09/05/13

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:

A-34 09/05/13

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:

A-35 09/05/13

Subject Item: EU 019 Units 3 and 4 Fly Ash Silo Vent

Associated Items: CE 006 Electrostatic Precipitator - High Efficiency

CE 007 Electrostatic Precipitator - High Efficiency

CE 008 Electrostatic Precipitator - High Efficiency

CE 009 Electrostatic Precipitator - 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:

A-36 09/05/13

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:

A-37 09/05/13

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:

A-38 09/05/13

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

Average (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:

A-39 09/05/13

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:

A-40 09/05/13

(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:

A-41 09/05/13

(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:

A-42 09/05/13

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:

A-43 09/05/13

Subject Item: CE 032 Selective Catalytic Reduction

Associated Items: EU 026 Combustion Turbine (Dry Low NOx Combustors & 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).

At 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

As 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:

A-44 09/05/13

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:

A-45 09/05/13

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:

A-46 09/05/13

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:

A-47 09/05/13

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:

A-48 09/05/13

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:

A-49 09/05/13

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:

A-50 09/05/13

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:

A-51 09/05/13

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:

A-52 09/05/13

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

Additional 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.

Acceptable 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:

A-53 09/05/13

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

Additional 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:

A-54 09/05/13

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