Technical Support Document, Permit Action Number: 05900014‐004 Page 1 of 14
TECHNICAL SUPPORT DOCUMENT
For DRAFT/PROPOSED AIR EMISSION PERMIT NO. 05900014‐004
This technical support document (TSD) is intended for all parties interested in the draft/proposed 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 preliminary determination to issue the draft/proposed permit. 1. General Information 1.1 Applicant and Stationary Source Location
Table 1. Applicant and Source Address
Applicant/Address Stationary Source/Address
(SIC Code: 4911)
Great River Energy 12300 Elm Creek Boulevard Maple Grove, MN 55369
Great River Energy ‐ Cambridge
2438 349th Avenue Northeast
Cambridge, Isanti County, Minnesota 55008
Contact: Greg Archer Phone: 763‐445‐5206
1.2 Facility Description Great River Energy owns and operates a simple‐cycle combustion turbine generating plant in Cambridge,
Isanti County, Minnesota. The facility consists of one 29.3 megawatts (MW) combustion turbine, a 190
MW natural gas turbine equipped with dry low NOx burners, a black‐start generator, emergency diesel
fire pump, telecom building generator, a fuel tank for distillate oil storage, associated fuel oil forwarding
system and insignificant activities.
The facility is a major source under the federal operation permits program (40 CFR pt. 70) and non major
source under federal New Source Review (NSR). The facility is an area source under the National
Emission Standards for Hazardous Air Pollutants (NESHAPs, 40 CFR pt. 63). This facility is subject to the
Acid Rain Program and was subject the Clean Air Interstate Rule (CAIR) but is now subject to the
Transport Rule (TR)/Cross‐State Air Pollution Rule (CSAPR).
1.3 Description of the Activities Allowed by this Permit Action This permit action is the reissuance of the Part 70 operating permit.
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1.4 Description of Notifications and Applications Included in this Action
Table 2. Notifications and Applications Included in this Action Date Received DQ# Application/Notification Type and description
01/24/2013 4275 Part 70 Reissuance Application
1.5 Facility Emissions
Table 3. 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
21 21 5.1 140 245 122 312,570 14 1.9 2.7
Total Facility Actual
Emissions (2012)
0.302 0.301 0.050 0.311 32.9 14.7 * 1.05 *
*Not reported in MN emission inventory.
Table 4. Facility Classification Classification Major/Affected Source Synthetic Minor/Area Minor/Area
PSD X
Part 70 Permit Program X
Part 63 NESHAP X
1.6 Changes to Permit The permit does not authorize any specific modifications, however, 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 to the permit are also made through this permit action:
The permit has been updated to reflect current MPCA templates and standard citation formatting.
PTE Calculations were updated to include Greenhouse Gases (GHGs), and PM2.5 emissions.
Completed requirements and the requirements for equipment that has been removed have been deleted.
Appendix D was added to the permit. Appendix D contains the 40 CFR pt. 63, subp. ZZZZ requirements for emergency diesel fire pump engine (EU 003) and black start diesel engine (EU 004) since the facility is an area source.
Appendix E was added to the permit. Appendix E contains the 40 CFR pt. 63, subp. ZZZZ requirements for telecom building generator.
On November 3, 2009, EPA promulgated a final rule entitled “Administrative Stay of Clean Air Interstate Rule (CAIR) for Minnesota; Administrative Stay of Federal Implementation Plan to Reduce Interstate Transport of Fine Particulate Matter and Ozone for Minnesota” (74 FR 56721). This rule became effective on December 3, 2009. The rule states that EPA is staying the
Technical Support Document, Permit Action Number: 05900014‐004 Page 3 of 14
application of CAIR and the CAIR FIP with respect to Minnesota and Minnesota sources, pending further rulemaking in response to the DC Circuit Court’s remand of CAIR to EPA. CAIR requirements were removed from the permit. The Cross‐State Air Pollution Rule (CSAPR) general requirements stating that the facility shall comply with 40 CFR pt. 97 have been added at the total facility level, as well as requirements stating that the facility shall submit information related to 40 CFR pt. 97 when requested by the MPCA after the sunset of CAIR.
Insignificant activities data have been updated based on the equipment that was actually installed.
Updated the Data Acquisition Systems (DAS) to reflect existing continuous emission monitoring systems (CEMS) MR 001 and MR 002 for NOx and O2 respectively, which were certified and installed in 2011.
MRs 003 and 004 were removed from the permit. EU 001 lists monitoring systems MR 003 and MR 004 to reflect a future ability to install CEMS. EU 001 does not currently have CEMS; therefore, MR 003 and MR 004 will be removed from the permit until the Permittee plans to install the units. EU 001 does have a calibrated fuel flow monitor, consistent with EPA 40 CFR Section 75.19, a Low Mass Emissions (LME) requirement, which was installed to comply with CAIR. QA/QC plan requirements were added under EU 001.
Based on EPA authorizations to use Part 75 in lieu of Part 60 for RATA/linearity schedules, the permit was updated to reflect this authorization.
NOx Predictive Emissions Monitoring System (PEMS) has been removed from the site; therefore all the applicable requirements under GP 002 were removed from the permit. The Permittee has no intention to replace with another PEMS.
Under GP 002, the citations to 40 CFR pt. 72, Section 2.2.2 were removed since these requirements apply to flow monitors. EU 002 does not have a flow monitor.
Low NOx burners (CE 001) for NOx control are listed for natural gas combustion turbine (EU 002). These burners are integral to the combustion process, are not considered control devices as defined in 40 CFR Section 64.1. (See also the definitions in NSPS, 40 CFR pt. 60, subp. KKKK for stationary turbine, which excludes emission controls, and lean premix stationary combustion turbine, which inherently include the premix burner, as a non‐emission control, which is consistent with 40 CFR Section 64.1.) Based on this information from the Permittee, CE 001 was removed from the facility description in Delta.
Fuel certification is no longer necessary for compliance with Minn. R. 7011.2300; therefore, the requirement was removed from EU 003 and EU 004. The fuel type restriction will meet the requirements of 40 CFR Section 80.510(c), of less than 15 parts per million (ppm).
Some requirements have been reordered to help with clarity (i.e., similar requirements are grouped).
2. Regulatory and/or Statutory Basis New Source Review The facility is an existing non major source under New Source Review regulations. No changes are authorized by this permit. Part 70 Permit Program The facility is a major source under the Part 70 permit program.
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New Source Performance Standards (NSPS) EU 002 is subject to 40 CFR pt. 60, subp. KKKK, Standards of Performance for Stationary Combustion Turbines. In addition to the general requirements, the subpart contains limits for NOx and SO2 provisions to monitor sulfur and nitrogen content of fuels burned, and for CEMS. EU 002 is connected to Northern Natural Gas pipeline, which has a maximum sulfur content of less than 20 grains of sulfur or less per 100 standard cubic feet. By maintaining a current tariff sheet, as indicated in 40 CFR Section 60.4365(a), EU 002 is exempt from 40 CFR pt. 60, subp. KKKK sulfur monitoring and annual performance test requirements as described in 40 CFR Section 60.4365. EU 001 is not subject to 40 CFR pt. 60, subp. KKKK due to its construction date which was August 1, 1977. The subpart is applicable to units that commenced construction, modification or reconstruction after February 18, 2005. The provisions of 40 CFR pt. 60 subp. GG (Standards of Performance for Stationary Gas Turbines) are applicable to all stationary gas turbines, which commence construction, modification, or reconstruction after October 3, 1977, with a heat input at peak load equal to or greater than 10 mmBtu/hr, based on the lower heating value of the fuel fired. The combustion turbine (EU 001) was constructed on August 1, 1977 and has a peak load greater than 10 mmBtu/hr but the burners were replaced during permit action 002 which resulted in a decrease in hourly emission rates of pollutants regulated under the rule; therefore, 40 CFR pt. subp. GG does not apply to the combustion turbine (EU 001). EU 002 is exempt from the requirements of 40 CFR pt. 60, subp. GG because the turbine is regulated under 40 CFR pt. 60, subp. KKKK. The NOx limit of 103.8ppm by volume was removed because it was based on 40 CFR pt. 60, subp. GG. The engines (EUs 003 and 004) are not subject to 40 CFR pt. 60, subp. IIII, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines based on the date they were constructed (ordered) and manufactured. National Emission Standards for Hazardous Air Pollutants (NESHAP) The existing facility is an area source for HAPs and is subject to 40 CFR pt. 63, subp. ZZZZ , the Reciprocating Internal Combustion Engines (RICE) for the three existing engines. Combustion turbines (EUs 001 and 002) are not subject to 40 CFR pt. 63 subp. YYYY, National Emission Standards for Hazardous Air Pollutants for Stationary Combustion Turbines because the turbines are not located at a major source of HAP emissions. Compliance Assurance Monitoring (CAM)
This permit action is a reissuance of a Part 70 permit; therefore, CAM applies to any emission units which meet the CAM applicability requirements in 40 CFR pt. 64:
The unit is subject to an emission limitation or standard for the applicable regulated air pollutant,
The unit uses a control device to achieve compliance, and
The unit has potential pre‐control device emissions of the pollutant that are equal to or greater than 100 percent of the amount, in tons per year, required for the source to be classified as a major source.
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The facility does not use a control device to achieve compliance; therefore, the requirements of 40 CFR pt. 64 are not applicable. Acid Rain program The facility is an affected facility and the combustion turbine, EU 002 is subject to the acid rain provisions in 40 CFR pt. 75. The Phase II permit application is included in the permit as Appendix B. Clean Air Interstate Rule (CAIR) and the Transport Rule (TR)/Cross‐State Air Pollution Rule (CSAPR)
Great River Energy‐ Cambridge was subject to CAIR when initially promulgated in 2005.
Great River Energy‐ Cambridge submitted a CAIR application on June 30, 2008.
CAIR was administratively stayed in Minnesota in December of 2009, so the application was returned.
CAIR was replaced by TR/CSAPR in 2011, but TR/CSAPR was stayed by the D.C. Circuit, and EPA was told to go back to CAIR.
The Supreme Court reversed the decision in 2014, and requested the D.C. Circuit to lift the stay
The D.C. Circuit court did so, with an extension of the original compliance dates by three years
Now, implementation of CSAPR will occur. Additional EPA guidance is expected in early 2015.
For now, general requirements stating that the facility shall comply with 40 CFR pt. 97 have been added at the total facility level, as well as requirements stating that the facility shall submit information related to 40 CFR pt. 97 when requested by the MPCA.
When EPA guidance is available on how to incorporate CAIR requirements in permits, we plan on sending letters to CSAPR facilities. This letter may include a request for an amendment application. Therefore, a requirement making it clear that an amendment application must be submitted for newly promulgated applicable requirements if there are 3 years remaining in the permit term has also been added at the total facility level.
Minnesota State Rules
Minn. R. 7011.0715 Standards of Performance for Post‐1969 Industrial Process Equipment for Insignificant Activities
Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines
Table 5. Regulatory Overview of Facility Subject Item* Applicable Regulations Rationale
FC 40 CFR pt. 72 Subject to the U.S. EPA Acid Rain Program codified at 40 CFR pts. 72,
73, 75, 77 and 78.
FC Minn. R. 7030.0010 through 7030.0080
The language 'This is a state‐only requirement and is not enforceable
by the U.S. Environmental Protection Agency (EPA) Administrator
and citizens under the Clean Air Act' refers to permit requirements
that are established only under state law and are not established
under or required by the federal Clean Air Act. The language is to
clarify the distinction between permit conditions that are required
by federal law and those that are required only under state law.
State law‐only requirements are not enforceable by the EPA or by
citizens under the federal Clean Air Act, but are fully enforceable by
the MPCA and citizens under provisions of state law.
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Subject Item* Applicable Regulations Rationale
GP 001 (NOx
limit)
40 CFR § 52.21 and Minn. R. 7007.3000
Title I Condition: limit taken to avoid major source status. This limit
includes a total NOX emission limit of 244 tons/yr. Since NOx is the
limiting pollutant, all other criteria pollutants would be less than 250
tons/yr.
EU 001
(Combustion
Turbine)
Minn. R. 7011.2300
40 CFR pt. 97
Standards of Performance for Stationary Internal Combustion
Engines. The rule applies to opacity and SO2.
Transport Rule (TR)/Cross‐State Air Pollution (CSAPR). The rule
applies to NOx and SO2.
EU 002
(Combustion
Turbine)
40 CFR pt. 60, subp. KKKK New Source Performance Standards for Stationary Gas Turbines. The
rule applies to NOx and SO2.
40 CFR pt. 72 The Acid Rain application is included as an appendix to the permit.
EUs 003 and
004 (Pump
Engine and
Black Start
Engine)
Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion
Engines. The rule applies to opacity and SO2.
40 CFR § 52.21 and Minn. R. 7007.3000
Title I Condition: limit on hours of operation set in a previous permit.
40 CFR pt. 63, subp. ZZZZ National Emission Standards for Hazardous Air Pollutants (NESHAP)
for Stationary Reciprocating Internal Combustion Engines. All engines
are Existing, Compression Ignition, emergency less than 500hp
Engines.
*Location of the requirement in the permit (e.g., EU, SV, GP, etc.). 3. Technical Information 3.1 Calculations of Potential to Emit Attachment 2 to this TSD contains Form GI‐07, which summarizes the PTE of the Facility, while Attachment 1 contains detailed spreadsheets and supporting information prepared by the Permittee and audited and approved by the MPCA staff. The PTE emissions for the PM, PM10,VOCs and HAPs for the turbines were based on emission factors from AP‐42 and EPA Technology Transfer Network Air Toxics Website, Stationary Combustion Turbines NESHAP, Combustion Turbine Emissions. PM2.5 PTE emissions were estimated based upon EPA’s Webfire emission factors. GRE’s Turbine manufacturer does not have PM2.5 emission estimates. The EPA test procedures (Method 5 and Method 202) have significant difficulties with the elevated temperatures of combustion turbine exhaust and the extremely low emissions. While CO is not directly limited through an emission limit, it is inherently limited by the NOX limit on GP 001 and the startup time limit of 45 minutes. CO emissions are significantly higher during the startup, when the dry low NOx combustors are not operating in lean pre‐mix mode. It was demonstrated for the permit of another Great River Energy facility with the same type of combustion gas turbine at the Great River Energy‐Pleasant Valley facility that based on startup and operating mode emission factors provided by the Permittee, and the relative amount of time that the combustion turbine generators would spend in “normal” operation vs.
Technical Support Document, Permit Action Number: 05900014‐004 Page 7 of 14
“startup” operation, it is conservative to assume that overall CO emissions would be 50% of the NOX emissions. NOX emissions from EU 001 and EU 002 are measured using a NOX CEMS, as required by the NSPS and Acid Rain programs. The Permittee will follow the fuel sulfur monitoring requirements as indicated in 40 CFR Section 60.4365. CO2e includes CO2 emissions as well as CO2e emissions of CH4 and N2O calculated using Global‐warming potential (GWP). Emission Factors for CO2, CH4 and N2O taken from EPA 40 CFR pt. 98 Tables C‐1 and C‐2. EU 003 has a source restricted operation to 150 hours per year. The PM PTE emissions were calculated based on PM using emission factors supplied by the manufacturer. PM10 emissions were based on emission factors from AP‐42 Table 3.3‐1. The manufacturer does not supply an emission factor for PM2.5; therefore PM2.5 was conservatively assumed the same as PM10. CO2e includes CO2 emissions as well as CO2e emissions of CH4 and N2O calculated using GWP. Emission Factors for CO2, CH4 and N2O (lb/mmBtu) taken from EPA 40 CFR 98 Tables C‐1 and C‐2 as no other GHG emission factors are provided for this type of engine. The Permittee will follow the emergency only operating provisions of 40 CFR pt. 63, subp. ZZZZ. EU 004 has a source restricted operation to 70 hours per year. The PM and PM10 PTE emissions were based on emission factors from AP‐42 Table 3.3‐1. No emission factor for PM2.5 is provided in AP‐42 or EPA Webfire for uncontrolled gasoline and diesel engines; therefore PM2.5 was conservatively assumed the same as PM10. CO2e includes CO2 emissions as well as CO2e emissions of CH4 and N2O calculated using GWP. Emission Factors for CO2, CH4 and N2O (lb/mmBtu) taken from EPA 40 CFR 98 Tables C‐1 and C‐2 as no other GHG emission factors are provided for this type of engine. The Permittee will follow the emergency only operating provisions of 40 CFR pt. 63, subp. ZZZZ. 3.2 Dispersion Modeling Per MPCA policy, as permitted in the original Part 70 permit, the facility triggered the requirement to submit modeling information. The company was not required to complete dispersion modeling. So, the Tier language does not apply. This modeling information will be used if required by nearby sources. 3.3 Monitoring 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. In evaluating the monitoring included in the permit, the MPCA considered the following:
the likelihood of the facility 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.
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Table 6 summarizes the monitoring requirements.
Table 6. Monitoring Subject
Item* Requirement (basis) Monitoring Discussion
GP 001 (NOx
limit for EU
001 and EU
002)
NOx ≤ 244.0 tons
per year, on a 12
month rolling basis
(Facility‐wide limit
of 245 tons per year,
which includes
significant activities)
(limit to avoid NSR)
Recordkeeping:
Monthly records and
calculations of NOx
emissions. CEMS will
be used to measure
NOx emissions from
EU 002
This facility is a peaking plant. The plant is
intended for intermittent use rather than daily
usage; therefore, it is reasonable for this facility to
have monthly recordkeeping and calculation for
the source wide NOx limit than daily
recordkeeping.
NOx is the limiting pollutant for the entire facility;
therefore it is adequate to restrict and monitor
NOx emissions for purposes of avoiding NSR. By
limiting NOx emissions from the turbines, all other
pollutants will be limited as well; therefore, no
additional monitoring is warranted. One ton was
added for the insignificant activities.
The company will use CEM to measure NOx
emissions. Since the facility will not have the 5‐
10% buffer between the permitted emission limit
and the federal threshold, if the limit is relaxed at
any time, the facility will be subject to the
requirements of 40 CFR Section 52.21(r)(4).
EU 001
(Combustion
Turbine)
SO2: 0.50 lb/mmBtu
heat input
Opacity: ≤ 20 %
(Minn. R.
7011.2300)
Fuel Type: Pipeline
natural gas or No. 2
fuel oil/diesel fuel
(Minn. R.
7005.0100)
Fuel Monitoring
(CSAPR)
CMS: Fuel flow meter
will be used to record
and calculate NOx and
SO2 emissions for
CSAPR allowances
Fuel certification is no longer necessary for
compliance with Minn. R. 7011.2300. The fuel type
restriction will meet the requirements of 40 CFR
Section 80.510(c), of less than 15 parts per million
(ppm).
The Permittee will use the fuel flow meter as
described under 40 CFR Section 75.19 low mass
emission methodology to record and calculate NOx
and SO2 emissions for CSAPR based on its effective
date January 1, 2015.
The Permittee can demonstrate that the turbine
will continue to operate such that emissions are
well below the emission limits by burning natural
gas and sulfur fuel oil; therefore, no additional
monitoring is required.
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Subject
Item* Requirement (basis) Monitoring Discussion
Operating Scenarios
(Minn. R.
7007.0800)
There are three
operating Scenarios
for this unit
1. Daily and monthly
recordkeeping
2. Performance testing
3. CEMS
The company continues to operate under Scenario
1. The Permittee will record on a daily basis the
amounts of natural gas and fuel oil combusted in
the turbine. In addition, the Permittee will
calculate and record on a monthly basis the
amount of natural gas and fuel oil combusted. The
facility currently has a fuel flow monitor, which will
be used consistent with 40 CFR Section 75.19. The
other two scenarios are still viable.
EU 002
(Combustion
Turbine 002)
NOx: ≤ 15 ppm at
15% O2 when
operating at above
75% of peak loading
(NSPS, subp. KKKK)
Monitoring: CEMS will
be used to measure
NOx emissions
The CEMS was installed and operated in
accordance with the acid rain program (40 CFR pt.
75), which was allowed as a NOx monitoring
option. NOx performance test was done in 2007 to
calibrate the CEMS. The CEMS will be used to
monitor the NOx emission limits; therefore, no
additional monitoring will be required.
NOx: ≤ 96 ppm at
15% O2 when
operating less than
75% of peak loading
(NSPS, subp. KKKK)
SO2:≤0.90 lb/MWh
gross output
(NSPS, subp. KKKK)
Tariff sheet specifying
the maximum sulfur
content: ≤ 20
grains/100 scf.
EU 002 is connected to Northern Natural Gas
pipeline, which has a maximum sulfur content of
less than 20 grains/scf. By maintaining a current
tariff sheet as described in 40 CFR Section 60.4365,
the turbine is exempt from sulfur monitoring and
annual performance test requirements.
SO2: 0.50 lb/mmBtu
heat input
Opacity: ≤ 20 %
(Minn. R.
7011.2300)
None The NSPS limit (0.060 lb/mmBtu heat input) is
more stringent than Minn. R. SO2 limit; therefore
compliance will be demonstrated with the NSPS
limit.
Startup time:≤ 45
minutes
(limit to avoid NSR)
Recordkeeping‐Daily Recordkeeping is adequate to ensure CO emissions
are minimized during startup of the turbine.
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Subject
Item* Requirement (basis) Monitoring Discussion
EU 003
(Emergency
Diesel Fire
Pump
Engine)
SO2: 0.50 lb/mmBtu
heat input
Opacity: ≤ 20 %
(Minn. R.
7011.2300)
None Fuel certification no longer necessary for
compliance with Minn. R. 7011.2300. The fuel type
will meet the requirements of 40 CFR Section
80.510(c), of less than 15 parts per million (ppm).
The Permittee can demonstrate that the turbine
will continue to operate such that emissions are
well below the emission limits by burning natural
gas and sulfur fuel oil; therefore, no additional
monitoring is required.
Hours of operation:
≤ 150 hours per year
(limit to avoid NSR)
Recordkeeping‐
Monthly
recordkeeping if
actual hours of
operating is greater
than 75 hours per year
in any calendar year
Monitoring actual hours of operation will ensure
NOx emissions to be minimized. Maintaining
monthly records over 75 operating hours will be
adequate to ensure NOx emissions will not exceed
major source thresholds.
Operating
Limitations
(NESHAP, subp.
ZZZZ)
Area Source NESHAP
(See Appendix D of
the permit)
Monitoring and recordkeeping as prescribed by the
NESHAPS, Subpart ZZZZ is adequate to ensure
continuous compliance.
EU 004
(Diesel
Starting
Engine)
SO2: 0.50 lb/mmBtu
heat input
Opacity: ≤ 20 %
(Minn. R.
7011.2300)
None Fuel certification is no longer necessary for
compliance with Minn. R. 7011.2300. The fuel type
restriction will meet the requirements of 40 CFR
Section 80.510(c), of less than 15 parts per million
(ppm).
Hours of operation:
≤ 70 hours per year
(limit to avoid NSR)
Recordkeeping‐
Monthly
recordkeeping if
actual hours of
operating is greater
than 20 hours per year
in any calendar year
Monitoring actual hours of operation will ensure
NOx emissions to be minimized. Maintaining
monthly records over 20 operating hours will be
adequate to ensure NOx emissions will not exceed
major source thresholds.
Operating
Limitations
(NESHAP, subp.
ZZZZ)
Area Source NESHAP
(See Appendix D of
the permit)
Monitoring and recordkeeping as prescribed by the
NESHAPS, Subpart ZZZZ is adequate to ensure
continuous compliance.
*Location of the requirement in the permit (e.g., EU, SV, GP, etc.). 3.4 Insignificant Activities Great River Energy ‐ Cambridge has several operations which are classified as insignificant activities under the MPCA’s permitting rules. These are listed in Appendix C to the permit.
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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 current insignificant activities. See Attachment 1 of this TSD for PTE information for the insignificant activities.
Table 7. Insignificant Activities
Insignificant Activity
General Applicable
Emission limit Discussion
Miscellaneous: brazing,
soldering or welding
equipment
[Facility performs some
brazing, soldering or welding
activities for plant
maintenance and repairs]
PM, variable depending
on airflow
Opacity ≤ 20%
(Minn. R.
7011.0710/0715)
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
1) 4,000 lbs/year of CO; 2)
2,000 lbs/year each of NOx,
SO2, PM, PM10, VOCs and
ozone; and 3) 1,000 tpy of
CO2e.
[Telecom building LP generator SG020
Substation circuit breakers
SF6]
PM, variable depending
on airflow
Opacity ≤ 20% (with
exceptions)
(Minn. R. 7011.0715 and
Minn. R. 7011.0610)
or
SO2 ≤ 0.50 lb/MMBtu
Opacity ≤ 20%
(Minn. R. 7011.2300)
40 CFR pt. 63, subp. ZZZZ
There is a circuit breaker and an emergency
generator. The circuit breaker estimated emissions
are significant below the threshold for CO2e
emissions. The generator combusted very low
sulfur diesel; therefore based on the fuel used and
EPA published emissions factors, it is highly unlikely
that they could violate the applicable requirement.
The applicable requirements for the Telecom
building generator are listed in Appendix E of the
permit.
Fugitive Emissions
[Fugitive Emissions from
unpaved roads and parking
lots]
Requirement to take
reasonable measures to
prevent PM from
becoming airborne (Minn.
R. 7011.0150)
The Permittee will take reasonable precautions to
prevent the discharge of visible fugitive dust
emissions beyond the fence line of the property on
which the emissions will be generated.
Emissions units with actual
emissions of 1) 2 tpy CO; 2)
1 tpy each of NOx, SO2, PM.
PM10, VOCs and ozone; 3)
1,000 tpy CO2e.
[Parts washers – VOC actual
emissions less than 1 tpy]
PM, variable depending
on airflow
Opacity ≤ 20% (with
exceptions)
Minn. R. 7011.0710/0715
This is very small, intermittent, bench‐top
operation that typically does not even have any
emissions. It is highly unlikely that they could
violate the applicable requirements.
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Insignificant Activity
General Applicable
Emission limit Discussion
Emissions units with actual
emissions of 1) 2 tpy CO; 2)
1 tpy each of NOx, SO2, PM.
PM10, VOCs and ozone; 3)
1,000 tpy CO2e.
[150,000 gals fuel oil storage
tank and associated piping]
Minn. R. 7011.1505
There are no standards of performance applicable
for storage vessels/tanks.
3.5 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 electronically tracked (e.g., limits, submittals, etc.), should be in Table A or B of the permit. The main reason is that the appendices are word processing sections and are not part of the electronic 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. Another area that deviates from the guidance is in the use of groups where the requirements in the group apply to the members of the group individually. This was done in order to shorten the permit and where no testing or tracking specific to a unit is in the permit (thereby reducing the likelihood that there where will be further unit‐specific requirements later). This is the case for the requirements at GP 001(combined NOx limit) and GP 002 (continuous emission monitors). 3.6 Comments Received Public Notice Period: <start date> ‐ <end date> EPA 45‐day Review Period: <start date> ‐ <end date> This section will be completed after the referenced review periods above. 4. Permit Fee Assessment This permit action is the reissuance of an individual Part 70; therefore, no application fees apply under Minn. R. 7002.0016, subp. 1. There are no additional points required by this permit action. 5. Conclusion Based on the information provided by Great River Energy, the MPCA has reasonable assurance that the proposed operation of the emission facility, as described in the Air Emission Permit No. 05900014‐004 and this TSD, will not cause or contribute to a violation of applicable federal regulations and Minnesota Rules. Staff Members on Permit Team: Amrill Okonkwo (permit engineer)
David Crowell (compliance and enforcement)
Technical Support Document, Permit Action Number: 05900014‐004 Page 13 of 14
Tarik Hanafy (peer reviewer) Beckie Olson (permit writing assistant) Laurie O’Brien (administrative support)
AQ File No. 147C; DQ 4275 Attachments: 1. PTE Summary Calculation Spreadsheets
2. Facility Description and CD‐01 Forms 3. Points Calculator
Attachment 1 – PTE Summary Calculation Spreadsheets (Available electronically in the Central File of Delta)
Attachment 2‐ Facility Description and CD‐01 Forms (Available electronically in the Central File of Delta)
Attachment 3‐ Points Calculator
(Available electronically in an excel spreadsheet in the Central File of Delta)
Attachment 1- PTE Summary Calculation Spreadsheets
Gre
at R
iver
Ene
rgy
- Cam
brid
geE
miss
ion
Cal
cula
tions
Max
imum
Em
issi
onE
mis
sion
Ope
ratin
gPo
tent
ial t
oO
pera
ting
Pote
ntia
l to
Uni
tH
eat I
nput
Rat
eR
ate
Hou
rsE
mit
(PT
E)
Hou
rsE
mit
(PT
E)
IDU
nit N
ame
Fuel
Pollu
tant
(MM
Btu
/hr)
(lb/h
r)(g
/s)
(hr/
yr)
(ton/
yr)
(hr/
yr)
(ton/
yr)
001
Uni
t 1N
at. G
asV
OC
363.
32.
10E
-03
20.
89.
61E
-02
8760
3.3
4197
1.6
001
Uni
t 1N
at. G
asPM
363.
36.
60E
-03
22.
43.
02E
-01
8760
10.5
4197
5.0
001
Uni
t 1N
at. G
asPM
1036
3.3
6.60
E-0
32
2.4
3.02
E-0
187
6010
.541
975.
000
1U
nit 1
Nat
. Gas
PM2.
536
3.3
1.90
E-0
38
0.7
8.70
E-0
287
603.
041
971.
400
1U
nit 1
Nat
. Gas
CO
363.
38.
20E
-02
229
.83.
75E
+00
8760
130.
541
9762
.500
1U
nit 1
Nat
. Gas
SO2
363.
39.
15E
-05
20.
034.
19E
-03
8760
0.1
4197
0.07
000
1U
nit 1
Nat
. Gas
H2S
O4
Mis
t36
3.3
1.83
E-0
65
0.00
078.
37E
-05
8760
0.00
341
970.
0014
001
Uni
t 1N
at. G
asN
OX
363.
33.
20E
-01
211
61.
46E
+01
8760
509.
241
9724
4.0
001
Uni
t 1N
at. G
asC
O2e
363.
31.
17E
+02
742
,509
5.36
E+
0387
6018
6,19
041
9789
,206
001
Uni
t 1N
at. G
as1,
3-B
utad
iene
363.
34.
30E
-07
21.
6E-0
41.
97E
-05
8760
0.00
141
970.
0003
001
Uni
t 1N
at. G
asA
ceta
ldeh
yde
363.
34.
00E
-05
21.
5E-0
21.
83E
-03
8760
0.06
441
970.
030
001
Uni
t 1N
at. G
asA
crol
ein
363.
36.
40E
-06
22.
3E-0
32.
93E
-04
8760
0.01
041
970.
005
001
Uni
t 1N
at. G
asB
enze
ne36
3.3
1.20
E-0
52
4.4E
-03
5.49
E-0
487
600.
019
4197
0.00
900
1U
nit 1
Nat
. Gas
Eth
yl b
enze
ne36
3.3
3.20
E-0
52
1.2E
-02
1.46
E-0
387
600.
051
4197
0.02
400
1U
nit 1
Nat
. Gas
Form
alde
hyde
363.
37.
10E
-04
22.
6E-0
13.
25E
-02
8760
1.13
041
970.
5400
1U
nit 1
Nat
. Gas
Nap
htha
lene
363.
31.
30E
-06
24.
7E-0
45.
95E
-05
8760
0.00
241
970.
0009
900
1U
nit 1
Nat
. Gas
PAH
363.
32.
20E
-06
28.
0E-0
41.
01E
-04
8760
0.00
441
970.
0016
800
1U
nit 1
Nat
. Gas
Prop
ylen
e ox
ide
363.
32.
90E
-05
21.
1E-0
21.
33E
-03
8760
0.04
641
970.
022
001
Uni
t 1N
at. G
asT
olue
ne36
3.3
1.30
E-0
42
4.7E
-02
5.95
E-0
387
600.
207
4197
0.09
900
1U
nit 1
Nat
. Gas
Xyl
enes
363.
36.
40E
-05
22.
3E-0
22.
93E
-03
8760
0.10
241
970.
049
Tota
l HAP
3.7E
-01
4.70
E-0
21.
635
7.8E
-01
001
Uni
t 1D
is. O
ilV
OC
363.
34.
10E
-04
21.
5E-0
11.
88E
-02
8760
0.65
215
260.
114
001
Uni
t 1D
is. O
ilPM
363.
31.
20E
-02
24.
365.
49E
-01
8760
19.0
9515
263.
326
001
Uni
t 1D
is. O
ilPM
1036
3.3
4.30
E-0
32
1.56
1.97
E-0
187
606.
842
1526
1.19
200
1U
nit 1
Dis
. Oil
PM2.
536
3.3
1.11
E-0
28
4.02
5.07
E-0
187
6017
.615
1526
3.06
900
1U
nit 1
Dis
. Oil
CO
363.
33.
30E
-03
21.
201.
51E
-01
8760
5.25
115
260.
915
001
Uni
t 1D
is. O
ilSO
236
3.3
5.05
E-0
22
18.3
52.
31E
+00
8760
80.3
5815
2613
.998
001
Uni
t 1D
is. O
ilH
2SO
4 M
ist
363.
31.
01E
-03
50.
374.
62E
-02
8760
1.60
715
260.
280
001
Uni
t 1D
is. O
ilN
OX
363.
38.
80E
-01
231
9.70
4.03
E+
0187
6014
00.3
0415
2624
3.93
400
1U
nit 1
Dis
. Oil
CO
2e36
3.3
1.64
E+
027
59,4
357,
489
8760
260,
327
1526
45,3
4900
1U
nit 1
Dis
. Oil
1,3
-but
adie
ne36
3.3
1.60
E-0
52
5.8E
-03
7.32
E-0
487
600.
025
1526
0.00
400
1U
nit 1
Dis
. Oil
Ben
zene
363.
35.
50E
-05
22.
0E-0
22.
52E
-03
8760
0.08
815
260.
015
001
Uni
t 1D
is. O
ilFo
rmal
dehy
de36
3.3
2.80
E-0
42
1.0E
-01
1.28
E-0
287
600.
446
1526
0.07
800
1U
nit 1
Dis
. Oil
Nap
htha
lene
363.
33.
50E
-05
21.
3E-0
21.
60E
-03
8760
0.05
615
260.
010
001
Uni
t 1D
is. O
ilPA
H36
3.3
4.00
E-0
52
1.5E
-02
1.83
E-0
387
600.
064
1526
0.01
100
1U
nit 1
Dis
. Oil
Ars
enic
363.
31.
10E
-05
24.
0E-0
35.
04E
-04
8760
0.01
815
260.
003
001
Uni
t 1D
is. O
ilB
eryl
lium
363.
33.
10E
-07
21.
1E-0
41.
42E
-05
8760
0.00
015
260.
000
001
Uni
t 1D
is. O
ilC
adm
ium
363.
34.
80E
-06
21.
7E-0
32.
20E
-04
8760
0.00
815
260.
001
001
Uni
t 1D
is. O
ilC
hrom
ium
363.
31.
10E
-05
24.
0E-0
35.
04E
-04
8760
0.01
815
260.
003
001
Uni
t 1D
is. O
ilL
ead
363.
31.
40E
-05
25.
1E-0
36.
41E
-04
8760
0.02
215
260.
004
001
Uni
t 1D
is. O
ilM
anga
nese
363.
37.
90E
-04
22.
9E-0
13.
62E
-02
8760
1.25
715
260.
219
001
Uni
t 1D
is. O
ilM
ercu
ry36
3.3
1.20
E-0
62
4.4E
-04
5.49
E-0
587
600.
002
1526
0.00
000
1U
nit 1
Dis
. Oil
Nic
kel
363.
34.
60E
-06
21.
7E-0
32.
11E
-04
8760
0.00
715
260.
001
001
Uni
t 1D
is. O
ilSe
leni
um36
3.3
2.50
E-0
52
9.1E
-03
1.14
E-0
387
600.
040
1526
0.00
7
Em
issi
on F
acto
r(lb
/uni
ts)
(R
ef.)
Unl
imite
d L
imite
d O
pera
tion
Ope
ratio
n(2
44 tp
y N
Ox)
Unc
ontr
olle
dL
imite
d
P:\2
3\19
\845
\Air\
Emiss
ions
\Cal
cs\W
orks
heet
inol
e_m
ain
Page
1of
12Pr
inte
d4/
21/2
015
Gre
at R
iver
Ene
rgy
- Cam
brid
geE
miss
ion
Cal
cula
tions
Max
imum
Em
issi
onE
mis
sion
Ope
ratin
gPo
tent
ial t
oO
pera
ting
Pote
ntia
l to
Uni
tH
eat I
nput
Rat
eR
ate
Hou
rsE
mit
(PT
E)
Hou
rsE
mit
(PT
E)
IDU
nit N
ame
Fuel
Pollu
tant
(MM
Btu
/hr)
(lb/h
r)(g
/s)
(hr/
yr)
(ton/
yr)
(hr/
yr)
(ton/
yr)
Em
issi
on F
acto
r(lb
/uni
ts)
(R
ef.)
Unl
imite
d L
imite
d O
pera
tion
Ope
ratio
n(2
44 tp
y N
Ox)
Unc
ontr
olle
dL
imite
d
Tota
l HAP
4.7E
-01
5.90
E-0
22.
049
3.6E
-01
002
Uni
t 2N
at. G
asV
OC
1850
5.08
E-0
31
9.4
1.18
E+
0087
6041
.228
8713
.600
2U
nit 2
Nat
. Gas
PM18
507.
84E
-03
114
.51.
83E
+00
8760
63.5
2887
20.9
002
Uni
t 2N
at. G
asPM
1018
507.
84E
-03
114
.51.
83E
+00
8760
63.5
2887
20.9
002
Uni
t 2N
at. G
asPM
2.5
1850
1.90
E-0
38
3.5
4.43
E-0
187
6015
.428
875.
100
2U
nit 2
Nat
. Gas
CO
1850
2.00
E-0
21
37.0
4.66
E+
0087
6016
2.1
2887
53.4
002
Uni
t 2N
at. G
asSO
218
509.
15E
-05
20.
22.
13E
-02
8760
0.7
2887
0.2
002
Uni
t 2N
at. G
asH
2SO
4 M
ist
1850
1.83
E-0
65
0.00
344.
26E
-04
8760
0.01
528
870.
0049
002
Uni
t 2N
at. G
asN
OX
1850
9.14
E-0
21
1.69
E+
022.
13E
+01
8760
740.
228
8724
4.0
002
Uni
t 2N
at. G
asC
O2e
1850
1.17
E+
027
216,
466
2.73
E+
0487
6094
8,12
228
8731
2,46
900
2U
nit 2
Nat
. Gas
1,3-
But
adie
ne18
504.
30E
-07
28.
0E-0
41.
00E
-04
8760
0.00
328
870.
0011
002
Uni
t 2N
at. G
asA
ceta
ldeh
yde
1850
4.00
E-0
52
7.4E
-02
9.32
E-0
387
600.
324
2887
0.10
700
2U
nit 2
Nat
. Gas
Acr
olei
n18
506.
40E
-06
21.
2E-0
21.
49E
-03
8760
0.05
228
870.
017
002
Uni
t 2N
at. G
asB
enze
ne18
501.
20E
-05
22.
2E-0
22.
80E
-03
8760
0.09
728
870.
032
002
Uni
t 2N
at. G
asE
thyl
ben
zene
1850
3.20
E-0
52
5.9E
-02
7.46
E-0
387
600.
259
2887
0.08
500
2U
nit 2
Nat
. Gas
Form
alde
hyde
1850
7.10
E-0
42
1.3E
+00
1.65
E-0
187
605.
753
2887
1.90
002
Uni
t 2N
at. G
asN
apht
hale
ne18
501.
30E
-06
22.
4E-0
33.
03E
-04
8760
0.01
128
870.
0034
700
2U
nit 2
Nat
. Gas
PAH
1850
2.20
E-0
62
4.1E
-03
5.13
E-0
487
600.
018
2887
0.00
588
002
Uni
t 2N
at. G
asPr
opyl
ene
oxid
e18
502.
90E
-05
25.
4E-0
26.
76E
-03
8760
0.23
528
870.
077
002
Uni
t 2N
at. G
asT
olue
ne18
501.
30E
-04
22.
4E-0
13.
03E
-02
8760
1.05
328
870.
347
002
Uni
t 2N
at. G
asX
ylen
es18
506.
40E
-05
21.
2E-0
11.
49E
-02
8760
0.51
928
870.
171
Tota
l HAP
1.90
E+
002.
39E
-01
8.32
42.
74E
+00
NN
G D
ata:
Wor
st C
ase
Em
issi
ons w
hen
NO
X is
lim
ited
to 2
44 tp
ySu
lfur
con
tent
= <
0.03
2gr
ains
/100
cf
VO
C E
mis
sion
s 13
.6H
eat C
onte
nt (
gros
s) =
99
9.5
Btu
/cf
PM E
mis
sion
s20
.9s%
=0.
032
grai
ns S
1 lb
scf
Nat
. Gas
1000
000
Btu
2 lb
SO
2PM
10 E
mis
sion
s 20
.9
100
scf
Nat
. Gas
7000
gra
ins
999.
5 B
tuM
MB
tulb
S5.
1
=9.
15E
-05
lb S
O2
CO
Em
issi
ons
[6]
122.
0M
MB
tuSO
2 E
mis
sion
s 14
.0R
EFE
RE
NC
ES:
312,
469
1. I
nfor
mat
ion
for
new
uni
t 2 (
EU
002)
pro
vide
d by
Sie
men
s W
esti
ngho
use
for
Est
imat
ed V
84.3
A(2
) G
as T
urbi
ne P
erfo
rman
ceH
2SO
4 M
ist E
mis
sion
s 0.
32.
Em
issi
on f
acto
r fr
om A
P-4
2 Se
ctio
n 3.
1 .
All
sulf
ur in
the
fuel
is a
ssum
ed to
be
conv
erte
d to
SO
2 (s
ee c
alcu
lati
on b
elow
)L
imit
ed N
OX E
mis
sion
s24
4.0
3. E
PA
. T
echn
olog
y T
rans
fer
Net
wor
k A
ir T
oxic
s W
ebsi
te, S
tati
onar
y C
ombu
stio
n T
urbi
nes
NE
SHA
P, C
ombu
stio
n T
urbi
ne E
mis
sion
s
Tot
al H
AP
Em
issi
ons
2.7
Dat
abas
e v.
5, 1
0/15
/02.
htt
p://
ww
w.e
pa.g
ov/t
tn/a
tw/t
urbi
ne/t
urbi
nepg
.htm
l#T
EC
H
Sing
le H
AP
Em
issi
ons
(For
mal
dehy
de)
1.90
4. E
mis
sion
fac
tor
from
AP
-42
Sect
ion
1.4
for
Nat
. Gas
fir
ed e
xter
nal c
ombu
stio
n (a
uxili
ary
boile
r w
/low
NO
x bu
rner
s).
Sulf
ur e
mis
sion
fac
tor
is 0
.67
lb S
O2/
MM
scf
* sc
f/1,
020
Btu
per
sup
plie
r (N
orth
ern
Nat
. Gas
).
5. A
ssum
es a
1-2
% c
onve
rsio
n of
SO
2 to
SO
3 an
d, c
onse
rvat
ivel
y, 1
00%
con
vers
ion
of S
O3
to H
2SO
4.
(ref
: R
eisi
ng, B
.; Si
emen
s-W
esti
ngho
use;
Rev
iew
of
Air
Tox
ics
from
Com
bust
ion
Sour
ces;
Pow
er G
en 2
003
- L
as V
egas
; Dec
embe
r 20
03)
6. A
ssum
e C
O is
50%
of
tota
l NO
X, t
o ac
coun
t for
incr
ease
d C
O d
urin
g st
artu
p. (
See
Gre
at R
iver
Ene
rgy
- P
leas
ant V
alle
y pe
rmit
.)
7. C
O2e
incl
udes
CO
2 em
issi
ons
as w
ell a
s C
O2e
em
issi
ons
of C
H4
and
N2O
cal
cula
ted
usin
g G
WP
. Em
issi
on F
acto
rs f
or C
O2,
CH
4an
d N
2O ta
ken
from
EP
A 4
0 C
FR 9
8 T
able
s C
-1 a
nd C
-2
8. F
rom
EP
A W
ebFi
re f
or P
M 2
.5-P
RI
for
"con
trol
led"
sou
rces
sin
ce E
PA
Web
Fire
doe
s no
t pro
vide
"un
cont
rolle
d" P
M 2
.5 e
mis
sion
fac
tor
PM2.
5 E
mis
sion
s
CO
2 E
mis
sion
s
P:\2
3\19
\845
\Air\
Emiss
ions
\Cal
cs\W
orks
heet
inol
e_m
ain
Page
2of
12Pr
inte
d4/
21/2
015
Gre
at R
iver
Ene
rgy
- Cam
brid
geE
miss
ion
Cal
cula
tions
Max
imum
Em
issi
onE
mis
sion
Ope
ratin
gPo
tent
ial t
oO
pera
ting
Pote
ntia
l to
Uni
tH
eat I
nput
Rat
eR
ate
Hou
rsE
mit
(PT
E)
Hou
rsE
mit
(PT
E)
IDU
nit N
ame
Fuel
Pollu
tant
(MM
Btu
/hr)
(lb/h
r)(g
/s)
(hr/
yr)
(ton/
yr)
(hr/
yr)
(ton/
yr)
Em
issi
on F
acto
r(lb
/uni
ts)
(R
ef.)
Unl
imite
d L
imite
d O
pera
tion
Ope
ratio
n(2
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y N
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ontr
olle
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imite
d
P:\2
3\19
\845
\Air\
Emiss
ions
\Cal
cs\W
orks
heet
inol
e_m
ain
Page
3of
12Pr
inte
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21/2
015
Great River Energy - Cambridge Emission Calculations
Great River EnergyFacility CambridgePermit# 5900014Unit# EU003 (Diesel Driven Fire Pump Package FM-DFPS-3650)Fire Pump Eng. JU6H-UFG8 (Clarke)Model 6068TF220 (John Deere)Rated Input 9.50 gal/hr #2 Fuel OilRated Input 1.3205 MMbtu/hr (@0.139 MMbtu/gal)Rated Output 149 bhp
EmissionFactor (1)
EmissionRate
Potential to Emit (2)
RestrictedEmissions (3)
(lb/hr) (tpy) (tpy)
PM (a) 0.19 0.217 0.952 0.016PM10 (a) 0.19 0.217 0.952 0.016PM2.5 (c) 0.19 0.217 0.952 0.016SOx (b) 0.29 0.383 1.677 0.029CO2e (d) 215 943 16.15NOx (a) 4.99 5.708 25.001 0.428VOC (b) 0.36 0.475 2.082 0.036CO (a) 0.33 0.377 1.653 0.028Lead (b) 0.00 0.00 0.00 0.000NMHC (a) 0.21 0.240 1.052 0.018
EmissionFactor
(lb/MMBtu) Emission Rate Potential to EmitRestrictedEmissions
CO2 163.05 215.308 943.047 16.148CH4 0.01 0.009 0.038 0.000NO2 0.00 0.002 0.008 0.000
EmissionFactor (4)
EmissionRate
Potential to Emit (2)
RestrictedEmissions (3)
(lb/MMBtu) (lb/hr) (tpy) (tpy)
1,3-Butadiene 3.91E-05 5.16E-05 2.26E-04 3.87E-06Acetaldehyde 7.67E-04 1.01E-03 4.44E-03 7.60E-05Acrolein (c) 9.25E-05 1.22E-04 5.35E-04 9.16E-06Benzene 9.33E-04 1.23E-03 5.40E-03 9.24E-05Formaldehyde 1.18E-03 1.56E-03 6.82E-03 1.17E-04Naphthalene 8.48E-05 1.12E-04 4.90E-04 8.40E-06Total PAH 1.68E-04 2.22E-04 9.72E-04 1.66E-05Toluene 4.09E-04 5.40E-04 2.37E-03 4.05E-05Xylenes 2.85E-04 3.76E-04 1.65E-03 2.82E-05Mercury(5) 3.01E-07 3.98E-07 1.74E-06 2.98E-08
1) a - Emission factors supplied by manufacturer (grams/hp-hr).(1 hp-hr = 2,545 Btu, #2 Oil = 139,000 Btu/gal, 453.59 gram = 1 lb)
b - Emission factors from MPCA Table EC-03.1 Reciprocating Engine <600 hp Diesel/
USEPA AP-42 Table 3.3-1: Emission Factors for Uncontrolled Gasoline and Diesel Industrual Engines (lb/MMBtu). http://www.epa.gov/ttn/chief/ap42/ch03/final/c03s03.pdf
c - Manufacturer does not supply an emission factor for PM2.5. It can be reasonably assumed that the emission
factor will be the same as PM10
d - CO2e includes CO2 emissions as well as CO2e emissions of CH4 and N2O calculated using GWP. Emission Factors for CO2, CH4 and N2O (lb/mmBtu) taken from EPA 40 CFR 98 Tables C-1 and C-2 as no other GHG emission factors are provided for
P:\23\19\845\Air\Emissions\Calcs\Worksheet in ole_main Page 4 of 12 Printed 4/21/2015
Great River Energy - Cambridge Emission Calculations
this type of engine.
2) Potential to emit is calculated at 8760 hr/yr since the EPA emergency generator memo does not apply to fire pumps.
3) This emission source has restricted emissions to 150 hours per year.
4) USEPA AP-42 Table 3.3-2: Speciated Organic Compound Emission Factors for Uncontrolled Diesel Engines.
c - less than 9.25E-05 lb/MMBtu http://www.epa.gov/ttn/chief/ap42/ch03/final/c03s03.pdf
5) Hg emission factor from WebFire for SIC 20200102
P:\23\19\845\Air\Emissions\Calcs\Worksheet in ole_main Page 5 of 12 Printed 4/21/2015
Great River Energy - Cambridge Emission Calculations
Great River EnergyFacility Cambridge
Permit# 5900014
Unit# EU004 -Diesel Starting Engine
Diesel Start Eng. Massaro Detroit Diesel Alison
Model 7123-7000 V12 #2 Fuel Oil
Rated Output 500.00 hp Rated Input (5) 3.5 mmBtu/hr
EmissionFactor (1)
EmissionRate
Potential to Emit (2)
RestrictedEmissions (3)
lb/hp-hr lb/hr tpy tpy
PM 2.20E-03 1.100 4.818 0.039
PM10 2.20E-03 1.100 4.818 0.039
PM2.5 (a) 2.20E-03 1.100 4.818 0.039
SOx 2.05E-03 1.025 4.490 0.036
NOx 3.10E-02 15.50 67.89 0.543
CO2e (b) 571 2499.68 19.97
VOC 2.51E-03 1.257 5.506 0.044
CO 6.68E-03 3.340 14.63 0.117
Lead 0.00 0.00 0.00 0.000Emission
Factor(lb/MMBtu) Emission Rate Potential to Emit
RestrictedEmissions
CO2 163.05 570.675 2499.557 19.974CH4 0.01 0.023 0.101 0.001NO2 0.00 0.005 0.020 0.000
EmissionFactor (4)
EmissionFactor
EmissionRate
Potential to Emit (2)
RestrictedEmissions (3)
lb/MMBtu lb/hp-hr lb/hr tpy tpy
Benzene 9.33E-04 6.53E-06 3.27E-03 1.43E-02 1.14E-04 Toluene 4.09E-04 2.86E-06 1.43E-03 6.27E-03 5.01E-05 Xylenes 2.85E-04 2.00E-06 9.98E-04 4.37E-03 3.49E-05 1,3-Butadiene 3.91E-05 2.74E-07 1.37E-04 5.99E-04 4.79E-06 Formaldehyde 1.18E-03 8.26E-06 4.13E-03 1.81E-02 1.45E-04 Acetaldehyde 7.67E-04 5.37E-06 2.68E-03 1.18E-02 9.40E-05 Acrolein (a) 9.25E-05 6.48E-07 3.24E-04 1.42E-03 1.13E-05 Naphthalene 8.48E-05 5.94E-07 2.97E-04 1.30E-03 1.04E-05 Mercury (6) 3.01E-07 2.11E-09 1.05E-06 4.62E-06 3.69E-08Total PAH 1.68E-04 1.18E-06 5.88E-04 2.58E-03 2.06E-05
1) Emission factors are from MPCA Table EC-03.1 Reciprocating Engine <600 hp Diesel USEPA AP-42 Table 3.3-1: Emission Factors for Uncontrolled Gasoline and Diesel Industrual Engines (lb/MMBtu). http://www.epa.gov/ttn/chief/ap42/ch03/final/c03s03.pdf
a - No emission factor for PM2.5 is provided in AP-42 or EPA WebFire for Uncontrolled Gasoline and Diesel Engines It can be reasonably assumed that the emission factor will be the same as PM10 b - CO2e includes CO2 emissions as well as CO2e emissions of CH4 and N2O calculated using GWP. Emission Factors for CO2, CH4 and N2O taken from EPA 40 CFR 98 Tables C-1 and C-2 as no other GHG emission factors are provided for this type of engine. An average brake-specific fuel consumption (BSFC) of
P:\23\19\845\Air\Emissions\Calcs\Worksheet in ole_main Page 6 of 12 Printed 4/21/2015
Great River Energy - Cambridge Emission Calculations
7,000 Btu/hp-hr was used to convert from lb/MMBtu to lb/hp-hr.2) Potential to emit is calculated at 8760 since the EPA emergency generator memo does not apply to starting engines3) This emission source has restricted emissions to 70 hours per year.4) USEPA AP-42 Table 3.3-2: Speciated Organic Compound Emission Factors for Uncontrolled Diesel Engines. http://www.epa.gov/ttn/chief/ap42/ch03/final/c03s03.pdf
An average brake-specific fuel consumption (BSFC) of 7,000 Btu/hp-hr was used to convert from lb/MMBtu to lb/hp-hr. a - less than 9.25E-05 lb/MMBtu5) An average brake-specific fuel consumption (BSFC) of 7,000 Btu/hp-hr was used to convert hp to mmBtu/hr6) Hg emission factor from WebFire for SIC 20200102
P:\23\19\845\Air\Emissions\Calcs\Worksheet in ole_main Page 7 of 12 Printed 4/21/2015
Gre
at R
iver
En
erg
yF
acili
tyC
ambr
idge
Per
mit
#05
9000
14-0
03
Gen
erat
or
Tel
ecom
Gen
erac
Mo
del
SG
020
kW20
Rat
ed In
pu
t1.
65ga
l/hr
Pro
pane
144
cf/h
rP
ropa
ne
0.09
1m
mbt
u/ga
lP
ropa
ne -
40C
FR
98 C
-1
Em
issi
on
Fac
tor
(1)
Em
issi
on
Rat
eP
ote
nti
alto
Em
it (
2)
lb/g
al
lb/h
rtp
y
PM
0.00
50.
008
0.00
2
PM
100.
005
0.00
80.
002
PM
2.5
(5)
0.00
50.
008
0.00
2
SO
x0.
0003
50.
001
0.00
0
NO
x0.
139
0.23
00.
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VO
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083
0.13
70.
034
CO
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90.
213
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3
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00
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6)20
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5.10
(1)
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ctor
s ar
e fr
om M
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A T
able
EC
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1 R
ecip
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ting
Eng
ine
Pro
pane
(2)
Pot
entia
l to
emit
is c
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late
d ba
sed
on E
PA
em
erge
ncy
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emo
at 5
00 h
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) T
his
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sion
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rce
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n in
sign
ifica
nt a
ctiv
ity u
nder
MN
Rul
es 7
007.
1300
Sub
o (I
) si
nce
pote
ntia
l
emis
sion
s ar
e le
ss th
an 1
tpy
for
the
liste
d po
lluta
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(4)
Acc
ordi
ng to
MN
Rul
es 7
007.
1250
Sub
p. 1
(B),
lb/h
r em
issi
ons
are
less
than
app
licab
le th
resh
olds
,
whi
ch w
ould
trig
ger
a pe
rmit
amen
dmen
t. U
pdat
e pe
rmit
whe
n re
new
ed.
(5)
PM
2.5
cons
erva
tivel
y as
sum
ed to
be
equa
l to
PM
10
(6)
CO
2e v
alue
from
EP
A 4
0 C
FR
Par
t 98
Tab
les
C1
and
C2,
con
vert
ed to
GW
P.
kg/h
rto
nn
es/h
rto
nn
es/y
rto
nn
es C
O2e
/yr
ton
s C
O2e
/yr
lb/h
rN
ote
CH
40.
0001
5037
41.
5037
4E-0
77.
519E
-05
0.00
1879
672
0.00
2071
963
0.00
8288
Tab
le C
2 -
nat g
as
N2O
1.50
374E
-05
1.50
374E
-08
7.51
9E-0
60.
0022
4056
90.
0024
6977
90.
0098
79T
able
C2
- na
t gas
CO
29.
2419
7193
40.
0092
4197
24.
6209
864.
6209
8596
75.
0937
1283
220
.374
85T
able
C1
- P
ropa
ne5.
0982
5457
420
.393
02
Great River EnergyCambridge Turbines (EU001 and EU002)Permit #05900014
GP001 at 244 tpy
EU001/EU002 EU003 EU004
TPY TPY TPY
1,3 -butadiene 4.44E-03 3.91E-06 4.79E-06
Acetaldehyde 1.07E-01 7.68E-05 9.40E-05
Acrolein 1.71E-02 9.26E-06 8.09E-05
Arsenic 3.05E-03
Benzene 3.20E-02 9.34E-05 1.14E-04
Beryllium 8.59E-05
Cadmium 1.33E-03
Chromium 3.05E-03
Ethyl benzene 8.55E-02
Formaldehyde 1.90E+00 1.18E-04 1.45E-04H2SO4 Mist 2.80E-01
Lead 3.88E-03
Manganese 2.19E-01
Mercury 3.33E-04 3.02E-08 2.64E-07
Naphthalene 9.70E-03 8.49E-06 7.42E-05
Nickel 1.28E-03
Propylene oxide 7.74E-02
Selenium 6.93E-03
Toluene 3.47E-01 4.09E-05 5.01E-05
Xylenes 1.71E-01 2.85E-05 3.49E-05
Total PAHs 5.88E-03 5.55E-05 2.06E-05
Total 2.74E+00 3.79E-04 5.98E-04 2.74E+00
Facility Limited at 245 tpy NOX
limited to 1 tpy combined
Worksheet in ole_main 4/21/2015
EU 001 and EU 002
Worst Case Emissions when NOX is limited to 244 tpy tpyPM Emissions 20.931
PM10 Emissions 20.931
PM2.5 Emissions 5.074
SO2 Emissions 13.998
CO2 Emissions 312,469
VOC Emissions 13.569
CO Emissions [6] 122.000
H2SO4 Mist Emissions 0.280
Limited NOX Emissions 244.000
Total HAP Emissions 2.743
Single HAP Emissions (Formaldehyde) 1.896
EU 003
PM (a) 0.016
PM10 (a) 0.016
PM2.5 (a) 0.016
SOx (b) 0.029
NOx (a) 0.428
CO2 (b) 16
VOC (b) 0.036
CO (a) 0.028
Lead (b) 0.000
NMHC (a) 0.018
Formaldehyde 0.000
EU 004PM 0.039PM10 0.039PM2.5 0.039SOx 0.036NOx 0.543CO2 19.975VOC 0.044CO 0.117Formaldehyde 0.000
TotalsPM 21.0PM10 21.0PM2.5 5.1SO2 14.1NOX 225.0CO2 312,505NO2 4.01CH4 19.59
CO2e 312528.54VOCs 13.6CO 122.1Formaldehyde 1.9Total HAPs 2.7
Attachment 2- Facility Description and CD-01 Forms
MIN
NE
SOTA
PO
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UT
ION
CO
NT
RO
L A
GE
NC
YA
IR Q
UA
LIT
Y52
0 L
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T. P
AU
L, M
N 5
5155
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4
Sho
w:
Act
ion:
AQ
D F
acili
ty ID
:
Fac
ility
Nam
e:
All
Rec
ords
0590
0014
Gre
at R
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Ene
rgy
- C
ambr
idge
FAC
ILIT
Y D
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RIP
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N: G
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UPS
(GP)
21 A
pril,
201
5 0
9:48
ID N
o.A
dded
By
(Act
ion)
Ret
ired
By
(Act
ion)
Incl
ude
in E
IO
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tor
IDfo
r It
em
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up D
escr
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nG
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upS
tatu
s
1G
P 0
01P
ER
002
001
NO
X L
imit
EU
001
, EU
002
Act
ive
2G
P 0
02P
ER
002
Con
tinuo
us E
mis
sion
Mon
itors
- E
U00
2M
R 0
01, M
R 0
02A
ctiv
e
3G
P 0
03P
ER
002
Con
tinuo
us E
mis
sion
Mon
itors
- E
U00
1M
R 0
03, M
R 0
04A
ctiv
e
4G
P 0
03P
ER
004
Con
tinuo
us E
mis
sion
Mon
itors
- E
U00
1M
R 0
03, M
R 0
04R
emov
ed
Pag
e 1
of
1
MIN
NE
SOTA
PO
LL
UT
ION
CO
NT
RO
L A
GE
NC
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IR Q
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LIT
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TT
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AU
L, M
N 5
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-419
4
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w:
All
Rec
ords
Act
ion:
AQ
D F
acili
ty ID
:05
9000
14
Fac
ility
Nam
e:G
reat
Riv
er E
nerg
y -
Cam
brid
ge
21 A
pril,
201
5 0
9:49
FAC
ILIT
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RIP
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N: S
TAC
K/V
EN
TS
(SV
)
ID N
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isch
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Dire
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low
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reIn
form
atio
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ign
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ate
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Wid
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ning
Fro
mG
roun
d(f
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Add
edB
y(A
ctio
n)
Ret
ired
By
(Act
ion)
Ope
rato
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for
Item
Ope
rato
rs D
escr
iptio
nS
tack
/V
ent
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tus
1S
V 0
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p, N
o C
apM
anuf
actu
rer
842
5626
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.512
.75
35.0
PE
R 0
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ER
002
Act
ive
2S
V 0
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p, N
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apM
anuf
actu
rer
842
5626
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12.8
035
PE
R 0
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ombu
stio
n T
urbi
neA
ctiv
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3S
V 0
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p, N
o C
apM
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000
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bine
002
Exh
aust
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551
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194
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w:
All
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21 A
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FAC
ILIT
Y D
ESC
RIP
TIO
N: E
MIS
SIO
N U
NIT
(EU
)
Max
Fue
lIn
put
(mil
Btu
)
Gre
at R
iver
Ene
rgy
- C
ambr
idge
Ret
ired
By
(Act
ion)
Ope
rato
r D
escr
iptio
nID
No.
Em
issi
onU
nit
Sta
tus
Add
edB
y(A
ctio
n)
Con
trol
Equ
ip.
ID N
o(s)
.
Sta
ck/
Ven
tID
No(
s).
Ope
rato
rID
for
Item
Insi
gnif-
ican
tA
ctiv
ity
SIC
Man
ufac
ture
rM
odel
Num
ber
Max
.D
esig
nC
apac
ity
Max
imum
Des
ign
Cap
acity
Mat
eria
lsU
nits
nU
nits
d
1P
ER
001
Com
bust
ion
Tur
bine
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001
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ive
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4911
363.
32
Com
bust
ion
Tur
bine
EU
001
Act
ive
PE
R 0
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V 0
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lect
Ene
rgy
4911
GE
PG
5341
29.3
Mw
363.
33
Com
bust
ion
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bine
001
EU
001
Act
ive
PE
R 0
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V 0
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lect
Ene
rgy
4911
GE
PG
5341
29.3
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1
21 April, 2015 11:19
Show: Active and Pending Records
FACILITY DESCRIPTION: Potential-to-emit (by pollutant)
RetiredBy
(Action)
AddedBy
(Action)
ItemPollutant ActualEmissions
(tons per yr)
LimitedPotential
(tons per yr)
UnrestrictedPotential
(tons per yr)
HourlyPotential
(lbs per hr)
AQD Facility ID: 05900014
Facility Name: Great River Energy - Cambridge
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194
Acetaldehyde
PER 003EU 001 1.500E-02 6.400E-02 0.000E+00
PER 003EU 002 7.400E-02 3.240E-01 0.000E+00
PER 003EU 003 1.042E-03 4.564E-03 0.000E+00
PER 003EU 004 2.685E-03 1.176E-02 0.000E+00
PER 003GP 001 7.400E-02 3.241E-01 1.068E-01
PER 004GP 001 7.400E-02 3.241E-01 1.070E-01
Totals 7.284E-01 1.070E-01 0.000E+00
Acrolein
PER 003EU 001 2.300E-03 1.000E-02 0.000E+00
PER 003EU 002 1.200E-02 5.200E-02 0.000E+00
PER 003EU 003 1.257E-04 5.504E-04 0.000E+00
PER 003EU 004 3.238E-04 1.418E-03 0.000E+00
PER 003GP 001 1.184E-02 5.186E-02 1.709E-02
PER 004GP 001 1.184E-02 5.186E-02 1.700E-02
Totals 1.158E-01 1.700E-02 0.000E+00
Benzene
PER 003EU 001 2.000E-02 8.800E-02 0.000E+00
PER 003EU 002 2.200E-02 9.700E-02 0.000E+00
PER 003EU 003 1.267E-03 5.552E-03 0.000E+00
PER 003EU 004 3.266E-03 1.430E-02 0.000E+00
PER 003GP 001 2.220E-02 9.724E-02 3.205E-02
PER 004GP 001 2.220E-02 9.724E-02 3.200E-02
Totals 3.021E-01 3.200E-02 0.000E+00
Arsenic compounds
PER 003EU 001 4.000E-03 1.800E-02 0.000E+00
PER 003GP 001 3.996E-03 1.750E-02 3.049E-03
Totals 3.550E-02 3.049E-03 0.000E+00
1,3-Butadiene
PER 003EU 001 5.800E-03 2.500E-02 0.000E+00
PER 003EU 002 8.000E-04 3.000E-03 0.000E+00
PER 003EU 003 5.312E-05 2.327E-04 0.000E+00 0.000E+00
PER 003EU 004 1.369E-04 5.994E-04 0.000E+00
PER 003GP 001 5.813E-03 2.546E-02 4.435E-03
Totals 5.429E-02 4.435E-03 0.000E+00
Beryllium
PER 003EU 001 1.100E-04 1.000E-04 0.000E+00
Page 1 of 6
21 April, 2015 11:19
Show: Active and Pending Records
FACILITY DESCRIPTION: Potential-to-emit (by pollutant)
RetiredBy
(Action)
AddedBy
(Action)
ItemPollutant ActualEmissions
(tons per yr)
LimitedPotential
(tons per yr)
UnrestrictedPotential
(tons per yr)
HourlyPotential
(lbs per hr)
AQD Facility ID: 05900014
Facility Name: Great River Energy - Cambridge
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194
Beryllium
PER 003GP 001 1.126E-04 4.933E-04 8.593E-05
Totals 5.933E-04 8.593E-05 0.000E+00
Carbon Dioxide Equivalent
PER 004EU 001 4.251E+04 1.862E+05 1.563E+05
PER 004EU 002 9.471E+05 4.148E+06 1.563E+05
PER 004EU 003 2.150E+02 9.430E+02 1.615E+01
PER 004EU 004 5.710E+02 2.500E+03 1.997E+01
PER 004EU 005 2.039E+01 8.930E+01 5.100E+00
Totals 4.338E+06 3.126E+05 0.000E+00
Cadmium compounds
PER 003EU 001 1.700E-03 8.000E-03 0.000E+00
PER 003GP 001 1.744E-03 7.638E-03 1.331E-03
Totals 1.564E-02 1.331E-03 0.000E+00
Methane
PER 004EU 001 7.260E-01 3.200E+00 3.200E+00
PER 004EU 002 3.700E+00 1.620E+01 1.620E+01
PER 004EU 003 9.000E-03 3.800E-02 0.000E+00
PER 004EU 004 2.000E-03 8.000E-03 0.000E+00
Totals 1.945E+01 1.940E+01 0.000E+00
Carbon Monoxide
PER 003EU 001 2.980E+01 1.305E+02 0.000E+00 4.000E-03
PER 004EU 001 2.980E+01 1.305E+02 0.000E+00
PER 003EU 002 3.700E+01 1.621E+02 0.000E+00
PER 003EU 003 3.883E-01 1.701E+00 2.800E-02
PER 003EU 004 3.340E+00 1.463E+01 1.170E-01
PER 003GP 001 3.700E+01 1.621E+02 1.220E+02
Totals 4.710E+02 1.221E+02 0.000E+00
Carbon Dioxide
PER 004EU 001 3.567E+04 1.563E+05 1.563E+05
PER 004EU 002 3.567E+04 1.563E+05 1.563E+05
PER 004EU 003 5.707E+02 2.500E+03 1.997E+01
PER 004EU 004 2.153E+02 9.430E+02 1.615E+01
Totals 3.159E+05 3.125E+05 0.000E+00
Chromium compounds
PER 003EU 001 4.000E-03 1.800E-02 0.000E+00
Page 2 of 6
21 April, 2015 11:19
Show: Active and Pending Records
FACILITY DESCRIPTION: Potential-to-emit (by pollutant)
RetiredBy
(Action)
AddedBy
(Action)
ItemPollutant ActualEmissions
(tons per yr)
LimitedPotential
(tons per yr)
UnrestrictedPotential
(tons per yr)
HourlyPotential
(lbs per hr)
AQD Facility ID: 05900014
Facility Name: Great River Energy - Cambridge
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194
Chromium compounds
PER 003GP 001 3.996E-03 1.750E-02 3.049E-03
Totals 3.550E-02 3.049E-03 0.000E+00
Ethylbenzene
PER 003EU 001 1.200E-02 5.100E-02 0.000E+00
PER 003EU 002 5.900E-02 2.590E-01 0.000E+00
PER 003GP 001 5.920E-02 2.593E-01 8.546E-02
Totals 5.693E-01 8.546E-02 0.000E+00
Formaldehyde
PER 003EU 001 2.600E-01 1.130E+00 0.000E+00
PER 003EU 002 1.300E+00 5.753E+00 0.000E+00
PER 003EU 003 1.603E-03 7.021E-03 0.000E+00
PER 003EU 004 4.130E-03 1.809E-02 0.000E+00
PER 003GP 001 1.314E+00 5.753E+00 1.896E+00
Totals 1.266E+01 1.896E+00 0.000E+00
Naphthalene
PER 003EU 001 1.300E-02 5.600E-02 0.000E+00
PER 003EU 002 2.400E-03 1.100E-02 0.000E+00
PER 003EU 003 1.152E-04 5.046E-04 0.000E+00
PER 003EU 004 2.968E-04 1.300E-03 0.000E+00
PER 003GP 001 1.272E-02 5.569E-02 9.702E-03
Totals 1.245E-01 9.702E-03 0.000E+00
HAPs - Total
PER 003EU 001 4.700E-01 2.050E+00 0.000E+00
PER 003EU 002 2.033E+00 8.320E+00 0.000E+00
PER 003GP 001 1.901E+00 8.324E+00 2.743E+00
Totals 1.869E+01 2.743E+00 0.000E+00
Mercury
PER 003EU 001 4.400E-04 2.000E-03 0.000E+00
PER 003EU 003 4.095E-07 1.793E-06 0.000E+00
PER 003EU 004 1.055E-06 4.621E-06 0.000E+00
PER 003GP 001 4.360E-04 1.910E-03 3.326E-04
Totals 3.916E-03 3.326E-04 0.000E+00
Propylene oxide
PER 003EU 001 1.100E-02 4.600E-02 0.000E+00
PER 003EU 002 5.400E-02 2.350E-01 0.000E+00
Page 3 of 6
21 April, 2015 11:19
Show: Active and Pending Records
FACILITY DESCRIPTION: Potential-to-emit (by pollutant)
RetiredBy
(Action)
AddedBy
(Action)
ItemPollutant ActualEmissions
(tons per yr)
LimitedPotential
(tons per yr)
UnrestrictedPotential
(tons per yr)
HourlyPotential
(lbs per hr)
AQD Facility ID: 05900014
Facility Name: Great River Energy - Cambridge
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194
Propylene oxide
PER 003GP 001 5.365E-02 2.350E-01 7.744E-02
Totals 5.160E-01 7.744E-02 0.000E+00
Toluene
PER 003EU 001 4.700E-02 2.070E-01 0.000E+00
PER 003EU 002 2.400E-01 1.053E+00 0.000E+00
PER 003EU 003 5.556E-04 2.434E-03 0.000E+00
PER 003EU 004 1.432E-03 6.270E-03 0.000E+00
PER 003GP 001 2.405E-01 1.053E+00 3.472E-01
Totals 2.322E+00 3.472E-01 0.000E+00
Xylenes (mixed isomers)
PER 003EU 001 2.300E-02 1.020E-01 0.000E+00
PER 003EU 002 1.200E-01 5.190E-01 0.000E+00
PER 003EU 003 3.872E-04 1.696E-03 0.000E+00
PER 003EU 004 9.975E-04 4.369E-03 0.000E+00
PER 003GP 001 1.184E-01 5.186E-01 1.709E-01
Totals 1.146E+00 1.709E-01 0.000E+00
Manganese compounds
PER 003EU 001 2.900E-01 1.257E+00 0.000E+00
PER 003GP 001 2.870E-01 1.257E+00 2.190E-01
Totals 2.514E+00 2.190E-01 0.000E+00
Nitrous Oxide
PER 004EU 001 3.630E-05 3.000E-01 3.000E-01
PER 004EU 002 1.850E-04 1.621E+00 1.621E+00
PER 004EU 003 7.900E-07 2.068E+00 2.068E+00
PER 004EU 004 2.100E-06 1.840E-02 1.840E-02
Totals 4.007E+00 4.007E+00 0.000E+00
Total Polycyclic aromatic hydr
PER 003EU 003 2.282E-04 9.996E-04 0.000E+00
PER 003EU 004 5.880E-04 2.575E-03 0.000E+00
Totals 3.575E-03 0.000E+00 0.000E+00
Nickel compounds
PER 003EU 001 1.700E-03 7.000E-03 0.000E+00
PER 003GP 001 1.671E-03 7.320E-03 1.275E-03
Totals 1.432E-02 1.275E-03 0.000E+00
Nitrogen Oxides
PER 003EU 001 3.200E+02 1.400E+03 0.000E+00 1.142E+00
Page 4 of 6
21 April, 2015 11:19
Show: Active and Pending Records
FACILITY DESCRIPTION: Potential-to-emit (by pollutant)
RetiredBy
(Action)
AddedBy
(Action)
ItemPollutant ActualEmissions
(tons per yr)
LimitedPotential
(tons per yr)
UnrestrictedPotential
(tons per yr)
HourlyPotential
(lbs per hr)
AQD Facility ID: 05900014
Facility Name: Great River Energy - Cambridge
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194
Nitrogen Oxides
PER 004EU 001 3.200E+02 1.400E+03 0.000E+00
PER 003EU 002 1.690E+02 7.402E+02 0.000E+00 0.000E+00
PER 004EU 002 1.690E+02 7.400E+02 0.000E+00 0.000E+00
PER 003EU 003 5.872E+00 2.572E+01 4.280E-01 0.000E+00
PER 004EU 003 5.710E+00 2.500E+01 0.000E+00 0.000E+00
PER 003EU 004 1.550E+01 6.789E+01 5.430E-01 0.000E+00
PER 004EU 004 1.550E+01 6.789E+01 0.000E+00 0.000E+00
PER 004EU 005 2.300E-01 1.071E+00 0.000E+00
PER 003GP 001 3.197E+02 1.400E+03 2.440E+02 0.000E+00
PER 004GP 001 2.450E+02 0.000E+00
Totals 2.234E+03 2.450E+02 0.000E+00
PM < 2.5 micron
PER 004EU 001 7.000E-01 3.000E+00 0.000E+00
PER 004EU 002 3.500E+00 1.540E+01 0.000E+00
PER 004EU 003 2.236E-02 9.793E-01 1.600E-03
PER 004EU 004 1.100E+00 4.818E+00 3.900E-03
PER 004GP 001 3.500E+00 1.540E+01 5.100E+00
Totals 3.960E+01 5.106E+00 0.000E+00
Lead
PER 003EU 001 5.100E-03 2.200E-02 0.000E+00 0.000E+00
PER 003GP 001 5.086E-03 2.228E-02 3.881E-03
Totals 4.428E-02 3.881E-03 0.000E+00
PM < 10 micron
PER 003EU 001 2.400E+00 1.050E+01 0.000E+00 3.100E-02
PER 004EU 001 2.400E+00 1.050E+01 0.000E+00
PER 003EU 002 2.400E+00 6.350E+01 0.000E+00 0.000E+00
PER 004EU 002 1.450E+01 6.350E+01 0.000E+00 0.000E+00
PER 003EU 003 2.236E-01 9.793E-01 1.600E-02 0.000E+00
PER 003EU 004 1.100E+00 4.818E+00 3.900E-02 0.000E+00
PER 003GP 001 1.450E+01 6.351E+01 2.093E+01 0.000E+00
PER 004GP 001 1.450E+01 6.350E+00 2.090E+01 0.000E+00
Totals 8.615E+01 2.096E+01 0.000E+00
Total Particulate Matter
PER 003EU 001 4.400E+00 1.910E+01 0.000E+00 3.100E-02
PER 004EU 001 4.400E+00 1.910E+01 0.000E+00
PER 003EU 002 1.450E+01 6.350E+01 0.000E+00
Page 5 of 6
21 April, 2015 11:19
Show: Active and Pending Records
FACILITY DESCRIPTION: Potential-to-emit (by pollutant)
RetiredBy
(Action)
AddedBy
(Action)
ItemPollutant ActualEmissions
(tons per yr)
LimitedPotential
(tons per yr)
UnrestrictedPotential
(tons per yr)
HourlyPotential
(lbs per hr)
AQD Facility ID: 05900014
Facility Name: Great River Energy - Cambridge
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194
Total Particulate Matter
PER 003EU 003 2.236E-01 9.793E-01 1.600E-02
PER 003EU 004 1.100E+00 4.818E+00 3.900E-02
PER 003GP 001 1.450E+01 6.351E+01 2.093E+01
Totals 1.519E+02 2.099E+01 0.000E+00
Sulfuric Acid Mist
PER 003EU 001 3.700E+00 1.607E+01 0.000E+00
PER 003EU 002 3.400E-03 1.500E-02 0.000E+00
PER 003GP 001 3.669E+00 1.607E+01 2.800E+00
PER 004GP 001 3.700E+00 1.607E+00 2.800E+00
Totals 1.769E+01 2.800E+00 0.000E+00
Selenium compounds
PER 003EU 001 9.100E-03 4.000E-02 0.000E+00
PER 003GP 001 9.083E-03 3.978E-02 6.930E-03
Totals 7.978E-02 6.930E-03 0.000E+00
Sulfur Dioxide
PER 003EU 001 1.800E+02 8.036E+02 0.000E+00 1.300E-01
PER 004EU 001 1.800E+02 8.036E+02 0.000E+00 0.000E+00
PER 003EU 002 2.000E-01 7.000E-01 0.000E+00 0.000E+00
PER 003EU 003 3.940E-01 1.726E+00 2.900E-02 0.000E+00
PER 003EU 004 1.025E+00 4.490E+00 3.600E-02 0.000E+00
PER 003GP 001 1.835E+02 8.036E+02 1.400E+02 0.000E+00
PER 004GP 001 1.835E+02 8.036E+02 1.400E+02 0.000E+00
Totals 1.614E+03 1.401E+02 0.000E+00
Volatile Organic Compounds
PER 003EU 001 8.000E-01 3.300E+00 0.000E+00 1.000E-03
PER 004EU 001 8.000E-01 3.300E+00 0.000E+00
PER 003EU 002 9.400E+00 4.120E+01 0.000E+00
PER 003EU 003 4.890E-01 2.142E+00 3.600E-02
PER 003EU 004 1.257E+00 5.506E+00 4.400E-02
PER 003GP 001 9.400E+00 4.117E+01 1.357E+01
Totals 9.332E+01 1.365E+01 0.000E+00
Page 6 of 6
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 1 of 15
Subject Item: Total Facility
NC/CA
Type Citation Requirement
CD Minn. R. 7007.0800, subp. 2 FACILITY SUBJECT TO TRANSPORT RULE(TR) /CROSS-STATE AIRPOLLUTION RULE (CSAPR)
1.0
CD 40 CFR pt. 97; 40 CFR 52.1240;40 CFR 52.38
The Permittee shall comply with all applicable requirements of 40 CFR pt. 97 forTransport Rule (TR) NOx Annual Units and a TR NOx Annual Source, described in40 CFR Section 97.404.
2.0
CD 40 CFR pt. 97; 40 CFR 52.1241;40 CFR 52.38
The Permittee shall comply with all applicable requirements of 40 CFR pt. 97 forTransport Rule (TR) SO2 Group 2 Units and a TR SO2 Group 2 Source, describedin 40 CFR Section 97.704.
3.0
CD 40 CFR pt. 97; Minn. R.7007.0800, subp. 2
The Permittee shall submit information to the MPCA that the MPCA deemsnecessary to evaluate the applicable requirements of 40 CFR pt. 97 within 60 daysof the date of a letter requesting such information.
4.0
CD Minn. R. 7007.0400, subp. 3 Upon adoption of a new or amended federal applicable requirement and if there aremore than 3 years remaining in the permit term, the Permittee shall file anapplication for an amendment within nine months of promulgation of the applicablerequirement.
5.0
CD hdr SOURCE-SPECIFIC REQUIREMENTS6.0
CD Minn. R. 7007.0800, subp. 2 Permit Appendices: This permit contains appendices as listed in the permit Table ofContents. The Permittee shall comply with all requirements contained in AppendixB: Phase II Acid Rain Permit Application Renewal, Appendix C: InsignificantActivities and Applicable Requirements, Appendices D and E: ApplicableRequirements for Emergency Engines under the area source for 40 CFR pt. 63,subp. ZZZZ.
7.0
CD 40 CFR 72.6 This source is subject to the U.S. EPA Acid Rain Program codified at 40 CFR pts.72, 73, 75, 77, and 78. Certain Acid Rain Program requirements are included inTables A and/or B of this permit, for MPCA tracking purposes. All other Acid RainProgram requirements are referenced in the Phase II Permit Application attached tothis permit as Appendix B.
8.0
CD Minn. R. 7007.0800, subp. 7 Acid Rain Do Not Exceed Allowances: Emissions from the facility cannot exceedany allowances that the source lawfully holds under federal acid rain regulations,except as allowed by Minn. R. 7007.0800, subp. 7.
9.0
CD 40 CFR 72.9(e); Minn. R.7007.1075
Acid Rain Excess Emissions Requirements; If the unit has excess emissions, thedesignated representative shall submit a proposed offset plan in accordance withthe following below:(1) The Permittee of an affected source that has excess emissions in any calendaryear shall submit a proposed offset plan, as required under 40 CFR pt. 77.(2) The Permittee of an affected source that has excess emissions in any calendaryear shall:(i) Pay without demand the penalty required, and pay upon demand the interest onthat penalty, as required by 40 CFR pt. 77; and(ii) Comply with the terms of an approved offset plan, as required by 40 CFR pt. 77.
10.0
CD 40 CFR 72.9(f); Minn. R.7007.1075
Acid Rain Recordkeeping Requirements: The Permittee shall keep the certificate ofrepresentation, all emissions monitoring information, copies of all reports,compliance certifications and related submissions and all records made or requiredunder the Acid Rain Program on site for a period of 5 years from the date thedocument was created.
11.0
CD 40 CFR 72.9(c); Minn. R.7007.1075
Hold allowances after January 1, 2001, as of the allowance transfer deadline, in theunit's compliance subaccount. Allowances may not be less than the total annualemissions of sulfur dioxide from the previous calendar year from the unit andComply with the applicable Acid Rain emissions limitation for sulfur dioxide.
12.0
CD 40 CFR 72.30(c) Acid Rain Program Application for Reissuance: The Permittee shall submit acomplete Acid Rain permit application for each source with an affected unit at least6 months prior to the expiration of an existing Acid Rain permit governing the unitduring Phase II in accordance with 40 CFR Section 72.21.
13.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 2 of 15
CD 40 CFR 52.21(b)(1)(i)(a) andMinn. R. 7007.3000
Conversion to Steam Generating Facility: If the owner or operator proposes tomodify this facility to also generate steam either for cogeneration or for combinedcycle electric generation, the facility becomes one of the 28 source categories listedin 40 CFR Section 52.21(b)(1)(i)(a) for which the major source threshold is 100 tonsper year. Such a modification constitutes construction of a new major source andmust comply with the requirements of 40 CFR Section 52.21 prior to commencingconstruction of the modification.
14.0
CD hdr OPERATIONAL REQUIREMENTS15.0
CD 40 CFR pt. 50; Minn. Stat. 116.07,subds. 4a & 9; Minn. R.7007.0100, subps. 7A, 7L & 7M;Minn. R. 7007.0800, subps. 1, 2 &4; Minn. Rs.7009.0100-7009.0080.
The Permittee shall comply with National Primary and Secondary Ambient AirQuality Standards, 40 CFR pt. 50, and the Minnesota Ambient Air QualityStandards, Minn. R. 7009.0010 to 7009.0080. Compliance shall be demonstratedupon written request by the MPCA.
16.0
CD Minn. R. 7011.0020 Circumvention: Do not install or use a device or means that conceals or dilutesemissions, which would otherwise violate a federal or state air pollution control rule,without reducing the total amount of pollutant emitted.
17.0
CD Minn. R. 7007.0800, subp. 2;Minn. R. 7007.0800, subp. 16(J)
Air Pollution Control Equipment: Operate all pollution control equipment wheneverthe corresponding process equipment and emission units are operated. At the timeof permit issuance of Permit No. 059000014-004, the facility does not have any airpollution control equipment.
18.0
CD Minn. R. 7007.0800, subps. 14and 16(J)
Operation and Maintenance Plan: Retain at the stationary source an operation andmaintenance plan for all air pollution control equipment. At a minimum, the O & Mplan shall identify all air pollution control equipment and control practices and shallinclude a preventative maintenance program for the equipment and practices, adescription of (the minimum but not necessarily the only) corrective actions to betaken to restore the equipment and practices to proper operation to meet applicablepermit conditions, a description of the employee training program for properoperation and maintenance of the control equipment and practices, and the recordskept to demonstrate plan implementation. At the time of permit issuance of PermitNo. 059000014-004, the facility does not have any air pollution control equipment.
19.0
CD Minn. R. 7019.1000, subp. 4 Operation Changes: In any shutdown, breakdown, or deviation the Permittee shallimmediately take all practical steps to modify operations to reduce the emission ofany regulated air pollutant. The Commissioner may require feasible and practicalmodifications in the operation to reduce emissions of air pollutants. No emissionsunits that have an unreasonable shutdown or breakdown frequency of process orcontrol equipment shall be permitted to operate.
20.0
CD Minn. R. 7011.0150 Fugitive Emissions: Do not cause or permit the handling, use, transporting, orstorage of any material in a manner which may allow avoidable amounts ofparticulate matter to become airborne. Comply with all other requirements listed inMinn. R. 7011.0150.
21.0
CD Minn. Rs. 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 orcitizens under the Clean Air Act.
22.0
CD Minn. R. 7007.0800, subp. 9(A) Inspections: The Permittee shall comply with the inspection procedures andrequirements as found in Minn. R. 7007.0800, subp. 9(A).
23.0
CD Minn. R. 7007.0800, subp. 16 The Permittee shall comply with the General Conditions listed in Minn. R.7007.0800, subp. 16.
24.0
CD hdr MONITORING25.0
CD Minn. R. 7007.0800, subp. 4(D) Monitoring Equipment Calibration - The Permittee shall either:
1. Calibrate or replace required monitoring equipment every 12 months; or2. Calibrate at the frequency stated in the manufacturer's specifications.
For each monitor, the Permittee shall maintain a record of all calibrations, includingthe date conducted, and any corrective action that resulted. The Permittee shallinclude the calibration frequencies, procedures, and manufacturer's specifications(if applicable) in the Operations and Maintenance Plan. Any requirements applyingto continuous emission monitors are listed separately in this permit.
26.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 3 of 15
CD Minn. R. 7007.0800, subp. 4(D) Operation of Monitoring Equipment: Unless otherwise noted in Tables A, and Bmonitoring a process or control equipment connected to that process is notnecessary during periods when the process is shutdown, or during checks of themonitoring systems, such as calibration checks and zero and span adjustments. Ifmonitoring records are required, they should reflect any such periods of processshutdown or checks of the monitoring system.
27.0
CD hdr PERFORMANCE TESTING28.0
CD Minn. R. ch. 7017 Performance Testing: Conduct all performance tests in accordance with Minn. R.ch. 7017 unless otherwise noted in Tables A, and B.
29.0
CD Minn. Rs. 7017.2030, subps. 1-4,7017.2018, 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 TableB for additional testing requirements.
Performance Test Notification (written): due 30 days before each Performance TestPerformance Test Plan: due 30 days before each Performance TestPerformance Test Pre-test Meeting: due 7 days before each Performance TestPerformance Test Report: due 45 days after each Performance TestPerformance Test Report - Microfiche Copy: due 105 days after each PerformanceTest
The Notification, Test Plan, and Test Report may be submitted in alternative formatas allowed by Minn. R. 7017.2018.
30.0
CD Minn. R. 7017.2025, subp. 3 Limits set as a result of a performance test (conducted before or after permitissuance) apply until superseded as stated in the MPCA's Notice of Complianceletter granting preliminary approval. Preliminary approval is based on formal reviewof a subsequent performance test on the same unit as specified by Minn. R.7017.2025, subp. 3. The limit is final upon issuance of a permit amendmentincorporating the change.
31.0
CD hdr RECORDKEEPING32.0
CD Minn. R. 7007.0800, subp. 5(C) Recordkeeping: Retain all records at the stationary source or at Great River Energyheadquarters, 12300 Elm Creek Blvd., Maple Grove, Minnesota, 55369, for aperiod of five (5) years from the date of monitoring, sample, measurement, orreport. Records which must be retained at this location include all calibration andmaintenance records, all original recordings for continuous monitoringinstrumentation, and copies of all reports required by the permit. Records mustconform to the requirements listed in Minn. R. 7007.0800, subp. 5(A).
33.0
CD Minn. R. 7007. 0800, subp. 5(B) Recordkeeping: Maintain records describing any insignificant modifications (asrequired by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms (asrequired by Minn. R. 7007.1350, subp. 2), including records of the emissionsresulting from those changes.
34.0
CD Minn. R. 7007.1200, subp. 4 If the Permittee determines that no permit amendment or notification is requiredprior to making a change, the Permittee must retain records of all calculationsrequired under Minn. R. 7007.1200. These records shall be kept for a period of fiveyears from the date the change was made or until permit reissuance, whichever islonger. The records shall be kept at the stationary source for the current calendaryear of operation and may be kept at the stationary source or office of thestationary source for all other years. The records may be maintained in eitherelectronic or paper format.
35.0
CD hdr REPORTING/SUBMITTALS36.0
CD Minn. R. 7019.1000, subp. 3 Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of aplanned shutdown of any control equipment or process equipment if the shutdownwould cause any increase in the emissions of any regulated air pollutant. If theowner or operator does not have advance knowledge of the shutdown, notificationshall be made to the Commissioner as soon as possible after the shutdown.However, notification is not required in the circumstances outlined in Items A, Band C of Minn. R. 7019.1000, subp. 3.
At the time of notification, the owner or operator shall inform the Commissioner ofthe cause of the shutdown and the estimated duration. The owner or operator shallnotify the Commissioner when the shutdown is over.
37.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 4 of 15
CD Minn. R. 7019.1000, subp. 2 Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdownof more than one hour duration of any control equipment or process equipment ifthe breakdown causes any increase in the emissions of any regulated air pollutant.The 24-hour time period starts when the breakdown was discovered or reasonablyshould have been discovered by the owner or operator. However, notification is notrequired 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 operatorshall inform the Commissioner of the cause of the breakdown and the estimatedduration. The owner or operator shall notify the Commissioner when thebreakdown is over.
38.0
CD Minn. R. 7019.1000, subp. 1 Notification of Deviations Endangering Human Health or the Environment: As soonas possible after discovery, notify the Commissioner or the state duty officer, eitherorally or by facsimile, of any deviation from permit conditions which could endangerhuman health or the environment.
39.0
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 anydeviation from permit conditions which could endanger human health or theenvironment. 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 yetcorrected; and5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of thedeviation.
40.0
S/A Minn. R. 7007.0800, subp. 6(A)(2) Semiannual Deviations Report: due 30 days after end of each calendar half-yearfollowing Permit Issuance. The first semiannual report submitted by the Permitteeshall cover the calendar half-year in which the permit is issued. The first report ofeach calendar year covers January 1 - June 30. The second report of eachcalendar year covers July 1 - December 31. If no deviations have occurred, thePermittee shall submit the report stating no deviations.
41.0
CD Minn. Rs. 7007.1150 - 7007.1500;Minn. R. 7007.0400, subp. 3
Application for Permit Amendment: If a permit amendment is needed, submit anapplication in accordance with the requirements of Minn. R. 7007.1150 throughMinn. R. 7007.1500. Submittal dates vary, depending on the type of amendmentneeded.
Upon adoption of a new or amended federal applicable requirement, and if thereare more than 3 years remaining in the permit term, the Permittee shall file anapplication for an amendment within nine months of promulgation of the applicablerequirement, pursuant to Minn. R. 7007.0400, subp. 3.
42.0
S/A Minn. R. 7007.0400, subp. 2 Application for Permit Reissuance: due 180 days before expiration of ExistingPermit
43.0
CD Minn. R. 7007.1400, subp. 1(H) Extension Requests: The Permittee may apply for an Administrative Amendment toextend a deadline in a permit by no more than 120 days, provided the proposeddeadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H).Performance testing deadlines from the General Provisions of 40 CFR pt. 60 andpt. 63 are examples of deadlines for which the MPCA does not have authority togrant extensions and therefore do not meet the requirements of Minn. R.7007.1400, subp. 1(H).
44.0
S/A Minn. R. 7007.0800, subp. 6(C) Compliance Certification: due 31 days after end of each calendar year followingPermit Issuance (for the previous calendar year). Submit the certification to theCommissioner on a form approved by the Commissioner. This report covers alldeviations experienced during the calendar year.
45.0
CD Minn. R. 7019.3000 - 7019.3100 Emission Inventory Report: due on or before April 1 of each calendar year followingpermit issuance. The Permittee shall submit this on a form approved by theCommissioner.
46.0
CD Minn. R. 7002.0005 - 7002.0095 Emission Fees: due 30 days after receipt of an MPCA bill.47.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 5 of 15
S/A 40 CFR 60.7; 40 CFR 75.64; 40CFR 60.4395; Minn. R.7017.1110, subps. 1 & 2
Excess Emissions/Downtime Reports (EER's): due 30 days after end of eachcalendar quarter following Permit Issuance. Submit Deviations Reporting FormDRF-1 as amended. The EER must contain all of the information requested in 40CFR Section 60.7(c). The EER shall indicate all periods of monitor bypass and allperiods of exceedances of a limit including exceedances allowed by an applicablestandard, i.e. during start-up, shutdown, and malfunctions. The EER must besubmitted even if there were no excess emissions, downtime or bypasses duringthe quarter.
48.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 6 of 15
Subject Item: GP 001 NOX Limit
Associated Items: EU 001 Combustion Turbine 001
EU 002 Turbine 002
NC/CA
Type Citation Requirement
CD hdr EMISSION LIMITS1.0
LIMIT Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000
Nitrogen Oxides: less than or equal to 244.0 tons/year using 12-month Rolling Sumfrom the two turbines combined.
This limit applies continuously under all conditions including startup, shutdown, andmalfunction.
2.0
CD hdr RECORDKEEPING REQUIREMENTS3.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5
By the 15th day of each month, the Permittee shall calculate and record the NOxemissions from the previous month and the previous 12 months, as follows:
NOxmo = NOx001 + NOx002
NOxmo = the NOx emissions from the previous calendar month
NOx12mo = the 12-month rolling sum of the NOxmo values calculated for theprevious 12 calendar months
Where:NOx001 = NOx emissions from EU 001 for the previous month, calculated asdescribed under Subject Item EU 001 of this permit
NOx002 = NOx emissions from EU 002 for the previous month, calculated asdescribed under Subject Item EU 002 of this permit
4.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 7 of 15
Subject Item: GP 002 Continuous Emission Monitors - EU002
Associated Items: MR 001 NOX monitor
MR 002 O2 monitor
NC/CA
Type Citation Requirement
CD Minn. R. 7007.0800, subp. 2 CEMS REQUIREMENTS
The following table is a list of emission units and associated CEMS:
EU 002/SV 002: MR 001 (NOx) and MR 002 (O2)
1.0
CD 40 CFR 75.10(d)(1); 40 CFR60.13(e)(2)
CEMS Monitor Design: Each CEMS shall be designed to complete a minimum ofone cycle of sampling, analyzing, and data recording in each 15-minute period.
2.0
CD 40 CFR 75.10(d)(1) Monitoring Data: Hourly averages shall be computed using at least one data pointin each fifteen minute quadrant of an hour, where the unit combusted fuel duringthat quadrant of an hour. Not withstanding this requirement, an hourly average maybe 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 isunavailable as a result of the performance of calibration, quality assurance, orpreventive maintenance activities pursuant to 40 CFR Section 75.21 and appendixB of Part 75, or backups of data from the data acquisition and handling system, orrecertification, pursuant to 40 CFR Section 75.20. The owner or operator shall useall valid measurements or data points collected during an hour to calculate thehourly averages. All data points collected during an hour shall be, to the extentpracticable, evenly spaced over the hour.
3.0
CD 40 CFR 60.13(e); Minn. R.7017.1090
Continuous Operation: CEMS must be operated and data recorded during allperiods of emission unit operation including periods of emission unit start-up,shutdown, or malfunction except for periods of acceptable monitor downtime. Thisrequirement applies whether or not a numerical emission limit applies during theseperiods. A CEMS must not be bypassed except in emergencies where failure tobypass would endanger human health, safety, or plant equipment. Acceptablemonitor downtime includes reasonable periods as listed in Items A, B, C and D ofMinn. R. 7017.1090, subp. 2.
4.0
CD 40 CFR 75.21 CEMS QA/QC: The Permittee of an affected facility shall operate, calibrate, andmaintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75,appendix B as amended.
5.0
CD 40 CFR pt. 75, Appendix B,Section 2.1.1
Daily Calibration Error (CE) Test: The Permittee shall conduct daily CE testing onall CEMS required by the Acid Rain Program, in accordance with 40 CFR pt. 75,Appendix B.
6.0
CD 40 CFR pt. 75, Appendix B,Section 2.2.1 & Section 2.2.2;Minn. R. 7017.1020
Linearity and Leak Check Test (Acid Rain Program): due before end of each QAoperating quarter (as defined in Section 72.) in accordance with procedures in 40CFR pt. 75, Appendix B, Section 2.2.1 and Appendix A, Section 6.2.
7.0
CD Minn. R. 7017.1180, subp. 4 Linearity Test Results Summary: due 30 days after end of each calendar quarterfollowing Linearity and Leak Check Test if performed.
8.0
CD 40 CFR pt. 75, Appendix B,section 2.3.1; Minn. R. 7017.1020
CEMS Relative Accuracy Test Audit (RATA): due before end of each calendarhalf-year following CEM Certification Test, i.e., once every two successive QAoperating quarters (calendar quarter in which there are at least 168 unit operatinghours). Conduct a RATA on all CEMS required by the Acid Rain Program, inaccordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may beperformed annually (i.e., once every four successive QA operating quarters, ratherthan once every two successive QA operating quarters) if any of the conditionslisted in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)are met.
9.0
CD Minn. R. 7017.1180, subp. 2 Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMSRelative Accuracy Test Audit (RATA)).
10.0
CD Minn. R. 7017.1180, subp. 3 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end ofeach calendar quarter in which the CEMS RATA was conducted.
11.0
CD 40 CFR 75.64 Quarterly Reports: Electronically report the data and information in 40 CFR Section75.64 (a), (b), and (c) to the Administrator quarterly.
12.0
CD 40 CFR 75.57; 40 CFR 60.7(f);Minn. R. 7017.1130
Recordkeeping: The Permittee shall retain records of all CEMS monitoring data andsupport information for a period of five years from the date of the monitoringsample, measurement or report. Records shall be kept at the source.
13.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 8 of 15
CD 40 CFR 60.4345(b) and CFR 4060.13(e)(2)
During each full unit operating hour, both the NOX monitor and the diluent monitormust complete a minimum of one cycle of operation (sampling, analyzing, and datarecording) for each 15-minute quadrant of the hour, to validate the hour. For partialunit operating hours, at least one valid data point must be obtained with eachmonitor for each quadrant of the hour in which the unit operates. For unit operatinghours in which required quality assurance and maintenance activities areperformed on the CEMS, a minimum of two valid data points (one in each of twoquadrants) are required for each monitor to validate the NOX emission rate for thehour.
14.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 9 of 15
Subject Item: EU 001 Combustion Turbine 001
Associated Items: GP 001 NOX Limit
SV 001 Combustion Turbine
NC/CA
Type Citation Requirement
CD hdr EMISSION AND OPERATING LIMITS1.0
LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20 percent opacity once operating temperatures havebeen attained.
2.0
LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input using 3-hourRolling Average (compliance with the fuel sulfur content of 40 CFR Section80.510(c) will demonstrate compliance with this requirement.)
3.0
CD Minn. R. 7005.0100, subp. 35a Permitted Fuel type: Pipeline natural gas or No. 2 fuel oil/diesel fuel meeting therequirements of 40 CFR Section 80.510(c) only by design.
4.0
CD hdr MONITORING AND RECORDKEEPING REQUIREMENTS5.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5
By the 15th day of each month, the Permittee shall calculate and record the NOxemissions from the previous month (NOx001) using the procedures outlined inScenario 1, 2, or 3, below as applicable.
6.0
CD 40 CFR 75.19; Minn. R.7007.0800, subps. 4 and 5
The Permittee shall use the fuel flow meter as described under 40 CFR Section75.19 low mass emission methodology to track fuel use and calculate NOx andSO2 emissions for CSAPR allowances.
7.0
CD Minn. R. 7007.0800, subp. 11 Operating Scenarios - The Permittee shall select and adhere to one of the followingoperating scenarios (Scenario 1, 2, or 3) for EU 001. The selection of the scenarioshall be documented as a permanent written record and shall include the date ofimplementation. The Permittee may change from Scenario 1 to Scenario 2 or 3, orfrom Scenario 2 to Scenario 3. The Permittee is prohibited from changing fromScenario 3 to Scenario 1 or 2, or from Scenario 2 to Scenario 1. If the Permitteechanges the operating scenario, the record shall be amended to reflect the changeand the date of change. A change in operating scenario may only occur on the firstday of a calendar month.
8.0
CD Minn. R. 7007.0800, subps. 2, 4,and 5
Calculations and Recordkeeping During Change of Operating Scenario:
If the Permittee changes from Scenario 1 or 2 to Scenario 3, NOx CEMS data shallbe used to calculate the monthly NOx emissions starting on the first day of the nextcalendar month following CEMS certification testing.
If the Permittee changes from Scenario 1 to Scenario 2, NOx emission curve datashall be used to calculate monthly NOx emissions starting on the first day of thenext calendar month following approval of the NOx testing. Upon receipt ofapproval letter from the MPCA, the Permittee shall recalculate emissions after themonitoring change and prior to availability of test results.
9.0
CD Minn. R. 7007.0800, subp. 11 OPERATING SCENARIO 1 MONITORING AND CALCULATIONS10.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5
Daily Recordkeeping: Each day, the Permittee shall record the amounts of naturalgas and fuel oil combusted in EU 001.
11.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5
Monthly Recordkeeping: By the 15th day of each month, the Permittee shallcalculate and record the amounts of natural gas and fuel oil combusted during theprevious calendar month.
12.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 10 of 15
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000
By the 15th day of each month, calculate and record the NOx emissions using thefollowing equation:
NOx001 = NOXfo1 + NOXng1
where:NOXfo1 = NOX from fuel oil combustion in EU 001, in tonsNOXng1 = NOX from natural gas combustion in EU 001, in tonsNOXfo1 = (EFfo1 x Qfo1 x 0.137)/2000NOXng1 = (EFng1 x Qng1 x NGhc)/2000
EFfo1 = the current site-specific or most current AP-42 and 40 CFR Section 75.19NOx emission factor for uncontrolled fuel oil combustion in a turbine, in lb/MMBtuheat input (current AP-42 factor is 0.88 lb/MMBtu heat input)(continued below)
13.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000
(continued from above)where:EFng1 = the current site-specific or AP-42 and 40 CFR Section 75.19 NOxemission factor for uncontrolled turbine firing natural gas (unless the Permitteechooses lean pre-mix or water injection, in which it is the appropriate factor for thattechnology), in lb/MMBtu heat input (current AP-42 factor for uncontrolled firing is0.32 lb/MMBtu heat input)
Qfo1 = the quantity of fuel oil combusted in EU 001 during the previous month, ingallons
Qng1 = the quantity of natural gas combusted in EU 001 during the previousmonth, in million cubic feet
0.137 = fuel oil heating value conversion factor (137 MMBtu/1000 gal)
NGhc = natural gas heating value, in MMBtu/million cubic feet (1050, or valuecalculated from hourly fuel usage and hourly heat input determined for EU 002)
14.0
CD Minn. R. 7007.0800, subp. 11 OPERATING SCENARIO 2 MONITORING AND CALCULATIONS15.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7017.2020,subp. 1
Initial Performance Test: to be completed prior to implementation of OperatingScenario 2, to measure NOx emissions for developing a NOx emissions curve fornatural gas and fuel oil.
NOx emissions shall be measured at a minimum of 4 equally spaced operatingloads ranging from minimum to maximum operating load, using US EPA Method 20in 40 CFR Part 60, Appendix A. Test results shall be used to develop a NOxemissions curve based on operating load (lb NOx/hr vs. gross megawatt-hours).Separate curves shall be developed for each fuel (oil and gas) and for eachoperating season (summer and winter). As an alternative, the Permittee maychoose to use the NOx Emissions Estimation Protocol for Gas-Fired Peaking Unitsand Oil-Fired Peaking Units, from 40 CFR Part 75, Appendix E.
Additional requirements related to performance testing are found under SubjectItem Total Facility. The Permittee shall submit a copy of each NOx emission curvealong with the required test report.
16.0
S/A Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7017.2020,subp. 1
Performance Test: due before end of each 60 months following Initial PerformanceTest or after each 3000 hours of operation after implementation of OperatingScenario 2, whichever timeframe is shorter, to measure NOx emissions andredevelop NOx emissions curves as described for the Initial Performance Test.
17.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5
Hourly Recordkeeping and Calculations: for each hour of operation, the Permitteeshall record the total gross megawatt-hours of electricity produced, and the type offuel combusted. The Permittee shall calculate and record the hourly NOxemissions rate in lb/hr based on the emissions curve developed from test data.
18.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.3000,subps. 4 and 5
Monthly Recordkeeping and Calculations: By the 15th day of each month, thePermittee shall calculate and record the NOx emission from the previous calendarmonth (NOx001) by summing the hourly NOx emission rates for the month.
19.0
CD Minn. R. 7007.0800, subp. 11 OPERATING SCENARIO 3 MONITORING AND CALCULATIONS20.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 11 of 15
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subp. 5
NOx Monitoring: The Permittee shall install, calibrate, maintain, and operate acontinuous emission monitoring system (CEMS) for NOx and oxygen, and shallrecord the output of the system when combusting any fuel. The system shall at aminimum calculate NOx emissions on an hourly lb/MMBtu basis for conversion tolb/hour emissions based on hourly fuel usage.
A flowmeter shall be installed to determine hourly fuel usage and the hourly heatinput.
21.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5
Hourly Fuel Usage Recordkeeping: The Permittee shall calculate and record thehourly fuel usage in gallons/hour (gph) of fuel oil and cubic feet per hour (cfh) ofnatural gas.
22.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5
Monthly Recordkeeping and Calculations: By the 15th day of each month, thePermittee shall calculate and record the monthly NOx emissions (NOx001), in tons,using the hourly CEMS and fuel usage data.
23.0
CD hdr MONITORING REQUIREMENTS FOR CMS24.0
CD Minn. R. 7007.0800, subp. 4 The Permittee shall calibrate, operate and maintain a continuous monitoring system(CMS) for the fuel flow monitor consistent with 40 CFR Section 75.19.
25.0
CD Minn. R. 7007.0800, subp. 4 CMS QA/QC: The Permittee shall follow the manufacturer recommendation forpreventative maintenance and periodic monitoring to ensure CMS reliabilityincluding but not limited to annual calibrations for the fuel flow monitor.
26.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 12 of 15
Subject Item: EU 002 Turbine 002
Associated Items: GP 001 NOX Limit
MR 001 NOX monitor
MR 002 O2 monitor
SV 002 Turbine 002 Exhaust
NC/CA
Type Citation Requirement
CD hdr EMISSION LIMITS1.0
LIMIT 40 CFR 60.4320(a) and 40 CFRpt. 60, subp. KKKK, Table 1
Nitrogen Oxides: less than or equal to 15 parts per million at 15 percent O2 or 54ng/J of useful output (0.43 lb/MWh) when turbine is operating at or above 75percent of peak load and when operating at 0°F or above.
2.0
LIMIT 40 CFR 60.4320(a) and 40 CFRpt. 60, subp. KKKK, Table 1
Nitrogen Oxides: less than or equal to 96 parts per million at 15 percent O2 or 590ng/J of useful output (4.70 lb/MWh) when turbine is operating at less than 75percent of peak load or operating at temperatures less than 0°F.
3.0
LIMIT 40 CFR 60.4330(a) Sulfur Dioxide: less than or equal to 110 nanograms/joule heat input (0.90 lb/MWh)gross output or the Permittee must not burn any fuel in EU 002 which contains totalpotential sulfur emissions in excess of 26 ng SO2/J (0.060 lb SO2/MMBtu) heatinput.
4.0
LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input using 3-hourRolling Average (compliance with 40 CFR Section 60.4330(a) will demonstratecompliance with this requirement.)
5.0
LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20 percent opacity once operating temperatures havebeen attained. Operating temperatures are attained after completion of startup andcontinue until a shutdown or malfunction occurs.
6.0
CD hdr OPERATING REQUIREMENTS7.0
CD Minn. R. 7007.0800, subp. 2 Permitted Fuel Type: Pipeline natural gas by design.8.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000
Startup shall be completed no later than 45 minutes after the start of fuelcombustion.
9.0
CD 40 CFR 60.8(c) Operations during periods of startup, shutdown, and malfunction shall not constituterepresentative conditions for the purpose of a performance test nor shall emissionsin excess of the level of the applicable emission limit during periods of startup,shutdown, and malfunction be considered a violation of the applicable emissionlimit unless otherwise specified in the applicable standards.
10.0
CD 40 CFR 60.4333(a) The Permittee must operate and maintain EU 002, air pollution control equipment,and monitoring equipment in a manner consistent with good air pollution controlpractices for minimizing emissions at all times including startup, shutdown, andmalfunction.
11.0
CD hdr MONITORING AND RECORDKEEPING REQUIREMENTS12.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5
Each time EU 002 is operated, monitor and record the amount of time it is operatedin "startup" mode. The Permittee shall maintain a log showing the length of thestartup time for each operating event.
13.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; 40 CFR 60.4340(b);Minn. R. 7011.2350; Minn. R.7017.1006
NOx Monitoring: The Permittee shall use a CEMS to measure NOx emissions forSV 002 being monitored. The NOx CEMS shall be operated and maintained inaccordance with 40 CFR pt. 75, Appendix B and 40 CFR Section 60.4340(b)(1).Additional monitoring requirements are also located at GP 002 Level.
A flowmeter shall be installed to determine hourly fuel usage and the hourly heatinput.
The system shall at a minimum calculate NOx emissions on an hourly lb/MMBtubasis for conversion to lb/hr NOx emissions based on hourly fuel usage.
14.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 13 of 15
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5
Hourly Fuel Usage Recordkeeping: The Permittee shall calculate and record thehourly fuel usage in cubic feet per hour (cfh) of natural gas.
15.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; 40 CFR 60.4350;Minn. R. 7007.0800, subps. 4 and5
Monthly Recordkeeping and Calculations: By the 15th day of each month, thePermittee shall calculate and record the monthly NOx emissions (NOx002), in tons,using the hourly CEMS and fuel usage data.
16.0
CD 40 CFR 75.10 The Permittee shall record, measure and calculate SO2, NOx, and CO2 emissionrates for EU 002 in accordance with 40 CFR pt. 75.
17.0
CD 40 CFR 60.4365(a); Minn. R.7007.0800, subp. 4
Fuel Monitoring: The Permittee must use a current, valid purchase contract, tariffsheet or transportation contract specifying that the total sulfur content for naturalgas is 20 grains of sulfur or less per 100 standard cubic feet to demonstrate thatthe potential sulfur emissions of the fuel combusted in the turbine do not exceed 26ng SO2/J (0.060 lb SO2/MMBtu) heat input.
18.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 14 of 15
Subject Item: EU 003 Emergency Diesel Fire Pump Engine
NC/CA
Type Citation Requirement
CD hdr EMISSION LIMITS1.0
LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input using 3-hourRolling Average (compliance with the fuel sulfur content requirements of 40 CFRSection 80.510(c) will demonstrate compliance with this requirement.)
2.0
LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20 percent opacity once operating temperatures havebeen attained.
3.0
CD hdr OPERATING CONDITIONS4.0
LIMIT Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subp. 5
Operating Hours: less than or equal to 150 hours/year using 12-month Rolling Sumto be calculated by the 28th day of each month.
5.0
CD Minn. R. 7005.0100, subp. 35a Permitted Fuel Restriction: No. 2 fuel oil/diesel fuel meeting the requirements of 40CFR Section 80.510(c) only by design.
6.0
CD hdr MONITORING AND RECORDKEEPING REQUIREMENTS7.0
CD Minn. R. 7007.0800, subp. 5 The Permittee shall keep records of fuel type and usage on a monthly basis.8.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5
Operating Hours Recordkeeping: Except as described below, the Permittee shallmaintain a record of hours of operation of EU 003 and calculate and record the12-month rolling sum of operating hours by the 28th day of each month.
If operating hours recordkeeping demonstrates that EU 003 operated for no morethan 75 operating hours in the previous calendar year, the Permittee may recordEU 003 operating hours on a calendar year basis. The annual sum must becalculated by April 1 of each year for the previous calendar year.
If any calendar year sum exceeds 75 operating hours, the Permittee shallcommence monthly recordkeeping until records document no more than 75operating hours during each of two consecutive calendar years.
9.0
CD Minn. R. 7007.0800, subp. 2 Additional Requirements for Engine EU 003 are in Appendix D.10.0
MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01
Facility Name: Great River Energy - Cambridge
Permit Number: 05900014 - 004
21 Apr, 2015 11:26Page 15 of 15
Subject Item: EU 004 Diesel Starting Engine
NC/CA
Type Citation Requirement
CD hdr EMISSION LIMITS1.0
LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20 percent opacity once operating temperatures havebeen attained.
2.0
LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input (compliance withthe fuel sulfur content with the requirements of 40 CFR Section 80.510(c) willdemonstrate compliance with this requirement.)
3.0
CD hdr OPERATING CONDITIONS4.0
LIMIT Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subp. 5
Operating Hours: less than or equal to 70 hours/year using 12-month Rolling Sumto be calculated by the 28th day of each month.
5.0
CD Minn. R. 7005.0100, subp. 35a Permitted Fuel Restriction: No. 2 fuel oil/diesel fuel meeting the requirements of 40CFR Section 80.510(c) only by design.
6.0
CD hdr RECORDKEEPING REQUIREMENTS7.0
CD Minn. R. 7007.0800, subp. 5 The Permittee shall keep records of fuel type and usage on a monthly basis.8.0
CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5
Operating Hours Recordkeeping: Except as described below, maintain a record ofEU 004 hours of operation and calculate and record the EU 004 12-month rollingsum of operating hours by the 28th day of each month. Hours may be tracked bytracking the number of starts, and assuming an operating time of 15 minutes perstart.
If operating hours recordkeeping demonstrates that EU 004 operated for no morethan 20 operating hours in the previous calendar year, the Permittee may recordEU 004 operating hours on a calendar year basis. The annual sum must becalculated by April 1 of each year for the previous calendar year.
If any calendar year sum exceeds 20 operating hours, the Permittee shallcommence monthly recordkeeping until records document no more than 20operating hours during each of two consecutive calendar years.
9.0
CD Minn. R. 7007.0800, subp. 2 Additional Requirements for Engine EU 004 are in Appendix D.10.0
Attachment 3- Points Calculator
Points Calculator
1) AQ Facility ID No.: 147C Total Points 02) Facility Name: Great River Energy-Cambridge3) Small business? y/n? N 4) DQ Numbers (including all rolled) : 4275 5) Date of each Application Received: 01/24/20136) Final Permit No. 05900014-0047) Permit Staff Amrill Okonkwo8) "Work completed" in which .xls file (i.e. unit 2b, unit 1a, biofuels)? NA
TotalApplication Type DQ No. Qty. Points Points DetailsAdministrative Amendment 1 0Minor Amendment 4 0Applicability Request 10 0Moderate Amendment 15 0Major Amendment 25 0Individual State Permit (not reissuance) 50 0Individual Part 70 Permit (not reissuance) 75 0
Additional PointsModeling Review 15 0
BACT Review 15 0LAER Review 15 0CAIR/Part 75 CEM analysis 10 0NSPS Review 10 0NESHAP Review 10 0Case-by-case MACT Review 20 0Netting 10 0Limits to remain below threshold 10 0Plantwide Applicability Limit (PAL) 20 0AERA review 15 0Variance request under 7000.7000 35 0Confidentiality request under 7000.1300 2 0EAW reviewPart 4410.4300, subparts 18, item A; and 29 15 0Part 4410.4300, subparts 8, items A & B; 10, items A to C; 16, items A & D; 17, items A to C & E to G; and 18, items B & C
35 0
Part 4410.4300, subparts 4; 5 items A & B; 13; 15; 16, items B & C; and 17 item D
70 0
Add'l Points 0NOTES: This permit is a reissuance; therefore no additional points are required for this reissuance.
(DQ DQ 4275)