Application to the Alberta Utilities Commission for a Time Extension to Complete Construction

APPLICATION TO THE ALBERTA UTILITIES COMMISSION FOR A TIME EXTENSION TO COMPLETE CONSTRUCTION

NORTHERN PRAIRIE POWER PROEJCT

Prepared for: Grande Prairie Generation, Inc. 1005 Brandon Shores Road Baltimore, MD 21226

Submitted to: Alberta Utilities Commission Fifth Avenue Place 4th Floor, 425-1 Street S.W. Calgary, Alberta T2P 3L8

March 24, 2015 Grande Prairie Generation, Inc. March 2015 Northern Prairie Power Project AUC Rule 007 Power Plant Application

TABLE OF CONTENTS

1.0 Introduction ...... 3 2.0 Schedule 1 Applicant General Information ...... 4 3.0 Other Applications ...... 5 3.1 Information Requirements ...... 5 3.2 Other Application Attachments ...... 7

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Grande Prairie Generation, Inc. March 2015 Northern Prairie Power Project AUC Rule 007 Power Plant Application

INTRODUCTION

Grande Prairie Generation, Inc. (GPG), a wholly-owned subsidiary of Exelon Corporation, owns and operates the Northern Prairie Power Plant (Power Plant). The Power Plant operates under Alberta Utilities Commission (AUC) Power Plant Approval U2017-218 and Alberta Environment and Sustainable Resource Development (AESRD) Environmental Protection and Enhancement Act (EPEA) Approval Number 238762-00-02. A copy of Power Plant Approval U2007-218 is provided in Attachment A, a copy of AESRD EPEA Approval 238762-00-02 is provided in Attachment B. The Power Plant operates a General Electric (GE) Model MS7001/EA (Frame 7EA) natural gas-fired turbine. The turbine-generator has a nominal output of 85 MW. The turbine-generator is capable of generating 105 MW of electricity under its current configuration; however, constraints on the electric system limit the generator output to 99 MW.

GPG has applied to the Alberta Electric System Operator (AESO) to remove the operating constraints. Authorization from AESO is expected in June 2015. Clause 2 of AUC Power Plant Approval U2007-218 specifies the Power Plant has a ‘total generating capacity’ of 85 MW. Once the generating constraints issued by AESO are removed, GPG is seeking authorization to operate the turbine-generator at the maximum generating capacity of 105 MW. As such, GPG is hereby applying under Section 10 of AUC Rule 007 to amend the Clause 2 of AUC Power Plant Approval U2007-218 to change total generating capacity from the existing 85 MW to 105 MW.

The requested change is purely administrative in nature as there will be no change to the design of the Power Plant. The Power Plant is currently authorized under the EPEA Approval 238762-00-02 to emit up to 0.030 t/h of NOx. Furthermore, emissions from the turbine are required to remain within the limit of 0.3 kg/MWhoutput required by the Alberta Air Emissions Standards for Electricity Generation and AESRD EPEA Approval Number 238762-00-02. Emissions from the turbine will remain within the existing authorized emission limits. As such, the public and stakeholders will not be affected by this change.

BACKGROUND

The AESO recently posted on July 29, 2014 a revision to Information Document "Northwest Area Transmission Constraint Management ID # 2011-004R" that relates to Section 302.1 of the ISO Rules "Real Time Transmission Constraint Management". This latest revision eliminates the generation capacity limit at the Power Plant that was previously established for transmission congestion management. Furthermore, the Power Plant has undergone combustion controls tuning and is now capable of achieving a maximum capability of 105 MWs during periods when ambient temperatures are at or below -20 degrees Celsius. On August 14, 2014, GPG filed a System Access Service Request (SASR) Form formally increase the contract capacity of an existing system access service agreement for the Power Plant. GPG requested to increase the Supply Transmission Service (STS) to 105 MW. GPG is now seeking to amend the total generating capacity identified in AUC Power Plant Approval U2007-218 to reflect the unconstrained maximum generating capacity of the turbine-generator of 105 MW, as reflected in the SASR. Copies of the SASR documents, along with the Connection Plan and Connection System Study, are provided in Attachment C.

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Grande Prairie Generation, Inc. March 2015 Northern Prairie Power Project AUC Rule 007 Power Plant Application

SCHEDULE 1 APPLICANT GENERAL INFORMATION

Part 1: Applicant Information Company Name Grande Prairie Generation, Inc.

Contact Name Karen Hunt

Telephone/Fax (610) 765-6784 / (610) 765-5980

Email Address [email protected]

Mailing Address 300 Exelon Way, Kennett Square, Pa 19348

Part 2: Project Overview Application description Grande Prairie Generation, Inc. (GPG), a wholly owned subsidiary of Exelon Corporation, hereby applying under Section 10 of AUC Rule 007 to amend the Clause 2 of AUC Power Plant Approval U2007-218 to change total generating capacity from the existing 85 MW to 105 MW.

Are there any other AUC applications directly No. related to this application?

Part 3: Application Types 1. Identify what this application is for Application Category Electric Power Plant Application Type Application Type: Stipulation - Facility

2. Is this application for a power plant less than No. 1 MW?

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Grande Prairie Generation, Inc. March 2015 Northern Prairie Power Project AUC Rule 007 Power Plant Application

10.0 OTHER APPLICATIONS

10.1 INFORMATION REQUIREMENTS

OTH1) Identify the sections of the Hydro and Electric Energy Act and Hydro and Electric Energy Regulation under which the application is made.

This application is made pursuant to Section 19 of the Hydro and Electric Energy Act.

OTH2) State the approvals that are being applied for from the Commission.

Grande Prairie Generation, Inc. (GPG) hereby submits this application to the Alberta Utilities Commission (AUC) to amend the Clause 2 of AUC Power Plant Approval U2007-218 to change total generating capacity from the existing 85 MW to 105 MW.

OTH3) Provide a list of existing approvals for facilities directly affected by the application, if any.

A copy of AUC Power Plant Approval is provided in Attachment A. GPG also owns and operate the Lowe Lake Substation 944S, which operates under AUC Substation Permit and Licence No. U2007- 220. The requested change will not result in any changes to the design or operation of the Lowe Lake Substation 944S.

OTH4) For a minor alteration, provide details regarding the work being proposed.

Not applicable. GPG is not proposing any changes to the design of the Power Plant.

OTH5) Provide a list of companies that may be affected by the project, confirm that these companies have no concerns regarding the application, and indicate which other agreements are necessary to carry out the project.

Not applicable. The requested change is purely administrative in nature as there will be no change to the design of the Power Plant. The Power Plant is currently authorized under the EPEA Approval 238762-00-02 to emit up to 0.030 t/h of NOx. Furthermore, emissions from the turbine are required to remain within the limit of 0.3 kg/MWhoutput required by the Alberta Air Emissions Standards for Electricity Generation and AESRD EPEA Approval Number 238762-00-02. Emissions from the turbine will remain within the existing authorized emission limits. As such, the public and stakeholders will not be affected by this change.

OTH6) Describe the participant involvement program that has been conducted, if any.

Not applicable. GPG believes that a participant involvement program is not necessary to be conducted since the change being requested is administrative in nature and that there will not be any change to the design of the Power Plant.

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Grande Prairie Generation, Inc. March 2015 Northern Prairie Power Project AUC Rule 007 Power Plant Application

OTH7) List all occupants, residents and landowners, as well as other interested parties that were contacted as part of the participant involvement program, if any.

OTH8) If potentially directly and adversely affected persons raised any concerns, describe how the concerns were dealt with or will be dealt with.

Not applicable. No participant involvement program was required to be conducted.

OTH9) For a change of ownership application, the applicant shall provide details of the ownership structure, including providing the names of all companies having an ownership interest in the project and their ownership share, and if applicable, the name of the operator, for the facilities for which they are seeking to acquire the approval, permit or license. The details should include confirmation of whether and in which of the following category the owner, and if applicable, the operator falls:

(a) Registered under the Companies Act. (b) Registered, incorporated or continued under the Business Corporations Act. (c) Registered, incorporated or continued under the Cooperatives Act. (d) Incorporated by an ordinance or an act of the legislature that empowers it to engage in the business of generation or transmission of electricity. (e) A bank. (f) A railway company incorporated under an act of the Parliament of Canada. (g) A loan corporation or trust corporation. (h) An insurer licensed under the Insurance Act. (i) A municipal corporation. (j) A co-operative association.

Not applicable. This application is not proposing a change of ownership.

10.2 OTHER APPLICATION ATTACHMENTS

Although there is no change to the design of the Power Plant or the authorized emission limit for the turbine, the Alberta Air Quality Model Guideline (AQMG) and Alberta Ambient Air Quality Objectives (AAAQO) have changed since the original air quality dispersion modelling assessment for the Power Plant was completed in 2007. In order to ensure that the operation of the Power Plant is still predicted to comply with the AAAQOs under the revised AQMG, GPG proactively completed an updated dispersion modeling assessment for NOx. A copy of the dispersion modelling assessment is provided in Attachment D. As indicated in the dispersion modelling assessment, ground-level concentrations of NO2 are predicted to comply with the AAAQOs.

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Grande Prairie Generation, Inc. March 2015 Northern Prairie Power Project AUC Rule 007 Power Plant Application

ATTACHMENT A

AUC POWER PLANT APPROVAL U2007-218

Attachments

Power Plant Approval No. U2007-218

MADE at the City of Calgary, in the Province of Alberta, on

19th day of December 2007. ALBERTA ENERGY AND UTILITIES BOARD

Grande Prairie Generation Inc. Power Plant Application No. 1514077

Grande Prairie Generation Inc.(the Operator), by Application No. 1514077 (the Application), registered on June 1, 2007, applied to the Alberta Energy and Utilities Board (the Board) for approval to construct and operate an 85-MW power plant (the Power Plant) in the County of Grande Prairie.

The Board, pursuant to section 11 of the Hydro and Electric Energy Act , being chapter H-16 of the Revised Statutes of Alberta, 2000, approves the Application and grants an Approval to the Operator, to construct and operate the Power Plant, subject to the provisions of the Act, the Regulations, Orders made pursuant thereto, and to the following terms and conditions:

1. The Power Plant shall be located in the South-east quarter of Section 19, Township 73, Range 8, West of the 6th Meridian.and as further described in the Application.

2. The Power Plant shall consist of one gas-fired unit with a total generating capacity of 85 MW and as further described in the Application.

3. The Operator shall notify the Board within 30 days of completing the power plant.

4. The Operator shall satisfy the Board by April 30, 2009, that the power plant has been completed. However, upon application from the Operator, the Board may stipulate a later date for completing the power plant.

5. The Operator shall obtain Board approval prior to making any material changes to the Power Plant or substantially varying the design and/or specifications of the Power Plant from what was stated in the Application or what the Board has approved.

6. This Approval is not transferable unless approved by the Board.

7. The Board may cancel, suspend, or amend this Approval, in whole or in part, upon its own motion, an application by an interested person, or failure of the Operator to comply with any provisions of the Act, the Regulations, or this Approval.

END OF DOCUMENT

Approval No. U2007-218 Page 1 of 1 Grande Prairie Generation, Inc. March 2015 Northern Prairie Power Project AUC Rule 007 Power Plant Application

ATTACHMENT B

AESRD EPEA APPROVAL 238762-00-02

Attachments

APPROVAL

PROVINCE OF ALBERTA

ENVIRONMENTAL PROTECTION AND ENHANCEMENT ACT R.S.A. 2000, c.E-12, as amended.

238762-00-00 APPROVAL NO.

001-238762 APPLICATION NO.

January 11, 2008 EFFECTIVE DATE:.

December 31, 2017 EXPIRY DATE:

Grande Prairie Generation Inc. APPROVAL HOLDER

ACTIVITY: CONSTRUCTION, OPERATION AND RECLAMATION OF THE

Northern Prairie Thermal Electric Power Plant

IS SUBJECT TO THE ATTACHED TERMS AND CONDITIONS.

signed by Gary Sasseville Designated Director under the Act Gary Sasseville

January 11, 2008 Date Signed APPROVAL NO. 238762-00-00 Page 1 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

PART 1: DEFINITIONS

SECTION 1.1: DEFINITIONS

1.1.1 All definitions from the Act and the regulations apply except where expressly defined in this approval.

1.1.2 In all PARTS of this approval:

(a) “720 hour rolling average” means for each pollutant, the average of the consecutive hourly means emission rates, determined for the preceding 720 hour of the unit operation. Intervals of zero are not to be included in the calculation of the rolling averages;

(b) “Act” means the Environmental Protection and Enhancement Act, R.S.A. 2000, c.E-12, as amended;

(c) “air contaminant” means any solid, liquid or gas or combination of any of them in the atmosphere resulting directly or indirectly from the activities of man;

(d) “application” means the written submissions to the Director in respect of application number 001-238762 and any subsequent applications for amendments of approval number 238762-00-00;

(e) “CEM” means continuous emissions monitor;

(f) “CEMS Code” means the Continuous Emissions Monitoring System Code, Alberta Environment, as amended;

(g) "commence operation" means to start up the plant for the first time with the introduction of thermal energy and the simultaneous production of electrical energy excluding predetermined period of commissioning or testing;

(h) “container” means any portable device in which a substance is kept, including but not limited to drums, barrels and pails which have a capacity greater than 18 litres but less than 210 litres;

(i) “day” means any sampling period of 24 consecutive hours unless otherwise specified;

(j) “decommissioning” means the dismantling and decontamination of a plant undertaken subsequent to the termination or abandonment of any activity or any part of any activity regulated under the act; APPROVAL NO. 238762-00-00 Page 2 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

(k) “Director” means an employee of the Government of Alberta designated as a Director under the Act;

(l) “dismantling” means the removal of buildings, structures, process and pollution abatement equipment, vessels, storage facilities, material handling facilities, railways, roadways, pipelines and any other installations that are being or have been used or held for or in connection with the plant;

(m) “effluent stream” means any substance in a gaseous medium released by or from a plant;

(n) “fugitive emissions” means air contaminant emissions to the atmosphere other than ozone depleting substances, originating from a plant source other than a flue, vent, or stack but does not include sources which may occur due to breaks or ruptures in process equipment;

(o) “grab sample" means an individual sample collected in less than 30 minutes and which is representative of the substance sampled;

(p) “ISO 17025” means the international standard, developed and published by International Organization for Standardization (ISO), specifying management and technical requirements for laboratories;

(q) “industrial runoff” means precipitation that falls on or transverses the plant developed area;

(r) “industrial runoff control system” means the parts of the plant that collect, store or treat industrial runoff from the plant;

(s) “industrial wastewater” means the composite of liquid wastes and water-carried wastes, any portion of which results from any industrial process carried on at the plant;

(t) “land reclamation” means the stabilization, contouring, maintenance, conditioning or reconstruction of the surface of the land to a state that permanently returns the site to a capability equivalent to its predisturbed state;

(u) "manual stack survey" means a survey conducted in accordance with the Alberta Stack Sampling Code, as amended;

(v) “Meadowville Drainage II” means the man made channel that runs across the SE 1/4 of Section 19, Township 073, Range 8, West of 6th Meridian;

(w) “month" means calendar month; APPROVAL NO. 238762-00-00 Page 3 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

(x) “PASZA Air Quality Monitoring Program Network” means the air monitoring network established and operated by the Peace Airshed Zone Association, as accepted in writing by the Director;

(y) “plant” means all buildings, structures, process and pollution abatement equipment, vessels, storage facilities, material handling facilities, roadways, pipelines and other installations, and includes the land, located on the SE 1/4 of Section 19, Township 073, Range 08, West of 6th Meridian, that is being or has been used or held for or in connection with the Northern Prairie power project;

(z) “representative grab sample” means a sample consisting of equal volume portions of water collected from at least four sites and approximately 0.25 metres below the water surface within a pond;

(aa) “week” means any consecutive 7-day period; and

(bb) “year” means calendar year, unless otherwise specified.

PART 2: GENERAL

SECTION 2.1: GENERAL

2.1.1 The approval holder shall immediately report by telephone any contravention of the terms and conditions of this approval to the Director at (780) 422-4505.

2.1.2 The approval holder shall submit a written report to the Director within 7 days of the reporting pursuant to 2.1.1.

2.1.3 The terms and conditions of this approval are severable. If any term or condition of this approval or the application of any term or condition is held invalid, the application of such term or condition to other circumstances and the remainder of this approval shall not be affected thereby.

2.1.4 The approval holder shall immediately notify the Director in writing if any of the following events occurs:

(a) the approval holder is served with a petition into bankruptcy;

(b) the approval holder files an assignment in bankruptcy or Notice of Intent to make a proposal;

(d) an application for protection from creditors is filed for the benefit of the approval holder under any creditor protection legislation; or APPROVAL NO. 238762-00-00 Page 4 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

(e) any of the assets which are the subject matter of this approval are seized for any reason.

2.1.5 If the approval holder monitors for any substances or parameters which are the subject of operational limits as set out in this approval more frequently than is required and using procedures authorized in this approval, then the approval holder shall provide the results of such monitoring as an addendum to the reports required by this approval.

2.1.6 All abbreviations used in this approval follow those given in Standard Methods for the Examination of Water and Wastewater published jointly by the American Public Health Association, the American Water Works Association, and the Water Environment Federation, 1998, as amended, unless otherwise specified in this approval.

SECTION 2.2: RECORD KEEPING

2.2.1 The approval holder shall record and retain all the following information in respect of any sampling conducted or analyses performed in accordance with this approval for a minimum of ten years, unless otherwise authorized in writing by the Director:

(a) the place, date and time of sampling;

(b) the dates the analyses were performed;

(d) the names of the persons who collected and analyzed each sample; and

(e) the results of the analyses.

SECTION 2.3: ANALYTICAL REQUIREMENTS

2.3.1 With respect to any sample required to be taken pursuant to this approval, the approval holder shall ensure that:

(a) collection;

(b) preservation;

(d) handling; and

(e) analysis; APPROVAL NO. 238762-00-00 Page 5 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

shall be conducted in accordance with the following unless otherwise authorized in writing by the Director:

(i) for air monitoring;

(A) the Alberta Stack Sampling Code, Alberta Environment, 1995, as amended;

(B) the Methods Manual for Chemical Analysis of Atmospheric Pollutants, Alberta Environment, 1993, as amended;

(D) the CEMS Code;

(ii) for industrial runoff parameters:

(A) the Standard Methods for the Examination of Water and Wastewater, published jointly by the American Public Health Association, American Water Works Association, and the Water Environment Federation, 1998, as amended;

(B) the Methods Manual for Chemical Analysis of Water and Wastes, Alberta Environmental Centre, Vegreville, Alberta, 1996, AECV96- M1, as amended;

(iii) for waste analysis:

(A) the Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, USEPA, SW-846, September 1986, as amended;

(B) the Industrial Waste Identification and Management Options, Alberta Environment, May 1996 as amended; and

2.3.2 The approval holder shall analyze all samples that are required to be obtained by this approval in a laboratory accredited pursuant to ISO 17025, as amended, for the specific parameter(s) to be analyzed, unless otherwise authorized in writing by the Director.

2.3.3 The approval holder shall comply with the terms and conditions of any written authorization issued by the Director under 2.3.2. APPROVAL NO. 238762-00-00 Page 6 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

SECTION 2.4: OTHER

2.4.1 All tanks shall conform to the Guidelines for Secondary Containment for Above Ground Storage Tanks, Alberta Environment, 1997, as amended, unless otherwise authorized in writing by the Director.

2.4.2 All aboveground storage tanks containing liquid hydrocarbons or organic compounds shall conform to the Environmental Guidelines for Controlling Emissions of Volatile Organic Compounds from Aboveground Storage Tanks, CCME-EPC-87-E, as amended.

PART 3: CONSTRUCTION

SECTION 3.1: GENERAL

3.1.1 If construction of the 99 MW thermal electric power plant as described in the application has not commenced by September 30, 2008, the approval holder shall apply for an amendment to this approval, unless otherwise authorized in writing by the Director.

3.1.2 The approval holder shall notify the Director in writing at least 14 days before commencing operations of the plant, as described in the application.

SECTION 3.2: AIR

3.2.1 The approval holder shall construct the 99 MW thermal electric power plant as described in the application and shall include, at the minimum, all of the following:

(a) one 99 MW dry low NOX gas turbine power generator; and

(b) one water bath natural gas heater exhaust stack.

3.2.2 The approval holder shall construct the 99 MW turbine exhaust stack according to the height requirement as prescribed in Table 3.2-A:

TABLE 3.2-A

MINIMUM HEIGHT ABOVE GRADE STACK (metres)

99 MW Turbine Exhaust Stack 19.8

3.2.3 The 99 MW turbine exhaust stack shall be equipped with sampling facilities as described in the application. APPROVAL NO. 238762-00-00 Page 7 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

SECTION 3.3: INDUSTRIAL WASTEWATER

3.3.1 The approval holder shall implement the industrial runoff plan as described in the application.

SECTION 3.4: WASTE MANAGEMENT

Not used at this time.

SECTION 3.5: DOMESTIC WASTEWATER

Not used at this time.

SECTION 3.6: WATERWORKS

Not used at this time.

SECTION 3.7: LAND CONSERVATION

3.7.1 The approval holder shall conserve all topsoil for reclamation.

3.7.2 The approval holder shall locate all topsoil stockpiles at the plant.

3.7.3 The approval holder shall stockpile all topsoil as follows:

(a) all stockpile foundation shall be stable; and

(b) all stockpiles shall be located on undisturbed topsoil.

3.7.4 The approval holder shall take all steps necessary to prevent erosion; including but not limited to all of the following:

(a) revegetate the stockpiles; and

(b) any other steps as authorized in writing by the Director.

3.7.5 The approval holder shall immediately suspend conservation of topsoil only when wet or frozen field conditions will result in mixing, loss or degradation of topsoil.

3.7.6 The approval holder shall recommence conservation of topsoil only when wet or frozen conditions in 3.7.5 no longer exists. APPROVAL NO. 238762-00-00 Page 8 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

PART 4: OPERATIONS, LIMITS, MONITORING AND REPORTING

SECTION 4.1: GENERAL

4.1.1 The approval holder shall comply as follows:

(i) maintain at least one of the following Environmental Management Systems:

(a) the Best Management Practices, developed from the Best Management Practices Guidance Document, Industrial Wastewater Branch, July 1994, as amended; or

(b) the ISO 14000 document CAN/CSA-ISO 14001-2004: Environmental Management Systems Specification with Guidance for Use {Reference No. ISO 14001:2004(E)}, as amended; or

(ii) implement the proposed emergency response plan.

4.1.2 The approval holder shall make the Environmental Management Systems and the proposed Emergency Spill Response Plan, available at any time for inspection by a representative of the Department of Environment, in the Province of Alberta.

SECTION 4.2: AIR

4.2.1 The approval holder shall not emit any effluent streams to the atmosphere except as provided in this approval.

4.2.2 The approval holder shall only emit effluent streams to the atmosphere from the following sources:

(a) the 99 MW turbine exhaust stack;

(b) the water bath natural gas heater exhaust stack;

(d) the space heater exhaust stack/vents; and

(e) any other source(s) authorized in writing by the Director or by an amendment to this approval. APPROVAL NO. 238762-00-00 Page 9 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

4.2.3 The approval holder shall maintain the stack referred to in 4.2.2(a) according to the minimum height requirement specified in TABLE 4.2-A:

TABLE 4.2-A: STACK HEIGHTS

MINIMUM HEIGHT ABOVE GRADE STACK (metres)

99 MW Turbine Exhaust Stack 19.8

4.2.4 Except as provided for by the Director in writing, the approval holder shall not emit fugitive emissions or an air contaminant from any source not specified in 4.2.2 in accordance with 4.2.5 of this approval.

4.2.5 With respect to fugitive emissions and any other source not in 4.2.2, the approval holder shall not release a substance or cause to release a substance that causes or may cause any of the following:

(a) impairment, degradation or alteration of the quality of natural resources; or

(b) material discomfort, harm or adversely affect the well being or health of a person; or

4.2.6 The approval holder shall not burn any debris by means of an open fire unless authorized in writing by the Director.

LIMITS

4.2.7 Release of the following air contaminant shall not exceed the limits specified in TABLE 4.2-B.

TABLE 4.2-B: AIR EMISSION LIMITS

MAXIMUM HOURLY ANNUAL EMISSION SOURCE AIR CONTAMINANT AVERAGE INTENSITY LIMITS 0.030 tonnes/hour based 99 MW Turbine Nitrogen Oxides on a 720 hour rolling 0. 30 kg/MWh Exhaust Stack (expressed as NO ) output 2 average APPROVAL NO. 238762-00-00 Page 10 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

4.2.8 Visible emissions from any source shall not exceed an opacity of 20 percent averaged over one six consecutive minute period per hour.

4.2.9 For the purpose of calculation of the MWhoutput, as required in Table 4.2-B, the approval holder shall include both the combined total thermal energy and the net generation of electricity excluding any electricity used to produce the electricity

MONITORING AND REPORTING

4.2.10 The approval holder shall monitor as specified in TABLE 4.2-C.

4.2.11 The approval holder shall report as required in TABLE 4.2-C.

TABLE 4.2-C: SOURCE MONITORING AND REPORTING

EMISSION REPORTING SOURCE/ SAMPLING MONITORING METHOD OF FREQUENCY REPORT PARAMETER EFFLUENT FREQUENCY METHOD ANALYSIS (one copy TO STREAM required)

Concentration and mass Annual emission of summary and nitrogen oxides evaluation (expressed as Continuous CEM CEMS Code report, as NO ), instack 2 indicated in opacity, 4.2.13 temperature and 99 MW Turbine flow rate Director Exhaust stack

Before the end Nitrogen Oxides of the month (expressed as Alberta stack Manual stack following the NO ), Twice per year sampling 2 survey month in Temperature and code which the Flow Rate survey is done

4.2.12 The approval holder shall notify the Director in writing a minimum of two weeks prior to any manual stack survey that is required to be conducted by this approval. APPROVAL NO. 238762-00-00 Page 11 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

ANNUAL REPORTING 4.2.13 The approval holder shall submit to the Director by March 15 of each year an annual summary and evaluation report that contains for the previous year information related to: (a) an overview of the plant operation; (b) the total annual net production of the generating unit in MWh; (c) the total number of generating hours; (d) performance of air pollution control equipment; (e) air contaminant emissions; and (f) any other information as required by the Director. AMBIENT MONITORING AND REPORTING

4.2.13 The approval holder shall operate or cause to be operated the PASZA Air Quality Monitoring Program Network.

4.2.14 The approval holder shall submit or cause to be submitted monthly reports, which document the monitoring undertaken in 4.2.13, to the Director within 45 days from the end of each measured month.

4.2.15 The approval holder shall immediately apply to the Director to amend the ambient air monitoring and reporting requirements upon the occurrence of any of the following events:

(a) the approval holder ceases to actively participate in the PASZA Air Quality Monitoring Program Network;

(b) the PASZA Air Quality Monitoring Program Network ceases to operate; or

(c) the PASZA Air Quality Monitoring Program Network being amended without written acceptance from the Director. APPROVAL NO. 238762-00-00 Page 12 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

SECTION 4.3: INDUSTRIAL RUNOFF AND INDUSTRIAL WASTEWATER

OPERATIONS

4.3.1 The approval holder shall not release any substances from the plant to the surrounding watershed except as authorized by this approval.

4.3.2 All industrial runoff from the plant developed area shall be directed to the industrial runoff control system.

4.3.3 The approval holder shall only dispose of industrial runoff from the industrial runoff control system to the Meadowville Drainage II Project or as otherwise authorized in writing by the Director.

LIMITS

4.3.4 Releases from the industrial runoff control system shall not exceed the limits for the parameters specified in TABLE 4.3-A.

TABLE 4.3-A: INDUSTRIAL RUNOFF RELEASE LIMITS

PARAMETER LIMITS

pH 6.0 – 9.5 units Oil and Grease No visible sheen Total Suspended Solids 25 mg/l Chemical Oxygen Demand 50 mg/l

MONITORING AND REPORTING

4.3.5 Representative grab samples of water within the industrial runoff control system shall be obtained and analyzed for the parameters listed in TABLE 4.3-B prior to release.

4.3.6 The approval holder shall monitor the release of industrial runoff from the industrial runoff control system as required in TABLE 4.3-B throughout the release period.

4.3.7 The approval holder shall monitor and report as required in TABLE 4.3-B. APPROVAL NO. 238762-00-00 Page 13 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

TABLE 4.3-B: MONITORING AND REPORTING

MONITORING REPORTING PARAMETER, TEST, EVENT, STUDY REPORTING PROPOSAL OR PRIOR TO RELEASE DURING RELEASE TO FREQUENCY REPORTING REQUIREMENT Discharge volume in cubic Volume - Once/day A metres - estimate Annually - Representative grab Once/day Grab pH Once A sample sample Industrial Representative grab Once/day Grab Wastewater and Oil and Grease Once A sample sample Runoff Report (On or before Director Total Suspended Solids in Representative grab Once/week Grab th Once A March 15 of the mg/l sample sample year following the Chemical Oxygen Demand Representative grab Once/week Grab Once A year in which the in mg/l sample sample information was collected) A = Discharge point of industrial runoff control system

4.3.8 In addition to the annual reporting requirements in TABLE 4.3-B, the annual Industrial Wastewater and Runoff Report shall include the following information:

(a) an overview of the operation of the plant;

(b) a summary and evaluation of management and disposal of the industrial wastewater for the previous year;

(d) any other information as required by the Director.

SECTION 4.4: WASTE MANAGEMENT

4.4.1 Hazardous waste or hazardous recyclables stored in containers or tanks shall be stored in accordance with the Hazardous Waste Storage Guidelines, August 1999, Alberta Environment, as amended.

4.4.2 All containers and unrinsed empty containers shall be stored in the waste storage area.

4.4.3 The approval holder shall dispose of waste generated at the plant only to facilities holding a current Approval, Registration or as otherwise authorized under the Act, or to facilities approved by a local environmental authority outside of Alberta. APPROVAL NO. 238762-00-00 Page 14 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

MONITORING

4.4.4 The approval holder shall identify, characterize and classify all waste streams generated at the plant, not including air effluent streams.

4.4.5 The approval holder shall measure or, when not feasible to measure, estimate the quantity of each waste generated each year.

REPORTING

4.4.6 The approval holder shall compile all information required by 4.4.4 and 4.4.5 in an Annual Waste Management Summary Report as indicated in Table 4.4-A.

TABLE 4.4-A ANNUAL WASTE MANAGEMENT SUMMARY

Uniform Waste Code Quantity (kg or L) Stored Recycled Disposed Waste Name Non- On- On- Off- On- Off- WC PIN Class Mgmt Hazardous hazardous site site site site site

Total

4.4.7 The Annual Waste Management Summary Report shall be submitted to the Director by March 15th of the year following the year in which the information was collected.

SECTION 4.5: DOMESTIC WASTEWATER

4.5.1 The approval holder shall not release any substances from the domestic wastewater system to the surrounding watershed except as authorized by this approval.

4.5.2 The approval holder shall operate a domestic wastewater system which shall include, at a minimum, all of the following:

(a) a domestic wastewater collection system; and

(b) holding tank;

as described in the application, or as otherwise authorized in writing by the Director. APPROVAL NO. 238762-00-00 Page 15 of 15 .………......

TERMS, CONDITIONS AND REQUIREMENTS ATTACHED TO APPROVAL

4.5.3 The approval holder shall dispose of wastewater generated at the plant only to facilities holding a current Approval or Registration under the Act.

SECTION 4.6: WATERWORKS

Not used at this time.

SECTION 4.7: GROUNDWATER

Not used at this time.

SECTION 4.8: SOIL

Not used at this time.

PART 5: RECLAMATION

GENERAL 5.1: GENERAL

5.1.1 The approval holder shall apply for an amendment to this approval to reclaim the plant by submitting a Decommissioning and Land Reclamation Plan to the Director.

5.1.2 The Decommissioning and Land Reclamation Plan referred to in 5.1.1 shall be submitted within six months of the plant ceasing operation, except for repairs and maintenance, unless otherwise authorized in writing by the Director.

5.1.3 The approval holder shall implement the Decommissioning and Land Reclamation Plan as authorized by the Director.

signed by Gary Sasseville

DESIGNATED DIRECTOR UNDER THE ACT ENVIRONMENT

AMENDING APPROVAL

PROVINCE OF ALBERTA ENVIRONMENTAL PROTECTION AND ENHANCEMENT ACT R.S.A. 2000, c.E-12, as amended.

December /7,2008 EFFECTIVE DATE: ...... December 31,2017 EXPlRY DATE: ...... Grande Prairie Generation Inc. APPROVAL HOLDER: ......

Pursuant to Division 2, of Part 2, of the Environmental Protection and Enhancement Act, R.S.A.2000, c.E-12, as amended, the approval for the following activity:

Northern Prairie Thermal Electric Power Plant is amended as per the attached terms and conditions.

Designated Director under the Act

December /7,2008 Date Signed ...... APPROVAL NO. 238762-00-01 Page 1 of 2

TERMS AND CONDITIONS ATTACHED TO APPROVAL

Environmental Protection and Enhancement Act Approval No. 238762-00-00 is hereby amended as follows:

1. Notwithstanding Subsection 2.3.1(i)(D), prior to June 30, 2009, the approval holder shall collect air monitoring samples as per Application 003-238762 and the CEMS Monitoring Plan, dated October 3, 2008.

2. Table 4.2-C is repealed and the following is substituted:

TABLE 4.2-C SOURCE MONITORING AND REPORTING

EMISSION REPORTING SOURCE 1 SAMPLING MONITORIN METHOD OF FREQUENCY REPORT PARAMETER EFFLUENT FREQUENCY G METHOD ANALYSIS (one copy TO STREAM required)

Concentration and mass As per emission of Application and nitrogen oxides CEMS Continuous (expressed as Monitoring Plan. June 30,2009 dated October 99 MW NO>), temperature, 3,2008 Turbine and flow rate Director Exhaust Stack Nitrogen Before the end Oxides of the month Manual (expressed as Once prior to Alberta stack following the Stack June 30,2009 sampling code month in which N 02), Sun/ey temperature the survey is and flow rate done

After June 30,2009

Concentration and mass Annual emission of summary and nitrogen oxides evaluation Continuous CEM CEMS Code (expressed as report, as indicated in 99 MW N02h temperature, 4.2.13 Turbine and flow rate Director Exhaust Stack - Nitrogen Before the end Oxides of the month Manual (expressed as Twice per Alberta stack following the Stack year sampling code month in which N02), Survey temperature the survey is and flow rate done APPROVAL NO. 238762-00-01 Page 2 of 2

TERMS AND CONDITIONS ATTACHED TO APPROVAL

4.2.12.1 Manual stack surveys required under Table 4.2-C shall be conducted when the plant is operating at not less than 80% of its rated nominal capacity of 99 MW, unless authorized in writing by the Director.

DATED December ITj! 2008 ENVIRONMENT

AMENDING APPROVAL

PROVINCE OF ALBERTA ENVIRONMENTAL PROTECTION AND ENHANCEMENT ACT R.S.A. 2000, c.E-12, as amended.

January 9 , 2009 EFFECTIVE DATE: ...... December 31, 2017 EXPIRY DATE: ...... Grande Prairie Generation Inc. APPROVAL HOLDER: ......

Pursuant to Division 2, of Part 2, of the Environmental Protection and Enhancement Act, R.S.A.2000, c.E-12, as amended, the approval for the following activity:

Northern Prairie Thermal Electric Power Plant is amended as per the attached terms and conditions.

Designated Director under the Act ....55: ...... k.1-43 Gary Sasseville

January 9 , 2009 Date Signed ...... APPROVAL NO. 238762-00-02 Page 1 of 1

TERMS AND CONDITIONS ATTACHED TO APPROVAL

Environmental Protection and Enhancement Act Approval No. 238762-00-00 is hereby further amended as follows:

1. Table 4.2-C is repealed and the following is substituted:

TABLE 4.2-C SOLlRCE MONITORING AND REPORTING

EMISSION REPORTING SOURCE 1 SAMPLING MONITORING METHOD OF FREQUENCY REPORT PARAMETER EFFLUENT FREQUENCY METHOD ANALYSIS (one copy TO STREAM required)

Prior to June 30,2009

Concentration As per and mass Application emission of and CEMS Monthly, before nitrogen oxides Continuous CEM Monitoring the end of the (expressed as Plan, dated next month N02), October 3, 99 MW temperature, Turbine 2008 and flow rate Director Exhaust 1 Stack I I I I Nitrogen 1 Before the end 7 Oxides of the month Alberta stack (expressed as Once prior to Manual Stack following the sampling June 30,2009 Survey month in which Nod, code temperature the survey is and flow rate done

I I I I 1 I After June 30,2009 1 Concentration and mass emission of Monthly before nitrogen oxides Continuous CEM CEMS Code the end of the (expressed as next month NOz), 99 MW temperature, Turbine and flow rate Director Exhaust Stack --- Nitrogen Before the end Oxides of the month A'berta stack (expressed as Twice per Manual Stack following the Survey month in which Nos), year code temperature the survey is and flow rate done

,<' iJ~hL DATED Januarv ,2009 (' A!+- DESIGNATED DIRECTOR UNDER THE ACT Grande Prairie Generation, Inc. March 2015 Northern Prairie Power Project AUC Rule 007 Power Plant Application

ATTACHMENT C

SYSTEM ACCESS SERVICE REQUEST DOCUMENTATION

Attachments

Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

Information Documents are not authoritative. Information Documents are provided for information purposes only and are intended to provide guidance. In the event of any discrepancy between an Information Document and any Authoritative Document(s) in effect, the Authoritative Document(s) governs. 1 Purpose This information document relates to the following Authoritative Document:1 Section 302.1, Real Time Transmission Constraint Management. The purpose of this Information Document is to provide additional information regarding the unique operating characteristics and resulting constraint conditions and limits in two (2) regions in the northwest area. In this information document the AESO has defined the northwest area as the area illustrated by the maps in Appendix 2 and 3. 2 Related Authoritative Documents The AESO’s authoritative documents consist of ISO rules, the ISO tariff and the Alberta Reliability Standards. Authoritative documents contain binding rights, requirements and obligations for market participants and the AESO. Market participants and the AESO are required to comply with provisions set out in authoritative documents. The AESO encourages market participants to review the related authoritative documents which include: (1) Section 302.1 of the ISO rules, Real Time Transmission Constraint Management. This section of the ISO rules sets out the general constraint management protocol steps the AESO uses to manage constraints in real time on the interconnected electric system. These steps are referenced in Table 1 of this information document as they are applied to the northwest area. 3 General The northwest area consists of long 144 kV and 240 kV bulk transmission lines, generally with a low degree of redundancy of transmission paths. The northwest area total generating capacity is substantially less than the area load, leading to inflows of energy under normal operation. Some of the 144 kV bulk transmission lines are heavily loaded. The outage of a single bulk transmission line or a generating unit may result in voltage depressions outside of the acceptable system operating limits set out in Alberta Reliability Standard TPL-002-AB-0 – System Performance Following the Loss of a Single BES Element. The AESO can partially mitigate this risk by ensuring a sufficient minimum amount of transmission must-run generating unit capacity is available under contract with the AESO. The availability of transmission must-run services reduces the risk of losing firm load due to low voltages and of a voltage collapse for certain critical transmission or generation contingencies. Two (2) maps of the northwest area are provided in Appendix 2 and 3. Appendix 2 provides a detailed geographical map of the northwest area indicating bulk transmission lines, substations and cutplanes. Appendix 3 provides a detailed view of the northwest area cutplanes including the generating units effective in managing the regional constraints through transmission must-run dispatch or directive. A cutplane is a common term used in engineering studies and is a theoretical boundary or plane crossing two (2) or more bulk transmission lines or electrical paths. The cumulative power flow across the cutplane is measured and can be utilized to determine flow limits that approximate conditions that would allow safe, reliable operation of the interconnected system.

1 “Authoritative Documents” is the general name given by the AESO to categories of documents made by the AESO under the authority of the Electric Utilities Act and regulations, and that contain binding legal requirements for either market participants or the AESO, or both. Authoritative Documents include: the ISO rules, the Alberta reliability standards, and the ISO tariff. Information Document Page 1 Posting: 2014-07-29

Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

4 Constraint Conditions and Limits When managing a transmission constraint in the northwest area of Alberta which results from the total generating capacity of the area being substantially less than the area load, the AESO uses regional cutplane inflow limits to manage area reliability. The AESO calculates the cutplane inflow limits for the Grande Prairie and Rainbow cutplanes in accordance with voltage requirements and bulk transmission line transfer limits. A further description of these limits is set out below. 4.1 Studied Constraints and Limits Cutplane Inflow Limits There are two (2) cutplanes in the northwest area; one (1) for the Grande Prairie region and one (1) specific to the Rainbow Lake region. These cutplanes are reflected on the maps in Appendix 2 and 3. As mentioned above, the northwest area generation capacity is substantially less than the area load, which leads to inflows of energy into the northwest area under normal circumstances. The specific contingency conditions and inflow limits are set out in Appendix 4 and 5 of this information document. The limits in Appendix 4 are not absolute limits as certain generating units operating at or above minimum stable generation can provide a slight increase to the limits. The scenarios that provide an increase to the limits are set out in Appendix 5 of this information document. Operating Modes and Limits If the Poplar Hill or Valley View # 1 generating units are either generating MW or operating in synchronous condenser mode, the AESO increases the Grande Prairie cutplane inflow limits by the amount specified in Appendix 5 of this information document. The increases contemplated in Appendix 5 are only applicable when there is a net power transfer-out of the northeast area as measured on the Dover - Ruth Lake cutplane in the northeast area under N-0 and N-1 conditions. Due to angular stability and voltage concerns, there is a need for the AESO to issue directives or dispatches for transmission must-run in the northwest area to ensure that the system operating limits and dynamic reactive reserve requirements for the Rainbow region are met. These reactive reserve requirements are set out in Appendix 6. 5 Transmission Constraint Management While the AESO manages transmission constraints in all areas of Alberta in accordance with the provisions of section 302.1 of the ISO rules, not all of those provisions are effective in the northwest due to certain unique operating conditions that exist in that area. This information document represents and clarifies the application of the general provisions of section 302.1 to the northwest area. The Fort Nelson connection is unique and the curtailment of Fort Nelson load requires additions steps which are set out below. The protocol steps which are effective in managing transmission constraints are outlined in Table 1 below, followed by additional steps which may be required. Table 1 Transmission Constraint Management Sequential Procedures for the Northwest Area Applicable to the Applicable to the Section 302.1 of the ISO rules, subsection 2(1) Grande Prairie cutplane Rainbow cutplane protocol steps inflow? inflow? (a) Determine effective pool assets Yes Yes (b) Ensure maximum capability not exceeded No No (c) Curtail effective downstream constraint side No No export service and upstream constraint side Information Document Page 2 Posting: 2014-07-29

Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

import service (d) Curtail effective demand opportunity No No service on the downstream constraint side (e)(i) Issue a dispatch for effective contracted Yes Yes transmission must-run (e)(ii) Issue a directive for effective non- Yes Yes contracted transmission must-run (f) Curtail effective pool assets in reverse energy market merit order followed by pro-rata No No curtailment (g) Curtail effective loads with bids in reverse energy market merit order followed by pro-rata Yes Yes load curtailment Applicable Protocol Steps The first step in managing constraints in any area is to identify those generating units effective in managing the constraint. All generating units and loads operating in the northwest area are indicated in Appendix 3 (single line diagram), the generating units effective in managing constraints are identified in Appendix 1. Step (a) in Table 1 The effective pool assets are as shown in Appendix 1. Step (b) in Table 1 Ensuring maximum capabilities are not exceeded is not applicable to the northwest due to the deficiency of generation and inflow scenario. Step (c) in Table 1 There is no effective export or import opportunity service to curtail for either the Grande Prairie or Rainbow cutplane. Step (d) in Table 1 There is no demand opportunity service load in the area to curtail. Steps (e)(i) and (ii) in Table 1 Issue dispatches to effective contracted pool assets or directives to effective non-contracted pool assets for transmission must-run. Step (f) in Table 1 Reverse merit order curtailment is not effective and therefore not required because the constraint is caused by not having enough in-merit generation in the downstream constrained area. Step (g) in Table 1 Curtailing effective loads with bids in reverse energy market merit order followed by pro-rata load curtailment is available for both Grande Prairie and Rainbow cutplanes. Additional Steps Due to the operating characteristics of the northwest area, when managing a transmission constraint on the Rainbow cutplane, the AESO may utilize the following additional procedures: Information Document Page 3 Posting: 2014-07-29

Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

(i) curtail applicable load in accordance with the provisions of the contract between the AESO and the British Columbia Hydro and Power Authority (addressing Fort Nelson operation), after implementing step (e)(i) in Table 1 set out in subsection 3(1); and (ii) if necessary to maintain Rainbow area voltage levels, follow the Grande Prairie cutplane curtailment procedure. 6 Project Updates As necessary, the AESO intends to provide information in this section about projects underway in the northwest area that are known to have an impact on the information contained in this information document. 7 Appendices to this Information Document Appendix 1 – Effective Pool Assets Appendix 2 – Geographical Map of the Northwest Area Appendix 3 – Northwest Area Cutplanes Single Line Diagram Appendix 4 – Grande Prairie Cutplane Limits Appendix 5 – Grande Prairie Cutplane Inflow Limits and Operating Mode Appendix 6 – Rainbow Lake Cutplane Requirements Revision History Version Posting Date Description of Changes 1.0 2011-06-30 Initial Release 2.0 2012-03-03 Updated to reflect transmission upgrades in the area 3.0 Updated to include material content from existing section 302.4 of 2012-06-14 the ISO rules, Northwest Area Transmission Constraint Management 4.0 Updated to include minor drafting edits 5.0 2012-08-31 Updated to include Table 4 which reflects changes to the Rainbow Lake Cutplane limits and Dynamic Reactive Reserve requirements. 6.0 2013-01-01 Updated Table 4 to reflect changes to the Rainbow Lake Cutplane 2013-02-14 limit and Dynamic Reactive Reserve requirements. Minor drafting edit to geographical map. 7.0 Appendices 1 and 3 amended to reflect the decommissioning of 2014-04-03 assets ST1 and ST2. 8.0 Appendix 2 amended to reflect the addition of Chickadee Creek 2014-05-12 259S 9.0 2014-07-29 Subsection 4.1 updated and Appendix 7 removed in its entirety to reflect the elimination of generation capacity limits for Poplar Hill and Northern Prairie Power Project.

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Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

Appendix 1 - Effective Pool Assets The effective generation pool assets for the Grande Prairie cutplane2, listed alphabetically by their pool IDs, are: BCR2 BRCK DAI1 GPEC NPC1 NPP1 PH1 VVW1 The effective generation pool assets for the Rainbow cutplane, listed alphabetically by their pool IDs, are: FNG RB1 RB2 RB3 RB5 RL1

2 An operational study in this area is being conducted and the effective pool assets will be updated following the study.

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Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

Appendix 2 – Geographical Map of the Northwest Area

Zama Lake 795S

7L72

Sulphur Point High Level 828S 7L133 786S Rainbow Lake 7L93 7L76 Blumenort 1L359 7L81 791S 832S 7L109 Melito SVC Fort Nelson Arcenciel Bassett 890S 7L122 852S 930S 747S

7L59 SVC 7L64 Chinchaga 779S 7L113 Haig River 748S Keg River Ring Creek 789S 853S Kemp River 797S Rainbow Lake cutplane (RLC)

7L58 7L62 7L82 Hamburg 855S 7L63 Hotchkiss Meikle 788S 7L120 783S 878S 7L138 905S Kidney Lake

7L63

7L51 7L131 7L106 812S 7L94 861S Eureka River 839S 830S SVC 6L16 724S 827S 7L12 869S 780S Cranberry To Britnell 876S Lake 6L37 7L27 Wesley Creek Lubicon 7L75 793S 7L61 9L15 West 834S Peace 796S 829S 800S Fredenstal Grande 7L73 7L48 9L11 7L23 Prairie cutplane 858S 754S 7L10 730S 784S Ksituan Rycroft 720S 9L56 882S 6L99 865S 7L68 6L91 6L73 7L162 844S 790S 6L68 787S 727S 745S Poplar Hill 7L49 732S 815S 729S 811S Goodfare 7L22 728S Clairmont 862S 734S 6L57 7L07 749S 7L03 722S 7L32 7L57 794S 758S 808S 739S 735S 9L40 731S 736S Elmworth 845S 798S Little Smoky 9L913 7L45/7L46 854S 744S 823S Big Mountain 813S 742S SVC 725S 7L56 7L20 7L40 809S 9L02, 9L05 743S 7L90 738S 851S 7L230

824S 69S 234S 810S 733S 7L199 Dome 741S 9L939 Fox 9L938 7L80 Creek 347S 72kV 199L 720L 144kV HR 236S 77S 240kV Milner 397S 199AL 740S 857S To 854L Whitecourt To Bickerdike Chickadee 323S 39S Creek 259S

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Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

Appendix 3 – Northwest Area Cutplane Single Line Diagram

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Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

Appendix 4 – Grande Prairie Cutplane Limits Table 1 Grande Prairie Cutplane Limit for a Northeast area Export Grande Prairie Cutplane Limit for a Northeast area Export Maximum Grande Prairie area load studied 860 MW To increase the Grande Prairie import limit add the synchronous condenser Contingency mode effect (Table 3) Conditions HR Milner = 70MW 70 MW < HR Milner < 140 MW HR Milner ≥140 MW X = HR Milner output – 70 MW

No contingencies 585 585 – (0.71 * X) 535

GPEC or 590 590 – (0.79 * X) 535 BCR2 steam

9L11 610 610 – (0.93 * X) 545

9L15 585 585 – (0.57 * X) 545

9L02 or 9L05 485 485 485

919L or 989L 470 470 – (0.21 * X) 455

9L938 or 9L939 485 485 485

9L40 570 570 – (0.93 * X) 505

9L56 600 600 – (0.79 * X) 545

9L913 545 545 – (0.79 * X) 490

7L56 600 600 – (0.57 * X) 560

7L90 600 600 – (0.57 * X) 560

7L23 575 575 – (0.71 * X) 525

7L61 595 595 – (0.57 * X) 555

6L57 610 610 - (0.79 * X) 555

HR Milner < 70 590 590 590 MW Little Smoky static 565 565 – (1.29 * X) 475 VAr compensator Cranberry static 595 595 – (1 * X) 525 VAr compensator

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Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

Examples to assist with interpretation of Table 1: 1. If HR Milner is generating at 70 MW and transmission line 9L15 is out of service then the power flow limit into the northwest is 585 MW. 2. If HR Milner is generating at 100 MW and the region load is less than 860 MW, and transmission line 9L15 out of service then the power flow limit into the northwest is calculated as 585 – (0.57*(100 – 70)) = 567.9 MW. 3. If HR Milner is generating at 140 MW and transmission line 9L15 is out of service then the power flow limit into the northwest is 545.

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Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

Table 2 Grande Prairie Cutplane Limit for a Northeast area Import Grande Prairie Cutplane Limit for a Northeast area Import Maximum Grande Prairie area load studied 860 MW Contingency HR Milner=70 MW 70 MW < HR Milner < 140 MW HR Milner ≥140 MW Conditions X = HR Milner output – 70 MW

No contingencies 565 565 – (0.36 * X) 540

GPEC or 555 555 – (0.21 * X) 540 BCR2 steam

9L11 590 590 – (0.64 * X) 545

9L15 545 545 545

9L02 or 9L05 440 440 440

919L or 989L 405 405 405

9L938 or 9L939 460 460 460

9L40 530 530 – (0.71 * X) 480

9L56 575 575 – (0.29 * X) 555

9L913 550 550 – (1.43 * X) 450

7L56 570 570 570

7L90 570 570 570

7L23 550 550 – (0.36 * X0 525

7L61 560 560 560

6L57 580 580 – (0.29 * X) 560

HR Milner < 70 MW 560 560 560

Little Smoky static 540 540 – (1.14 * X) 460 VAr compensator Cranberry static 570 570 – (0.86 * X) 510 VAr compensator

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Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

Examples to assist with interpretation of the Table 2: 1. If HR Milner is generating at 70 MW and transmission line 9L11 is out of service then the power flow limit into the northeast is 590 MW. 2. If HR Milner is generating at 100 MW and the region load is less than 860 MW, and transmission line 9L11 out of service then the power flow limit into the northeast is calculated as 590 – (0.64*(100 – 70)) = 570.8 MW. 3. If HR Milner is generating at 140 MW and transmission line 9L11 is out of service then the power flow limit into the northeast is 545 MW.

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Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

Appendix 5 –Grande Prairie Cutplane Inflow Limits and Operating Mode Table 3 below sets out the power flow limits if the Poplar Hill or Valley View (VVW1) generating units are operating in either synchronous condenser mode or MW generation mode: Table 3 Increase to Grande Prairie Transfer Limit IF the Northeast area is Exporting PH1 in VVW1 in Both PH1 and VVW1 in synchronous synchronous synchronous condenser condenser condenser mode or System Conditions mode or both generating mode or either VVW 2 1 stations are generating generating generating unit is 1 MW MW generating MW System normal +30 +20 +45 HR Milner contingency +10 +0 +20 Note: 1. Generating units are considered in generating mode if they are above their minimum stable generation. 2. It is accepted that any combination of the following meets this requirement: a. PH1 is on synchronous condenser mode/generating MW; or b. VVW1 is on synchronous condenser mode or either VVW1 or Valley View 2 generating units are generating power. Examples to assist with interpretation of Table 3: 1. For any limit calculated in Appendix 4 and when VVW1 is in synchronous condenser mode or is generating MW, for system normal conditions, the limit calculated from Appendix 4 is increased by 20 MW. 2. For any limit calculated in Appendix 4, if PH1 is generating at some level or in synchronous condenser mode, and HR Milner is out of service, the cutplane limit is increased by 10 MW.

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Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

Appendix 6 – Rainbow Lake Cutplane and Dynamic Reactive Reserve Requirements Table 4 sets out the Rainbow Lake cutplane and the dynamic reactive reserve requirements. Table 4

Minimum Minimum Dynamic Dynamic Rainbow Lake Rainbow Lake 1 Reactive 1 Reactive Cutplane Limit 2 Cutplane Limit 2 Reserve Reserve Operating State3 (MVAr) (MVAr)

No Either Synchronous Condenser or A Synchronous Condenser or a Rainbow unit on line Rainbow unit is on line

130Summer / 155Winter “N-0” System Normal 103 MW 30 MVAr 30 MVAr (See Note 1)

130Summer / 155Winter N-1: Arcenciel SVC Out 103 MW 30 MVAr 30 MVAr (See Note 1)

130Summer / 155Winter N-1: High Level SVC Out 103 MW 30 MVAr 30 MVAr (See Note 1)

128 MW N-1: 7L131 or 7L106 Out 83 MW 20 MVAr 30 MVAr (See Note 1) 71Summer / 80Winter 71Summer / 80Winter 30 MVAr N-1: 7L82 or 7L113 Out 20 MVAr (See Note 1) (See Note 1)

N-1: 7L64 Out 83 MW 20 MVAr 83 MW 20 MVAr

75Summer / 86Winter 75Summer / 86Winter N-1: 7L59 or 7L93 Out 20 MVAr 20 MVAr (See Note 1) (See Note 1) N-1: 7L58 or 7L62 Out 83 MW 38 MVAr 83 MW 38 MVAr Notes: 1. The Rainbow Lake cutplane operating limits are based on voltage stability and thermal limits. Thermal limits are illustrated when summer and winter limits have been identified. 2. The dynamic reactive reserve units are: Arcenciel Static Var Contoller (desired range: 0 to -5), Arcenciel Synchronous Condenser, High Level Static Var Contoller (desired range: 0 to -5), Rainbow generators.

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Information Document Northwest Area Transmission Constraint Management ID # 2011-004R

3. An unstudied state occurs when two elements in the above table are out of service. Real time limits are determined using the energy management system advanced applications contingency analysis or voltage stability application.

Information Document Page 14 Posting: 2014-07-29

100 Constellation Way Suite 500C Baltimore, Maryland 21202 Constellation~

August 14, 2014

Catherine Fabian Energy Market Advisor Operations Support Alberta Electric System Operator 2500, 330- 5th Avenue SW Calgary, AB T2P OL4

Subject: Change Request to Existing System Access Service at Grande Prairie Generation, Inc.

Dear Catherine:

The intent of this letter is to initiate the process with the Alberta Electric System Operator ("AESO") to formally increase the contract capacity of an existing system access service agreement for Grande Prairie Generation, Inc. ("NPP1"). Currently, NPP1 is under contract for 93 MWs of Supply Transmission Service ("STS") and is requesting an increase of its STS to 105 MWs.

Please contact me at 410-470-2339 or [email protected] if you have any questions or require any additional information regarding this matter.

Best regards, ~~/ Don Schopp Principal Compliance Analyst Exelon Generation Company, LLC

Grande Prairie Generation, Inc. March 2015 Northern Prairie Power Project AUC Rule 007 Power Plant Application

ATTACHMENT D

DISPERSION MODELLING ASSESSMENT

Attachments

Dispersion Modelling Assessment Grande Prairie Generation, Inc. Northern Prairie Power Project Approval No. 238762-00-02

Commissioned for: Grande Prairie Generation, Inc. 1005 Brandon Shores Road Baltimore, MD 21226

Prepared by:

North Shore Environmental Consultants Inc. 120, 3132 - 118 Avenue S.E. Calgary, Alberta T2Z 3X1

Grande Prairie Generation, Inc. Dispersion Modelling Assessment Northern Prairie Power Project March 2015

EXECUTIVE SUMMARY

Grande Prairie Generation, Inc. (GPG), a wholly-owned subsidiary of Exelon Corporation, owns and operates the Northern Prairie Power Plant (the Power Plant). The Power Plant operates under Alberta Utilities Commission (AUC) Power Plant Approval U2017-218 and Alberta Environment and Sustainable Resource Development (AESRD) Environmental Protection and Enhancement Act (EPEA) Approval Number 238762-00-02. The Power Plant operates a General Electric (GE) Model MS7001/EA (Frame 7EA) natural gas-fired turbine. The turbine-generator has a nominal output of 85 MW. The turbine- generator is capable of generating 105 MW of electricity under its current configuration; however, constraints on the electric system limit the generator output to 99 MW.

The requested change is purely administrative in nature as there will be no change to the design of the Power Plant. The Power Plant is currently authorized under the EPEA Approval 238762-00-02 to emit up to 0.030 t/h of NOx. Furthermore, emissions from the turbine are required to remain within the limit of 0.3 kg/MWh output required by the Alberta Air Emissions Standards for Electricity Generation and AESRD EPEA Approval Number 238762-00-02. Emissions from the turbine will remain within the existing authorized emission limits. As such, the public and stakeholders will not be affected by this change.

Although there will not be a change to the authorized emission limit, GPG has elected to update the dispersion modelling assessment for NOx to ensure that ground-level concentrations of NO2 will be within the latest Alberta Ambient Air Quality Objectives when modelling in accordance with the latest Air quality Model Guideline (AQMG).

This dispersion modelling assessment conforms to the requirements of the AQMG and used the AERMOD V14134 dispersion model. This report was prepared in accordance with the requirements outlined in the AQMG (October 2013).

The results of this dispersion modelling assessment indicate that ground-level concentrations of NO2 from all sources are predicted to comply with the Alberta Ambient Air Quality Objectives (AAAQO).

North Shore Environmental Consultants Inc. Executive Summary Grande Prairie Generation, Inc. Dispersion Modelling Assessment Northern Prairie Power Project March 2015

TABLE OF CONTENTS ABBREVIATIONS ...... 3

1.0 INTRODUCTION ...... 4

2.0 SETTING ...... 4

2.1 Topography ...... 4 2.2 Vegetation ...... 5 2.3 General Climatology ...... 5 2.4 Population and Public Use ...... 5 3.0 DISPERSION MODELLING APPROACH ...... 5

3.1 Model ...... 5 3.2 Meteorology ...... 6 3.3 Terrain ...... 6 3.4 Receptor Grid ...... 6 3.5 Building Downwash ...... 6 3.6 Background Concentrations ...... 6 4.0 EMISSION SOURCES ...... 7

4.1 Plant Emission Sources ...... 7 4.1.1 NOx Emission Source ...... 7 4.2 Background Emission Sources ...... 7 5.0 DISPERSION MODELLING RESULTS ...... 7

5.1 Air Quality Criteria ...... 7

5.2 NO2 Modelling Results ...... 8

5.3 NOx Modelling Results ...... 8 6.0 CONCLUSION ...... 9

7.0 CLOSURE ...... 10

8.0 REFERENCES ...... 11

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Grande Prairie Generation, Inc. Dispersion Modelling Assessment Northern Prairie Power Project March 2015

LIST OF TABLES Table 1. Air Quality Criteria ...... 7

Table 2. Summary of Predicted NO2 Maximum Ground Level Concentration ...... 8

Table 3. Summary of Predicted NOx Maximum Ground Level Concentration ...... 8 Table 4. Power Plant Source Emission Rates and Physical Parameters ...... 13 Table 5. NOx Background Source Emission Rates and Physical Parameters ...... 14

LIST OF FIGURES

Figure 1. Project Area Map ...... 16 Figure 2. Topographical Maps of the Project Area ...... 18 th Figure 3. 105 MW - 9 highest 1-Hour NO2 Concentration Isopleth ...... 21 st Figure 4. 105 MW - 1 highest annual NO2 Concentration Isopleth ...... 23 th Figure 5. 0.030 t/h - 9 highest 1-Hour NO2 Concentration Isopleth ...... 25 st Figure 6. 0.030 t/h - 1 highest annual NO2 Concentration Isopleth ...... 27

APPENDICES Appendix A - Emission Parameters and Background Sources Appendix B - Project Area Maps and Concentration Isopleths Appendix C - AERMOD Output Files

North Shore Environmental Consultants Inc. TOC

Grande Prairie Generation, Inc. Dispersion Modelling Assessment Northern Prairie Power Project March 2015

ABBREVIATIONS

AAAQO Alberta Ambient Air Quality Objectives AER Alberta Energy Regulator AESO Alberta Electric System Operator AESRD Alberta Environment and Sustainable Resource Development AQMG Alberta Air Quality Modelling Guideline AUC Alberta Utilities Commission EPA Environmental Protection Agency EPEA Alberta Environmental Protection and Enhancement Act GE General Electric GPG Grande Prairie Generation Inc. MGLC maximum ground level concentration

NO2 nitrogen dioxide North Shore North Shore Environmental Consultants Inc.

NOx total oxides of nitrogen the Power Plant Northern Prairie Power Plant US United States

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1.0 INTRODUCTION

GPG has applied to the Alberta Electric System Operator (AESO) to remove the operating constraints. Authorization from AESO is expected in March 2015. Clause 2 of AUC Power Plant Approval U2007-218 specifies the Power Plant has a ‘total generating capacity’ of 85 MW. Once the generating constraints issued by AESO are removed, GPG is seeking authorization to operate the turbine-generator at the maximum generating capacity of 105 MW. As such, GPG is hereby applying under Section 10 of AUC Rule 007 to amend the Clause 2 of AUC Power Plant Approval U2007-218 to change total generating capacity from the existing 85 MW to 105 MW.

The requested change is purely administrative in nature as there will be no change to the design of the Power Plant. The Power Plant is currently authorized under the EPEA Approval 238762-00-02 to emit up to 0.030 t/h of NOx. Furthermore, emissions from the turbine are required to remain within the limit of 0.3 kg/MWh output required by the Alberta Air Emissions Standards for Electricity Generation and AESRD EPEA Approval Number 238762-00-02. Emissions from the turbine will remain within the existing authorized emission limits. As such, the public and stakeholders will not be affected by this change.

2.0 SETTING

The Power Plant is located approximately 30-km north-west of the city of Grande Prairie at LSD SE ¼-19- 073-08 W6M. Project area map is provided in Figure 1.

2.1 Topography

The Power Plant is located in the Dry Mixedwood Natural Subregion, which is the second largest Natural Subregion in Alberta. Elevations range from 200-m along the Peace River in the north-east, to 1,225-m west of Sundre. The dominant terrain type is level to gently undulating glacial till or lacustrine plains (Natural Regions Committee 2006). The elevation of the Power Plant is approximately 743-m.

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2.2 Vegetation

The vegetation in the Dry Mixedwood Natural Subregion is characterized by aspen forest and cultivated landscapes. Fens commonly occur in low-lying areas. Aspen forests with mixed understories of rose, low-bush cranberry, beaked hazelnut and Canada buffaloberry are typical in uplands. Jack pine stands occur on dry and well drained glaciofluvial and eolian parent materials. Treed, shrubby or sedge- dominated fens occupy the remaining 15 percent of the Subregion (Natural Regions Committee 2006).

2.3 General Climatology

The Dry Mixedwood Natural Subregion has the warmest summers and highest growing degree-day accumulations of any of the boreal Natural Subregion. It is the most southerly boreal Natural Subregion and it receives more solar energy than the other boreal Natural Subregions. Temperature and precipitation patterns are moderate compared to the other Natural Subregions. Approximately 70% of the annual precipitation falls between April and August, with peak precipitation in June and July.

The average annual total precipitation is 461 mm. The mean date of the first fall frost is September 4 and the date of the last spring frost is May 30. On average, the frost free period spans 98 days. The mean temperature ranges from 15.9°C at the warmest and -16.8°C at the coldest. The mean annual temperature is 1.1°C (Natural Regions Committee 2006).

2.4 Population and Public Use

Over 50% of the Dry Mixedwood Natural Subregion has been cultivated. The crops grown in this Subregion include barley, forage, oilseeds, wheat, and forage seed production.

Significant aspen harvesting occurs in this Subregion for pulp and paper production, and incidental conifer production. Oil and gas activity is a major land use as well, with heavy oil in the north and conventional oil and gas production in the west. Pit mining for thermal coal also occurs. Hunting and fishing are popular activities throughout the area (Natural Regions Committee 2006).

3.0 DISPERSION MODELLING APPROACH

3.1 Model

The air dispersion model was performed according to the requirements of the Alberta Air Quality Modelling Guideline (AQMG) (August 2013) and used the AERMOD V14134 dispersion model. AERMOD is a multi-source, steady state plume model that was developed by the United States (US) Environmental Protection Agency (EPA) in collaboration with the American Meteorological Society. More information on the AERMOD model can be found at:

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http://www.epa.gov/scram001/7thconf/aermod/aermod_mfd.pdf

The AERMOD input and output files are provided in Appendix C.

3.2 Meteorology

Five years of meteorological data were extracted from the Alberta Environment and Sustainable Resource Development (AESRD) Fifth Generation NCAR/Penn State Mesoscale Model V3.5 (MM5). The MM5 data was processed by AERMET, the meteorological data pre-processor for the AERMOD model.

3.3 Terrain

Canadian Digital Elevation Data was extracted from GeoGratis Canada and processed by AERMAP, the terrain pre-processor for the AERMOD model.

3.4 Receptor Grid

The receptor grids considered in this assessment are as follows:

. 20-m receptor spacing from the origin . 50-m receptor spacing within 0.5 km from the origin . 250-m receptor spacing within 2.5 km from the origin . 500-m spacing within 5 km from the origin . 1000-m spacing beyond 5 km

3.5 Building Downwash

Building downwash effects from all buildings within the applicable area of influence at the Power Plant were included in the assessment.

3.6 Background Concentrations

In accordance with the AQMG, background concentrations are added to the concentrations predicted by the model for a more accurate representation of ground-level concentrations.

The closest monitoring station for NO and NOx is the Beaverlodge Monitoring station, located approximately 19-km south-east of the Power Plant. Measured 1-hour values from January 1, 2013 to December 31, 2014 were used to estimate the 90th percentile concentrations for each averaging period. th The calculated 90 percentile background concentrations of NO2 and NOx were then added to the ground-level concentrations predicted by the dispersion modelling.

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4.0 EMISSION SOURCES

4.1 Plant Emission Sources

Table 4 (see Appendix A) outlines the physical parameters for the existing sources at the Power Plant.

4.1.1 NOx Emission Source

The Power Plant operates a General Electric (GE) Model MS7001/EA (Frame 7EA) natural gas-fired turbine. The turbine-generator has a nominal output of 85 MW. The turbine-generator is capable of generating 105 MW of electricity under its current configuration; however, constraints on the electric system limit the generator output to 99 MW. The Power Plant is currently authorized under the EPEA

Approval 238762-00-02 to emit up to 0.030 t/h of NOx.

Two scenarios were modelled:

1) 105 MW – Source parameters were scaled up based on increasing generator output from 99 MW to 105 MW. 2) 0.030 t/h – Source parameters were scaled up based on increasing generator output from 99 MW to 105 MW, however, the emission rate was set as the maximum of 0.030 t/h of NOx.

4.2 Background Emission Sources

There are several notable background NOx emission sources within five kilometers of the Power Plant: ATCO Poplar Hill Generating Plant, ConocoPhillips Wembley Sour Gas Plant, ConocoPhillips Compressor Stations 06-21 and 10-31, and Encana Oil and Gas Co. Ltd. Source and emission parameters for all background emissions sources are summarized in Table 5 (see Appendix A). These background sources are included in the dispersion modelling results for NO2 and NOx.

5.0 DISPERSION MODELLING RESULTS

5.1 Air Quality Criteria

Table 1 indicates the Alberta Ambient Air Quality Objectives (AAAQO) that were applied.

Table 1. Air Quality Criteria

Substance Averaging Period Units Criteria Source 1-hour µg/m3 300 AAAQO NO 2 Annual µg/m3 45 AAAQO

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5.2 NO2 Modelling Results

Dispersion modelling for NO2 was completed using the Total Conversion Method to convert NOx to NO2.

This is a conservative screening approach, where the emission rate of all NOx species is used in the dispersion model to predict ground-levels concentrations of total NOx. The levels of NOx are assumed to exist as total NO2.

Table 2 presents the ground-level concentrations of NO2 predicted by the dispersion modelling. As indicated in Table 2, all maximum predicted ground-level concentrations (MGLC) of NO2 are predicted to comply with the AAAQOs. The locations of the MGLCs are shown in Table 2. Isopleths for the one-hour and annual averaging periods for both scenarios are shown in Figure 3 to Figure 6.

Table 2. Summary of Predicted NO2 Maximum Ground Level Concentration

Location Predicted Background Averaging MGLC AAAQO Scenario UTM NAD83 Zone 11N NO Concentration Period 2 (m E) (m N) (µg/m3) (µg/m3) (µg/m3) (µg/m3) 1-hour 362462.20 6134342.97 271.45 23.32 294.77 300 1) 105 MW Annual 362568.45 6134344.24 6.53 8.90 15.43 45 1-hour 362462.20 6134342.97 271.45 23.32 294.77 300 2) 0.030 t/h Annual 362568.45 6134344.24 6.54 8.90 15.44 45

5.3 NOx Modelling Results

Table 3 presents the ground-level concentrations of NOx predicted by the dispersion modelling. There is currently no AAAQO for NOx.

Table 3. Summary of Predicted NOx Maximum Ground Level Concentration

Location Predicted Background Averaging MGLC AAAQO Scenario UTM NAD83 Zone 11N NOx Concentration Period (m E) (m N) (µg/m3) (µg/m3) (µg/m3) (µg/m3) 1-hour 362462.20 6134342.97 271.45 28.03 299.48 N/A 1) 105 MW Annual 362568.45 6134344.24 6.53 10.36 16.89 N/A 1-hour 362462.20 6134342.97 271.45 28.03 299.48 N/A 2) 0.030 t/h Annual 362568.45 6134344.24 6.54 10.36 16.90 N/A

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6.0 CONCLUSION

GPG is a wholly-owned subsidiary of Exelon Corporation, and owns and operates the Power Plant. The Power Plant operates under AUC Power Plant Approval U2017-218 and AESRD EPEA Approval Number 238762-00-02. The Power Plant operates a GE Model MS7001/EA (Frame 7EA) natural gas-fired turbine that has a nominal output of 85 MW. The turbine-generator is capable of generating 105 MW of electricity under its current configuration; however, constraints on the electric system limit the generator output to 99 MW.

GPG has applied to AESO to remove the operating constraints. Once the generating constraints issued by AESO are removed, GPG is seeking authorization to operate the turbine-generator at the maximum generating capacity of 105 MW. As such, GPG is hereby applying under Section 10 of AUC Rule 007 to amend the Clause 2 of AUC Power Plant Approval U2007-218 to change total generating capacity from the existing 85 MW to 105 MW.

The requested change is purely administrative in nature as there will be no change to the design of the Power Plant. Emissions from the turbine will remain within the existing authorized emission limits. As such, the public and stakeholders will not be affected by this change.

Dispersion modelling was performed to predict ground-level concentrations of NO2 and NOx. This report was prepared in accordance with the requirements outlined in the AQMG. The results of the dispersion modelling indicate that maximum ground-level concentrations of NO2 from the Power Plant with background industrial sources are predicted to comply with the AAAQOs.

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7.0 CLOSURE

This report is intended for the exclusive use of the company, organization, or individual to whom it is addressed and may not be relied upon by any third party without the express written permission of North Shore.

Any use which a third party makes of this report, or any reliance on or decisions to be made based on it, are the responsibility of such third parties. North Shore accepts no responsibility for damages, if any, suffered by any third party as a result of the use of this report or any decisions made or actions based on this report.

Should additional information become available than differs significantly from our understanding of conditions or parameters presented in this report, we request that this information is brought to the attention of North Shore so that North Shore may reassess the conclusions provided herein.

North Shore appreciated the opportunity to work on this project. Should there be any questions or comments regarding this report please do not hesitate to contact either of the undersigned at (403) 228-3095.

Report Prepared By: Reviewed By:

Hillary Yeung, B.A.Sc., E.I.T Jesse Stetson, B.Sc., P.Eng. Air Quality Consultant Air & Emissions Specialist

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8.0 REFERENCES

Abadata 2.0 Database, Abacus Datagraphics http://abadata.ca/

Alberta Air Quality Modelling Guideline, October 2013 http://environment.gov.ab.ca/info/library/8908.pdf

Alberta Ambient Air Quality Objectives, August 2013 http://environment.gov.ab.ca/info/library/5726.pdf

Clean Air Strategic Alliance Data Warehouse http://www.casadata.org/Reports/IDataReports/DataDownloadMain.aspx

GeoGratis Database – Database, Natural Resources Canada http://geogratis.gc.ca/

Guide to Content for Industrial Approval Applications, AESRD, June 2014 http://esrd.alberta.ca/lands-forests/land-industrial/forms- applications/documents/GuideIndustrialApprovalApplications-Jun2-2014.pdf

Natural Regions and Subregions of Alberta, Natural Regions Committee, 2006 http://www.albertaparks.ca/media/2942026/nrsrcomplete_may_06.pdf

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Appendix A

Emission Parameters and Background Sources

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Table 4. Power Plant Source Emission Rates and Physical Parameters

Coordinates (NAD83 Stack Stack Exit Exit Emission Source Description and ID UTM Zone 11N) Height Diameter Velocity Temp Rate

(m E) (m N) (m) (m) (m/s) (K) (g/s) NP-Tb - Northern Prairie Power Project - GE 7EA Gas Turbine – 1) 105 MW 359746.4 6133862.6 19.8 4.7 45.0 792.0 4.7 NP-Ta - Northern Prairie Power Project - GE 7EA Gas Turbine – 2) 0.030 t/h 359746.4 6133862.6 19.8 4.7 45.0 792.0 8.3

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Table 5. NOx Background Source Emission Rates and Physical Parameters

Coordinates (NAD83 Stack Stack Exit Exit Emission Source Description and ID UTM Zone 11N) Height Diameter Velocity Temp Rate

(m E) (m N) (m) (m) (m/s) (K) (g/s) ATCO Poplar Hill Generating Plant - LSD 11-19-073-08 W6M ATCO-T - ATCO Poplar Hill Generating Plant - Turbine Exhaust Stack 359292.00 6134773.00 13.60 2.70 43.90 725.00 5.07 ATCO-B - ATCO Poplar Hill Generating Plant - Boiler Exhaust Stack 359274.00 6134767.50 6.00 0.61 4.40 450.00 0.32 ConocoPhillips Wembley Sour Gas Plant - LSD 06-19-073-08 W6M CPWH611 - ConocoPhillips Wembley Sour Gas Plant - Glycol Heater H-611 358933.80 6134393.50 32.90 1.50 5.80 454.00 1.76 CPWH650 - ConocoPhillips Wembley Sour Gas Plant - Glycol Heater H-650 358942.20 6134398.40 7.90 0.69 13.00 575.00 0.66 CPWH100 - ConocoPhillips Wembley Sour Gas Plant - Stabilizer Reboiler H-100 358951.20 6134372.50 19.30 0.99 6.70 566.00 0.66 CPWH400 - ConocoPhillips Wembley Sour Gas Plant - Salt Bath Heater H-400 358929.70 6134506.10 7.80 0.39 1.90 406.00 0.04 CPWM311 - ConocoPhillips Wembley Sour Gas Plant - Dehy. Incinerator M-311 358941.00 6134481.00 16.20 0.59 0.60 518.00 0.03 CPW2M290 - ConocoPhillips Wembley Sour Gas Plant - Dehy. Incinerator 2M-290 358959.20 6134362.60 15.20 0.70 0.09 383.00 0.01 CPWM310 - ConcoPhillips Wembly Sour Gas Plant - Glycol Regen Heater M-310 358937.00 6134479.00 6.30 0.39 4.50 433.00 0.04 CPW2M310 - ConcoPhillips Wembly Sour Gas Plant - Glycol Regen Heater 2M-310 358949.00 6134365.00 6.00 0.25 2.00 433.00 0.01 ConcoPhillips Compressor Station 06-21 - LSD 06-21-073-08 W6M CPC-C1 - ConocoPhillips Compressor Station 06-21 - Compressor 1 362492.63 6134412.67 6.70 0.30 48.90 748.20 1.02 CPC-B1 - ConocoPhillips Compressor Station 06-21 - Boiler 1 362489.47 6134401.14 6.00 0.61 4.40 450.00 0.32 CPC-B1 - ConocoPhillips Compressor Station 06-21 - Boiler 2 362489.47 6134396.96 6.00 0.61 4.40 450.00 0.32 ConcoPhillips Compressor Station 10-31 - LSD 10-31-073-08 W6M CPC2-C1 - ConocoPhillips Compressor Station 10-31 - compressor 1 359813.41 6138145.10 7.00 0.36 45.30 986.15 0.60 CPC2-C2 - ConocoPhillips Compressor Station 10-31 - compressor 2 359818.79 6138197.06 7.00 0.36 45.30 986.15 0.60 Encana Oil & Gas Co. Ltd. - LSD 07-32-073-08 W6M ENC1 - Encana Oil & Gas Co. Ltd. - Heater 361081.12 6137458.89 4.70 0.51 4.58 623.15 0.05

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Appendix B

Project Area Maps and Concentration Isopleths

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Figure 1. Project Area Map

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Bear River Mulligan Creek La Glace Lake 6140000 6138000

Mulligan Lake Bear River 6138000 ConocoPhillips

Compressor 6136000 Station 06-21 Bear River

Poplar Hill 6136000

Anderson Lake 6134000 6134000 Lowe Lake

Bear River 6132000

Northern Prairie 6132000 Power Plant 6130000 6130000 6128000 6128000

354000 356000 358000 360000 362000 364000 366000

LEGEND

Northern Prairie Power Plant

ConocoPhillips Compressor Station 06-21

Other Modelled Background Facility Sources

0 2000 4000 6000

Project Area Map

DATE: March 2015 FIGURE 1

CLIENT: FILE: Grande Prairie Generation Inc. NP-Aerial v1.srf

PROJECT: Northern Prairie Power Plant

#120, 3132 118th Avenue SE DATUM/PROJECTION: Calgary, Alberta, T2Z 3X1 UTM Zone 11N NAD83 P: (403) 228-3095 Grande Prairie Generation, Inc. Dispersion Modelling Assessment Northern Prairie Power Project March 2015

Figure 2. Topographical Maps of the Project Area

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Bear River Mulligan Creek La Glace Lake 6140000

740 6138000 720

Mulligan Lake Bear River 720 ConocoPhillips 6138000 Compressor 740 740

Station740 06-21 6136000 760 Bear River

720 760 Poplar Hill 6136000

740 Anderson Lake740 6134000

700 6134000 Lowe Lake

740

Bear River 6132000 760 680 Northern Prairie

6132000 740 Power Plant 700 720 6130000 6130000 740

760 780 720 6128000

700 6128000

354000 356000 358000 360000 362000 364000 366000

Elevation (m): 660 680 700 720 740 760 780 800 820

LEGEND

Northern Prairie Power Plant

ConocoPhillips Compressor Station 06-21

Other Modelled Background Facility Sources

Section 0 2000 4000 6000 Township

Road

Water Body Project Area Topographical Contour Vegetation

DATE: March 2015 FIGURE 2-1

CLIENT: FILE: Grande Prairie Generation Inc. NP-Topo.srf

PROJECT: Northern Prairie Power Plant

#120, 3132 118th Avenue SE DATUM/PROJECTION: Calgary, Alberta, T2Z 3X1 UTM Zone 11N NAD83 P: (403) 228-3095 ConocoPhillips Compressor Station 06-21 Northern Prairie Power Plant

Elevation (m):

670 685 700 715 730 745 760 775 790 805 820

LEGEND

Northern Prairie Power Plant

ConocoPhillips Compressor Station 06-21

Other Modelled Background Facility Sources

Section

Township 0 2000 4000 6000 8000

Road Water Body Project Area Vegetation 3D Topographical Contour

DATE: March 2015 FIGURE 2-2

CLIENT: FILE: Grande Prairie Generation Inc. NP-3D Topo.srf

PROJECT: Northern Prairie Power Plant

th Figure 3. 105 MW - 9 highest 1-Hour NO2 Concentration Isopleth

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Bear River Mulligan Creek La Glace Lake 6140000 6138000

20 Mulligan Lake ConocoPhillips Bear River Compressor 6138000 Station 06-21 6136000

40 20 Bear River 20 Poplar Hill 20 6136000

Anderson Lake 80 40 6134000

6040 20 20 6134000 Lowe Lake

Bear River 6132000

20 Northern Prairie 6132000 Power Plant Maximum: 271.45 µg/m3 6130000 6130000 6128000

20 6128000

354000 356000 358000 360000 362000 364000 366000

Concentration (µg/m3): 0 20 40 60 80 100 120 140 160 180 200 220 240 260 LEGEND

Northern Prairie Power Plant

Maximum Concentration (µg/m3)

ConocoPhillips Compressor Station 06-21

Other Modelled Background Facility Sources

Section 0 2000 4000 6000 Township Road 1) 105 MW - Predicted 9th Water Body Highest 1-hour Maximum NO2 Vegetation Concentrations (µg/m3)

DATE: March 2015 FIGURE 3

CLIENT: FILE: Grande Prairie Generation Inc. NP-NO2-105-1hr.srf

PROJECT: Northern Prairie Power Plant 3 Maximum NO2 Concentration: 271.45 µg/m 3 #120, 3132 118th Avenue SE 1-hour NO2 AAAQO: 300 µg/m DATUM/PROJECTION: Calgary, Alberta, T2Z 3X1 UTM Zone 11N NAD83 P: (403) 228-3095 Grande Prairie Generation, Inc. Dispersion Modelling Assessment Northern Prairie Power Project March 2015

st Figure 4. 105 MW - 1 highest annual NO2 Concentration Isopleth

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Bear River Mulligan Creek La Glace Lake 6140000 6138000

Mulligan Lake Bear River 0.6 6138000 ConocoPhillips Compressor 0.6 6136000 Station 06-21 Bear River

Poplar Hill 6136000 1.2 Anderson Lake 1.8 0.6

1.8 2.4 6134000 3 1.2

6134000 0.6 Lowe Lake

Bear River 6132000

Northern Prairie 6132000 Power Plant Maximum: 6.53 µg/m3 6130000 6130000 6128000 6128000

354000 356000 358000 360000 362000 364000 366000

Concentration (µg/m3): 0 0.6 1.2 1.8 2.4 3 3.6 4.2 4.8 5.4 6 LEGEND

Northern Prairie Power Plant

Maximum Concentration (µg/m3)

ConocoPhillips Compressor Station 06-21

Other Modelled Background Facility Sources

Section 0 2000 4000 6000 Township Road 1) 105 MW - Predicted 1st Water Body Highest Annual Maximum NO2 Vegetation Concentrations (µg/m3)

DATE: March 2015 FIGURE 4

CLIENT: FILE: Grande Prairie Generation Inc. NP-NO2-105-annual.srf

PROJECT: Northern Prairie Power Plant 3 Maximum NO2 Concentration: 6.53 µg/m 3 #120, 3132 118th Avenue SE Annual NO2 AAAQO: 45 µg/m DATUM/PROJECTION: Calgary, Alberta, T2Z 3X1 UTM Zone 11N NAD83 P: (403) 228-3095 Grande Prairie Generation, Inc. Dispersion Modelling Assessment Northern Prairie Power Project March 2015

th Figure 5. 2) 0.030 t/h - 9 highest 1-Hour NO2 Concentration Isopleth

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Bear River Mulligan Creek La Glace Lake 6140000 6138000

20 ConocoPhillips Mulligan Lake Bear River Compressor 6138000 Station 06-21 6136000

40 20 Bear River 20 Poplar Hill 20 6136000

Anderson Lake 80 40 6134000

6040 20 20 6134000 Lowe Lake

Bear River 6132000

20 Northern Prairie 6132000 Power Plant Maximum: 271.45 µg/m3 6130000 6130000 6128000

20 6128000

354000 356000 358000 360000 362000 364000 366000

Concentration (µg/m3): 0 20 40 60 80 100 120 140 160 180 200 220 240 260 LEGEND

Northern Prairie Power Plant

Maximum Concentration (µg/m3)

ConocoPhillips Compressor Station 06-21

Other Modelled Background Facility Sources

Section 0 2000 4000 6000 Township Road 2) 0.030 t/h - Predicted 9th Water Body Highest 1-hour Maximum NO2 Vegetation Concentrations (µg/m3)

DATE: March 2015 FIGURE 5

CLIENT: FILE: Grande Prairie Generation Inc. NP-NO2-30-1hr.srf

st Figure 6. 2) 0.030 t/h - 1 highest annual NO2 Concentration Isopleth

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Bear River Mulligan Creek La Glace Lake 6140000 6138000

Mulligan Lake Bear River 0.6 6138000 ConocoPhillips

Compressor 6136000 0.6 Station 06-21 Bear River

Poplar Hill 6136000

0.6 Anderson Lake 1.2 1.8

1.8 2.4 6134000 3

1.2

6134000 0.6 Lowe Lake

Bear River 6132000

Northern Prairie 6132000 Power Plant Maximum: 6.54 µg/m3 6130000 6130000 6128000 6128000

354000 356000 358000 360000 362000 364000 366000

Concentration (µg/m3): 0 0.6 1.2 1.8 2.4 3 3.6 4.2 4.8 5.4 6 LEGEND

Northern Prairie Power Plant

Maximum Concentration (µg/m3)

ConocoPhillips Compressor Station 06-21

Other Modelled Background Facility Sources

Section 0 2000 4000 6000 Township Road 2) 0.030 t/h - Predicted 1st

Water Body Highest Annual Maximum NO2 3 Vegetation Concentrations (µg/m )

DATE: March 2015 FIGURE 6

CLIENT: FILE: Grande Prairie Generation Inc. NP-NO2-30-annual.srf

PROJECT: Northern Prairie Power Plant 3 Maximum NO2 Concentration: 6.54 µg/m 3 #120, 3132 118th Avenue SE Annual NO2 AAAQO: 45 µg/m DATUM/PROJECTION: Calgary, Alberta, T2Z 3X1 UTM Zone 11N NAD83 P: (403) 228-3095 Grande Prairie Generation, Inc. Dispersion Modelling Assessment Northern Prairie Power Project March 2015

Appendix C

AERMOD Output Files

North Shore Environmental Consultants Inc. Page 29 Appendix C - 1) 105 MW NO2 Output File.txt ** Lakes Environmental AERMOD MPI ** **************************************** ** ** AERMOD INPUT PRODUCED BY: ** AERMOD VIEW VER. 8.8.9 ** LAKES ENVIRONMENTAL SOFTWARE INC. ** DATE: 03/05/15 ** FILE: C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NP-NOX-105MW V2\NP-NOX-105MW V2.ADI ** **************************************** ** ** **************************************** ** AERMOD CONTROL PATHWAY **************************************** ** ** CO STARTING TITLEONE C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH MODELOPT DFAULT CONC AVERTIME 1 ANNUAL POLLUTID NO2 H1H RUNORNOT RUN ERRORFIL "NP-NOX-105MW V2.ERR" CO FINISHED ** **************************************** ** AERMOD SOURCE PATHWAY **************************************** ** ** SO STARTING ** SOURCE LOCATION ** ** SOURCE ID - TYPE - X COORD. - Y COORD. ** LOCATION NP_TB POINT 359746.393 6133862.578 743.000 ** DESCRSRC NORTHERN PRAIRIE POWER PROJECT - GE 7EA GAS TURBINE 105 KW SCALED LOCATION ATCO_T POINT 359292.000 6134773.000 748.000 ** DESCRSRC ATCO POPLAR HILL GENERATING PLANT - TURBINE EXHAUST STACK LOCATION ATCO_B POINT 359274.000 6134767.500 748.000 ** DESCRSRC ATCO POPLAR HILL GENERATING PLANT - BOILER EXHAUST STACK LOCATION CPWH611 POINT 358933.800 6134393.500 745.000 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - GLYCOL HEATER H-611 LOCATION CPWH650 POINT 358942.200 6134398.400 745.060 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - GLYCOL HEATER H-650 LOCATION CPWH100 POINT 358951.200 6134372.500 745.000 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - STABILIZER REBOILER H-100 LOCATION CPWH400 POINT 358929.700 6134506.100 746.000 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - SALT BATH HEATER H-400 LOCATION CPWM311 POINT 358941.000 6134481.000 746.000 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - DEHY. INCINERATOR M-311 LOCATION CPW2M290 POINT 358959.200 6134362.600 745.000 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - DEHY. INCINERATOR 2M-290 LOCATION CPC_C1 POINT 362492.630 6134412.670 753.000 ** DESCRSRC CONOCOPHILLIPS COMPRESSOR STATION 06-21 - COMPRESSOR 1 LOCATION CPC_B1 POINT 362489.470 6134401.140 753.000 ** DESCRSRC CONOCOPHILLIPS COMPRESSOR STATION 06-21 - BOILER 1 LOCATION CPC_B2 POINT 362489.470 6134396.960 753.000 ** DESCRSRC CONOCOPHILLIPS COMPRESSOR STATION 06-21 - BOILER 2 LOCATION CPC2_C1 POINT 359813.406 6138145.095 724.000 ** DESCRSRC CPC2-C1 - CONOCOPHILLIPS COMPRESSOR STATION 10-31 - COMPRESSOR 1 LOCATION CPC2_C2 POINT 359818.789 6138197.055 724.000 Page 1 Appendix C - 1) 105 MW NO2 Output File.txt ** DESCRSRC CPC2-C2 - CONOCOPHILLIPS COMPRESSOR STATION 10-31 - COMPRESSOR 2 LOCATION ENC1 POINT 361081.119 6137458.886 740.000 ** DESCRSRC ENC1 - ENCANA OIL & GAS CO. LTD. - HEATER LOCATION CPWM310 POINT 358937.000 6134479.000 746.000 ** DESCRSRC CPWM310 - CONCOPHILLIPS WEMBLY SOUR GAS PLANT - GLYCOL REGEN HEATER LOCATION CPW2M310 POINT 358949.000 6134365.000 745.000 ** DESCRSRC CPW2M310 - CONCOPHILLIPS WEMBLY SOUR GAS PLANT - GLYCOL REGEN HEATER ** SOURCE PARAMETERS ** SRCPARAM NP_TB 4.6504467268 19.800 791.950 45.03006 4.700 SRCPARAM ATCO_T 5.0694444444 13.600 725.000 43.90000 2.700 SRCPARAM ATCO_B 0.3194444444 6.000 450.000 4.40000 0.610 SRCPARAM CPWH611 1.7638888889 32.900 454.000 5.80000 1.500 SRCPARAM CPWH650 0.6585648148 7.900 575.000 13.00000 0.690 SRCPARAM CPWH100 0.6585648148 19.300 566.000 6.70000 0.990 SRCPARAM CPWH400 0.0439814815 7.800 406.000 1.90000 0.390 SRCPARAM CPWM311 0.025462963 16.200 518.000 0.60000 0.590 SRCPARAM CPW2M290 0.0069444444 15.200 383.000 0.09000 0.700 SRCPARAM CPC_C1 1.0150462963 6.700 748.200 48.90000 0.305 SRCPARAM CPC_B1 0.3194444444 6.000 450.000 4.40000 0.610 SRCPARAM CPC_B2 0.3194444444 6.000 450.000 4.40000 0.610 SRCPARAM CPC2_C1 0.5974166667 7.000 986.150 45.30000 0.356 SRCPARAM CPC2_C2 0.5974166667 7.000 986.150 45.30000 0.356 SRCPARAM ENC1 0.0527777778 4.700 623.150 4.58000 0.510 SRCPARAM CPWM310 0.038 6.300 433.000 4.50000 0.390 SRCPARAM CPW2M310 0.014 6.000 433.000 2.00000 0.250

** BUILDING DOWNWASH ** BUILDHGT NP_TB 12.34 12.34 12.34 12.34 12.34 12.34 BUILDHGT NP_TB 12.34 12.34 12.34 12.34 12.34 12.34 BUILDHGT NP_TB 12.34 12.34 12.34 12.34 12.34 12.34 BUILDHGT NP_TB 12.34 12.34 12.34 12.34 12.34 12.34 BUILDHGT NP_TB 12.34 12.34 12.34 12.34 12.34 12.34 BUILDHGT NP_TB 12.34 12.34 12.34 12.34 12.34 12.34

…

YBADJ CPW2M310 0.00 0.00 0.00 0.00 0.00 0.00 YBADJ CPW2M310 0.00 0.00 0.00 0.00 0.00 0.00 YBADJ CPW2M310 0.00 0.00 0.00 0.00 0.00 0.00 YBADJ CPW2M310 0.00 0.00 0.00 0.00 0.00 0.00 YBADJ CPW2M310 0.00 0.00 0.00 0.00 0.00 0.00 YBADJ CPW2M310 0.00 0.00 0.00 0.00 0.00 0.00

SRCGROUP ALL SO FINISHED ** **************************************** ** AERMOD RECEPTOR PATHWAY **************************************** ** ** RE STARTING INCLUDED "NP-NOX-105MW V2.ROU" RE FINISHED ** **************************************** ** AERMOD METEOROLOGY PATHWAY **************************************** ** ** ME STARTING SURFFILE ..\MET\NORTHERN_PRAIRIE.SFC PROFFILE ..\MET\NORTHERN_PRAIRIE.PFL Page 2 Appendix C - 1) 105 MW NO2 Output File.txt SURFDATA 12345 2002 UAIRDATA 12345678 2002 PROFBASE 743.0 METERS ME FINISHED ** **************************************** ** AERMOD OUTPUT PATHWAY **************************************** ** ** OU STARTING RECTABLE ALLAVE 1ST 9TH RECTABLE 1 1ST 9TH ** AUTO-GENERATED PLOTFILES PLOTFILE 1 ALL 1ST "NP-NOX-105MW V2.AD\01H1GALL.PLT" 31 PLOTFILE 1 ALL 9TH "NP-NOX-105MW V2.AD\01H9GALL.PLT" 32 PLOTFILE ANNUAL ALL "NP-NOX-105MW V2.AD\AN00GALL.PLT" 33 SUMMFILE "NP-NOX-105MW V2.SUM" OU FINISHED

*** Message Summary For AERMOD Model Setup ***

------Summary of Total Messages ------

A Total of 0 Fatal Error Message(s) A Total of 1 Warning Message(s) A Total of 0 Informational Message(s)

******** FATAL ERROR MESSAGES ******** *** NONE ***

******** WARNING MESSAGES ******** CO W276 22 POLLID: Special proc for 1h-NO2/SO2 24hPM25 NAAQS disabled NO2 H1H

*********************************** *** SETUP Finishes Successfully *** ***********************************

*** AERMOD - VERSION 14134 *** *** C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH *** 03/05/15 *** AERMET - VERSION 14134 *** *** *** 17:01:40

PAGE 1 **MODELOPTs: RegDFAULT CONC ELEV *** MODEL SETUP OPTIONS SUMMARY *** ------**Model Is Setup For Calculation of Average CONCentration Values.

-- DEPOSITION LOGIC -- **NO GAS DEPOSITION Data Provided. **NO PARTICLE DEPOSITION Data Provided. **Model Uses NO DRY DEPLETION. DRYDPLT = F **Model Uses NO WET DEPLETION. WETDPLT = F

Page 3 Appendix C - 1) 105 MW NO2 Output File.txt **Model Uses RURAL Dispersion Only.

**Model Uses Regulatory DEFAULT Options: 1. Stack-tip Downwash. 2. Model Accounts for ELEVated Terrain Effects. 3. Use Calms Processing Routine. 4. Use Missing Data Processing Routine. 5. No Exponential Decay. 6. Full Conversion Assumed for NO2.

**Other Options Specified: CCVR_Sub - Meteorological data includes CCVR substitutions TEMP_Sub - Meteorological data includes TEMP substitutions

**Model Assumes No FLAGPOLE Receptor Heights.

**The User Specified a Pollutant Type of: NO2 **NOTE: Special processing requirements applicable for the 1-hour NO2 NAAQS have been disabled!!! User has specified H1H on the POLLUTID keyword. High ranked 1-hour values are NOT averaged across the number of years modeled, and complete years of data are NOT required.

**Model Calculates 1 Short Term Average(s) of: 1-HR and Calculates ANNUAL Averages

**This Run Includes: 17 Source(s); 1 Source Group(s); and 2259 Receptor(s)

**Model Set To Continue RUNning After the Setup Testing.

**The AERMET Input Meteorological Data Version Date: 14134

**Output Options Selected: Model Outputs Tables of ANNUAL Averages by Receptor Model Outputs Tables of Highest Short Term Values by Receptor (RECTABLE Keyword) Model Outputs External File(s) of High Values for Plotting (PLOTFILE Keyword) Model Outputs Separate Summary File of High Ranked Values (SUMMFILE Keyword)

**NOTE: The Following Flags May Appear Following CONC Values: c for Calm Hours m for Missing Hours b for Both Calm and Missing Hours

**Misc. Inputs: Base Elev. for Pot. Temp. Profile (m MSL) = 743.00 ; Decay Coef. = 0.000 ; Rot. Angle = 0.0 Emission Units = GRAMS/SEC ; Emission Rate Unit Factor = 0.10000E+07 Output Units = MICROGRAMS/M**3

**Approximate Storage Requirements of Model = 4.0 MB of RAM.

**Detailed Error/Message File: NP-NOX-105MW V2.ERR

**File for Summary of Results: NP-NOX-105MW V2.SUM

*** AERMOD - VERSION 14134 *** *** C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH *** 03/05/15 Page 4 Appendix C - 1) 105 MW NO2 Output File.txt *** AERMET - VERSION 14134 *** *** *** 17:01:40

PAGE 2 **MODELOPTs: RegDFAULT CONC ELEV

*** POINT SOURCE DATA *** NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN CAP/ EMIS RATE SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE HOR SCALAR ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) VARY BY ------NP_TB 0 0.46504E+01 359746.4 6133862.6 743.0 19.80 791.95 45.03 4.70 YES NO NO ATCO_T 0 0.50694E+01 359292.0 6134773.0 748.0 13.60 725.00 43.90 2.70 NO NO NO ATCO_B 0 0.31944E+00 359274.0 6134767.5 748.0 6.00 450.00 4.40 0.61 NO NO NO CPWH611 0 0.17639E+01 358933.8 6134393.5 745.0 32.90 454.00 5.80 1.50 NO NO NO CPWH650 0 0.65856E+00 358942.2 6134398.4 745.1 7.90 575.00 13.00 0.69 NO NO NO CPWH100 0 0.65856E+00 358951.2 6134372.5 745.0 19.30 566.00 6.70 0.99 NO NO NO CPWH400 0 0.43981E-01 358929.7 6134506.1 746.0 7.80 406.00 1.90 0.39 NO NO NO CPWM311 0 0.25463E-01 358941.0 6134481.0 746.0 16.20 518.00 0.60 0.59 NO NO NO CPW2M290 0 0.69444E-02 358959.2 6134362.6 745.0 15.20 383.00 0.09 0.70 NO NO NO CPC_C1 0 0.10150E+01 362492.6 6134412.7 753.0 6.70 748.20 48.90 0.31 NO NO NO CPC_B1 0 0.31944E+00 362489.5 6134401.1 753.0 6.00 450.00 4.40 0.61 NO NO NO CPC_B2 0 0.31944E+00 362489.5 6134397.0 753.0 6.00 450.00 4.40 0.61 NO NO NO CPC2_C1 0 0.59742E+00 359813.4 6138145.1 724.0 7.00 986.15 45.30 0.36 NO NO NO CPC2_C2 0 0.59742E+00 359818.8 6138197.1 724.0 7.00 986.15 45.30 0.36 NO NO NO ENC1 0 0.52778E-01 361081.1 6137458.9 740.0 4.70 623.15 4.58 0.51 NO NO NO CPWM310 0 0.38000E-01 358937.0 6134479.0 746.0 6.30 433.00 4.50 0.39 NO NO NO CPW2M310 0 0.14000E-01 358949.0 6134365.0 745.0 6.00 433.00 2.00 0.25 NO NO NO *** AERMOD - VERSION 14134 *** *** C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH *** 03/05/15 *** AERMET - VERSION 14134 *** *** *** 17:01:40

PAGE 3 **MODELOPTs: RegDFAULT CONC ELEV

*** SOURCE IDs DEFINING SOURCE GROUPS ***

Page 5 Appendix C - 1) 105 MW NO2 Output File.txt SRCGROUP ID SOURCE IDs ------

ALL NP_TB , ATCO_T , ATCO_B , CPWH611 , CPWH650 , CPWH100 , CPWH400 , CPWM311 , CPW2M290 , CPC_C1 , CPC_B1 , CPC_B2 , CPC2_C1 , CPC2_C2 , ENC1 , CPWM310 , CPW2M310 , *** AERMOD - VERSION 14134 *** *** C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH *** 03/05/15 *** AERMET - VERSION 14134 *** *** *** 17:01:40

PAGE 4 **MODELOPTs: RegDFAULT CONC ELEV

*** DIRECTION SPECIFIC BUILDING DIMENSIONS ***

SOURCE ID: NP_TB IFV BH BW BL XADJ YADJ IFV BH BW BL XADJ YADJ 1 12.3, 27.2, 30.9, -18.2, 10.9, 2 12.3, 30.8, 33.6, -21.3, 10.3, 3 12.3, 33.4, 35.1, -23.8, 9.4, 4 12.3, 35.1, 35.6, -25.6, 8.1, 5 12.3, 35.6, 35.1, -26.6, 6.7, 6 12.3, 35.1, 33.4, -26.8, 5.0, 7 12.3, 33.6, 30.8, -26.2, 3.1, 8 12.3, 30.9, 27.2, -24.8, 1.2, 9 12.3, 27.4, 22.8, -22.6, -0.7, 10 12.3, 30.9, 27.2, -24.5, -2.7, 11 12.3, 33.6, 30.8, -25.7, -4.5, 12 12.3, 35.1, 33.4, -26.1, -6.2, 13 12.3, 35.6, 35.1, -25.7, -7.8, 14 12.3, 35.1, 35.6, -24.5, -9.1,

…

*** AERMOD - VERSION 14134 *** *** C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH *** 03/05/15 *** AERMET - VERSION 14134 *** *** *** 17:01:40

PAGE 120 **MODELOPTs: RegDFAULT CONC ELEV *** THE SUMMARY OF MAXIMUM ANNUAL RESULTS AVERAGED OVER 5 YEARS ***

** CONC OF NO2 IN MICROGRAMS/M**3 **

NETWORK GROUP ID AVERAGE CONC RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRID-ID ------Page 6 Appendix C - 1) 105 MW NO2 Output File.txt ------ALL 1ST HIGHEST VALUE IS 6.52867 AT ( 362568.45, 6134344.24, 751.54, 751.54, 0.00) DC 2ND HIGHEST VALUE IS 6.20676 AT ( 362753.53, 6134369.00, 746.92, 746.92, 0.00) DC 3RD HIGHEST VALUE IS 4.66998 AT ( 359312.67, 6134777.26, 748.00, 748.00, 0.00) DC 4TH HIGHEST VALUE IS 4.44617 AT ( 362462.20, 6134342.97, 753.00, 753.00, 0.00) DC 5TH HIGHEST VALUE IS 3.48646 AT ( 359303.53, 6134369.00, 746.00, 746.00, 0.00) DC 6TH HIGHEST VALUE IS 3.39969 AT ( 362571.14, 6134515.92, 751.00, 751.00, 0.00) DC 7TH HIGHEST VALUE IS 3.27896 AT ( 359353.53, 6134369.00, 745.55, 745.55, 0.00) DC 8TH HIGHEST VALUE IS 3.27235 AT ( 359503.53, 6134619.00, 746.46, 746.46, 0.00) DC 9TH HIGHEST VALUE IS 3.20258 AT ( 362253.53, 6134369.00, 755.00, 755.00, 0.00) DC 10TH HIGHEST VALUE IS 3.19315 AT ( 359192.72, 6134743.13, 748.00, 748.00, 0.00) DC

*** RECEPTOR TYPES: GC = GRIDCART GP = GRIDPOLR DC = DISCCART DP = DISCPOLR *** AERMOD - VERSION 14134 *** *** C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH *** 03/05/15 *** AERMET - VERSION 14134 *** *** *** 17:01:40

PAGE 121 **MODELOPTs: RegDFAULT CONC ELEV

*** THE SUMMARY OF HIGHEST 1-HR RESULTS ***

** CONC OF NO2 IN MICROGRAMS/M**3 **

DATE NETWORK GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRID-ID ------

ALL HIGH 1ST HIGH VALUE IS 302.29343 ON 05072221: AT ( 362462.20, 6134342.97, 753.00, 753.00, 0.00) DC HIGH 9TH HIGH VALUE IS 271.44939 ON 04090206: AT ( 362462.20, 6134342.97, 753.00, 753.00, 0.00) DC

PAGE 122 **MODELOPTs: RegDFAULT CONC ELEV *** Message Summary : AERMOD Model Execution *** ------Summary of Total Messages ------

A Total of 0 Fatal Error Message(s) A Total of 1 Warning Message(s) A Total of 266 Informational Message(s) A Total of 43824 Hours Were Processed A Total of 266 Calm Hours Identified A Total of 0 Missing Hours Identified ( 0.00 Percent)

******** FATAL ERROR MESSAGES ******** *** NONE ***

******** WARNING MESSAGES ******** CO W276 22 POLLID: Special proc for 1h-NO2/SO2 24hPM25 NAAQS disabled NO2 H1H

************************************ *** AERMOD Finishes Successfully *** ************************************

Page 8 Appendix C - 2) 0.030 tph NO2 Output File.txt ** Lakes Environmental AERMOD MPI ** **************************************** ** ** AERMOD INPUT PRODUCED BY: ** AERMOD VIEW VER. 8.8.9 ** LAKES ENVIRONMENTAL SOFTWARE INC. ** DATE: 03/05/15 ** FILE: C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NP-NOX-30KGH V2\NP-NOX-30KGH V2.ADI ** **************************************** ** ** **************************************** ** AERMOD CONTROL PATHWAY **************************************** ** ** CO STARTING TITLEONE C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH MODELOPT DFAULT CONC AVERTIME 1 ANNUAL POLLUTID NO2 H1H RUNORNOT RUN ERRORFIL "NP-NOX-30KGH V2.ERR" CO FINISHED ** **************************************** ** AERMOD SOURCE PATHWAY **************************************** ** ** SO STARTING ** SOURCE LOCATION ** ** SOURCE ID - TYPE - X COORD. - Y COORD. ** LOCATION NP_TA POINT 359746.393 6133862.578 743.000 ** DESCRSRC NORTHERN PRAIRIE POWER PROJECT - GE 7EA GAS TURBINE 30KG/H LOCATION ATCO_T POINT 359292.000 6134773.000 748.000 ** DESCRSRC ATCO POPLAR HILL GENERATING PLANT - TURBINE EXHAUST STACK LOCATION ATCO_B POINT 359274.000 6134767.500 748.000 ** DESCRSRC ATCO POPLAR HILL GENERATING PLANT - BOILER EXHAUST STACK LOCATION CPWH611 POINT 358933.800 6134393.500 745.000 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - GLYCOL HEATER H-611 LOCATION CPWH650 POINT 358942.200 6134398.400 745.060 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - GLYCOL HEATER H-650 LOCATION CPWH100 POINT 358951.200 6134372.500 745.000 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - STABILIZER REBOILER H-100 LOCATION CPWH400 POINT 358929.700 6134506.100 746.000 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - SALT BATH HEATER H-400 LOCATION CPWM311 POINT 358941.000 6134481.000 746.000 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - DEHY. INCINERATOR M-311 LOCATION CPW2M290 POINT 358959.200 6134362.600 745.000 ** DESCRSRC CONOCOPHILLIPS WEMBLEY SOUR GAS PLANT - DEHY. INCINERATOR 2M-290 LOCATION CPC_C1 POINT 362492.630 6134412.670 753.000 ** DESCRSRC CONOCOPHILLIPS COMPRESSOR STATION 06-21 - COMPRESSOR 1 LOCATION CPC_B1 POINT 362489.470 6134401.140 753.000 ** DESCRSRC CONOCOPHILLIPS COMPRESSOR STATION 06-21 - BOILER 1 LOCATION CPC_B2 POINT 362489.470 6134396.960 753.000 ** DESCRSRC CONOCOPHILLIPS COMPRESSOR STATION 06-21 - BOILER 2 LOCATION CPC2_C1 POINT 359813.406 6138145.095 724.000 ** DESCRSRC CPC2-C1 - CONOCOPHILLIPS COMPRESSOR STATION 10-31 - COMPRESSOR 1 LOCATION CPC2_C2 POINT 359818.789 6138197.055 724.000 Page 1 Appendix C - 2) 0.030 tph NO2 Output File.txt ** DESCRSRC CPC2-C2 - CONOCOPHILLIPS COMPRESSOR STATION 10-31 - COMPRESSOR 2 LOCATION ENC1 POINT 361081.119 6137458.886 740.000 ** DESCRSRC ENC1 - ENCANA OIL & GAS CO. LTD. - HEATER LOCATION CPWM310 POINT 358937.000 6134479.000 746.000 ** DESCRSRC CPWM310 - CONCOPHILLIPS WEMBLY SOUR GAS PLANT - GLYCOL REGEN HEATER LOCATION CPW2M310 POINT 358949.000 6134365.000 745.000 ** DESCRSRC CPW2M310 - CONCOPHILLIPS WEMBLY SOUR GAS PLANT - GLYCOL REGEN HEATER ** SOURCE PARAMETERS ** SRCPARAM NP_TA 8.3333333333 19.800 791.950 45.03006 4.700 SRCPARAM ATCO_T 5.0694444444 13.600 725.000 43.90000 2.700 SRCPARAM ATCO_B 0.3194444444 6.000 450.000 4.40000 0.610 SRCPARAM CPWH611 1.7638888889 32.900 454.000 5.80000 1.500 SRCPARAM CPWH650 0.6585648148 7.900 575.000 13.00000 0.690 SRCPARAM CPWH100 0.6585648148 19.300 566.000 6.70000 0.990 SRCPARAM CPWH400 0.0439814815 7.800 406.000 1.90000 0.390 SRCPARAM CPWM311 0.025462963 16.200 518.000 0.60000 0.590 SRCPARAM CPW2M290 0.0069444444 15.200 383.000 0.09000 0.700 SRCPARAM CPC_C1 1.0150462963 6.700 748.200 48.90000 0.305 SRCPARAM CPC_B1 0.3194444444 6.000 450.000 4.40000 0.610 SRCPARAM CPC_B2 0.3194444444 6.000 450.000 4.40000 0.610 SRCPARAM CPC2_C1 0.5974166667 7.000 986.150 45.30000 0.356 SRCPARAM CPC2_C2 0.5974166667 7.000 986.150 45.30000 0.356 SRCPARAM ENC1 0.0527777778 4.700 623.150 4.58000 0.510 SRCPARAM CPWM310 0.038 6.300 433.000 4.50000 0.390 SRCPARAM CPW2M310 0.014 6.000 433.000 2.00000 0.250

** BUILDING DOWNWASH ** BUILDHGT NP_TA 12.34 12.34 12.34 12.34 12.34 12.34 BUILDHGT NP_TA 12.34 12.34 12.34 12.34 12.34 12.34 BUILDHGT NP_TA 12.34 12.34 12.34 12.34 12.34 12.34 BUILDHGT NP_TA 12.34 12.34 12.34 12.34 12.34 12.34 BUILDHGT NP_TA 12.34 12.34 12.34 12.34 12.34 12.34 BUILDHGT NP_TA 12.34 12.34 12.34 12.34 12.34 12.34

…

SRCGROUP ALL SO FINISHED ** **************************************** ** AERMOD RECEPTOR PATHWAY **************************************** ** ** RE STARTING INCLUDED "NP-NOX-30KGH V2.ROU" RE FINISHED ** **************************************** ** AERMOD METEOROLOGY PATHWAY **************************************** ** ** ME STARTING SURFFILE ..\MET\NORTHERN_PRAIRIE.SFC PROFFILE ..\MET\NORTHERN_PRAIRIE.PFL Page 2 Appendix C - 2) 0.030 tph NO2 Output File.txt SURFDATA 12345 2002 UAIRDATA 12345678 2002 PROFBASE 743.0 METERS ME FINISHED ** **************************************** ** AERMOD OUTPUT PATHWAY **************************************** ** ** OU STARTING RECTABLE ALLAVE 1ST 9TH RECTABLE 1 1ST 9TH ** AUTO-GENERATED PLOTFILES PLOTFILE 1 ALL 1ST "NP-NOX-30KGH V2.AD\01H1GALL.PLT" 31 PLOTFILE 1 ALL 9TH "NP-NOX-30KGH V2.AD\01H9GALL.PLT" 32 PLOTFILE ANNUAL ALL "NP-NOX-30KGH V2.AD\AN00GALL.PLT" 33 SUMMFILE "NP-NOX-30KGH V2.SUM" OU FINISHED

*** Message Summary For AERMOD Model Setup ***

------Summary of Total Messages ------

A Total of 0 Fatal Error Message(s) A Total of 1 Warning Message(s) A Total of 0 Informational Message(s)

******** FATAL ERROR MESSAGES ******** *** NONE ***

******** WARNING MESSAGES ******** CO W276 22 POLLID: Special proc for 1h-NO2/SO2 24hPM25 NAAQS disabled NO2 H1H

*********************************** *** SETUP Finishes Successfully *** ***********************************

*** AERMOD - VERSION 14134 *** *** C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH *** 03/05/15 *** AERMET - VERSION 14134 *** *** *** 16:46:59

PAGE 1 **MODELOPTs: RegDFAULT CONC ELEV *** MODEL SETUP OPTIONS SUMMARY *** ------**Model Is Setup For Calculation of Average CONCentration Values.

-- DEPOSITION LOGIC -- **NO GAS DEPOSITION Data Provided. **NO PARTICLE DEPOSITION Data Provided. **Model Uses NO DRY DEPLETION. DRYDPLT = F **Model Uses NO WET DEPLETION. WETDPLT = F

Page 3 Appendix C - 2) 0.030 tph NO2 Output File.txt **Model Uses RURAL Dispersion Only.

**Other Options Specified: CCVR_Sub - Meteorological data includes CCVR substitutions TEMP_Sub - Meteorological data includes TEMP substitutions

**Model Assumes No FLAGPOLE Receptor Heights.

**Model Calculates 1 Short Term Average(s) of: 1-HR and Calculates ANNUAL Averages

**This Run Includes: 17 Source(s); 1 Source Group(s); and 2259 Receptor(s)

**Model Set To Continue RUNning After the Setup Testing.

**The AERMET Input Meteorological Data Version Date: 14134

**NOTE: The Following Flags May Appear Following CONC Values: c for Calm Hours m for Missing Hours b for Both Calm and Missing Hours

**Approximate Storage Requirements of Model = 4.0 MB of RAM.

**Detailed Error/Message File: NP-NOX-30KGH V2.ERR

**File for Summary of Results: NP-NOX-30KGH V2.SUM

*** AERMOD - VERSION 14134 *** *** C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH *** 03/05/15 Page 4 Appendix C - 2) 0.030 tph NO2 Output File.txt *** AERMET - VERSION 14134 *** *** *** 16:46:59

PAGE 2 **MODELOPTs: RegDFAULT CONC ELEV

*** POINT SOURCE DATA *** NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN CAP/ EMIS RATE SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE HOR SCALAR ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) VARY BY ------NP_TA 0 0.83333E+01 359746.4 6133862.6 743.0 19.80 791.95 45.03 4.70 YES NO NO ATCO_T 0 0.50694E+01 359292.0 6134773.0 748.0 13.60 725.00 43.90 2.70 NO NO NO ATCO_B 0 0.31944E+00 359274.0 6134767.5 748.0 6.00 450.00 4.40 0.61 NO NO NO CPWH611 0 0.17639E+01 358933.8 6134393.5 745.0 32.90 454.00 5.80 1.50 NO NO NO CPWH650 0 0.65856E+00 358942.2 6134398.4 745.1 7.90 575.00 13.00 0.69 NO NO NO CPWH100 0 0.65856E+00 358951.2 6134372.5 745.0 19.30 566.00 6.70 0.99 NO NO NO CPWH400 0 0.43981E-01 358929.7 6134506.1 746.0 7.80 406.00 1.90 0.39 NO NO NO CPWM311 0 0.25463E-01 358941.0 6134481.0 746.0 16.20 518.00 0.60 0.59 NO NO NO CPW2M290 0 0.69444E-02 358959.2 6134362.6 745.0 15.20 383.00 0.09 0.70 NO NO NO CPC_C1 0 0.10150E+01 362492.6 6134412.7 753.0 6.70 748.20 48.90 0.31 NO NO NO CPC_B1 0 0.31944E+00 362489.5 6134401.1 753.0 6.00 450.00 4.40 0.61 NO NO NO CPC_B2 0 0.31944E+00 362489.5 6134397.0 753.0 6.00 450.00 4.40 0.61 NO NO NO CPC2_C1 0 0.59742E+00 359813.4 6138145.1 724.0 7.00 986.15 45.30 0.36 NO NO NO CPC2_C2 0 0.59742E+00 359818.8 6138197.1 724.0 7.00 986.15 45.30 0.36 NO NO NO ENC1 0 0.52778E-01 361081.1 6137458.9 740.0 4.70 623.15 4.58 0.51 NO NO NO CPWM310 0 0.38000E-01 358937.0 6134479.0 746.0 6.30 433.00 4.50 0.39 NO NO NO CPW2M310 0 0.14000E-01 358949.0 6134365.0 745.0 6.00 433.00 2.00 0.25 NO NO NO *** AERMOD - VERSION 14134 *** *** C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH *** 03/05/15 *** AERMET - VERSION 14134 *** *** *** 16:46:59

PAGE 3 **MODELOPTs: RegDFAULT CONC ELEV

*** SOURCE IDs DEFINING SOURCE GROUPS ***

Page 5 Appendix C - 2) 0.030 tph NO2 Output File.txt SRCGROUP ID SOURCE IDs ------

ALL NP_TA , ATCO_T , ATCO_B , CPWH611 , CPWH650 , CPWH100 , CPWH400 , CPWM311 , CPW2M290 , CPC_C1 , CPC_B1 , CPC_B2 , CPC2_C1 , CPC2_C2 , ENC1 , CPWM310 , CPW2M310 , *** AERMOD - VERSION 14134 *** *** C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH *** 03/05/15 *** AERMET - VERSION 14134 *** *** *** 16:46:59

PAGE 4 **MODELOPTs: RegDFAULT CONC ELEV

*** DIRECTION SPECIFIC BUILDING DIMENSIONS ***

SOURCE ID: NP_TA IFV BH BW BL XADJ YADJ IFV BH BW BL XADJ YADJ 1 12.3, 27.2, 30.9, -18.2, 10.9, 2 12.3, 30.8, 33.6, -21.3, 10.3, 3 12.3, 33.4, 35.1, -23.8, 9.4, 4 12.3, 35.1, 35.6, -25.6, 8.1, 5 12.3, 35.6, 35.1, -26.6, 6.7, 6 12.3, 35.1, 33.4, -26.8, 5.0, 7 12.3, 33.6, 30.8, -26.2, 3.1, 8 12.3, 30.9, 27.2, -24.8, 1.2, 9 12.3, 27.4, 22.8, -22.6, -0.7, 10 12.3, 30.9, 27.2, -24.5, -2.7, 11 12.3, 33.6, 30.8, -25.7, -4.5, 12 12.3, 35.1, 33.4, -26.1, -6.2, 13 12.3, 35.6, 35.1, -25.7, -7.8, 14 12.3, 35.1, 35.6, -24.5, -9.1,

…

*** AERMOD - VERSION 14134 *** *** C:\USERS\EPEA\DESKTOP\EXELON NORTHERN PRAIRIE\NORTHERN_PRAIRIE\NORTH *** 03/05/15 *** AERMET - VERSION 14134 *** *** *** 16:46:59

PAGE 120 **MODELOPTs: RegDFAULT CONC ELEV *** THE SUMMARY OF MAXIMUM ANNUAL RESULTS AVERAGED OVER 5 YEARS ***

** CONC OF NO2 IN MICROGRAMS/M**3 **

NETWORK GROUP ID AVERAGE CONC RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRID-ID ------Page 6 Appendix C - 2) 0.030 tph NO2 Output File.txt ------ALL 1ST HIGHEST VALUE IS 6.54262 AT ( 362568.45, 6134344.24, 751.54, 751.54, 0.00) DC 2ND HIGHEST VALUE IS 6.22034 AT ( 362753.53, 6134369.00, 746.92, 746.92, 0.00) DC 3RD HIGHEST VALUE IS 4.67547 AT ( 359312.67, 6134777.26, 748.00, 748.00, 0.00) DC 4TH HIGHEST VALUE IS 4.46035 AT ( 362462.20, 6134342.97, 753.00, 753.00, 0.00) DC 5TH HIGHEST VALUE IS 3.49352 AT ( 359303.53, 6134369.00, 746.00, 746.00, 0.00) DC 6TH HIGHEST VALUE IS 3.41341 AT ( 362571.14, 6134515.92, 751.00, 751.00, 0.00) DC 7TH HIGHEST VALUE IS 3.28590 AT ( 359353.53, 6134369.00, 745.55, 745.55, 0.00) DC 8TH HIGHEST VALUE IS 3.27797 AT ( 359503.53, 6134619.00, 746.46, 746.46, 0.00) DC 9TH HIGHEST VALUE IS 3.21720 AT ( 362253.53, 6134369.00, 755.00, 755.00, 0.00) DC 10TH HIGHEST VALUE IS 3.19889 AT ( 359192.72, 6134743.13, 748.00, 748.00, 0.00) DC

PAGE 121 **MODELOPTs: RegDFAULT CONC ELEV

*** THE SUMMARY OF HIGHEST 1-HR RESULTS ***

** CONC OF NO2 IN MICROGRAMS/M**3 **

DATE NETWORK GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRID-ID ------

ALL HIGH 1ST HIGH VALUE IS 302.29352 ON 05072221: AT ( 362462.20, 6134342.97, 753.00, 753.00, 0.00) DC HIGH 9TH HIGH VALUE IS 271.44941 ON 04090206: AT ( 362462.20, 6134342.97, 753.00, 753.00, 0.00) DC

PAGE 122 **MODELOPTs: RegDFAULT CONC ELEV *** Message Summary : AERMOD Model Execution *** ------Summary of Total Messages ------

******** FATAL ERROR MESSAGES ******** *** NONE ***

******** WARNING MESSAGES ******** CO W276 22 POLLID: Special proc for 1h-NO2/SO2 24hPM25 NAAQS disabled NO2 H1H

************************************ *** AERMOD Finishes Successfully *** ************************************

Page 8 Grande Prairie Generation, Inc. March 2015 Northern Prairie Power Project AUC Rule 007 Power Plant Application

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