March 2012
EMISSION SUMMARY AND DISPERSION MODELLING REPORT
purEnergy Inc. Kawartha Biogas Facility (FIT-FPZXS2N)
REPO
RT
Report Number: 11-1151-0292
Distribution:
2 Copies - purEnergy Inc. 2 Copies - Golder Associates Ltd., Mississauga, Ontario
Submitted to: purEnergy Inc.
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Executive Summary
This Emission Summary and Dispersion Modelling (ESDM) Report was prepared to support an application for a Renewable Energy Approval and was prepared in accordance with s.26 of Ontario Regulation 419/05 (O. Reg. 419/05). In addition, guidance in the Ontario Ministry of the Environment (MOE) publication “Guideline A-10: Procedure for Preparing an Emission Summary and Dispersion Modelling (ESDM) Report, Version 3.0”, dated March 2009 (ESDM Procedure Document) PIBS 3614e03 was followed.
purEnergy Inc. (purEnergy) proposes to construct and operate the Kawartha Biogas Facility (the Facility) at 6830 Highway 7, in Havelock, Ontario. The Facility will produce biogas using an anaerobic digestion system. The biogas will be combusted in generators for the creation of electricity and heat. The electricity will be sold under a Feed-In-Tariff (FIT) contract (reference number FIT-FPZXS2N) awarded by the Ontario Power Authority.
In accordance with O. Reg. 359/09, the Facility is classified as a Class 3, non-farm based, anaerobic digestion facility producing biogas for the purpose of creating green energy. O. Reg. 359/09 also indicates that a Class 3 biogas facility (if the generating unit of the facility is located anywhere other than at a farm operation), requires a Emission Summary and Dispersion Modelling (EDSM) Report prepared in accordance with s.26 of O. Reg. 419/05.
The Facility will consist of four anaerobic Triton ® digesters producing biogas to fuel five combined heat and power (CHP) engines with a maximum electricity generation capacity of 9.8 MW. The Facility also has supporting equipment, including:
one emergency flare;
chemical storage tanks;
an ammonia recovery system;
a desulphurization unit; and
a plant exhaust system.
The North American Industry Classification System (NAICS) code that best applies to the Facility is 221119 (other electric power generation), which is not listed in either Schedule 4 or 5 of O. Reg. 419/05. The Facility is thus subject to s.19 of O. Reg. 419/05; therefore the modelled impact of emissions can be assessed as half-hour maximum point of impingement (POI) concentrations. However, to provide a more accurate estimate, compliance was assessed using the U.S. EPA AERMOD dispersion model, which is an approved dispersion model under O.Reg. 419/05. Therefore, the MOE form “Request Under s.20(4) to have Schedule 3 Standards Apply in Advance of the Date Required by Regulation 419/05” has been provided.
The Facility is expected to emit products of biogas combustion during normal operations and products of natural gas combustion during commissioning operations. The maximum emission rates for each significant contaminant emitted from the significant sources were calculated in accordance with s.11 of O. Reg. 419/05 and the data quality assessment follows the classification system outlined in the ESDM Procedure Document.
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Facility operating scenarios, which generated the highest point of impingement (POI) for each relevant time averaging period, were used. The results are presented in the following Emission Summary Table.
The POI concentrations listed in the Emission Summary Table were compared against published MOE POI Limits as described in the ESDM Procedure Document. At 91%, nitrogen oxides has the highest concentration relative to its MOE POI Limit for the normal operations scenario (Table I). For the commissioning operations scenario, polycyclic aromatic hydrocarbons (PAHs) as benzo(a)pyrene has the highest concentration at 87% of its MOE POI Limit (Table II).
Further details on potential odour emissions from the Facility are documented in “Odour Impact Assessment purEnergy Inc. Kawartha Biogas Facility“ dated January 2012, Report No. 11-1151-0292, Golder Associates Ltd.
This ESDM Report demonstrates that the Facility can operate in compliance with s.20 of O. Reg. 419/05.
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Table I: Normal Operations Emission Summary Table
Contaminant CAS No. Total Facility
Emission Rate [g/s]
Air Dispersion Model Used
Maximum POI Concentration
[µg/m³] Averaging
Period [hours] MOE POI Limit
[µg/m³] Limiting Effect Regulation Schedule No. Percentage of MOE Limit [%]
Ammonia 7664-41-7 7.70E-01 AERMOD 8.63E+01 24 100 Health Schedule 3 86% Ammonium sulphate 7783-20-2 1.10E-08 AERMOD 2.00E-05 24 20 — JSL Below JSL
Carbon monoxide 630-08-0 1.10E+01 AERMOD 9.63E+02 ½ 6000 Health Schedule 3 16% Formaldehyde 50-00-0 1.50E+00 AERMOD 4.63E+01 24 65 Health Schedule 3 71%
Hydrogen sulphide 7783-06-4 7.52E-03 AERMOD 1.74E+00 24 7 Health Schedule 3 25% Hydrogen sulphide 7783-06-4 7.52E-03 AERMOD 8.69E+00 10-min 13 Odour Schedule 3 67%
Nitrogen oxides 10102-44-0 5.02E+00 AERMOD 1.54E+02 24 200 Health Schedule 3 77% Nitrogen oxides 10102-44-0 5.02E+00 AERMOD 3.63E+02 1 400 Health Schedule 3 91%
Particulate matter N/A 2.01E-01 AERMOD 6.16E+00 24 120 Visibility Schedule 3 5% Sulphur dioxide 7446-09-5 7.42E-01 AERMOD 2.28E+01 24 275 Health & Vegetation Schedule 3 8% Sulphur dioxide 7446-09-5 7.42E-01 AERMOD 5.37E+01 1 690 Health & Vegetation Schedule 3 8% Sulphuric acid 7664-93-9 1.53E-03 AERMOD 2.38E+00 24 5 Health Schedule 3 48%
VOCs as Benzene 71-43-2 1.50E+00 AERMOD 4.63E+01 24 100 — Schedule 6 Below URT
Table II: Commissioning Operations Emission Summary Table
Contaminant CAS No. Total Facility
Emission Rate [g/s]
Air Dispersion Model Used
Maximum POI Concentration
[µg/m³] Averaging
Period [hours] MOE POI Limit
[µg/m³] Limiting Effect Regulation Schedule No. Percentage of MOE Limit [%]
Ammonia 7664-41-7 7.70E-01 AERMOD 8.66E+01 24 100 Health Schedule 3 87% Ammonium sulphate 7783-20-2 1.10E-08 AERMOD 2.00E-05 24 20 — JSL Below JSL
Carbon monoxide 630-08-0 1.44E-02 AERMOD 1.73E+00 ½ 6000 Health Schedule 3 <1% Hydrogen sulphide 7783-06-4 2.42E-02 AERMOD 1.97E+00 24 7 Health Schedule 3 28% Hydrogen sulphide 7783-06-4 2.42E-02 AERMOD 8.69E+00 10-min 13 Odour Schedule 3 67%
Nitrogen oxides 10102-44-0 1.83E+00 AERMOD 1.85E+02 1 400 Health Schedule 3 46% Nitrogen oxides 10102-44-0 1.83E+00 AERMOD 6.57E+01 24 200 Health Schedule 3 33%
PAH as Benzo(a)pyrene 50-32-8 2.26E-05 AERMOD 9.60E-04 24 0.0011 Health Guideline 87% Particulate matter N/A 2.21E-01 AERMOD 1.11E+01 24 120 Visibility Schedule 3 9% Sulphur dioxide 7446-09-5 2.39E-02 AERMOD 1.20E+00 24 275 Health & Vegetation Schedule 3 <1% Sulphur dioxide 7446-09-5 2.39E-02 AERMOD 2.40E+00 1 690 Health & Vegetation Schedule 3 <1% Sulphuric acid 7664-93-9 1.53E-03 AERMOD 2.38E+00 24 5 Health Schedule 3 48%
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Table of Contents
1.0 INTRODUCTION ............................................................................................................................................................... 1
1.1 Purpose and Scope ............................................................................................................................................. 1
2.0 FACILITY AND PROCESS DESCRIPTION ..................................................................................................................... 2
2.1 Raw Materials ...................................................................................................................................................... 2
2.2 Anaerobic Digestion ............................................................................................................................................. 3
2.3 Biogas Pre-Treatment .......................................................................................................................................... 3
2.4 Combined Heat and Power System ..................................................................................................................... 3
2.5 Digestate Treatment ............................................................................................................................................ 4
2.6 Emergency Flare ................................................................................................................................................. 4
2.7 Supporting Operations ......................................................................................................................................... 5
2.7.1 Comfort Heating Equipment ........................................................................................................................... 5
2.7.2 Chemical Storage........................................................................................................................................... 5
2.8 NAICS Code ........................................................................................................................................................ 5
2.9 Operating Schedule ............................................................................................................................................. 6
2.10 Facility Production Limit ....................................................................................................................................... 6
3.0 INITIAL IDENTIFICATION OF SOURCES AND CONTAMINANTS ................................................................................. 7
3.1 Sources and Contaminants Identification Table................................................................................................... 7
3.2 Potential Odour Emissions .................................................................................................................................. 7
3.3 Potential Dust Emissions ..................................................................................................................................... 7
4.0 ASSESSMENT OF THE SIGNIFICANCE OF CONTAMINANTS AND SOURCES ......................................................... 8
4.1 Identification of Negligible Contaminants and Sources ........................................................................................ 8
4.2 Rationale for Assessment .................................................................................................................................... 8
5.0 OPERATING CONDITIONS, EMISSION ESTIMATING AND DATA QUALITY ............................................................... 9
5.1 Description of Operation Conditions .................................................................................................................... 9
5.1.1 Normal Operations ......................................................................................................................................... 9
5.1.2 Commissioning Operations ............................................................................................................................ 9
5.2 Explanation of the Methods Used to Calculate Emission Rates ........................................................................ 10
5.3 Sample Calculations .......................................................................................................................................... 10
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5.3.1 Biogas Engine Emissions ............................................................................................................................. 10
5.3.2 Emergency Flare Emissions ........................................................................................................................ 10
5.3.3 Chemical Storage Tanks .............................................................................................................................. 11
5.3.4 Ammonia Scrubbers ..................................................................................................................................... 11
5.3.5 Common Plant Exhaust ............................................................................................................................... 11
5.4 Assessment of Data Quality............................................................................................................................... 11
5.5 Conservatism of Emission Estimates and Operating Condition ......................................................................... 11
6.0 SOURCE SUMMARY TABLE AND SITE PLAN ............................................................................................................ 12
6.1 Source Summary Table ..................................................................................................................................... 12
6.2 Site Plan ............................................................................................................................................................ 12
7.0 DISPERSION MODELLING ............................................................................................................................................ 13
7.1 Meteorology and Land Use Data ....................................................................................................................... 13
7.2 Terrain ............................................................................................................................................................... 13
7.3 Receptors .......................................................................................................................................................... 14
7.4 Building Downwash ........................................................................................................................................... 14
7.5 Deposition .......................................................................................................................................................... 14
7.6 Averaging Time and Conversions ...................................................................................................................... 15
7.7 Dispersion Modelling Options ............................................................................................................................ 15
7.8 Coordinate System ............................................................................................................................................ 15
7.9 Dispersion Modelling Input Summary Table ...................................................................................................... 16
7.10 Dispersion Modelling Runs ................................................................................................................................ 16
7.11 Dispersion Modelling Input and Output Files ..................................................................................................... 16
8.0 EMISSION SUMMARY TABLE ...................................................................................................................................... 17
8.1 Emission Summary Table .................................................................................................................................. 17
8.2 Assessment of Contaminants with no MOE POI Limits ..................................................................................... 17
9.0 CONCLUSIONS .............................................................................................................................................................. 18
TABLES
No table of figures entries found.
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TABLES
Table 1: Sources and Contaminants Identification Table
Table 2a: Normal Operations Source Summary Table
Table 2b: Normal Operations Source Summary Table
Table 3: Dispersion Modelling Input Summary Table
Table 4a: Normal Operations Dispersion Modelling Source Summary Table
Table 4b: Normal Operations Dispersion Modelling Source Summary Table
Table 5a: Emission Summary Table – Normal Operations
Table 5b: Emission Summary Table – Commissioning Operations
FIGURES
Figure 1: Site Location Plan
Figure 2: Process Flow Diagram
Figure 3: Roof Layout
Figure 4: Land Use Zoning Designation Plan
Figure 5: Terrain Elevations
Figure 6: Dispersion Modelling Receptors
Figure 7: Building Downwash Plan
APPENDICES APPENDIX A Emission Rate Calculations
APPENDIX B Supporting Information for Emission Rate Calculations
APPENDIX C Dispersion Modelling Files (on CD)
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1.0 INTRODUCTION
1.1 Purpose and Scope purEnergy Inc. (purEnergy) proposes to construct and operate the Kawartha Biogas Facility at 6830 Highway 7, in Havelock, Ontario (the Facility). The Facility will produce biogas using an anaerobic digestion system. The biogas will be combusted in generators for the creation of electricity and heat. The Facility will have a maximum electricity generation capacity of 9.8 MW. The electricity will be sold under a Feed-In-Tariff (FIT) contract (reference number FIT-FPZXS2N) awarded by the Ontario Power Authority.
On September 24, 2009, Ontario Regulation 359/09 (O. Reg. 359/09) of the Environmental Protection Act received Royal Assent and on October 1, 2009 was filed and came into force. O. Reg. 359/09 contains the current requirements for approval of renewable energy projects under the Renewable Energy Approval (REA) process. This documentation consists of seven parts, including interpretation; classes of renewable energy generation facilities; application of the act of renewable energy project; renewable energy approval, etc.
In accordance with O. Reg. 359/09, the Facility is classified as a Class 3, non-farm based, anaerobic digestion facility producing biogas for the purpose of creating green energy. O. Reg. 359/09 also indicates that a Class 3 biogas facility (if the generating unit of the facility is located anywhere other than at a farm operation), requires a Emission Summary and Dispersion Modelling (EDSM) Report prepared in accordance with s.26 of O. Reg. 419/05.
This ESDM Report is, therefore, intended to support a Renewable Energy Approval Application for the Facility. In addition, guidance in the Ontario Ministry of the Environment (MOE) publication “Guideline A-10: Procedure for Preparing an Emission Summary and Dispersion Modelling (ESDM) Report, Version 3.0”, dated March 2009 (ESDM Procedure Document) PIBS 3614e03 was followed.
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2.0 FACILITY AND PROCESS DESCRIPTION purEnergy proposes to construct and operate the Kawartha Biogas facility at 6830 Highway 7, in Havelock, Ontario (refer to Figure 1 – Site Location Plan). The Facility will use an anaerobic digestion system to produce biogas that will be combusted in generators for the creation of electricity and heat.
The Facility will consist of four anaerobic Triton ® digesters producing biogas to fuel five combined heat and power (CHP) engines with a maximum electricity generation capacity of 9.8 MW. The electricity will be sold under a Feed-In-Tariff (FIT) contract (reference number FIT-FPZXS2N) awarded by the Ontario Power Authority.
Product usages and process information are provided in greater detail in Appendix A – Emission Rate Calculations. Refer to Table 1 – Sources and Contaminants Identification Table, which tabulates the individual sources of emissions at the Facility.
Refer to Figure 2 – Process Flow Diagram for a graphical representation of the processes occurring at the Facility.
2.1 Raw Materials The Facility will continuously receive organic materials (feedstock) in both liquid and solid form. Both types of feedstock will be delivered to the site by truck. Liquid materials are those that are pumpable without any additional particle size reduction or dilution; solid materials are those that may require further particle size reduction or dilution in order to render them pumpable.
Feedstock will be delivered by trucks at scheduled times throughout the year. In the solids reception building, the trucks will empty the loads of solid feedstock into a below-ground reception pit which is outfitted with a mixer and a chopper pump. The solid feedstock will be pre-treated before entering the reception tank. The trucks delivering liquid feedstock will stop at the liquid reception area and empty their load through the appropriate hose. The liquid organic reception pump will be activated to pump the liquid feedstock to the reception tank.
There will be three reception tanks located on the site used for receiving organic materials.
Tank 1: Low energy substrates (e.g., manure);
Tank 2: Medium energy substrates (e.g., food waste, distillers wet grain); and
Tank 3: High energy substrates (e.g., syrup, grease, whey).
The reception tanks will be insulated and equipped with hydraulic mixers. Hot water piping will be installed around the interior circumference of each tank to heat the feedstock. Dilution water will be mixed with the feedstock in order to achieve its optimum liquid content for the digestion.
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2.2 Anaerobic Digestion The diluted feed substrates will be pumped to four anaerobic Triton® digesters. Their main characteristic is the ring-in-ring construction, which consists of an outer ring used as fermenter and an inner ring used as a secondary fermenter. Both the inner and the outer ring will be mixed by hydraulic submersible mixers. The inner ring of the digester will have a dual layer flexible membrane that is used for biogas storage.
The digestate feedstock exiting the four anaerobic digesters will enter a buffer storage tank. This tank allows additional residence time for the organic materials to be digested completely. As a result, the production of methane gas from the organic substrate will be optimized. It is expected that the odour level of the digestate will be reduced to undetectable levels. The buffer storage tank also acts as a digestate storage and volume buffering tank. At the same time, low solids digestate can be returned to the anaerobic digesters in order to maintain the optimal total solids content. The buffer storage tank also provides storage for biogas in its double-membrane gas holder roof.
2.3 Biogas Pre-Treatment The biogas produced in the digesters and the buffer tank will contain hydrogen sulphide (H2S) that needs to be partly removed before the biogas is fed to the engines. Higher concentrations of H2S reduce the lubrication function of the engine oil, leading to reduced life time of the engines and expensive breakdowns, repairs and oil changes. The H2S content in the biogas needs to be reduced to less than 200 ppm before being fed to the engines.
An external bio-scrubber will be used to reduce the H2S concentration. Bio-scrubbing involves a two stage process: absorption of H2S via a liquid medium followed by the biological oxidation of H2S in the liquid. The sulphate is discharged in the scrubber effluent as diluted sulphuric acid. The sulphuric acid will be pumped in the day tank and will entirely be used in ammonia removal/scrubbing process (for digestate) along with fresh commercial sulphuric acid.
Once the H2S has been removed, the biogas enters a gas drying unit where a chiller cools the biogas to allow moisture to condense. The biogas will then be heated again so that the relative humidity will have decreased to acceptable values for the engines. A blower station will be installed to provide the biogas with the required pressure to enter the CHP engines.
2.4 Combined Heat and Power System Five CHP engines will use the produced biogas as fuel to generate 9.8 MW of electrical power. Approximately 10 MW of thermal energy will also be produced in the form of hot water and exhaust gases from the engines. The hot water will be used to heat the reception tanks, the digesters, the buffer tank, and also to provide the required heat for the ammonia recovery system. Five steam boilers will use heat from the exhaust gas to produce steam.
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2.5 Digestate Treatment The digestate will be separated into a liquid and solid form with three screw presses in the dewatered solid loading area. Dewatered sludge will be loaded into trucks to be transported to the end user for application as soil conditioner. If the truck transport is interrupted by unforeseeable circumstances (e.g., strike, poor weather), the dewatered sludge will be temporarily stored in the dewatered storage solid building.
The digestate produced by the Facility is expected to have a high ammonia content. Ammonia will be removed from the digestate (filtrate) by a two stage continuous process: ammonia stripping and ammonia chemical scrubbing. In the first stage, the filtrate is pumped to the top of the stripper tower and flows downward through an air stream. Ammonia is stripped from the filtrate into the air stream. The air stream is then directed to the scrubbers where the air stream is put in contact with sulphuric acid scrubbing solution to produce an ammonium sulphate solution. The ammonium sulphate solution will have a concentration of approximately 35 weight percent and will be sold to third parties as a commodity. The system is designed to consistently meet an ammonia reduction of approximately 85 to 90% with the denitrified effluent used for diluting the fresh substrates so that no fresh water is needed.
The balance of the denitrified effluent that has not been used for diluting the feedstock will be treated in a Sequencing Batch Reactor (SBR) plant before being discharged into the adjacent quarry. The SBR operates in sequential fill and draw mode. The system incorporates a surge/anoxic mix tank as part of the SBR to optimally control the process and provide rapid and complete treatment. This surge tank provides flow and nutrient equalization to ensure treatment at the full range of flows and loadings. Odour control and scum skimming will be achieved in the process. There will be two SBR tanks that can operate independently and in true batch mode as flow accumulates in the tank during settling and decanting.
The solid portion of the digestate (dewatered sludge) is sold to end users for application as soil conditioner and will be directly loaded into trucks to be transported offsite. In the rare event that the solids cannot be immediately transported offsite and the buffer storage capacity has been exceeded (three days), the solids will be transferred to the dewatered storage solid building through an enclosed conveyor and loaded onto transport trucks by a loader at a later time.
2.6 Emergency Flare An emergency flare will burn off biogas produced by the Facility during the commissioning operations until the biogas quantity and quality is sufficient to feed the engines. Commissioning operations are expected to last for two months. In the unlikely situation where one or more biogas engines are not operational and the Facility’s biogas storage volume is exceeded, the emergency flare will burn off the excess biogas as a means of relieving the pressure within the digesters. A side benefit of burning off the excess biogas may be to mitigate potential odour emissions. During normal operations, the emergency flare will not be in use.
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2.7 Supporting Operations In addition to the main operations described above, other operations and/or equipment at the Facility include:
comfort heating equipment; and
chemical storage.
The emissions for these supporting operations are described in the subsequent sections.
2.7.1 Comfort Heating Equipment The Facility will operate two 121,331 kJ (115,000 BTU) natural gas comfort heating units for heating the office space and scale house. As the total thermal heat input of these units is less than 1.58 million kJ, they are exempt from the permitting assessment in accordance with O.Reg. 524/98 Environmental Compliance Approvals – Exemptions from Section 9 of the Act.
2.7.2 Chemical Storage Chemical usage at the Facility is summarized in the following table:
Chemical Usage Storage Emissions
Polymer Used as flocculant Totes Non-volatile, no emissions expected
Acid Small amounts used to adjust pH of feedstock
Totes Acid is consumed in reaction, no emissions expected
Base Small amounts used to adjust pH of feedstock
Totes Base is consumed in reaction, no emissions expected
Ferric chloride Used for the SBR Indoor storage tank Non-volatile, no emissions expected
Ammonium sulphate
Product from ammonia scrubber
Above-ground storage tank
Tank filling emissions
Sulphuric acid Used in ammonia scrubber
Above-ground storage tank
Tank filling emissions
2.8 NAICS Code The North American Industry Classification System (NAICS) code that best applies to the Facility is 221119 (other electric power generation).
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2.9 Operating Schedule The Facility will operate 24 hours per day, seven days per week. Deliveries and shipping offsite will primarily occur during daytime hours.
2.10 Facility Production Limit The Facility has the capacity to generate 9.8 MW of electrical power and approximately 10 MW of thermal energy.
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3.0 INITIAL IDENTIFICATION OF SOURCES AND CONTAMINANTS This section provides an initial identification of all of the sources and contaminants emitted at the Facility, as required by subparagraphs 2 to 4 of s.26(1) of O. Reg. 419/05.
3.1 Sources and Contaminants Identification Table Table 1 – Sources and Contaminants Identification Table tabulates all the emission sources at the Facility and the expected contaminants emitted from each source.
3.2 Potential Odour Emissions The Facility’s ventilation system has been designed to minimize odourous emissions.
The solid feedstock offloading area will be equipped with an air lock and all solid handling conveyers will be covered, so that odorous air cannot escape to the atmosphere. In addition, the Solids Reception building and Reception Tanks will be kept under slight negative pressure at all times to prevent any odours from being emitted to the atmosphere.
Negative pressure will be maintained in buildings by controlling the flow of incoming and outgoing air. By keeping the flow of building make‐up air slightly lower than the exhaust air, negative pressure will be established.
Air from the Solids Reception building will be drawn into the CHP building at a rate of 10,203 m³/hr for use as combustion air in the biogas engines. As the five CHP engines require 40,000 to 60,000 m³/hr of combustion air, this ensures that the potentially odourous air is not released to the atmosphere.
The Solids Reception building, below-ground reception pit, Reception tanks and CHP buildings will be sealed so that negative pressure is not lost by air infiltrating through exterior walls, windows and doors.
The Digestate Management Building and Dewatered Solids Loading Building will be maintained at negative pressure. The materials handled in these areas have gone through the digestion process and have minimal odours. The exhaust ventilation air from the Digestate Management Building and Dewatered Solids Loading Building will be conducted through an air duct to a common plant exhaust air stack for monitoring purposes.
Further details on potential odour emissions from the Facility are documented in “Odour Impact Assessment purEnergy Inc. Kawartha Biogas Facility“ dated March 2012, Report No. 11-1151-0292, Golder Associates Ltd.
3.3 Potential Dust Emissions Fugitive dust emissions with metal content from the Facility are expected to be negligible. The procedure for the identification of negligible sources is detailed in Section 4 of this report.
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4.0 ASSESSMENT OF THE SIGNIFICANCE OF CONTAMINANTS AND SOURCES
4.1 Identification of Negligible Contaminants and Sources Some of the sources listed in Table 1 – Sources and Contaminants Identification Table have been identified as negligible. The remaining sources are significant and are included in the dispersion modelling for the Facility.
Similarly, some contaminants from the sources that are considered significant have been deemed to be negligible.
4.2 Rationale for Assessment For each source or contaminant that has been deemed negligible, the technical information required to substantiate the argument that each of the identified sources is negligible is presented in Table 1.
In accordance with s.8 of O. Reg. 419/05, emission rate calculations and dispersion modelling is not required for emissions from negligible sources.
The following is a summary of the assessment for each source.
Solids Storage Building Ventilation (S31 and S32) – The materials handled in the Solids Storage Building have gone through the digestion process and have minimal odours.
Waste Water Tank Vent (S33 and S34) – The waste water treated in this area has gone through the digestion process as well as the ammonia recovery system and no odours or other emissions are expected.
Chemical Storage (S36) – Chemical additives are stored on-site in totes or indoor storage tanks. Table B-3 in Appendix B.2 of the ESDM Procedure Document states that emissions from “low temperature handling of compound with a vapour pressure less than 1 kPa” are considered negligible. Therefore, emissions from the chemical storage area considered negligible.
Comfort Heating Equipment (S37) – The Facility will operate two 121,331 kJ (115,000 BTU) natural gas comfort heating units for heating the office space and scale house. As the total thermal heat input of these units is less than 1.58 million kJ, they are considered negligible.
Desulphurization Unit (S40) – The desulphurization unit is a closed system and has no external exhaust points.
Several contaminants were also determined to be negligible using the dispersion factor method provided in Table B-1 of the ESDM Procedure Document. For the purpose of this screening level assessment, it was conservatively assumed that contaminants would be emitted from the stack closest to the property line (16 m).
The resulting POI concentrations were then compared against half the value of the corresponding MOE POI limit. No further assessment is required if the POI concentration is less than half the value of the MOE POI limit. The screening level assessment is provided in Appendix D – Negligible Contaminants.
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5.0 OPERATING CONDITIONS, EMISSION ESTIMATING AND DATA QUALITY
This section provides a description of the operating conditions used in the calculation of the emission estimates and an assessment of the data quality of the emission estimates for each significant contaminant from the Facility, as required by sub paragraphs 6 and 7 of s.26(1) of O. Reg. 419/05.
5.1 Description of Operation Conditions Section 10 of O.Reg.419/05 states that an acceptable operating condition is a scenario in which operating conditions for the Facility would result, for the relevant contaminant, in the highest concentration of the contaminant possible at the point of impingement (POI). The operating condition(s) described in this ESDM Report meets this requirement.
The MOE has established standards and guidelines for over 300 contaminants, as documented in the publication “Summary of Standards and Guidelines to support Ontario Regulation 419: Air Pollution - Local Air Quality (including Schedule 6 of O. Reg. 419 on Upper Risk Thresholds)”, dated February 2008 (MOE POI Limit[s]). The averaging time for the operating condition is dependent on the averaging time for the MOE POI Limit. The operating conditions used for the Facility that result in the maximum concentration at a POI are the scenarios where all significant sources are operating simultaneously at their individual maximum rates of production for the appropriate averaging time, as described in Appendix A of this ESDM Report. The individual maximum rates of production for each significant source of emissions correspond to the maximum emission rate for the averaging time. Two different operational scenarios were modelled for the facility, each of these scenarios is defined below:
5.1.1 Normal Operations During maximum normal operations, all five CHP engines will be in operation at 100% load, generating 9.8 MW of electrical power. All five boilers will be operating to generate approximately 4.8 MW of thermal energy in the form of steam. All other sources are also expected to be in operation except the emergency flare.
5.1.2 Commissioning Operations During the Facility’s commissioning operations (approximately 2 months), the biogas produced will be combusted by the flare until the biogas quantity and quality is enough to feed the engines. Up to 25% of the Facility’s biogas production capacity, estimated to be 935 m³/hr, will be burned in the flare. During this time, two biogas engines will also be in operation at half load using natural gas as fuel.
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5.2 Explanation of the Methods Used to Calculate Emission Rates The maximum emission rates for each significant contaminant emitted from the significant sources were estimated and the methodology for the calculation are documented in Tables 2a and 2b, the Source Summary Tables for normal and commissioning operations. All emission rates were calculated in accordance with requirements of the ESDM Procedure Document.
5.3 Sample Calculations The technical rationale, including sample calculations, required to substantiate the emission rates presented in Tables 2a and 2b are documented in Appendix A – Emission Rate Calculations. Emission factors for natural gas combustion are publicly available. Emission data for the biogas engines and emergency flare are provided in Appendix B – Supporting Information for Emission Rate Calculations.
5.3.1 Biogas Engine Emissions Emissions from the combustion of biogas in the CHP engines were estimated using emission factors (units of mg/m³) provided by the CHP engine manufacturer. The emission factors were multiplied by the engine exhaust flow rate to provide a g/s emission rate. Emissions include products of combustion, particulate matter, hydrogen sulphide, VOCs as benzene and formaldehyde.
The CHP engines have a hydrogen sulphide oxidation/destruction efficiency of greater than 99%. Emission rates were estimated assuming 1% of the hydrogen sulphide in biogas would be emitted to the atmosphere.
During commissioning operations, two biogas engines will operate using natural gas as fuel. Nitrogen oxides emissions were estimated using an emission factor obtained from the US EPA AP-42 Chapter 3.2: Natural Gas Fired Reciprocating Engines.
5.3.2 Emergency Flare Emissions Emissions from the emergency flare were calculated using emission factors obtained from Environment Canada's biogas flaring emissions estimation tool. The emission factors were multiplied by the emergency flare biogas consumption rate to provide a g/s emission rate. Emissions include products of combustion, particulate matter, hydrogen sulphide and PAHs.
The emergency flare has a hydrogen sulphide oxidation/destruction efficiency of greater than 98%. Emission rates were estimated assuming 2% of the hydrogen sulphide in biogas would be emitted to the atmosphere.
The emergency flare was also assumed to destroy 99% of polyaromatic hydrocarbon compounds (PAHs). All PAHs were assumed to be benzo(a)pyrene.
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March 2012 Report No. 11-1151-0292 11
5.3.3 Chemical Storage Tanks Tank filling emissions from the ammonium sulphate and sulphuric acid storage tanks were calculated using the Air & Waste Management Association document, "Vapour Emissions from a Solvent Waste Storage Tank" (December 2008), as part of Ontario Air and Noise Best Practices.
5.3.4 Ammonia Scrubbers Emissions from the ammonia scrubbers were estimated using the maximum ammonia inlet concentration and the guaranteed ammonia removal efficiency of 98%.
5.3.5 Common Plant Exhaust Air from the Digestate Management building and Dewatered Solids Storage and Loading building is exhausted through the Common Plant Exhaust. Emissions from this exhaust were based on source testing data obtained from a similar facility.
Odour emissions are the main concern from this exhaust, therefore, all emissions were conservatively assumed to be hydrogen sulphide.
5.4 Assessment of Data Quality The assessment of data quality for each source listed in Tables 2a and 2b are documented in Appendix A – Emission Rate Calculations.
5.5 Conservatism of Emission Estimates and Operating Condition The following assumptions were included in the development of the emission estimates and operating condition for the Facility:
The highest emission rate that each source is capable of (i.e., maximum usage rates or throughputs) was used to characterize the emissions.
All sources are assumed to be operating simultaneously at the corresponding maximum emission rate for the averaging period for each operational scenario.
Based on the conservative assumptions summarized above and detailed in Appendix A – Emission Rate Calculations, the emission rates listed in Tables 2a and 2b are likely to be an overestimate of the actual emission rates.
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6.0 SOURCE SUMMARY TABLE AND SITE PLAN
6.1 Source Summary Table The emission rates for each source of significant contaminants are documented in Tables 2a and 2b in accordance with requirements of sub paragraph 8 of s.26(1) of O. Reg. 419/05.
6.2 Site Plan The Facility property line is illustrated on Figure 1 – Site Location Plan. Scaled site information is provided in Figure 3 – Roof Layout. This includes:
each significant source of significant contaminants; and
the location of buildings on the property.
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March 2012 Report No. 11-1151-0292 13
7.0 DISPERSION MODELLING The dispersion modelling was conducted in accordance with the MOE publication “Guideline A-11: Air Dispersion Modelling Guideline for Ontario, Version, 2.0”, dated March 2009 (ADMGO) PIBS 5165e02.
The Facility is currently subject to s.19 of O. Reg. 419/05; therefore, the modelled impact of contaminant emissions can be assessed as half-hour maximum point of impingement (POI) concentrations. However, the AERMOD model is being used for this ESDM Report to allow for the improved dispersion from plume rise due to high temperature and high velocity exhaust characteristics from Facility’s exhaust stacks. The MOE form “Request Under s.20(4) to have the Schedule 3 Standards Apply in Advance of the Date Required by Regulation 419/05” has been provided.
The AERMOD modelling system consists of the AERMOD dispersion model, the AERMET meteorological pre-processor, the AERMAP terrain pre-processor, and the BPIP-Prime building downwash pre-processor.
The following approved dispersion model and pre-processors were used in the assessment:
AERMOD dispersion model (v. 09292);
AERMAP surface pre-processor (v. 11103); and
BPIP-Prime building downwash pre-processor (v. 04274).
7.1 Meteorology and Land Use Data The AERMOD model was run using a five-year (1996 to 2000) crops meteorological data set obtained from the MOE’s “Ontario Regional Meteorological Data” website for the Eastern Region – Ottawa, Peterborough, Belleville.
A zoning map including local land uses is provided as Figure 4 – Land Use Zoning Designation Plan.
7.2 Terrain Terrain data used in this assessment was obtained from MOE (7.5 minute format) and is illustrated in Figure 5 –Terrain Elevation. DEM files used in this assessment include the following:
1006_3.DEM; and
1007_3.DEM.
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March 2012 Report No. 11-1151-0292 14
7.3 Receptors Receptors were chosen based on recommendations provided in section 7.1 of the ADMGO, which is in accordance with section 14 of O. Reg. 419/05. Specifically, a nested receptor grid, centered around the outer edges of all the sources, was placed as follows:
a) 20 m spacing, within an area of 200 m by 200 m;
b) 50 m spacing, within an area surrounding the area described in (a) with a boundary at 300 m by 300 m outside the boundary of the area described in (a);
c) 100 m spacing, within an area surrounding the area described in (b) with a boundary at 800 m by 800 m outside the boundary of the area described in (a);
d) 200 m spacing, within an area surrounding the area described in (c) with a boundary at 1,800 m by 1,800 m outside the boundary of the area described in (a); and
e) 500 m spacing, within an area surrounding the area described in (d) with a boundary at 4,800 m by 4,800 m outside the boundary of the area described in (a).
In addition to using the nested receptor grid, receptors were also placed every 10 m along the property line.
The area of modeling coverage is illustrated on Figure 6 – Dispersion Modelling Receptors.
7.4 Building Downwash Building wake effects were considered in this modelling study using the U.S. EPA’s Building Profile Input Program (BPIP-PRIME), a pre-processor to AERMOD. The inputs into this pre-processor include the coordinates and heights of the buildings and stacks. The BPIP output is used in the AERMOD building wake effect calculation.
The PRIME plume rise algorithms include vertical wind shear calculations (important for buoyant releases from short stacks [i.e., stacks at release heights within the recirculation zones of buildings]). The PRIME algorithm also allows for the wind speed deficit induced by the building to change with respect to the distance from the building. These factors improve the accuracy of predicted concentrations within building wake zones that form in the lee of buildings.
The building obstacles as used in the BPIP program are shown in Figure 7 – Building Downwash Plan.
7.5 Deposition AERMOD has the capability to account for wet and dry deposition of substances that would reduce ground level concentrations at POIs. However, the deposition algorithm has not been implemented as only regulatory defaults have been used.
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March 2012 Report No. 11-1151-0292 15
7.6 Averaging Time and Conversions The Schedule 3 standards of O. Reg. 419/05 that apply to the Facility have 10-minute, ½-hour, 1-hour or 24-hour averaging periods. The 1-hour and 24-hour averaging periods are provided by AERMOD. Carbon monoxide has a ½-hour standard, therefore, the hourly concentration was converted to a ½-hour average by multiplying the 1-hour value by 1.21 as recommended in section 4.4 of the ADMGO. Hydrogen sulphide has a 10-minute standard, therefore, the hourly concentration was converted to a 10-minute average by multiplying the 1-hour value by 1.65 as recommended in section 4.4 of the ADMGO.
7.7 Dispersion Modelling Options The options used in the AERMOD dispersion model are summarized in below.
Modelling Parameter Description Used in the Assessment?
DFAULT Specifies that regulatory default options will be used Yes
CONC Specifies that concentration values will be calculated Yes
DDPLETE Specifies that dry deposition will be calculated No
WDPLETE Specifies that wet deposition will be calculated No
FLAT Specifies that the non-default option of assuming flat terrain will be used
No, the model uses elevated terrain data files as detailed in the AERMAP output.
NOSTD Specifies that the non-default option of no stack-tip downwash will be used No
AVERTIME Time averaging periods calculated 1-hour, 24-hour
URBANOPT
Allows the model to incorporate the effects of increased surface heating from an urban area on pollutant dispersion under stable atmospheric conditions
No
URBANROUGHNESS Specifies the urban roughness length (m) Default value used
FLAGPOLE Specifies that receptor heights above local ground level are allowed on the receptors No
7.8 Coordinate System The Universal Transverse Mercator (UTM) coordinate system, as per Section 5.2.2 of the ADMGO, was used to specify model object sources, buildings and receptors. All coordinates were defined in the North American Datum of 1983 (NAD83).
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7.9 Dispersion Modelling Input Summary Table A description of the way in which the approved dispersion model was performed is included as Table 3 – Dispersion Modelling Input Summary Table. This table meets both the requirements of paragraph 26(1)(11) and sections 8 to 17 of O. Reg. 419/05 and follows the format provided in the ESDM Procedure Document. Furthermore, the dispersion modelling input parameters are summarized in Tables 4a and 4b, the Dispersion Modelling Source Summary Tables for normal and commissioning operations. Although not required by section 26 of O. Reg. 419/05, these tables simplify the data presentation.
7.10 Dispersion Modelling Runs Modelling runs were completed for each significant contaminant in the two operating scenarios.
7.11 Dispersion Modelling Input and Output Files Electronic copies of all input and output files are also provided in Appendix C on compact disc (CD).
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March 2012 Report No. 11-1151-0292 17
8.0 EMISSION SUMMARY TABLE This section provides the table required by sub paragraph 14 of s.26(1) of O. Reg. 419/05 and provides an interpretation of the results, as required by the ESDM Procedure Document.
8.1 Emission Summary Table A POI concentration for each significant contaminant emitted from the Facility was calculated based on the emission rates listed in Tables 2a and 2b and the output from the approved dispersion model presented in Appendix E. The results are presented in Tables 5a and 5b, the Emission Summary Tables for normal and commissioning operations. This table follows the format provided in the ESDM Procedure Document.
The POI concentrations listed in Tables 5a and 5b were compared against the MOE POI Limits. At 91%, nitrogen oxides has the highest concentration relative to its MOE POI Limit for the normal operations scenario. For the commissioning operations scenario, PAH as benzo(a)pyrene has the highest concentration at 87% of its MOE POI Limit.
8.2 Assessment of Contaminants with no MOE POI Limits Sub paragraph 14 subsection viii of s.26(1) O. Reg. 419/05 requires an indication of the likelihood, nature and location of any adverse effect if the contaminant is not listed in any of Schedules 1, 2 and 3.
Contaminants at the Facility that do not have MOE POI Limits were screened against the Jurisdictional Screening Limits (JSLs) listed in the MOE publication “Jurisdictional Screening Level (JSL) List a Screening Tool for Ontario Regulation 419: Air Pollution – Local Air Quality” dated February 2008.
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March 2012 Report No. 11-1151-0292 18
9.0 CONCLUSIONS This ESDM Report was prepared in accordance with s.26 of O. Reg. 419/05. In addition, guidance in the ESDM Procedure Document was followed, as appropriate.
Contaminant emissions are assessed using the AERMOD dispersion model and the maximum POI concentrations were compared to Schedule 3 standards of O. Reg. 419/05.
All the emission rates listed in Tables 2a and 2b correspond to the operating scenario where all significant sources are operating simultaneously at their individual maximum rates of production. Therefore, the emission rates listed in Tables 2a and 2b are conservative and overestimate the actual emissions.
A POI concentration for each significant contaminant emitted from the Facility was estimated based on the calculated emission rates and the output from the AERMOD dispersion model. The results are presented in Tables 5a and 5b and were compared against the respective MOE POI Limits.
Contaminants that do not have MOE POI Limits were screened against the JSL limits.
All the predicted POI concentrations are below the corresponding limits. At 91%, nitrogen oxides has the highest concentration relative to its MOE POI Limit for the normal operations scenario. For the commissioning operations scenario, PAH as benzo(a)pyrene has the highest concentration at 87% of its MOE POI Limit.
It is assumed that the conservative emission rates, when combined with the conservative operating conditions and conservative dispersion modelling assumptions, are not likely to under predict the concentrations at a receptor. Therefore, this assessment conservatively demonstrates that the Facility can operate in compliance with s.20 of O. Reg. 419/05.
EMISSION SUMMARY AND DISPERSION MODELLING REPORT
March 2012 Report No. 11-1151-0292
Report Signature Page
GOLDER ASSOCIATES LTD.
Emily Lau, B.A.Sc., P.Eng. Anthony Ciccone, Ph.D., P.Eng. Air Quality Engineer Principal
EKL/ADC/ng
Golder, Golder Associates and the GA globe design are trademarks of Golder Associates Corporation.
n:\active\2011\1151\11-1151-0292 bioenv-biogas rea-kawartha\air-noise\air\report\esdm\final\11-1151-0292 rpt mar12 kawartha biogas esdm.docx
Original signed by Original signed by
March 2012 11-1151-0292
Source IDSource Description
or TitleGeneral Location
S01 Emergency Flare Flare Pad (Main Plant) Products of Biogas Combustion Yes Yes N/A
S02 Ammonium Sulphate Tank Main Plant Ammonium Sulphate Yes Yes N/AS03 Sulphuric Acid Tank Main Plant Sulphuric Acid Yes Yes N/A
S04 CHP Unit 1 Air InletCHP Building (Main
Plant)None No No No emissions expected.
S05 CHP Unit 1 Cooler 1CHP Building (Main
Plant)None No No No emissions expected.
S06 CHP Unit 1 Cooler 2CHP Building (Main
Plant)None No No No emissions expected.
S07 CHP Unit 1 Air OutletCHP Building (Main
Plant)None No No No emissions expected.
S08 CHP Boiler 1 StackCHP Building (Main
Plant)Products of Biogas Combustion Yes Yes N/A
S09 CHP Unit 2 Air InletCHP Building (Main
Plant)None No No No emissions expected.
S10 CHP Unit 2 Cooler 1CHP Building (Main
Plant)None No No No emissions expected.
S11 CHP Unit 2 Cooler 2CHP Building (Main
Plant)None No No No emissions expected.
S12 CHP Unit 2 Air OutletCHP Building (Main
Plant)None No No No emissions expected.
S13 CHP Boiler 2 StackCHP Building (Main
Plant)Products of Biogas Combustion Yes Yes N/A
S14 CHP Unit 3 Air InletCHP Building (Main
Plant)None No No No emissions expected.
S15 CHP Unit 3 Cooler 1CHP Building (Main
Plant)None No No No emissions expected.
S16 CHP Unit 3 Cooler 2CHP Building (Main
Plant)None No No No emissions expected.
S17 CHP Unit 3 Air OutletCHP Building (Main
Plant)None No No No emissions expected.
S18 CHP Boiler 3 StackCHP Building (Main
Plant)Products of Biogas Combustion Yes Yes N/A
S19 CHP Unit 4 Air InletCHP Building (Main
Plant)None No No No emissions expected.
S20 CHP Unit 4 Cooler 1CHP Building (Main
Plant)None No No No emissions expected.
S21 CHP Unit 4 Cooler 2CHP Building (Main
Plant)None No No No emissions expected.
S22 CHP Unit 4 Air OutletCHP Building (Main
Plant)None No No No emissions expected.
S23 CHP Boiler 4 StackCHP Building (Main
Plant)Products of Biogas Combustion Yes Yes N/A
Table 1
Sources and Contaminants Identification Table
Source InformationExpected Contaminants
Significant
(Yes or No)?
Modelled
(Yes or No)?Rationale
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Source IDSource Description
or TitleGeneral Location
Table 1
Sources and Contaminants Identification Table
Source InformationExpected Contaminants
Significant
(Yes or No)?
Modelled
(Yes or No)?Rationale
S24 CHP Unit 5 Air InletCHP Building (Main
Plant)None No No No emissions expected.
S25 CHP Unit 5 Cooler 1CHP Building (Main
Plant)None No No No emissions expected.
S26 CHP Unit 5 Cooler 2CHP Building (Main
Plant)None No No No emissions expected.
S27 CHP Unit 5 Air OutletCHP Building (Main
Plant)None No No No emissions expected.
S28 CHP Boiler 5 StackCHP Building (Main
Plant)Products of Biogas Combustion Yes Yes N/A
S29 Ammonia Scrubber 1 Main Plant Ammonia Yes Yes N/AS30 Ammonia Scrubber 2 Main Plant Ammonia Yes Yes N/A
S31Solids Storage Building Ventilation
1Solids Storage Building None No No
No emissions expected. Material is
saturated.
S32Solids Storage Building Ventilation
2Solids Storage Building None No No
No emissions expected. Material is
saturated.
S33 Waste Water Tank Vent 1 Water Treatment Tanks None No No No emissions expected.
S34 Waste Water Tank Vent 2 Water Treatment Tanks None No No No emissions expected.
S35 Plant Exhaust Air Main Plant Hydrogen sulphide Yes Yes N/A
S36 Chemical StorageChemical Containment
(Main Plant)None No No
Contaminants emitted in negligible
amounts as per section 7.2.1 of the
ESDM Procedure Document.
S37 HVAC EquipmentOffice and Maintenance
Building (Main Plant)Products of combustion No No
Negligible source used for comfort
heating only with a total thermal input
of less than 1.58 million kJ/hr (O.Reg.
524/98)
S38Fugitive Odours from Raw
Materials Delivery
Solids
Reception/Loading
(Main Plant)
Odour Yes NoVentilation systems in place to control
odour.
S39Fugitive Odours from Raw
Materials Storage and Pre-
Treatment
Main Plant Odour Yes NoVentilation systems in place to control
odour.
S40 Desulphurization Unit Main Plant None No NoUnit is enclosed and contains no
external exhaust.
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Stack Volumetric
Flow Rate [Am³/s]
Stack Exit Gas
Temperature [°C]
Stack Inner
Diameter [m]
Stack Height
Above Grade [m]
Stack Height
Above Roof [m]Contaminant CAS No.
Maximum
Emission Rate
[g/s]
Emission
Estimating
Technique
Emissions Data
Quality
Percentage of
Overall Emissions
[%]
S02Ammonium
Sulphate TankN/A 25 N/A 6.3 N/A Ammonium sulphate 7783-20-2 1.10E-08 EC Above-Average 100%
S03 Sulphuric Acid Tank N/A 25 N/A 6.3 N/A Sulphuric acid 7664-93-9 1.53E-03 EC Above-Average 100%
S08 CHP Boiler 1 Stack 2.0 180 0.25 19 N/A Nitrogen oxides 10102-44-0 1.00E+00 EF Above-Average 20%Carbon monoxide 630-08-0 2.21E+00 EF Above-Average 20%VOCs as Benzene 71-43-2 3.01E-01 EF Above-Average 20%
Formaldehyde 50-00-0 3.01E-01 EF Above-Average 20%Particulate matter N/A 4.01E-02 EF Above-Average 20%
Sulphur dioxide 7446-09-5 1.48E-01 EF Above-Average 20%Hydrogen sulphide 7783-06-4 6.12E-04 EF Above-Average 8%
S13 CHP Boiler 2 Stack 2.0 180 0.25 19 N/A Nitrogen oxides 10102-44-0 1.00E+00 EF Above-Average 20%Carbon monoxide 630-08-0 2.21E+00 EF Above-Average 20%VOCs as Benzene 71-43-2 3.01E-01 EF Above-Average 20%
Formaldehyde 50-00-0 3.01E-01 EF Above-Average 20%Particulate matter N/A 4.01E-02 EF Above-Average 20%
Sulphur dioxide 7446-09-5 1.48E-01 EF Above-Average 20%Hydrogen sulphide 7783-06-4 6.12E-04 EF Above-Average 8%
S18 CHP Boiler 3 Stack 2.0 180 0.25 19 N/A Nitrogen oxides 10102-44-0 1.00E+00 EF Above-Average 20%Carbon monoxide 630-08-0 2.21E+00 EF Above-Average 20%VOCs as Benzene 71-43-2 3.01E-01 EF Above-Average 20%
Formaldehyde 50-00-0 3.01E-01 EF Above-Average 20%Particulate matter N/A 4.01E-02 EF Above-Average 20%
Sulphur dioxide 7446-09-5 1.48E-01 EF Above-Average 20%Hydrogen sulphide 7783-06-4 6.12E-04 EF Above-Average 8%
S23 CHP Boiler 4 Stack 2.0 180 0.25 19 N/A Nitrogen oxides 10102-44-0 1.00E+00 EF Above-Average 20%Carbon monoxide 630-08-0 2.21E+00 EF Above-Average 20%VOCs as Benzene 71-43-2 3.01E-01 EF Above-Average 20%
Formaldehyde 50-00-0 3.01E-01 EF Above-Average 20%Particulate matter N/A 4.01E-02 EF Above-Average 20%
Sulphur dioxide 7446-09-5 1.48E-01 EF Above-Average 20%Hydrogen sulphide 7783-06-4 6.12E-04 EF Above-Average 8%
S28 CHP Boiler 5 Stack 2.0 180 0.25 19 N/A Nitrogen oxides 10102-44-0 1.00E+00 EF Above-Average 20%Carbon monoxide 630-08-0 2.21E+00 EF Above-Average 20%VOCs as Benzene 71-43-2 3.01E-01 EF Above-Average 20%
Formaldehyde 50-00-0 3.01E-01 EF Above-Average 20%Particulate matter N/A 4.01E-02 EF Above-Average 20%
Sulphur dioxide 7446-09-5 1.48E-01 EF Above-Average 20%Hydrogen sulphide 7783-06-4 6.12E-04 EF Above-Average 8%
S29Ammonia Scrubber
19.4 15 0.45 6 N/A Ammonia 7664-41-7 7.70E-01 EC Above-Average 100%
S30Ammonia Scrubber
29.4 15 0.45 6 N/A Ammonia 7664-41-7 0.00E+00 EC Above-Average <1%
S35 Plant Exhaust Air 2.3 20 0.41 8 N/A Hydrogen sulphide 7783-06-4 4.46E-03 EC Average 59%
Notes:"V-ST" - Validated Source Test, "ST" - Source Test, "EF" - Emission Factor, "MB" Mass Balance, "EC" - Engineering Calculation
Table 2a
Normal Operations Source Summary Table
Source Identifier Source Description
Source Parameters Emission Data
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Stack Volumetric
Flow Rate [Am³/s]
Stack Exit Gas
Temperature [°C]
Stack Inner
Diameter [m]
Stack Height
Above Grade [m]
Stack Height
Above Roof [m]Contaminant CAS No.
Maximum
Emission Rate
[g/s]
Emission
Estimating
Technique
Emissions Data
Quality
Percentage of
Overall Emissions
[%]S01 Emergency Flare 2.0 900 0.3 14 N/A Nitrogen oxides 10102-44-0 1.18E-01 EF Above-Average 6%
Carbon monoxide 630-08-0 1.44E-02 EF Above-Average 100%Sulphur dioxide 7446-09-5 2.39E-02 EF Above-Average 100%
Particulate matter N/A 2.21E-01 EF Above-Average 100%PAH as Benzo(a)pyrene 50-32-8 2.26E-05 EC Above-Average 100%
Hydrogen sulphide 7783-06-4 1.97E-02 EC Above-Average 82%
S02Ammonium
Sulphate TankN/A 25 N/A 6.3 N/A Ammonium sulphate 7783-20-2 1.10E-08 EC Above-Average 100%
S03 Sulphuric Acid Tank N/A 25 N/A 6.3 N/A Sulphuric acid 7664-93-9 1.53E-03 EC Above-Average 100%
S23 CHP Boiler 4 Stack 1.0 180 0.25 19 N/A Nitrogen oxides 10102-44-0 8.59E-01 EF Above-Average 47%
S28 CHP Boiler 5 Stack 1.0 180 0.25 19 N/A Nitrogen oxides 10102-44-0 8.59E-01 EF Above-Average 47%
S29Ammonia Scrubber
19.4 15 0.45 6 N/A Ammonia 7664-41-7 7.70E-01 EC Above-Average 100%
S30Ammonia Scrubber
29.4 15 0.45 6 N/A Ammonia 7664-41-7 0.00E+00 EC Above-Average <1%
S35 Plant Exhaust Air 2.3 20 0.41 8 N/A Hydrogen sulphide 7783-06-4 4.46E-03 EC Average 18%
Notes:"V-ST" - Validated Source Test, "ST" - Source Test, "EF" - Emission Factor, "MB" Mass Balance, "EC" - Engineering Calculation
Table 2b
Commissioning Operations Source Summary Table
Source Identifier Source Description
Source Parameters Emission Data
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Relevant Section of the Regulation Section TitleSummary of How the Approved Dispersion
Model Was Used
Location of Supporting
Documentation in ESDM Report
Section 8Negligible Sources of
Contaminants
Sources and contaminants that were considered
negligible were explicitly identified, and
therefore were not modelled in accordance with
s.8 of O.Reg.419/05.
Section 4.0, Table 1
Section 9 Same Structure Contamination
Not applicable as the Facility is the only tenant
occupying the site, and does not have a child
care facility, health care facility, senior's
residence, long-term care facility or an
education facility located at the on-site.
N/A
Section 10 Operating Conditions
All equipment in each modelling scenario was
assumed to be operating at the maximum
production rates, unless otherwise specified.
Section 5.0
Section 11Source of Contaminant Emission
Rates
The emission rate for each significant
contaminant emitted from a significant source
was estimated.
Section 5.0, Table 2
Section 12
Combined Effect of Assumptions
for Operating Conditions and
Emission Rates
The Operating Conditions were estimated in
accordance with s.10(1) 1 and s.11(1) 1 of
O.Reg.419/05 and are therefore considered to
result in the highest POI concentration that the
Facility is capable of for each contaminant
emitted.
Section 5.0
Section 13 Meteorological ConditionsMeteorological conditions were obtained for the
Ottawa, Peterborough and Belleville region from
the MOE website.
Section 7.0
Section 14Area of Modelling Coverage
(receptor locations)
Receptor grid was developed using the grid
density provided in s.14 of O.Reg.419/05.Section 7.0, Figure 6
Section 15Stack Height for Certain New
Sources of Contaminant
Building downwash accounted for using BPIP
pre-processor.Section 7.0
Section 16 Terrain DataTerrain data was assessed for sources and
receptors at the Facility using AERMAP.Section 7.0, Figure 5
Section 17 Averaging Periods
Maximum emission scenarios were developed
for 1-hour and 24-hour averaging periods. For
averaging periods less than 1-hr, POI
concentrations were adjusted using s.17.2 of
O.Reg.419/05.
Section 7.0
Dispersion Modelling Input Summary Table
Table 3
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Stack Height
Above Grade
[m]
Stack Exit Gas
Temperature
[K]
Stack Exit
Velocity [m/s]
Stack Inner
Diameter [m]
Stack
Volumetric
Flow Rate
[Am³/s]
X-coordinate Y-Coordinate
S08 CHP Boiler 1 Stack Point 19 453 40.9 0.25 2.0 275333 4924736 Nitrogen oxides 10102-44-0 1.00E+00 24
S08 Carbon monoxide 630-08-0 2.21E+00 24S08 VOCs as Benzene 71-43-2 3.01E-01 24S08 Formaldehyde 50-00-0 3.01E-01 24S08 Particulate matter N/A 4.01E-02 24S08 Sulphur dioxide 7446-09-5 1.48E-01 24S08 Hydrogen sulphide 7783-06-4 6.12E-04 24
S13 CHP Boiler 2 Stack Point 19 453 40.9 0.25 2.0 275333 4924735 Nitrogen oxides 10102-44-0 1.00E+00 24
S13 Carbon monoxide 630-08-0 2.21E+00 24S13 VOCs as Benzene 71-43-2 3.01E-01 24S13 Formaldehyde 50-00-0 3.01E-01 24S13 Particulate matter N/A 4.01E-02 24S13 Sulphur dioxide 7446-09-5 1.48E-01 24S13 Hydrogen sulphide 7783-06-4 6.12E-04 24
S18 CHP Boiler 3 Stack Point 19 453 40.9 0.25 2.0 275333 4924735 Nitrogen oxides 10102-44-0 1.00E+00 24
S18 Carbon monoxide 630-08-0 2.21E+00 24S18 VOCs as Benzene 71-43-2 3.01E-01 24S18 Formaldehyde 50-00-0 3.01E-01 24S18 Particulate matter N/A 4.01E-02 24S18 Sulphur dioxide 7446-09-5 1.48E-01 24S18 Hydrogen sulphide 7783-06-4 6.12E-04 24
S23 CHP Boiler 4 Stack Point 19 453 40.9 0.25 2.0 275332 4924735 Nitrogen oxides 10102-44-0 1.00E+00 24
S23 Carbon monoxide 630-08-0 2.21E+00 24S23 VOCs as Benzene 71-43-2 3.01E-01 24S23 Formaldehyde 50-00-0 3.01E-01 24S23 Particulate matter N/A 4.01E-02 24S23 Sulphur dioxide 7446-09-5 1.48E-01 24S23 Hydrogen sulphide 7783-06-4 6.12E-04 24
S28 CHP Boiler 5 Stack Point 19 453 40.9 0.25 2.0 275332 4924736 Nitrogen oxides 10102-44-0 1.00E+00 24
S28 Carbon monoxide 630-08-0 2.21E+00 24S28 VOCs as Benzene 71-43-2 3.01E-01 24S28 Formaldehyde 50-00-0 3.01E-01 24S28 Particulate matter N/A 4.01E-02 24S28 Sulphur dioxide 7446-09-5 1.48E-01 24S28 Hydrogen sulphide 7783-06-4 6.12E-04 24
S29Ammonia Scrubber
1Point 6 288 59.3 0.45 9.4 275392 4924762 Ammonia 7664-41-7 7.70E-01 24
Averaging Period
[hours]
Table 4a
Dispersion Modelling Source Summary Table
Source ID Source ID(s) Source Type
Modelling Source Data Emissions Data
Contaminant CAS No.Maximum Emission
Rate [g/s]
N:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 6 of 10
Made by: EKL
Checked by: KSAGolder Associates
March 2012 11-1151-0292
Stack Height
Above Grade
[m]
Stack Exit Gas
Temperature
[K]
Stack Exit
Velocity [m/s]
Stack Inner
Diameter [m]
Stack
Volumetric
Flow Rate
[Am³/s]
X-coordinate Y-Coordinate
Averaging Period
[hours]
Table 4a
Dispersion Modelling Source Summary Table
Source ID Source ID(s) Source Type
Modelling Source Data Emissions Data
Contaminant CAS No.Maximum Emission
Rate [g/s]
S30Ammonia Scrubber
2Point 6 288 59.3 0.45 9.4 275396 4924763 Ammonia 7664-41-7 N/A 24
S35 Plant Exhaust Air Point 8 293 17.7 0.4064 2.3 275328 4924735 Hydrogen sulphide 7783-06-4 4.46E-03 24
Modelling ID Source ID(s) Source TypeBuilding Length
[m]
Release Height
[m]
Initial Lateral
Dimension [m]
Initial Vertical
Dimension [m]
Initial
Lateral
Dimension
[m]
X-coordinate Y-Coordinate Contaminant CAS No.Maximum Emission
Rate [g/s]
Averaging Period
[hours]
S02Ammonium
Sulphate TankVolume 4.5 6.3 1.05 2.93 1.05 275323 4924710 Ammonium sulphate 7783-20-2 1.10E-08 24
S03Sulphuric Acid
TankVolume 4.5 6.3 1.05 2.93 1.05 275324 4924703 Sulphuric acid 7664-93-9 1.53E-03 24
N:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 7 of 10
Made by: EKL
Checked by: KSAGolder Associates
March 2012 11-1151-0292
Stack Height
Above Grade [m]
Stack Exit Gas
Temperature
[K]
Stack Exit
Velocity [m/s]
Stack Inner
Diameter [m]
Stack
Volumetric
Flow Rate
[Am³/s]
X-coordinate Y-Coordinate
S23 CHP Boiler 4 Stack Point 19 453 20.4 0.25 1.0 275332 4924735 Nitrogen oxides 10102-44-0 8.59E-01 24
S28 CHP Boiler 5 Stack Point 19 453 20.4 0.25 1.0 275332 4924736 Nitrogen oxides 10102-44-0 8.59E-01 24
S29 Ammonia Scrubber 1 Point 6 288 59.3 0.45 9.4 275392 4924762 Ammonia 7664-41-7 7.70E-01 24
S30 Ammonia Scrubber 2 Point 6 288 59.3 0.45 9.4 275396 4924763 Ammonia 7664-41-7 N/A 24
S35 Plant Exhaust Air Point 8 293 17.7 0.4064 2.3 275328 4924735 Hydrogen sulphide 7783-06-4 4.46E-03 24
Modelling ID Source ID(s) Source TypeBuilding Length
[m]
Release Height
[m]
Initial Lateral
Dimension [m]
Initial Vertical
Dimension [m]
Initial
Lateral
Dimension
[m]
X-coordinate Y-Coordinate Contaminant CAS No.Maximum Emission
Rate [g/s]
Averaging Period
[hours]
S02Ammonium Sulphate
TankVolume 4.5 6.3 1.0 2.9 1.05 275323 4924710 Ammonium sulphate 7783-20-2 1.10E-08 24
S03 Sulphuric Acid Tank Volume 4.5 6.3 1.0 2.9 1.05 275324 4924703 Sulphuric acid 7664-93-9 1.53E-03 24
Modelling ID Source ID(s) Source TypeStack Height
Above Grade [m]
Stack Exit Gas
Temperature
[K]
Stack Exit
Velocity [m/s]
Heat Release
[BTU/hr]
Radiation
Loss [%]X-coordinate Y-Coordinate Contaminant CAS No.
Maximum Emission
Rate [g/s]
Averaging Period
[hours]
S01 Emergency Flare Flare 14 1173 39.6 2.06E+07 50.0 275323 4924749 Nitrogen oxides 10102-44-0 1.18E-01 24S01 Carbon monoxide 630-08-0 1.44E-02 24S01 Sulphur dioxide 7446-09-5 2.39E-02 24S01 Particulate matter N/A 2.21E-01 24
S01PAH as
Benzo(a)pyrene50-32-8 2.26E-05 24
S01 Hydrogen sulphide 7783-06-4 1.97E-02 24
Source ID Source ID(s)
Table 4b
Commissioning Operations Dispersion Modelling Source Summary Table
Source Type
Modelling Source Data Emissions Data
Contaminant CAS No.Maximum Emission
Rate [g/s]
Averaging Period
[hours]
N:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 8 of 10
Made by: EKL
Checked by: KSAGolder Associates
March 2012 11-1151-0292
Contaminant CAS No.
Total Facility
Emission Rate
[g/s]
Air Dispersion
Model Used
Maximum POI
Concentration
[µg/m³]
Averaging
Period [hours]
MOE POI Limit
[µg/m³]Limiting Effect
Regulation Schedule
No.
Percentage of MOE
Limit [%]
Ammonia 7664-41-7 7.70E-01 AERMOD 8.63E+01 24 100 Health Schedule 3 86%
Ammonium sulphate 7783-20-2 1.10E-08 AERMOD 2.00E-05 24 20 — JSL Below JSL
Carbon monoxide 630-08-0 1.10E+01 AERMOD 9.63E+02 ½ 6000 Health Schedule 3 16%
Formaldehyde 50-00-0 1.50E+00 AERMOD 4.63E+01 24 65 Health Schedule 3 71%
Hydrogen sulphide 7783-06-4 7.52E-03 AERMOD 1.74E+00 24 7 Health Schedule 3 25%
Hydrogen sulphide 7783-06-4 7.52E-03 AERMOD 8.69E+00 10-min 13 Odour Schedule 3 67%
Nitrogen oxides 10102-44-0 5.02E+00 AERMOD 1.54E+02 24 200 Health Schedule 3 77%
Nitrogen oxides 10102-44-0 5.02E+00 AERMOD 3.63E+02 1 400 Health Schedule 3 91%
Particulate matter N/A 2.01E-01 AERMOD 6.16E+00 24 120 Visibility Schedule 3 5%
Sulphur dioxide 7446-09-5 7.42E-01 AERMOD 2.28E+01 24 275 Health & Vegetation Schedule 3 8%
Sulphur dioxide 7446-09-5 7.42E-01 AERMOD 5.37E+01 1 690 Health & Vegetation Schedule 3 8%
Sulphuric acid 7664-93-9 1.53E-03 AERMOD 2.38E+00 24 5 Health Schedule 3 48%
VOCs as Benzene 71-43-2 1.50E+00 AERMOD 4.63E+01 24 100 — Schedule 6 Below URT
Table 5a
Normal Operations Emission Summary Table
Made By: EKL Checked By: KSA
N:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 9 of 10 Golder Associates
March 2012 11-1151-0292
Contaminant CAS No.
Total Facility
Emission Rate
[g/s]
Air Dispersion
Model Used
Maximum POI
Concentration
[µg/m³]
Averaging
Period [hours]
MOE POI Limit
[µg/m³]Limiting Effect
Regulation Schedule
No.
Percentage of MOE
Limit [%]
Ammonia 7664-41-7 7.70E-01 AERMOD 8.66E+01 24 100 Health Schedule 3 87%
Ammonium sulphate 7783-20-2 1.10E-08 AERMOD 2.00E-05 24 20 — JSL Below JSL
Carbon monoxide 630-08-0 1.44E-02 AERMOD 1.73E+00 ½ 6000 Health Schedule 3 <1%
Hydrogen sulphide 7783-06-4 2.42E-02 AERMOD 1.97E+00 24 7 Health Schedule 3 28%
Hydrogen sulphide 7783-06-4 2.42E-02 AERMOD 8.69E+00 10-min 13 Odour Schedule 3 67%
Nitrogen oxides 10102-44-0 1.83E+00 AERMOD 1.85E+02 1 400 Health Schedule 3 46%
Nitrogen oxides 10102-44-0 1.83E+00 AERMOD 6.57E+01 24 200 Health Schedule 3 33%
PAH as Benzo(a)pyrene 50-32-8 2.26E-05 AERMOD 9.60E-04 24 0.0011 Health Guideline 87%
Particulate matter N/A 2.21E-01 AERMOD 1.11E+01 24 120 Visibility Schedule 3 9%
Sulphur dioxide 7446-09-5 2.39E-02 AERMOD 1.20E+00 24 275 Health & Vegetation Schedule 3 <1%
Sulphur dioxide 7446-09-5 2.39E-02 AERMOD 2.40E+00 1 690 Health & Vegetation Schedule 3 <1%
Sulphuric acid 7664-93-9 1.53E-03 AERMOD 2.38E+00 24 5 Health Schedule 3 48%
Table 5b
Commissioning Operations Emission Summary Table
Made By: EKL Checked By: KSA
N:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 10 of 10 Golder Associates
!
!
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!
!
!
!
!
!
!
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!
!!
!
!!
!
!
!
!
BE
LM
ON
T TO
WN
SH
IP 6T
H L
INE
HWY 7
HWY 7
CO
UN
TY
RD
50
Preneveau
1
2
3
4
5
6
78
9
10
1112
13
14
274500
274500
275000
275000
275500
275500
276000
276000
4924
500
4924
500
4925
000
4925
000
G:\P
roje
cts\
2011
\11-
115
1-02
92_
Ka
war
tha_
Bio
Gas
\GIS
\MX
Ds\
Rep
ortin
g\A
ir\S
ite_L
oca
tion.
mxd
³LEGEND
Base Data - MNR NRVIS, obtained 2004, CANMAP v2006.4Produced by Golder Associates Ltd under licence from Ontario Ministry of Natural Resources, © Queens Printer 2008Projection: Transverse Mercator Datum: NAD 83 Coordinate System: UTM Zone 18
REV. 0.0
Mississauga, Ontario
DESIGN
SITE LOCATION PLAN
FIGURE: 1
PROJECT NO. 11-1151-0292 SCALE AS SHOWN
PROJECT
TITLE
GIS
REVIEW
KD 23 Nov. 2011
CHECK
RENEWABLE ENERGY APPROVAL
KAWARTHA BIOGAS FACILITY
KD 1 Feb. 2012
EKL
EKL
1 Feb. 2012
1 Feb. 2012
!.
!.
!.
!.
!.
!. !.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.!.
!.
!.!.
!.
!.
!.
HIGHWAY 7
HIGHWAY 7
Marmora
Havelock
Norwood
TrentRiver
AllanMills
AshbyMill Blairton
Connellys
CroweBridge
Rockdale
Woodland
Bonarlaw
CentreDummer
ChaseCorners
Cottesloe
FreemanCorners
Healey Falls
Preneveau
RushPoint
SpringBrookStanwood
Deloro
RylstoneSouthDummer
Kellers
BlairtonStation
MarmoraStation
REFERENCE
INDEX MAP
SCALE
Study Area
1:5,000
100 0 100 200 30050
METERS
Site Boundary Point
Roads
Railways
! ! Utility Line
Watercourse
Proposed Building
Site Boundary
Id Easting Northing
1 275374.4 4924843.2
2 275423.5 4924870.4
3 275440.3 4924891.9
4 275496.6 4924848.1
5 275504.2 4924826.5
6 275510.4 4924790.0
7 275501.2 4924763.0
8 275504.2 4924746.3
9 275464.7 4924674.2
10 275458.9 4924640.1
11 275460.4 4924625.7
12 275458.3 4924593.9
13 275326.6 4924570.1
14 275295.9 4924740.3
SITE BOUNDARY POINT COORDINATES
DRAWING NUMBER
APPROVED:
CHECKED:
NUM
REV
DRAWN:
DESIGNED:
DESCRIPTION CHK'D DATE
BY
PROJECT NO.:
DRWN
BY
10 1/2
ATTENTION:
IF THIS BAR DOES NOT
MEASURE 1" @ 22x34 or
1
2
" @ 11x17, THEN
DRAWING IS NOT TO
SCALE - SCALE
ACCORDINGLY
SCALE:
PURENERGY PROJECT
CANADA, NA
ANAERGIA
NOV. 2011
311210003
REV
1
A
B
C
D
E
F
G
H
I
J
A
B
C
D
E
F
G
H
I
J
234678910111213141516
12345678910111213141516
A
B1.0BLOCK DIAGRAM
NTS
A.K.
WBL
TANKER
RECEIPTION
ANAEROBIC
DIGESTERS
(4 UNITS)
REJECTS
DEWATERED
SOLIDS
FLARE
(1 UNITS)
TREATED
EFFLUENT
RECEPTION TANKS
(3 UNITS)
ELECTRICITY
COMBINED
HEAT &
POWER UNIT
(5 UNITS)
HOT WATER
SUPPLY
CONDENSATE
HOT WATER
RETURN
SOLIDS
SEPERATION
(3 UNITS)
DUMP TRUCK
RECEIPTION
DISPOSE
OFF SITE
PRETREATMENT
GAS
DRYING
(1 UNIT)
DESULPHERIZATION
(1 UNIT)
SERVICE BOXES
HYDRAULIC
MIXERS
BY PRODUCT
VENT TO
ATMOSPHERE
AMMONIUM SULPHATE
STORAGE
(1 UNIT)
AMMONIA
STRIPPER
(2 UNITS)
DE AMMONIFIED EFFLUENT
(RECYCLED)
AMMONIA
SCRUBBER
(2 UNITS)
CENTRIFUGAL
BLOWER
CHEMICAL
RECEIPTION
SULPHURIC ACID
STORAGE
DRY SOLIDS
RECEIPTION
SYRUP AND
DWG
#1
#2
#3 #4
HEAT EXCHANGER
#5 #6 #7 #8
BUFFER TANK
WWTP
DRY SOLIDS
STORAGE
BLOWER
HOT WATER LOOP
DE AMMONIFIED
EFFLUENT /
DILUTION TANK
(1 UNIT)
GRID
INTERCONNECTION
AIR
COMBINATION AIR FOR CHP
TO
DESULPHURIZATION
TO AMMONIA
RECOVERY
POLYMER
DOSING
STEAM
BOILER
STEAM
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DMSRL1 LR
CHP
SRL2
SS
WTT2
WTT1
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DWRT3
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D2B
D2A
D4B
D4A
D1B
D1A
D3B
D3A
SRLT
3029
2
3
1823
28
81335
1
275300
275300
275400
275400
275500
275500
4924
60 0
4924
600
4924
700
4924
700
4924
800
4924
800
G:\P
roje
cts\
2011
\11-
115
1-02
92_
Ka
war
tha_
Bio
Gas
\GIS
\MX
Ds\
Rep
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out.m
xd
³LEGEND
Base Data - MNR NRVIS, obtained 2004, CANMAP v2006.4Produced by Golder Associates Ltd under licence from Ontario Ministry of Natural Resources, © Queens Printer 2008Projection: Transverse Mercator Datum: NAD 83 Coordinate System: UTM Zone 18
REV. 0.0
Mississauga, Ontario
DESIGN
ROOF LAYOUT
FIGURE: 3
PROJECT NO. 11-1151-0292 SCALE AS SHOWN
PROJECT
TITLE
GIS
REVIEW
KD 23 Nov. 2011
CHECK
RENEWABLE ENERGY APPROVAL
KAWARTHA BIOGAS FACILITY
KD 22 Feb. 2012
EKL
EKL
22 Feb. 2012
22 Feb. 2012
!.
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!.
!.
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HIGHWAY 7
HIGHWAY 7
Marmora
Havelock
Norwood
TrentRiver
AllanMills
AshbyMill Blairton
Connellys
CroweBridge
Rockdale
Woodland
Bonarlaw
CentreDummer
ChaseCorners
Cottesloe
FreemanCorners
Healey Falls
Preneveau
RushPoint
SpringBrookStanwood
Deloro
RylstoneSouthDummer
Kellers
BlairtonStation
MarmoraStation
REFERENCE
INDEX MAP
SCALE
Study Area
1:1,000
20 0 20 40 6010
METRES
!. Point Source
�) Volume Source
Roads
Railways
Site Boundary
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4TH
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273000
273000
274000
274000
275000
275000
276000
276000
277000
277000
278000
278000
279000
279000
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000
4922
000
4923
000
4923
000
4924
000
4924
000
4925
000
4925
000
4926
000
4926
000
G:\P
roje
cts\
2011
\11-
115
1-02
92_
Ka
war
tha_
Bio
Gas
\GIS
\MX
Ds\
Rep
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g\A
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and_
Use
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ing.
mxd
³LEGEND
Base Data - MNR NRVIS, obtained 2004, CANMAP v2006.4Produced by Golder Associates Ltd under licence from Ontario Ministry of Natural Resources, © Queens Printer 2008Projection: Transverse Mercator Datum: NAD 83 Coordinate System: UTM Zone 18Zoning data obtained from The Township ofHavelock-Belmont-Methuen
REV. 0.0
Mississauga, Ontario
DESIGN
LAND USE ZONING DESIGNATION PLAN
FIGURE: 4
PROJECT NO. 11-1151-0292 SCALE AS SHOWN
PROJECT
TITLE
GIS
REVIEW
KD 23 Nov. 2011
CHECK
RENEWABLE ENERGY APPROVAL
KAWARTHA BIOGAS FACILITY
KD 1 Feb. 2012
EKL
EKL
1 Feb. 2012
1 Feb. 2012
!.
!.
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!.
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!.
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!.
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!.
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HIGHWAY 7
HIGHWAY 7
Marmora
Havelock
Norwood
TrentRiver
AllanMills
AshbyMill Blairton
Connellys
CroweBridge
Rockdale
Woodland
Bonarlaw
CentreDummer
ChaseCorners
Cottesloe
FreemanCorners
Healey Falls
Preneveau
RushPoint
SpringBrookStanwood
Deloro
RylstoneSouthDummer
Kellers
BlairtonStation
MarmoraStation
REFERENCE
INDEX MAP
SCALE
Study Area
1:20,000
0.5 0 0.5 10.25
KILOMETERS
Roads
Railways
Site Boundary
!
!
!
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SH
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PreneveauBlairtonStation
273000
273000
274000
274000
275000
275000
276000
276000
277000
277000
278000
278000
279000
279000
4922
000
4922
000
4923
000
4923
000
4924
000
4924
000
4925
000
4925
000
4926
000
4926
000
G:\P
roje
cts\
2011
\11-
115
1-02
92_
Ka
war
tha_
Bio
Gas
\GIS
\MX
Ds\
Rep
ortin
g\A
ir\T
erra
in_E
leva
tions
.mxd
³LEGEND
Base Data - MNR NRVIS, obtained 2004, CANMAP v2006.4Produced by Golder Associates Ltd under licence from Ontario Ministry of Natural Resources, © Queens Printer 2008Projection: Transverse Mercator Datum: NAD 83 Coordinate System: UTM Zone 18
REV. 0.0
Mississauga, Ontario
DESIGN
TERRAIN ELEVATIONS
FIGURE: 5
PROJECT NO. 11-1151-0292 SCALE AS SHOWN
PROJECT
TITLE
GIS
REVIEW
KD 23 Nov. 2011
CHECK
RENEWABLE ENERGY APPROVAL
KAWARTHA BIOGAS FACILITY
KD 1 Feb. 2012
EKL
EKL
1 Feb. 2012
1 Feb. 2012
!.
!.
!.
!.
!.
!. !.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.!.
!.
!.!.
!.
!.
!.
HIGHWAY 7
HIGHWAY 7
Marmora
Havelock
Norwood
TrentRiver
AllanMills
AshbyMill Blairton
Connellys
CroweBridge
Rockdale
Woodland
Bonarlaw
CentreDummer
ChaseCorners
Cottesloe
FreemanCorners
Healey Falls
Preneveau
RushPoint
SpringBrookStanwood
Deloro
RylstoneSouthDummer
Kellers
BlairtonStation
MarmoraStation
REFERENCE
INDEX MAP
SCALE
Study Area
1:20,000
0.5 0 0.5 10.25
KILOMETERS
Roads
Railways
! ! Utility Line
Watercourse
Waterbody
Site Boundary
Elevation (masl)High : 261
Low : 157
!.
!.
!.
!.
!.
!.
!.
!.
!.
F R
26A
BROWNS LINE RD
TR
ILL
IUM
DR
CO
UN
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RD
46
CO
NC
ST
GEORGE ST EOA
K S
T
LK
RD
FR 36
MA
RY
ST
ALMAC DR
FR
31
FR 2
7A
FR 31G
HEMLOC K LANE
OTTAWA ST W
FR 31A
OLD NORWOOD RD
WE
LLE
R R
D
FR 33
CH
UR
CH
ST
SEY
MO
UR
ST
CH
AN
DO
S S
T
ME
THU
EN S
T
OTTAWA ST E
MCLEAN AVE
CO
UN
TY
RD
50
CHURCH RD
POMER OY DR
FR 1
FR
34
HWY 7
TIM
BE
RL
AN
D D
R
14TH LINE E
VIE
WM
OU
NT
AVE
ROUND LK RD
FR 53
MI L
E O
F ME
MO
RIE
S R
D
COUNTY RD 42
COOK
RD
BE
LMO
NT
TOW
NS
HIP
2ND
LINE
FR 28
BE
LMO
NT
TOW
NS
HIP
6TH
LIN
E
13TH LINE E
HWY 7
CR
OW
E R
IVE
R R
D
COLE RD
EV
ER
GR
EE
N
RD
BE
LM
ON
T T
OW
NS
HIP
3RD
LIN
E
CO
UN
TY
RD
30
S B
EL
MO
NT
TO
WN
SH
IP 7T
H L
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BE
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NS
HIP 2N
D L
INE
BE
LMO
NT
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NS
HIP
4TH LIN
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FR 2
CO
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TY R
D 48
CO
UN
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RD
48
DEWEY RD
FR
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FR 31F
WA
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FR 26
FR
26
FR
37
FR
3A
FR
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FR 26F
FR 3
CO
NC
8 B
EL
MO
NT
TOW
NS
HIP
LK S
T
FR 30
SAW
MIL
L B
AY
RD
BIG
ISLA
ND
RD
FR 27
TE
RR
RD
BLA
IRTO
N R
D
FR
5
Havelock
AshbyMill
Blairton
ChaseCorners
FreemanCorners
Preneveau
RushPoint
BlairtonStation
270000
270000
271000
271000
272000
272000
273000
273000
274000
274000
275000
275000
276000
276000
277000
277000
278000
278000
279000
279000
280000
280000
281000
281000
4920
000
4920
000
4921
000
4921
000
4922
000
4922
000
4923
000
4923
000
4924
000
4924
000
4925
000
4925
000
4926
000
4926
000
4927
000
4927
000
4928
000
4928
000
4929
000
4929
000
G:\P
roje
cts\
2011
\11-
115
1-02
92_
Ka
war
tha_
Bio
Gas
\GIS
\MX
Ds\
Rep
ortin
g\A
ir\D
ispe
rsio
n_M
odel
ling.
mxd
³LEGEND
Base Data - MNR NRVIS, obtained 2004, CANMAP v2006.4Produced by Golder Associates Ltd under licence from Ontario Ministry of Natural Resources, © Queens Printer 2008Projection: Transverse Mercator Datum: NAD 83 Coordinate System: UTM Zone 18
REV. 0.0
Mississauga, Ontario
DESIGN
DISPERSION MODELLING RECEPTORS
FIGURE: 6
PROJECT NO. 11-1151-0292 SCALE AS SHOWN
PROJECT
TITLE
GIS
REVIEW
KD 23 Nov. 2011
CHECK
RENEWABLE ENERGY APPROVAL
KAWARTHA BIOGAS FACILITY
KD 1 Feb. 2012
EKL
EKL
1 Feb. 2012
1 Feb. 2012
!.
!.
!.
!.
!.
!. !.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.!.
!.
!.!.
!.
!.
!.
HIGHWAY 7
HIGHWAY 7
Marmora
Havelock
Norwood
TrentRiver
AllanMills
AshbyMill Blairton
Connellys
CroweBridge
Rockdale
Woodland
Bonarlaw
CentreDummer
ChaseCorners
Cottesloe
FreemanCorners
Healey Falls
Preneveau
RushPoint
SpringBrookStanwood
Deloro
RylstoneSouthDummer
Kellers
BlairtonStation
MarmoraStation
REFERENCE
INDEX MAP
SCALE
Study Area
1:40,000
0.5 0 0.5 1 1.5 20.25
KILOMETERS
Receptors
Roads
Railways
Watercourse
Watercourse, Intermittent
Waterbody
Site Boundary
DM
SRL1LRCHP
SRL2
SS
WTT2
WTT1
RT1
RT2DW
RT3
BT
D2B
D2A
D4B
D4A
D1B
D1A
D3B
D3A
SRLT
275300
275300
275400
275400
275500
275500
49
24
60
0
49
24
60
0
49
24
70
0
49
24
70
0
49
24
80
0
49
24
80
0
G:\
Pro
jects
\20
11\1
1-1
15
1-0
29
2_
Ka
wa
rth
a_
Bio
Ga
s\G
IS\M
XD
s\R
ep
ort
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\Air
\Bu
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g_
Do
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wa
sh
_P
lan
.mxd
³LEGEND
Base Data - MNR NRVIS, obtained 2004, CANMAP v2006.4
Produced by Golder Associates Ltd under licence from
Ontario Ministry of Natural Resources, © Queens Printer 2008
Projection: Transverse Mercator Datum: NAD 83 Coordinate System: UTM Zone 18
REV. 0.0
Mississauga, Ontario
DESIGN
BUILDING DOWNWASH PLAN
FIGURE: 7
PROJECT NO. 11-1151-0292 SCALE AS SHOWN
PROJECT
TITLE
GIS
REVIEW
KD 23 Nov. 2011
CHECK
RENEWABLE ENERGY APPROVAL
KAWARTHA BIOGAS FACILITY
KD 22 Feb. 2012
EKL
EKL
22 Feb. 2012
22 Feb. 2012
!.
!.
!.
!.
!.
!. !.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.
!.!.
!.
!.!.
!.
!.
!.
HIGHWAY 7
HIGHWAY
7
Marmora
Havelock
Norwood
TrentRiver
AllanMills
AshbyMill Blairton
Connellys
CroweBridge
Rockdale
Woodland
Bonarlaw
CentreDummer
ChaseCorners
Cottesloe
FreemanCorners
Healey Falls
Preneveau
RushPoint
Spring
BrookStanwood
Deloro
Rylstone
SouthDummer
Kellers
BlairtonStation
MarmoraStation
REFERENCE
INDEX MAP
SCALE
Study Area
1:1,000
20 0 20 40 6010
METRES
Roads
Railways
Virtual Source
Site Boundary
Building ID Height Above Grade [m]
BT 9.3
CHP 7
D1A 9.3
D1B 7.3
D2A 9.3
D2B 7.3
D3A 9.3
D3B 7.3
D4A 9.3
D4B 7.3
DM 8
DW 9
RT1 9
RT2 9
RT3 9
SRL1 10
SRL2 6
SLRT 17
SS 6
WTT1 7
WTT2 7
EMISSION SUMMARY AND DISPERSION MODELLING REPORT
March 2012 Report No. 11-1151-0292
APPENDIX A Emission Rate Calculations
March 2012 11-1151-0292
Source Number Source 01
Source Name Emergency Flare
Source Description
Operating Rate
Biogas fuel consumption rate = 935 Nm³/hFlare Removal Efficiency = 98%H2S concentration in biogas = 2500 ppmMolecular Weight of H2S = 34.08 g/mol
Sample Calculation Biogas CombustionNitrogen oxides = 4.53E-04 kg 935 Nm³ 1 hr 1000 g
m³ hr engine 3600 s 1 kgNitrogen oxides = 0.12 g
s
Hydrogen Sulfide = 2500 ppm 1 mol K 101325 N 1 34.08 g1.00E+06 8.314 N m m² 273.15 K mol
Hydrogen Sulfide = 3.80 gmn³
Hydrogen Sulfide = 3.80 g 935 mn³ 1 hr 100% - 98%mn³ hr 3600 s
Hydrogen Sulfide = 1.97E-02 gs
Source ID Contaminant CAS NumberEmission
Factor
[kg/m³]
Concentration [ppm]Destruction
Efficiency
Emission Rate
[g/s]MOE Data
Quality
Nitrogen oxides 10102-44-0 4.53E-04 — — 1.18E-01 Above-Average
Carbon monoxide 630-08-0 5.56E-05 — — 1.44E-02 Above-Average
Sulphur dioxide 7446-09-5 9.21E-05 — — 2.39E-02 Above-Average
Particulate matter N/A 8.49E-04 — — 2.21E-01 Above-Average
PAH as Benzo(a)pyrene 50-32-8 8.71E-06 — 99% 2.26E-05 Above-Average
Hydrogen sulphide 7783-06-4 — 2500 98% 1.97E-02 Above-Average
The emission rates for the emergency flare were calculated using emission factors obtained from Environment Canada's biogas flaring emissions estimation tool.
The emergency flare is designed for 100% capacity (replacement of all 5 engines). Most likely, the emergency flare will only operate during maintenance operations or during
emergency situations. These scenarios have not been modelled as maintenance or emergencies are not long term events.
The flare will also operate during commissioning operations that will last approximately 2 months. during this time, the flare will burn off approximately 935 Nm³/hr of biogas or 25%
of the total plant capacity.
It is assumed that 98% of the untreated biogas is removed during combustion, with 2% of the compounds being emitted. It is assumed that 98% of the hydrogen sulphide in the
biogas is destroyed by the flaring process and that 99% of the PAHs would be destroyed by the flaring process.
The biogas plant contains an emergency flare which may be fired with untreated biogas during process upset conditions. The untreated biogas may contain hydrogen sulfide.
S01
Made by: JLK
Checked by: EKLN:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 1 of 8 Golder Associates
March 2012 11-1151-0292
Source Number Source 02
Source Name Ammonium Sulphate Tank
Source Description
Operating Rate
Maximum tank storage capacity = 100,800.00 LTank Storage Temperature = 25 °C
298 KFilling Frequency = 22 fills per weekFilling Rate = 2 m³/hr
0.56 L/sSample Calculation Tank Filling Emissions for One Tank
ammonium sulphate = 3.35E-05 mm Hg 0.08 (mole fraction) 0.56 L 132.14 g 1 mol·K 1 101.3 kPa
s mol 8.314 kPa·L 298 K 760 mm Hgammonium sulphate = 1.10E-08 g
s
Source ID ContaminantCAS
Number
Saturated
Vapour
Pressure
[mm Hg]
Molecular
Weight
[g/mol]
Percent by
Weight
[%]
Moles
Contaminant
/kg Solvent
[g/mol]
Vapour
Mole
Fraction
Maximum
Hourly
Emission
Rate [g/s]
US EPA
Emission
Factor
Rating
MOE Data
Quality
S02 Water 7732-18-5 24.0 18.02 60%0.033
0.92 3.53 N/AAbove-
AverageS02 Ammonium sulphate 7783-20-2 3.35E-05 132.14 40% 0.00303 0.08 1.10E-08 N/A Above-Average
The biogas plant contains three ammonium sulphate storage tanks. The ammonium sulphate is one of two effluent streams from the ammonia scrubbers and will be
sold as a commidity to a third party.
The emissions are calculated using the AWMA "Vapour Emissions from a Solvent Waste Storage Tank" (December 2008) as part of Ontario Air and Noise Best
Practices.
Made by: JLK
Checked by: EKLN:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 2 of 8 Golder Associates
March 2012 11-1151-0292
Source Number Source 03
Source Name Sulphuric Acid Tank
Source Description
Operating Rate
Maximum tank storage capacity = 100,800 LTank Storage Temperature = 25 °C
298 KFilling Frequency = 1 fill per day or 1 hour per dayFilling Rate = 25 m³/hr Where does this rate come from (pretty high)
6.94 L/s
Sample Calculation Tank Filling Emissions for One Tank
sulphuric acid = 1.00E+00 mm Hg 1.00 (mole fraction) 6.94 L 98.08 g 1 mol·K 1 101.3 kPa 1 hr
s mol 8.314 kPa·L 298 K 760 mm Hg 24 hrsulphuric acid = 1.53E-03 g
s
Source ID ContaminantCAS
Number
Saturated
Vapour
Pressure
[mm Hg]
Molecular
Weight
[g/mol]
Percent by
Weight
[%]
Moles
Contaminant
/kg Solvent
[g/mol]
Vapour
Mole
Fraction
Maximum
Hourly
Emission
Rate [g/s]
MOE Data
Quality
S03 Sulphuric acid 7664-93-9 1.00E+00 98.08 100% 0.010 1.00 1.53E-03 Above-Average
The biogas plant contains one sulphuric acid storage tank. The sulphuric acid is used in the counter flow ammonia scrubbers.
The emissions are calculated using the AWMA "Vapour Emissions from a Solvent Waste Storage Tank" (December 2008) as part of Ontario Air and Noise Best
Practices.
Made by: JLK
Checked by: EKLN:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 3 of 8 Golder Associates
March 2012 11-1151-0292
Source Number Source 8, 13, 18, 23, and 28
Source Name Combined Heat and Power Engines
Source Description
Operating Rate
Exhaust gas volume dry = 7222 mn³/h (per engine)
Compound Emissions [mg/mn³]NOX 500CO 1100
VOCs 150HCHO 150
PM 20
PM2.5 15
PM10 20
SO2 74
Biogas fuel per engine = 725 m³/hrHydrogen sulphide concentration in biogas 200 ppmMolecular Weight of H2S = 34.08 g/molFlare Removal Efficiency = 99%
Sample Calculation Biogas CombustionNitrogen oxides = 500.000 mg 7222 mn³ 1 hr 1 g
mn³ hr 3600 s 1000 mgNitrogen oxides = 1.003 g
s
Hydrogen Sulfide = 200 ppm 1 mol K 101325 N 1 34.08 g1.00E+06 8.314 N m m² 273.15 K mol
Hydrogen Sulfide = 0.30 gmn³
Hydrogen Sulfide = 0.30 g 725 mn³ 1 hr 100% - 99%mn³ hr 3600 s
Hydrogen Sulfide = 6.12E-04 gs
The biogas plant contains five combined heat and power engines which may be fired with either natural gas or biogas. The facility will have a nameplate capacity
of 9.8 MW of power fuelled by a maximum biogas production of 3625 m³/hr.
The emission rates for the biogas fired engines were calculated using manufacturer's specifications for the MWM engine (model number TCG 2020 V 20) provide
in Appendix B - Supporting Information for Emission Rate Calculations. Normal operations include all five engines operating simultaneously. The biogas
produced by the digestion process is evenly divided between the five engines.
The emission rate for PM10 is used as a subsitute for total particulate matter, as a value is not available. It is assumed that 99% of the hydrogen sulphide in the
biogas is destroyed by the combustion process.
Made by: JLK
Checked by: EKLN:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 4 of 8 Golder Associates
March 2012 11-1151-0292
Source ID Contaminant CAS NumberExhaust
Flow Rate
[mn³/h]
Emission
Factor
[mg/mn³]
Emission
Rate [g/s]
MOE Data
Quality
Nitrogen oxides 10102-44-0 500 1.00E+00 Above-AverageCarbon monoxide 630-08-0 1100 2.21E+00 Above-AverageVOCs as Benzene 71-43-2 150 3.01E-01 Above-AverageFormaldehyde 50-00-0 150 3.01E-01 Above-AverageParticulate matter N/A 20 4.01E-02 Above-Average
Sulphur dioxide 7446-09-5 74 1.48E-01 Above-Average
Hydrogen sulphide 7783-06-4 N/A 6.12E-04 Above-Average
Nitrogen oxides 10102-44-0 500 1.00E+00 Above-AverageCarbon monoxide 630-08-0 1100 2.21E+00 Above-AverageVOCs as Benzene 71-43-2 150 3.01E-01 Above-AverageFormaldehyde 50-00-0 150 3.01E-01 Above-AverageParticulate matter N/A 20 4.01E-02 Above-Average
Sulphur dioxide 7446-09-5 74 1.48E-01 Above-Average
Hydrogen sulphide 7783-06-4 N/A 6.12E-04 Above-Average
Nitrogen oxides 10102-44-0 500 1.00E+00 Above-AverageCarbon monoxide 630-08-0 1100 2.21E+00 Above-AverageVOCs as Benzene 71-43-2 150 3.01E-01 Above-AverageFormaldehyde 50-00-0 150 3.01E-01 Above-AverageParticulate matter N/A 20 4.01E-02 Above-Average
Sulphur dioxide 7446-09-5 74 1.48E-01 Above-Average
Hydrogen sulphide 7783-06-4 N/A 6.12E-04 Above-Average
Nitrogen oxides 10102-44-0 500 1.00E+00 Above-AverageCarbon monoxide 630-08-0 1100 2.21E+00 Above-AverageVOCs as Benzene 71-43-2 150 3.01E-01 Above-AverageFormaldehyde 50-00-0 150 3.01E-01 Above-AverageParticulate matter N/A 20 4.01E-02 Above-Average
Sulphur dioxide 7446-09-5 74 1.48E-01 Above-Average
Hydrogen sulphide 7783-06-4 N/A 6.12E-04 Above-Average
Nitrogen oxides 10102-44-0 500 1.00E+00 Above-AverageCarbon monoxide 630-08-0 1100 2.21E+00 Above-AverageVOCs as Benzene 71-43-2 150 3.01E-01 Above-AverageFormaldehyde 50-00-0 150 3.01E-01 Above-AverageParticulate matter N/A 20 4.01E-02 Above-Average
Sulphur dioxide 7446-09-5 74 1.48E-01 Above-Average
Hydrogen sulphide 7783-06-4 N/A 6.12E-04 Above-Average
Note: VOCs are NMHC (non-methane hydrocarbons)
8
13
18
23
28 7,222
7,222
7,222
7,222
7,222
Made by: JLK
Checked by: EKLN:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 5 of 8 Golder Associates
March 2012 11-1151-0292
Source Number Source 29 and 30
Source Name Ammonia Scrubbers
Source Description
Operating Rate
Maximum ammonia concentration in filtrate = 3,328 kg/dayScrubber removal efficiency = 98%Scrubber exhaust flow rate = 40,000 CFM
18.88 m³/sExhaust temperature = 20 °C
293.15 KMolecular weight = 17.03 g/mol
Sample Calculation Ammonia Scrubbing
Ammonia = 3,328 kg 1 day 1 h 1000 g 100% - 98%
day 24 h 3600 s 1 kg
Ammonia = 0.77 gs
Source ID Contaminant CAS numberAmmonia
in Filtrate
[kg/day]
Exhaust
Flow Rate
[m³/s]
Removal
Efficiency
Emission
Rate [g/s]
MOE Data
Quality
S29 Ammonia 7664-41-7 3,328 18.88 98% 7.70E-01 Above-Average
S30 Ammonia 7664-41-7 0 18.88 98% 0.00E+00 Above-Average
The biogas plant contains two counter flow ammonia scrubbers containing sulfuric acid. It has a maximum ammonia concentration of 3328 Kg/day in the filtrate
per unit. Only one unit will operate at any time with the second unit acting as a back-up system.
The emission rates for the ammonia scrubber were calculated using the maximum ammonia amount in the filtrate, scrubber removal efficiency and
the scrubber exhaust parameters (provided by PurEnergy). Where a range was given, the value leading to the highest emission rate was chosen.
Made by: JLK
Checked by: EKLN:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 6 of 8 Golder Associates
March 2012 11-1151-0292
Source Number Source 35
Source Name Common Plant Exhaust
Source Description
Operating Rate
Exhaust flow rate = 8288 m³/h2.302 m³/s
Exhaust Temperature = 293.15 K
Sample Calculation Common Plant Exhaust
Ammonia = 0.002 ppm 1 mol K 101325 N 1 17.03 g1.00E+06 8.314 N m m² 293.15 K mol
Ammonia = 1.42E-06 gm³
Ammonia = 1.42E-06 g 2.30 m³m³ s
Ammonia = 3.26E-06 g
s
Source ID Contaminant CAS numberConcentration
[ppmv]
Molecular
Weight
[g/mol]
Exhaust
Flow Rate
[m³/s]
Emission Rate
[g/s]
MOE Data
Quality
Ammonia 7664-41-7 0.002 17.03 2.30 3.26E-06 Average
Hydrogen Sulphide 7783-06-4 0.186 34.08 2.30 6.07E-04 Average
Carbonyl Sulphide 463-58-1 0.015 60.00 2.30 8.61E-05 Average
Methyl Mercaptan 74-93-1 0.157 48.11 2.30 7.23E-04 Average
Ethyl Mercaptan 75-08-1 0.001 62.13 2.30 5.95E-06 Average
Dimethyl Disulphide 642-92-0 0.003 94.20 2.30 2.70E-05 Average
Dimethyl Sulphide 75-18-3 0.002 62.13 2.30 1.19E-05 Average
Carbon disulphide 75-15-0 0.02 76.10 2.30 1.46E-04 Average
Methane 74-82-8 0.057 15.03 2.30 8.20E-05 Average
Acetaldehyde 75-07-0 0.135 44.05 2.30 5.69E-04 Average
Isobutyraldehyde 78-84-2 0.01 72.11 2.30 6.90E-05 Average
Isovaleraldehyde 590-86-3 0.186 76.13 2.30 1.36E-03 Average
Methyl Alcohol 67-56-1 0.015 32.04 2.30 4.60E-05 Average
Ethyl Alcohol 64-17-5 0.157 46.04 2.30 6.92E-04 Average
Isopropyl Alcohol 67-63-0 0.001 60.10 2.30 5.75E-06 Average
Toluene 108-88-3 0.003 92.14 2.30 2.65E-05 Average
TOTAL Hydrogen sulphide 7783-06-4 - - - 4.46E-03 Average
The common plant exhaust was designed for the exhaust air coming from the Digestate Management Building and from its load-out area.
S35
Emissions from the exhaust are based on source testing from a similar facility provided in Appendix B. As there is the potential for odour emissions from this source, all
emissions are conservatively assumed to be hydrogen sulphide.
Made by: JLK
Checked by: EKLN:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 7 of 8 Golder Associates
March 2012 11-1151-0292
Source Number Source 8, 13, 18, 23, and 28
Source Name Combined Heat and Power Engines
Source Description
Operating Rate
Number of Engines in Operation = 2Maximum Fuel Consumption Per Engine = 4711 kWHalf Load Fuel Consumption = 2355.5 kW
8.04E+00 MMBtu/hr
Sample Calculation Natural Gas CombustionNitrogen oxides = 8.04E+00 MMBtu 8.47E-01 lb 1 hr 453.5924 g
hr MMBtu 3600 s 1 lbNitrogen oxides = 8.59E-01 g
s
Source ID Contaminant CAS Number
Emission
Factor
[lb/MMBtu]
Emission
Rate [g/s]
US EPA
Emission
Factor
Rating
MOE Data
Quality
23 Nitrogen oxides 10102-44-0 8.47E-01 8.59E-01 A Above-Average
28 Nitrogen oxides 10102-44-0 8.47E-01 8.59E-01 A Above-Average
The biogas plant contains five combined heat and power engines which may be fired with either natural gas or biogas. The facility will have a nameplate capacity of 9.8 MW of power and a fuel
consumption of 4711 kW.
During plant startup (approximately 2 months), two of the CHP engines will be in operation at half load (1 MWe each) using natural gas as fuel.
The nitrogen oxides emission rates for the natural gas fired engines were calculated using an emission factor from Tables 3.2-2, in US EPA AP-42 Section 3.2 Natural Gas Fired Reciprocating
Engines (7/00) and are based on the half load fuel consumption of 2355.5 kW per engine.
As per the ESDM Guidance Document, nitrogen oxides is the only significant contaminant resulting from natural gas combustion.
Made by: JLK
Checked by: EKLN:\Active\2011\1151\11-1151-0292 bioEnv-Biogas REA-Kawartha\Air-Noise\Air\Calculations\11-1151-0292 Calculations and Tables 16Mar12.xlsm
Page 8 of 8 Golder Associates
EMISSION SUMMARY AND DISPERSION MODELLING REPORT
March 2012 Report No. 11-1151-0292
APPENDIX B Supporting Information for Emission Rate Calculations
Engine: TCG 2020 V20
515
7,222202319608.38
EU:Emission [mg/mn3] NOx 500Emission [mg/mn3] CO 1100Emission [mg/mn3] VOC (NMHC) 150Emission [mg/mn3] HCHO 150Emission [mg/mn3] PM 2.5 15Emission [mg/mn3] PM 10 20
CAN - RAW Emissions:Emission [g/bhp hr] NOx 1.05Emission [g/bhp hr] CO 2.35Emission [g/bhp hr] VOC (NMHC) 0.32Emission [g/bhp hr] HCHO 0.32Emission [g/bhp hr] PM 2.5 0.03Emission [g/bhp hr] PM 10 0.04
Biogas 60%CH4, 40%CO2
Kawartha Biogas
real O2-content in dry Exhaust [%]
Shaft rated power [kW]Exhaust gas volume dry [mn3/h]
Raw Emission in CAN-Values
Basis EU: O2 in mg/m3 (%)Basis CAN: O2 in ppm (%)
Electrical output [kWe]
MWM 30/09/2011
EMISSION SUMMARY AND DISPERSION MODELLING REPORT
March 2012 Report No. 11-1151-0292
APPENDIX C Dispersion Modelling Files (on CD)