City of Toronto Solid Waste Management Services

Transcription

1 City of Toronto Solid Waste Management Services 8 th Canadian Waste Resource Symposium BIOGAS UTILIZATION: Disco Road Organics Processing Facility Carlyle Khan, Director Infrastructure Development & Asset Management December 1, 2015

2 Agenda City of Toronto Solid Waste Management Services Climate Change Goals Biogas and Landfill Gas Assets Disco Road Organics Processing Facility The Anaerobic Digestion Process Biogas Overview Biogas Utilization Options Preferred Biogas Utilization Option Electricity & Thermal Energy Overview The Renewable Energy Approval Process and Reports Financials and Payback Biogas Consumption Amounts

3 Solid Waste Management Mission Statement: To be a leader in providing innovative management services to residents, businesses and visitors within the City of Toronto in a safe, efficient, effective and courteous manner, creating environmental sustainability, promoting diversion and maintaining a clean city.

4 Climate Change & Solid Waste The City of Toronto has committed to: Reducing GHGs by 30% from 1990 levels by Reducing GHGs by 80% from 1990 levels by Renewable Natural Gas (Fuel) Renewable Electricity Renewable Natural Gas (Heat)

5 Biogas & Landfill Gas Assets The Greenlane Landfill The Disco Road Organics Processing Facility The Dufferin Organics Processing Facility The Keele Valley Landfill (closed)

6 Disco Road Organics Processing Facility

7 The Anaerobic Digestion Process Residual Waste, such as plastic bags, sent to Green Lane Landfill Green Bin materials collected and sent to transfer stations. Tipping Floor Clean Organic Pulp Water added to material Suspension Buffer Tank Water Removed Digester Solids Effluent AD Facility Electricity generation for facility (reduce reliance on power grid) Heat for buildings and the anaerobic digestion process (reduce reliance on NG) Biogas Utilization Facility Biogas Flare Renewable Natural Gas production to use in NG vehicles (reduce reliance on diesel)

8 Biogas Overview Component Amount Unit Temperature 33 C Water (H 2 O) 100 %RH Pressure In. Hg Methane (CH 4 ) 68.7 Vol.% Carbon Dioxide (CO 2 ) 30.6 Vol.% Nitrogen (N 2 ) ND Vol.% Oxygen (O 2 ) 0.68 Vol.% Hydrogen Sulphide (H 2 S) 821 Vol.% Total Non Methane Hydrocarbons 2247 mg/m 3 Total Silicon 187 µ/m 3 * ~ 97 m 3 /tonne SSO

9 Biogas Utilization Options Power Purchase Agreement Electricity Generation with Limited Heat Capture Power Purchase Agreement Combined Heat and Power Load Displacement Electricity Generation with Limited Heat Capture Load Displacement Combined Heat and Power Renewable Natural Gas Renewable Compressed Natural Gas as Vehicle Fuel Renewable Liquefied Natural Gas as Vehicle Fuel Biogas to Methanol

10 Electricity and Heat Generation Electricity A 2.0 MW Plant with two internal combustion engines. Both generators to operate during on-peak hours One generator (0.850 MW) to operate during off-peak hours Thermal Energy Limited heat capture with design flexibility to convert to full scale CHP. Heat to be conveyed by 90 C hot water Supply of full thermal demands at 120 Disco (DROPF and Transfer Station) Supply of majority of thermal demands at 150 Disco (Partner Division)

11 Behind the Meter Conceptual Design D B Electrical and Hot Water Connections Hot Water Connection A 150 Disco Road (Disco Yard) C Biogas, Electrical, Hot Water Connections Biogas Utilization Facility DROPF Transfer Station 120 Disco Road (DRWMF)

12 Financial Estimates Estimated Capital Cost Approximately $5.0 million Estimated Annual Operating Cost $260,000 plus major overhaul every 10 years of $790,000 Estimated Annual Energy Savings $1.4 million in Electricity $77,000 in Natural Gas Simple Payback of approximately 4.8 years

13 But Wait.

14 Triple-bottom Line Framework Environmental Recommendations Social Economic

15 RNG Estimated that we can produce 4.5M diesel litre equivalents each year (1.2M diesel gallon equivalents)

16 RNG Option

17 Behind the Meter Theoretical Design Biogas Upgrading Facility Compressor Biogas Stream DISCO Transfer Station Natural Gas Pipeline

18 Financial Estimates Estimated Capital Cost Approximately $ million (technology dependent) Estimated Annual Operating Cost $ M (technology dependent) Estimated Annual Diesel Cost Avoidance $4.0M (entirely dependent on price of diesel) Simple Payback of approximately 2.5 years

19 Environmental Estimates

20 Social Estimates Social Benefits NG vehicles are far less noisy Local health outcomes Job creation potential through new technology adoption

21 Thank You