1. Data Tables for the OPO Technical Report August 2016

2. Figure 1: Ontario Installed Supply Mix in 2005 and 2015 2

3. Data for Figure 1: Ontario Installed Supply Mix in 2005 and 2015 3 MW20052015 Nuclear11,39713,014 Natural Gas & Oil4,9769,852 Water7,9108,768 Solar/Wind/Bioenergy1347,068 Coal6,4340 Demand Response0690

4. Figure 2: Ontario Electricity Production in 2005 and 2015 4

5. Data for Figure 2: Ontario Electricity Production in 2005 and 2015 5 TWh20052015 Nuclear79.092.3 Natural Gas & Oil12.915.9 Water34.037.3 Solar/Wind/Bioenergy0.314.2 Coal30.00.0

6. Figure 3: Historical Ontario Energy Demand 6 Gross Demand is the total demand for electricity services in Ontario prior to the impact of conservation programs Net Demand is Ontario Gross Demand minus the impact of conservation programs Grid Demand is Ontario Net Demand minus the demand met by embedded generation. It is equal to the energy supplied by the bulk system to wholesale customers and local distribution companies

7. Data for Figure 3: Historical Ontario Energy Demand 7 TWh20052006200720082009201020112012201320142015 Gross Demand158.8154.4157.3154.7146.0149.9151.0152.3153.8156.2155.8 Conservation0.01.63.54.04.95.46.77.98.911.312.8 Net Demand158.8152.8153.8150.6141.1144.5144.3144.5144.8144.9143.0 Embedded Generation1.81.71.62.0 2.32.83.24.15.16.0 Grid Demand157.0151.1152.2148.7139.2142.2141.5141.3140.7139.8137.0

8. Figure 4: Conservation Savings in 2015 8

9. Figure 5: Demand Response Capacity in 2015 9 Peaksaver PLUS and CBDR can controlled by system operators. These programs are treated elsewhere as supply resources totalling 690 MW TOU pricing and ICI reflect customer response to prices. These programs are considered as part of the net demand forecast

10. Data for Figure 5: Demand Response Capacity in 2015 10 CategoryMW TOU59 ICI1,000 Peaksaver PLUS164 CBDR526

11. Figure 6: Electricity Sector GHG Emissions 11 Note: GHG emissions for 2015 is an estimate

12. Data for Figure 6: Electricity Sector GHG Emissions 12 MT CO 2 e20052006200720082009201020112012201320142015 Electricity Sector GHG Emissions 34.529.932.927.414.919.814.2 10.97.1

13. Figure 8: Ontario Net Energy Demand across Demand Outlooks 13

14. Data for Figure 8: Ontario Net Energy Demand across Demand Outlooks 14 Energy (TWh)20152016201720182019202020212022202320242025 Outlook A142.5143.0141.9140.6138.9137.7136.1135.0134.1133.5132.5 Outlook B142.5143.4142.9142.7142.2 141.7141.6141.5141.7141.5 Outlook C142.5143.5143.2143.7144.2145.1145.6146.6147.7149.3150.4 Outlook D142.5143.5143.2144.3145.3146.9148.1149.9151.9154.4156.5 Energy (TWh)2026202720282029203020312032203320342035 Outlook A131.7131.2131.0130.8130.7 131.0131.5132.3133.4 Outlook B141.2141.5142.1142.4142.8143.3144.0145.0146.3147.8 Outlook C151.7153.5155.9158.0160.5163.1166.2169.4173.1177.1 Outlook D158.8161.7165.3168.6172.4176.3181.0185.6191.0196.7

15. Figure 9: Ontario Net Summer Peak Demand across Demand Outlooks 15

16. Data for Figure 9: Ontario Net Summer Peak Demand across Demand Outlooks 16 Summer Peak Demand (MW) 20152016201720182019202020212022202320242025 Outlook A23,96523,97123,90023,70523,46523,21623,02922,87922,77722,62822,568 Outlook B23,96524,04624,08324,04123,99323,91623,88923,88123,89023,86823,918 Outlook C23,96524,04824,08824,10824,12424,11224,15224,21624,29824,35324,486 Outlook D23,96524,04824,08824,16624,24224,29124,39324,52024,66724,78824,987 Summer Peak Demand (MW) 2026202720282029203020312032203320342035 Outlook A22,45322,37222,29522,29222,25822,23122,19822,31722,43622,586 Outlook B23,88223,91823,94024,03024,08224,13324,17124,36924,56824,792 Outlook C24,54924,68024,80425,04925,55026,02226,19926,55126,90227,276 Outlook D25,44625,92126,12426,41026,66726,93727,19727,63328,07128,532

17. Figure 10: Ontario Net Winter Peak Demand across Demand Outlooks 17

18. Data for Figure 10: Ontario Net Winter Peak Demand across Demand Outlooks 18 Winter Peak Demand (MW) 20152016201720182019202020212022202320242025 Outlook A22,15922,09322,02021,82521,57421,33821,14320,97620,86420,69420,602 Outlook B22,15922,14022,14322,07221,98521,89821,84121,79921,77821,718 Outlook C22,15922,19022,25122,31522,39522,50122,66122,86323,10523,32623,626 Outlook D22,15922,19022,25122,38522,56022,78323,08323,44223,86224,27324,779 Winter Peak Demand (MW) 2026202720282029203020312032203320342035 Outlook A20,48320,39420,31520,31620,29520,28220,26020,37520,48820,622 Outlook B21,65921,66821,67221,74621,79421,84421,87522,05222,22922,422 Outlook C23,91124,26524,63324,51325,08525,69526,33027,18528,14429,167 Outlook D24,74225,49226,27727,22628,29629,45130,68332,15833,71635,379

19. Table 1: Assumptions across Demand Outlooks 19 SectorOutlook AOutlook BOutlook COutlook D Residential (52 TWh in 2015) 48 TWh in 203551 TWh in 2035 Oil heating switches to heat pumps, electric space and water heating gain 25% of gas market share (58 TWh in 2035)* Oil heating switches to heat pumps, electric space and water heating gain 50% of gas market share (64TWh in 2035) Commercial (51 TWh in 2015) 49 TWh in 203554 TWh in 2035 Oil heating switches to heat pumps, electric space and water heating gain 25% of gas market share (63 TWh in 2035) Oil heating switches to heat pumps, electric space and water heating gain 50% of gas market share (69 TWh in 2035) Industrial (35 TWh in 2015) 29 TWh in 203535 TWh in 2035 5% of 2012 fossil energy switches to electric equivalent (43 TWh in 2035) 10% of 2012 fossil energy switches to electric equivalent (51 TWh in 2035) Electric Vehicles (<1 TWh in 2015) 2 TWh in 20353 TWh in 2035 2.4 million electric vehicles (EVs) by 2035 (8 TWh in 2035) 2.4 million EVs by 2035 (8 TWh in 2035) Transit (<1 TWh in 2015) 1 TWh in 2035 Planned projects, 2017-2035 (1 TWh in 2035) Other**5 TWh Total*** (143 TWh in 2015) 133 TWh in 2035148 TWh in 2035177 TWh in 2035197 TWh in 2035 Note: Outlooks C and D assume the same economic drivers as Outlook B. * By 2035, of the number of natural gas fuelled space and water heating equipment being sold in Outlook B (due to existing equipment reaching end of life and new additions driven by growth in the residential and commercial sectors), 25 percent of this stock in Outlook C and 50 percent in Outlook D is replaced with air-source heat pumps. ** Others = Agriculture, Remote Communities, Generator Demand, IEI and Street Lighting *** Total may not add up due to rounding

20. Figure 11: Conservation Achievement and Outlook to Meet the 2013 LTEP Target 20

21. Data for Figure 11: Conservation Achievement and Outlook to Meet the 2013 LTEP Target 21 Savings (TWh)2006200720082009201020112012201320142015 Codes and Standards (Implemented by 2015) -0.10.20.30.51.01.61.83.14.2 Codes and Standards (Implemented 2016 and beyond) - - - - - - - - - - Historical program persistence (2006-2015)1.63.43.94.65.05.76.37.18.18.6 Forecast savings from planned programs (2016-2020) - - - - - - - - - - Planned savings from future programs & Codes and Standards - - - - - - - - - - Savings (TWh)2016201720182019202020212022202320242025 Codes and Standards (Implemented by 2015)5.26.36.97.37.4 7.5 Codes and Standards (Implemented 2016 and beyond)0.0 0.20.30.40.60.91.41.82.2 Historical program persistence (2006-2015)7.56.45.75.54.94.43.63.12.11.9 Forecast savings from planned programs (2016-2020)1.63.35.06.47.98.07.87.77.36.8 Planned savings from future programs & Codes and Standards - - - - -0.61.31.83.03.9 Savings (TWh)2026202720282029203020312032203320342035 Codes and Standards (Implemented by 2015)7.57.6 7.77.8 7.9 Codes and Standards (Implemented 2016 and beyond)2.63.03.44.14.85.46.06.46.77.0 Historical program persistence (2006-2015)1.40.90.40.30.1 0.0 Forecast savings from planned programs (2016-2020)6.66.46.25.74.84.34.03.73.43.0 Planned savings from future programs & Codes and Standards 5.56.78.19.110.511.512.4 12.612.8

22. Figure 12: Outlook for Installed Capacity to 2035 22

23. Data for Figure 12: Outlook for Installed Capacity to 2035 23 Installed Capacity (MW)2016201720182019202020212022202320242025 Existing Supply38,41737,86837,51037,05635,30734,42534,28829,40528,62025,756 Committed, Not Yet Online 1,0781,6782,6552,8113,194 3,2303,2293,244 Directed Procurements0125433683 9631,5632,0472,2872,767 Expired Contracts325819391,4921,548 1,6843,8754,6614,689 Refurbished Nuclear0000881 1,7623,4654,346 Installed Capacity (MW)2026202720282029203020312032203320342035 Existing Supply23,90323,78921,44017,59915,15514,25413,47112,44310,4019,345 Committed, Not Yet Online 3,244 3,2393,2383,021 2,9912,6962,517 Directed Procurements2,855 3,033 Expired Contracts5,7195,8327,37611,22112,84313,96114,74415,80318,14019,375 Refurbished Nuclear5,127 5,9006,722 7,544 8,366

24. Figure 13a: Available Supply at the Time of Peak Demand Relative to Total Resource Requirements (Summer) 24

25. Data for Figure 13a: Available Supply at the Time of Peak Demand Relative to Total Resource Requirements (Summer) 25 Capacity Contribution at Summer Peak (MW)2016201720182019202020212022202320242025 Existing Supply30,12228,72428,47728,19826,33625,45625,33720,49719,79316,951 Refurbished Nuclear0000878 1,7563,453 Committed, Not Yet Online1838991,3052,1472,3602,4272,451 2,452 Directed Procurements017199318136255315559752993 Expired Contracts314777251,0871,2521,2631,3813,5604,2654,276 Capacity Contribution at Summer Peak (MW)2026202720282029203020312032203320342035 Existing Supply15,55815,51014,66611,6019,5968,6828,1287,9047,5037,145 Refurbished Nuclear5,084 5,851 6,670 7,488 8,307 Committed, Not Yet Online1,952 1,9501,9491,8231,7521,7461,7261,701 Directed Procurements1,056 1,176 Expired Contracts4,8504,8984,9408,0099,19510,23510,86111,09111,51111,894 Resource Requirement at Summer Peak (MW) 2016201720182019202020212022202320242025 Outlook A28,07028,13027,71127,38328,18627,94427,76927,64927,47526,953 Outlook B28,15728,34528,10428,00029,00628,95028,94128,95128,92528,505 Outlook C28,13728,18328,20728,22529,21229,25829,33229,42929,49329,648 Outlook D28,13728,18328,27528,36329,42129,54029,68929,86130,00230,235 Resource Requirement at Summer Peak (MW) 2026202720282029203020312032203320342035 Outlook A26,82126,72826,63926,63626,59726,56526,52726,66425,80225,973 Outlook B28,46528,50528,53128,63528,69428,75328,79629,02428,25328,510 Outlook C29,72329,87630,02130,30730,89431,44531,65332,06531,47631,912 Outlook D30,77231,32731,56631,90032,20032,51732,82133,33132,84333,383

26. Figure 13b: Available Supply at the Time of Peak Demand Relative to Total Resource Requirements (Winter) 26

27. Data for Figure 13b: Available Supply at the Time of Peak Demand Relative to Total Resource Requirements (Winter) 27 Capacity Contribution at Winter Peak (MW)2016201720182019202020212022202320242025 Existing Supply29,26828,44828,23927,98126,02025,98024,98320,69620,64917,057 Refurbished Nuclear00000878 1,7563,453 Committed, Not Yet Online003143491,2791,587 1,6141,6131,617 Directed Procurements00299157849200367573 Expired Contracts311515127691,1001,1491,2673,4083,4564,216 Capacity Contribution at Winter Peak (MW)2,0262,0272,0282,0292,0302,0312,0322,0332,0342,035 Existing Supply16,45915,52515,47113,38510,3378,3668,1287,6337,3846,814 Refurbished Nuclear3,4535,084 5,8516,670 7,488 8,307 Committed, Not Yet Online2,117 2,1142,113 1,9061,9021,8951,790 Directed Procurements741807791936 Expired Contracts4,8154,9295,0006,2719,32010,47210,91711,41611,67212,347 Resource Requirement at Winter Peak (MW)2016201720182019202020212022202320242025 Outlook A25,87025,91725,51425,17625,98725,73725,54225,41125,21224,693 Outlook B25,92626,06325,80225,65726,64326,55426,50526,48026,41125,975 Outlook C25,96226,03326,10826,20227,32627,51427,74928,03328,29228,643 Outlook D25,96226,03326,19126,39527,65628,00728,42828,91829,39929,992 Resource Requirement at Winter Peak (MW)2026202720282029203020312032203320342035 Outlook A24,55524,45324,36324,36424,33924,32524,29924,43123,56123,715 Outlook B25,90825,91925,92226,00826,06326,12026,15626,35925,56325,785 Outlook C28,97629,39029,82029,68030,34931,06331,80632,80632,92834,125 Outlook D29,94830,82631,74532,85434,10635,45736,89938,62539,44841,393

28. Figure 14: Installed Capacity of Future Contract Expirations 28

29. Data for Figure 14: Installed Capacity of Future Contract Expirations 29 (MW)2016 - 20202021 - 20292030 - 2035 Expiring Contracts - Natural Gas4497,1062,161 Expiring Contracts - Renewables2382,5505,993 TOTAL6879,6568,154

30. Figure 15: Electricity Supply Requirements in Outlooks C and D 30

31. Data for Figure 15: Electricity Supply Requirements in Outlooks C and D 31 20152035, Outlook C2035, Outlook D Annual Energy (TWh)142.5177.1196.7 Total Resource Requirement (MW)28,15734,12541,393

32. Table 2: Current Technology Characteristics 32 CapacityEnergy Operating Reserve Load Following Frequency Regulation Capacity Factor Contribution to Winter Peak Contribution to Summer Peak LUEC ($/MWh) ConservationYes No Depends on Measure $30-50 Demand ResponseYesNoYes LimitedN/A60-70%80-85%N/A Solar PVLimitedYesNoLimitedNo15%3-5%20-35%$140-290 WindLimitedYesNoLimitedNo30-40%20-30%11%$65-210 BioenergyYes LimitedNo40-80%85-90% $160-260 StorageYesNoYes Depends on technology/ application Depends on technology/ application WaterpowerYes 30-70%67-75%63-71%$120-240 NuclearYes NoLimitedNo70-95%90-95%95-99%$120-290 Natural GasYes up to 65%95%89%$80-310

33. Figure 16: Installed Solar PV Cost Projections in Ontario 33

34. Installed Cost ($/kW)2016201720182019202020212022202320242025 Residential Rooftop Solar PV (3-10 kW) 2,8282,6702,5212,3802,2462,2112,1762,1422,1092,075 Commercial Rooftop Solar PV (100 kW) 2,5922,4472,3102,1812,0592,0261,9951,9631,9321,902 Commercial Rooftop Solar PV (500 kW) 2,5022,3622,2302,1051,9871,9561,9261,8951,8661,836 Small-Scale Ground-Mounted Solar PV (500 kW) 2,6892,5602,4372,3202,2092,1402,0922,0462,0001,956 Utility-Scale Ground- Mounted Solar PV (> 5 MW) 1,8001,7141,6311,5531,4781,4321,4001,3691,3391,309 Installed Cost ($/kW)2026202720282029203020312032203320342035 Residential Rooftop Solar PV (3-10 kW) 2,0562,0372,0181,9991,981 Commercial Rooftop Solar PV (100 kW) 1,8841,8671,8501,8321,815 Commercial Rooftop Solar PV (500 kW) 1,8191,8021,7851,7691,752 Small-Scale Ground-Mounted Solar PV (500 kW) 1,9141,8721,8321,7921,753 Utility-Scale Ground- Mounted Solar PV (> 5 MW) 1,2811,2531,2261,1991,173 Data for Figure 16: Installed Solar PV Cost Projections in Ontario 34

35. Figure 17: Existing Interconnections 35

36. Table 3: Status and Drivers of Transmission Projects in Outlook B 36 ProjectsStatus Drivers Maintaining Bulk System Reliability Addressing Regional Reliability and Adequacy Needs Achieving 2013 Long- Term Energy Plan (LTEP) Policy Objectives Facilitating Interconnections with Neighbouring Jurisdictions East-West Tie ExpansionExpected to be in service in 2020 XX Line to Pickle Lake Plan is complete; Expected to be in service in early 2020. XX Remote Community Connection Plan Draft technical report released; development work underway for connection of 16 communities; engagement with communities is ongoing. XX Northwest Bulk Transmission Line Hydro One is carrying out early development work to maintain the viability of the option. XX Supply to Essex County Transmission Reinforcement Expected In-service date of 2018 X West GTA Bulk reinforcement Plan is being finalized. X Guelph Area Transmission Refurbishment Expected to be in service in 2016 X Remedial Action Scheme (RAS) in Bruce and Northwest Under development. Northwest RAS targeted for late 2016 in-service; Bruce RAS early 2017 X Clarington 500/230kV transformers Expected to be in service in 2018 X Ottawa Area Transmission Reinforcement Project has been initiated; expected to be in service 2020. XX Richview to Manby Transmission Reinforcement Expected to be in service in 2020 X

37. Figure 18: Electricity Sector GHG Emissions in Outlook B 37

38. Data for Figure 18: Electricity Sector GHG Emissions in Outlook B 38 MT CO2e20052006200720082009201020112012201320142015 Electricity Sector GHG Emissions 34.529.932.927.414.919.814.2 10.97.1 MT CO2e2016201720182019202020212022202320242025 Forecast GHG Emissions (Outlook B)4.63.83.53.13.43.63.74.23.44.7 MT CO2e2026202720282029203020312032203320342035 Forecast GHG Emissions (Outlook B)3.83.93.73.93.84.54.04.24.65.3

39. Figure 19: Total Cost of Electricity Service in Outlook B 39

40. Data for Figure 19: Total Cost of Electricity Service in Outlook B 40 Total Cost of Electricity Service (2016$ Billions) 2016201720182019202020212022202320242025 Outlook B20.721.321.220.521.520.820.921.020.921.5 Total Cost of Electricity Service (2016$ Billions) 2026202720282029203020312032203320342035 Outlook B20.421.220.920.420.2 20.119.9 19.4

41. Figure 20: Average Unit Cost of Electricity Service in Outlook B 41

42. Data for Figure 20: Average Unit Cost of Electricity Service in Outlook B 42 2016201720182019202020212022202320242025 Demand Outlook - B (TWh)143.5143.0142.8142.4 141.9141.7141.6141.9141.7 Average Unit Cost - B (2016$/MWh)144.3149.2148.6144.1150.9146.4147.2148.0147.0151.7 2026202720282029203020312032203320342035 Demand Outlook - B (TWh)141.4141.6142.2142.5143.0143.4144.2145.1146.5148.0 Average Unit Cost - B (2016$/MWh)144.6149.5146.8143.3141.4140.8139.5137.4135.9131.0

43. Figure 21: Cost of Electricity Service across Demand Outlooks 43

44. Data for Figure 21: Cost of Electricity Service across Demand Outlooks 44 Outlook AOutlook BOutlook COutlook D Minimum System Cost (2016$ Billions) 17.819.423.127.1 Maximum System Cost (2016$ Billions) 18.219.423.327.9 Minimum Unit Cost (2016$/MWh) 134131130137 Maximum Unit Cost (2016$/MWh) 136131132142 Energy Demand in 2035 (TWh)133148177197