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TRCA Pearson Eco-Business Zone District Energy Feasibility Study 10 April 2012 Appendices 13.8 Solar Thermal FVB has investigated solar thermal possibilities for more than one local client recently and was involved some years ago as a peer reviewer of the Drakes Landing Solar Community project in Okotoks, Alberta. All of these projects have been very small scale, i.e. less than 1 MWt. From these experiences FVB has concluded that solar thermal cannot be viewed as a large scale economic thermal energy source in Ontario. Although it may seem there is a greenhouse gas reduction justification this becomes weaker when CHP is incorporated. CHP typically results in excess useful heat being available in the summer. It is better to maximize CHP run– hours, thereby not only producing heat for zero on-site incremental greenhouse gas emission impact but also simultaneously displacing grid electricity coming from central coal-fired generation. 121
TRCA Pearson Eco-Business Zone District Energy Feasibility Study 10 April 2012 Appendices 14 Appendix D: GTAA Cogeneration Plant Operations The CUP has an associated Cogeneration Plant with the capability to extract steam for heating purposes. A published case study 20 identifies a high pressure (HP) steam (760 psia) flow of 175,000 lbs/hr, plus a low pressure (LP) steam (179 psia) flow of 11,000 lbs /hr from each of two Once through Steam Generators. The HP steam is used to drive a steam turbine, from which steam can be extracted for heating purposes, whereas the LP steam is used directly for heating or to drive steam turbine driven chillers. The potential steam production from the Cogeneration Plant varies according to: (a) whether the Cogeneration Plant is running or not, (b) the point in its startup cycle, (c) outside ambient air temperature, with greater steam potential in winter when air is denser, (d) the extent to which duct firing is being used, and (e) the particulars of design of the steam turbine, e.g. minimum flow requirements to cool the downstream blades. A conservative assumption was made of 40 MWt applied constantly throughout the year for simplicity. Using this steam quantity, with a reasonable running time assumption (2,586 hours per year) and a typical annual hourly demand profile applied to the both the airport and the DES heat loads, and Thermal Energy Storage with a design and size similar to that installed in 2009 by Markham District Energy, it was estimated that 48% of the thermal energy for the DES could be recovered from CHP. It must be emphasized that there is considerable uncertainty in this estimate due to the large number of assumptions. It was further assumed, based on general experience for this type of plant, that extraction of each MWt would result in de-rating of power generation by 0.25 MWe, from which a variable cost estimate for steam from the Cogeneration Plant could be derived from the variable price forecast to be received for electricity. Hence the total average variable cost of production of steam could be estimated as a weighted average based on the percentage of steam from CHP and its cost and the balance of steam from boilers and its cost, which would be tied to gas prices and boiler efficiency. The GTAA cautioned that the price expected to be received by the Cogeneration Plant for electricity is very uncertain and might increase considerably in future when Locational Marginal Pricing comes into effect. Moreover, the GTAA advised it would not be prudent to base the business plan on an assumed supply from the Cogeneration Plant because of both the uncertain value of electricity in future and other uncertainties impacting the availability of steam. 20 IST – SNC Lavalin Constructors Inc, Greater Toronto Airports Authority, GTAA Cogeneration Plant 122
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