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Study on Renewable Energy Resources, Oman - authority for ...

Study on Renewable Energy Resources, Oman - authority for ...

Renewable Energy Resources in Oman Table 6.1 Assumptions and calculation of short- and long-term marginal costs, USD /MWh -low gas price (595 US c/Gcal) Gas turbine, 140 MW Combined Cycle, 400 MW HFO Steam, 300 MW Coal Steam, 1000 MW Power capacity, MW 140 400 300 1000 Economic Lifetime, years 25 25 30 30 Investment costs, million USD 45 184 289 1640 Specific investment costs, million USD/MW 0.32 0.46 0.96 1.64 Fuel efficiency, % 33.9% 48.4% 38.2% 38.0% Fuel costs, US c/Gcal 595 595 2519 880 Variable O&M costs, USD/MWh 0.55 0.70 0.80 0.05 Short run marginal costs, USD/MWh 15.64 11.28 57.50 19.97 Fixed annual O&M costs, USD Mill 4.26 5.04 12.65 18.60 Annual capital/investment costs, USD Mill Long run marginal costs, USD/MWh (5.000 h) Long run marginal costs, USD/MWh (7.500 h) 4.09 16.58 24.59 139.54 27.57 22.09 82.33 51.59 23.59 18.49 74.05 41.05 It appears from the table that short-run marginal costs at the conventional gas plants differ from around 11 USD/MWh to 16 USD/MWh. The short-run marginal costs are lowest for the combined cycle plants because these plants have larger fuel efficiencies than the gas turbines. With the assumed oil and coal prices conventional gas plants have the lowest economic cost. The results with respect to long-run costs are shown in Fig. 6.1. Page 94 of 134 .

Renewable Energy Resources in Oman Fig. 6.1 Long-run marginal costs for conventional technologies (two annual full load hours scenarios) - Low Gas Price USD/MWh 90 80 70 60 50 40 30 20 10 0 GT 140MW CCGT 400MW HFO 300MW Coal 1000MW 5000 Hours 7500 Hours The assumed number of annual full load hours influences long-run marginal costs. Increasing the assumed number of full load hours per year from 5000 to 7500, acts to reduce the long-run marginal cost per unit. The long-run costs of the gas turbine are least sensitive towards number of full load hours because this technology has the lowest specific investment costs. If the annual number of full load hours was decreased to below approximately 2000 hours, the long-run costs for the gas turbines would be lower than for the combined cycle plants. This is one reason why gas turbines are suitable as peak load units with only few operational hours per year. The tables 6.2 and 6.3 below show the short- and long-run marginal costs, if fuel prices were 3 USD per MMBtu and 6 USD per MMBtu. The low gas price (1.5 USD per MMBtu) corresponds to the price currently charged the power plants, i.e. actual cost, not economic costs. Economic costs are assumed to be 3 USD/MMBtu with a depletion premium of 3% p.a. Table 6.2 shows the marginal cost with a natural gas price of 3 USD/MMBtu and Table 6.3 the cost with a natural gas price of 6 USD/MMBtu. Table 6.2 Assumptions and calculation of short- and long-term marginal costs, USD /MWh -( medium gas price 1190 US c/Gcal) Gas turbine, 140 MW Combined Cycle, 400 MW HFO Steam, 300 MW Coal Steam, 1000 MW Fuel costs, US c/Gcal 1190 1190 2519 880 Short run marginal costs, USD/MWh 30.73 21.86 57.50 19.97 Long run marginal costs, USD/MWh (5.000 h) Long run marginal costs, USD/MWh (7.500 h) 42.66 32.67 82.33 51.59 38.68 29.06 74.05 41.05 Page 95 of 134 .

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