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MPR Capacity Factor

MPR Capacity Factor. William B. Marcus JBS Energy, Inc. for The Utility Reform Network. Two alternatives. Actual Operating Capacity Factor (60-70%) Theoretical Availability (about 90%). Fixed and Variable Costs. Fixed Costs are Incurred regardless of capacity factor

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MPR Capacity Factor

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  1. MPR Capacity Factor William B. MarcusJBS Energy, Inc.for The Utility Reform Network

  2. Two alternatives • Actual Operating Capacity Factor (60-70%) • Theoretical Availability (about 90%)

  3. Fixed and Variable Costs • Fixed Costs are Incurred regardless of capacity factor • Variable costs increase as operations increase • Cost in cents per kWh declines as capacity factor increases because fixed costs are spread over more kWh of operations

  4. Combined Cycle Economics • Why does a plant only run at 60% of the time when it could theoretically run 90% of the time? • ECONOMICS • Either cheaper power is available the other 30% of the time, or demand isn’t available to keep it running at full capacity, or both.

  5. So what does a baseload renewable avoid (levelized market price in all hours)? • 100% of the fixed cost of a combined cycle • Operating costs of the combined cycle when it would run • Costs that are a maximum of the variable costs of the combined cycle during hours when the combined cycle would not run or would be turned down. • In other words, fixed and variable costs calculated at a 90% capacity factor

  6. Combined Cycle Cost ($/kW-year) at 60% and 90% capacity factor

  7. Spreading fixed costs over kWh: 9.3 cents/kWh at 60%, 8.5 cents/kWh at 90%

  8. How the Current Baseload MPR Overstates Cost

  9. Time Differentiation Doesn’t Help • Lower prices at 3 AM and higher prices at 3 PM are not enough. • The total number before time differentiation is too high, so that prices paid for baseload operation are still too high.

  10. Conclusion • Appropriate payout for baseload or intermittent plant that is not dispatched spreads fixed costs over the theoretical maximum capacity factor for a combined cycle. • Time-differentiated MPR for 30-40% of low load hours should be no more than combined cycle variable cost. All fixed costs should be in 60-70% of hours for time-differentiation purposes. • Only this method gives appropriate value to both baseload plant and plants that can be dispatched downward in off-peak hours.

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