Cost-Causation and Integration Cost Analysis for Variable Generation Michael Milligan, Ph.D. National Renewable Energy Laboratory NREL is a national laboratory of the U.S. Department of Energy, Office of Energy Efficiency and Renewable Energy, operated by the Alliance for Sustainable Energy, LLC. About this presentation • Information in this presentation is taken from “Cost-Causation and Integration Cost Analysis for Variable Generation,” Milligan, M.; Ela, E.; Hodge, B. M.; Kirby, B.; Lew, D.; Clark, C.; DeCesaro, J.; Lynn, K. • http://www.nrel.gov/ docs/fy11osti/ 51860.pdf National Renewable Energy Laboratory 2 Innovation for Our Energy Future Outline • Power system operation: variability and uncertainty • Cost-causation and integration tariffs • Thought experiments: testing tariffs • Conclusions National Renewable Energy Laboratory 3 Innovation for Our Energy Future Time scale for power system operation National Renewable Energy Laboratory 4 Innovation for Our Energy Future Additional ramping/rangemore flexibility 10000 8000 MW 6000 4000 2000 0 800 Net load (load-wind) Additional ramping needs with wind Maximum/Minimum Load Peak Load Ramp (MW/hour) 600 400 200 0 -200 -400 -600 -800 0 20 National Renewable Energy Laboratory 40 60 80 Hours (1 week) 5 100 120 140 160 Innovation for Our Energy Future Integration costs: wind and solar • • Wind and solar generation increase the variability and uncertainty in power systems operation Solar and wind integration issues are similar – Wind is becoming reasonably well understood – Solar • PV has high potential for short-term variability from cloud variations, but the impact of large PV plants is largely unknown because of limited experience with small plants • CSP without storage has some thermal inertia and is likely less variable than PV • CSP with storage is thought to be much less of an integration challenge but still unknown • • Cycling efficiency Are not unique to wind or solar National Renewable Energy Laboratory 6 Innovation for Our Energy Future Variability and Uncertainty Variability: Wind and solar generator outputs vary on different 3me scales as the intensity of their energy sources (wind and sun) Uncertainty: Wind and solar genera3on cannot be predicted with perfect accuracy Variability Uncertainty 2500 CSP Actual CSP Forecasted 20000 2000 15000 1500 MW MW 25000 10000 1000 Wind Actual 5000 500 Forecasted Wind 0 0 0 6 12 18 24 Hours 30 36 42 0 48 6 12 18 24 Hours 30 36 42 48 Variability: load varies throughout the day, conven3onal genera3on can o=en stray from schedules Uncertainty: Con3ngencies are unexpected, load forecast errors are unexpected National Renewable Energy Laboratory 7 Innovation for Our Energy Future Integration cost of wind and solar • • Delta Market Value ($) 5 0 0 -5 -50 Daily flat energy block ($52.33/MWh) Daily flat block difference $/MWh (right) 6-Hour flat energy block ($48.59/MWh) 6_Hour flat energy block difference $/MWh (right) (Wind: $48.98/MWh) 40 -10 10 5 20 0 0 -20 -40 -5 -60 -80x10 3 -10 0 20 40 60 80 100 120 140 160 Related reports: Milligan, M.; Kirby, B. (2009). Calcula3ng Wind Integra3on Costs: Separa3ng Wind Energy Value from Integra3on Cost Impacts. 28 pp.; NREL Report No. TP-­‐550-­‐46275. hXp://www.nrel.gov/docs/fy09os3/46275.pdf Milligan, M.; Ela, E.; Lew, D.; Corbus, D.; Wan, Y. H. (2010). Advancing Wind Integra3on Study Methodologies: Implica3ons of Higher Levels of Wind. 50 pp.; NREL Report No. CP-­‐550-­‐48944. hXp://www.nrel.gov/docs/fy10os3/48944.pdf – Do all AGC units follow the signal? – Are there efficiency costs of adding conventional generators? National Renewable Energy Laboratory (Flat block value) - (wind value) 50 Delta Market Value ($) • Can it be measured? If so, how is it defined? What is the proper benchmark unit? How are cost and value untangled? What about units in one region that economically respond to needs in another region? Are there integration costs for other units? 10 3 Over or Under-estimate of Wind Value ($/MWh) • • • 100x10 8 Innovation for Our Energy Future How are integration costs calculated? • Compare two (or more) alternative simulations of the power system using production simulation/cost models – With wind/solar – Without wind/solar • To provide an energy-equivalent basis, a hypothetical unit is often chosen for the “without wind/solar” case • This proxy resource may introduce unintended consequences • It is natural to ask about integration costs, but extremely difficult, if not impossible, to measure them accurately National Renewable Energy Laboratory 9 Innovation for Our Energy Future Wind/Daily Block (MW) The flat-block proxy resource distorts the value of the energy 6000 Flat block value - wind value 5000 4000 3000 2000 1000 0 10 200 5 Delta Market Value ($) 100 0 0 -100 -5 -200 -300x10 Wind Generation Daily wind-equivalent energy block Daily flat energy block $43.12/MWh Daily flat block difference $1.06/MWh 6-Hour flat energy block $42.18/MWh 6-Hour flat energy block difference $0.11/MWh (Wind: $42.06/MWh) 3 150 100 10 5 50 0 0 -50 -5 -100 -150x10 -10 3 -10 0 20 National Renewable Energy Laboratory 40 60 80 100 10 120 140 160 Average Over or Under-estimate of Wind Value ($/MWh) 300 Innovation for Our Energy Future Total system costs or integration costs • Total operating costs are relatively easy to calculate • Integration costs are difficult to calculate correctly • Both of these are sensitive to assumptions about the other parts of the power system – What is the mix of conventional generation? – What is the transmission build-out (if any)? – What are the institutional constraints? – Electrical footprint? – Do markets allow access to physical capability that exists, or is this access constrained? – What will the power system look like in 20xx? National Renewable Energy Laboratory 11 Innovation for Our Energy Future Are there other sources of integration costs? • Contingency reserves • Conventional units may impose additional variability and uncertainty that must be managed • Interaction between generators in the economic dispatch process can result in generator A imposing a cost on generator B, even if both units are “conventional” • Gas purchase/nomination requirements National Renewable Energy Laboratory 12 Innovation for Our Energy Future Contingency reserves • Specific rules vary, but the contingency reserve is typically set by the largest unit in the pool. • Often the specific reserve allocation is based on load ratio share or other similar metric • When the largest unit is replaced by a still larger unit, contingency reserve obligations increase • à if I am a generation owner/operator, I will find my contingency reserve obligation may increase independently of any action I have taken (or not taken) National Renewable Energy Laboratory 13 Innovation for Our Energy Future Contingency reserve costs could be allocated based on generators’ contribution to contingency reserve activation…but this is not done National Renewable Energy Laboratory 14 Innovation for Our Energy Future Conventional units may impose regulation costs Two similar coal fired generators: both are trying to provide regula;on but the upper generator is following dispatch instruc;ons fairly well providing regula;on while the lower generator is not and is imposing a regula;on burden on the power system. National Renewable Energy Laboratory 15 Innovation for Our Energy Future New, low-cost base-load may cause integration costs 1. Coal is operated as base-load unit 2. With new wind generation added, gas and coal cycling increase and capacity factors decline 3. Instead of adding wind, a new, cheap base-load technology is introduced. Coal cycling increases; gas is nearly pushed out. Both coal and gas have lower capacity factors. National Renewable Energy Laboratory 16 Innovation for Our Energy Future Gas nominations • Day-ahead nominations • Week-end (or holiday weekends) can pose challenges because of long forecast horizons and uncertainty, and can increase costs and/ or limit flexible use of gas generation • This is an institutional issue and is unrelated to the capability of the gas generation National Renewable Energy Laboratory 17 Innovation for Our Energy Future Principles of Cost-causation: 1 • Maintaining reliability is critical • If tariffs are based on costs, they provide transparency and can induce desired behavior National Renewable Energy Laboratory 18 Innovation for Our Energy Future Principles of Cost-causation: 2 • Individuals who cause costs should pay • Individuals who mitigate (reduce, eliminate) costs should either incur a lower cost, or be paid for helpful actions • Complex systems like electric grids product both joint produces and joint costs that must be allocated among the users of the system • Joint costs can be recovered base on the principle of “relative use.” National Renewable Energy Laboratory 19 Innovation for Our Energy Future Principles of Cost-causation: 3 • Tariffs should not collect revenue if no cost is incurred National Renewable Energy Laboratory 20 Innovation for Our Energy Future Principles of Cost-causation: 4 • Tariffs should be based on the physical characteristics of the power system • Aggregate load and generation must be balanced • It is un-necessary and usually quite costly to balance individual loads or resources, and this is inconsistent with the way the power system is operated National Renewable Energy Laboratory 21 Innovation for Our Energy Future Principles of Cost-causation: 5 • Tariffs should result in an efficient allocation of resources • This can be tested: is there another way that the required services can be supplied at less cost? Or is there another way that the system can be planned or operated at less cost? • If either of these are true, resources are not efficiently allocated National Renewable Energy Laboratory 22 Innovation for Our Energy Future Other characteristics of tariffs • Vertical consistency: individuals who impose higher costs should be assessed more than an individual who imposes lower (or no) cost • Horizontal consistency: individuals who cause similar (identical) costs should be assessed similar (identical) costs National Renewable Energy Laboratory 23 A: High cost B: Low cost A B A and B have similar cost contributions Innovation for Our Energy Future The sum of all parts physically cannot exceed the whole • Methods that separate regulation, following, uncertainty for the analysis must follow the principle of re-composition. • à The sum of – Regulation – Following – Uncertainty • Components must combine so that they do not exceed the total variability + uncertainty… • Sum of all parts of the tariff revenue cannot exceed total costs National Renewable Energy Laboratory 24 Innovation for Our Energy Future Thought experiments: How can tariffs be tested to see how they behave? National Renewable Energy Laboratory 25 Innovation for Our Energy Future Thought experiment #1: Block schedules and regulation Useful to test the behavior of proposed, or actual, tariffs How does the tariff treat perfect following of a volatile schedule? 1600 350 29000 1400 1400 250 27000 1200 1200 150 1000 50 800 -50 600 -150 Load 25000 1000 23000 800 Block schedule 21000 Load Pure block schedule 19000 600 Generation schedule (MW) 1600 400 Pure Block Schedule 400 Generation ramp rate (MW/min) 31000 Scheduled Generation (MW) Total Load (MW) • • -250 Generation ramp rate 17000 00:00 200 03:00 06:00 09:00 12:00 15:00 18:00 21:00 200 00:00 00:00 Time National Renewable Energy Laboratory -350 03:00 06:00 09:00 12:00 15:00 18:00 21:00 00:00 Time 26 Innovation for Our Energy Future Thought experiment #2: Ramping • 1600 35 29000 1400 1400 25 27000 1200 1200 15 1000 5 800 -5 600 -15 Load 25000 1000 23000 800 Load Ramped block schedule Block schedule 21000 19000 600 Generation schedule (MW) 1600 400 Ramped Block Schedule 400 Generation ramp rate (MW/min) 31000 Scheduled Generation (MW) Total Load (MW) • Should a tariff quantify peak-to-peak movements of generator or load? Ramping the block schedule does not impact the energy delivery or forecast accuracy but reduces regulation requirements. -25 Generation ramp rate 17000 00:00 200 03:00 06:00 09:00 12:00 15:00 18:00 21:00 200 00:00 00:00 Time National Renewable Energy Laboratory -35 03:00 06:00 09:00 12:00 15:00 18:00 21:00 00:00 Time 27 Innovation for Our Energy Future Thought experiment #3: Ramp metric • • • • Some approaches to assessing ramping needs (or supply) may not produce desired result Red: regulation, lots of small movements Green: longer time interval but essentially energy-neutral Blue: likely the most challenging • If considered in isolation, does not capture what the system must do 60 50 MW 40 30 20 10 0 0 10 20 30 40 50 60 Minutes National Renewable Energy Laboratory 28 Innovation for Our Energy Future Thought experiment #4 • Equal but opposite behavior is benign to the power system operator • Even though #4 may not be realistic, it can identify tariffs that over-charge based on this principle 30000 1500 System Load Wind Generator Mirror Wind Generator 20000 1000 15000 500 10000 00:00 Generation (MW) Total Load (MW) 25000 2000 0 03:00 06:00 09:00 12:00 15:00 18:00 21:00 00:00 Time National Renewable Energy Laboratory 29 Innovation for Our Energy Future Thought experiment #5 • How does the tariff assess beneficial movement? • For example, would both coal plants be paid the same amount? National Renewable Energy Laboratory 30 Innovation for Our Energy Future Other considerations • Does the tariff recognize all cost-causers? • Does the tariff recognize all helpful actions (intended or otherwise)? National Renewable Energy Laboratory 31 Innovation for Our Energy Future Common errors in integration analysis • Double-counting • Assuming fixed schedules/resources that may be variables in the long-run • Balancing individual actors • Scaling • How are wind/solar forecasts simulated? • Excessive or unknown implied CPS performance • Assumptions regarding replacement power sources and costs National Renewable Energy Laboratory 32 Innovation for Our Energy Future Common errors in integration analysis • Constant reserves (wind and solar generation cannot be less than zero, nor greater than rated) • Failure to release following (or related reserves) when they are called on • Excessive lead times prior to the dispatch period • Assuming specific fleet characteristics (limited turn-down, for example) for future scenarios • Generally – nearly any aspect of the system may change in the future. Assuming all else constant may drive results National Renewable Energy Laboratory 33 Innovation for Our Energy Future Accommodating Wind and Solar Integration Large BA Geographically Dispersed Wind and Solar Wind/Solar Forecasting Effectively Integrated Into System Operations Sub-Hourly Energy Markets Fast Access to Neighboring Markets NonSpinning and 30 Minute Reserves for Wind/Solar Event Response Regional Transmission Planning For Economics and Reliability Robust Electrical Grid More Flexible Transmission Service Flexibility in Generation Responsive Load Overall Example Utility Structures 10 8 7 10 7 2 7 6 7 7 3 7 Large RTO with spot markets 6 6 6 3 3 2 6 4 7 2 2 4 Smaller ISO 1 3 2 1 2 1 2 3 2 2 2 2 Interior west & upper Midwest (non-MISO) 7 6 6 2 2 2 5 4 2 5 2 4 Large vertically integrated utility 1 3 2 1 2 1 2 4 2 2 2 2 Smaller Vertically Integrated Local Utility 1 1 1 1 1 1 1 1 1 8 Unconstrained hydro system 3 Heavily fish constrained hydro system 1 1 11 Weightings Factors Adapted from Milligan, M.; Kirby, B.; Gramlich, R.; Goggin, M. (2009). Impact of Electric Industry Structure on High Wind Penetra3on Poten3al. 31 pp.; NREL Report No. TP-­‐550-­‐46273. hXp://www.nrel.gov/docs/fy09os3/ 46273.pdf National Renewable Energy Laboratory 34 Innovation for Our Energy Future Conclusions • There is no universal agreement on integration cost methods, or whether these costs are measureable • Integration costs are part of normal power systems operation, beyond wind/solar – Conventional units may impose integration costs – Performance-based tariffs are more appropriate than technology-based tariffs, assuming other factors are properly considered • There are many potential non-(wind/solar) cases that may be good base cases • High penetrations of wind/solar will have an impact on the conventional plant mix and institutional practice National Renewable Energy Laboratory 35 Innovation for Our Energy Future Questions? 36