NREL study suggests cost gap for Western renewables could narrow by 2025
26 August 2013
A new Energy Department study conducted by the National Renewable Energy Laboratory (NREL) indicates that by 2025 wind and solar power electricity generation could become cost-competitive without federal subsidies, if new renewable energy development occurs in the most productive locations. The cost of generation includes any needed transmission and integration costs.
The benchmark for the study is based on the projected future cost of a new combined-cycle natural gas turbine (CCGT) built in the destination market, with natural gas in 2025 at a nominal price of between $7.50/mmBtu and $8.43/mmBtu. According to the analysis, by 2025 geothermal generation could on average be 12% to 35% higher than CCCGT baseline; solar 1-19% higher; and wind at parity up to 13% higher.
|Competitiveness indicators for regionally developed renewables in 2025. Source: Hurlbut et al. Click to enlarge.|
The study, “Beyond Renewable Portfolio Standards: An Assessment of Regional Supply and Demand Conditions Affecting the Future of Renewable Energy in the West,” divides the timeline of renewable energy development into two periods: the time covered by state renewable portfolio standard (RPS) policies as they exist today, and what may be termed “next generation” renewable energy policies. In the West, the last state RPS culminates in 2025, so the analysis uses 2025 as a transition point.
Renewable energy development, to date, has mostly been in response to state mandates. What this study does is look at where the most cost-effective yet untapped resources are likely to be when the last of these mandates culminates in 2025, and what it might cost to connect them to the best-matched population centers.—NREL Senior Analyst David Hurlbut
The study draws on an earlier analysis the lab conducted for the Western Governors’ Association to identify areas where renewable resources are the strongest, most consistent, and most concentrated, and where development would avoid protected areas and minimize the overall impact on wildlife habitat.
Among the study’s findings:
Wyoming and New Mexico could be areas of robust competition among wind projects aiming to serve California and the Southwest. Both states are likely to have large amounts of untapped, developable, prime-quality wind potential after 2025. Wyoming’s surplus will probably have the advantage of somewhat higher productivity per dollar of capital invested in generation capacity; New Mexico’s will have the advantage of being somewhat closer to the California and Arizona markets.
Montana and Wyoming could emerge as attractive areas for wind developers competing to meet demand in the Pacific Northwest. The challenge for Montana wind power appears to be the cost of transmission through the rugged forests that dominate the western part of the state.
Wyoming wind power could also be a low-cost option for customers in Utah, which also has its own diverse portfolio of in-state resources.
Colorado is a major demand center in the Rockies and will likely have a surplus of prime-quality wind potential in 2025. However, the study suggests that Colorado is likely to be isolated from future renewable energy trading in the West due to transmission costs between the state and its Rocky Mountain neighbors.
California, Arizona, and Nevada are likely to have surpluses of prime-quality solar resources. None is likely to have a strong comparative advantage over the others within the three-state market, unless environmental or other siting challenges limit in-state development. Consequently, development of utility-scale solar will probably continue to meet local needs rather than expand exports.
New geothermal development could trend toward Idaho by 2025 since much of Nevada’s resources have already been developed. Geothermal power from Idaho could be competitive in California as well as in the Pacific Northwest, but the quantity is relatively small. Reaching California, Oregon, and Washington may depend on access to unused capacity on existing transmission lines, or on being part of a multi-resource portfolio carried across new lines.
The study notes future electricity demand will be affected by several factors including: trends in the supply and price of natural gas; consumer preferences; technological breakthroughs; further improvements in energy efficiency; and future public policies and regulations. While most of these demand factors are difficult to predict, the study’s supply forecasts rely on empirical trends and the most recent assessments of resource quality.
David J. Hurlbut, Joyce McLaren, and Rachel Gelman (2013) Beyond Renewable Portfolio Standards: An Assessment of Regional Supply and Demand Conditions Affecting the Future of Renewable Energy in the West (NREL/TP-6A20-57830)
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