FERC would relax price caps—sending rates skyward—to encourage customers to curtail loads.
About four months ago, at a conference at Stanford University’s Center for International Development, the economist and utility industry expert Frank Wolak turned heads with a not-so-new but very outrageous idea.
What the U.S. electricity sector must do to significantly reduce CO2 emissions in coming decades.
Revis James, Richard Richels, Geoff Blanford, and Steve Gehl
The large-scale CO2 reductions envisioned to stabilize, and ultimately reverse, global atmospheric CO2 concentrations present major technical, economic, regulatory and policy challenges. Reconciling these challenges with continued growth in energy demand highlights the need for a diverse, economy-wide approach.
The big challenge facing the Northeast energy markets.
The Northeast energy markets are working hard to establish new levels of regional coordination and cooperation. The region’s concerted effort is essential to resolving some of the industry’s toughest issues since the individual markets evolved. These issues include the elimination, reduction, or bridging of seams issues that prevent the economic transfer of capacity and energy between neighboring wholesale electricity markets, or control areas, as a result of incompatible market rules or designs.
A lengthy letter to the editor addresses whether the Energy Information Administration’s gas-market forecasts, as laid out in a recent article, are biased. The authors of the original piece, Timothy J. Considine and Frank A. Clemente, then respond to the letter.
The 2005 Act, designed to streamline projects, may fall short of that goal.
David B. MacGregor and Matthew J. Agen
The Energy Policy Act of 2005 was supposed to streamline the siting process and provide a federal “trump card” for projects delayed at the local level, but it is far from clear whether these goals have been, or will be, achieved.
Next-gen technologies race to dominate the big build.
New nuke plants will take at least eight years to complete, while the coal that powers new IGCC plants is no longer cheap. Regulatory and market obstacles confront both technologies, just as they emerge from the starting gate. Which type of plant will win the future?
Can markets co-exist with renewable mandates?
Part way through the Feb. 27 conference on electric competition, it was so quiet you could hear a hockey puck slide across the ice. No, hell had not frozen over. Rather, it was Commissioner Marc Spitzer, who had found a clever story to ease the tension and allay fears that FERC somehow might want to undo the sins of the past, and give up its dream of workable markets for wholesale power.
Electric shortages and the generation overbuild continue to co-exist.
While maintaining its stance as the most sophisticated competitive electricity market in the country, PJM still faces several challenges, all of which are augmented by its expanded footprint. Most prominent is the RTO’s plan to implement a new reliability pricing model. Further, parts of PJM are ailing from transmission congestion issues that limit access to abundant, cheap power sources in the region.
Billions in new revenue could be realized early in the transition.
In a hydrogen-electric economy, power companies could see very large market opportunities—and play a major role in enabling and accelerating implementation.
Everyone is in favor of more demand response, but little gets delivered when system operators need it the most.
Scott Neumann, Fereidoon Sioshansi, Ali Vojdani, and Gaymond Yee
Despite overwhelming theoretical and empirical evidence, we aren’t seeing more DR when it is needed most—during emergency periods. The reasons boil down to two obstacles, both of which must be addressed before widespread DR implementation can move forward.