If transmission can substitute for gen-plant capacity, why not clear both products in the same auction?
PJM applied to FERC for authority to impose a new regime of requirements for reserves of electric generating capacity. This new construct, known as the reliability pricing model (RPM), would replace PJM’s current capacity market.
The battle for the future of coal-fired power is heating up. Recent developments give IGCC a fighting chance.
Does the future belong to pulverized coal or integrated gasification combined-cycle technologies? The answer will determine how the industry manages load growth and regulatory risks, while protecting shareholders and ratepayers.
Why haven’t reliability markets developed?
Capacity and energy, although related, are not identical products. If we are to continue to rely on competitive market forces to provide new generation supplies, we need separate, long-term, installed capacity markets.
Opportunities and limitations of five top strategies.
How can regulated utilities create value? Each of five key options present their own risks. Which way should management go?
How EPACT fails to address key industry issues.
The Energy Policy Act of 2005 ducks three crucial issues: volatile prices and fuel supplies; insufficient, erratic capital investment in generation and transmission; and energy commodity pricing. What should policymakers do now?
How will the commission answer Congress’ call for energy market transparency?
How will the Federal Energy Regulatory Commission answer Congress’ call for energy market transparency? Will it rest on its laurels, or move forward to restore confidence in wholesale energy markets?
Regulators and Utilities: The Ball’s in Your Court
Are the smart-metering provisions of EPACT 2005 a good thing? The answer, like most things in life, is, “It depends.” Looked at holistically, the opportunity is great. Viewed incrementally, it’s empty words on paper. It’s up to regulators and utilities to take the initiative.
How they can generate green energy and improve a municipality’s bottom line.
Federal incentive payment of 1.8 cents/kWh for the generation of renewable energy—part of The Energy Policy Act of 2005—increases the economic attractiveness of many potential hydro sites, and, as a consequence, could revive the building of low-head dams.
Utilities and financiers want ratepayers to fund the next wave of power plants. Will higher electric rates spoil the party?
You’ve heard the story. The local utility ought to be investing billions in new power plants, but the company CEO wants a guarantee from regulators for upfront costs and future operating expenses before laying down dollar one on the project. What to do? Utility CEOs attending the Edison Electric Institute’s 40th Financial Conference last month in Hollywood, Fla., were shuffling to the old rate base song-and-dance. But this time, they were working out a few new moves.
(December 2005) Mark Mulhern joins Progress Energy’s senior management committee and Bob Adrian is vice president of competitive commercial operations within the Ventures organization. The California Independent System Operator board of governors approved the appointment of Karen Edson to the position of vice president of external affairs. DTE Energy announced a series of organizational changes. The Southern California Edison board of directors elected John R. Fielder president.