ITC and AEP jockey for the lead in building the grid of tomorrow.
On February 9, a group of the nation’s major grid system operators released a study estimating the nation’s electric industry sector needs to spend some $80 billion—more than 10 times the size of that portion of the Obama stimulus package directed specifically at transmission construction—in order to achieve a 20 percent retail penetration for renewable wind energy in just the Eastern Interconnection.
Left-coast lawmakers envision a greener America.
As the new U.S. government takes shape, at least one trend seems clear: California is taking over the country. Well, maybe not “taking over,” exactly. But leading.
As green mandates tighten, utilities scramble to comply.
Mandatory renewable portfolio standards are becoming the norm. But after low-hanging green fruits are harvested, renewable power might get scarce. Many utilities will struggle to meet RPS requirements until lawmakers create stable federal policies and a national market for green credits.
What do customers get from AMI investments?
Utility commissions are responding to their constituents by dramatically increasing emphasis on funding for energy-efficiency and demand-response programs. They believe—and expect—advanced metering infrastructure (AMI) will contribute substantially to both areas.
Why predictions from the Energy Information Administration may contain systematic errors.
Timothy J. Considine, Ph.D. and Frank A. Clemente, Ph.D.
Natural-gas estimates from the Energy Information Administration (EIA) are supposed to be “policy neutral.” Are they? Over the past decade, EIA forecasts for NG differ substantially from actual outcomes—even though overestimations of supply capabilities could lead to underestimating the costs of carbon regulations.
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.
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.
Using demand response to mitigate rate shocks.
In the minds of many policy-makers, DR has become associated with rate shocks, rate volatility, unpredictability, and loss of control over energy costs—the very things DR was designed to overcome. What can be done to change this?
To what extent can the EPA force utilities to update aging fleets with expensive pollution-control technology?
John D. Wilson and Brian H. Potts
The U.S. Supreme Court soon will issue a potentially far-reaching decision in a case involving Duke Energy Corp. What’s the upside for the electric industry?
How reliability performance monitoring and standards compliance will be achieved in real time.
Carlos A. Martinez, Robert W. Cummings, Philip N. Overholt, and Joseph H. Eto
The North American electric power grid has suffered several significant outages in recent years. These events and other incidents around the world spotlight the need for enforceable grid-reliability standards, wide-area visibility of the health of the power system, and real-time monitoring of grid-reliability performance to prevent blackouts. Effective reliability management requires real-time tools and technologies that can detect standards violations so that timely corrective or preventive actions can be taken.