"Generic statements that transmission reinforcement is desirable do not amount to establishment of need."

They can contact the IG hotline at:
[email protected]
D.C. Metro Area: (202) 586-4073
Toll free: (800) 541-1625
FAX: (202) 586-4902

Construction of major new transmission facilities, in particular, raises unique issues because transmission facilities have long lives – typically 40 years or more. Evaluating the merits of a proposed new facility is  challenging, because common practices take into account only those expected costs and benefits from a project that can be quantified with a high degree of perceived certainty. This has two effects:
First, it leads to a focus on the subset of cost and benefits that can be readily quantified. Not taking into account the costs and benefits that are hard to quantify has the effect of setting their value to zero in a comparison of costs and benefits.
Second, it leads to projections of costs and benefits that are generally on extrapolations drawn from recent experiences. Projections based only on recent experiences will not value the costs and benefits a transmission project will have under very different assumptions or scenarios regarding the future because they ignore or discount the likelihood of these possibilities. Such a narrow view of the range of costs and benefits that could occur provides a false sense of precision.

As will be discussed later in this chapter, many states adopted Renewable Portfolio Standards with requirements or goals to use more  renewable‐sourced electricity.
Because much of the best utility‐scale renewable resource potential is relatively remote from the load centers, the states then had to authorize new transmission construction to enable the desired renewable‐based electricity to reach the grid.

Many points of transmission congestion today result from the need to deliver electricity from
changing sources of generation. For example, generation sources are changing because of
state‐mandated RPSs. The best renewable resources (i.e., those with the highest potential capacity factors) tend to be located far from load and sometimes in areas with less transmission than desired for effective resource development. Existing transmission constraints may deter development of these resources. While this is not a challenge in all parts of the Eastern Interconnect, it is a principal cause of evolving congestion concerns in the Midwest.

Designation of an area as a National Corridor is one of several preconditions required for
possible exercise by the Federal Energy Regulatory Commission (FERC) of “backstop” authority to approve the siting of transmission facilities in that area.

The company and the union have been negotiating for a new contract since March 2013. Federal mediators have been involved during the past several months.
Whalen said union members are upset at FirstEnergy demands such as that they use their own "vehicles on their own time" to reach construction and maintenance worksites, and, because the utility is at "an all-time low staffing level," each worker is being forced to respond to emergency calls far more often than was normal a few years ago.

...the utility has plans to continue providing electrical power to its 382,000 customers in Potomac Edison’s Maryland and West Virginia territory “no matter what happens,” company spokesman Todd Meyers said.

“We’ll keep the lights on for our customers,” he said.

"The economic potential for our area is tremendous and uses South Dakota's renewable resources to help solve our country's energy needs," said Beresford Mayor Jim Fedderson.

Based on a study done for a similar project, Dakota Power says the potential revenue from turbines to landowners could be between $6 million and $7 million annually. State gross production annual tax receipts could reach more than $4.5 million and the county nameplate tax revenue could equal $3 million per year. Statewide direct economic effect could be more than $200 million.