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Potomac Edison Completes 2013 Equipment Upgrades Designed to Enhance Service Reliability
$50 Million Spent Last Year to Expand and Strengthen Electric System and Meet Growing Electric Demand in the Region



January 9, 2014

Potomac Edison, a subsidiary of FirstEnergy Corp. (NYSE: FE), has completed scheduled reliability projects for 2013 designed to further enhance the electrical system and reliability in its Western Maryland and Eastern Panhandle of West Virginia service areas. Major projects included transmission improvements, completion of new distribution circuits, replacement of underground cables, inspection and replacement of utility poles and ongoing vegetation management programs.

Potomac Edison's 2013 enhancements have both localized and widespread system benefits to customers throughout the service area. Upgrades to the distribution system include installation of new wire, cables and fuses to enhance service reliability. The company also completed transmission expansions and enhancements intended to increase the capacity and robustness of Potomac Edison's high-voltage transmission system. The work is part of Potomac Edison's overall $50 million investment in 2013 designed to help improve service reliability.

"These infrastructure investments are designed to help maintain our system on a day-to-day basis to benefit Potomac Edison customers now while helping to prepare our system for future load growth," said James A. Sears, Jr., president of FirstEnergy's Maryland Operations. "When combined with similar investments we've made in recent years, it's part of our ongoing effort to enhance the reliability of our system to benefit our customers."

Highlights of the Potomac Edison reliability work completed in 2013 include:

  • The $5.3 million reconstruction of a transmission line to help maintain reliable electric service for more than 65,000 customers in Carroll, Frederick and Montgomery counties in Maryland.
  • Completing $4.6 million in substation improvements to help enhance service reliability in Frederick County, Md.
  • Replacing equipment at Ridgeley Substation in Ridgeley, W. Va. to help ensure reliability for 13,000 customers in Allegany County, Md.
  • Completing vegetation management work along nearly 2,900 miles of distribution and transmission lines at a cost of about $23 million.
  • Upgrading 90 distribution circuits at a cost of $1.5 million to help enhance the electrical system and reliability for 65,000 customers in Maryland and West Virginia.
  • Replacing underground distribution cables at a cost of more than $2.5 million in Hagerstown, Frederick, Damascus and Mt. Airy, Md., and Wardensville, W. Va.
  • Work to divide large distribution circuits in Germantown and Urbana, Md., and Martinsburg, W. Va., to prepare for load expansion in high-growth areas and to help reduce outage frequency.
  • Inspection of 37,000 utility poles and replacement of 250 poles at a cost of about $2 million.

Potomac Edison serves about 250,000 customers in seven Maryland counties and 132,000 customers in the Eastern Panhandle of West Virginia. Follow Potomac Edison on Twitter.

Forward-Looking Statements

This news release includes forward-looking statements based on information currently available to management. Such statements are subject to certain risks and uncertainties. These statements include declarations regarding management's intents, beliefs and current expectations. These statements typically contain, but are not limited to, the terms "anticipate," "potential," "expect," "will," "intend," "believe," "estimate" and similar words. Forward-looking statements involve estimates, assumptions, known and unknown risks, uncertainties and other factors that may cause actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. Actual results may differ materially due to the speed and nature of increased competition in the electric utility industry, in general, and the retail sales market in particular; the impact of the regulatory process on the pending matters before the Federal Energy Regulatory Commission and in the various states in which we do business including, but not limited to, matters related to rates and pending rate cases; the uncertainties of various cost recovery and cost allocation issues resulting from American Transmission Systems, Incorporated's realignment into PJM Interconnection LLC; economic or weather conditions affecting future sales and margins; regulatory outcomes associated with storm restoration, including but not limited to Hurricane Sandy, Hurricane Irene and the October snowstorm of 2011; changing energy, capacity and commodity market prices including, but not limited to, coal, natural gas and oil, and availability and their impact on retail margins; the continued ability of our regulated utilities to recover their costs; costs being higher than anticipated and the success of our policies to control costs and to mitigate low energy, capacity and market prices; other legislative and regulatory changes, and revised environmental requirements, including possible greenhouse gas emission, water discharge, water intake and coal combustion residual regulations, the potential impacts of Cross-State Air Pollution Rule, Clean Air Interstate Rule (CAIR), and/or any laws, rules or regulations that ultimately replace CAIR, and the effects of the United States Environmental Protection Agency's Mercury and Air Toxics Standards rules including our estimated costs of compliance; the uncertainty of the timing and amounts of the capital expenditures that may arise in connection with any litigation, including New Source Review litigation or potential regulatory initiatives or rulemakings (including that such expenditures could result in our decision to deactivate or idle certain generating units); the uncertainties associated with the deactivation of certain older regulated and competitive fossil units including the impact on vendor commitments, and the timing thereof as they relate to, among other things, Reliability Must-Run arrangements and the reliability of the transmission grid; adverse regulatory or legal decisions and outcomes with respect to our nuclear operations (including, but not limited to the revocation or non-renewal of necessary licenses, approvals or operating permits by the Nuclear Regulatory Commission or as a result of the incident at Japan's Fukushima Daiichi Nuclear Plant); issues arising from the indications of cracking in the shield building at Davis-Besse; the impact of future changes to the operational status or availability of our generating units; the risks and uncertainties associated with litigation, arbitration, mediation and like proceedings, including, but not limited to, any such proceedings related to vendor commitments; replacement power costs being higher than anticipated or not fully hedged; the ability to comply with applicable state and federal reliability standards and energy efficiency and peak demand reduction mandates; changes in customers' demand for power, including but not limited to, changes resulting from the implementation of state and federal energy efficiency and peak demand reduction mandates; the ability to accomplish or realize anticipated benefits from strategic and financial goals including, but not limited to, the ability to reduce costs and to successfully complete our announced financial plans designed to improve our credit metrics and strengthen our balance sheet, including but not limited to, proposed capital raising and debt reduction initiatives, and the proposed sale of non-core hydro assets; our ability to improve electric commodity margins and the impact of, among other factors, the increased cost of fuel and fuel transportation on such margins; the ability to experience growth in the Regulated Distribution and Regulated Transmission segments and to continue to successfully implement our direct retail sales strategy in the Competitive Energy Services segment; changing market conditions that could affect the measurement of liabilities and the value of assets held in our Nuclear Decommissioning Trusts, pension trusts and other trust funds, and cause us and our subsidiaries to make additional contributions sooner, or in amounts that are larger than currently anticipated; the impact of changes to material accounting policies; the ability to access the public securities and other capital and credit markets in accordance with our announced financial plan, the cost of such capital and overall condition of the capital and credit markets affecting us and our subsidiaries; actions that may be taken by credit rating agencies that could negatively affect us and our subsidiaries' access to financing, increase the costs thereof, and increase requirements to post additional collateral to support outstanding commodity positions, letters of credit and other financial guarantees; changes in national and regional economic conditions affecting us, our subsidiaries and our major industrial and commercial customers, and other counterparties including fuel suppliers, with which we do business; issues concerning the stability of domestic and foreign financial institutions and counterparties with which we do business; the risks and other factors discussed from time to time in our United States Securities and Exchange Commission filings, and other similar factors. The foregoing review of factors should not be construed as exhaustive. New factors emerge from time to time, and it is not possible for management to predict all such factors, nor assess the impact of any such factor on FirstEnergy's business or the extent to which any factor, or combination of factors, may cause results to differ materially from those contained in any forward-looking statements. FirstEnergy expressly disclaims any current intention to update, except as required by law, any forward-looking statements contained herein as a result of new information, future events or otherwise.

For more information :

Organization:
FirstEnergy Corp.
www.firstenergycorp.com


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