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Potomac Edison Spend of $55 Million in 2013 Designed to Enhance Electric System and Reliability

   Potomac Edison Spend of $55 Million in 2013 Designed to Enhance Electric
                            System and Reliability

PR Newswire

WILLIAMSPORT, Md., April 23, 2013

WILLIAMSPORT, Md., April 23, 2013 /PRNewswire/ --Potomac Edison, a subsidiary
of FirstEnergy Corp. (NYSE: FE), announced today that its spend of
approximately $55 million in 2013 is designed to further enhance the
electrical system and reliability in its western Maryland and Eastern
Panhandle of West Virginia service areas. Major projects scheduled for this
year include transmission improvements, building new distribution circuits,
replacing underground cables, inspecting and replacing utility poles and
ongoing vegetation management programs.

"The planned infrastructure projects 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 V. Fakult,
FirstEnergy's president of Maryland Operations and vice president of Potomac
Edison. "Whether it be installing new equipment at substations, replacing
cables or spending on vegetation management, our ultimate goal is to continue
to enhance the reliability of our system to benefit our customers."

Potomac Edison's 2013 enhancements are expected to have both localized and
widespread system benefits to customers throughout the service area. More
than $23 million will be spent on a variety of transmission expansions and
enhancements intended to increase the capacity and robustness of Potomac
Edison's high-voltage transmission system. Other scheduled projects include:

  oUpgrading a 138-kV line in Frederick County, Md., at a cost of more than
    $3 million to ensure ongoing reliable service for more than 65,000
    customers in Carroll, Frederick, Howard and Montgomery counties.
  oAdding high-voltage equipment and other improvements to a substation at a
    cost of $5 million to enhance service reliability in fast-growing
    Frederick County and the region.
  oPurchasing several spare high-voltage power transformers at a cost of more
    than $1 million to help reduce outage duration, if needed.
  oSpending more than $500,000 to replace aging equipment and install new
    monitoring technology in the Ridgeley Substation in Ridgeley, W. Va., to
    ensure continued reliability to about 13,000 customers in Allegany County,
    Md.
  oSpending more than $17 million as part of Potomac Edison's ongoing
    vegetation management program to trim trees and maintain proper clearances
    to help reduce tree-related storm damage. Some of the scheduled areas
    include Allegany, Frederick, Garrett, Berkeley and Washington counties.
  oUpgrading equipment on about 90 distribution circuits throughout the
    service territory to enhance service reliability at a cost of $2.7
    million. The improvements – installing new wire, cable and fuses – are
    expected to enhance the electrical system and reliability for about 65,000
    customers in Maryland and West Virginia.
  oReplacing underground distribution cables. Work totaling more than $3
    million will target Damascus and Mt. Airy in Frederick County,
    Shepherdstown in Jefferson County, W. Va., and Wardensville in Hardy
    County, W. Va. Outages involving underground wires often take longer to
    restore than overhead outages.
  oDividing two large distribution circuits in the Germantown and Urbana
    areas to prepare for load expansion in high-growth areas and reduce outage
    frequency for more than 3,500 Potomac Edison customers in Frederick and
    Montgomery counties.
  oInstalling a new distribution line to accommodate recent development and
    prepare for future growth in the Spring Mills area of Berkeley County, W.
    Va.
  oTransferring more than 1,700 Potomac Edison customers in the Augusta area
    of Hampshire County, W. Va., to another circuit to improve service
    reliability.
  oInspecting and proactively replacing distribution and sub-transmission
    utility poles in the Potomac Edison service area. The inspection process
    is conducted on a 10-year cycle in Maryland and a 12-year cycle in West
    Virginia. Approximately 33,000 utility poles will be inspected in 2013,
    with about 500 expected to be replaced.

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 @PotomacEdison.

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," "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 FERC 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 ATSI's realignment into PJM,
economic or weather conditions affecting future sales and margins, regulatory
outcomes associated with Hurricane Sandy, changing energy, capacity and
commodity (including, but not limited to, coal, natural gas and oil) market
prices and availability and their impact on retail margins, financial
derivative reforms that could increase our liquidity needs and collateral
costs, the continued ability of our regulated utilities to collect transition
and other costs, operation and maintenance costs being higher than
anticipated, other legislative and regulatory changes, and revised
environmental requirements, including possible GHG emission, water discharge,
water intake and coal combustion residual regulations, the potential impacts
of CAIR, and any laws, rules or regulations that ultimately replace CAIR, and
the effects of the EPA's MATS 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 NSR
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 unscrubbed regulated and competitive fossil units, including the
impact on vendor commitments, and the timing thereof as they relate to, among
other things, the RMR 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 NRC
or as a result of the incident at Japan's Fukushima Daiichi Nuclear Plant),
adverse legal decisions and outcomes related to ME's and PN's ability to
recover certain transmission costs through their TSC riders, 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 inadequately 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 successfully
complete the proposed West Virginia asset transfer and to improve our credit
metrics, 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
segment 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 NDTs, 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 financing plans, 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, LOCs 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 SEC 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 the business of FirstEnergy or the Companies 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 and the
Companies expressly disclaim 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.

www.firstenergycorp.com

SOURCE FirstEnergy Corp.

Website: http://www.firstenergycorp.com
Contact: Media: Todd Meyers, 888-233-3583
 
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