Ohio Edison Spend of $275 Million in 2013 Designed to Enhance Electric System and Reliability
AKRON, Ohio, March 28, 2013 /PRNewswire/ -- Ohio Edison, a subsidiary of FirstEnergy Corp. (NYSE: FE), announced today that its spend of approximately $275 million in 2013 is designed to further enhance the electrical system and reliability in its northern and central Ohio service areas. Major projects scheduled for this year include completing three new substations, enhancing circuits and substations, 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 Ohio Edison customers now while helping to prepare our system for future load growth," said David Karafa, regional president of Ohio Edison. "Whether it be building new substations, installing equipment that can be operated remotely, or spending on vegetation management, our ultimate goal is to continue to enhance the reliability of our system to benefit our customers."
Ohio Edison's 2013 reliability enhancements are expected to benefit customers throughout its service area. The scheduled projects include:
- Completing two new modular substations to serve areas of growing load in Montville Township in southeast Medina County and Brimfield Township in western Portage County. The combined costs for these projects total almost $4 million. These facilities are expected to be in service prior to the start of this year's hot, high electrical demand summer months.
- Completing the new Black River Substation Project in Lorain. The new station is expected to provide support for system load growth in Lorain, including the new arc furnace load planned at Republic Steel. This project also includes removing transmission lines and an existing substation that ultimately will allow Lorain to develop key lakefront and riverfront property. Overall, the cost for this project is about $17 million.
- Spending approximately $2 million improving circuit capacity and replacing wires to enhance system operation capabilities designed to help ensure reliable service for customers in Columbiana, Trumbull, Lorain and Medina counties.
- Installing improved relays and computer control systems at substations in Akron, Canal Fulton, Cortland, Garrettsville, Medina, North Fairfield, Warren and Youngstown to aid remote monitoring and operations of these stations from Ohio Edison's dispatch center in Akron. As part of the substation enhancements, animal guards will be installed, insulators and switches will be replaced, and breaker upgrades will be made to help reduce the frequency and duration of outages.
- Spending more than $8.5 million inspecting and replacing distribution poles in the Ohio Edison service area. This inspection process is conducted on a 10-year cycle. Approximately 58,000 utility poles will be inspected in 2013, with about 3,000 expected to be replaced.
- Spending more than $20 million as part of Ohio Edison's ongoing vegetation management program to trim trees and maintain proper clearances to help reduce tree-related outages. Some of the scheduled communities include Akron, Alliance, Delaware, Elyria, Fairlawn, Kent, Lorain, Mansfield, Massillon, Marion, Medina, Ravenna, Sandusky, Springfield, Warren and Youngstown. Overall, more than 6,200 miles of Ohio Edison distribution lines will be trimmed in 2013.
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.
SOURCE FirstEnergy Corp.