[  ]  TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
      SECURITIES EXCHANGE ACT OF 1934

For the transition period from             to              

Commission file number 1-14766

(518) 434-3049
(Registrant's telephone number, including area code)

N/A
(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Yes     X        No           

The number of shares of common stock (par value $.01 per share) outstanding as of July 31, 2000, was 111,526,745.

TABLE OF CONTENTS

PART I

PART II

Energy East Corporation
Consolidated Statements of Income - (Unaudited)

Energy East Corporation
Consolidated Statements of Cash Flows - (Unaudited)

Note 2. Acquisition of Connecticut Energy Corporation

The company completed its merger with CNE on February 8, 2000. The following pro forma information for the company for the three months and six months ended June 30, 2000 and 1999, which is based on unaudited data, gives effect to the company's merger with CNE as if it had been completed January 1, 1999. This information does not reflect future revenues or cost savings that may result from the merger and is not indicative of actual results of operations had the merger occurred at the beginning of the periods presented or of results that may occur in the future.

Pro forma adjustments reflected in the amounts presented above include: (1) adjusting CNE's non-utility assets to fair value based on an independent appraisal, (2) amortization of goodwill, (3) elimination of merger costs and (4) adjustments for estimated tax effects of the above adjustments.

Selected unaudited financial information for the company's business segments is presented in the following table. The company's "Energy Delivery" segment consists of its regulated electricity distribution, transmission and generation operations, and its regulated natural gas distribution, transportation and storage operations. "Other" includes the company's energy services businesses, corporate assets and intersegment eliminations.

Merger Agreements

The company completed its merger with CNE on February 8, 2000. (See Item 1 - Note 2 to the Consolidated Financial Statements.) The three other mergers that the company entered into definitive merger agreements for during 1999 are still pending: CMP Group, Inc., CTG Resources, Inc. and Berkshire Energy Resources. Each of those companies will become a wholly-owned subsidiary of the company. The transactions will be accounted for using the purchase method. In connection with the mergers the company intends to register as a holding company with the Securities and Exchange Commission (SEC) under the Public Utility Holding Company Act of 1935. The company expects SEC approval of the mergers in late August 2000 and expects to complete the mergers shortly thereafter.

CMP Group Merger: The company will acquire all of the common stock of CMP Group for $29.50 per share in cash. The transaction has an equity market value of approximately $957 million. The company will also assume approximately $113 million of CMP Group preferred stock and long-term debt.

On October 7, 1999, CMP Group shareholders approved the merger agreement. Orders approving the merger were issued by the Maine Public Utilities Commission on January 4, 2000, the Nuclear Regulatory Commission (NRC) on February 4, 2000, and the Federal Energy Regulatory Commission (FERC) on April 3, 2000. The merger is subject to, among other things, SEC approval. All necessary filings have been made.

CTG Resources Merger: This transaction values CTG Resources' common equity at approximately $355 million, and the company will assume approximately $220 million of CTG Resources' long-term debt.

Under the agreement, 45% of the common stock of CTG Resources will be converted into the company's common stock with a value of $41.00 per CTG Resources share, and 55% will be converted into $41.00 in cash per CTG Resources share, subject to restrictions on the minimum and maximum number of shares to be issued. Shareholders will be able to specify the percentage of the consideration they wish to receive in stock and in cash, subject to proration.

On October 18, 1999, CTG Resources shareholders approved the merger agreement. The Connecticut Department of Public Utility Control (DPUC) issued an order approving the merger on January 19, 2000. The merger is subject to, among other things, SEC approval. All necessary filings have been made.

Berkshire Energy Resources Merger: The company will acquire all of the common stock of Berkshire Energy for $38.00 per share in cash. The transaction has an equity market value of approximately $96 million. The company will also assume approximately $40 million of Berkshire Energy preferred stock and long-term debt. On February 29, 2000, Berkshire Energy shareholders approved the merger agreement. The merger is subject to, among other things, SEC approval. All necessary filings have been made.

Energy Delivery Business

(See the company's Form 10-Q for the quarter ended March 31, 2000, Item 2(a) Liquidity and Capital Resources - Energy Delivery Business.)

Sale of Coal-fired Generation Assets: The sale of the company's seven coal-fired stations and associated assets and liabilities to Edison Mission Energy and The AES Corporation was completed in the first half of 1999. In the second quarter of 2000 New York State Electric & Gas Corporation (NYSEG) revised its estimate of deferred taxes related to the coal-fired plants and Nine Mile Point 2. As a result, 1999 depreciation and amortization expense increased, and the writeoff of the remaining investment in Nine Mile Point 2 decreased, by $10 million.

Nine Mile Point 2: In June 1999 NYSEG announced that it had agreed to sell its 18% interest in Nine Mile Point 2 to AmerGen Energy Company, a joint venture of PECO Energy Company and British Energy. In July 1999 NYSEG filed the sale agreement with the Public Service Commission of the State of New York (PSC) for its approval.

On April 5, 2000, NYSEG filed a motion asking the PSC to dismiss its July 1999 petition to sell its interest in Nine Mile Point 2 to AmerGen. NYSEG noted that the market for nuclear generation has changed dramatically since the agreement to sell the majority interest in Nine Mile Point 2 was announced in June 1999. The motion also asked the PSC to reaffirm its mandate in NYSEG's restructuring plan that there be an auction of Nine Mile Point 2 with pre-approved protocols and pre-approved regulatory treatment.

On April 25, 2000, the PSC issued an order approving withdrawal of the petition. The order did not specifically provide for pre-approved protocols and pre-approved regulatory treatment. It did note, however, the desirability of selling Nine Mile Point 2 through an open process. The order also noted (1) that the sale of Nine Mile Point 2 at current market values would constitute appropriate mitigation of the utilities' stranded costs and would establish a basis for the PSC to further consider the extent of the utilities' ability to recover their remaining stranded costs and (2) that the PSC would resolve the ratemaking treatment of any sale of Nine Mile Point 2 by following the principles established in the utilities' restructuring orders and examining reduced utility risks and corollary effects resulting from plant divestiture.

On May 11, 2000, NYSEG, Niagara Mohawk and AmerGen executed a termination agreement related to the sale.

On May 31, 2000, NYSEG filed a petition with the PSC asking for approval of proposed auction protocols and ratemaking treatment for the sale of its interest in Nine Mile Point 2. NYSEG has not received a response from the PSC on the May 31, 2000 petition. NYSEG's participation in the auction of Nine Mile Point 2 awaits PSC approval.

New York Independent System Operator: The New York Independent System Operator (NYISO) began operating on November 18, 1999. The NYISO and the New York State Reliability Council were formed to restructure the New York Power Pool in response to FERC Order 888. FERC Orders 888 and 889 were issued to foster the development of competitive wholesale electricity markets by opening up transmission services and to address the resulting stranded costs. The NYISO administers a new, centralized energy and ancillary services market.

The NYISO continues to experience software and operational breakdowns, which have resulted in unexplained spikes in the price of electricity, billing errors and reliability concerns. Those problems, along with allegations of market power, have resulted in numerous FERC filings by the NYISO and market participants.

On March 31, 2000, NYSEG petitioned the FERC to allow for the recalculation of operating reserve prices in a manner consistent with a properly functioning competitive market and to seek refunds as provided within the framework of the NYISO's tariffs. In response to NYSEG's and other parties' operating reserve filings, on May 31, 2000, the FERC ordered a bid cap for a portion of the operating reserves markets. It also required the NYISO to alter tariff provisions and market mechanisms to address software and implementation flaws in the operating reserves markets. The FERC did not, however, order the recalculation of prices or refunds as sought by NYSEG. Several requests for rehearing have been filed.

In April and May 2000 NYSEG petitioned the FERC to investigate and initiate emergency actions to correct start-up and transitional problems of the NYISO administered energy markets. On June 30, 2000, the NYISO filed a petition requesting a $1,300 bid cap in its administered energy markets. In response to NYSEG's petition concerning the energy markets and the NYISO's bid cap filing, on July 26, 2000, the FERC ordered a bid cap of $1,000 per megawatt-hour in the NYISO's energy markets until October 28, 2000, to give the NYISO time to correct transitional problems.

The company does not expect that the transitional problems in the NYISO energy and operating reserves markets will have a material adverse effect on its financial position or results of operations.

Power Requirements: Approximately 60% of NYSEG's power requirements are satisfied through generation from its nuclear and hydroelectric stations and by purchases under long-term contracts from non-utility generators and the New York Power Authority. At June 30, 2000, NYSEG had electricity contracts through the end of 2000 for 85% of its remaining power requirements and has fully satisfied its expected power requirements for this summer.

Natural Gas Rate Agreements: In February 2000 The Southern Connecticut Gas Company (Southern) requested reconsideration of the DPUC's denial of Southern's performance-based ratemaking proposal. In April 2000 the DPUC issued a notice of hearings to consider Southern's request to implement alternative ratemaking in the form of an incentive rate plan. The hearings are currently underway and Southern expects a final decision later in 2000.

Energy Tax Reform: The New York State 2000 Budget includes major reforms to the taxation of electric and natural gas companies. Those reforms include, among others, the repeal of certain gross receipts taxes and the imposition of a net income tax. A PSC proceeding is in progress to determine the ratemaking treatment related to the implementation of these reforms.

Investing and Financing Activities

Investing Activities: Capital spending for the first six months of 2000 was $55 million including nuclear fuel but excluding the merger transaction with CNE. (See Item 1 - Note 2 to the Consolidated Financial Statements and Merger Agreements.) Capital spending for 2000, including nuclear fuel but excluding the CNE and pending merger transactions, is projected to be $126 million and is expected to be paid for entirely with internally generated funds. Capital spending will be primarily for the extension of energy delivery service, necessary improvements to existing facilities and compliance with environmental requirements.

Financing Activities: The company repurchased 6.6 million shares of its common stock during the six months ended June 30, 2000.

The company has a revolving credit agreement with certain banks that provides for borrowing up to $300 million for a 364-day period, which the company expects to renew annually.

The company expects to issue long-term debt prior to the completion of the CMP Group, CTG Resources and Berkshire Energy merger transactions. The proceeds from the debt issuance, along with the proceeds from the sale of its generation assets, internally generated funds and funds from the revolving credit agreement will be used to fund the cash portion of the consideration for the merger transactions and to fund the company's ongoing share repurchase program. (See Merger Agreements.) In anticipation of this debt issuance, in June 1999 the company entered into a $500 million, one-year interest rate hedge on the benchmark 30-year Treasury Bond. This hedge was extended until August 26, 2000, with an associated interest rate of 6.31%.

In January 2000 NYSEG redeemed $163 million of unsecured notes with cash and commercial paper.

CNE and Southern have credit lines with certain banks that renew annually and provide for borrowing up to $70 million. Southern has committed lines of $50 million until the end of June 2001, and CNE and Southern share a committed line of $20 million until December 29, 2000. Due to the company's acquisition of CNE, an additional short-term facility of $96 million was established to temporarily finance the redemption of long-term debt. This redemption was due to a provision in Southern's bond purchase agreements that gave the bondholders the right to have the bonds redeemed as a result of the acquisition. First mortgage bonds totaling $77 million were redeemed at a premium of $18 million.

Southern has filed an application with the DPUC requesting authorization to issue up to $200 million of secured medium-term notes. The proceeds from the medium-term notes will be used to pay down the short-term debt incurred to redeem first mortgage bonds, and for other general corporate purposes.

Forward-looking Statements

This Form 10-Q contains certain forward-looking statements that are based on management's current expectations and information that is currently available. The Private Securities Litigation Reform Act of 1995 provides a safe harbor for forward-looking statements in certain circumstances. Whenever used in this report, the words "estimate," "expect," "believe," "anticipate," or similar expressions are intended to identify such forward-looking statements.

In addition to the assumptions and other factors referred to specifically in connection with such statements, factors that could cause actual results to differ materially from those contemplated in any forward-looking statements include, among others, the deregulation and unbundling of energy services; the company's ability to compete in the rapidly changing and increasingly competitive electricity and natural gas utility markets; its ability to control non-utility generator and other costs; changes in fuel supply or cost and the success of its strategies to satisfy its power requirements now that all of its coal-fired generation assets have been sold; its ability to expand its products and services, including its energy infrastructure in the Northeast; its ability to integrate the operations of CNE, CMP Group, CTG Resources and Berkshire Energy with its operations; market risk; the ability to obtain adequate and timely rate relief; nuclear or environmental incidents; legal or administrative proceedings; changes in the cost or availability of capital; growth in the areas in which it is doing business; weather variations affecting customer energy usage; and other considerations that may be disclosed from time to time in its publicly disseminated documents and filings. The company undertakes no obligation to publicly update any forward-looking statements, whether as a result of new information, future events or otherwise.

Excluding the non-recurring benefits in 2000 and 1999 from the sale of the company's coal-fired plants net of the Nine Mile Point 2 writeoff, earnings per share for the quarter ended June 30, 2000, were 43 cents compared to 39 cents in 1999. The increase was primarily due to certain transmission revenues, which the company began earning this quarter, and cost control efforts. Those increases were partially offset by NYSEG's higher purchase costs of electricity and natural gas.

Excluding the non-recurring benefits in 2000 and 1999 from the sale of the company's coal-fired plants net of the Nine Mile Point 2 writeoff, earnings per share for the first half of 2000 were $1.25 compared to $1.07 in 1999. The increase was primarily due to cost control efforts, certain transmission revenues that the company began earning in the second quarter, fewer shares outstanding due to the share repurchase program, the addition of CNE's earnings and a federal income tax adjustment due to the settlement of the 1995 and 1996 IRS audit. Those increases were partially offset by NYSEG's higher purchase costs of electricity and natural gas, higher than anticipated ancillary services costs associated with the NYISO, lower wholesale electricity deliveries as a result of the sale of the company's coal-fired plants last year and lower retail electricity prices.

The $40 million increase in operating revenues is due to the addition of Southern's natural gas revenues, certain transmission revenues that the company began earning this quarter, and higher retail and wholesale natural gas activities. Those increases were partially offset by a decrease in wholesale electricity deliveries as a result of the sale of the company's coal-fired generation plants last year and lower retail electricity prices.

Operating expenses increased $41 million, excluding a $98 million benefit in 1999 from the sale of the company's coal-fired generation assets net of the writeoff of Nine Mile Point 2. This was primarily due to the addition of Southern's natural gas purchases and operating costs and increases in NYSEG's purchase costs of electricity and natural gas that were primarily due to higher market prices. Maintenance expenses increased in 2000 due to the Nine Mile Point 2 refueling outage and higher storm costs. Those increases were partially offset by cost control efforts and a reduction in operating expenses because of the sale of the coal-fired generation plants and a related reduction in amortization of Nine Mile Point 2.

The $52 million increase in operating revenues is due to the addition of Southern's natural gas revenues, certain transmission revenues that the company began earning in the second quarter, and higher retail and wholesale natural gas activities. Those increases were partially offset by a decrease in wholesale electricity deliveries as a result of the sale of the company's coal-fired generation plants last year and lower retail electricity prices.

Operating expenses increased $46 million, excluding a $98 million benefit in 1999 from the sale of the company's coal-fired generation assets net of the writeoff of Nine Mile Point 2. That increase was primarily due to the addition of Southern's natural gas purchases and operating costs and increases in NYSEG's purchase costs of electricity and natural gas that were primarily due to higher market prices and higher than anticipated ancillary services costs associated with the NYISO. Those increases were partially offset by cost control efforts and a reduction in operating expenses because of the sale of the coal-fired generation plants and a related reduction in amortization of Nine Mile Point 2.

(See the company's Form 10-K for the fiscal year ended December 31, 1999, Item 7A - Quantitative and qualitative disclosures about market risk.)

Interest Rate Risk: In June 1999 the company entered into a $500 million, one-year interest rate hedge on the benchmark 30-year Treasury Bond in anticipation of the expected issuance of long-term debt related to its pending mergers. This hedge has been extended until August 26, 2000. The interest rate associated with this hedge is 6.31%. The effect of market risk on results of operations is not material since the company plans to amortize the difference between the actual 30-year U.S. Treasury rate and 6.31% over the life of the new issue.

Commodity Price Risk: NYSEG is exposed to the effect of market fluctuations in the price of natural gas and electricity purchased. NYSEG's natural gas exposure is limited to purchases for residential customers because it is allowed to pass through increases in the market price of natural gas to non-residential customers. It manages its electricity and natural gas risk by the use of forward purchases, futures, contracts for differences (CFDs) and options.

NYSEG uses natural gas futures and options contracts to manage its exposure to fluctuations in natural gas commodity prices. Such contracts allow NYSEG to fix margins on sales of natural gas. The cost or benefit of natural gas futures and options contracts is included in the commodity cost when the related sales commitments are fulfilled. The difference between cost and fair value of natural gas futures and options contracts outstanding is not material to the company's results of operations.

At June 30, 2000, NYSEG had purchased option contracts for almost one-half of its residential natural gas load for August through December 2000 to reduce price risk. NYSEG will continue to purchase options to reduce its remaining price risk exposure.

NYSEG uses electricity contracts to manage its exposure to fluctuations in the cost of electricity. These contracts allow NYSEG to fix margins on the majority of its retail electricity sales. The cost or benefit of electricity contracts is included in the amount expensed for electricity purchased when the electricity is sold. With the implementation of the NYISO NYSEG began utilizing CFDs, which are financial contracts with features similar to commodity swap agreements. The CFDs effectively fix the price NYSEG pays for certain power purchased from the NYISO. Using electricity contracts and CFDs, NYSEG has hedged 100% of its expected summer demand for 2000 and approximately 85% of its expected demand through March 2003.

(a)  In February 1988 the New York State Department of Environmental Conservation (NYSDEC) notified NYSEG that it had been identified as a potentially responsible party (PRP) for investigation and remediation of the disposal of hazardous wastes at the Lockport City Landfill Site in Lockport, New York. The Lockport Site is listed on the New York State Registry of Inactive Hazardous Waste Sites. Five other PRPs were identified by the NYSDEC. The Lockport Site has been remediated by the site owner, the City of Lockport. In May 1988 NYSEG notified the NYSDEC that it declined to finance remediation costs because it believed that the NYSDEC had not demonstrated that a significant threat to public health or the environment existed as a result of hazardous waste disposal at the Lockport Site.

On May 17, 2000, the New York State Attorney General's office wrote to NYSEG and eight other PRPs advising them that the State intended to pursue claims against them for about $3.3 million. The company and the other PRPs were asked to enter into an agreement to suspend the statute of limitations and pursue a negotiated settlement. NYSEG (and all other recipients) agreed to the suspension. NYSEG expects negotiations to begin shortly.

(b)  (See the company's Form 10-Q for the quarter ended March 31, 2000, Part II - Other Information, Item 1(b) Legal Proceedings.) NYSEG received a letter in October 1999 from the New York State Attorney General's office alleging that NYSEG may have constructed and operated major modifications to certain emission sources at the Goudey and Greenidge generating stations, which it formerly owned, without obtaining the required prevention of significant deterioration or new source review permits.

On April 19, 2000, NYSEG received a letter from the U.S. Environmental Protection Agency (EPA) requesting information with respect to the operation of the Milliken and Kintigh generating stations, which it formerly owned.

On May 25, 2000, NYSEG received a notice of violation from the NYSDEC alleging that two projects at Goudey and four projects at Greenidge were constructed without the necessary permits having been obtained.

NYSEG believes it has complied with the applicable rules and regulations and there is no basis for the Attorney General's and the NYSDEC's allegations. NYSEG furnished documents pursuant to the Attorney General's and the NYSDEC's requests. It is reviewing its files for documents relating to the EPA's request and for additional documents relating to the Attorney General's and the NYSDEC's requests. NYSEG believes that any liability related to this matter will be the responsibility of AES in accordance with the asset purchase agreement.

The Pennsylvania Department of Environmental Protection has requested records regarding the Homer City plant in which NYSEG formerly had a 50% interest.

The company's Annual Meeting of Stockholders was held on May 19, 2000. The following matters were voted on:

(a) The election of four directors:

(b) Approval of the 2000 Stock Option Plan:

(a)  Exhibits - See Exhibit Index.

(b)  Reports on Form 8-K

      No reports on Form 8-K were filed during the quarter.

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

Date:  August 11, 2000

(a) (1)  The following exhibits are delivered with this report:

(a) (2)  The following exhibit is incorporated herein by reference:

_____________________________
(A)  Management contract or compensatory plan or arrangement.