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SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One) | ||
[X] |
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
|
For the quarterly period ended June 30, 2000, or | ||
[ ] |
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 1-10070
MCN ENERGY GROUP INC.
(Exact name of registrant as specified in its charter)
Michigan
500 Griswold Street, Detroit, Michigan
48226
Registrants telephone number, including area code 313-256-5500
No Changes
(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 [ ]
Number of shares outstanding of each of the registrants classes of common stock, as of August 11, 2000:
Common Stock, par value $.01 per share: 90,212,588
INDEX TO FORM 10-Q
For Quarter Ended June 30, 2000
Page | ||||
Number | ||||
COVER | i | |||
INDEX | ii | |||
PART I FINANCIAL INFORMATION | ||||
Item 1. Financial Statements | 22 | |||
Item 2. Managements Discussion and Analysis of Financial Condition and Results of Operations | 1 | |||
PART II OTHER INFORMATION | ||||
Item 5. Other Information | 46 | |||
Item 6. Exhibits and Reports on Form 8-K | 46 | |||
SIGNATURE | 47 |
ii
RESULTS OF OPERATIONS
Results reflect Energy Marketing losses, asset sales and reduced contributions from MichCons gas sales program MCNs earnings for the 2000 second quarter were $22.2 million or $.25 per diluted share compared with losses of $78.7 million or $.94 per share for the 1999 second quarter. Earnings for the 2000 six-month period were $91.7 million or $1.03 per diluted share compared to earnings of $10.2 million or $.12 per diluted share for the same 1999 period. Earnings for the 2000 twelve-month period were $62.5 million or $.72 per diluted share compared to losses of $149.0 million or $1.86 per share in the corresponding 1999 period. As subsequently discussed, the comparability of earnings was affected by the impact of several unusual items, merger costs and an accounting change for start-up costs. Also affecting comparability was the implementation of mark-to-market accounting for storage-related trading activities, in combination with a change in accounting for inventory (Notes 3 and 4).
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
(in Millions, Except Per Share Amounts) | |||||||||||||||||||||||||
Net Income (Loss) | |||||||||||||||||||||||||
Diversified Energy: | |||||||||||||||||||||||||
Before unusual items and merger costs | $ | (25.5 | ) | $ | (3.2 | ) | $ | (31.0 | ) | $ | 2.3 | $ | (55.9 | ) | $ | (15.7 | ) | ||||||||
Unusual items (Note 5) | 45.8 | (81.8 | ) | 54.1 | (79.8 | ) | 42.9 | (227.4 | ) | ||||||||||||||||
Merger costs (Note 2) | (.9 | ) | | (.9 | ) | | (6.8 | ) | | ||||||||||||||||
19.4 | (85.0 | ) | 22.2 | (77.5 | ) | (19.8 | ) | (243.1 | ) | ||||||||||||||||
Gas Distribution: | |||||||||||||||||||||||||
Before unusual items and merger costs | 3.5 | 6.3 | 70.4 | 90.6 | 100.0 | 113.7 | |||||||||||||||||||
Unusual items (Note 5f) | | | | | | (16.7 | ) | ||||||||||||||||||
Merger costs (Note 2) | (.7 | ) | | (.9 | ) | | (17.7 | ) | | ||||||||||||||||
2.8 | 6.3 | 69.5 | 90.6 | 82.3 | 97.0 | ||||||||||||||||||||
Total Before Accounting Change: | |||||||||||||||||||||||||
Before unusual items and merger costs | (22.0 | ) | 3.1 | 39.4 | 92.9 | 44.1 | 98.0 | ||||||||||||||||||
Unusual items (Note 5) | 45.8 | (81.8 | ) | 54.1 | (79.8 | ) | 42.9 | (244.1 | ) | ||||||||||||||||
Merger costs (Note 2) | (1.6 | ) | | (1.8 | ) | | (24.5 | ) | | ||||||||||||||||
22.2 | (78.7 | ) | 91.7 | 13.1 | 62.5 | (146.1 | ) | ||||||||||||||||||
Accounting Change for Start-up Costs (Note 7) | | | | (2.9 | ) | | (2.9 | ) | |||||||||||||||||
$ | 22.2 | $ | (78.7 | ) | $ | 91.7 | $ | 10.2 | $ | 62.5 | $ | (149.0 | ) | ||||||||||||
Diluted Earnings (Loss) Per Share | |||||||||||||||||||||||||
Diversified Energy: | |||||||||||||||||||||||||
Before unusual items and merger costs | $ | (.29 | ) | $ | (.04 | ) | $ | (.31 | ) | $ | .03 | $ | (.64 | ) | $ | (.20 | ) | ||||||||
Unusual items (Note 5) | .52 | (.98 | ) | .59 | (.97 | ) | .49 | (2.83 | ) | ||||||||||||||||
Merger costs (Note 2) | (.01 | ) | | (.01 | ) | | (.08 | ) | | ||||||||||||||||
.22 | (1.02 | ) | .27 | (.94 | ) | (.23 | ) | (3.03 | ) | ||||||||||||||||
Gas Distribution: | |||||||||||||||||||||||||
Before unusual items and merger costs | .04 | .08 | .77 | 1.10 | 1.15 | 1.42 | |||||||||||||||||||
Unusual items (Note 5f) | | | | | | (.21 | ) | ||||||||||||||||||
Merger costs (Note 2) | (.01 | ) | | (.01 | ) | | (.20 | ) | | ||||||||||||||||
.03 | .08 | .76 | 1.10 | .95 | 1.21 | ||||||||||||||||||||
Total Before Accounting Change: | |||||||||||||||||||||||||
Before unusual items and merger costs | (.25 | ) | .04 | .46 | 1.13 | .51 | 1.22 | ||||||||||||||||||
Unusual items (Note 5) | .52 | (.98 | ) | .59 | (.97 | ) | .49 | (3.04 | ) | ||||||||||||||||
Merger costs (Note 2) | (.02 | ) | | (.02 | ) | | (.28 | ) | | ||||||||||||||||
.25 | (.94 | ) | 1.03 | .16 | .72 | (1.82 | ) | ||||||||||||||||||
Accounting Change for Start-up Costs (Note 7) | | | | (.04 | ) | | (.04 | ) | |||||||||||||||||
$ | .25 | $ | (.94 | ) | $ | 1.03 | $ | .12 | $ | .72 | $ | (1.86 | ) | ||||||||||||
1
Excluding the unusual items, merger costs and the accounting change for start-up costs, MCNs earnings decreased $25.1 million or $.29 per diluted share in the 2000 quarter, $53.5 million or $.67 per diluted share in the 2000 six-month period and $53.9 million or $.71 per diluted share in the 2000 twelve-month period, as compared to the corresponding 1999 periods. The earnings comparisons reflect losses within the Diversified Energy group as well as reduced contributions from the Gas Distribution segment.
Inventory accounting change As described in Note 3 to the Consolidated Financial Statements included herein, in the 2000 quarter, MCN changed its method of accounting for inventory held by its Energy Marketing segment. The consolidated financial statements of prior periods have been restated to apply the new inventory accounting method retroactively. The effect of the accounting change increased earnings as follows.
Quarter | 6 Months | 12 Months | ||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | |||||||||||||||||||
(in Millions, Except Per Share Amounts) | ||||||||||||||||||||||||
Net Income | $ | 26.6 | $ | 7.6 | $ | 37.2 | $ | 10.9 | $ | 38.2 | $ | 4.4 | ||||||||||||
Diluted Earnings Per Share | $ | .30 | $ | .09 | $ | .40 | $ | .13 | $ | .44 | $ | .05 | ||||||||||||
Pending merger MCN and DTE Energy Company (DTE) signed a definitive merger agreement dated October 4, 1999 under which DTE will acquire all outstanding shares of MCN common stock. The boards of directors and shareholders of both companies have approved the proposed merger. The transaction is subject to regulatory approvals and other customary merger conditions. Both companies continue their discussions with the Federal Trade Commission (FTC) in connection with its review of the proposed merger. Because of the length of the FTC review, it appears unlikely that the transaction will be completed before the fourth quarter of 2000. MCN recorded legal, accounting, employee benefit and other expenses associated with the merger which had the effect of reducing earnings by $1.6 million for the 2000 quarter, $1.8 million for the 2000 six-month period and $24.5 million for the 2000 twelve-month period. MCN will incur additional merger-related costs during 2000.
Strategic direction MCNs objective is to achieve competitive long-term returns for its shareholders. In 1999, MCN significantly revised its strategic direction that now includes: focusing on the Midwest-to-Northeast region; emphasizing operational efficiencies and growth through the integration of existing businesses; and reducing capital investment levels to approximately $150 million to $350 million annually.
To achieve the operating efficiencies expected from the new strategic direction, MCN is reorganizing into the following business segments: Gas Distribution; Midstream & Supply; Energy Marketing; Power; and Energy Holdings. Although MCN intended to begin reporting its operating results based on the new segments in 2000, the new reporting may be delayed to 2001.
Gas Distribution is responsible for MCNs regulated operations that serve more than 1.2 million customers in Michigan.
Midstream & Supply develops and manages MCNs gas producing, gathering, processing, storage and transmission facilities within the Midwest-to-Northeast target region. It also integrates all of MCNs gas-supply functions, including purchasing the commodity itself and aggregating the transportation and storage capacity required to deliver gas to the Gas Distribution, Energy Marketing and Power segments.
2
Energy Marketing consists of MCNs non-regulated marketing activities as well as trading activities. The marketing activities primarily relate to industrial and commercial customers, both inside and outside the Gas Distribution segments service areas. The segment also provides full-service energy solutions to business customers. Trading activities are utilized to optimize the value of storage assets.
Power develops and manages independent electric power projects that produce electricity and other useful forms of thermal energy, such as steam.
Energy Holdings manages and seeks to maximize the value of existing ventures outside MCNs target region. It consists primarily of gas gathering and processing investments in major U.S. producing basins.
Unusual items As discussed in MCNs 1999 Annual Report on Form 10-K and Note 5 to the Consolidated Financial Statements included herein, MCN recorded several unusual items in the 2000 and 1999 periods consisting of gains and losses on asset sales, property write-downs, investment and contract losses, and restructuring charges. The unusual items increased earnings in the 2000 periods, and reduced earnings in the 1999 periods.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
(in Millions, Except Per Share Amounts) | |||||||||||||||||||||||||
Unusual Items (Net of Taxes) | |||||||||||||||||||||||||
Diversified Energy | |||||||||||||||||||||||||
Pipelines & Processing (Note 5a) | $ | 15.7 | $ | | $ | 17.9 | $ | | $ | 17.9 | $ | (89.5 | ) | ||||||||||||
Electric Power (Note 5b) | 28.0 | | 30.3 | | 27.1 | (1.6 | ) | ||||||||||||||||||
Energy Marketing (Note 5c) | | | | | (1.6 | ) | | ||||||||||||||||||
Exploration & Production (Note 5d) | 2.1 | (81.8 | ) | 5.9 | (79.8 | ) | (.5 | ) | (129.6 | ) | |||||||||||||||
Corporate & Other (Note 5e) | | | | | | (6.7 | ) | ||||||||||||||||||
45.8 | (81.8 | ) | 54.1 | (79.8 | ) | 42.9 | (227.4 | ) | |||||||||||||||||
Gas Distribution (Note 5f) | | | | | | (16.7 | ) | ||||||||||||||||||
$ | 45.8 | $ | (81.8 | ) | $ | 54.1 | $ | (79.8 | ) | $ | 42.9 | $ | (244.1 | ) | |||||||||||
Diluted Earnings (Loss) Per Share | $ | .52 | $ | (.98 | ) | $ | .59 | $ | (.97 | ) | $ | .49 | $ | (3.04 | ) | ||||||||||
Diversified Energy
Results reflect Energy Marketing losses and asset sales The Diversified Energy groups earnings were $19.4 million and $22.2 million for the 2000 quarter and six-month period, respectively, compared to losses of $85.0 million and $77.5 million for the same 1999 periods. Diversified Energy had losses of $19.8 million in the 2000 twelve-month period compared to losses of $243.1 million in the corresponding 1999 period. The comparability of results was impacted by several unusual items and merger costs, as previously discussed. Excluding the unusual items and merger costs, Diversified Energys earnings declined by $22.3 million, $33.3 million and $40.2 million in the 2000 quarter, six- and twelve-month periods, respectively. The results for all three 2000 periods reflect losses of the Energy Marketing segment and reduced earnings attributable to the sale of properties and joint
3
venture interests in the Exploration & Production (E&P), Pipelines & Processing and Electric Power segments.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
(in Millions) | |||||||||||||||||||||||||
Diversified Energy Operations | |||||||||||||||||||||||||
Operating Revenues* | $ | 303.2 | $ | 309.7 | $ | 775.3 | $ | 608.3 | $ | 1,510.0 | $ | 1,086.0 | |||||||||||||
Operating Expenses* | |||||||||||||||||||||||||
Unusual items (Note 5) | (70.4 | ) | 118.3 | (83.3 | ) | 115.3 | (66.0 | ) | 342.4 | ||||||||||||||||
Merger costs (Note 2) | 1.4 | | 1.4 | | 10.5 | | |||||||||||||||||||
Other operating expenses | 326.4 | 302.3 | 795.2 | 581.8 | 1,543.8 | 1,077.6 | |||||||||||||||||||
257.4 | 420.6 | 713.3 | 697.1 | 1,488.3 | 1,420.0 | ||||||||||||||||||||
Operating Income (Loss) | 45.8 | (110.9 | ) | 62.0 | (88.8 | ) | 21.7 | (334.0 | ) | ||||||||||||||||
Equity in Earnings of Joint Ventures | 5.1 | 11.6 | 15.3 | 23.6 | 42.1 | 56.6 | |||||||||||||||||||
Other Income & (Deductions)* | |||||||||||||||||||||||||
Interest income | 1.1 | 1.5 | 3.2 | 2.0 | 5.4 | 2.8 | |||||||||||||||||||
Interest expense | (13.0 | ) | (15.4 | ) | (28.4 | ) | (32.2 | ) | (59.6 | ) | (64.8 | ) | |||||||||||||
Dividends on preferred securities of subsidiaries | (7.5 | ) | (10.4 | ) | (16.1 | ) | (20.7 | ) | (35.5 | ) | (38.1 | ) | |||||||||||||
Investment losses (Note 5d) | | (7.5 | ) | | (7.5 | ) | | (7.5 | ) | ||||||||||||||||
Other | (1.6 | ) | 1.3 | (2.4 | ) | 4.6 | .6 | 4.3 | |||||||||||||||||
(21.0 | ) | (30.5 | ) | (43.7 | ) | (53.8 | ) | (89.1 | ) | (103.3 | ) | ||||||||||||||
Income (Loss) Before Income Taxes | 29.9 | (129.8 | ) | 33.6 | (119.0 | ) | (25.3 | ) | (380.7 | ) | |||||||||||||||
Income Tax Provision (Benefit) | 10.5 | (44.8 | ) | 11.4 | (41.5 | ) | (5.5 | ) | (137.6 | ) | |||||||||||||||
Net Income (Loss) | |||||||||||||||||||||||||
Before unusual items | (25.5 | ) | (3.2 | ) | (31.0 | ) | 2.3 | (55.9 | ) | (15.7 | ) | ||||||||||||||
Unusual items and merger costs (Notes 2 and 5) | 44.9 | (81.8 | ) | 53.2 | (79.8 | ) | 36.1 | (227.4 | ) | ||||||||||||||||
$ | 19.4 | $ | (85.0 | ) | $ | 22.2 | $ | (77.5 | ) | $ | (19.8 | ) | $ | (243.1 | ) | ||||||||||
* | Includes intercompany transactions |
Operating and Joint Venture Income
4
month periods include increased Pipelines & Processing earnings and a decline in earnings from the E&P segment.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
(in Millions) | |||||||||||||||||||||||||
Operating and Joint Venture Income (Loss) | |||||||||||||||||||||||||
Before Unusual Items: | |||||||||||||||||||||||||
Pipelines & Processing | $ | 3.9 | $ | 4.6 | $ | 9.7 | $ | 9.6 | $ | 19.3 | $ | 15.4 | |||||||||||||
Electric Power | .7 | 3.9 | 2.5 | 11.4 | 14.1 | 25.0 | |||||||||||||||||||
Energy Marketing | (24.4 | ) | 9.4 | (20.1 | ) | 19.7 | (32.8 | ) | 5.8 | ||||||||||||||||
Exploration & Production | 1.8 | .2 | 4.5 | 8.2 | 10.9 | 20.3 | |||||||||||||||||||
Corporate & Other | (.1 | ) | .9 | (1.2 | ) | 1.2 | (3.2 | ) | (1.5 | ) | |||||||||||||||
(18.1 | ) | 19.0 | (4.6 | ) | 50.1 | 8.3 | 65.0 | ||||||||||||||||||
Unusual Items and Merger Costs (Notes 2 & 5) | 69.0 | (118.3 | ) | 81.9 | (115.3 | ) | 55.5 | (342.4 | ) | ||||||||||||||||
$ | 50.9 | $ | (99.3 | ) | $ | 77.3 | $ | (65.2 | ) | $ | 63.8 | $ | (277.4 | ) | |||||||||||
Pipelines & Processing operating and joint venture results, excluding unusual items, decreased $.7 million in the 2000 quarter, and increased $.1 million and $3.9 million in the 2000 six- and twelve-month periods, respectively. Results for all three 2000 periods were unfavorably affected by the sale of interests in pipeline projects that were located in areas outside MCNs target region. The 2000 periods also include increased losses from Pipelines & Processings interest in an asphalt manufacturing plant as well as reduced contributions from certain joint ventures that had fixed returns. The asphalt facility was designed to produce annually up to 100,000 tons of high-quality asphalt. The plant is experiencing technical difficulties in producing economical quantities of asphalt and, as a result, is encountering operating losses. MCN is aggressively working to resolve the technical issues. Pipelines & Processing recorded earnings in the 1999 periods from certain joint ventures where its allocated income was based on its share of the ventures earnings but not less than a predetermined fixed amount. Joint venture income from these investments in the 1999 periods was based on the fixed amounts. Under the joint venture agreements, the fixed amounts were lowered or eliminated in 2000.
Pipelines & Processings improved operating and joint venture income for the 2000 six- and twelve-month periods reflects contributions from new and expanded gas pipeline, gathering and processing ventures. Gas processed to remove natural gas liquids (NGLs) increased .8 billion cubic feet (Bcf) and 19.7 Bcf in the 2000 six- and twelve-month periods, respectively. In addition to the higher volumes, the increased earnings are attributable to improved processing margins. The 2000 six- and twelve-month periods also reflect improved results from MCNs 25%-owned methanol production venture resulting from higher methanol prices and margins as well as an increase in methanol volumes produced. Pipelines & Processings average methanol sales prices increased 33% in the 2000 six-month period and 25% in the 2000 twelve-month period. Methanol production rose
5
8.9 million and 11.3 million gallons for the current six- and twelve-month periods, respectively, primarily due to the shutdown of the methanol plant for scheduled maintenance in March 1999.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
Pipelines & Processing Statistics* | |||||||||||||||||||||||||
Methanol Produced (Million Gallons) | 16.7 | 16.8 | 33.8 | 24.9 | 66.3 | 55.0 | |||||||||||||||||||
Transportation (Bcf) | 28.5 | 53.0 | 72.0 | 101.1 | 179.5 | 192.4 | |||||||||||||||||||
Gas Processed (Bcf): | |||||||||||||||||||||||||
Carbon dioxide treatment | 13.7 | 12.9 | 26.5 | 25.8 | 52.6 | 51.1 | |||||||||||||||||||
Natural gas liquids removal | 14.8 | 22.6 | 32.3 | 31.5 | 73.8 | 54.1 | |||||||||||||||||||
28.5 | 35.5 | 58.8 | 57.3 | 126.4 | 105.2 | ||||||||||||||||||||
* | Includes MCNs share of joint ventures |
Electric Power operating and joint venture results, excluding unusual items, decreased $3.2 million, $8.9 million and $10.9 million in the 2000 quarter, six- and twelve-month periods, respectively. The declines in earnings for all three 2000 periods reflect the sale of interests in a number of power projects which were sold as a condition of MCNs pending merger with DTE (Note 2). MCN sold its 23% interest in the 1,370 megawatt (MW) Midland Cogeneration Venture facility and its 33% interest in the 42 MW Carson Cogeneration facility in the 2000 first quarter. In addition, MCN sold its 50% interest in the 123 MW Michigan Power Project, its 50% interest in the 30 MW Ada Cogeneration facility and its 95% interest in the 140 MW Cobisa-Person facility in the 2000 second quarter. Also contributing to the decreases was the sale in 1999 of MCNs 40% interest in a joint venture that held minority interests in electric distribution companies and power generation facilities in India.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
(Thousands of MW hours)* | |||||||||||||||||||||||||
Electric Power | |||||||||||||||||||||||||
Electricity Sales Domestic | | 691.1 | 185.2 | 1,392.0 | 1,549.0 | 2,704.6 | |||||||||||||||||||
Electricity Sales International | | | | | | 750.7 | |||||||||||||||||||
| 691.1 | 185.2 | 1,392.0 | 1,549.0 | 3,455.3 | ||||||||||||||||||||
* | Includes MCNs share of joint ventures |
Energy Marketing operating and joint venture results, excluding unusual items, decreased $33.8 million, $39.8 million and $38.6 million in the 2000 quarter, six- and twelve-month periods, respectively. Results for all three 2000 periods were impacted by reduced gas sales margins, significantly higher reserves for potentially uncollectible accounts receivable balances, higher storage and transportation expenses, and fair value and mark-to-market accounting adjustments.
Energy Marketings gas sales margins have declined in all three 2000 periods as a result of the narrowing or reversal of seasonal and geographical price differentials. As subsequently discussed, seasonal price differentials allow Energy Marketing to profit from its ability to purchase and store gas in the summer months and sell such gas in winter months. Geographical price differentials allow Energy Marketing to purchase lower priced gas in the Midcontinent/ Gulf Coast region, and transport and sell such gas at higher prices in the Midwest and Eastern Regions. The lower price differentials have reduced the value of Energy Marketings storage and transportation assets and
6
have continued into the 2000 third quarter. The decline in gas sales margins in the 2000 second quarter and six-month period is also attributable to a 56.7 Bcf and a 10.9 Bcf decrease in gas sales and exchange gas deliveries, respectively. The decline in gas sales and exchange gas deliveries is due in part to the exiting of two marketing joint ventures during 2000.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
(Bcf)* | |||||||||||||||||||||||||
Energy Marketing | |||||||||||||||||||||||||
Gas Sales | 87.8 | 144.5 | 262.3 | 282.6 | 565.4 | 518.8 | |||||||||||||||||||
Exchange Gas Deliveries | .1 | .1 | 15.0 | 5.6 | 21.3 | 9.9 | |||||||||||||||||||
87.9 | 144.6 | 277.3 | 288.2 | 586.7 | 528.7 | ||||||||||||||||||||
* | Includes MCNs share of joint ventures |
Current natural gas prices are high when compared to historical periods. Higher prices, coupled with lower margins, have resulted in financial pressures for some of Energy Marketings customers. As a result of these financial pressures and a customer bankruptcy filing, Energy Marketing accrued $14.5 million in the 2000 quarter for potentially uncollectible accounts receivable balances.
Energys Marketings results for the 2000 periods also include higher expenses for increased natural gas storage and transportation capacity. As discussed in MCNs 1999 Annual Report on Form 10-K, Energy Marketing has marketing rights for 100% of the storage capacity of the 42 Bcf Washington 10 storage project which was placed in operation in July 1999. Additionally, Energy Marketing added new firm transportation capacity in 1999 with the completion of the 292-mile Portland Natural Gas Transmission System.
As discussed in Notes 3 and 4 to the Consolidated Financial Statements included herein, Energy Marketing began trading activities upon changing its operating strategy in the 2000 quarter to optimize the value of its storage assets. In connection with this change in strategy, Energy Marketing also changed to the Fair Value method of accounting for gas in inventory and implemented mark-to-market accounting for the related derivative financial and storage capacity contracts. The fair value accounting change and the mark-to-market adjustments had the effect of increasing Energy Marketings operating and joint venture income by $1.1 million, $12.2 million and $23.7 million for the 2000 quarter, six- and twelve-month periods, respectively, compared to the same 1999 periods.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
(in Millions, Except Per Share Amounts) | |||||||||||||||||||||||||
Energy Marketing Adjustments | |||||||||||||||||||||||||
Mark-to-Market Accounting | $ | (28.2 | ) | $ | | $ | (28.2 | ) | $ | | $ | (28.2 | ) | $ | | ||||||||||
Fair Value Accounting | 41.0 | 11.7 | 57.2 | 16.8 | 58.7 | 6.8 | |||||||||||||||||||
Pre-Tax Income | $ | 12.8 | $ | 11.7 | $ | 29.0 | $ | 16.8 | $ | 30.5 | $ | 6.8 | |||||||||||||
Net Income | $ | 8.3 | $ | 7.6 | $ | 18.8 | $ | 10.9 | $ | 19.8 | $ | 4.4 | |||||||||||||
Diluted Earnings Per Share | $ | .09 | $ | .09 | $ | .21 | $ | .13 | $ | .23 | $ | .05 | |||||||||||||
The traditional value of storage assets resulted from the ability to buy natural gas and inject it into storage fields during the spring to early fall period when gas demand and prices are usually their lowest. The gas is withdrawn from storage and sold in the late fall-to-winter period when demand and gas prices are traditionally their highest. There has been a change in the natural gas pricing
7
environment, including the narrowing or reversal of these summer-to-winter price differentials. In the 2000 quarter, Energy Marketing implemented a strategy of optimizing the value of its storage assets through financial instruments, while continuing to minimize its exposure to commodity price changes. These financial instruments and the related storage capacity contracts are considered energy trading activities under generally accepted accounting principles and are required to be marked-to-market with unrealized gains and losses recorded to earnings.
In conjunction with applying mark-to-market accounting to storage related financial instruments and capacity contracts, Energy Marketing changed its method of accounting for gas in inventory from the Last In First Out (LIFO) method to the Fair Value method. The Fair Value method allows Energy Marketing to revalue its gas in inventory each accounting period at current market prices, with unrealized gains and losses recorded to earnings. Fair Value accounting better aligns financial reporting for energy trading inventory with the way in which price risk is measured and managed as part of trading activities. Fair Value accounting for inventory, coupled with mark-to-market accounting for storage-related financial instruments and capacity contracts, is expected to remove or minimize earnings mismatches. As the value of gas in inventory increases or decreases, the value of the storage-related financial instruments is expected to move in the opposite direction and in similar amounts, thereby offsetting each other. As previously discussed, the change to Fair Value accounting required the financial statements of prior periods to be restated to apply the new accounting method retroactively.
Exploration & Production operating and joint venture income, excluding unusual items, increased $1.6 million in the 2000 quarter, and decreased $3.7 million and $9.4 million in the 2000 six- and twelve-month periods, respectively. Results for all three 2000 periods were impacted by a significant decline in overall gas production due to the sale of MCNs Western and Midcontinent/ Gulf Coast E&P properties in early and mid-1999, as well as the sale of its Appalachian properties in December 1999. Gas and oil production decreased by 10.9 Bcf equivalent (Bcfe) in the 2000 quarter, 26.7 Bcfe in the 2000 six-month period and 43.3 Bcfe in the 2000 twelve-month period.
E&P results for 2000 were also impacted by an increase in production-related expenses and an increase in the overall average gas and oil sales prices. The higher average sales prices in the 2000 quarter, coupled with significantly lower administrative and general expenses, more than offset the effects of the increased production costs and the drop in gas and oil production, resulting in the improvement in operating and joint venture income for the current quarter. The increased production expenses reflect higher severance taxes as a result of the increase in gas and oil sales prices. Additionally, the production expenses comparison reflects the sale of non-Michigan E&P properties that had lower operating costs. The increased average sales prices are due to higher industry prices for both natural gas and oil. The impact of higher natural gas and oil sales prices on
8
E&P operating and joint venture income was moderated by hedging with swap and futures agreements, as discussed in the Risk Management Strategy section that follows.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
Exploration & Production Statistics | |||||||||||||||||||||||||
Gas and Oil Production (Bcf equivalent): | |||||||||||||||||||||||||
Michigan | 6.2 | 6.9 | 11.9 | 13.9 | 25.4 | 22.7 | |||||||||||||||||||
Western, Midcontinent/ Gulf Coast & Appalachia | .5 | 10.7 | 1.4 | 26.1 | 16.7 | 62.7 | |||||||||||||||||||
6.7 | 17.6 | 13.3 | 40.0 | 42.1 | 85.4 | ||||||||||||||||||||
Production Costs (per Mcf equivalent) | $ | 1.07 | $ | .98 | $ | 1.05 | $ | .88 | $ | 1.05 | $ | .87 | |||||||||||||
Average Selling Price (per Mcf equivalent)* | $ | 2.54 | $ | 2.19 | $ | 2.60 | $ | 2.16 | $ | 2.37 | $ | 2.09 | |||||||||||||
* | The average selling prices have been adjusted for amounts received or paid under hedging contracts |
Risk management strategy MCN uses futures, options and swap contracts to manage commodity price risk on its portfolio of gas and oil supply and sales agreements. MCNs Energy Marketing business coordinates all of MCNs hedging and trading activities to ensure compliance with risk management policies that are periodically reviewed by MCNs Board of Directors. Certain hedging gains or losses related to gas and oil production are recorded by MCNs E&P operations. Gains and losses on gas and oil production-related hedging transactions that are not recorded by MCNs E&P segment are recorded by Energy Marketing.
Corporate & Other operating and joint venture results, excluding unusual items, declined $1.0 million, $2.4 million and $1.7 million for the 2000 quarter, six-and twelve-month periods, respectively. The results primarily reflect adjustments recorded in the 1999 periods that reduced or eliminated accruals for employee incentive awards that are based on MCNs operating or stock-price performance.
Other Income and Deductions
9
Income Taxes
Outlook
Gas Distribution
10
higher financing costs drove the earnings decline in the 2000 twelve-month period and contributed to the decline in the 2000 six-month period.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
Gas Distribution Operations (in Millions) | |||||||||||||||||||||||||
Operating Revenues* | |||||||||||||||||||||||||
Gas sales | $ | 136.8 | $ | 135.6 | $ | 515.5 | $ | 578.6 | $ | 861.5 | $ | 918.6 | |||||||||||||
End user transportation | 25.7 | 23.4 | 64.6 | 50.2 | 118.3 | 89.2 | |||||||||||||||||||
Intermediate transportation | 12.7 | 13.9 | 27.2 | 28.6 | 56.4 | 58.0 | |||||||||||||||||||
Other | 19.2 | 19.6 | 40.8 | 44.8 | 80.3 | 77.5 | |||||||||||||||||||
194.4 | 192.5 | 648.1 | 702.2 | 1,116.5 | 1,143.3 | ||||||||||||||||||||
Cost of Sales | 75.0 | 65.7 | 299.2 | 321.4 | 485.1 | 504.0 | |||||||||||||||||||
Gross Margin | 119.4 | 126.8 | 348.9 | 380.8 | 631.4 | 639.3 | |||||||||||||||||||
Other Operating Expenses* | |||||||||||||||||||||||||
Operation and maintenance | 60.8 | 67.7 | 127.5 | 138.2 | 267.9 | 268.9 | |||||||||||||||||||
Depreciation, depletion and amortization | 26.5 | 25.1 | 52.9 | 50.0 | 103.0 | 97.5 | |||||||||||||||||||
Property and other taxes | 13.8 | 12.9 | 33.0 | 31.5 | 47.4 | 55.9 | |||||||||||||||||||
Unusual items (Note 5f) | | | | | | 33.3 | |||||||||||||||||||
Merger costs (Note 2) | 1.0 | | 1.4 | | 27.2 | | |||||||||||||||||||
102.1 | 105.7 | 214.8 | 219.7 | 445.5 | 455.6 | ||||||||||||||||||||
Operating Income | 17.3 | 21.1 | 134.1 | 161.1 | 185.9 | 183.7 | |||||||||||||||||||
Equity in Earnings of Joint Ventures | .1 | .6 | .7 | 1.0 | 1.7 | 1.6 | |||||||||||||||||||
Other Income and (Deductions)* | |||||||||||||||||||||||||
Interest income | .6 | .8 | 1.2 | 1.8 | 1.7 | 5.5 | |||||||||||||||||||
Interest expense | (14.0 | ) | (12.7 | ) | (29.5 | ) | (26.5 | ) | (59.5 | ) | (56.0 | ) | |||||||||||||
Minority interest | (.2 | ) | (.2 | ) | (.3 | ) | (.5 | ) | (.8 | ) | 6.4 | ||||||||||||||
Other | .1 | (.3 | ) | .5 | .1 | (.7 | ) | (.7 | ) | ||||||||||||||||
(13.5 | ) | (12.4 | ) | (28.1 | ) | (25.1 | ) | (59.3 | ) | (44.8 | ) | ||||||||||||||
Income Before Income Taxes | 3.9 | 9.3 | 106.7 | 137.0 | 128.3 | 140.5 | |||||||||||||||||||
Income Taxes | 1.1 | 3.0 | 37.2 | 46.4 | 46.0 | 43.5 | |||||||||||||||||||
Net Income | |||||||||||||||||||||||||
Before unusual items and merger costs | 3.5 | 6.3 | 70.4 | 90.6 | 100.0 | 113.7 | |||||||||||||||||||
Unusual items and merger costs (Notes 2 and 5f) | (.7 | ) | | (.9 | ) | | (17.7 | ) | (16.7 | ) | |||||||||||||||
$ | 2.8 | $ | 6.3 | $ | 69.5 | $ | 90.6 | $ | 82.3 | $ | 97.0 | ||||||||||||||
* | Includes intercompany transactions |
Gross Margin
11
Gross margins for the 2000 twelve-month period include higher margins generated under MichCons gas sales program. As a result of the gas sales program beginning in January 1999, the 2000 twelve-month period includes a full years contribution, whereas the 1999 twelve-month period includes only six months of contributions.
Gross margins for all three 2000 periods were affected by the number of customers who chose to purchase their gas from other suppliers under MichCons three-year customer choice program. Year one of this program began in April 1999 with approximately 70,000 customers choosing to participate. Year two commenced in April 2000 with the number of customers participating declining to approximately 55,000. Distribution margins are retained from these customers as MichCon continues to transport and deliver the gas to the customers premises.
Gross margins for all three 2000 periods were also impacted by varying weather which was 13.3% colder in the 2000 quarter, and 5.2% and .6% warmer in the 2000 six- and twelve-month periods, respectively, compared to the same 1999 periods. Additionally, the 2000 periods reflect a provision for customer refunds (Note 8b), as well as a decline in intermediate transportation revenues. Revenues from other gas-related services declined in the 2000 quarter and six-month period and increased in the 2000 twelve-month period.
Quarter | 6 Months | 12 Months | ||||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | |||||||||||||||||||||
Effect of Weather on Gas Markets and Earnings | ||||||||||||||||||||||||||
Percent Colder (Warmer) Than Normal | (8.1 | )% | (21.4 | )% | (13.0 | )% | (7.8 | )% | (12.2 | )% | (11.6 | )% | ||||||||||||||
Increase (Decrease) From Normal in: | ||||||||||||||||||||||||||
Gas markets (Bcf) | (1.9 | ) | (5.3 | ) | (18.0 | ) | (10.4 | ) | (26.4 | ) | (25.4 | ) | ||||||||||||||
Net income (in Millions) | $ | (1.7 | ) | $ | (5.1 | ) | $ | (16.7 | ) | $ | (10.3 | ) | $ | (25.0 | ) | $ | (23.7 | ) | ||||||||
Diluted earnings per share | $ | (.02 | ) | $ | (.06 | ) | $ | (.18 | ) | $ | (.13 | ) | $ | (.29 | ) | $ | (.29 | ) | ||||||||
Gas sales and end user transportation revenues in total increased $3.5 million for the 2000 quarter, and decreased $48.7 million and $28.0 million for the 2000 six- and twelve-month periods, respectively. Revenues for the 2000 quarter reflect an increase in gas sales volumes and end user transportation deliveries due primarily to more normal weather. The 2000 six-and twelve-month periods reflect a decline in gas sales revenues due to lower sales volumes, partially offset by higher end user transportation revenues due to increased deliveries. Gas sales volumes decreased 13.6 Bcf in the 2000 six-month period and 16.0 Bcf in the 2000 twelve-month period due primarily to warmer weather and customers who chose to purchase their gas from other suppliers under MichCons customer choice program. End user transportation deliveries increased 14.7 Bcf in the 2000 six-month period and 25.6 Bcf in the 2000 twelve-month period. The improvement includes volumes associated with customers participating in the customer choice program who are reflected as end user transportation customers rather than gas sales customers. Accordingly, gas sales revenues have decreased, partially offset by an increase in end user transportation revenues, resulting in a net decrease in total operating revenues due to the gas commodity component included in gas sales rates. Partially offsetting the 2000 six- and twelve-month periods increase in end user transportation volumes attributable to the customer choice program was the impact of warmer weather.
The gas sales revenues comparison was impacted by a $2.4 million provision for customer refunds recorded in the 2000 quarter, and the end user transportation comparison was affected by the temporary shutdown of an industrial customers plant in the 1999 quarter.
12
Additionally, the gas sales revenues comparison for the twelve-month period was impacted by the cost of the gas commodity component of gas sales rates. As previously discussed, this gas commodity component was fixed under MichCons gas sales program at $2.95 per Mcf beginning in January 1999. Prior to 1999, MichCons sales rates were set to recover all of its reasonably and prudently incurred gas costs. The gas commodity component of MichCons sales increased $.12 per Mcf (4%) for the 2000 twelve-month period.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
(Bcf) | |||||||||||||||||||||||||
Gas Distribution | |||||||||||||||||||||||||
Gas Sales | 24.8 | 24.1 | 103.0 | 116.6 | 168.1 | 184.1 | |||||||||||||||||||
End User Transportation | 37.4 | 31.8 | 89.1 | 74.4 | 166.7 | 141.1 | |||||||||||||||||||
62.2 | 55.9 | 192.1 | 191.0 | 334.8 | 325.2 | ||||||||||||||||||||
Intermediate Transportation* | 111.7 | 135.0 | 294.6 | 262.4 | 564.1 | 503.1 | |||||||||||||||||||
173.9 | 190.9 | 486.7 | 453.4 | 898.9 | 828.3 | ||||||||||||||||||||
* | Includes intercompany volumes |
Intermediate transportation revenues decreased $1.2 million, $1.4 million and $1.6 million in the 2000 quarter, six- and twelve-month periods, respectively. Although revenues declined slightly, the related deliveries fluctuated significantly, decreasing 23.3 Bcf in the 2000 quarter and increasing 32.2 Bcf and 61.0 Bcf in the 2000 six- and twelve-month periods, respectively. A significant portion of the volume variations was for customers who pay a fixed fee for intermediate transportation capacity regardless of actual usage. Although volumes associated with these fixed-fee customers may vary, the related revenues are not affected. The decrease in intermediate transportation revenues is due to non fixed-fee customers shifting volumes from a higher rate to a lower rate transportation route.
Other operating revenues decreased $.4 million and $4.0 million in the 2000 quarter and six-month period, respectively, and increased $2.8 million in the 2000 twelve-month periods. Revenues in the 2000 six-month period reflect a decline in storage revenues, partially offset by an increase in late payment fees and revenues from providing appliance maintenance services. The increase in the 2000 twelve-month period is attributable to revenues from the acquisition of three heating and cooling firms in October 1998, as well as higher late payment fees and appliance maintenance revenues.
Cost of Sales
Cost of gas sales increased $9.3 million in the 2000 quarter, and decreased $22.2 million and $18.9 million in the 2000 six- and twelve-month periods, respectively. The cost of sales variations primarily reflects weather-driven gas sales volumes as well as changes in sales volumes associated with customers who have chosen to purchase gas from other suppliers under MichCons customer
13
choice program. Also impacting cost of sales was an increase in the price paid for gas purchased of $.10 per Mcf (4%) in the 2000 quarter and $.11 per Mcf (4%) in both the 2000 six- and twelve-month periods. Additionally, the comparison was impacted by the cost of sales associated with the operations of the three heating and cooling companies acquired in October 1998.
Other Operating Expenses
Partially offsetting the improvement in the 2000 twelve-month period were additional computer system support costs associated with MichCons new customer information system, higher injuries and damages costs, and higher employee incentive payments.
Depreciation and depletion increased $1.4 million, $2.9 million and $5.5 million in the 2000 quarter, six-and twelve-month periods, respectively, reflecting depreciation on higher plant balances.
Property and other taxes increased $.9 million and $1.5 million in the 2000 quarter and six-month period, respectively, and decreased $8.5 million in the 2000 twelve-month period. All three 2000 periods were impacted by taxes on higher plant balances. However, the effect of higher plant balances in the 2000 twelve-month period was more than offset by a change in the calculation of the value of personal property subject to taxation by local taxing jurisdictions. MichCon has pending tax appeals with various local taxing jurisdictions to recover excess payments made in prior years based on the revised calculation. This calculation change, coupled with the favorable impact of new valuation tables approved by the Michigan State Tax Commission (STC) in November 1999, is expected to lower Gas Distributions personal property taxes by approximately $8 million annually beginning in July 2000. Several local taxing jurisdictions have taken legal action against the State of Michigan to prevent the STC from implementing the new valuation tables (Note 12a).
Unusual items of $33.3 million in the 1999 twelve-month period reflects a $24.8 million impairment of certain gas gathering properties in northern Michigan as well as an $8.5 million write-down of an investment in a small Missouri natural-gas distribution company (Note 5f).
Merger costs of $1.0 million, $1.4 million and $27.2 million in the 2000 quarter, six- and twelve-month periods, respectively, include legal, consulting, accounting, employee benefit and other expenses associated with the pending merger between MCN and DTE Energy Company (Note 2).
Equity in Earnings of Joint Ventures
14
Other Income and Deductions
Income Taxes
Outlook
MichCon has begun, and plans to continue capitalizing on opportunities resulting from the gas industry restructuring. MichCon is currently operating under its Regulatory Reform Plan, which includes a comprehensive experimental three-year customer choice program that is designed to offer all sales customers added choices and greater price certainty. Year two of the customer choice program began April 1, 2000, and approximately 55,000 customers have chosen to purchase natural gas from suppliers other than MichCon. There are approximately 15,000 fewer customers participating in year two of the plan than in year one as a result of fewer natural gas marketers participating due to higher gas prices.
As discussed in MCNs 1999 Annual Report on Form 10-K, the Regulatory Reform Plan also suspended the GCR mechanism for customers who continue to purchase gas from MichCon, and fixed the gas commodity component of MichCons sales rates at $2.95 per Mcf. The suspension of the GCR mechanism allows MichCon to profit from its ability to purchase gas at less than $2.95 per Mcf. The plan also increases MichCons risk associated with generating margins that cover its gas costs. As part of its gas acquisition strategy, MichCon entered into fixed-price contracts at an average cost below $2.95 per Mcf for a substantial portion of its expected supply requirements in 2000 and approximately 65% of such requirements in 2001. However, margins are expected to be lower in future periods as MichCons fixed-price supplies in 2000 and 2001 are at prices higher than those paid in 1999. MichCon expects to meet its remaining gas supply requirements for 2000 and 2001 through open-market gas purchases, supplemented with gas from storage. Margins in future periods could decline further if gas prices remain at their current levels, which are high compared to historical periods. The level of margins generated from selling gas will also be affected by actual gas sales volumes, which will fluctuate as a result of changes in weather and the number of customers who ultimately choose to purchase gas from suppliers other than MichCon.
The State of Michigan is continuing its initiatives designed to give all of Michigans natural gas customers added choices and the opportunity to benefit from lower gas costs resulting from
15
competition. Although MichCon supports customer choice initiatives, management is concerned with the structure of the current three-year customer choice and gas sales programs which fixed the gas commodity component of its sales rates at $2.95 per Mcf. MichCon is unable to adjust its sales prices to levels that are responsive to changes in the marketplace. Given the current environment of high gas prices, MichCon could incur losses on incremental volumes associated with unexpected demand, such as volumes resulting from colder weather or additional gas sales customers. MichCon is exploring its options to minimize its exposure to price risk, including supplementing its fixed-price supplies with heavier reliance on withdrawals from storage and seeking regulatory or legislative reform.
Change in Accounting for Start-up Costs
CAPITAL RESOURCES AND LIQUIDITY
6 Months | |||||||||
2000 | 1999 | ||||||||
(in Millions) | |||||||||
Cash and Cash Equivalents | |||||||||
Cash Flow Provided From (Used For): | |||||||||
Operating activities | $ | 308.2 | $ | 290.9 | |||||
Financing activities | (632.7 | ) | (249.3 | ) | |||||
Investing activities | 289.3 | (38.6 | ) | ||||||
Net Increase (Decrease) in Cash and Cash Equivalents | $ | (35.2 | ) | $ | 3.0 | ||||
Operating Activities
Financing Activities
MCNs FELINE PRIDES securities matured on May 16, 2000. Each security initially represented a stock purchase contract and a preferred security. Under each stock purchase contract, MCN was obligated to sell, and the FELINE PRIDES holder was obligated to purchase between 1.4132 and 1.7241 shares of MCN common stock for $50. The number of MCN common shares purchased
16
totaled approximately 4.6 million. Each FELINE PRIDES holder had the option to use the preferred securities, treasury securities or cash to satisfy the $50 purchase commitment. Holders of approximately 99% of the FELINE PRIDES used their preferred securities to purchase MCN common shares. The remaining holders purchased their MCN shares with cash totaling $1.5 million.
MCN had a $290 million revolving credit agreement that expired in July 2000 and was not renewed. There were no amounts outstanding under the credit agreement at June 30, 2000.
Diversified Energy
MCN received approximately $411.7 million during the 2000 six-month period from the sale of assets and joint venture interests which was used to repay outstanding debt. Proceeds from additional sales are expected in 2000 and will be used to repay outstanding borrowings and for general corporate purposes.
Gas Distribution
In March 2000, MichCon repaid $12.3 million of term debt of a non-utility subsidiary that was scheduled to mature in 2006. Additionally, MichCon repaid $20 million of first mortgage bonds that matured in May 2000.
Investing Activities
17
Capital investments equaled $130.2 million in the 2000 six-month period compared to $263.8 million for the same period in 1999. The 2000 investments include significantly lower levels of investments within the Diversified Energy Group.
6 Months | |||||||||
2000 | 1999 | ||||||||
(in Millions) | |||||||||
Capital Investments | |||||||||
Consolidated Capital Expenditures: | |||||||||
Electric Power | $ | .7 | $ | 31.9 | |||||
Exploration & Production | 2.2 | 70.2 | |||||||
Gas Distribution | 50.0 | 58.4 | |||||||
Other | 4.0 | 2.4 | |||||||
56.9 | 162.9 | ||||||||
MCNs Share of Joint Venture Capital Expenditures:* | |||||||||
Pipelines & Processing | 57.2 | 51.1 | |||||||
Electric Power | 16.0 | 15.1 | |||||||
Other | .1 | .1 | |||||||
73.3 | 66.3 | ||||||||
Acquisitions | | 34.6 | |||||||
Total Capital Investments | $ | 130.2 | $ | 263.8 | |||||
* A portion of joint venture capital expenditures is financed with joint venture debt
Outlook
The proposed level of investments in future years is expected to be financed with internally generated funds, including proceeds received from the sale of non-strategic assets. MCNs actual capital requirements will depend on proceeds received from the sale of assets. It is managements opinion that MCN and its subsidiaries will have sufficient capital resources, both internal and external, to meet anticipated capital requirements.
Commodity Price Risk
Hedging Activities
18
sensitivity analysis performed for commodity price risk at June 30, 2000 as compared to December 31, 1999.
As discussed in MCNs 1999 Annual Report on Form 10-K, a sensitivity analysis calculates the change in fair values of MCNs natural gas and oil futures and swap agreements given a hypothetical 10% increase or decrease in commodity prices utilizing applicable forward commodity rates in effect at the end of the reporting period.
The results of the sensitivity analysis calculations follow:
June 30, 2000 | December 31, 1999 | |||||||||||||||
Assuming | Assuming | Assuming | Assuming | |||||||||||||
a 10% | a 10% | a 10% | a 10% | |||||||||||||
Increase in | Decrease in | Increase in | Decrease in | |||||||||||||
Commodity | Commodity | Commodity | Commodity | |||||||||||||
Prices | Prices | Prices | Prices | |||||||||||||
(in Millions) | ||||||||||||||||
Commodity Price Sensitive:* | ||||||||||||||||
Swaps: Pay fixed/receive variable | $ | 109.3 | $ | (109.3 | ) | $ | 89.8 | $ | (89.8 | ) | ||||||
Pay variable/receive fixed | $ | (90.7 | ) | $ | 90.7 | $ | (81.1 | ) | $ | 81.1 | ||||||
Futures: Longs | $ | 4.5 | $ | (4.5 | ) | $ | 5.0 | $ | (5.0 | ) | ||||||
Shorts | $ | (.1 | ) | $ | .1 | $ | (2.1 | ) | $ | 2.1 | ||||||
* | Includes only the risk related to the derivative instruments that serve as hedges and does not include the related underlying hedged item |
Trading Activities
The results of the sensitivity analysis calculations previously discussed follow:
June 30, 2000 | December 31, 1999 | |||||||||||||||
Assuming | Assuming | Assuming | Assuming | |||||||||||||
a 10% | a 10% | a 10% | a 10% | |||||||||||||
Increase in | Decrease in | Increase in | Decrease in | |||||||||||||
Commodity | Commodity | Commodity | Commodity | |||||||||||||
Prices | Prices | Prices | Prices | |||||||||||||
(in Millions) | ||||||||||||||||
Commodity Price Sensitive:** | ||||||||||||||||
Swaps: Pay fixed/receive variable | $ | 1.0 | $ | (1.0 | ) | N/A | N/A | |||||||||
Pay variable/receive fixed | $ | (8.3 | ) | $ | 8.3 | N/A | N/A | |||||||||
Futures: Longs | $ | 1.0 | $ | (1.0 | ) | N/A | N/A | |||||||||
Shorts | $ | (1.9 | ) | $ | 1.9 | N/A | N/A | |||||||||
** | Includes only the risk related to the derivative instruments and does not include the related gas in inventory and storage capacity contracts |
19
Interest Rate Risk
SFAS No. 133 requires all derivatives to be recognized in the balance sheet as either assets or liabilities measured at their fair value, and sets forth conditions in which a derivative instrument may be designated as a hedge. The Statement requires that changes in the fair value of derivatives be recognized currently in earnings unless specific hedge accounting criteria are met. Special accounting for qualifying hedges allows a derivatives gains and losses to be recorded to other comprehensive income or to offset related results on the hedged item in earnings.
MCN manages commodity price risk and interest rate risk through the use of various derivative instruments. MCN also uses derivative instruments to optimize the value of its storage assets. The effects of SFAS No. 133 on MCNs financial statements are subject to fluctuations in the market value of derivative instruments which are, in turn, affected by variations in gas and oil prices and in interest rates. Accordingly, management cannot quantify the effects of adopting SFAS No. 133 at this time.
MCN initiated a corporate-wide plan in 1998 to address the issues associated with adopting SFAS No. 133. The plan consists of: i) inventorying and categorizing derivatives; ii) assessing risk management policies and determining the effectiveness of hedging methodologies; iii) modeling the impact of hedging strategies; and iv) assessing processes and technology requirements. MCN does not expect any complications in completing the plan or having the related computer systems operational by the end of 2000.
Revenue Recognition In December 1999, the Securities and Exchange Commission (SEC) issued Staff Accounting Bulletin (SAB) No. 101, Revenue Recognition in Financial Statements. SAB No. 101 summarized certain of the SECs views in applying generally accepted accounting principles to recognizing revenues. SAB 101 will be effective for MCN in the fourth quarter of 2000. Management does not expect SAB No. 101 to have a material effect on MCNs financial statements.
20
21
June 30 | December 31 | ||||||||||||
1999 | 1999 | ||||||||||||
(Restated) | (Restated) | ||||||||||||
2000 | Note 3 | Note 3 | |||||||||||
(in Thousands) | |||||||||||||
ASSETS | |||||||||||||
Current Assets | |||||||||||||
Cash and cash equivalents, at cost (which approximates market value) | $ | 24,201 | $ | 20,076 | $ | 59,366 | |||||||
Accounts receivable, less allowance for doubtful accounts of $36,812, $15,344 and $20,720, respectively | 387,852 | 326,648 | 546,689 | ||||||||||
Accrued unbilled revenues | 18,435 | 20,516 | 100,439 | ||||||||||
Gas in inventory (Note 9) | 164,985 | 120,927 | 179,826 | ||||||||||
Property taxes assessed applicable to future periods | 39,487 | 50,595 | 62,651 | ||||||||||
Deferred income taxes | 41,570 | | 32,508 | ||||||||||
Assets from trading activities (Note 4) | 6,326 | | | ||||||||||
Other | 53,509 | 46,178 | 51,043 | ||||||||||
736,365 | 584,940 | 1,032,522 | |||||||||||
Deferred Charges and Other Assets | |||||||||||||
Deferred income taxes | | 28,457 | 14,549 | ||||||||||
Investments in debt and equity securities | 100,797 | 70,516 | 72,077 | ||||||||||
Deferred swap losses and receivables (Note 13) | 110,820 | 64,567 | 43,907 | ||||||||||
Deferred environmental costs | 28,422 | 31,174 | 31,173 | ||||||||||
Prepaid benefit costs | 184,824 | 132,805 | 156,276 | ||||||||||
Other | 102,963 | 114,501 | 108,288 | ||||||||||
527,826 | 442,020 | 426,270 | |||||||||||
Investments in and Advances to Joint Ventures | |||||||||||||
Pipelines & Processing | 538,592 | 568,921 | 575,684 | ||||||||||
Electric Power | 31,072 | 248,456 | 145,684 | ||||||||||
Energy Marketing | 23,624 | 27,299 | 21,512 | ||||||||||
Gas Distribution | 2,677 | 1,978 | 2,898 | ||||||||||
Other | 17,986 | 18,694 | 18,194 | ||||||||||
613,951 | 865,348 | 763,972 | |||||||||||
Property, Plant and Equipment | |||||||||||||
Pipelines & Processing | 48,577 | 46,902 | 46,480 | ||||||||||
Exploration & Production (Note 5d) | 564,672 | 753,357 | 573,514 | ||||||||||
Gas Distribution | 3,051,228 | 2,970,482 | 3,016,231 | ||||||||||
Other | 76,254 | 65,139 | 76,245 | ||||||||||
3,740,731 | 3,835,880 | 3,712,470 | |||||||||||
Less Accumulated depreciation and depletion | 1,758,433 | 1,685,079 | 1,697,212 | ||||||||||
1,982,298 | 2,150,801 | 2,015,258 | |||||||||||
$ | 3,860,440 | $ | 4,043,109 | $ | 4,238,022 | ||||||||
The notes to the consolidated financial statements are an integral part of this statement
22
June 30 | December 31 | ||||||||||||
1999 | 1999 | ||||||||||||
(Restated) | (Restated) | ||||||||||||
2000 | Note 3 | Note 3 | |||||||||||
(in Thousands) | |||||||||||||
LIABILITIES AND SHAREHOLDERS EQUITY | |||||||||||||
Current Liabilities | |||||||||||||
Accounts payable | $ | 347,345 | $ | 252,791 | $ | 296,139 | |||||||
Notes payable | 102,279 | 346,809 | 617,755 | ||||||||||
Current portion of long-term debt and capital lease obligations | 186,176 | 46,351 | 28,102 | ||||||||||
Gas inventory equalization (Note 9) | 43,012 | 22,773 | | ||||||||||
Federal income, property and other taxes payable | 44,726 | 43,201 | 68,500 | ||||||||||
Gas payable | 25,264 | 38,108 | 23,422 | ||||||||||
Liabilities from trading activities (Note 4) | 22,793 | | | ||||||||||
Customer deposits | 15,613 | 15,856 | 17,707 | ||||||||||
Other | 120,073 | 84,551 | 146,949 | ||||||||||
907,281 | 850,440 | 1,198,574 | |||||||||||
Deferred Credits and Other Liabilities | |||||||||||||
Deferred income taxes | 36,079 | | | ||||||||||
Unamortized investment tax credit | 27,053 | 29,082 | 28,022 | ||||||||||
Tax benefits amortizable to customers | 134,996 | 128,869 | 136,236 | ||||||||||
Deferred swap gains and payables (Note 13) | 128,311 | 62,617 | 64,962 | ||||||||||
Accrued environmental costs | 27,126 | 34,704 | 28,068 | ||||||||||
Minority interest | 1,651 | 10,529 | 11,096 | ||||||||||
Other | 102,181 | 74,857 | 91,613 | ||||||||||
457,397 | 340,658 | 359,997 | |||||||||||
Long-Term Debt, including capital lease obligations | 1,223,215 | 1,463,756 | 1,457,617 | ||||||||||
MCN-Obligated Mandatorily Redeemable Preferred Securities of Subsidiaries Holding Solely Debentures of MCN | 272,343 | 502,232 | 402,922 | ||||||||||
Commitments and Contingencies (Note 12) | |||||||||||||
Common Shareholders Equity | |||||||||||||
Common stock | 902 | 855 | 857 | ||||||||||
Additional paid-in capital | 1,093,570 | 966,956 | 960,176 | ||||||||||
Retained earnings (deficit) | (71,664 | ) | (45,995 | ) | (119,677 | ) | |||||||
Accumulated other comprehensive loss (Note 11) | (188 | ) | (13,505 | ) | (156 | ) | |||||||
Yield enhancement, contract and issuance costs | (22,416 | ) | (22,288 | ) | (22,288 | ) | |||||||
1,000,204 | 886,023 | 818,912 | |||||||||||
$ | 3,860,440 | $ | 4,043,109 | $ | 4,238,022 | ||||||||
The notes to the consolidated financial statements are an integral part of this statement
23
Three Months Ended | Six Months Ended | Twelve Months Ended | |||||||||||||||||||||||
June 30 | June 30 | June 30 | |||||||||||||||||||||||
1999 | 1999 | 1999 | |||||||||||||||||||||||
(Restated) | (Restated) | (Restated) | |||||||||||||||||||||||
2000 | Note 3 | 2000 | Note 3 | 2000 | Note 3 | ||||||||||||||||||||
(in Thousands, Except Per Share Amounts) | |||||||||||||||||||||||||
Operating Revenues | $ | 494,200 | $ | 500,470 | $ | 1,413,951 | $ | 1,302,170 | $ | 2,611,185 | $ | 2,215,164 | |||||||||||||
Operating Expenses | |||||||||||||||||||||||||
Cost of sales | 353,236 | 314,948 | 1,005,305 | 788,833 | 1,831,464 | 1,342,062 | |||||||||||||||||||
Operation and maintenance | 95,030 | 98,477 | 186,422 | 200,427 | 397,217 | 403,339 | |||||||||||||||||||
Depreciation, depletion and amortization | 34,747 | 42,162 | 68,966 | 87,337 | 146,267 | 175,580 | |||||||||||||||||||
Property and other taxes | 15,940 | 16,270 | 37,533 | 37,928 | 56,802 | 68,768 | |||||||||||||||||||
Property write-downs, contract losses and restructuring charges (Note 5) | | 52,000 | | 52,000 | 9,782 | 319,796 | |||||||||||||||||||
Gains and losses on sale of assets, net (Note 5) | (70,388 | ) | 66,333 | (83,263 | ) | 63,328 | (75,766 | ) | 55,930 | ||||||||||||||||
Merger costs (Note 2) | 2,459 | | 2,821 | | 37,677 | | |||||||||||||||||||
431,024 | 590,190 | 1,217,784 | 1,229,853 | 2,403,443 | 2,365,475 | ||||||||||||||||||||
Operating Income (Loss) | 63,176 | (89,720 | ) | 196,167 | 72,317 | 207,742 | (150,311 | ) | |||||||||||||||||
Equity in Earnings of Joint Ventures | 5,158 | 12,166 | 15,937 | 24,624 | 43,699 | 58,251 | |||||||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||||||
Interest income | 1,706 | 2,369 | 4,454 | 3,865 | 7,164 | 8,595 | |||||||||||||||||||
Interest on long-term debt | (23,123 | ) | (21,604 | ) | (46,632 | ) | (43,506 | ) | (92,557 | ) | (92,899 | ) | |||||||||||||
Other interest expense | (4,022 | ) | (6,682 | ) | (11,376 | ) | (15,317 | ) | (26,401 | ) | (28,058 | ) | |||||||||||||
Dividends on preferred securities of subsidiaries | (7,437 | ) | (10,334 | ) | (16,059 | ) | (20,669 | ) | (35,529 | ) | (38,055 | ) | |||||||||||||
Investment losses (Note 5d) | | (7,456 | ) | | (7,456 | ) | | (7,456 | ) | ||||||||||||||||
Minority interest (Note 5f) | (309 | ) | (420 | ) | (794 | ) | (739 | ) | (1,667 | ) | 6,498 | ||||||||||||||
Other | (1,388 | ) | 1,254 | (1,383 | ) | 4,904 | 496 | 3,107 | |||||||||||||||||
(34,573 | ) | (42,873 | ) | (71,790 | ) | (78,918 | ) | (148,494 | ) | (148,268 | ) | ||||||||||||||
Income (Loss) Before Income Taxes | 33,761 | (120,427 | ) | 140,314 | 18,023 | 102,947 | (240,328 | ) | |||||||||||||||||
Income Tax Provision (Benefit) | 11,582 | (41,783 | ) | 48,624 | 4,928 | 40,410 | (94,177 | ) | |||||||||||||||||
Income (Loss) Before Cumulative Effect of Accounting Change | 22,179 | (78,644 | ) | 91,690 | 13,095 | 62,537 | (146,151 | ) | |||||||||||||||||
Cumulative Effect of Accounting Change for Start-up Costs (Note 7) | | | | (2,872 | ) | | (2,872 | ) | |||||||||||||||||
Net Income (Loss) | $ | 22,179 | $ | (78,644 | ) | $ | 91,690 | $ | 10,223 | $ | 62,537 | $ | (149,023 | ) | |||||||||||
Basic Earnings (Loss) Per Share (Note 10) | |||||||||||||||||||||||||
Before cumulative effect of accounting change | $ | .25 | $ | (.94 | ) | $ | 1.06 | $ | .16 | $ | .73 | $ | (1.82 | ) | |||||||||||
Cumulative effect of accounting change for start-up costs (Note 7) | | | | (.03 | ) | | (.04 | ) | |||||||||||||||||
$ | .25 | $ | (.94 | ) | $ | 1.06 | $ | .13 | $ | .73 | $ | (1.86 | ) | ||||||||||||
Diluted Earnings (Loss) Per Share (Note 10) | |||||||||||||||||||||||||
Before cumulative effect of accounting change | $ | .25 | $ | (.94 | ) | $ | 1.03 | $ | .16 | $ | .72 | $ | (1.82 | ) | |||||||||||
Cumulative effect of accounting change for start-up costs (Note 7) | | | | (.04 | ) | | (.04 | ) | |||||||||||||||||
$ | .25 | $ | (.94 | ) | $ | 1.03 | $ | .12 | $ | .72 | $ | (1.86 | ) | ||||||||||||
Average Common Shares Outstanding | |||||||||||||||||||||||||
Basic | 87,840 | 83,413 | 86,673 | 81,424 | 86,012 | 80,242 | |||||||||||||||||||
Diluted | 88,510 | 83,413 | 90,882 | 82,514 | 86,645 | 80,242 | |||||||||||||||||||
Dividends Declared Per Share | $ | .2550 | $ | .2550 | $ | .5100 | $ | .5100 | $ | 1.0200 | $ | 1.0200 | |||||||||||||
Three Months Ended | Six Months Ended | Twelve Months Ended | ||||||||||||||||||||||
June 30 | June 30 | June 30 | ||||||||||||||||||||||
1999 | 1999 | 1999 | ||||||||||||||||||||||
(Restated) | (Restated) | (Restated) | ||||||||||||||||||||||
2000 | Note 3 | 2000 | Note 3 | 2000 | Note 3 | |||||||||||||||||||
(in Thousands) | ||||||||||||||||||||||||
Balance Beginning of Period | $ | (82,858 | ) | $ | 62,775 | $ | (120,081 | ) | $ | (2,977 | ) | $ | (45,400 | ) | $ | 190,548 | ||||||||
Add Cumulative effect on prior years of change in accounting for inventory (Note 3) | 10,973 | (8,191 | ) | 404 | (11,515 | ) | (595 | ) | (4,996 | ) | ||||||||||||||
Add Net Income (Loss) | 22,179 | (78,644 | ) | 91,690 | 10,223 | 62,537 | (149,023 | ) | ||||||||||||||||
(49,706 | ) | (24,060 | ) | (27,987 | ) | (4,269 | ) | 16,542 | 36,529 | |||||||||||||||
Deduct Cash Dividends Declared | 21,958 | 21,935 | 43,677 | 41,726 | 88,206 | 82,524 | ||||||||||||||||||
Balance End of Period | $ | (71,664 | ) | $ | (45,995 | ) | $ | (71,664 | ) | $ | (45,995 | ) | $ | (71,664 | ) | $ | (45,995 | ) | ||||||
24
Six Months Ended | ||||||||||||
June 30 | ||||||||||||
1999 | ||||||||||||
(Restated) | ||||||||||||
2000 | Note 3 | |||||||||||
(in Thousands) | ||||||||||||
Cash Flow From Operating Activities | ||||||||||||
Net income | $ | 91,690 | $ | 10,223 | ||||||||
Adjustments to reconcile net income to net cash provided from operating activities Depreciation, depletion and amortization: | ||||||||||||
Per statement of operations | 68,966 | 87,337 | ||||||||||
Charged to other accounts | 4,687 | 4,423 | ||||||||||
Unusual items, net of taxes (Note 5) | (50,690 | ) | 83,365 | |||||||||
Cumulative effect of accounting change, net of taxes (Note 7) | | 2,872 | ||||||||||
Deferred income taxes current | (9,062 | ) | 3,614 | |||||||||
Deferred income taxes and investment tax credits, net | 21,142 | 65,246 | ||||||||||
Equity in earnings of joint ventures, net of distributions | (3,864 | ) | (8,256 | ) | ||||||||
Other | (10,146 | ) | (1,118 | ) | ||||||||
Changes in assets and liabilities, exclusive of changes shown separately | 195,521 | 43,262 | ||||||||||
Net cash provided from operating activities | 308,244 | 290,968 | ||||||||||
Cash Flow From Financing Activities | ||||||||||||
Notes payable, net | (515,476 | ) | (272,042 | ) | ||||||||
Dividends paid | (43,677 | ) | (41,726 | ) | ||||||||
Issuance of common stock | 4,642 | 135,120 | ||||||||||
Reacquisition of common stock | (2,079 | ) | (783 | ) | ||||||||
Issuance of long-term debt | | 106,535 | ||||||||||
Long-term commercial paper and bank borrowings, net (Note 15) | (35,761 | ) | 92,344 | |||||||||
Retirement of long-term debt and preferred securities (Note 15) | (40,221 | ) | (268,773 | ) | ||||||||
Other | (128 | ) | | |||||||||
Net cash used for financing activities | (632,700 | ) | (249,325 | ) | ||||||||
Cash Flow From Investing Activities | ||||||||||||
Capital expenditures | (56,918 | ) | (159,880 | ) | ||||||||
Acquisitions | | (31,153 | ) | |||||||||
Investment in debt and equity securities, net | (6,936 | ) | (2,597 | ) | ||||||||
Investment in joint ventures | (63,812 | ) | (39,991 | ) | ||||||||
Sale of property and joint venture interests (Notes 5 and 6) | 411,736 | 200,705 | ||||||||||
Other | 5,221 | (5,690 | ) | |||||||||
Net cash provided from (used for) investing activities | 289,291 | (38,606 | ) | |||||||||
Net Increase (Decrease) in Cash and Cash Equivalents | (35,165 | ) | 3,037 | |||||||||
Cash and Cash Equivalents, January 1 | 59,366 | 17,039 | ||||||||||
Cash and Cash Equivalents, June 30 | $ | 24,201 | $ | 20,076 | ||||||||
Changes in Assets and Liabilities, Exclusive of Changes Shown Separately | ||||||||||||
Accounts receivable, net | $ | 39,155 | $ | 72,787 | ||||||||
Accrued unbilled revenues | 82,004 | 67,372 | ||||||||||
Gas in inventory | 14,841 | 8,051 | ||||||||||
Accrued/deferred gas cost recovery revenues, net | | (19,795 | ) | |||||||||
Prepaid/accrued benefit costs, net | (27,984 | ) | (20,422 | ) | ||||||||
Accounts payable | 51,206 | (46,758 | ) | |||||||||
Federal income, property and other taxes payable | (23,774 | ) | (35,194 | ) | ||||||||
Gas payable | 1,842 | (3,821 | ) | |||||||||
Asset/ Liability from trading activity | 16,467 | | ||||||||||
Gas inventory equalization | 43,012 | 22,967 | ||||||||||
Other current assets and liabilities, net | (10,413 | ) | 7,190 | |||||||||
Other deferred assets and liabilities, net | 9,165 | (9,115 | ) | |||||||||
$ | 195,521 | $ | 43,262 | |||||||||
Supplemental Disclosures | ||||||||||||
Cash paid during the year for: | ||||||||||||
Interest, net of amounts capitalized | $ | 63,159 | $ | 71,640 | ||||||||
Federal income taxes | $ | 4,000 | $ | 3,550 | ||||||||
Noncash investing and financing activities: | ||||||||||||
FELINE PRIDES settlement (Note 16) | $ | 130,721 | $ | | ||||||||
25
1. GENERAL
The accompanying consolidated financial statements should be read in conjunction with the MCN Energy Group Inc. (MCN) 1999 Annual Report on Form 10-K. Certain reclassifications have been made to the prior years financial statements to conform to the 2000 presentation. In the opinion of management, the unaudited information furnished herein reflects all adjustments necessary for a fair presentation of the financial statements for the periods presented.
Because of seasonal and other factors, revenues, expenses, net income and earnings per share for the interim periods should not be construed as representative of revenues, expenses, net income and earnings per share for all or any part of the balance of the current year or succeeding periods.
2. MERGER AGREEMENT WITH DTE ENERGY COMPANY
As discussed in MCNs 1999 Annual Report on Form 10-K, MCN and DTE Energy Company (DTE) signed a definitive merger agreement, dated October 4, 1999, under which DTE will acquire all outstanding shares of MCN common stock. The boards of directors and the shareholders of both companies have approved the proposed merger. The transaction is subject to regulatory approvals and other customary merger conditions. Both companies continue their discussions with the Federal Trade Commission (FTC) in connection with its review of the proposed merger. Because of the length of the FTC review, it appears unlikely that the transaction will be completed before the fourth quarter of 2000.
As a result of the pending merger, MCN has incurred merger-related costs which include legal, accounting, consulting, employee benefit and other expenses. These costs had the effect of decreasing earnings by $2,459,000 pre-tax ($1,598,000 net of taxes), $2,821,000 pre-tax ($1,834,000 net of taxes) and $37,677,000 pre-tax ($24,490,000 net of taxes) for the three-, six- and twelve-month periods ended June 30, 2000, respectively.
Furthermore, pursuant to the merger agreement, MCN sold its interest in five power projects, four of which are defined as Qualifying Facilities (QFs) under the Public Utility Regulatory Policies Act of 1978, as amended. This act limits the interest in a project that can be owned by electric utilities while maintaining the projects status as a QF. In the first quarter of 2000, MCN completed the sale of its 23% interest in the Midland Cogeneration Venture (MCV), a QF located in Michigan, and its 33 1/3% interest in the Carson Cogeneration facility, a QF located in California. In the second quarter of 2000, MCN completed the sale of its 50% interest in the Michigan Power Project, a QF located in Michigan, its 50% interest in the Ada Cogeneration facility, a QF located in Michigan, and its 95% interest in the Cobisa-Person facility, a 140 megawatt (MW) power plant under construction in New Mexico.
3. CHANGE IN ACCOUNTING FOR INVENTORY
During the second quarter of 2000, MCNs Energy Marketing segment began trading activities. Under Emerging Issues Task Force (EITF) Issue No. 98-10, Accounting for Energy Trading and Risk Management Activities, these activities are marked-to-market with unrealized gains and losses recorded to earnings (Note 4). In connection with entering into these energy trading activities, MCN changed its method of accounting for natural gas inventory held by Energy Marketing from the Last In First Out (LIFO) method to the Fair Value method.
Fair Value accounting for energy trading inventories is preferable because: (1) it better informs users of the financial statements of the companys net commodity price risk with respect to its
26
energy trading activities; (2) it better aligns financial reporting for energy trading inventory with the way in which price risk is measured and managed as part of trading activities; and (3) the company expects to continue its future involvement with trading activities.
In accordance with Accounting Principles Board Opinion No. 20, Accounting Changes, the financial statements of prior periods have been restated to apply the new inventory accounting method retroactively. The effect of the accounting change on net income for the periods ended June 30 follows:
Three Months | Six Months | Twelve Months | |||||||||||||||||||||||
Ended | Ended | Ended | |||||||||||||||||||||||
June 30, | June 30, | June 30, | |||||||||||||||||||||||
(in Thousands, Except Per | 2000 | 1999 | 2000 | 1999 | 2000 | 1999 | |||||||||||||||||||
Share Amounts) | |||||||||||||||||||||||||
Net Income (Loss) | |||||||||||||||||||||||||
LIFO method | $ | (4,445 | ) | $ | (86,240 | ) | $ | 54,497 | $ | (697 | ) | $ | 24,345 | $ | (153,424 | ) | |||||||||
Effect of accounting change | 26,624 | 7,596 | 37,193 | 10,920 | 38,192 | 4,401 | |||||||||||||||||||
Fair Value method | $ | 22,179 | $ | (78,644 | ) | $ | 91,690 | $ | 10,223 | $ | 62,537 | $ | (149,023 | ) | |||||||||||
Basic Earnings (Loss) Per Share |
|||||||||||||||||||||||||
LIFO method | $ | (.05 | ) | $ | (1.03 | ) | $ | .63 | $ | (.01 | ) | $ | .28 | $ | (1.91 | ) | |||||||||
Effect of accounting change | .30 | .09 | .43 | .14 | .45 | .05 | |||||||||||||||||||
Fair Value method | $ | .25 | $ | (0.94 | ) | $ | 1.06 | $ | .13 | $ | .73 | $ | (1.86 | ) | |||||||||||
Diluted Earnings (Loss) Per Share |
|||||||||||||||||||||||||
LIFO method | $ | (.05 | ) | $ | (1.03 | ) | $ | .63 | $ | (.01 | ) | $ | .28 | $ | (1.91 | ) | |||||||||
Effect of accounting change | .30 | .09 | .40 | .13 | .44 | .05 | |||||||||||||||||||
Fair Value method | $ | .25 | $ | (0.94 | ) | $ | 1.03 | $ | .12 | $ | .72 | $ | (1.86 | ) | |||||||||||
The balances of retained earnings for all prior periods have been adjusted for the effect of applying retroactively the new inventory accounting method.
4. TRADING ACTIVITIES
During the second quarter of 2000, MCNs Energy Marketing segment began trading activities by entering into financial transactions that better utilize its gas storage capacity and assets. Energy Marketing utilizes forward contracts, futures contracts, swap agreements, and natural gas inventories as part of its trading strategy. Financial instruments and storage capacity contracts used in connection with trading activities are marked-to-market and recorded at their fair value in the Consolidated Statement of Financial Position and are shown as Assets and Liabilities from Trading Activities. Energy Marketings gas inventory is also recorded at its fair value (Notes 3 and 9). Unrealized gains and losses from newly originated contracts, financial instruments, storage contracts and inventories are recognized in revenues in the Consolidated Statement of Operations. The net unrealized loss included in revenues from marking-to-market MCNs financial instruments and storage contracts utilized in trading activities for the three-, six-and twelve-month periods ended June 30, 2000 was $28,215,000 pre-tax ($18,340,000 net of taxes). The net unrealized gains included in revenues from marking-to-market MCNs gas inventory for the three-, six- and twelve-month periods ended June 30, 2000 was $40,960,000 pre-tax ($26,624,000 net of taxes),
27
$57,220,000 pre-tax ($37,193,000 net of taxes) and $58,756,000 pre-tax ($38,192,000 net of taxes), respectively.
5. UNUSUAL ITEMS
a. Pipelines & Processing
Gain on Sale of Joint Ventures: In May 2000, MCN recognized a $24,138,000 pre-tax ($15,689,000 net of taxes) gain from the sale of its interest in the Jonah Gas Gathering Company. | |
In March 2000, MCN recognized a $3,419,000 pre-tax ($2,222,000 net of taxes) gain from the sale of its interest in the Cardinal States Gathering Company. | |
Property Write-Downs: In the third quarter of 1998, MCN recorded a $133,782,000 pre-tax ($86,959,000 net of taxes) write-off of its coal fines project equal to the carrying value of its six plants, reflecting the likely inability to recover such costs. MCN sold four of its coal fines plants to DTE in 1999. MCN is seeking to maximize the value of its investment in the two remaining plants, but is unable to predict the outcome of such efforts. In the third quarter of 1998, MCN also recorded an impairment loss of $3,899,000 pre-tax ($2,534,000 net of taxes) relating to an acquired out-of-service pipeline in Michigan. MCN reviewed the business alternatives for this asset and determined that its development is unlikely. Accordingly, MCN recorded an impairment loss equal to the carrying value of this asset. |
b. Electric Power
Gain on Sale of Joint Ventures: In June 2000, MCN sold its interest in the Cobisa-Person facility resulting in a pre-tax gain of $1,298,000 ($844,000 net of taxes). | |
In April 2000, MCN recognized a $41,723,000 pre-tax ($27,120,000 net of taxes) gain from the sale of its interest in the Michigan Power Project and its interest in the Ada Cogeneration facility. | |
In March 2000, MCN recognized a $3,672,000 pre-tax ($2,387,000 net of taxes) gain from the sale of its interest in the Carson Cogeneration facility. | |
Property Write-Downs: In the fourth quarter of 1999, MCN exited two power projects under development that were not consistent with its new strategic direction. As a result, MCN recorded a $4,995,000 pre-tax ($3,247,000 net of taxes) write-off of capitalized costs associated with these projects. | |
Restructuring Charge: In the third quarter of 1998, MCN recorded a $2,470,000 pre-tax ($1,605,000 net of taxes) restructuring charge related to its decision to exit certain international power projects. |
c. Energy Marketing
Loss on Contracts: In the fourth quarter of 1999, MCN recognized a $2,447,000 pre-tax ($1,591,000 net of taxes) loss resulting from the termination of gas sales contracts with a joint venture. These contracts were terminated in conjunction with MCNs sale of its 49% interest in the joint venture. |
28
d. Exploration & Production
Property Write-Downs: In the second quarter of 1999, MCN recognized a $52,000,000 pre-tax ($33,800,000 net of taxes) write-down of its gas and oil properties under the full cost method of accounting, due primarily to an unfavorable revision in the timing of the production of proved gas and oil reserves as well as reduced expectations of sales proceeds on unproved acreage. | |
In the fourth quarter of 1999, MCN recorded a $2,340,000 pre-tax ($1,521,000 net of taxes) write-down relating to unproved property which is not included in the full cost pool. An impairment loss was recorded representing the amount by which the carrying value exceeded the appraised value of the property. | |
In the third quarter of 1998, MCN recognized a write-down of its gas and oil properties totaling $83,955,000 pre-tax ($54,570,000 net of taxes). The write-down was the result of MCNs capitalized exploration and production costs exceeding the full cost ceiling. | |
Losses on Sale of Properties: In the second and third quarters of 1999, MCN recognized losses from the sale of its Western and Midcontinent/ Gulf Coast E&P properties totaling $68,798,000 pre-tax ($44,719,000 net of taxes) and $5,877,000 pre-tax ($3,820,000 net of taxes), respectively. In the fourth quarter of 1999, MCN recognized losses from the sale of its Appalachian E&P properties totaling $7,314,000 pre-tax ($4,754,000 net of taxes). In the first quarter of 2000, subsequent adjustments related to these prior-period losses reduced the losses by $3,735,000 pre-tax ($2,428,000 net of taxes). | |
Gain on the Sale of Tax Credits: Gains are recorded in each period as the result of the sale of tax credits in the third quarter of 1998. The purchaser forwards payments to MCN as a result of generating gas production credits, and accordingly, MCN records the amount as a gain on the sale of the tax credits. Credits will continue to be generated through 2002. For the three-, six- and twelve-month periods ended June 30, 2000, MCN recognized gains of $3,230,000 pre-tax ($2,100,000 net of taxes), $5,278,000 pre-tax ($3,431,000 net of taxes) and $10,973,000 pre-tax ($7,132,000 net of taxes), respectively. For the three-, six- and twelve-month periods ended June 30, 1999, MCN recognized gains of $2,465,000 pre-tax ($1,602,000 net of taxes), $5,470,000 pre-tax ($3,555,000 net of taxes) and $12,868,000 pre-tax ($8,364,000 net of taxes), respectively. | |
Loss on Investment: In the second quarter of 1999, MCN recognized a $7,456,000 pre-tax ($4,846,000 net of taxes) loss from the write-down of an investment in the common stock of an E&P company. The loss was due to decline in the fair value of the securities that are not considered temporary. MCN has no carrying value in this investment after the write-down. |
e. Corporate & Other
Restructuring Charge: In the third quarter of 1998, MCN recorded a $10,390,000 pre-tax ($6,753,000 net of taxes) restructuring charge related to a corporate realignment designed to improve operating efficiencies through a more streamlined organizational structure. The realignment included cost saving initiatives expected to reduce operating expenses. As of June 30, 2000, payments of $7,932,000 have been charged against the restructuring accruals relating to severance and termination benefits and net lease costs. The remaining restructuring costs of $2,458,000 are expected to be paid through 2006. |
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f. Gas Distribution
Property Write-Downs: In the third quarter of 1998, MCN recorded a $24,800,000 pre-tax ($11,200,000 net of taxes and minority interest) write-down of certain gas gathering properties. An analysis revealed that projected cash flows from the gathering system were not sufficient to cover the systems carrying value. Therefore, an impairment loss was recorded representing the amount by which the carrying value of the system exceeded its estimated fair value. | |
Loss on Investment: In the third quarter of 1998, MCN also recorded an $8,500,000 pre-tax ($5,525,000 net of taxes) loss from the write-down of an investment in a Missouri gas distribution company. The write-down represents the amount by which the carrying value exceeded the estimated fair value of the investment. |
6. ACQUISITIONS AND DISPOSITIONS
a. Pipelines & Processing
In May 2000, MCN sold its 35% interest in the Jonah Gas Gathering Company for approximately $45,000,000. | |
In March 2000, MCN sold its 50% interest in the Cardinal States Gathering Company for approximately $60,000,000. |
b. Electric Power
Qualifying and Other Facilities: As discussed in MCNs 1999 Annual Report on Form 10-K, MCN agreed to sell its interest in five power projects, four of which are Qualifying Facilities as defined by the Public Utility Regulatory Policies Act of 1978, as amended (Note 2). | |
In June 2000, MCN sold its 95% interest in the Cobisa-Person facility, a 140 MW power plant that was under construction in New Mexico, for approximately $1,700,000. | |
In April 2000, MCN sold 50% interest in the Michigan Power Project, a 123 MW cogeneration plant located in Ludington, Michigan, and its 50% interest in the Ada Cogeneration facility, a 30 MW cogeneration plant located in Ada, Michigan, for $57,500,000. | |
In March 2000, MCN sold its 33 1/3% interest in the Carson Cogeneration facility, a 42 MW cogeneration plant located in California, for $3,000,000. | |
In January 2000, MCN sold its 23% ownership in MCV, a 1,370 MW cogeneration facility located in Michigan, for approximately $105,000,000. Under the terms of the sales agreement, if MCN does not merge with DTE, MCN may reacquire its 23% interest in MCV. |
7. ACCOUNTING FOR START-UP ACTIVITIES
As discussed in MCNs 1999 Annual Report on Form 10-K, in January 1999 MCN adopted Statement of Position (SOP) 98-5, Reporting on the Costs of Start-up Activities, issued by the Accounting Standards Executive Committee of the American Institute of Certified Public Accountants. SOP 98-5 requires start-up and organizational costs to be expensed as incurred. This change in accounting principle resulted in the write-off of start-up and organization costs capitalized as of December 31, 1998. The cumulative effect of the change was to decrease earnings by $4,418,000 pre-tax ($2,872,000 net of taxes) for the six- and twelve-month periods ended June 30, 1999.
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8. REGULATORY MATTERS
a. Regulatory Reform Plan
As discussed in MCNs 1999 Annual Report on Form 10-K, MichCon implemented its Regulatory Reform Plan in January 1999. The plan includes a three-year gas sales program under which MichCons gas sales rates include a gas commodity component that is fixed at $2.95 per thousand cubic feet (Mcf). As part of its gas acquisition strategy, MichCon has entered into fixed-price contracts at an average cost below $2.95 per Mcf for a substantial portion of its expected supply requirements in 2000 and approximately 65% of such requirements in 2001. | |
The plan also includes a comprehensive experimental three-year customer choice program, which is subject to annual caps on the level of participation. The customer choice program began in April 1999, with approximately 70,000 customers choosing to purchase natural gas from suppliers other than MichCon. Year two of the plan began in April 2000, and the number of customers participating decreased to approximately 55,000. MichCon continues to transport and deliver gas to these customers premises at prices that generate favorable margins. | |
In addition, the plan encompasses an income sharing mechanism that allows customers to share profits when actual returns on equity exceed predetermined thresholds. MichCon filed its income sharing report with the Michigan Public Service Commission (MPSC) on March 31, 2000, using the MPSC approved formula, indicating that no income sharing was required for 1999. The MPSC staff has requested a hearing on this matter. Management believes that no income sharing is required. | |
On August 4, 2000, the MPSC issued an order establishing a proceeding to obtain information regarding the experience gained from the customer choice programs of Michigan utilities. The information will be used by the MPSC to determine the future regulatory environment following the conclusion of the current regulatory reform programs. The MPSC is expected to issue an order on its findings during October 2000. |
b. Gas Cost Recovery Proceedings
The Gas Cost Recovery (GCR) process was suspended with the implementation of MichCons Regulatory Reform Plan in January 1999. In February 1999, MichCon filed its final GCR reconciliation case covering gas costs incurred during 1998 indicating an overrecovery of $18,000,000, including interest. During the first quarter of 1999, MichCon refunded the overrecovery to customers. In July 2000, the MPSC issued an order on this case indicating that an additional $3,200,000, including $740,000 of interest, had been overrecovered. In July 2000, MichCon began refunding the additional overrecovery to customers as a reduction in gas sales rates. |
c. Other Rate Matters
As discussed in MCNs Annual Report on Form 10-K, several shippers on MichCons northern Michigan gathering system filed a complaint with the MPSC requesting that the commission issue an order reducing the rate charged for Antrim gas transportation services from $.09 per Mcf to approximately $.039 to $.031 per Mcf. The complaint also included a request for refunds of approximately $21,000,000 for periods during which the rate was in effect. The |
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presiding MPSC administrative law judge found that no refunds are required. The MPSC staff has proposed a rate of $.049 per Mcf which would result in an annual revenue reduction of approximately $4,500,000. Management will vigorously defend its proposed rate of $.088 per Mcf, however, it is unable to predict the eventual outcome of this complaint. |
9. GAS IN INVENTORY
Inventory gas held by MCNs Gas Distribution segment is priced on a LIFO basis. In anticipation that interim inventory reductions will be replaced prior to year end, the cost of gas for net withdrawals from inventory is recorded at the estimated average purchase rate for the calendar year. The excess of these charges over the LIFO cost is credited to the gas inventory equalization account. During interim periods when there are net injections to inventory, the equalization account is reversed. Inventory gas held by MCNs Energy Marketing segment is recorded at fair value (Note 3).
10. EARNINGS PER SHARE COMPUTATION
MCN reports basic and diluted earnings per share (EPS). Basic EPS is computed by dividing income or loss available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted EPS assumes the issuance of potential dilutive common shares outstanding during the period and adjusts for changes in income and the repurchase of common shares that would have occurred with proceeds from the assumed issuance. For the three-and twelve-month periods ended June 30, 1999, potentially dilutive securities have been
32
excluded from the diluted EPS calculation since their inclusion would have been antidilutive. A reconciliation of both calculations follows.
Net Income | Weighted | ||||||||||||||||||||||||
(Loss) Before | Average | Earnings | |||||||||||||||||||||||
Cumulative Effect of | Common | (Loss) | |||||||||||||||||||||||
Accounting Change | Shares | Per Share | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
(in Thousands, Except Per Share Amounts) | |||||||||||||||||||||||||
Three Months Ended June 30 | |||||||||||||||||||||||||
Basic EPS | $ | 22,179 | $ | (78,644 | ) | 87,840 | 83,413 | $ | .25 | $ | (.94 | ) | |||||||||||||
Effect of Dilutive Securities FELINE PRIDES |
| | | | |||||||||||||||||||||
Stock-based compensation plans | | | 670 | | |||||||||||||||||||||
Diluted EPS | $ | 22,179 | $ | (78,644 | ) | 88,510 | 83,413 | $ | .25 | $ | (.94 | ) | |||||||||||||
Six Months Ended June 30 | |||||||||||||||||||||||||
Basic EPS | $ | 91,690 | $ | 13,095 | 86,673 | 81,424 | $ | 1.06 | $ | .16 | |||||||||||||||
Effect of Dilutive Securities FELINE PRIDES |
2,349 | | 3,433 | | |||||||||||||||||||||
Stock-based compensation plans | | | 776 | 1,090 | |||||||||||||||||||||
Diluted EPS | $ | 94,039 | $ | 13,095 | 90,882 | 82,514 | $ | 1.03 | $ | .16 | |||||||||||||||
Twelve Months Ended June 30 | |||||||||||||||||||||||||
Basic EPS | $ | 62,537 | $ | (146,151 | ) | 86,012 | 80,242 | $ | .73 | $ | (1.82 | ) | |||||||||||||
Effect of Dilutive Securities FELINE PRIDES |
| | | | |||||||||||||||||||||
Stock-based compensation plans | | | 633 | | |||||||||||||||||||||
Diluted EPS | $ | 62,537 | $ | (146,151 | ) | 86,645 | 80,242 | $ | .72 | $ | (1.82 | ) | |||||||||||||
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11. COMPREHENSIVE INCOME
MCN reports comprehensive income, which is defined as the change in common shareholders equity during a period from transactions and events from non-owner sources, including net income. Total comprehensive income for the applicable periods is as follows:
Three Months Ended | Six Months Ended | Twelve Months Ended | ||||||||||||||||||||||||
June 30, | June 30, | June 30, | ||||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | |||||||||||||||||||||
(in Thousands) | ||||||||||||||||||||||||||
Comprehensive Income (Loss) | ||||||||||||||||||||||||||
Net Income (Loss) | $ | 22,179 | $ | (78,644 | ) | $ | 91,690 | $ | 10,223 | $ | 62,537 | $ | (149,023 | ) | ||||||||||||
Other Comprehensive Income (Loss), | ||||||||||||||||||||||||||
Net of Taxes | ||||||||||||||||||||||||||
Foreign currency translation adjustment | ||||||||||||||||||||||||||
Foreign currency translation adjustment | (42 | ) | (898 | ) | (32 | ) | (616 | ) | 185 | (1,357 | ) | |||||||||||||||
Less: Reclassification for losses Recognized in net income | | | | | 13,132 | | ||||||||||||||||||||
(42 | ) | (898 | ) | (32 | ) | (616 | ) | 13,317 | (1,357 | ) | ||||||||||||||||
Unrealized loss on securities Unrealized losses during period | | (642 | ) | | (1,159 | ) | | (4,846 | ) | |||||||||||||||||
Less: Reclassification for losses Recognized in net income | | 4,846 | | 4,846 | | 4,846 | ||||||||||||||||||||
| 4,204 | | 3,687 | | | |||||||||||||||||||||
Total Other Comprehensive Income (Loss), Net of Taxes | (42 | ) | 3,306 | (32 | ) | 3,071 | 13,317 | (1,357 | ) | |||||||||||||||||
Total Comprehensive Income (Loss) | $ | 22,137 | $ | (75,338 | ) | $ | 91,658 | $ | 13,294 | $ | 75,854 | $ | (150,380 | ) | ||||||||||||
12. CONTINGENCIES
a. Personal Property Taxes
As discussed in MCNs 1999 Annual Report on Form 10-K, in 1998, MichCon began filing its personal property tax information with local taxing jurisdictions which reflected a change in the calculation of the value of personal property subject to taxation. The revised calculation excludes intangible costs from the value of personal property. A number of local taxing jurisdictions have accepted the revised calculation, and MichCon recorded lower property tax expense in 1999 and 1998 associated with the accepting taxing jurisdictions. MichCon has also filed appeals to recover excess payments made in 1996 and 1997 based on the revised calculation. MichCon has pending tax appeals with local taxing jurisdictions that have not accepted the revised calculation. | |
Additionally, MichCon and other Michigan utilities have asserted that Michigans valuation tables result in the substantial overvaluation of utility personal property. Valuation tables established by the Michigan State Tax Commission (STC) are used to estimate the reduction in value of personal property based on the propertys age. In November 1999, the STC approved new valuation tables that more accurately recognize the value of a utilitys personal property. The new tables are effective in 2000 and are being used for current year assessments |
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in most jurisdictions. However, several local taxing jurisdictions have taken legal action attempting to prevent the STC from implementing the new valuation tables and have continued to prepare assessments based on the superceded tables. The legal actions regarding the appropriateness of the new tables are currently before the Michigan Tax Tribunal (MTT) which issued an order on June 21 stating that the tables are presumed to be correct, thus assigning the burden of proving otherwise to the taxing jurisdictions. A trial is scheduled for December 2000. The legal action, along with possible additional appeals by local taxing jurisdictions, could delay expected recoveries related to the new valuation tables until 2001. | |
MichCon will seek to apply the new tables retroactively and to ultimately settle the pending tax appeals related to prior periods. This is a solution supported by the STC in the past. MCNs future results of operations could be significantly affected if the valuation tables are not upheld in court or MichCon is unsuccessful in its appeals. |
b. Legal and Administrative Proceedings
MCN is involved in certain legal and administrative proceedings before various courts and governmental agencies concerning claims arising in the ordinary course of business. Management cannot predict the final disposition of such proceedings, but believes that adequate provision has been made for probable losses. It is managements belief, after discussion with legal counsel, that the ultimate resolution of those proceedings still pending will not have a material adverse effect on MCNs financial statements. |
13. COMMODITY SWAP AGREEMENTS
MCNs Diversified Energy group manages commodity price risk through the use of various derivative instruments. The following assets and liabilities related to the use of gas and oil swap agreements are reflected in the Consolidated Statement of Financial Position:
June 30 | December 31 | ||||||||||||
2000 | 1999 | 1999 | |||||||||||
(in Thousands) | |||||||||||||
Deferred Swap Losses and Receivables | |||||||||||||
Unrealized losses | $ | 47,992 | $ | 42,556 | $ | 13,884 | |||||||
Receivables | 127,774 | 31,156 | 40,089 | ||||||||||
175,766 | 73,712 | 53,973 | |||||||||||
Less current portion | 64,946 | 9,145 | 10,066 | ||||||||||
$ | 110,820 | $ | 64,567 | $ | 43,907 | ||||||||
Deferred Swap Gains and Payables | |||||||||||||
Unrealized gains | $ | 61,973 | $ | 24,822 | $ | 29,596 | |||||||
Payables | 131,277 | 51,720 | 48,066 | ||||||||||
193,250 | 76,542 | 77,662 | |||||||||||
Less current portion | 64,939 | 13,925 | 12,700 | ||||||||||
$ | 128,311 | $ | 62,617 | $ | 64,962 | ||||||||
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14. SEGMENT INFORMATION
MCN is organized into two business groups, Diversified Energy and Gas Distribution. The groups operate five major business segments as set forth in the following table:
Three Months Ended | Six Months Ended | Twelve Months Ended | |||||||||||||||||||||||
June 30, | June 30, | June 30, | |||||||||||||||||||||||
2000 | 1999 | 2000 | 1999 | 2000 | 1999 | ||||||||||||||||||||
(in Thousands) | |||||||||||||||||||||||||
Revenues From Unaffiliated Customers: | |||||||||||||||||||||||||
Pipelines & Processing | $ | 8,648 | $ | 5,426 | $ | 15,013 | $ | 11,331 | $ | 28,474 | $ | 23,749 | |||||||||||||
Electric Power | 16,454 | 12,980 | 30,357 | 25,123 | 57,440 | 50,008 | |||||||||||||||||||
Energy Marketing | 274,096 | 277,263 | 719,175 | 524,989 | 1,411,231 | 874,461 | |||||||||||||||||||
Exploration & Production | 3,124 | 12,961 | 7,740 | 41,875 | 9,236 | 128,928 | |||||||||||||||||||
Gas Distribution | 191,878 | 191,840 | 641,666 | 698,852 | 1,104,804 | 1,138,018 | |||||||||||||||||||
494,200 | 500,470 | 1,413,951 | 1,302,170 | 2,611,185 | 2,215,164 | ||||||||||||||||||||
Revenues From Affiliated Customers: | |||||||||||||||||||||||||
Pipelines & Processing | 62 | 928 | 238 | 1,102 | 1,385 | 1,212 | |||||||||||||||||||
Energy Marketing | 23,408 | 13,441 | 47,081 | 31,525 | 84,349 | 104,992 | |||||||||||||||||||
Exploration & Production | 13,965 | 24,958 | 27,110 | 45,544 | 91,285 | 56,879 | |||||||||||||||||||
Gas Distribution | 2,618 | 666 | 6,483 | 3,334 | 11,759 | 5,259 | |||||||||||||||||||
40,053 | 39,993 | 80,912 | 81,505 | 188,778 | 168,342 | ||||||||||||||||||||
Eliminations | (40,053 | ) | (39,993 | ) | (80,912 | ) | (81,505 | ) | (188,778 | ) | (168,342 | ) | |||||||||||||
Consolidated Operating Revenues | $ | 494,200 | $ | 500,470 | $ | 1,413,951 | $ | 1,302,170 | $ | 2,611,185 | $ | 2,215,164 | |||||||||||||
Net Income (Loss) | |||||||||||||||||||||||||
Pipelines & Processing | $ | 16,080 | $ | 1,782 | $ | 18,800 | $ | 3,457 | $ | 19,866 | $ | (85,485 | ) | ||||||||||||
Electric Power | 28,065 | 2,970 | 32,506 | 7,371 | 36,593 | 14,913 | |||||||||||||||||||
Energy Marketing | (16,776 | ) | 4,854 | (15,142 | ) | 10,533 | (28,387 | ) | 133 | ||||||||||||||||
Exploration & Production | 1,055 | (79,708 | ) | 4,229 | (79,708 | ) | (3,226 | ) | (125,668 | ) | |||||||||||||||
Gas Distribution | 2,833 | 6,340 | 69,489 | 90,633 | 82,299 | 96,997 | |||||||||||||||||||
Corporate & Other | (9,078 | ) | (14,882 | ) | (18,192 | ) | (19,191 | ) | (44,608 | ) | (47,041 | ) | |||||||||||||
22,179 | (78,644 | ) | 91,690 | 13,095 | 62,537 | (146,151 | ) | ||||||||||||||||||
Cumulative effect of accounting change | | | | (2,872 | ) | | (2,872 | ) | |||||||||||||||||
Consolidated Net Income (Loss) | $ | 22,179 | $ | (78,644 | ) | $ | 91,690 | $ | 10,223 | $ | 62,537 | $ | (149,023 | ) | |||||||||||
15. CREDIT FACILITIES AND LONG-TERM BORROWINGS
MCN Energy Enterprises Inc. (MCNEE) and MichCon maintain credit lines that allow for borrowings under 364-day revolving credit facilities and three-year facilities. The 364-day revolving credit facilities were renewed in July 2000 and were increased from $350,000,000 up to $500,000,000. The three-year facilities total $350,000,000 and expire in July 2001. These credit lines support commercial paper programs.
In March 2000, MichCon repaid $12,320,000 of a non-utility subsidiarys term debt that was scheduled to mature in 2006.
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16. FELINE PRIDES
The FELINE PRIDES securities matured on May 16, 2000. Each security initially represented a stock purchase contract and a preferred security. Under each stock purchase contract, MCN was obligated to sell, and the FELINE PRIDES holder was obligated to purchase between 1.4132 and 1.7241 shares of MCN common stock for $50. The FELINE PRIDES holders put $130,721,000 of preferred securities to satisfy the stock purchase commitment. MCN also received $1,529,000 of cash from FELINE PRIDES holders who chose to retain the 7.25% preferred securities that mature on May 16, 2002. MCN issued 4,557,000 shares of common stock in connection with the maturity of the FELINE PRIDES.
17. CONSOLIDATING FINANCIAL STATEMENTS
Debt securities issued by MCNEE are subject to a support agreement between MCN and MCNEE, under which MCN has committed to make payments of interest and principal on MCNEEs securities in the event of failure to pay by MCNEE. Under the terms of the support agreement, the assets of MCN, other than MichCon, and any cash dividends paid to MCN by any of its subsidiaries are available as recourse to holders of MCNEEs securities. The carrying value of MCNs assets on an unconsolidated basis, which primarily consists of investments in subsidiaries other than MichCon, is $508,959,000 at June 30, 2000.
The following MCN consolidating financial statements are presented and include separately MCNEE, MichCon and MCN and other subsidiaries. MCN has determined that separate financial statements and other disclosures concerning MCNEE are not material to investors. The other MCN subsidiaries represent Citizens Gas Fuel Company, MCN Michigan Limited Partnership, MCN Financing I, MCN Financing II, MCN Financing III, MCN Financing VI, and MichCon Enterprises, Inc.
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CONSOLIDATING STATEMENT OF FINANCIAL POSITION
MCN | Eliminations | |||||||||||||||||||||
and Other | and | Consolidated | ||||||||||||||||||||
Subsidiaries | MCNEE | MichCon | Reclasses | Total | ||||||||||||||||||
June 30, 2000 | ||||||||||||||||||||||
(in Thousands) | ||||||||||||||||||||||
ASSETS | ||||||||||||||||||||||
Current Assets | ||||||||||||||||||||||
Cash and cash equivalents, at cost | $ | | $ | 21,212 | $ | 3,039 | $ | (50 | ) | $ | 24,201 | |||||||||||
Accounts receivable | 17,371 | 260,476 | 160,716 | (13,899 | ) | 424,664 | ||||||||||||||||
Less Allowance for doubtful accounts | 173 | 17,378 | 19,261 | | 36,812 | |||||||||||||||||
Accounts receivable, net | 17,198 | 243,098 | 141,455 | (13,899 | ) | 387,852 | ||||||||||||||||
Accrued unbilled revenues | 191 | | 18,244 | | 18,435 | |||||||||||||||||
Gas in inventory | | 112,189 | 52,796 | | 164,985 | |||||||||||||||||
Property taxes assessed applicable to future periods | 142 | 885 | 38,460 | | 39,487 | |||||||||||||||||
Deferred income taxes | (345 | ) | 44,310 | | (2,395 | ) | 41,570 | |||||||||||||||
Assets from trading activities | | 6,326 | | | 6,326 | |||||||||||||||||
Other | 10,248 | 41,532 | 36,422 | (34,693 | ) | 53,509 | ||||||||||||||||
27,434 | 469,552 | 290,416 | (51,037 | ) | 736,365 | |||||||||||||||||
Deferred Charges and Other Assets | ||||||||||||||||||||||
Deferred income taxes | 95 | 87,347 | | (87,442 | ) | | ||||||||||||||||
Investments in debt and equity securities | | 28,026 | 68,162 | 4,609 | 100,797 | |||||||||||||||||
Deferred swap losses and receivables | | 110,820 | | | 110,820 | |||||||||||||||||
Deferred environmental costs | 2,253 | | 26,169 | | 28,422 | |||||||||||||||||
Prepaid benefit costs | 4,505 | | 184,835 | (4,516 | ) | 184,824 | ||||||||||||||||
Other | 3,039 | 28,755 | 63,678 | 7,491 | 102,963 | |||||||||||||||||
9,892 | 254,948 | 342,844 | (79,858 | ) | 527,826 | |||||||||||||||||
Investments in and Advances to Joint Ventures and Subsidiaries | 1,232,847 | 591,497 | 19,777 | (1,230,170 | ) | 613,951 | ||||||||||||||||
Property, Plant and Equipment, at cost | 44,487 | 673,280 | 3,022,964 | | 3,740,731 | |||||||||||||||||
Less Accumulated depreciation and depletion | 19,866 | 229,488 | 1,509,079 | | 1,758,433 | |||||||||||||||||
24,621 | 443,792 | 1,513,885 | | 1,982,298 | ||||||||||||||||||
$ | 1,294,794 | $ | 1,759,789 | $ | 2,166,922 | $ | (1,361,065 | ) | $ | 3,860,440 | ||||||||||||
LIABILITIES AND SHAREHOLDERS EQUITY | ||||||||||||||||||||||
Current Liabilities | ||||||||||||||||||||||
Accounts payable | $ | 8,247 | $ | 260,852 | $ | 92,391 | $ | (14,145 | ) | $ | 347,345 | |||||||||||
Notes payable | | 59,459 | 42,869 | (49 | ) | 102,279 | ||||||||||||||||
Current portion of long-term debt and capital lease obligations | | 160,099 | 26,077 | | 186,176 | |||||||||||||||||
Gas inventory equalization | | | 43,012 | | 43,012 | |||||||||||||||||
Federal income, property and other taxes payable | (9,278 | ) | 3,353 | 72,464 | (21,813 | ) | 44,726 | |||||||||||||||
Gas payable | | 24,687 | 577 | | 25,264 | |||||||||||||||||
Customer deposits | 9 | | 15,604 | | 15,613 | |||||||||||||||||
Liabilities from trading activities | | 22,793 | | | 22,793 | |||||||||||||||||
Other | 8,409 | 65,596 | 48,414 | (2,346 | ) | 120,073 | ||||||||||||||||
7,387 | 596,839 | 341,408 | (38,353 | ) | 907,281 | |||||||||||||||||
Deferred Credits and Other Liabilities | ||||||||||||||||||||||
Deferred income taxes | (2,540 | ) | | 125,965 | (87,346 | ) | 36,079 | |||||||||||||||
Unamortized investment tax credit | 231 | | 26,822 | | 27,053 | |||||||||||||||||
Tax benefits amortizable to customers | | | 134,996 | | 134,996 | |||||||||||||||||
Deferred swap gains and payables | | 128,311 | | | 128,311 | |||||||||||||||||
Accrued environmental costs | 2,663 | | 24,463 | | 27,126 | |||||||||||||||||
Minority interest | | 616 | 1,035 | | 1,651 | |||||||||||||||||
Other | 14,318 | 29,169 | 63,210 | (4,516 | ) | 102,181 | ||||||||||||||||
14,672 | 158,096 | 376,491 | (91,862 | ) | 457,397 | |||||||||||||||||
Long-Term Debt, including capital lease obligations | | 580,621 | 642,594 | | 1,223,215 | |||||||||||||||||
Redeemable Preferred Securities of Subsidiaries | 272,343 | | | | 272,343 | |||||||||||||||||
Common Shareholders Equity | ||||||||||||||||||||||
Common stock | 902 | 5 | 10,300 | (10,305 | ) | 902 | ||||||||||||||||
Additional paid-in capital | 1,093,570 | 720,085 | 230,399 | (950,484 | ) | 1,093,570 | ||||||||||||||||
Retained earnings (deficit) | (71,664 | ) | (295,669 | ) | 565,730 | (270,061 | ) | (71,664 | ) | |||||||||||||
Accumulated other comprehensive loss | | (188 | ) | | | (188 | ) | |||||||||||||||
Yield enhancement, contract and issuance costs | (22,416 | ) | | | | (22,416 | ) | |||||||||||||||
1,000,392 | 424,233 | 806,429 | (1,230,850 | ) | 1,000,204 | |||||||||||||||||
$ | 1,294,794 | $ | 1,759,789 | 2,166,922 | $ | (1,361,065 | ) | $ | 3,860,440 | |||||||||||||
38
CONSOLIDATING STATEMENT OF FINANCIAL POSITION
MCN | Eliminations | |||||||||||||||||||||
and Other | and | Consolidated | ||||||||||||||||||||
Subsidiaries | MCNEE | MichCon | Reclasses | Total | ||||||||||||||||||
June 30, 1999 | ||||||||||||||||||||||
(in Thousands) | ||||||||||||||||||||||
ASSETS | ||||||||||||||||||||||
Current Assets | ||||||||||||||||||||||
Cash and cash equivalents, at cost | $ | 434 | $ | 8,819 | $ | 10,823 | $ | | $ | 20,076 | ||||||||||||
Accounts receivable | 7,065 | 193,029 | 155,509 | (13,611 | ) | 341,992 | ||||||||||||||||
Less Allowance for doubtful accounts | 79 | 1,773 | 13,492 | | 15,344 | |||||||||||||||||
Accounts receivable, net | 6,986 | 191,256 | 142,017 | (13,611 | ) | 326,648 | ||||||||||||||||
Accrued unbilled revenues | 214 | | 20,302 | | 20,516 | |||||||||||||||||
Gas in inventory | | 77,035 | 43,892 | | 120,927 | |||||||||||||||||
Property taxes assessed applicable to future periods | 170 | 1,952 | 48,473 | | 50,595 | |||||||||||||||||
Deferred income taxes | | | | | | |||||||||||||||||
Assets from trading activities | | | | | | |||||||||||||||||
Other | 4,555 | 58,345 | 34,512 | (51,234 | ) | 46,178 | ||||||||||||||||
12,359 | 337,407 | 300,019 | (64,845 | ) | 584,940 | |||||||||||||||||
Deferred Charges and Other Assets | ||||||||||||||||||||||
Deferred income taxes | 10,660 | 121,287 | | (103,490 | ) | 28,457 | ||||||||||||||||
Investments in debt and equity securities | | 3,714 | 66,202 | 600 | 70,516 | |||||||||||||||||
Deferred swap losses and receivables | | 64,567 | | | 64,567 | |||||||||||||||||
Deferred environmental costs | 2,770 | | 28,404 | | 31,174 | |||||||||||||||||
Prepaid benefit costs | | | 134,590 | (1,785 | ) | 132,805 | ||||||||||||||||
Other | 13,806 | 29,983 | 66,758 | 3,954 | 114,501 | |||||||||||||||||
27,236 | 219,551 | 295,954 | (100,721 | ) | 442,020 | |||||||||||||||||
Investments in and Advances to Joint Ventures and Subsidiaries | 1,525,781 | 843,517 | 19,853 | (1,523,803 | ) | 865,348 | ||||||||||||||||
Property, Plant and Equipment, at cost | 48,752 | 844,272 | 2,942,856 | | 3,835,880 | |||||||||||||||||
Less Accumulated depreciation and depletion | 18,684 | 220,428 | 1,445,967 | | 1,685,079 | |||||||||||||||||
30,068 | 623,844 | 1,496,889 | | 2,150,801 | ||||||||||||||||||
$ | 1,595,444 | $ | 2,024,319 | $ | 2,112,715 | $ | (1,689,369 | ) | $ | 4,043,109 | ||||||||||||
LIABILITIES AND SHAREHOLDERS EQUITY | ||||||||||||||||||||||
Current Liabilities | ||||||||||||||||||||||
Accounts payable | $ | 6,148 | $ | 168,281 | $ | 89,662 | $ | (11,300 | ) | $ | 252,791 | |||||||||||
Notes payable | 156,440 | 162,886 | 28,319 | (836 | ) | 346,809 | ||||||||||||||||
Current portion of long-term debt and capital lease obligations | | 216 | 46,135 | | 46,351 | |||||||||||||||||
Gas inventory equalization | | | 22,773 | | 22,773 | |||||||||||||||||
Federal income, property and other taxes payable | (387 | ) | 2,450 | 86,097 | (44,959 | ) | 43,201 | |||||||||||||||
Deferred gas cost recovery revenues | | | | | | |||||||||||||||||
Gas payable | | 17,263 | 20,845 | | 38,108 | |||||||||||||||||
Customer deposits | 26 | | 15,830 | | 15,856 | |||||||||||||||||
Liabilities from trading activities | | | | | | |||||||||||||||||
Other | 15,319 | 28,686 | 43,126 | (2,580 | ) | 84,551 | ||||||||||||||||
177,546 | 379,782 | 352,787 | (59,675 | ) | 850,440 | |||||||||||||||||
Deferred Credits and Other Liabilities | ||||||||||||||||||||||
Deferred income taxes | | | 103,198 | (103,198 | ) | | ||||||||||||||||
Unamortized investment tax credit | 259 | | 28,823 | | 29,082 | |||||||||||||||||
Tax benefits amortizable to customers | | | 128,869 | | 128,869 | |||||||||||||||||
Deferred swap gains and payables | | 62,617 | | | 62,617 | |||||||||||||||||
Accrued environmental costs | 3,000 | | 31,704 | | 34,704 | |||||||||||||||||
Minority interest | | 2,166 | 8,363 | | 10,529 | |||||||||||||||||
Other | 12,879 | 12,685 | 51,663 | (2,370 | ) | 74,857 | ||||||||||||||||
16,138 | 77,468 | 352,620 | (105,568 | ) | 340,658 | |||||||||||||||||
Long-Term Debt, including capital lease obligations | | 777,752 | 686,004 | | 1,463,756 | |||||||||||||||||
Redeemable Preferred Securities of Subsidiaries | 502,232 | | | | 502,232 | |||||||||||||||||
Common Shareholders Equity | ||||||||||||||||||||||
Common stock | 855 | 5 | 10,300 | (10,305 | ) | 855 | ||||||||||||||||
Additional paid-in capital | 966,956 | 1,080,383 | 230,399 | (1,310,782 | ) | 966,956 | ||||||||||||||||
Retained earnings (deficit) | (45,995 | ) | (277,566 | ) | 480,605 | (203,039 | ) | (45,995 | ) | |||||||||||||
Accumulated other comprehensive loss | | (13,505 | ) | | | (13,505 | ) | |||||||||||||||
Yield enhancement, contract and issuance costs | (22,288 | ) | | | | (22,288 | ) | |||||||||||||||
899,528 | 789,317 | 721,304 | (1,524,126 | ) | 886,023 | |||||||||||||||||
$ | 1,595,444 | $ | 2,024,319 | $ | 2,112,715 | $ | (1,689,369 | ) | $ | 4,043,109 | ||||||||||||
39
MCN | Eliminations | |||||||||||||||||||||
and Other | and | Consolidated | ||||||||||||||||||||
Subsidiaries | MCNEE | MichCon | Reclasses | Total | ||||||||||||||||||
December 31, 1999 | ||||||||||||||||||||||
(in Thousands) | ||||||||||||||||||||||
ASSETS | ||||||||||||||||||||||
Current Assets | ||||||||||||||||||||||
Cash and cash equivalents, at cost | $ | 470 | $ | 49,191 | $ | 9,705 | $ | | $ | 59,366 | ||||||||||||
Accounts receivable | 23,989 | 404,299 | 165,189 | (26,068 | ) | 567,409 | ||||||||||||||||
Less Allowance for doubtful accounts | 176 | 2,767 | 17,777 | | 20,720 | |||||||||||||||||
Accounts receivable, net | 23,813 | 401,532 | 147,412 | (26,068 | ) | 546,689 | ||||||||||||||||
Accrued unbilled revenues | 1,573 | | 98,866 | | 100,439 | |||||||||||||||||
Gas in inventory | | 105,676 | 74,150 | | 179,826 | |||||||||||||||||
Property taxes assessed applicable to future periods | 277 | 1,785 | 60,589 | | 62,651 | |||||||||||||||||
Deferred income taxes | (878 | ) | 44,024 | | (10,638 | ) | 32,508 | |||||||||||||||
Assets from trading activities | | | | | | |||||||||||||||||
Other | 9,938 | 17,458 | 31,594 | (7,947 | ) | 51,043 | ||||||||||||||||
35,193 | 619,666 | 422,316 | (44,653 | ) | 1,032,522 | |||||||||||||||||
Deferred Charges and Other Assets | ||||||||||||||||||||||
Deferred income taxes | (254 | ) | 114,754 | | (99,951 | ) | 14,549 | |||||||||||||||
Investments in debt and equity securities | | 4,242 | 67,210 | 625 | 72,077 | |||||||||||||||||
Deferred swap losses and receivables | | 43,907 | | | 43,907 | |||||||||||||||||
Deferred environmental costs | 2,534 | | 28,639 | | 31,173 | |||||||||||||||||
Prepaid benefit costs | | | 156,290 | (14 | ) | 156,276 | ||||||||||||||||
Other | 3,638 | 30,647 | 64,546 | 9,457 | 108,288 | |||||||||||||||||
5,918 | 193,550 | 316,685 | (89,883 | ) | 426,270 | |||||||||||||||||
Investments in and Advances to Joint Ventures and Subsidiaries | 1,388,790 | 741,960 | 19,115 | (1,385,893 | ) | 763,972 | ||||||||||||||||
Property, Plant and Equipment, at cost | 44,141 | 680,011 | 2,988,318 | | 3,712,470 | |||||||||||||||||
Less Accumulated depreciation and depletion | 18,147 | 215,359 | 1,463,706 | | 1,697,212 | |||||||||||||||||
25,994 | 464,652 | 1,524,612 | | 2,015,258 | ||||||||||||||||||
$ | 1,455,895 | $ | 2,019,828 | $ | 2,282,728 | $ | (1,520,429 | ) | $ | 4,238,022 | ||||||||||||
LIABILITIES AND SHAREHOLDERS EQUITY | ||||||||||||||||||||||
Current Liabilities | ||||||||||||||||||||||
Accounts payable | $ | 11,426 | $ | 215,228 | $ | 93,549 | $ | (24,064 | ) | $ | 296,139 | |||||||||||
Notes payable | 200,721 | 179,249 | 237,785 | | 617,755 | |||||||||||||||||
Current portion of long-term debt and capital lease obligations | | 118 | 27,984 | | 28,102 | |||||||||||||||||
Gas inventory equalization | | | | | | |||||||||||||||||
Federal income, property and other taxes payable | (6,343 | ) | 3,428 | 71,415 | | 68,500 | ||||||||||||||||
Gas payable | | 19,824 | 3,598 | | 23,422 | |||||||||||||||||
Customer deposits | 9 | | 17,698 | | 17,707 | |||||||||||||||||
Liabilities from trading activities | | | | | | |||||||||||||||||
Other | 18,935 | 73,910 | 64,741 | (10,637 | ) | 146,949 | ||||||||||||||||
224,748 | 491,757 | 516,770 | (34,701 | ) | 1,198,574 | |||||||||||||||||
Deferred Credits and Other Liabilities | ||||||||||||||||||||||
Deferred income taxes | (5,678 | ) | | 105,351 | (99,673 | ) | | |||||||||||||||
Unamortized investment tax credit | 244 | | 27,778 | | 28,022 | |||||||||||||||||
Tax benefits amortizable to customers | | | 136,236 | | 136,236 | |||||||||||||||||
Deferred swap gains and payables | | 64,962 | | | 64,962 | |||||||||||||||||
Accrued environmental costs | 3,000 | | 25,068 | | 28,068 | |||||||||||||||||
Minority interest | | 2,380 | 8,716 | | 11,096 | |||||||||||||||||
Other | 11,591 | 33,639 | 46,398 | (15 | ) | 91,613 | ||||||||||||||||
9,157 | 100,981 | 349,547 | (99,688 | ) | 359,997 | |||||||||||||||||
Long-Term Debt, including capital lease obligations | | 776,708 | 680,909 | | 1,457,617 | |||||||||||||||||
Redeemable Preferred Securities of Subsidiaries | 402,922 | | | | 402,922 | |||||||||||||||||
Common Shareholders Equity | ||||||||||||||||||||||
Common stock | 857 | 5 | 10,300 | (10,305 | ) | 857 | ||||||||||||||||
Additional paid-in capital | 960,176 | 969,733 | 230,399 | (1,200,132 | ) | 960,176 | ||||||||||||||||
Retained earnings (deficit) | (119,677 | ) | (319,200 | ) | 494,803 | (175,603 | ) | (119,677 | ) | |||||||||||||
Accumulated other comprehensive loss | | (156 | ) | | | (156 | ) | |||||||||||||||
Yield enhancement, contract and issuance costs | (22,288 | ) | | | | (22,288 | ) | |||||||||||||||
819,068 | 650,382 | 735,502 | (1,386,040 | ) | 818,912 | |||||||||||||||||
$ | 1,455,895 | $ | 2,019,828 | $ | 2,282,728 | $ | (1,520,429 | ) | $ | 4,238,022 | ||||||||||||
40
CONSOLIDATING STATEMENTS OF OPERATIONS
MCN | Eliminations | ||||||||||||||||||||
and Other | and | Consolidated | |||||||||||||||||||
Subsidiaries | MCNEE | MichCon | Reclasses | Total | |||||||||||||||||
Three Months Ended June 30, 2000 | |||||||||||||||||||||
(in Thousands) | |||||||||||||||||||||
Operating Revenues | $ | 7,007 | $ | 303,226 | $ | 187,488 | $ | (3,521 | ) | $ | 494,200 | ||||||||||
Operating Expenses | |||||||||||||||||||||
Cost of sales | 4,874 | 281,589 | 70,108 | (3,335 | ) | 353,236 | |||||||||||||||
Operation and maintenance | 1,112 | 35,692 | 58,412 | (186 | ) | 95,030 | |||||||||||||||
Depreciation, depletion and amortization | 952 | 7,732 | 26,063 | | 34,747 | ||||||||||||||||
Property and other taxes | 366 | 1,983 | 13,591 | | 15,940 | ||||||||||||||||
Property write-downs, contract losses and restructuring charges | | | | | | ||||||||||||||||
Gains and losses on sale of assets, net | | (70,388 | ) | | | (70,388 | ) | ||||||||||||||
Merger costs | 463 | 917 | 1,079 | | 2,459 | ||||||||||||||||
7,767 | 257,525 | 169,253 | (3,521 | ) | 431,024 | ||||||||||||||||
Operating Income (Loss) | (760 | ) | 45,701 | 18,235 | | 63,176 | |||||||||||||||
Equity in Earnings of Joint Ventures | 23,247 | 5,026 | 599 | (23,714 | ) | 5,158 | |||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||
Interest income | 7,487 | 1,029 | 846 | (7,656 | ) | 1,706 | |||||||||||||||
Interest on long-term debt | (30 | ) | (10,982 | ) | (12,111 | ) | | (23,123 | ) | ||||||||||||
Other interest expense | (10 | ) | (9,809 | ) | (1,860 | ) | 7,657 | (4,022 | ) | ||||||||||||
Dividends on preferred securities of subsidiaries | | | | (7,437 | ) | (7,437 | ) | ||||||||||||||
Investment losses | | | | | | ||||||||||||||||
Minority interest | | (182 | ) | (127 | ) | | (309 | ) | |||||||||||||
Other | (1,133 | ) | (395 | ) | 140 | | (1,388 | ) | |||||||||||||
6,314 | (20,339 | ) | (13,112 | ) | (7,436 | ) | (34,573 | ) | |||||||||||||
Income (Loss) Before Income Taxes | 28,801 | 30,388 | 5,722 | (31,150 | ) | 33,761 | |||||||||||||||
Income Tax Provision (Benefit) | (815 | ) | 10,662 | 1,735 | | 11,582 | |||||||||||||||
Income (Loss) Before Cumulative Effect of Accounting Change | 29,616 | 19,726 | 3,987 | (31,150 | ) | 22,179 | |||||||||||||||
Cumulative Effect of Accounting Change for Start-up Costs | | | | | | ||||||||||||||||
Net Income (Loss) | 29,616 | 19,726 | 3,987 | (31,150 | ) | 22,179 | |||||||||||||||
Dividends on Preferred Securities | 7,437 | | | (7,437 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | 22,179 | $ | 19,726 | $ | 3,987 | $ | (23,713 | ) | $ | 22,179 | ||||||||||
Three Months Ended June 30, 1999 | |||||||||||||||||||||
Operating Revenues | $ | 6,908 | $ | 309,598 | $ | 185,555 | $ | (1,591 | ) | $ | 500,470 | ||||||||||
Operating Expenses | |||||||||||||||||||||
Cost of gas | 5,233 | 250,736 | 60,410 | (1,431 | ) | 314,948 | |||||||||||||||
Operation and maintenance | 591 | 34,130 | 63,942 | (186 | ) | 98,477 | |||||||||||||||
Depreciation, depletion and amortization | 973 | 16,431 | 24,758 | | 42,162 | ||||||||||||||||
Property and other taxes | 389 | 3,187 | 12,700 | (6 | ) | 16,270 | |||||||||||||||
Property write-downs, contract losses and restructuring charges | | 52,000 | | | 52,000 | ||||||||||||||||
Gains and losses on sale of assets, net | | 66,333 | | | 66,333 | ||||||||||||||||
Merger costs | | | | | | ||||||||||||||||
7,186 | 422,817 | 161,810 | (1,623 | ) | 590,190 | ||||||||||||||||
Operating Income (Loss) | (278 | ) | (113,219 | ) | 23,745 | 32 | (89,720 | ) | |||||||||||||
Equity in Earnings of Joint Ventures | (76,947 | ) | 11,594 | 572 | 76,947 | 12,166 | |||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||
Interest income | 10,975 | 1,471 | 946 | (11,023 | ) | 2,369 | |||||||||||||||
Interest on long-term debt | 250 | (10,329 | ) | (11,525 | ) | | (21,604 | ) | |||||||||||||
Other interest expense | (3,150 | ) | (13,375 | ) | (1,181 | ) | 11,024 | (6,682 | ) | ||||||||||||
Dividends on preferred securities of subsidiaries | | | | (10,334 | ) | (10,334 | ) | ||||||||||||||
Investment losses | | (7,456 | ) | | | (7,456 | ) | ||||||||||||||
Minority interest | | (154 | ) | (266 | ) | | (420 | ) | |||||||||||||
Other | (127 | ) | 1,593 | (177 | ) | (35 | ) | 1,254 | |||||||||||||
7,948 | (28,250 | ) | (12,203 | ) | (10,368 | ) | (42,873 | ) | |||||||||||||
Income (Loss) Before Income Taxes | (69,277 | ) | (129,875 | ) | 12,114 | 66,611 | (120,427 | ) | |||||||||||||
Income Tax Provision (Benefit) | (967 | ) | (44,765 | ) | 3,949 | | (41,783 | ) | |||||||||||||
Income (Loss) Before Cumulative Effect of Accounting Change | (68,310 | ) | (85,110 | ) | 8,165 | 66,611 | (78,644 | ) | |||||||||||||
Cumulative Effect of Accounting Change for Start-up Costs | | | | | | ||||||||||||||||
Net Income (Loss) | (68,310 | ) | (85,110 | ) | 8,165 | 66,611 | (78,644 | ) | |||||||||||||
Dividends on Preferred Securities | 10,334 | | | (10,334 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | (78,644 | ) | $ | (85,110 | ) | $ | 8,165 | $ | 76,945 | $ | (78,644 | ) | ||||||||
41
CONSOLIDATING STATEMENTS OF OPERATIONS
MCN | Eliminations | ||||||||||||||||||||
and Other | and | Consolidated | |||||||||||||||||||
Subsidiaries | MCNEE | MichCon | Reclasses | Total | |||||||||||||||||
Six Months Ended June 30, 2000 | |||||||||||||||||||||
(in Thousands) | |||||||||||||||||||||
Operating Revenues | $ | 17,914 | $ | 775,241 | $ | 630,235 | $ | (9,439 | ) | $ | 1,413,951 | ||||||||||
Operating Expenses | |||||||||||||||||||||
Cost of sales | 12,583 | 714,589 | 286,628 | (8,495 | ) | 1,005,305 | |||||||||||||||
Operation and maintenance | 2,884 | 62,007 | 122,475 | (944 | ) | 186,422 | |||||||||||||||
Depreciation, depletion and amortization | 1,884 | 15,075 | 52,007 | | 68,966 | ||||||||||||||||
Property and other taxes | 636 | 4,316 | 32,581 | | 37,533 | ||||||||||||||||
Property write-downs, contract losses and restructuring charges | | | | | | ||||||||||||||||
Gains and losses on sale of assets, net | | (83,263 | ) | | | (83,263 | ) | ||||||||||||||
Merger costs | 464 | 931 | 1,426 | | 2,821 | ||||||||||||||||
18,451 | 713,655 | 495,117 | (9,439 | ) | 1,217,784 | ||||||||||||||||
Operating Income (Loss) | (537 | ) | 61,586 | 135,118 | | 196,167 | |||||||||||||||
Equity in Earnings of Joint Ventures | 93,938 | 15,271 | 1,186 | (94,458 | ) | 15,937 | |||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||
Interest income | 16,174 | 3,207 | 1,572 | (16,499 | ) | 4,454 | |||||||||||||||
Interest on long-term debt | (3 | ) | (22,245 | ) | (24,384 | ) | | (46,632 | ) | ||||||||||||
Other interest expense | (1,696 | ) | (21,310 | ) | (4,869 | ) | 16,499 | (11,376 | ) | ||||||||||||
Dividends on preferred securities of subsidiaries | | | | (16,059 | ) | (16,059 | ) | ||||||||||||||
Investment losses | | | | | | ||||||||||||||||
Minority interest | | (528 | ) | (266 | ) | | (794 | ) | |||||||||||||
Other | (1,557 | ) | (286 | ) | 460 | | (1,383 | ) | |||||||||||||
12,918 | (41,162 | ) | (27,487 | ) | (16,059 | ) | (71,790 | ) | |||||||||||||
Income (Loss) Before Income Taxes | 106,319 | 35,695 | 108,817 | (110,517 | ) | 140,314 | |||||||||||||||
Income Tax Provision (Benefit) | (1,430 | ) | 12,164 | 37,890 | | 48,624 | |||||||||||||||
Income (Loss) Before Cumulative Effect of Accounting Change | 107,749 | 23,531 | 70,927 | (110,517 | ) | 91,690 | |||||||||||||||
Cumulative Effect of Accounting Change for Start-up Costs | | | | | | ||||||||||||||||
Net Income (Loss) | 107,749 | 23,531 | 70,927 | (110,517 | ) | 91,690 | |||||||||||||||
Dividends on Preferred Securities | 16,059 | | | (16,059 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | 91,690 | $ | 23,531 | $ | 70,927 | $ | (94,458 | ) | $ | 91,690 | ||||||||||
Six Months Ended June 30, 1999 | |||||||||||||||||||||
Operating Revenues | $ | 18,572 | $ | 608,279 | $ | 683,645 | $ | (8,326 | ) | $ | 1,302,170 | ||||||||||
Operating Expenses | |||||||||||||||||||||
Cost of sales | 12,638 | 473,037 | 308,761 | (5,603 | ) | 788,833 | |||||||||||||||
Operation and maintenance | (834 | ) | 72,496 | 131,488 | (2,723 | ) | 200,427 | ||||||||||||||
Depreciation, depletion and amortization | 1,807 | 36,164 | 49,366 | | 87,337 | ||||||||||||||||
Property and other taxes | 777 | 5,989 | 31,162 | | 37,928 | ||||||||||||||||
Property write-downs, contract losses and restructuring charges | | 52,000 | | | 52,000 | ||||||||||||||||
Gains and losses on sale of assets, net | | 63,328 | | | 63,328 | ||||||||||||||||
Merger costs | | | | | | ||||||||||||||||
14,388 | 703,014 | 520,777 | (8,326 | ) | 1,229,853 | ||||||||||||||||
Operating Income (Loss) | 4,184 | (94,735 | ) | 162,868 | | 72,317 | |||||||||||||||
Equity in Earnings of Joint Ventures | 11,480 | 23,611 | 1,013 | (11,480 | ) | 24,624 | |||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||
Interest income | 21,629 | 1,988 | 1,945 | (21,697 | ) | 3,865 | |||||||||||||||
Interest on long-term debt | 461 | (21,476 | ) | (22,491 | ) | | (43,506 | ) | |||||||||||||
Other interest expense | (7,312 | ) | (25,867 | ) | (3,836 | ) | 21,698 | (15,317 | ) | ||||||||||||
Dividends on preferred securities of subsidiaries | | | | (20,669 | ) | (20,669 | ) | ||||||||||||||
Investment losses | | (7,456 | ) | | | (7,456 | ) | ||||||||||||||
Minority interest | | (216 | ) | (523 | ) | | (739 | ) | |||||||||||||
Other | (258 | ) | 4,876 | 287 | (1 | ) | 4,904 | ||||||||||||||
14,520 | (48,151 | ) | (24,618 | ) | (20,669 | ) | (78,918 | ) | |||||||||||||
Income (Loss) Before Income Taxes | 30,184 | (119,275 | ) | 139,263 | (32,149 | ) | 18,023 | ||||||||||||||
Income Tax Provision (Benefit) | (708 | ) | (41,489 | ) | 47,125 | | 4,928 | ||||||||||||||
Income (Loss) Before Cumulative Effect of Accounting Change | 30,892 | (77,786 | ) | 92,138 | (32,149 | ) | 13,095 | ||||||||||||||
Cumulative Effect of Accounting Change for Start-up Costs | | (2,872 | ) | | | (2,872 | ) | ||||||||||||||
Net Income (Loss) | 30,892 | (80,658 | ) | 92,138 | (32,149 | ) | 10,223 | ||||||||||||||
Dividends on Preferred Securities | 20,669 | | | (20,669 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | 10,223 | $ | (80,658 | ) | $ | 92,138 | $ | (11,480 | ) | $ | 10,223 | |||||||||
42
MCN | Eliminations | ||||||||||||||||||||
and Other | and | Consolidated | |||||||||||||||||||
Subsidiaries | MCNEE | MichCon | Reclasses | Total | |||||||||||||||||
Twelve Months Ended June 30, 2000 | |||||||||||||||||||||
(in Thousands) | |||||||||||||||||||||
Operating Revenues | $ | 34,276 | $ | 1,509,987 | $ | 1,082,329 | $ | (15,407 | ) | $ | 2,611,185 | ||||||||||
Operating Expenses | |||||||||||||||||||||
Cost of sales | 23,401 | 1,360,145 | 461,792 | (13,874 | ) | 1,831,464 | |||||||||||||||
Operation and maintenance | 1,990 | 139,669 | 257,091 | (1,533 | ) | 397,217 | |||||||||||||||
Depreciation, depletion and amortization | 3,210 | 41,537 | 101,520 | | 146,267 | ||||||||||||||||
Property and other taxes | 1,480 | 8,673 | 46,649 | | 56,802 | ||||||||||||||||
Property write-downs, contract losses and restructuring charges | | 9,782 | | | 9,782 | ||||||||||||||||
Gains and losses on sale of assets, net | | (75,766 | ) | | | (75,766 | ) | ||||||||||||||
Merger costs | 836 | 9,986 | 26,855 | | 37,677 | ||||||||||||||||
30,917 | 1,494,026 | 893,907 | (15,407 | ) | 2,403,443 | ||||||||||||||||
Operating Income (Loss) | 3,359 | 15,961 | 188,422 | | 207,742 | ||||||||||||||||
Equity in Earnings of Joint Ventures | 66,481 | 42,088 | 2,149 | (67,019 | ) | 43,699 | |||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||
Interest income | 35,928 | 5,457 | 2,231 | (36,452 | ) | 7,164 | |||||||||||||||
Interest on long-term debt | 344 | (43,743 | ) | (49,158 | ) | | (92,557 | ) | |||||||||||||
Other interest expense | (6,486 | ) | (46,705 | ) | (9,659 | ) | 36,449 | (26,401 | ) | ||||||||||||
Dividends on preferred securities of subsidiaries | | | | (35,529 | ) | (35,529 | ) | ||||||||||||||
Investment losses | | | | | | ||||||||||||||||
Minority interest | | (904 | ) | (763 | ) | | (1,667 | ) | |||||||||||||
Other | (459 | ) | 1,798 | (843 | ) | | 496 | ||||||||||||||
29,327 | (84,097 | ) | (58,192 | ) | (35,532 | ) | (148,494 | ) | |||||||||||||
Income (Loss) Before Income Taxes | 99,167 | (26,048 | ) | 132,379 | (102,551 | ) | 102,947 | ||||||||||||||
Income Tax Provision (Benefit) | 1,101 | (7,945 | ) | 47,254 | | 40,410 | |||||||||||||||
Income (Loss) Before Cumulative Effect of Accounting Change | 98,066 | (18,103 | ) | 85,125 | (102,551 | ) | 62,537 | ||||||||||||||
Cumulative Effect of Accounting Change for Start-up Costs | | | | | | ||||||||||||||||
Net Income (Loss) | 98,066 | (18,103 | ) | 85,125 | (102,551 | ) | 62,537 | ||||||||||||||
Dividends on Preferred Securities | 35,529 | | | (35,529 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | 62,537 | $ | (18,103 | ) | $ | 85,125 | $ | (67,022 | ) | $ | 62,537 | |||||||||
Twelve Months Ended June 30, 1999 | |||||||||||||||||||||
Operating Revenues | $ | 28,165 | $ | 1,085,995 | $ | 1,115,289 | $ | (14,285 | ) | $ | 2,215,164 | ||||||||||
Operating Expenses | |||||||||||||||||||||
Cost of sales | 18,901 | 847,508 | 485,189 | (9,536 | ) | 1,342,062 | |||||||||||||||
Operation and maintenance | (11,281 | ) | 159,574 | 259,795 | (4,749 | ) | 403,339 | ||||||||||||||
Depreciation, depletion and amortization | 3,674 | 75,594 | 96,312 | | 175,580 | ||||||||||||||||
Property and other taxes | 1,325 | 12,098 | 55,345 | | 68,768 | ||||||||||||||||
Property write-downs, contract losses and restructuring charges | 17,169 | 277,827 | 24,800 | | 319,796 | ||||||||||||||||
Gains and losses on sale of assets, net | | 55,930 | | | 55,930 | ||||||||||||||||
Merger costs | | | | | | ||||||||||||||||
29,788 | 1,428,531 | 921,441 | (14,285 | ) | 2,365,475 | ||||||||||||||||
Operating Income (Loss) | (1,623 | ) | (342,536 | ) | 193,848 | | (150,311 | ) | |||||||||||||
Equity in Earnings of Joint Ventures | (142,488 | ) | 56,687 | 2,009 | 142,043 | 58,251 | |||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||
Interest income | 39,428 | 4,432 | 5,699 | (40,964 | ) | 8,595 | |||||||||||||||
Interest on long-term debt | (583 | ) | (47,660 | ) | (44,656 | ) | | (92,899 | ) | ||||||||||||
Other interest expense | (9,127 | ) | (49,094 | ) | (10,801 | ) | 40,964 | (28,058 | ) | ||||||||||||
Dividends on preferred securities of subsidiaries | | | | (38,055 | ) | (38,055 | ) | ||||||||||||||
Investment losses | | (7,456 | ) | | | (7,456 | ) | ||||||||||||||
Minority interest | | 151 | 6,347 | | 6,498 | ||||||||||||||||
Other | (356 | ) | 4,064 | (601 | ) | | 3,107 | ||||||||||||||
29,362 | (95,563 | ) | (44,012 | ) | (38,055 | ) | (148,268 | ) | |||||||||||||
Income (Loss) Before Income Taxes | (114,749 | ) | (381,412 | ) | 151,845 | 103,988 | (240,328 | ) | |||||||||||||
Income Tax Provision (Benefit) | (3,781 | ) | (137,805 | ) | 47,409 | | (94,177 | ) | |||||||||||||
Income (Loss) Before Cumulative Effect of Accounting Change | (110,968 | ) | (243,607 | ) | 104,436 | 103,988 | (146,151 | ) | |||||||||||||
Cumulative Effect of Accounting Change for Start-up Costs | | (2,872 | ) | | | (2,872 | ) | ||||||||||||||
Net Income (Loss) | (110,968 | ) | (246,479 | ) | 104,436 | 103,988 | (149,023 | ) | |||||||||||||
Dividends on Preferred Securities | 38,055 | | | (38,055 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | (149,023 | ) | $ | (246,479 | ) | $ | 104,436 | $ | 142,043 | $ | (149,023 | ) | ||||||||
43
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
MCN | Eliminations | |||||||||||||||||||||
and Other | and | Consolidated | ||||||||||||||||||||
Subsidiaries | MCNEE | MichCon | Reclasses | Total | ||||||||||||||||||
Six Months Ended June 30, 2000 | ||||||||||||||||||||||
(in Thousands) | ||||||||||||||||||||||
Net Cash Flow From Operating Activities | $ | 8,545 | $ | 41,689 | $ | 275,020 | $ | (17,010 | ) | $ | 308,244 | |||||||||||
Cash Flow From Financing Activities | ||||||||||||||||||||||
Notes payable, net | (200,721 | ) | (119,790 | ) | (194,916 | ) | (49 | ) | (515,476 | ) | ||||||||||||
Capital contributions received from (distributions paid to) affiliates, net | | (249,648 | ) | | 249,648 | | ||||||||||||||||
Dividends paid | (43,677 | ) | | | | (43,677 | ) | |||||||||||||||
Preferred securities dividends paid | (16,059 | ) | | | 16,059 | | ||||||||||||||||
Issuance of common stock | 4,642 | | | | 4,642 | |||||||||||||||||
Reacquisition of common stock | (2,079 | ) | | | | (2,079 | ) | |||||||||||||||
Long-term commercial paper and bank borrowings, net | | (35,761 | ) | | | (35,761 | ) | |||||||||||||||
Retirement of long-term debt and preferred securities | | (65 | ) | (40,156 | ) | | (40,221 | ) | ||||||||||||||
Other | (128 | ) | | | | (128 | ) | |||||||||||||||
Net cash provided from (used for) financing activities | (258,022 | ) | (405,264 | ) | (235,072 | ) | 265,658 | (632,700 | ) | |||||||||||||
Cash Flow From Investing Activities | ||||||||||||||||||||||
Capital expenditures | (583 | ) | (6,889 | ) | (49,446 | ) | | (56,918 | ) | |||||||||||||
Investment in debt and equity securities, net | | (2,000 | ) | (4,936 | ) | | (6,936 | ) | ||||||||||||||
Investment in joint ventures and subsidiaries | 249,348 | (63,512 | ) | | (249,648 | ) | (63,812 | ) | ||||||||||||||
Sale of property and joint venture interests | | 408,119 | | 3,617 | 411,736 | |||||||||||||||||
Other | 242 | (122 | ) | 7,768 | (2,667 | ) | 5,221 | |||||||||||||||
Net cash provided from (used for) investing activities | 249,007 | 335,596 | (46,614 | ) | (248,698 | ) | 289,291 | |||||||||||||||
Net Increase (Decrease) in Cash and Cash Equivalents | (470 | ) | (27,979 | ) | (6,666 | ) | (50 | ) | (35,165 | ) | ||||||||||||
Cash and Cash Equivalents, January 1 | 470 | 49,191 | 9,705 | | 59,366 | |||||||||||||||||
Cash and Cash Equivalents, June 30 | $ | | $ | 21,212 | $ | 3,039 | $ | (50 | ) | $ | 24,201 | |||||||||||
Six Months Ended June 30, 1999 | ||||||||||||||||||||||
Net Cash Flow From Operating Activities | $ | 41,353 | $ | 65,837 | $ | 222,622 | $ | (38,844 | ) | $ | 290,968 | |||||||||||
Cash Flow From Financing Activities | ||||||||||||||||||||||
Notes payable, net | (104,331 | ) | 25,124 | (192,850 | ) | 15 | (272,042 | ) | ||||||||||||||
Capital contributions received from (distributions paid to) affiliates, net | | 8,993 | | (8,993 | ) | | ||||||||||||||||
Dividends paid | (41,726 | ) | | (17,500 | ) | 17,500 | (41,726 | ) | ||||||||||||||
Preferred securities dividends paid | (20,669 | ) | | | 20,669 | | ||||||||||||||||
Issuance of common stock | 135,120 | | | | 135,120 | |||||||||||||||||
Reacquisition of common stock | (783 | ) | | | | (783 | ) | |||||||||||||||
Issuance of long-term debt | | | 106,535 | | 106,535 | |||||||||||||||||
Long-term commercial paper and bank borrowings, net | | 92,344 | | | 92,344 | |||||||||||||||||
Retirement of long-term debt and preferred securities | | (212,855 | ) | (55,918 | ) | | (268,773 | ) | ||||||||||||||
Net cash provided from (used for) financing activities | (32,389 | ) | (86,394 | ) | (159,733 | ) | 29,191 | (249,325 | ) | |||||||||||||
Cash Flow From Investing Activities | ||||||||||||||||||||||
Capital expenditures | (637 | ) | (101,146 | ) | (58,097 | ) | | (159,880 | ) | |||||||||||||
Acquisitions | | (31,153 | ) | | | (31,153 | ) | |||||||||||||||
Investment in debt and equity securities, net | | (1,952 | ) | | (645 | ) | (2,597 | ) | ||||||||||||||
Investment in joint ventures and subsidiaries | (9,493 | ) | (39,477 | ) | (14 | ) | 8,993 | (39,991 | ) | |||||||||||||
Sale of property and joint venture interests | | 200,387 | | 318 | 200,705 | |||||||||||||||||
Other | 200 | (6,319 | ) | (558 | ) | 987 | (5,690 | ) | ||||||||||||||
Net cash provided from (used for) investing activities | (9,930 | ) | 20,340 | (58,669 | ) | 9,653 | (38,606 | ) | ||||||||||||||
Net Increase (Decrease) in Cash and Cash Equivalents | (966 | ) | (217 | ) | 4,220 | | 3,037 | |||||||||||||||
Cash and Cash Equivalents, January 1 | 1,400 | 9,036 | 6,603 | | 17,039 | |||||||||||||||||
Cash and Cash Equivalents, June 30 | $ | 434 | $ | 8,819 | $ | 10,823 | $ | | $ | 20,076 | ||||||||||||
44
INDEPENDENT ACCOUNTANTS REPORT
To the Board of Directors of
We have reviewed the accompanying condensed consolidated statements of financial position of MCN Energy Group Inc. and subsidiaries (the Company) as of June 30, 2000 and 1999, the related condensed consolidated statements of operations and retained earnings (deficit) for the three, six and twelve-month periods ended June 30, 2000 and 1999, and the condensed consolidated statements of cash flows for the six-month periods ended June 30, 2000 and 1999. These financial statements are the responsibility of the Companys management.
We conducted our review in accordance with standards established by the American Institute of Certified Public Accountants. A review of interim financial information consists principally of applying analytical review procedures to the financial data and of making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with auditing standards generally accepted in the United States of America, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.
Based on our review, we are not aware of any material modifications that should be made to such condensed consolidated financial statements for them to be in conformity with accounting principles generally accepted in the United States of America.
We have previously audited, in accordance with auditing standards generally accepted in the United States of America, the consolidated statement of financial position of the Company as of December 31, 1999, and the related consolidated statements of operations, financial position, and cash flows for the year then ended prior to restatement for the change in method of accounting for gas in inventory held by the Companys Energy Marketing segment (not presented herein); and in our report dated March 21, 2000, we expressed an unqualified opinion on those consolidated financial statements and included an explanatory paragraph relating to a change in accounting method as described in Note 5 to those consolidated financial statements. We also audited the adjustments described in Note 3 (presented herein) that were applied to restate the December 31, 1999 consolidated statement of financial position of the Company. In our opinion, such adjustments are appropriate and have been properly applied and the information set forth in the accompanying condensed consolidated statement of financial position as of December 31, 1999 is fairly stated, in all material respects, in relation to the restated consolidated statement of financial position from which it has been derived.
DELOITTE & TOUCHE LLP
Detroit, Michigan
45
EXHIBITS AND REPORTS ON FORM 8-K
(a) Other Information
The amount reported for Mr. Glancy in the All Other Compensation column of the Summary Compensation Table, as contained in MCNs 1999 Form 10-K and its 2000 Proxy Statement, should be $4,091,947 for 1999. The previously reported amount inadvertently failed to include $445,000 of previous accruals under a non-qualified retirement plan that were paid to Mr. Glancy per his change of control employment agreement.
(b) Exhibits
Exhibit | ||||
Number | Description | |||
15-1 | Letter re Unaudited Interim Financial Information | |||
18-1 | Letter re Change in Accounting Principles | |||
27-1 | Financial Data Schedule |
(c) Reports on Form 8-K
MCN filed a report on Form 8-K dated June 14, 2000, under item 5, with respect to the issuance of a press release. The press release, which was included in Form 8-K, noted that MCN and DTE continue their discussions with the Federal Trade Commission (FTC) in connection with its review of the proposed merger. Because of the length of the FTC review, it appears unlikely that the transaction can be completed before the fourth quarter of 2000.
46
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.
MCN ENERGY GROUP INC. |
Date: August 14, 2000
By: |
/s/ GERARD KABZINSKI |
Gerard Kabzinski | |
Vice President and Controller |
47
Exhibit | ||||||
Number | Description | |||||
15-1 | Letter re unaudited interim Financial information | |||||
18-1 | Letter re Change in Accounting Principles | |||||
27-1 | Financial Data Schedule |
|