|
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
[X]
For the quarterly period ended June 30, 1999, or
[ ]
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 July 30, 1999:
Common Stock, par value $.01 per share: 85,655,381
INDEX TO FORM 10-Q
For Quarter Ended June 30, 1999
Page | ||||
Number | ||||
COVER | i | |||
INDEX | ii | |||
PART I FINANCIAL INFORMATION | ||||
Managements
Discussion and Analysis of Financial Condition and Results of Operations |
1 | |||
Financial Statements | 22 | |||
PART II OTHER INFORMATION | ||||
Item 5. Other Information | 44 | |||
Item 6. Exhibits and Reports on Form 8-K | 48 | |||
SIGNATURE | 49 |
ii
MCN ENERGY GROUP INC.
MANAGEMENTS DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Results lower due to unusual charges, partially offset by earnings from new gas sales program MCN had a net loss for the 1999 second quarter of $86.3 million or $1.03 per share compared with a net loss of $212.6 million or $2.70 per share in the same 1998 quarter. MCN experienced a net loss in the 1999 six-and twelve-month periods of $.7 million or $.01 per share and $153.4 million or $1.91 per share, respectively, compared with a net loss of $133.7 million or $1.70 per share and $87.6 million or $1.12 per share for the same 1998 periods. As subsequently discussed, the comparability in earnings was affected by non-recurring items consisting of an accounting change and several unusual charges. The unusual charges include losses on the sale of properties, property write-downs, investment losses and restructuring charges.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | ||||||||||||||||||||
(in Millions, Except Per Share Amounts) | |||||||||||||||||||||||||
Net Income (Loss) | |||||||||||||||||||||||||
Diversified Energy: | |||||||||||||||||||||||||
Before unusual charges | $ | (9.2 | ) | $ | 5.1 | $ | (5.1 | ) | $ | 21.3 | $ | (11.7 | ) | $ | 51.4 | ||||||||||
Unusual charges (Note 2) | (83.4 | ) | (220.4 | ) | (83.4 | ) | (220.4 | ) | (235.8 | ) | (220.4 | ) | |||||||||||||
(92.6 | ) | (215.3 | ) | (88.5 | ) | (199.1 | ) | (247.5 | ) | (169.0 | ) | ||||||||||||||
Gas Distribution: | |||||||||||||||||||||||||
Before unusual charges | 6.3 | 2.7 | 90.6 | 65.4 | 113.7 | 81.4 | |||||||||||||||||||
Unusual charges (Note 2e) | | | | | (16.7 | ) | | ||||||||||||||||||
6.3 | 2.7 | 90.6 | 65.4 | 97.0 | 81.4 | ||||||||||||||||||||
Total Before Accounting Change: | |||||||||||||||||||||||||
Before unusual charges | (2.9 | ) | 7.8 | 85.6 | 86.7 | 102.0 | 132.8 | ||||||||||||||||||
Unusual charges (Note 2) | (83.4 | ) | (220.4 | ) | (83.4 | ) | (220.4 | ) | (252.5 | ) | (220.4 | ) | |||||||||||||
(86.3 | ) | (212.6 | ) | 2.2 | (133.7 | ) | (150.5 | ) | (87.6 | ) | |||||||||||||||
Cumulative Effect of Accounting Change, Net of Taxes (Note 4) | | | (2.9 | ) | | (2.9 | ) | | |||||||||||||||||
$ | (86.3 | ) | $ | (212.6 | ) | $ | (.7 | ) | $ | (133.7 | ) | $ | (153.4 | ) | $ | (87.6 | ) | ||||||||
Diluted Earnings (Loss) Per Share | |||||||||||||||||||||||||
Diversified Energy: | |||||||||||||||||||||||||
Before unusual charges | $ | (.11 | ) | $ | .07 | $ | (.06 | ) | $ | .27 | $ | (.15 | ) | $ | .66 | ||||||||||
Unusual charges (Note 2) | (1.00 | ) | (2.80 | ) | (1.01 | ) | (2.80 | ) | (2.94 | ) | (2.82 | ) | |||||||||||||
(1.11 | ) | (2.73 | ) | (1.07 | ) | (2.53 | ) | (3.09 | ) | (2.16 | ) | ||||||||||||||
Gas Distribution: | |||||||||||||||||||||||||
Before unusual charges | .08 | .03 | 1.10 | .83 | 1.42 | 1.04 | |||||||||||||||||||
Unusual charges (Note 2e) | | | | | (.21 | ) | | ||||||||||||||||||
.08 | .03 | 1.10 | .83 | 1.21 | 1.04 | ||||||||||||||||||||
Total Before Accounting Change: | |||||||||||||||||||||||||
Before unusual charges | (.03 | ) | .10 | 1.04 | 1.10 | 1.27 | 1.70 | ||||||||||||||||||
Unusual charges (Note 2) | (1.00 | ) | (2.80 | ) | (1.01 | ) | (2.80 | ) | (3.15 | ) | (2.82 | ) | |||||||||||||
(1.03 | ) | (2.70 | ) | .03 | (1.70 | ) | (1.88 | ) | (1.12 | ) | |||||||||||||||
Cumulative Effect of Accounting Change (Note 4) | | | (.04 | ) | | (.03 | ) | | |||||||||||||||||
$ | (1.03 | ) | $ | (2.70 | ) | $ | (.01 | ) | $ | (1.70 | ) | $ | (1.91 | ) | $ | (1.12 | ) | ||||||||
1
Excluding the non-recurring items, MCN had a net loss of $2.9 million for the 1999 quarter and earnings of $85.6 million and $102.0 million for the 1999 six-and twelve-month periods, respectively, resulting in decreases of $10.7 million, $1.1 million and $30.8 million from the corresponding 1998 periods. The comparisons reflect losses in the Diversified Energy group resulting from the decline in earnings in the Exploration & Production (E&P) segment due to the disposition of assets as well as increased financing costs. The decline in Diversified Energys results was partially offset by increased contributions from the Gas Distribution segment resulting from its new gas sales program and the favorable impact of more normal weather in the 1999 six-month period. Also affecting the comparability for the six-and twelve-month periods were gains recorded by the Diversified Energy group in 1998 from the sale of certain assets.
As discussed in Note 3 to the Consolidated Financial Statements included herein and in MCNs 1998 Annual Report on Form 10-K/ A, MCN conducted a special investigation of prior years operations of CoEnergy Trading Company, its non-utility energy marketing subsidiary, subsequent to the issuance of its December 31, 1998 financial statements. As a result of the investigation, MCN identified that its internal control systems had been overridden and that certain transactions had not been properly accounted for. The accompanying consolidated financial statements for the 1998 periods have been restated from those originally reported to properly account for the transactions identified. The restatements result in an increase in net loss of $2.5 million or $.03 per share, $4.2 million or $.05 per share and $9.5 million or $.12 per share for the 1998 second quarter, six- and twelve-month periods, respectively. The corrections did not have an impact on the liquidity or cash flows of MCN. The financial information contained in Managements Discussion and Analysis herein has been revised to reflect the impact of such restatement.
Strategic direction MCNs objective is to achieve competitive, long-term returns for its shareholders. Consistent with this objective, MCN announced in August 1999 a significantly revised strategic direction that includes: focusing on the Midwest-to-Northeast region rather than on North America; emphasizing operational efficiencies and growth through the integration of existing businesses rather than building a portfolio of diverse, non-operated energy investments; retaining its natural gas producing properties in Michigan while going forward with the sale of its other exploration and production oil and gas properties; and reducing capital investment levels to approximately $500 million in 1999 and to $300 million in 2000 and 2001.
Unusual charges MCN recorded several unusual charges in the 1999 second quarter as well as the 1998 second and third quarters, consisting of losses on the sale of properties, property write-downs, investment losses and restructuring charges (Note 2).
2
A discussion of each unusual charge by segment follows:
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | ||||||||||||||||||||
(in Millions, Except Per Share Amounts) |
|||||||||||||||||||||||||
Unusual Charges | |||||||||||||||||||||||||
Diversified Energy: | |||||||||||||||||||||||||
Pipelines & Processing | $ | | $ | | $ | | $ | | $ | (89.5 | ) | $ | | ||||||||||||
Electric Power | | | | | (1.6 | ) | | ||||||||||||||||||
Exploration & Production | (83.4 | ) | (220.4 | ) | (83.4 | ) | (220.4 | ) | (138.0 | ) | (220.4 | ) | |||||||||||||
Corporate & Other | | | | | (6.7 | ) | | ||||||||||||||||||
(83.4 | ) | (220.4 | ) | (83.4 | ) | (220.4 | ) | (235.8 | ) | (220.4 | ) | ||||||||||||||
Gas Distribution | | | | | (16.7 | ) | | ||||||||||||||||||
$ | (83.4 | ) | $ | (220.4 | ) | $ | (83.4 | ) | $ | (220.4 | ) | $ | (252.5 | ) | $ | (220.4 | ) | ||||||||
Diluted Loss Per Share | $ | (1.00 | ) | $ | (2.80 | ) | $ | (1.01 | ) | $ | (2.80 | ) | $ | (3.15 | ) | $ | (2.82 | ) | |||||||
Pipelines & Processing
In the third quarter of 1998, MCN also recorded an impairment loss of $3.9 million pre-tax ($2.5 million 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.
Electric Power
Exploration & Production
3
oil reserves as well as reduced expectations of sales proceeds on unproved acreage. Under the full cost method of accounting as prescribed by the Securities and Exchange Commission, MCNs capitalized exploration and production costs at June 30, 1999 exceeded the full cost ceiling, resulting in the excess being written off to income. The ceiling is the sum of discounted future net cash flows from the production of proved gas and oil reserves, and the lower of cost or estimated fair value of unproved properties, net of related income tax effects.
In the second and third quarters of 1998, MCN recognized write-downs of its gas and oil properties totaling $333.0 million pre-tax ($216.4 million net of taxes) and $83.9 million pre-tax ($54.6 million net of taxes), respectively. The write-downs were also the result of MCNs capitalized exploration and production costs exceeding the full cost ceiling.
Losses on Sale of Properties: In the second quarter of 1999, MCN recognized losses from the sale of its Western and Midcontinent/ Gulf Coast E&P properties totaling $68.8 million pre-tax ($44.7 million net of taxes).
Loss on Investment: In the second quarter of 1999, MCN recognized a $7.5 million pre-tax ($4.9 million net of taxes) loss from the write-down of an investment in the common stock of an E&P company. MCN had also recognized a $6.1 million pre-tax loss ($4.0 million net of taxes) from the write-down of this investment during the second quarter of 1998. The losses were due to declines in the fair value of the securities that are not considered temporary. MCN has no carrying value in this investment after the write-downs.
Corporate & Other
Gas Distribution
Loss on Investment: In the third quarter of 1998, MCN also recorded an $8.5 million pre-tax loss ($5.5 million net of taxes) from the write-down of an investment in a Missouri gas distribution company that MCN expects to sell in 2000. The write-down represents the amount by which the carrying value exceeded the estimated fair value of the investment.
4
Diversified Energy
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | ||||||||||||||||||||
(in Millions) | |||||||||||||||||||||||||
Diversified Energy Operations | |||||||||||||||||||||||||
Operating Revenues* | $ | 298.0 | $ | 233.2 | $ | 591.5 | $ | 505.1 | $ | 1,079.2 | $ | 1,019.1 | |||||||||||||
Operating Expenses* | |||||||||||||||||||||||||
Property write-downs and restructuring charges (Note 2) | 52.0 | 333.0 | 52.0 | 333.0 | 286.5 | 333.0 | |||||||||||||||||||
Other | 302.3 | 227.0 | 581.8 | 493.8 | 1,077.6 | 986.4 | |||||||||||||||||||
354.3 | 560.0 | 633.8 | 826.8 | 1,364.1 | 1,319.4 | ||||||||||||||||||||
Operating Loss | (56.3 | ) | (326.8 | ) | (42.3 | ) | (321.7 | ) | (284.9 | ) | (300.3 | ) | |||||||||||||
Equity in Earnings of Joint Ventures | 11.6 | 11.8 | 23.6 | 28.2 | 56.6 | 58.3 | |||||||||||||||||||
Other Income & (Deductions)* | |||||||||||||||||||||||||
Interest income | 1.5 | 1.1 | 2.0 | 4.4 | 2.8 | 9.1 | |||||||||||||||||||
Interest expense | (15.4 | ) | (11.8 | ) | (32.2 | ) | (21.7 | ) | (64.8 | ) | (34.3 | ) | |||||||||||||
Dividends on preferred securities of subsidiaries | (10.4 | ) | (9.2 | ) | (20.7 | ) | (19.0 | ) | (38.1 | ) | (38.5 | ) | |||||||||||||
Loss on sale of E&P properties (Note 2c) | (68.8 | ) | | (68.8 | ) | | (68.8 | ) | | ||||||||||||||||
Loss on E&P investment (Note 2c) | (7.5 | ) | (6.1 | ) | (7.5 | ) | (6.1 | ) | (7.5 | ) | (6.1 | ) | |||||||||||||
Other | 3.8 | .3 | 10.0 | 13.0 | 17.2 | 20.6 | |||||||||||||||||||
(96.8 | ) | (25.7 | ) | (117.2 | ) | (29.4 | ) | (159.2 | ) | (49.2 | ) | ||||||||||||||
Loss Before Income Taxes | (141.5 | ) | (340.7 | ) | (135.9 | ) | (322.9 | ) | (387.5 | ) | (291.2 | ) | |||||||||||||
Income Tax Benefit | (48.9 | ) | (125.4 | ) | (47.4 | ) | (123.8 | ) | (140.0 | ) | (122.2 | ) | |||||||||||||
Net Income (Loss) | |||||||||||||||||||||||||
Before unusual charges | (9.2 | ) | 5.1 | (5.1 | ) | 21.3 | (11.7 | ) | 51.4 | ||||||||||||||||
Unusual charges (Note 2) | (83.4 | ) | (220.4 | ) | (83.4 | ) | (220.4 | ) | (235.8 | ) | (220.4 | ) | |||||||||||||
$ | (92.6 | ) | $ | (215.3 | ) | $ | (88.5 | ) | $ | (199.1 | ) | $ | (247.5 | ) | $ | (169.0 | ) | ||||||||
* Includes intercompany transactions
Operating and Joint Venture Income
5
and $32.8 million, respectively. Results for all 1999 periods reflect reduced contributions from the Pipelines & Processing and E&P segments, partially offset by lower Corporate & Other expenses. The Electric Power segment had reduced contributions in the current quarter and six-month period. Energy Marketing had a larger loss in the current quarter and improved results in the current six-month period.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | ||||||||||||||||||||
Operating and Joint Venture Income (Loss) | |||||||||||||||||||||||||
Before Unusual Charges: | |||||||||||||||||||||||||
Pipelines & Processing | $ | 4.6 | $ | 6.1 | $ | 9.6 | $ | 15.6 | $ | 15.4 | $ | 31.3 | |||||||||||||
Electric Power | 3.9 | 6.9 | 11.4 | 12.4 | 25.0 | 24.7 | |||||||||||||||||||
Energy Marketing | (2.3 | ) | (.2 | ) | 2.9 | .3 | (1.0 | ) | (1.2 | ) | |||||||||||||||
Exploration & Production | .2 | 8.1 | 8.2 | 16.9 | 20.3 | 44.0 | |||||||||||||||||||
Corporate & Other | .9 | (2.9 | ) | 1.2 | (5.7 | ) | (1.5 | ) | (7.8 | ) | |||||||||||||||
7.3 | 18.0 | 33.3 | 39.5 | 58.2 | 91.0 | ||||||||||||||||||||
Unusual Charges (Note 2) | (52.0 | ) | (333.0 | ) | (52.0 | ) | (333.0 | ) | (286.5 | ) | (333.0 | ) | |||||||||||||
$ | (44.7 | ) | $ | (315.0 | ) | $ | (18.7 | ) | $ | (293.5 | ) | $ | (228.3 | ) | $ | (242.0 | ) | ||||||||
Pipelines & Processing operating and joint venture results (excluding the write-offs recorded in the 1998 third quarter) decreased by $1.5 million, $6.0 million and $15.9 million for the 1999 quarter, six- and twelve-month periods, respectively. The 1999 quarter reflects start-up expenditures associated with new projects and a decline in the allowance for funds used during construction (AFUDC) associated with MCNs 16%-owned Portland Natural Gas Transmission System, as it was placed in service in the first quarter of 1999. The 1999 six- and twelve-month periods also reflect reduced earnings from MCNs 25%-owned methanol production business resulting from lower methanol prices as well as lower methanol volumes produced. Earnings from the methanol production business benefited from strong methanol prices during 1997 and early 1998, but prices have since weakened. Pipelines & Processings average methanol sales prices declined 22% for the current six-month period and 37% for the 1999 twelve-month period. Methanol production declined 5.4 million gallons for the 1999 six-month period and 6.2 million gallons for the 1999 twelve-month period due primarily to the shutdown of the methanol plant for scheduled maintenance in March 1999. Additionally, Pipelines & Processing results for the 1999 twelve-month period were impacted by $9.1 million of operating losses related to the start-up of the coal fines plants (Note 2a).
Pipelines & Processing operating and joint venture income was also affected by an increase in transportation volumes for all 1999 periods due to new gas gathering ventures and the expansion of existing pipeline projects. Volumes transported increased for the 1999 quarter, six- and twelve-month periods by 10.7 billion cubic feet (Bcf), 16.9 Bcf and 40.6 Bcf, respectively. Pipelines & Processing results were also higher in all 1999 periods due to an increase in gas processed to remove natural gas liquids (NGLs). Gas processed to remove NGLs increased 10.5 Bcf, 9.0 Bcf and 16.9 Bcf in the 1999 quarter, six- and twelve-month periods, respectively, reflecting volumes associated with the acquisition and development of additional processing facilities. Pipelines & Processing operations include an increase in gas processed to remove carbon dioxide (CO2). The volume of CO2 gas treated increased 1.7 Bcf, 2.3 Bcf and 8.0 Bcf in the 1999 quarter, six- and twelve-month periods, respectively. However, earnings were not significantly affected by these
6
increases, since under the terms of Pipelines & Processings CO2 processing contracts, revenues are not volume sensitive.
Quarter | 6 Months | 12 Months | ||||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | |||||||||||||||||||||
Pipelines & Processing Statistics* | ||||||||||||||||||||||||||
Methanol Produced (Million Gallons) | 16.8 | 14.8 | 24.9 | 30.3 | 55.0 | 61.2 | ||||||||||||||||||||
Transportation (Bcf) | 53.0 | 42.3 | 101.1 | 84.2 | 192.4 | 151.8 | ||||||||||||||||||||
Gas Processed (Bcf): | ||||||||||||||||||||||||||
Carbon Dioxide Treatment | 12.9 | 11.2 | 25.8 | 23.5 | 51.1 | 43.1 | ||||||||||||||||||||
Natural Gas Liquids Removal | 22.6 | 12.1 | 31.5 | 22.5 | 54.1 | 37.2 | ||||||||||||||||||||
35.5 | 23.3 | 57.3 | 46.0 | 105.2 | 80.3 | |||||||||||||||||||||
* | Includes MCNs share of joint ventures |
Pipelines & Processing has also recorded earnings from certain joint venture investments where it is allocated income based on its share of the ventures earnings but not less than a predetermined fixed amount. Joint venture income recorded from these investments through June 1999 was based on the fixed amount. Under the joint venture agreements, the fixed amount will be lowered or eliminated in 2000.
Pipelines & Processing has a 75% interest in an asphalt manufacturing partnership that recently completed construction of a plant designed to produce annually up to 100,000 tons of high-quality asphalt. The plant is experiencing some technical difficulties in producing economical quantities of asphalt. MCN is aggressively working to resolve the technical issues.
In 1998, MCN advanced approximately $18 million to a developer of a natural gas-based fertilizer project in the United Arab Emirates. The advance was structured as an interest bearing loan with the possibility of being converted into an equity investment in the project. Under MCNs new strategic direction, it is no longer likely that it will make an equity interest in the project. While the advance is due in September 1999, the project is being developed slower than initially anticipated and MCNs continuing role in the project is under negotiation.
Electric Power operating and joint venture results (excluding the restructuring charges recorded in the 1998 third quarter) decreased by $3.0 million and $1.0 million in the 1999 quarter and six-month period, respectively, and increased by $.3 million in the 1999 twelve-month period. Results for all 1999 periods were unfavorably affected by an uncollectible expense provision associated with a customer in bankruptcy. Additionally, the 1999 periods were impacted by higher start-up expenditures associated with new ventures as well as reduced contributions from MCNs international power investments, specifically its interest in the Torrent Power Limited (TPL) venture, which holds minority interests in electric distribution companies and power generation facilities in the state of Gujarat, India. In February 1999, MCN reached an agreement to sell its 40% interest in TPL for approximately $130 million. Earnings from TPL for 1999 have been deferred due to the pending sale that is expected to be completed in August 1999. MCN does not expect to incur any significant gains or losses relating to the TPL sale.
Electric Powers earnings comparison also was impacted by increased contributions from the 1,370 megawatt (MW) Midland Cogeneration Venture (MCV) facility reflecting an increase in MCNs interest in the MCV partnership from 18% to 23% in June 1998. Earnings from the MCV partnership for the 1999 six-and twelve-month periods include a favorable $2.1 million pre-tax
7
adjustment for the resolution of a number of contract issues with the electricity purchaser. Also contributing favorably to the 1999 results were higher earnings from MCNs 50%-owned, 123 MW Michigan Power cogeneration facility due to higher electricity capacity payments received under its long-term sales contract.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | ||||||||||||||||||||
(Thousands of MW hours)* | |||||||||||||||||||||||||
Electric Power | |||||||||||||||||||||||||
Electricity Sales Domestic | 691.1 | 581.0 | 1,392.0 | 1,204.0 | 2,704.6 | 2,471.0 | |||||||||||||||||||
Electricity Sales International | | 298.9 | | 537.6 | 750.7 | 538.1 | |||||||||||||||||||
691.1 | 879.9 | 1,392.0 | 1,741.6 | 3,455.3 | 3,009.1 | ||||||||||||||||||||
* | Includes MCNs share of joint ventures |
Energy Marketing operating and joint venture results decreased $2.1 million for the 1999 quarter, and improved $2.6 million and $.2 million for the 1999 six-and twelve-month periods, respectively. Results for all 1999 periods were impacted by higher costs for natural gas transportation and storage capacity, higher uncollectible expense as well as costs associated with the June 1999 dissolution of the DTE-CoEnergy joint venture.
The 1999 periods were also affected by improved margins due to an increase in total gas sales and exchange deliveries of 41.1 Bcf, 62.9 Bcf and 115.1 Bcf during the 1999 quarter, six- and twelve-month periods, respectively. The increase in gas sales is due in part to the April 1999 acquisition of existing marketing operations that significantly increased Energy Marketings level of sales to large commercial and industrial customers in the Midwest. The comparisons of earnings for all periods were also affected by losses associated with trading activities (Note 3). Additionally, the twelve-month period comparison was impacted by the December 1997 sale of Energy Marketings 25% interest in a gas storage project, that contributed $1.0 million of joint venture income in the 1998 twelve-month period.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | ||||||||||||||||||||
(Bcf)* | |||||||||||||||||||||||||
Energy Marketing | |||||||||||||||||||||||||
Gas Sales | 144.5 | 103.3 | 282.6 | 218.5 | 518.8 | 401.7 | |||||||||||||||||||
Exchange Gas Deliveries | .1 | .2 | 5.6 | 6.8 | 9.9 | 11.9 | |||||||||||||||||||
144.6 | 103.5 | 288.2 | 225.3 | 528.7 | 413.6 | ||||||||||||||||||||
* | Includes MCNs share of joint ventures |
The Washington 10 storage project, for which MCN markets 100% of the 42 Bcf of storage capacity, was completed and placed into operation in July 1999. Completion of the storage field in time for the 1999-2000 winter heating season enhances Energy Marketings ability to offer a reliable gas supply during peak winter months.
Exploration & Production operating and joint venture results (excluding the unusual charges recorded in the 1999 second quarter, 1998 second quarter and the 1998 third quarter) decreased by $7.9 million, $8.7 million and $23.7 million for the 1999 quarter, six- and twelve-month periods, respectively. These results reflect a decline in overall gas and oil production of 7.6 billion cubic feet equivalent (Bcfe) in the 1999 quarter, 10.9 Bcfe in the 1999 six-month period and 17.7 Bcfe in the 1999 twelve-month period. The decrease in gas and oil production is due primarily to the sale of MCNs Western properties in April 1999. Gas and oil production in future 1999 periods will also be
8
lower than the comparable 1998 periods due to the expected sale of other non-Michigan E&P properties by the end of 1999.
E&P results for all 1999 periods were also impacted by an increase in production-related expenses and variations in gas and oil sales prices. Production expenses increased per thousand cubic feet (Mcf) equivalent by $.22, $.09 and $.11 for the 1999 quarter, six- and twelve-month periods, respectively. Gas prices increased by $.19 per Mcf in the 1999 second quarter, by $.16 per Mcf in the current six-month period and by $.13 per Mcf in the 1999 twelve-month period. Oil prices increased by $.55 per barrel (Bbl) in the 1999 quarter, but declined by $1.21 per Bbl and $3.02 per Bbl in the current six- and twelve-month periods, respectively. The impact of fluctuations in natural gas and oil sales prices on E&P operating and joint venture income was mitigated by hedging with swap and futures agreements, as discussed in the Risk Management Strategy section that follows.
Quarter | 6 Months | 12 Months | ||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | |||||||||||||||||||
Exploration & Production Statistics | ||||||||||||||||||||||||
Gas Production (Bcf) | 15.7 | 20.6 | 35.3 | 41.1 | 76.2 | 81.1 | ||||||||||||||||||
Oil Production (million Bbl) | .3 | .8 | .8 | 1.6 | 1.5 | 3.7 | ||||||||||||||||||
Gas and Oil Production (Bcf equivalent) | 17.6 | 25.2 | 40.0 | 50.9 | 85.4 | 103.1 | ||||||||||||||||||
Average Gas Selling Price (per Mcf) | $ | 2.18 | $ | 2.07 | $ | 1.99 | $ | 2.09 | $ | 2.02 | $ | 2.23 | ||||||||||||
Effect of Hedging (per Mcf) | .01 | (.07 | ) | .20 | (.06 | ) | .09 | (.25 | ) | |||||||||||||||
Overall Average Gas Sales Price (per Mcf) | $ | 2.19 | $ | 2.00 | $ | 2.19 | $ | 2.03 | $ | 2.11 | $ | 1.98 | ||||||||||||
Average Oil Sales Price (per Bbl) | $ | 12.94 | $ | 10.49 | $ | 11.38 | $ | 11.83 | $ | 10.86 | $ | 14.07 | ||||||||||||
Effect of Hedging (per Bbl) | .44 | 2.34 | .58 | 1.34 | .92 | .73 | ||||||||||||||||||
Overall Average Oil Sales Price (per Bbl) | $ | 13.38 | $ | 12.83 | $ | 11.96 | $ | 13.17 | $ | 11.78 | $ | 14.80 | ||||||||||||
Risk management strategy MCN manages commodity price risk by utilizing futures, options and swap contracts to more fully balance its portfolio of gas and oil supply and sales agreements. In late 1998, MCN began entering into offsetting positions for existing hedges of gas and oil production from properties that have been or were expected to be sold in 1999. MCNs risk management strategy is being revised to reflect the change in its business that will result from its new strategic direction as previously discussed. Additionally, as a result of the special investigation, MCN is taking additional steps to ensure compliance with risk management policies that are periodically reviewed by the Board of Directors.
Corporate & Other operating and joint venture results (excluding the restructuring charges recorded in the 1998 third quarter) improved $3.8 million, $6.9 million and $6.3 million for the 1999 quarter, six- and twelve-month periods, respectively. These improvements reflect adjustments that reduce or eliminate accruals for employee incentive awards that are based on MCNs operating or stock price performance.
Other Income and Deductions
9
include lower interest income due to the collection in March 1998 of a $46 million advance made to a Philippine independent power producer. Other income in the 1999 periods includes a $3.1 million pre-tax gain recorded in the 1999 second quarter from the sale of a pipeline facility. Other income in the 1998 six- and twelve-month periods includes $9.9 million of pre-tax gains recorded in the 1998 first quarter from the sale of certain gas sales contracts and a 50% interest in the 30 MW Ada cogeneration facility. Other income for the 1998 twelve-month period includes a $3.2 million pre-tax gain from the December 1997 sale of Diversified Energys 25% interest in a gas storage project.
Income Taxes
Outlook
To achieve the operating efficiencies expected from the new strategic direction, MCN is working to reorganize its Diversified Energy group into the segments detailed below. Financial information beginning by year-end 1999 will be presented based on these new segments.
| 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 the gas to the Gas Distribution, Energy Marketing and Power segments and other, non-affiliated wholesale customers. |
| Energy Marketing consists of MCNs non-regulated marketing activities to industrial, commercial and residential customers, both inside and outside the Gas Distribution segments service area. Energy Marketing also will provide full-service energy solutions to business customers. |
| Power develops and manages independent electric power projects. |
| Energy Holdings manages and seeks to maximize the value of existing ventures outside MCNs target region. It primarily consists of gas gathering and processing investments in major U.S. producing basins. |
10
Gas Distribution
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | ||||||||||||||||||||
(in Millions) | |||||||||||||||||||||||||
Gas Distribution Operations | |||||||||||||||||||||||||
Operating Revenues* | |||||||||||||||||||||||||
Gas sales | $ | 135.6 | $ | 126.0 | $ | 578.6 | $ | 499.0 | $ | 918.6 | $ | 929.1 | |||||||||||||
End user transportation | 23.4 | 18.3 | 50.2 | 43.3 | 89.2 | 82.7 | |||||||||||||||||||
Intermediate transportation | 13.9 | 15.9 | 28.6 | 33.8 | 58.0 | 60.9 | |||||||||||||||||||
Other | 19.6 | 15.1 | 44.8 | 34.6 | 77.5 | 61.9 | |||||||||||||||||||
192.5 | 175.3 | 702.2 | 610.7 | 1,143.3 | 1,134.6 | ||||||||||||||||||||
Cost of Sales | 65.7 | 58.8 | 321.4 | 279.5 | 504.0 | 529.8 | |||||||||||||||||||
Gross Margin | 126.8 | 116.5 | 380.8 | 331.2 | 639.3 | 604.8 | |||||||||||||||||||
Other Operating Expenses* | |||||||||||||||||||||||||
Operation and maintenance | 67.7 | 62.8 | 138.2 | 125.9 | 268.9 | 266.8 | |||||||||||||||||||
Depreciation, depletion and amortization | 25.1 | 23.6 | 50.0 | 46.3 | 97.5 | 98.4 | |||||||||||||||||||
Property and other taxes | 12.9 | 14.1 | 31.5 | 31.6 | 55.9 | 58.8 | |||||||||||||||||||
Property write-down (Note 2e) | | | | | 24.8 | | |||||||||||||||||||
105.7 | 100.5 | 219.7 | 203.8 | 447.1 | 424.0 | ||||||||||||||||||||
Operating Income | 21.1 | 16.0 | 161.1 | 127.4 | 192.2 | 180.8 | |||||||||||||||||||
Equity in Earnings of Joint Ventures | .6 | (.1 | ) | 1.0 | .4 | 1.6 | 1.0 | ||||||||||||||||||
Other Income and (Deductions)* | |||||||||||||||||||||||||
Interest income | .8 | 1.0 | 1.8 | 2.0 | 5.5 | 4.2 | |||||||||||||||||||
Interest expense | (12.7 | ) | (12.6 | ) | (26.5 | ) | (28.0 | ) | (56.0 | ) | (55.0 | ) | |||||||||||||
Investment loss (Note 2e) | | | | | (8.5 | ) | | ||||||||||||||||||
Minority interest | (.2 | ) | (.5 | ) | (.5 | ) | (1.2 | ) | 6.4 | (2.2 | ) | ||||||||||||||
Other | (.3 | ) | .6 | .1 | .7 | (.7 | ) | 1.2 | |||||||||||||||||
(12.4 | ) | (11.5 | ) | (25.1 | ) | (26.5 | ) | (53.3 | ) | (51.8 | ) | ||||||||||||||
Income Before Income Taxes | 9.3 | 4.4 | 137.0 | 101.3 | 140.5 | 130.0 | |||||||||||||||||||
Income Taxes | 3.0 | 1.7 | 46.4 | 35.9 | 43.5 | 48.6 | |||||||||||||||||||
Net Income | |||||||||||||||||||||||||
Before unusual charges | 6.3 | 2.7 | 90.6 | 65.4 | 113.7 | 81.4 | |||||||||||||||||||
Unusual charges (Note 2e) | | | | | (16.7 | ) | | ||||||||||||||||||
$ | 6.3 | $ | 2.7 | $ | 90.6 | $ | 65.4 | $ | 97.0 | $ | 81.4 | ||||||||||||||
* Includes intercompany transactions
Gross Margin
11
its Regulatory Reform Plan (Note 5a). Under the gas sales program that began in January 1999, MichCons gas sales rates include a gas commodity component that is fixed at $2.95 per Mcf. As part of its gas acquisition strategy, MichCon has entered into fixed-price contracts at costs below $2.95 per Mcf for a substantial portion of its expected gas supply requirements through 2001. This strategy is likely to continue producing favorable margins in each of the three years.
Gross margins for the 1999 six-month period also reflect higher gas sales resulting from colder weather compared to the same 1998 period. Additionally, gross margins for all 1999 periods reflect revenues from the continued growth in other gas-related services as well as revenues and cost of sales associated with the three heating and cooling firms acquired in October 1998.
Gas Distributions operations are seasonal, with gross margins and earnings concentrated in the first and fourth quarters of each calendar year. By the end of the first quarter, the heating season is largely over, and Gas Distribution typically incurs substantially reduced gross margins and earnings in the second quarter and losses in the third quarter. The seasonal nature of Gas Distributions operations is expected to be more pronounced as a result of MichCons new gas sales program.
Quarter | 6 Months | 12 Months | ||||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | |||||||||||||||||||||
Effect of Weather on Gas Markets and Earnings | ||||||||||||||||||||||||||
Percent Warmer Than Normal | (21.4 | )% | (24.8 | )% | (7.8 | )% | (20.1 | )% | (11.6 | )% | (12.9 | )% | ||||||||||||||
Decrease From Normal in: | ||||||||||||||||||||||||||
Gas Markets (Bcf) | (5.3 | ) | (6.1 | ) | (10.4 | ) | (25.3 | ) | (25.4 | ) | (26.2 | ) | ||||||||||||||
Net Income (Millions) | $ | (5.1 | ) | $ | (5.3 | ) | $ | (10.3 | ) | $ | (22.0 | ) | $ | (23.7 | ) | $ | (22.8 | ) | ||||||||
Diluted Earnings Per Share | $ | (.06 | ) | $ | (.07 | ) | $ | (.13 | ) | $ | (.28 | ) | $ | (.29 | ) | $ | (.29 | ) |
Gas sales and end user transportation revenues in total increased by $14.7 million and $86.5 million for the 1999 quarter and six-month period, respectively, and decreased by $4.0 million for the 1999 twelve-month period. Revenues were affected by fluctuations in gas sales and end user transportation deliveries that increased by .1 Bcf and 12.7 Bcf in the current quarter and six-month period, respectively, and decreased by .2 Bcf in the 1999 twelve-month period. The fluctuations in gas sales and end user transportation deliveries were due primarily to weather, which was colder in all the 1999 periods compared to the corresponding 1998 periods. The effect of more favorable weather on deliveries in the 1999 twelve-month period was more than offset by a decrease in end user transportation deliveries as a result of the temporary shut-down of an industrial customers plant.
Revenues were also impacted by variations in the cost of the gas commodity component of gas sales rates. As previously discussed, this gas commodity component was fixed under MichCons new 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 $.20 per Mcf (7%) and $.18 per Mcf (6%) for the 1999
12
quarter and six-month period, respectively, and decreased $.12 per Mcf (4%) for the 1999 twelve-month period.
Quarter | 6 Months | 12 Months | |||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | ||||||||||||||||||||
(Bcf) | |||||||||||||||||||||||||
Gas Distribution | |||||||||||||||||||||||||
Gas Sales | 24.1 | 24.7 | 116.6 | 104.7 | 184.1 | 183.9 | |||||||||||||||||||
End User Transportation | 31.8 | 31.1 | 74.4 | 73.6 | 141.1 | 141.5 | |||||||||||||||||||
55.9 | 55.8 | 191.0 | 178.3 | 325.2 | 325.4 | ||||||||||||||||||||
Intermediate Transportation* | 135.0 | 148.4 | 262.4 | 296.8 | 503.1 | 601.2 | |||||||||||||||||||
190.9 | 204.2 | 453.4 | 475.1 | 828.3 | 926.6 | ||||||||||||||||||||
* | Includes intercompany volumes |
Additionally, gas sales and end user transportation revenues in total were impacted by MichCons three-year customer choice program, which is also part of its Regulatory Reform Plan. Under the customer choice program that began in April 1999, approximately 70,000 or 6% of its customers are purchasing natural gas from suppliers other than MichCon. However, MichCon continues to transport and deliver the gas to the customers premises at prices that maintain its previously existing sales margins on these services. MichCons customers who have chosen to purchase their gas from other suppliers 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.
Intermediate transportation revenues decreased $2.0 million, $5.2 million and $2.9 million in the 1999 quarter, six- and twelve-month periods, respectively. Intermediate transportation revenues reflect lower off-system volumes of 13.4 Bcf, 34.4 Bcf and 98.1 Bcf in the 1999 quarter, six-and twelve-month periods, respectively. A significant portion of the volume decrease 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 for all 1999 periods is due in part to an adjustment in 1998 of revenues related to fees generated from tracking the transfer of gas title on MichCons transportation system. The decrease for all 1999 periods is also due to customers shifting volumes from a higher rate to a lower rate transportation route.
Other operating revenues increased $4.5 million, $10.1 million and $15.6 million in the 1999 quarter, six-and twelve-month periods, respectively. The improvements are due to an increase in facility development and appliance maintenance services, late payment fees and other gas-related services. Additionally, all 1999 periods reflect revenues from the acquisition of three heating and cooling firms in October 1998.
Cost of Sales
13
is fixed. Accordingly, beginning in January 1999, changes in cost of gas sold directly impact gross margins and earnings.
Cost of sales increased $6.9 million and $41.9 million in the 1999 quarter and six-month period, respectively, and decreased $25.8 million in the 1999 twelve-month period. The increase in the current quarter and six-month period was due primarily to higher weather-driven gas sales volumes. Cost of sales was also impacted by a decrease in average prices paid for gas of $.05 per Mcf (2%) in the 1999 six-month period and $.27 per Mcf (9%) in the current twelve-month period. Prices paid for gas sold in the 1999 second quarter increased by $.01 per Mcf. Additionally, all 1999 periods reflect cost of sales associated with the operations of the three heating and cooling firms acquired in October 1998.
Other Operating Expenses
Depreciation and depletion increased $1.5 million and $3.7 million in the 1999 quarter and six-month period, respectively, and decreased $.9 million in the 1999 twelve-month period. Depreciation on higher plant balances impacted all 1999 periods. Additionally, the twelve-month period comparison reflects the effect of lower depreciation rates for MichCons utility property, plant and equipment that became effective in January 1998.
Property and other taxes decreased $1.2 million, $.1 million and $2.9 million in the 1999 quarter, six- and twelve-month periods, respectively. The improvement in all 1999 periods is attributable to lower property taxes. The 1999 quarter and twelve-month periods were also impacted by lower Michigan Single Business Tax resulting from an increase in capital acquisitions deductions.
Property write-down of $24.8 million in the 1999 twelve-month period represents the impairment of a Michigan gas gathering system (Note 2e).
Equity in Earnings of Joint Ventures
Other Income and Deductions
14
in the 1999 twelve-month period also reflect an unusual charge to write down the investment in a small natural gas distribution company located in Missouri (Note 2e). Also impacting other income and deductions in the 1999 twelve-month period was a change in minority interest reflecting the joint venture partners share of the write-down of the Michigan gas gathering properties (Note 2e).
Income Taxes
Outlook
Gas Distribution has begun, and plans to continue capitalizing on opportunities resulting from the gas industry restructuring. MichCon is currently implementing its Regulatory Reform Plan, which includes a comprehensive experimental three-year customer choice program which is designed to offer all sales customers added choices and greater price certainty. Beginning April 1, 1999, a limited number of customers have the option of purchasing natural gas from suppliers other than MichCon. However, MichCon will continue to transport and deliver the gas to the customers premises at prices that maintain its previously existing sales margins on these services. The 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 for the three-year period that began in January 1999. The suspension of the GCR mechanism allows MichCon to profit from its ability to purchase gas at less than $2.95 per Mcf. Also beginning in 1999, an income sharing mechanism allows customers to share in profits when actual returns on equity from utility operations exceed predetermined thresholds. The impact of weather and expenses incurred in the second half of 1999 will determine the actual amount of profits, if any, to be shared with customers.
Gas Distribution also plans to grow revenues and earnings by offering a variety of energy-related services, which include appliance maintenance. Growth in revenues is expected from the three heating and cooling firms acquired in October 1998 that have been integrated under MichCon Home Services, which is expanding its customer base and range of services.
Changes in Accounting
In the 1999 first quarter, MCN adopted the Emerging Issues Task Force consensus on Issue No. 98-10, Accounting for Energy Trading and Risk Management Activities (EITF 98-10). EITF 98-10 requires all energy trading contracts to be recognized in the balance sheet as either
15
assets or liabilities measured at their fair value, with changes in fair value recognized in earnings. Adoption of EITF 98-10 did not have a material impact on MCNs financial statements.
CAPITAL RESOURCES AND LIQUIDITY
6 Months | |||||||||
1999 | 1998 | ||||||||
(in Millions) | |||||||||
Cash and Cash Equivalents | |||||||||
Cash Flow Provided From (Used For): | |||||||||
Operating activities | $ | 290.9 | $ | 275.2 | |||||
Financing activities | (249.3 | ) | 62.1 | ||||||
Investing activities | (38.6 | ) | (295.8 | ) | |||||
Net Increase in Cash and Cash Equivalents | $ | 3.0 | $ | 41.5 | |||||
Operating Activities
Financing Activities
Prior to mid-February 1999, MCN issued new shares of common stock pursuant to its Dividend Reinvestment and Stock Purchase Plan and various employee benefit plans. MCN generated $.2 million in the 1999 six-month period and $10.4 million in the same 1998 period from common stock issuances under these plans. Beginning in mid-February 1999, shares issued under these plans are being acquired by MCN through open market purchases.
MCNs 5,865,000 of Preferred Redeemable Increased Dividend Equity Securities (Enhanced PRIDES) matured in April 1999. Each security represented a contract to purchase one share of MCN common stock. Upon conversion of the Enhanced PRIDES, MCN received cash proceeds totaling approximately $135.0 million. The proceeds were used to repay a $130.0 million medium-term note of Diversified Energy that came due in May 1999.
In March 1999, MCN entered into a $150 million revolving credit agreement that expires in October 1999. Borrowings under the credit agreement will be used to fund capital investments and for general corporate purposes. There was $40 million outstanding under this credit agreement at June 30, 1999.
Diversified Energy
16
finance capital investments and to finance Energy Marketings working capital requirements. The 364-day facility was renewed in July 1999. During the first six months of 1999, Diversified Energys commercial paper and bank borrowings outstanding increased by $112.1 million, leaving borrowings of $337.8 million outstanding under this program at June 30, 1999.
MCN received approximately $165 million in April 1999 from the sale of its Western E&P properties and approximately $65 million in August 1999 from the sale of its Midcontinent/ Gulf Coast E&P properties. Proceeds from the sales were used to repay outstanding debt at the MCN Corporate and Diversified Energy levels. Proceeds from the sale of additional non-Michigan E&P properties are expected by the end of 1999 and will be used to repay outstanding borrowings and for general corporate purposes.
MCN repaid $80 million of medium-term notes and $130 million of medium-term notes that came due in February 1999 and May 1999, respectively.
Gas Distribution
During the 1999 quarter, MichCon issued approximately $110 million of debt (Note 9) and repaid $50 million of first mortgage bonds.
Investing Activities
17
Capital investments equaled $263.8 million in the 1999 six-month period compared to $443.7 million for the same period in 1998. The 1999 investments include significantly lower levels of investments in E&P properties, pipeline and processing ventures and gas distribution facilities.
6 Months | |||||||||
1999 | 1998 | ||||||||
(in Millions) | |||||||||
Capital Investments | |||||||||
Consolidated Capital Expenditures: | |||||||||
Diversified Energy | $ | 104.5 | $ | 202.5 | |||||
Gas Distribution | 58.4 | 75.2 | |||||||
162.9 | 277.7 | ||||||||
MCNs Share of Joint Venture Capital Expenditures:(1) | |||||||||
Pipelines & Processing | 51.1 | 94.3 | |||||||
Energy Marketing, Gas Storage & Electric Power | 15.1 | 11.9 | |||||||
Other | .1 | .5 | |||||||
66.3 | 106.7 | ||||||||
Acquisitions:(2) | 34.6 | 59.3 | |||||||
Total Capital Investments | $ | 263.8 | $ | 443.7 | |||||
(1) A portion of joint venture capital expenditures is financed with joint venture debt
(2) Includes MCNs share of certain debt existing at the date of acquisitions
Total capital investments were partially funded from the sale of certain E&P properties and joint venture investments that totaled approximately $200 million in the 1999 six-month period.
Outlook
The proposed level of investments for 2000 and each of the next several years will approximate $300 million and is expected to be financed primarily with internally generated funds. No issuance of incremental equity securities is expected for the next few years. It is managements opinion that MCN and its subsidiaries will have sufficient capital resources to meet anticipated capital and operating requirements.
YEAR 2000
As discussed in MCNs 1998 Annual Report on Form 10-K/ A, MCN has implemented a corporate-wide, four-phase Year 2000 approach consisting of: i) inventory identification of the components of MCNs systems, equipment and facilities; ii) assessment assessing Year 2000 readiness and prioritizing the risks of items identified in the inventory phase; iii) remediation upgrading, repairing and replacing non-compliant systems, equipment and facilities; and iv) testing verifying items remediated. MCN is on schedule to have its mission-critical business systems, and measurement and control systems (including embedded microprocessors) Year 2000 ready as detailed below. The extension of the program reflects MCNs determination that additional testing and remediation is appropriate for some critical business and control systems for both MCN and its partners and vendors. The decision to retain the Michigan E&P properties has also made it
18
necessary to extend the testing timeline for a few business systems. The estimated completion status of these systems and the projected status for the future follows:
Inventory | Assessment | Remediation | Testing | ||||||||||||||
Business Systems: | |||||||||||||||||
June 30, 1999 | 100 | % | 100 | % | 90 | % | 80 | % | |||||||||
September 30, 1999 | 100 | % | 100 | % | 100 | % | 98 | % | |||||||||
November 30, 1999 | 100 | % | 100 | % | 100 | % | 100 | % | |||||||||
Measurement and Control Systems: | |||||||||||||||||
June 30, 1999 | 100 | % | 100 | % | 98 | % | 98 | % | |||||||||
September 30, 1999 | 100 | % | 100 | % | 100 | % | 100 | % |
Costs associated with the Year 2000 issue are not expected to have a material adverse effect on MCN results of operation, liquidity and financial condition. The total costs are estimated to be between $5 million and $6 million, of which approximately $4.2 million was incurred through June 1999. This estimate does not include MCNs share of Year 2000 costs that may be incurred by partnerships and joint ventures. The anticipated costs are not higher due in part to the ongoing replacement of significant old systems. New systems in process of being installed, as well as those installed over the past few years, are Year 2000 ready. These systems were necessary to maintain a high level of customer satisfaction and to respond to changes in regulation and increased competition within the energy industry.
MCN anticipates a smooth transition to the Year 2000. However, the failure to correct a material Year 2000 problem could result in an interruption in or a failure of certain business activities and operations. Such interruptions or failures could have a material adverse effect on MCNs results of operations, liquidity and financial condition. Due to the uncertainty inherent in the Year 2000 issue, resulting in part from the uncertainty of the Year 2000 readiness of key partners, operators, suppliers and government agencies, MCN cannot certify that it will be unaffected by Year 2000 complications.
In order to reduce its Year 2000 risk, MCN is developing contingency plans for mission-critical processes in the event of a Year 2000 complication. Contingency plans for several essential gas transmission facilities continue to be tested under a power outage scenario and have achieved excellent results. Contingency plans will continue to be refined throughout 1999 as MCN works with partners, operators, suppliers and governmental agencies.
MARKET RISK INFORMATION
As discussed in MCNs 1998 Annual Report on Form 10-K/ A, MCN manages commodity price and interest rate risk through the use of various derivative instruments and limits the use of such instruments to hedging activities. A discussion and analysis of the events and factors that have changed MCNs commodity price, interest rate and foreign currency risk during the 1999 six-month period follows.
Commodity Price Risk
19
a result of entering into the offsetting positions, as well as changes in commodity prices that occurred during the 1999 six-month period, there have been significant changes in the outcome of the sensitivity analysis performed for commodity price risk at June 30, 1999 as compared to December 31, 1998.
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, 1999 | December 31, 1998 | |||||||||||||||
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 | $ | 85.2 | $ | (85.2 | ) | $ | 53.6 | $ | (53.6 | ) | ||||||
Pay variable/receive fixed | $ | (76.6 | ) | $ | 76.6 | $ | (54.0 | ) | $ | 54.0 | ||||||
Futures: Longs | $ | 6.3 | $ | (6.3 | ) | $ | 1.9 | $ | (1.9 | ) | ||||||
Shorts | $ | (7.4 | ) | $ | 7.4 | $ | (.1 | ) | $ | .1 |
* | Includes only the risk related to the derivative instruments that serve as hedges and does not include the related underlying hedged item. |
Interest Rate Risk
Foreign Currency Risk
NEW ACCOUNTING PRONOUNCEMENTS
Derivative and Hedging Activities In June 1998, the Financial Accounting Standards Board issued Statement of Financial Accounting Standards (SFAS) No. 133, Accounting for Derivative Instruments and Hedging Activities, effective for fiscal years beginning after June 15, 1999. In June 1999, the FASB issued SFAS No. 137, Accounting for Derivative Instruments and Hedging Activities Deferral of the Effective Date of FASB Statement No. 133. SFAS No. 137 changes the effective date of SFAS No. 133 to fiscal years beginning after June 15, 2000.
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
20
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 and predominantly limits the use of such instruments to hedging activities. The effects of SFAS No. 133 on MCNs financial statements are subject to fluctuations in the market value of hedging contracts 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.
FORWARD-LOOKING STATEMENTS
The Quarterly Report on Form 10-Q includes forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements involve certain risks and uncertainties as set forth in MCNs 1998 Annual Report on Form 10-K/A.
The Year 2000 disclosure is a Year 2000 Readiness Disclosure under the Year 2000 Information and Readiness Disclosure Act. Therefore, MCN claims the full protections established by the Act.
AVAILABLE INFORMATION
The following information is available without charge to shareholders and other interested parties: the Form 10-K/A Annual Report; the Form 10-Q Quarterly Reports and the Annual and Quarterly Statistical Supplements. To request these publications, shareholders and other interested parties are instructed to contact: MCN Investor Relations, 500 Griswold Street, Detroit, Michigan 48226, (800) 548-4655. Information is also available on MCNs website at http://www.mcnenergy.com.
21
MCN ENERGY GROUP INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF FINANCIAL POSITION (Unaudited)
June 30, | December 31, | ||||||||||||
1998 | |||||||||||||
(Restated) | |||||||||||||
1999 | Note 3 | 1998 | |||||||||||
(in Thousands) | |||||||||||||
ASSETS | |||||||||||||
Current Assets | |||||||||||||
Cash and cash equivalents, at cost (which approximates market value) | $ | 20,076 | $ | 80,999 | $ | 17,039 | |||||||
Accounts receivable, less allowance for doubtful accounts of $15,847, $14,682 and $9,655, respectively | 326,648 | 327,653 | 400,120 | ||||||||||
Accrued unbilled revenues | 20,516 | 15,725 | 87,888 | ||||||||||
Gas in inventory (Note 7) | 122,536 | 103,671 | 147,387 | ||||||||||
Property taxes assessed applicable to future periods | 50,595 | 44,526 | 72,551 | ||||||||||
Other | 46,419 | 76,972 | 42,472 | ||||||||||
586,790 | 649,546 | 767,457 | |||||||||||
Deferred Charges and Other Assets | |||||||||||||
Deferred income taxes | 28,136 | | 50,547 | ||||||||||
Investments in debt and equity securities | 70,516 | 48,967 | 69,705 | ||||||||||
Deferred swap losses and receivables (Note 13) | 64,567 | 63,123 | 63,147 | ||||||||||
Deferred environmental costs | 31,174 | 30,468 | 30,773 | ||||||||||
Prepaid benefit costs | 132,805 | 88,711 | 111,775 | ||||||||||
Other | 114,501 | 91,037 | 98,940 | ||||||||||
441,699 | 322,306 | 424,887 | |||||||||||
Investments in and Advances to Joint Ventures | |||||||||||||
Pipelines & Processing | 568,921 | 429,846 | 521,711 | ||||||||||
Electric Power | 248,456 | 215,648 | 231,668 | ||||||||||
Energy Marketing | 27,299 | 23,873 | 29,435 | ||||||||||
Gas Distribution (Note 2e) | 1,978 | 8,822 | 1,478 | ||||||||||
Other | 18,694 | 19,029 | 18,939 | ||||||||||
865,348 | 697,218 | 803,231 | |||||||||||
Property, Plant and Equipment | |||||||||||||
Pipelines & Processing (Note 2a) | 46,902 | 112,138 | 48,706 | ||||||||||
Exploration & Production (Note 2c) | 753,357 | 1,066,673 | 1,040,047 | ||||||||||
Gas Distribution (Note 2e) | 2,970,482 | 2,867,494 | 2,916,540 | ||||||||||
Other | 65,139 | 32,875 | 36,124 | ||||||||||
3,835,880 | 4,079,180 | 4,041,417 | |||||||||||
Less Accumulated depreciation and depletion | 1,685,079 | 1,562,383 | 1,644,094 | ||||||||||
2,150,801 | 2,516,797 | 2,397,323 | |||||||||||
$ | 4,044,638 | $ | 4,185,867 | $ | 4,392,898 | ||||||||
22
MCN ENERGY GROUP INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF FINANCIAL POSITION (Unaudited)
June 30, | December 31, | ||||||||||||
1998 | |||||||||||||
(Restated) | |||||||||||||
1999 | Note 3 | 1998 | |||||||||||
(in Thousands) | |||||||||||||
LIABILITIES AND SHAREHOLDERS EQUITY | |||||||||||||
Current Liabilities | |||||||||||||
Accounts payable | $ | 252,791 | $ | 317,893 | $ | 304,349 | |||||||
Notes payable | 346,809 | 149,697 | 618,851 | ||||||||||
Current portion of long-term debt and capital lease obligations | 46,351 | 269,690 | 269,721 | ||||||||||
Gas inventory equalization (Note 7) | 22,967 | 15,490 | | ||||||||||
Federal income, property and other taxes payable | 43,201 | 79,376 | 69,465 | ||||||||||
Deferred gas cost recovery revenues (Note 5b) | | 29,139 | 14,980 | ||||||||||
Gas payable | 38,848 | 40,277 | 42,669 | ||||||||||
Customer deposits | 15,856 | 14,924 | 18,791 | ||||||||||
Interest payable | 22,416 | 29,073 | 30,314 | ||||||||||
Other | 62,135 | 38,034 | 77,996 | ||||||||||
851,374 | 983,593 | 1,447,136 | |||||||||||
Deferred Credits and Other Liabilities | |||||||||||||
Deferred income taxes | | 43,176 | | ||||||||||
Unamortized investment tax credit | 29,082 | 32,109 | 30,056 | ||||||||||
Tax benefits amortizable to customers | 128,869 | 123,444 | 130,120 | ||||||||||
Deferred swap gains and payables (Note 13) | 62,617 | 50,014 | 62,956 | ||||||||||
Accrued environmental costs | 34,704 | 35,000 | 35,000 | ||||||||||
Minority interest | 10,529 | 19,166 | 10,898 | ||||||||||
Other | 74,857 | 115,498 | 75,439 | ||||||||||
340,658 | 418,407 | 344,469 | |||||||||||
Long-Term Debt, including capital lease obligations (Note 9) | 1,463,756 | 1,405,252 | 1,307,168 | ||||||||||
MCN-Obligated Mandatorily Redeemable Preferred Securities of Subsidiaries Holding Solely Debentures of MCN | 502,232 | 405,428 | 502,203 | ||||||||||
Contingencies (Note 12) | |||||||||||||
Common Shareholders Equity | |||||||||||||
Common stock (Note 9) | 855 | 789 | 797 | ||||||||||
Additional paid-in capital (Note 9) | 966,956 | 816,286 | 832,966 | ||||||||||
Retained earnings (deficit) | (45,400 | ) | 190,548 | (2,977 | ) | ||||||||
Accumulated other comprehensive loss (Note 11) | (13,505 | ) | (12,148 | ) | (16,576 | ) | |||||||
Yield enhancement, contract and issuance costs | (22,288 | ) | (22,288 | ) | (22,288 | ) | |||||||
886,618 | 973,187 | 791,922 | |||||||||||
$ | 4,044,638 | $ | 4,185,867 | $ | 4,392,898 | ||||||||
23
MCN ENERGY GROUP INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited)
Three Months Ended | Six Months Ended | Twelve Months Ended | |||||||||||||||||||||||
June 30, | June 30, | June 30, | |||||||||||||||||||||||
1998 | 1998 | 1998 | |||||||||||||||||||||||
(Restated) | (Restated) | (Restated) | |||||||||||||||||||||||
1999 | Note 3 | 1999 | Note 3 | 1999 | Note 3 | ||||||||||||||||||||
(in Thousands, except Per Share Amounts) | |||||||||||||||||||||||||
Operating Revenues | $ | 488,784 | $ | 406,214 | $ | 1,285,370 | $ | 1,107,674 | $ | 2,208,394 | $ | 2,138,855 | |||||||||||||
Operating Expenses | |||||||||||||||||||||||||
Cost of sales | 314,948 | 228,249 | 788,833 | 652,545 | 1,342,062 | 1,282,252 | |||||||||||||||||||
Operation and maintenance | 98,477 | 91,629 | 200,427 | 186,503 | 403,339 | 386,158 | |||||||||||||||||||
Depreciation, depletion and amortization | 42,162 | 46,458 | 87,337 | 91,247 | 175,580 | 183,918 | |||||||||||||||||||
Property and other taxes | 16,270 | 17,838 | 37,928 | 38,713 | 68,768 | 72,976 | |||||||||||||||||||
Property write-downs and restructuring charges (Note 2) | 52,000 | 333,022 | 52,000 | 333,022 | 311,296 | 333,022 | |||||||||||||||||||
523,857 | 717,196 | 1,166,525 | 1,302,030 | 2,301,045 | 2,258,326 | ||||||||||||||||||||
Operating Income (Loss) | (35,073 | ) | (310,982 | ) | 118,845 | (194,356 | ) | (92,651 | ) | (119,471 | ) | ||||||||||||||
Equity in Earnings of Joint Ventures | 12,166 | 11,837 | 24,624 | 28,598 | 58,251 | 59,426 | |||||||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||||||
Interest income | 2,369 | 1,815 | 3,865 | 6,163 | 8,595 | 12,953 | |||||||||||||||||||
Interest on long-term debt | (21,604 | ) | (19,424 | ) | (43,506 | ) | (37,953 | ) | (92,899 | ) | (73,072 | ) | |||||||||||||
Other interest expense | (6,682 | ) | (4,822 | ) | (15,317 | ) | (11,663 | ) | (28,058 | ) | (16,322 | ) | |||||||||||||
Dividends on preferred securities of subsidiaries | (10,334 | ) | (9,230 | ) | (20,669 | ) | (18,984 | ) | (38,055 | ) | (38,516 | ) | |||||||||||||
Loss on sale of E&P properties (Note 2c) | (68,798 | ) | | (68,798 | ) | | (68,798 | ) | | ||||||||||||||||
Investment losses (Notes 2c and 2e) | (7,456 | ) | (6,135 | ) | (7,456 | ) | (6,135 | ) | (15,956 | ) | (6,135 | ) | |||||||||||||
Recognition of deferred loss related to discontinued operations subsequently retained (Note 6) | (1,982 | ) | | | | | | ||||||||||||||||||
Minority interest (Note 2e) | (420 | ) | (635 | ) | (739 | ) | (1,245 | ) | 6,498 | (2,242 | ) | ||||||||||||||
Other | 5,701 | 1,272 | 10,374 | 13,961 | 15,974 | 22,140 | |||||||||||||||||||
(109,206 | ) | (37,159 | ) | (142,246 | ) | (55,856 | ) | (212,699 | ) | (101,194 | ) | ||||||||||||||
Income (Loss) Before Income Taxes | (132,113 | ) | (336,304 | ) | 1,223 | (221,614 | ) | (247,099 | ) | (161,239 | ) | ||||||||||||||
Income Tax Benefit | (45,873 | ) | (123,681 | ) | (952 | ) | (87,873 | ) | (96,547 | ) | (73,627 | ) | |||||||||||||
Income (Loss) Before Cumulative Effect of Accounting Change | (86,240 | ) | (212,623 | ) | 2,175 | (133,741 | ) | (150,552 | ) | (87,612 | ) | ||||||||||||||
Cumulative Effect of Accounting Change, Net of Taxes (Note 4) | | | (2,872 | ) | | (2,872 | ) | | |||||||||||||||||
Net Loss | $ | (86,240 | ) | $ | (212,623 | ) | $ | (697 | ) | $ | (133,741 | ) | $ | (153,424 | ) | $ | (87,612 | ) | |||||||
Basic Earnings (Loss) Per Share (Note 10) | |||||||||||||||||||||||||
Before cumulative effect of accounting change | $ | (1.03 | ) | $ | (2.70 | ) | $ | .03 | $ | (1.70 | ) | $ | (1.88 | ) | $ | (1.12 | ) | ||||||||
Cumulative effect of accounting change (Note 4) | | | (.04 | ) | | (.03 | ) | | |||||||||||||||||
$ | (1.03 | ) | $ | (2.70 | ) | $ | (0.01 | ) | $ | (1.70 | ) | $ | (1.91 | ) | $ | (1.12 | ) | ||||||||
Diluted Earnings (Loss) Per Share (Note 10) | |||||||||||||||||||||||||
Before cumulative effect of accounting change | $ | (1.03 | ) | $ | (2.70 | ) | $ | .03 | $ | (1.70 | ) | $ | (1.88 | ) | $ | (1.12 | ) | ||||||||
Cumulative effect of accounting change (Note 4) | | | (.04 | ) | | (.03 | ) | | |||||||||||||||||
$ | (1.03 | ) | $ | (2.70 | ) | $ | (0.01 | ) | $ | (1.70 | ) | $ | (1.91 | ) | $ | (1.12 | ) | ||||||||
Average Common Shares Outstanding | |||||||||||||||||||||||||
Basic | 83,413 | 78,758 | 81,424 | 78,563 | 80,242 | 78,303 | |||||||||||||||||||
Diluted | 83,413 | 78,758 | 82,514 | 78,563 | 80,242 | 78,303 | |||||||||||||||||||
Dividends Declared Per Share | $ | .2550 | $ | .2550 | $ | .5100 | $ | .5100 | $ | 1.0200 | $ | 1.0075 | |||||||||||||
CONSOLIDATED STATEMENT OF RETAINED EARNINGS (DEFICIT) (Unaudited)
Three Months Ended | Six Months Ended | Twelve Months Ended | ||||||||||||||||||||||
June 30, | June 30, | June 30, | ||||||||||||||||||||||
1998 | 1998 | 1998 | ||||||||||||||||||||||
(Restated) | (Restated) | (Restated) | ||||||||||||||||||||||
1999 | Note 3 | 1999 | Note 3 | 1999 | Note 3 | |||||||||||||||||||
(in Thousands) | ||||||||||||||||||||||||
Balance Beginning of period | $ | 62,775 | $ | 424,157 | $ | (2,977 | ) | $ | 365,730 | $ | 190,548 | $ | 358,825 | |||||||||||
Add Net loss | (86,240 | ) | (212,623 | ) | (697 | ) | (133,741 | ) | (153,424 | ) | (87,612 | ) | ||||||||||||
(23,465 | ) | 211,534 | (3,674 | ) | 231,989 | 37,124 | 271,213 | |||||||||||||||||
Deduct Cash dividends declared | 21,935 | 20,986 | 41,726 | 41,441 | 82,524 | 80,665 | ||||||||||||||||||
Balance End of period | $ | (45,400 | ) | $ | 190,548 | $ | (45,400 | ) | $ | 190,548 | $ | (45,400 | ) | $ | 190,548 | |||||||||
24
MCN ENERGY GROUP INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited)
Six Months Ended | |||||||||||
June 30, | |||||||||||
1998 | |||||||||||
(Restated) | |||||||||||
1999 | Note 3 | ||||||||||
(in Thousands) | |||||||||||
Cash Flow From Operating Activities | |||||||||||
Net loss | $ | (697 | ) | $ | (133,741 | ) | |||||
Adjustments to reconcile net loss to net cash provided from operating activities Depreciation, depletion and amortization | |||||||||||
Per statement of operations | 87,337 | 91,247 | |||||||||
Charged to other accounts | 4,423 | 4,020 | |||||||||
Unusual charges, net of taxes (Note 2) | 83,365 | 220,452 | |||||||||
Cumulative effect of accounting change, net of taxes (Note 4) | 2,872 | | |||||||||
Deferred income taxes current | (2,266 | ) | (11,994 | ) | |||||||
Deferred income taxes and investment tax credit, net | 65,246 | 10,356 | |||||||||
Equity in earnings of joint ventures, net of distributions | (8,256 | ) | (17,715 | ) | |||||||
Other | (1,118 | ) | (4,798 | ) | |||||||
Changes in assets and liabilities, exclusive of changes shown separately | 60,062 | 117,393 | |||||||||
Net cash provided from operating activities | 290,968 | 275,220 | |||||||||
Cash Flow From Financing Activities | |||||||||||
Notes payable, net | (272,042 | ) | (161,672 | ) | |||||||
Dividends paid | (41,726 | ) | (41,441 | ) | |||||||
Issuance of common stock (Note 9) | 135,120 | 10,374 | |||||||||
Reacquisition of common stock | (783 | ) | | ||||||||
Issuance of long-term debt (Note 9) | 106,535 | 460,161 | |||||||||
Long-term commercial paper and bank borrowings | 92,344 | 109,643 | |||||||||
Retirement of long-term debt and preferred securities (Note 9) | (268,773 | ) | (323,454 | ) | |||||||
Other | | 8,506 | |||||||||
Net cash provided from (used for) financing activities | (249,325 | ) | 62,117 | ||||||||
Cash Flow From Investing Activities | |||||||||||
Capital expenditures | (159,880 | ) | (277,655 | ) | |||||||
Acquisitions | (31,153 | ) | (36,731 | ) | |||||||
Investment in debt and equity securities, net | (2,597 | ) | 44,241 | ||||||||
Investment in joint ventures | (39,991 | ) | (96,647 | ) | |||||||
Sale of property and joint venture interests | 200,705 | 81,026 | |||||||||
Return of investment in joint ventures | 1,193 | 4,801 | |||||||||
Other | (6,883 | ) | (14,868 | ) | |||||||
Net cash used for investing activities | (38,606 | ) | (295,833 | ) | |||||||
Net Increase in Cash and Cash Equivalents | 3,037 | 41,504 | |||||||||
Cash and Cash Equivalents, January 1 | 17,039 | 39,495 | |||||||||
Cash and Cash Equivalents, June 30 | $ | 20,076 | $ | 80,999 | |||||||
Changes in Assets and Liabilities, Exclusive of Changes Shown Separately | |||||||||||
Accounts receivable, net | $ | 72,787 | $ | 66,451 | |||||||
Accrued unbilled revenues | 67,372 | 77,285 | |||||||||
Accrued/deferred gas cost recovery revenues, net | (19,795 | ) | 42,001 | ||||||||
Gas in inventory | 24,851 | (46,894 | ) | ||||||||
Accounts payable | (46,758 | ) | (32,753 | ) | |||||||
Gas inventory equalization | 22,967 | 15,490 | |||||||||
Federal income, property and other taxes payable | (35,194 | ) | (7,422 | ) | |||||||
Gas payable | (3,821 | ) | 38,214 | ||||||||
Interest payable | (7,898 | ) | 612 | ||||||||
Prepaid benefit costs, net | (20,422 | ) | (7,818 | ) | |||||||
Other current assets and liabilities, net | 15,088 | (17,883 | ) | ||||||||
Other deferred assets and liabilities, net | (9,115 | ) | (9,890 | ) | |||||||
$ | 60,062 | $ | 117,393 | ||||||||
Supplemental Disclosures | |||||||||||
Cash paid during the year for: | |||||||||||
Interest, net of amounts capitalized | $ | 71,640 | $ | 47,166 | |||||||
Federal income taxes | $ | 3,550 | $ | 11,700 | |||||||
25
MCN ENERGY GROUP INC. AND SUBSIDIARIES
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
1. GENERAL
The accompanying consolidated financial statements should be read in conjunction with MCNs 1998 Annual Report on Form 10-K/ A. Certain reclassifications have been made to the prior years financial statements to conform with the 1999 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. UNUSUAL CHARGES
As discussed in MCNs 1998 Annual Report on Form 10-K/ A, MCN recorded several unusual charges in 1998, consisting of property write-downs, investment losses, and restructuring charges. In June 1999, MCN recorded additional unusual charges related to the Exploration & Production (E&P) segment, which had previously been classified as discontinued operations (Note 6). A discussion of each unusual charge by segment follows:
a. Pipelines & Processing
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. The economic viability of the project is dependent on coal briquettes produced from six coal fines plants qualifying for synthetic fuel tax credits and MCNs ability to utilize or sell such credits. Although the plants were in service by June 30, 1998, the date specified to qualify for the tax credits, operating delays at the plants in the 1998 third quarter have significantly increased the possibility that the Internal Revenue Service (IRS) will challenge the projects eligibility for tax credits. In addition, there was uncertainty as to whether MCN could utilize or sell the credits. These factors led to MCNs decision to record an impairment loss equal to the carrying value of the plants, reflecting the likely inability to recover such costs. MCN is seeking to maximize the value of its investment in the coal fines project, and in May 1999 filed a request with the IRS seeking a factual determination that its coal fines plants were in service on June 30, 1998. Management is unable to predict what action the IRS will take on its request. | |
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
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 certain international power projects. The charge was incurred as a result of refocusing MCNs strategic plan, particularly to exit certain international power projects. |
26
c. Exploration and 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. Under the full cost method of accounting as prescribed by the Securities and Exchange Commission, MCNs capitalized exploration and production costs at June 30, 1999 exceeded the full cost ceiling, resulting in the excess being written off to income. The ceiling is the sum of discounted future net cash flows from the production of proved gas and oil reserves, and the lower of cost or estimated fair value of unproved properties, net of related income tax effects. | |
In the second and third quarters of 1998, MCN recognized write-downs of its gas and oil properties totaling $333,022,000 pre-tax ($216,465,000 net of taxes) and $83,955,000 pre-tax ($54,570,000 net of taxes), respectively. The write-downs were also the result of MCNs capitalized exploration and production costs exceeding the full cost ceiling. | |
Losses on Sale of Properties: In the second quarter 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). | |
Loss on Investment: In the second quarter of 1999, MCN recognized a $7,456,000 pre-tax loss ($4,846,000 net of taxes) from the write-down of an investment in the common stock of an E&P company. MCN had also recognized a $6,135,000 pre-tax loss ($3,987,000 net of taxes) from the write-down of this investment during the second quarter of 1998. The losses were due to declines in the fair value of the securities that are not considered temporary. MCN has no carrying value in this investment after the write-downs. |
d. 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 the corporate realignment designed to improve operating efficiencies through a more streamlined organizational structure. The realignment includes cost saving initiatives expected to reduce future operating expenses. As of June 30, 1999, payments of $2,224,000 have been charged against the restructuring accruals relating to severance and termination benefits. These benefits will continue to be paid through 2000. The remaining restructuring costs, primarily for net lease expenses, are expected to be paid over the related lease terms that expire through 2006. |
e. 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 |
27
distribution company that MCN expects to sell in 2000. The write-down represents the amount by which the carrying value exceeded the estimated fair value of the investment. |
3. RESTATEMENT
As discussed in MCNs 1998 Annual Report on Form 10-K/ A, subsequent to the issuance of MCNs December 31, 1998 financial statements, certain matters came to managements attention and resulted in a special investigation of prior years operations of CoEnergy Trading Company (CTC), MCNs non-utility energy marketing subsidiary. As a result of the investigation, MCN identified that its internal controls had been overridden and that certain transactions had not been properly accounted for. Specifically, the investigation concluded that CTC had entered into gas supply contracts and agreed to pay significantly less than market prices in one period in return for above-market prices to be paid in subsequent periods through March 2000. The effect of these transactions was to improperly delay the accrual of cost of gas expenses, resulting in the understatement of net loss for the 1998 second quarter, six- and twelve-month periods by $2,234,000, $1,364,000 and $6,471,000, respectively.
Additionally, the investigation identified that CTC had entered into certain unauthorized gas purchase and sale contracts for trading purposes. The unauthorized transactions violate MCNs risk-management policy that requires all such activities to be reviewed and approved by a risk committee that reports regularly to the MCN Board of Directors. The gas purchase and sale contracts entered into in connection with trading activities, some of which remain in effect through March 2000, were not accounted for properly using the required mark-to-market method, under which unrealized gains and losses are recorded as an adjustment to cost of gas. The effect of not properly accounting for these transactions was the understatement of net loss for the 1998 second quarter, six- and twelve-month periods by $268,000, $2,744,000 and $2,926,000, respectively. However, net income of $276,000, $1,187,000 and $2,613,000 was realized and recorded in connection with these trading activities in the 1998 second quarter, six- and twelve-month periods, respectively, resulting in net income of $8,000 in the 1998 second quarter, a net loss of $1,557,000 in the 1998 six-month period and a net loss of $313,000 in the 1998 twelve-month period from such activities. From the inception of these trading activities in March 1997 through June 1999, $2,714,000 of net loss was realized and recorded in connection with these trading activities. All of the contracts were effectively closed in June 1999.
Other items identified during the investigation resulted in the understatement of net loss for the 1998 second quarter, six- and twelve-month periods by $21,000, $43,000 and $86,000, respectively.
28
The 1998 information in the accompanying consolidated financial statements has been restated from amounts originally reported to properly account for the transactions identified. A summary of the significant effects of the restatement on MCNs June 30, 1998 financial statements is as follows:
Three Months Ended | Six Months Ended | Twelve Months Ended | |||||||||||||||||||||||
June 30, 1998 | June 30, 1998 | June 30, 1998 | |||||||||||||||||||||||
Previously | Previously | Previously | |||||||||||||||||||||||
Reported | Restated | Reported | Restated | Reported | Restated | ||||||||||||||||||||
(in Thousands, Except Per Share Amounts) |
|||||||||||||||||||||||||
Consolidated Statement of | |||||||||||||||||||||||||
Operations | |||||||||||||||||||||||||
Cost of Sales | $ | 224,368 | $ | 228,249 | $ | 646,160 | $ | 652,545 | $ | 1,267,665 | $ | 1,282,252 | |||||||||||||
Loss Before Income Taxes | $ | (332,423 | ) | $ | (336,304 | ) | $ | (215,229 | ) | $ | (221,614 | ) | $ | (146,652 | ) | $ | (161,239 | ) | |||||||
Income Tax Benefit | $ | (122,323 | ) | $ | (123,681 | ) | $ | (85,639 | ) | $ | (87,873 | ) | $ | (68,523 | ) | $ | (73,627 | ) | |||||||
Net Loss | $ | (210,100 | ) | $ | (212,623 | ) | $ | (129,590 | ) | $ | (133,741 | ) | $ | (78,129 | ) | $ | (87,612 | ) | |||||||
Basic Loss Per Share | $ | (2.67 | ) | $ | (2.70 | ) | $ | (1.65 | ) | $ | (1.70 | ) | $ | (1.00 | ) | $ | (1.12 | ) | |||||||
Diluted Loss Per Share | $ | (2.67 | ) | $ | (2.70 | ) | $ | (1.65 | ) | $ | (1.70 | ) | $ | (1.00 | ) | $ | (1.12 | ) |
June 30, 1998 | |||||||||
Previously | |||||||||
Reported | Restated | ||||||||
Consolidated Statement of | |||||||||
Financial Position | |||||||||
Accounts Receivable | $ | 318,620 | $ | 327,653 | |||||
Gas in Inventory | $ | 114,071 | $ | 103,671 | |||||
Accounts Payable | $ | 298,912 | $ | 317,893 | |||||
Federal Income, Property and Other Taxes Payable | $ | 86,496 | $ | 79,376 | |||||
Common Shareholders Equity | $ | 986,415 | $ | 973,187 |
4. ACCOUNTING FOR START-UP ACTIVITIES
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.
5. REGULATORY MATTERS
a. Regulatory Reform Plan
As discussed in MCNs 1998 Annual Report on Form 10-K/A, MichCon implemented its Regulatory Reform Plan in January 1999. The plan includes a new 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 costs below $2.95 per Mcf for a substantial portion of its expected gas supply requirements through 2001. |
29
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. Plan years begin April 1 of each year, and the number of customers allowed to participate in the plan is limited to 75,000 in 1999, 150,000 in 2000 and 225,000 in 2001. There is also a volume limitation on commercial and industrial participants. The volume limitation for these participants is 10 billion cubic feet (Bcf) in 1999, 20 Bcf in 2000 and 30 Bcf in 2001. MichCon will continue to transport and deliver the gas to the customers premises at prices that maintain its previously existing sales margins on these services. Various parties have appealed the Michigan Public Service Commissions (MPSC) approval of the plan. While management believes the plan will be upheld on appeal, there can be no assurance as to the outcome. |
b. Gas Cost Recovery Proceedings
Prior to January 1999, the Gas Cost Recovery (GCR) process allowed MichCon to recover its cost of gas sold if the MPSC determined that such costs were reasonable and prudent. An annual GCR reconciliation proceeding provided a review of gas costs incurred during the previous year and determined whether gas costs had been overcollected or undercollected, and as a result, whether a refund or surcharge, including interest, was required to be returned to or collected from GCR customers. The 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 which indicates an overrecovery of $18,000,000, including interest. Management believes that 1998 gas costs were reasonable and prudent and that the MPSC will approve the gas costs incurred. However, management cannot predict the outcome of this proceeding. During the first quarter of 1999, MichCon refunded the overrecovery to customers as a reduction in gas sales rates. |
6. DISCONTINUED OPERATIONS SUBSEQUENTLY RETAINED
In December 1998, MCN accounted for its E&P segment as a discontinued operation as a result of its decision to sell all of its gas and oil properties. In August 1999, management announced its intention to retain its natural gas producing properties in Michigan. Accordingly, E&Ps operating results for prior periods have been reclassified from discontinued operations to continuing operations. The decision to retain these properties was based on the interaction of two factors. MCN significantly revised its strategic direction. Key aspects of the new corporate strategy include a Midwest-to-Northeast regional focus rather than a North American focus, and an emphasis on achieving operational efficiencies and growth through the integration of existing businesses. Shortly thereafter, the bid for the Michigan properties was lowered significantly. The lower price was unacceptable, especially in light of MCNs new strategic direction.
In accordance with Emerging Issues Task Force (EITF) Issue No. 85-36, Discontinued Operations with Expected Gain and Interim Operating Losses, E&Ps operating results for the first quarter of 1999 were initially deferred until the sale of all E&P properties was completed. Prior to the lowering of the bid for the Michigan properties, management expected that the disposition of all of the E&P properties would result in a gain. As a result of MCNs decision to retain its Michigan
30
E&P properties, the deferred loss of $1,982,000 pre-tax ($1,288,000 net of taxes) was recorded in the second quarter of 1999.
Additionally, the E&P segment recorded several unusual charges in the 1999 and 1998 periods (Note 2c). Included in these unusual charges for 1999 was the loss on the sale of the Western and Midcontinent/ Gulf Coast properties. Proceeds from the sale of these properties totaled approximately $265,000,000. At December 31, 1998, the Western and Midcontinent/ Gulf Coast properties had 360 billion cubic feet equivalent of proven reserves. MCN will continue selling its other non-Michigan E&P oil and gas properties.
Under EITF Issue No. 87-24, Allocation of Interest to Discontinued Operations, Diversified Energys interest and preferred dividend expenses were allocated to the discontinued E&P segment based on its ratio of total capital to that of Diversified Energy. The interest and preferred dividend expenses have been reallocated to the E&P segment based on an imputed debt structure reflective of its industry as is done with MCNs other segments.
The following financial information summarizes E&Ps operations:
Three Months Ended | Six Months Ended | Twelve Months Ended | |||||||||||||||||||||||
June 30, | June 30, | June 30, | |||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | ||||||||||||||||||||
(in Thousands) | |||||||||||||||||||||||||
Operating Revenues | $ | 37,918 | $ | 53,101 | $ | 87,417 | $ | 108,713 | $ | 185,806 | $ | 223,434 | |||||||||||||
Operating Loss | $ | (51,824 | ) | $ | (324,864 | ) | $ | (43,774 | ) | $ | (316,132 | ) | $ | (115,596 | ) | $ | (290,951 | ) | |||||||
Net Income (Loss): | |||||||||||||||||||||||||
Before Unusual Charges | $ | 3,657 | $ | 7,241 | $ | 3,657 | $ | 13,061 | $ | 12,267 | $ | 34,330 | |||||||||||||
Unusual Charges (Note 2c) | (83,365 | ) | (220,452 | ) | (83,365 | ) | (220,452 | ) | (137,935 | ) | (220,452 | ) | |||||||||||||
$ | (79,708 | ) | $ | (213,211 | ) | $ | (79,708 | ) | $ | (207,391 | ) | $ | (125,668 | ) | $ | (186,122 | ) | ||||||||
7. GAS IN INVENTORY
Inventory gas is priced on a last-in, first-out (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 generally recorded at the estimated average purchase rate for the calendar year. The excess of these changes 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. Approximately 95.7 Bcf and 90.7 Bcf of gas was in inventory at June 30, 1999 and 1998, respectively.
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8. CREDIT FACILITIES AND SHORT-TERM BORROWINGS
In March 1999, MCN entered into a $150,000,000 revolving credit agreement that expires in October 1999. Borrowings under the credit agreement are at variable rates.
MCN Investment Corporation (MCNIC) and MichCon maintain credit lines that allow for borrowings of up to $350,000,000 under 364-day revolving credit facilities and up to $350,000,000 under three-year revolving credit facilities. These credit lines totaling $700,000,000 support their commercial paper programs. The 364-day revolving credit facilities were renewed in July 1999. The three-year revolving credit facilities expire in July 2001.
As discussed in MCNs 1998 Annual Report on Form 10-K/ A, MCN borrowed $260,000,000 under a one-year term loan facility, due December 31, 1999. Principal payments are required based on certain proceeds received from the sale of E&P assets. As of June 30, 1999, MCN had repaid $143,000,000 of the facility.
9. ENHANCED PRIDES AND LONG-TERM DEBT
As discussed in MCNs 1998 Annual Report on Form 10-K/ A, MCN issued 5,865,000 of Preferred Redeemable Increased Dividend Equity Securities (Enhanced PRIDES) in 1996. Each security represented a contract to purchase one share of MCN common stock. The Enhanced PRIDES were converted into MCN common stock in April 1999, and as a result MCN received cash proceeds totaling approximately $135,000,000. These proceeds were used to repay a $130,000,000 medium-term note that came due in May 1999. Also in February 1999, MCN repaid an $80,000,000 medium-term note.
In June 1999, MichCon issued $55,000,000 of 6.85% senior secured notes, due June 2038, and 55,000,000 of 6.85% senior secured notes, due June 2039. The notes are insured by a financial guaranty insurance policy and are rated AAA or its equivalent by the major rating agencies. The notes are redeemable on or after June 1, 2004.
32
10. EARNINGS PER SHARE COMPUTATION
MCN reports both basic and diluted earnings per share. Basic EPS is computed by dividing income before cumulative effect of accounting change 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. A reconciliation of both calculations is shown below.
Net Income (Loss) | Weighted | |||||||||||||||||||||||||
Before Cumulative | Average | |||||||||||||||||||||||||
Effect of | Common | Earnings | ||||||||||||||||||||||||
Accounting Change | Shares | Per Share | ||||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | |||||||||||||||||||||
(in Thousands, Except Per Share Amounts) | ||||||||||||||||||||||||||
Three Months Ended June 30 | ||||||||||||||||||||||||||
Basic EPS | $ | (86,240 | ) | $ | (212,623 | ) | 83,413 | 78,758 | $ | (1.03 | ) | $ | (2.70 | ) | ||||||||||||
Effect of Dilutive Securities:* | ||||||||||||||||||||||||||
FELINE PRIDES | | | | | ||||||||||||||||||||||
Enhanced PRIDES | | | | | ||||||||||||||||||||||
Stock-based compensation plans | | | | | ||||||||||||||||||||||
Diluted EPS | $ | (86,240 | ) | $ | (212,623 | ) | 83,413 | 78,758 | $ | (1.03 | ) | $ | (2.70 | ) | ||||||||||||
Six Months Ended June 30 | ||||||||||||||||||||||||||
Basic EPS | $ | 2,175 | $ | (133,741 | ) | 81,424 | 78,563 | $ | .03 | $ | (1.70 | ) | ||||||||||||||
Effect of Dilutive Securities:* | ||||||||||||||||||||||||||
FELINE PRIDES | | | | | ||||||||||||||||||||||
Enhanced PRIDES | | | | | ||||||||||||||||||||||
Stock-based compensation plans | | | 1,090 | | ||||||||||||||||||||||
Diluted EPS | $ | 2,175 | $ | (133,741 | ) | 82,514 | 78,563 | $ | .03 | $ | (1.70 | ) | ||||||||||||||
Twelve Months Ended June 30 | ||||||||||||||||||||||||||
Basic EPS | $ | (150,552 | ) | $ | (87,612 | ) | 80,242 | 78,303 | $ | (1.88 | ) | $ | (1.12 | ) | ||||||||||||
Effect of Dilutive Securities:* | ||||||||||||||||||||||||||
FELINE PRIDES | | | | | ||||||||||||||||||||||
Enhanced PRIDES | | | | | ||||||||||||||||||||||
Stock-based compensation plans | | | | | ||||||||||||||||||||||
Diluted EPS | $ | (150,552 | ) | $ | (87,612 | ) | 80,242 | 78,303 | $ | (1.88 | ) | $ | (1.12 | ) | ||||||||||||
* | Except for the 1999 six-month period, the potentially dilutive securities have been excluded from the diluted EPS calculation since their inclusion would have been antidilutive. |
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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, | |||||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | ||||||||||||||||||||||
(in Thousands) | |||||||||||||||||||||||||||
Comprehensive Income (Loss) | |||||||||||||||||||||||||||
Net Loss | $ | (86,240 | ) | $ | (212,623 | ) | $ | (697 | ) | $ | (133,741 | ) | $ | (153,424 | ) | $ | (87,612 | ) | |||||||||
Other Comprehensive Income (Loss), Net of Taxes: | |||||||||||||||||||||||||||
Foreign currency translation adjustment | (898 | ) | (5,314 | ) | (616 | ) | (5,813 | ) | (1,357 | ) | (12,092 | ) | |||||||||||||||
Unrealized loss on securities: | |||||||||||||||||||||||||||
Unrealized losses during period | (642 | ) | (1,736 | ) | (1,159 | ) | (2,803 | ) | (4,846 | ) | (3,987 | ) | |||||||||||||||
Less: Reclassification for losses recognized in net income | 4,846 | 3,987 | 4,846 | 3,987 | 4,846 | 3,987 | |||||||||||||||||||||
4,204 | 2,251 | 3,687 | 1,184 | | | ||||||||||||||||||||||
Total Other Comprehensive Income (Loss), Net of Taxes | 3,306 | (3,063 | ) | 3,071 | (4,629 | ) | (1,357 | ) | (12,092 | ) | |||||||||||||||||
Total Comprehensive Income (Loss) | $ | (82,934 | ) | $ | (215,686 | ) | $ | 2,374 | $ | (138,370 | ) | $ | (154,781 | ) | $ | (99,704 | ) | ||||||||||
12. CONTINGENCIES
MCN is involved in certain legal and administrative proceedings before various courts and governmental agencies concerning claims arising in the ordinary course of business. These proceedings include certain contract disputes between Gas Distribution and gas producers. 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.
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13. COMMODITY SWAP AGREEMENTS
MCNs Diversified Energy and Gas Distribution groups manage commodity price risk through the use of various derivative instruments and predominately limit the use of such instruments to hedging activities. 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, | ||||||||||||
1999 | 1998 | 1998 | |||||||||||
(in Thousands) | |||||||||||||
Deferred Swap Losses and Receivables | |||||||||||||
Unrealized losses | $ | 42,556 | $ | 55,042 | $ | 48,700 | |||||||
Receivables | 31,156 | 8,786 | 25,864 | ||||||||||
73,712 | 63,828 | 74,564 | |||||||||||
Less Current portion | 9,145 | 705 | 11,417 | ||||||||||
$ | 64,567 | $ | 63,123 | $ | 63,147 | ||||||||
Deferred Swap Gains and Payables | |||||||||||||
Unrealized gains | $ | 24,822 | $ | 5,626 | $ | 24,126 | |||||||
Payables | 51,720 | 62,545 | 54,525 | ||||||||||
76,542 | 68,171 | 78,651 | |||||||||||
Less Current portion | 13,925 | 18,157 | 15,695 | ||||||||||
$ | 62,617 | $ | 50,014 | $ | 62,956 | ||||||||
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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, | |||||||||||||||||||||||
1999 | 1998 | 1999 | 1998 | 1999 | 1998 | ||||||||||||||||||||
(in Thousands) | |||||||||||||||||||||||||
Revenues From Unaffiliated Customers: | |||||||||||||||||||||||||
Pipelines & Processing | $ | 5,426 | $ | 6,205 | $ | 11,331 | $ | 8,438 | $ | 23,749 | $ | 11,474 | |||||||||||||
Electric Power | 12,980 | 12,568 | 25,123 | 22,246 | 50,008 | 47,498 | |||||||||||||||||||
Energy Marketing | 253,081 | 175,153 | 495,693 | 389,666 | 873,095 | 801,565 | |||||||||||||||||||
Exploration & Production | 25,457 | 38,474 | 54,371 | 81,350 | 123,525 | 153,224 | |||||||||||||||||||
Gas Distribution | 191,840 | 173,814 | 698,852 | 605,974 | 1,138,017 | 1,125,094 | |||||||||||||||||||
488,784 | 406,214 | 1,285,370 | 1,107,674 | 2,208,394 | 2,138,855 | ||||||||||||||||||||
Revenues From Affiliated Customers: | |||||||||||||||||||||||||
Pipelines & Processing | 928 | 62 | 1,102 | 236 | 1,211 | 395 | |||||||||||||||||||
Energy Marketing | 25,938 | 25,966 | 44,023 | 49,975 | 99,591 | 96,147 | |||||||||||||||||||
Exploration & Production | 12,461 | 14,627 | 33,046 | 27,363 | 62,281 | 70,210 | |||||||||||||||||||
Gas Distribution | 666 | 1,460 | 3,334 | 4,710 | 5,259 | 9,541 | |||||||||||||||||||
39,993 | 42,115 | 81,505 | 82,284 | 168,342 | 176,293 | ||||||||||||||||||||
Eliminations | (39,993 | ) | (42,115 | ) | (81,505 | ) | (82,284 | ) | (168,342 | ) | (176,293 | ) | |||||||||||||
Consolidated Operating Revenues | $ | 488,784 | $ | 406,214 | $ | 1,285,370 | $ | 1,107,674 | $ | 2,208,394 | $ | 2,138,855 | |||||||||||||
Net Income (Loss): | |||||||||||||||||||||||||
Pipelines & Processing | $ | 1,782 | $ | 2,776 | $ | 3,457 | $ | 7,243 | $ | (85,485 | ) | $ | 16,779 | ||||||||||||
Electric Power | 2,970 | 4,957 | 7,371 | 12,663 | 14,913 | 22,375 | |||||||||||||||||||
Energy Marketing | (2,742 | ) | (568 | ) | (387 | ) | 2,843 | (4,268 | ) | 2,945 | |||||||||||||||
Exploration & Production | (79,708 | ) | (213,211 | ) | (79,708 | ) | (207,391 | ) | (125,668 | ) | (186,122 | ) | |||||||||||||
Gas Distribution | 6,340 | 2,714 | 90,633 | 65,370 | 96,997 | 81,388 | |||||||||||||||||||
Corporate & Other | (14,882 | ) | (9,291 | ) | (19,191 | ) | (14,469 | ) | (47,041 | ) | (24,977 | ) | |||||||||||||
(86,240 | ) | (212,623 | ) | 2,175 | (133,741 | ) | (150,552 | ) | (87,612 | ) | |||||||||||||||
Cumulative effect of accounting change | | | (2,872 | ) | | (2,872 | ) | | |||||||||||||||||
Consolidated Net Loss | $ | (86,240 | ) | $ | (212,623 | ) | $ | (697 | ) | $ | (133,741 | ) | $ | (153,424 | ) | $ | (87,612 | ) | |||||||
15. CONSOLIDATING FINANCIAL STATEMENTS
Debt securities issued by MCN Investment Corporation (MCNIC) are subject to a support agreement between MCN and MCNIC, under which MCN has committed to make payments of interest and principal on MCNICs securities in the event of failure to pay by MCNIC. 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 MCNICs securities. The carrying value of MCNs assets on an unconsolidated basis, which primarily consists of investments in subsidiaries other than MichCon, is $878,334,000 at June 30, 1999.
The following MCN consolidating financial statements are presented and include separately MCNIC, MichCon and MCN and other subsidiaries. MCN has determined that separate financial statements and other disclosures concerning MCNIC 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 V, MCN Financing VI, MichCon Enterprises, Inc. and Blue Lake Holdings, Inc., until its sale on December 31, 1997.
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CONSOLIDATING STATEMENTS OF OPERATIONS (Unaudited)
MCN | Eliminations | ||||||||||||||||||||
and Other | and | Consolidated | |||||||||||||||||||
Subsidiaries | MCNIC | MichCon | Reclasses | Total | |||||||||||||||||
Three Months Ended June 30, 1999 | |||||||||||||||||||||
(in Thousands) | |||||||||||||||||||||
Operating Revenues | $ | 6,908 | $ | 297,912 | $ | 185,555 | $ | (1,591 | ) | $ | 488,784 | ||||||||||
Operating Expenses | |||||||||||||||||||||
Cost of sales | 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 and restructuring charges | | 52,000 | | | 52,000 | ||||||||||||||||
7,186 | 356,484 | 161,810 | (1,623 | ) | 523,857 | ||||||||||||||||
Operating Income (Loss) | (278 | ) | (58,572 | ) | 23,745 | 32 | (35,073 | ) | |||||||||||||
Equity in Earnings (Losses) of Joint Ventures and Subsidiaries | (83,493 | ) | 11,594 | 572 | 83,493 | 12,166 | |||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||
Interest income | 16,336 | 1,471 | 946 | (16,384 | ) | 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 | ) | ||||||||||||||
Loss on sale of E&P properties | | (68,798 | ) | | | (68,798 | ) | ||||||||||||||
Investment losses | | (7,456 | ) | | | (7,456 | ) | ||||||||||||||
Recognition of deferred loss related to discontinued operations subsequently retained | | (1,982 | ) | | | (1,982 | ) | ||||||||||||||
Minority interest | | (154 | ) | (266 | ) | | (420 | ) | |||||||||||||
Other | (127 | ) | 6,040 | (177 | ) | (35 | ) | 5,701 | |||||||||||||
13,309 | (94,583 | ) | (12,203 | ) | (15,729 | ) | (109,206 | ) | |||||||||||||
Income (Loss) Before Income Taxes | (70,462 | ) | (141,561 | ) | 12,114 | 67,796 | (132,113 | ) | |||||||||||||
Income Tax Provision (Benefit) | (967 | ) | (48,855 | ) | 3,949 | | (45,873 | ) | |||||||||||||
Net Income (Loss) | (69,495 | ) | (92,706 | ) | 8,165 | 67,796 | (86,240 | ) | |||||||||||||
Dividends on Preferred Securities | 10,334 | | | (10,334 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | (79,829 | ) | $ | (92,706 | ) | $ | 8,165 | $ | 78,130 | $ | (86,240 | ) | ||||||||
Three Months Ended June 30, 1998 | |||||||||||||||||||||
Operating Revenues | $ | 2,487 | $ | 233,228 | $ | 172,787 | $ | (2,288 | ) | $ | 406,214 | ||||||||||
Operating Expenses | |||||||||||||||||||||
Cost of sales | 1,322 | 170,955 | 57,512 | (1,540 | ) | 228,249 | |||||||||||||||
Operation and maintenance | 100 | 30,409 | 61,868 | (748 | ) | 91,629 | |||||||||||||||
Depreciation, depletion and amortization | 693 | 22,273 | 23,492 | | 46,458 | ||||||||||||||||
Property and other taxes | 538 | 3,347 | 13,953 | | 17,838 | ||||||||||||||||
Property write-downs and restructuring charges | | 333,022 | | | 333,022 | ||||||||||||||||
2,653 | 560,006 | 156,825 | (2,288 | ) | 717,196 | ||||||||||||||||
Operating Income (Loss) | (166 | ) | (326,778 | ) | 15,962 | | (310,982 | ) | |||||||||||||
Equity in Earnings (Losses) of Joint Ventures and Subsidiaries | (209,940 | ) | 11,859 | 361 | 209,557 | 11,837 | |||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||
Interest income | 9,527 | 971 | 822 | (9,505 | ) | 1,815 | |||||||||||||||
Interest on long-term debt | 162 | (9,073 | ) | (10,513 | ) | | (19,424 | ) | |||||||||||||
Other interest expense | (210 | ) | (12,163 | ) | (1,891 | ) | 9,442 | (4,822 | ) | ||||||||||||
Dividends on preferred securities of subsidiaries | | | | (9,230 | ) | (9,230 | ) | ||||||||||||||
Investment losses | | (6,135 | ) | | | (6,135 | ) | ||||||||||||||
Minority interest | | (34 | ) | (398 | ) | (203 | ) | (635 | ) | ||||||||||||
Other | (541 | ) | 1,025 | 585 | 203 | 1,272 | |||||||||||||||
8,938 | (25,409 | ) | (11,395 | ) | (9,293 | ) | (37,159 | ) | |||||||||||||
Income (Loss) Before Income Taxes | (201,168 | ) | (340,328 | ) | 4,928 | 200,264 | (336,304 | ) | |||||||||||||
Income Tax Provision (Benefit) | (360 | ) | (125,235 | ) | 1,914 | | (123,681 | ) | |||||||||||||
Net Income (Loss) | (201,808 | ) | (215,093 | ) | 3,014 | 200,264 | (212,623 | ) | |||||||||||||
Dividends on Preferred Securities | 9,230 | | | (9,230 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | (210,038 | ) | $ | (215,093 | ) | $ | 3,014 | $ | 209,494 | $ | (212,623 | ) | ||||||||
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MCN | Eliminations | ||||||||||||||||||||
and Other | and | Total | |||||||||||||||||||
Subsidiaries | MCNIC | MichCon | Reclasses | Consolidated | |||||||||||||||||
Six Months Ended June 30, 1999 | |||||||||||||||||||||
(in Thousands) | |||||||||||||||||||||
Operating Revenues | $ | 18,572 | $ | 591,479 | $ | 683,645 | $ | (8,326 | ) | $ | 1,285,370 | ||||||||||
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 and restructuring charges | | 52,000 | | | 52,000 | ||||||||||||||||
14,388 | 639,686 | 520,777 | (8,326 | ) | 1,166,525 | ||||||||||||||||
Operating Income (Loss) | 4,184 | (48,207 | ) | 162,868 | | 118,845 | |||||||||||||||
Equity in Earnings of Joint Ventures and Subsidiaries | 560 | 23,611 | 1,013 | (560 | ) | 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 | ) | ||||||||||||||
Loss on sale of E&P properties | | (68,798 | ) | | | (68,798 | ) | ||||||||||||||
Investment losses | | (7,456 | ) | | | (7,456 | ) | ||||||||||||||
Minority interest | | (216 | ) | (523 | ) | | (739 | ) | |||||||||||||
Other | (258 | ) | 10,346 | 287 | (1 | ) | 10,374 | ||||||||||||||
14,520 | (111,479 | ) | (24,618 | ) | (20,669 | ) | (142,246 | ) | |||||||||||||
Income (Loss) Before Income Taxes | 19,264 | (136,075 | ) | 139,263 | (21,229 | ) | 1,223 | ||||||||||||||
Income Tax Provision (Benefit) | (708 | ) | (47,369 | ) | 47,125 | (952 | ) | ||||||||||||||
Income (Loss) Before Cumulative Effect of Accounting Change | 19,972 | (88,706 | ) | 92,138 | (21,229 | ) | 2,175 | ||||||||||||||
Cumulative Effect of Accounting Change, Net of Taxes | | (2,872 | ) | | | (2,872 | ) | ||||||||||||||
Net Income (Loss) | 19,972 | (91,578 | ) | 92,138 | (21,229 | ) | (697 | ) | |||||||||||||
Dividends on Preferred Securities | 20,669 | | | (20,669 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | (697 | ) | $ | (91,578 | ) | $ | 92,138 | $ | (560 | ) | $ | (697 | ) | |||||||
Six Months Ended June 30, 1998 | |||||||||||||||||||||
Operating Revenues | $ | 8,669 | $ | 505,082 | $ | 602,014 | $ | (8,091 | ) | $ | 1,107,674 | ||||||||||
Operating Expenses | |||||||||||||||||||||
Cost of sales | 4,443 | 377,736 | 275,101 | (4,735 | ) | 652,545 | |||||||||||||||
Operation and maintenance | 240 | 65,529 | 124,090 | (3,356 | ) | 186,503 | |||||||||||||||
Depreciation, depletion and amortization | 1,339 | 43,971 | 45,937 | | 91,247 | ||||||||||||||||
Property and other taxes | 1,171 | 6,287 | 31,255 | | 38,713 | ||||||||||||||||
Write-down of E&P properties | | 333,022 | | | 333,022 | ||||||||||||||||
7,193 | 826,545 | 476,383 | (8,091 | ) | 1,302,030 | ||||||||||||||||
Operating Income (Loss) | 1,476 | (321,463 | ) | 125,631 | | (194,356 | ) | ||||||||||||||
Equity in Earnings (Losses) of Joint Ventures and Subsidiaries | (130,687 | ) | 28,166 | 950 | 130,169 | 28,598 | |||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||
Interest income | 19,572 | 4,165 | 1,934 | (19,508 | ) | 6,163 | |||||||||||||||
Interest on long-term debt | 403 | (15,637 | ) | (22,719 | ) | | (37,953 | ) | |||||||||||||
Other interest expense | (659 | ) | (25,403 | ) | (5,148 | ) | 19,547 | (11,663 | ) | ||||||||||||
Dividends on preferred securities of subsidiaries | | | | (18,984 | ) | (18,984 | ) | ||||||||||||||
Loss on sale of E&P properties | | | | | | ||||||||||||||||
Investment losses | | (6,135 | ) | (6,135 | ) | ||||||||||||||||
Minority interest | (102 | ) | (1,143 | ) | (1,245 | ) | |||||||||||||||
Other | (507 | ) | 13,762 | 706 | | 13,961 | |||||||||||||||
18,809 | (29,350 | ) | (26,370 | ) | (18,945 | ) | (55,856 | ) | |||||||||||||
Income (Loss) Before Income Taxes | (110,402 | ) | (322,647 | ) | 100,211 | 111,224 | (221,614 | ) | |||||||||||||
Income Tax Provision (Benefit) | 244 | (123,650 | ) | 35,533 | | (87,873 | ) | ||||||||||||||
Net Income (Loss) | (110,646 | ) | (198,997 | ) | 64,678 | 111,224 | (133,741 | ) | |||||||||||||
Dividends on Preferred Securities | 18,984 | | | (18,984 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | (129,630 | ) | $ | (198,997 | ) | $ | 64,678 | $ | 130,208 | $ | (133,741 | ) | ||||||||
38
CONSOLIDATING STATEMENTS OF OPERATIONS (Unaudited)
MCN | Eliminations | ||||||||||||||||||||
and Other | and | Consolidated | |||||||||||||||||||
Subsidiaries | MCNIC | MichCon | Reclasses | Total | |||||||||||||||||
Twelve Months Ended June 30, 1999 | |||||||||||||||||||||
(in Thousands) | |||||||||||||||||||||
Operating Revenues | $ | 28,165 | $ | 1,079,225 | $ | 1,115,289 | $ | (14,285 | ) | $ | 2,208,394 | ||||||||||
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 and restructuring charges | 8,669 | 277,827 | 24,800 | | 311,296 | ||||||||||||||||
21,288 | 1,372,601 | 921,441 | (14,285 | ) | 2,301,045 | ||||||||||||||||
Operating Income (Loss) | 6,877 | (293,376 | ) | 193,848 | | (92,651 | ) | ||||||||||||||
Equity in Earnings (Losses) of Joint Ventures and Subsidiaries | (143,524 | ) | 56,687 | 2,009 | 143,079 | 58,251 | |||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||
Interest income | 20,708 | 4,432 | 5,699 | (22,244 | ) | 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 | ) | ||||||||||||||
Loss on sale of E&P properties | | (68,798 | ) | | | (68,798 | ) | ||||||||||||||
Investment losses | (8,500 | ) | (7,456 | ) | | | (15,956 | ) | |||||||||||||
Minority interest | | 151 | 6,347 | | 6,498 | ||||||||||||||||
Other | (356 | ) | 16,932 | (601 | ) | (1 | ) | 15,974 | |||||||||||||
2,142 | (151,493 | ) | (44,012 | ) | (19,236 | ) | (212,699 | ) | |||||||||||||
Income (Loss) Before Income Taxes | (134,505 | ) | (388,182 | ) | 151,845 | 123,743 | (247,099 | ) | |||||||||||||
Income Tax Provision (Benefit) | (3,781 | ) | (140,175 | ) | 47,409 | | (96,547 | ) | |||||||||||||
Income (Loss) Before Cumulative Effect of Accounting Change | (130,724 | ) | (248,007 | ) | 104,436 | 123,743 | (150,552 | ) | |||||||||||||
Cumulative Effect of Accounting Change, Net of Taxes | | (2,872 | ) | | | (2,872 | ) | ||||||||||||||
Net Income (Loss) | (130,724 | ) | (250,879 | ) | 104,436 | 123,743 | (153,424 | ) | |||||||||||||
Dividends on Preferred Securities | 38,055 | | | (38,055 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | (168,779 | ) | $ | (250,879 | ) | $ | 104,436 | $ | 161,798 | $ | (153,424 | ) | ||||||||
Twelve Months Ended June 30, 1998 | |||||||||||||||||||||
Operating Revenues | $ | 16,186 | $ | 1,019,010 | $ | 1,118,448 | $ | (14,789 | ) | $ | 2,138,855 | ||||||||||
Operating Expenses | |||||||||||||||||||||
Cost of gas | 8,763 | 761,742 | 521,026 | (9,279 | ) | 1,282,252 | |||||||||||||||
Operation and maintenance | 1,865 | 126,572 | 263,231 | (5,510 | ) | 386,158 | |||||||||||||||
Depreciation, depletion and amortization | 2,491 | 83,712 | 97,715 | | 183,918 | ||||||||||||||||
Property and other taxes | 1,821 | 13,091 | 58,064 | | 72,976 | ||||||||||||||||
Property write-downs and restructuring charges | | 333,022 | | | 333,022 | ||||||||||||||||
14,940 | 1,318,139 | 940,036 | (14,789 | ) | 2,258,326 | ||||||||||||||||
Operating Income | 1,246 | (299,129 | ) | 178,412 | | (119,471 | ) | ||||||||||||||
Equity in Earnings (Losses) of Joint Ventures and Subsidiaries | (77,835 | ) | 58,038 | 1,508 | 77,715 | 59,426 | |||||||||||||||
Other Income and (Deductions) | |||||||||||||||||||||
Interest income | 40,507 | 8,729 | 4,107 | (40,390 | ) | 12,953 | |||||||||||||||
Interest on long-term debt | 599 | (27,740 | ) | (45,931 | ) | | (73,072 | ) | |||||||||||||
Other interest expense | (1,414 | ) | (46,562 | ) | (9,063 | ) | 40,717 | (16,322 | ) | ||||||||||||
Dividends on preferred securities of subsidiaries | | | | (38,516 | ) | (38,516 | ) | ||||||||||||||
Investment loss | | (6,135 | ) | | | (6,135 | ) | ||||||||||||||
Minority interest | | (150 | ) | (2,092 | ) | | (2,242 | ) | |||||||||||||
Other | (406 | ) | 21,201 | 1,345 | | 22,140 | |||||||||||||||
39,286 | (50,657 | ) | (51,634 | ) | (38,189 | ) | (101,194 | ) | |||||||||||||
Income (Loss) Before Income Taxes | (37,303 | ) | (291,748 | ) | 128,286 | 39,526 | (161,239 | ) | |||||||||||||
Income Tax Provision (Benefit) | 1,251 | (122,590 | ) | 47,712 | | (73,627 | ) | ||||||||||||||
Net Income (Loss) | (38,554 | ) | (169,158 | ) | 80,574 | 39,526 | (87,612 | ) | |||||||||||||
Dividends on Preferred Securities | 38,516 | | | (38,516 | ) | | |||||||||||||||
Net Income (Loss) Available for Common Stock | $ | (77,070 | ) | $ | (169,158 | ) | $ | 80,574 | $ | 78,042 | $ | (87,612 | ) | ||||||||
39
CONSOLIDATING STATEMENT OF FINANCIAL POSITION (Unaudited)
MCN | Eliminations | |||||||||||||||||||||
and Other | and | Consolidated | ||||||||||||||||||||
Subsidiaries | MCNIC | 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 | | 78,644 | 43,892 | | 122,536 | |||||||||||||||||
Property taxes assessed applicable to future periods | 170 | 1,952 | 48,473 | | 50,595 | |||||||||||||||||
Other | 4,555 | 58,586 | 34,512 | (51,234 | ) | 46,419 | ||||||||||||||||
12,359 | 339,257 | 300,019 | (64,845 | ) | 586,790 | |||||||||||||||||
Deferred Charges and Other Assets | ||||||||||||||||||||||
Deferred income taxes | 10,660 | 120,966 | | (103,490 | ) | 28,136 | ||||||||||||||||
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 | 219,230 | 295,954 | (100,721 | ) | 441,699 | |||||||||||||||||
Investments in and Advances to Joint Ventures and Subsidiaries | 1,526,376 | 843,517 | 19,853 | (1,524,398 | ) | 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 | ||||||||||||||||||
$ | 1,596,039 | $ | 2,025,848 | $ | 2,112,715 | $ | (1,689,964 | ) | $ | 4,044,638 | ||||||||||||
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 | | 193 | 22,774 | | 22,967 | |||||||||||||||||
Federal income, property and other taxes payable | (387 | ) | 2,450 | 86,097 | (44,959 | ) | 43,201 | |||||||||||||||
Deferred gas cost recovery revenues | | | | | | |||||||||||||||||
Gas payable | | 18,003 | 20,845 | | 38,848 | |||||||||||||||||
Customer deposits | 26 | | 15,830 | | 15,856 | |||||||||||||||||
Interest payable | 1,486 | 11,680 | 9,250 | | 22,416 | |||||||||||||||||
Other | 13,833 | 17,007 | 33,875 | (2,580 | ) | 62,135 | ||||||||||||||||
177,546 | 380,716 | 352,787 | (59,675 | ) | 851,374 | |||||||||||||||||
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 | 1,080,379 | 230,399 | (1,310,778 | ) | 966,956 | ||||||||||||||||
Retained earnings (deficit) | (45,400 | ) | (276,967 | ) | 480,605 | (203,638 | ) | (45,400 | ) | |||||||||||||
Accumulated other comprehensive loss | | (13,505 | ) | | | (13,505 | ) | |||||||||||||||
Yield enhancement, contract and issuance costs | (22,288 | ) | | | | (22,288 | ) | |||||||||||||||
900,123 | 789,912 | 721,304 | (1,524,721 | ) | 886,618 | |||||||||||||||||
$ | 1,596,039 | $ | 2,025,848 | $ | 2,112,715 | $ | (1,689,964 | ) | $ | 4,044,638 | ||||||||||||
40
CONSOLIDATING STATEMENT OF FINANCIAL POSITION (Unaudited)
MCN | Eliminations | |||||||||||||||||||||
and Other | and | Consolidated | ||||||||||||||||||||
Subsidiaries | MCNIC | MichCon | Reclasses | Total | ||||||||||||||||||
June 30, 1998 | ||||||||||||||||||||||
(in Thousands) | ||||||||||||||||||||||
ASSETS | ||||||||||||||||||||||
Current Assets | ||||||||||||||||||||||
Cash and cash equivalents, at cost | $ | 53 | $ | 60,914 | $ | 20,032 | $ | | $ | 80,999 | ||||||||||||
Accounts receivable | 16,343 | 193,634 | 150,380 | (18,022 | ) | 342,335 | ||||||||||||||||
Less Allowance for doubtful accounts | 97 | 453 | 14,132 | | 14,682 | |||||||||||||||||
Accounts receivable, net | 16,246 | 193,181 | 136,248 | (18,022 | ) | 327,653 | ||||||||||||||||
Accrued unbilled revenues | 225 | | 15,500 | | 15,725 | |||||||||||||||||
Gas in inventory | | 68,054 | 35,617 | | 103,671 | |||||||||||||||||
Property taxes assessed applicable to future periods | 98 | 1,276 | 43,152 | | 44,526 | |||||||||||||||||
Other | 2,815 | 45,819 | 28,408 | (70 | ) | 76,972 | ||||||||||||||||
19,437 | 369,244 | 278,957 | (18,092 | ) | 649,546 | |||||||||||||||||
Deferred Charges and Other Assets | ||||||||||||||||||||||
Investments in debt and equity securities | | 12,084 | 36,532 | 351 | 48,967 | |||||||||||||||||
Deferred swap losses and receivables | | 63,123 | | | 63,123 | |||||||||||||||||
Deferred environmental costs | 2,534 | | 27,934 | | 30,468 | |||||||||||||||||
Prepaid benefit costs | 630 | | 95,008 | (6,927 | ) | 88,711 | ||||||||||||||||
Other | 8,956 | 32,424 | 52,612 | (2,955 | ) | 91,037 | ||||||||||||||||
12,120 | 107,631 | 212,086 | (9,531 | ) | 322,306 | |||||||||||||||||
Investments in and Advances to Joint Ventures and Subsidiaries | 1,374,445 | 667,961 | 20,436 | (1,365,624 | ) | 697,218 | ||||||||||||||||
Property, Plant and Equipment, at cost | 42,928 | 1,192,544 | 2,843,708 | | 4,079,180 | |||||||||||||||||
Less Accumulated depreciation and depletion | 14,274 | 191,267 | 1,356,842 | | 1,562,383 | |||||||||||||||||
28,654 | 1,001,277 | 1,486,866 | | 2,516,797 | ||||||||||||||||||
$ | 1,434,656 | $ | 2,146,113 | $ | 1,998,345 | $ | (1,393,247 | ) | $ | 4,185,867 | ||||||||||||
LIABILITIES AND SHAREHOLDERS EQUITY | ||||||||||||||||||||||
Current Liabilities | ||||||||||||||||||||||
Accounts payable | $ | 6,752 | $ | 240,244 | $ | 89,329 | $ | (18,432 | ) | $ | 317,893 | |||||||||||
Notes payable | | 147,822 | 4,067 | (2,192 | ) | 149,697 | ||||||||||||||||
Current portion of long-term debt and capital lease obligations | | 211,486 | 58,204 | | 269,690 | |||||||||||||||||
Gas inventory equalization | | 12 | 15,478 | | 15,490 | |||||||||||||||||
Federal income, property and other taxes payable | 543 | (2,098 | ) | 80,931 | | 79,376 | ||||||||||||||||
Deferred gas cost recovery revenues | | | 29,139 | | 29,139 | |||||||||||||||||
Gas payable | | 13,279 | 26,998 | | 40,277 | |||||||||||||||||
Customer deposits | 24 | | 14,900 | | 14,924 | |||||||||||||||||
Interest payable | 1,686 | 17,032 | 10,355 | | 29,073 | |||||||||||||||||
Other | 5,860 | 5,317 | 26,886 | (29 | ) | 38,034 | ||||||||||||||||
14,865 | 633,094 | 356,287 | (20,653 | ) | 983,593 | |||||||||||||||||
Deferred Credits and Other Liabilities | ||||||||||||||||||||||
Deferred income taxes | (4,549 | ) | (41,824 | ) | 89,549 | | 43,176 | |||||||||||||||
Unamortized investment tax credit | 286 | | 31,823 | | 32,109 | |||||||||||||||||
Tax benefits amortizable to customers | | | 123,444 | | 123,444 | |||||||||||||||||
Deferred swap gains and payables | | 50,014 | | | 50,014 | |||||||||||||||||
Accrued environmental costs | 3,000 | | 32,000 | | 35,000 | |||||||||||||||||
Minority interest | | 2,565 | 16,600 | 1 | 19,166 | |||||||||||||||||
Other | 17,063 | 61,438 | 43,926 | (6,929 | ) | 115,498 | ||||||||||||||||
15,800 | 72,193 | 337,342 | (6,928 | ) | 418,407 | |||||||||||||||||
Long-Term Debt, including capital lease obligations | | 781,238 | 624,014 | | 1,405,252 | |||||||||||||||||
Redeemable Preferred Securities of Subsidiaries | 405,428 | | | | 405,428 | |||||||||||||||||
Common Shareholders Equity | ||||||||||||||||||||||
Common stock | 789 | 5 | 10,300 | (10,305 | ) | 789 | ||||||||||||||||
Additional paid-in capital | 816,285 | 697,823 | 230,399 | (928,221 | ) | 816,286 | ||||||||||||||||
Retained earnings | 203,777 | (26,092 | ) | 440,003 | (427,140 | ) | 190,548 | |||||||||||||||
Accumulated other comprehensive loss | | (12,148 | ) | | | (12,148 | ) | |||||||||||||||
Yield enhancement, contract and issuance costs | (22,288 | ) | | | | (22,288 | ) | |||||||||||||||
998,563 | 659,588 | 680,702 | (1,365,666 | ) | 973,187 | |||||||||||||||||
$ | 1,434,656 | $ | 2,146,113 | $ | 1,998,345 | $ | (1,393,247 | ) | $ | 4,185,867 | ||||||||||||
41
CONSOLIDATING STATEMENT OF FINANCIAL POSITION (Unaudited)
MCN | Eliminations | |||||||||||||||||||||
and Other | and | Consolidated | ||||||||||||||||||||
Subsidiaries | MCNIC | MichCon | Reclasses | Total | ||||||||||||||||||
December 31, 1998 | ||||||||||||||||||||||
(in Thousands) | ||||||||||||||||||||||
ASSETS | ||||||||||||||||||||||
Current Assets | ||||||||||||||||||||||
Cash and cash equivalents, at cost | $ | 1,400 | $ | 9,036 | $ | 6,603 | $ | | $ | 17,039 | ||||||||||||
Accounts receivable | 10,039 | 265,312 | 151,746 | (17,312 | ) | 409,785 | ||||||||||||||||
Less Allowance for doubtful accounts | 84 | 653 | 8,928 | | 9,665 | |||||||||||||||||
Accounts receivable, net | 9,955 | 264,659 | 142,818 | (17,312 | ) | 400,120 | ||||||||||||||||
Accrued unbilled revenues | 1,121 | | 86,767 | | 87,888 | |||||||||||||||||
Gas in inventory | | 90,418 | 56,969 | | 147,387 | |||||||||||||||||
Property taxes assessed applicable to future periods | 214 | 1,172 | 71,165 | | 72,551 | |||||||||||||||||
Other | 5,143 | 11,872 | 30,169 | (4,712 | ) | 42,472 | ||||||||||||||||
17,833 | 377,157 | 394,491 | (22,024 | ) | 767,457 | |||||||||||||||||
Deferred Charges and Other Assets | ||||||||||||||||||||||
Deferred income taxes | 3,305 | 128,807 | | (81,565 | ) | 50,547 | ||||||||||||||||
Investments in debt and equity securities | | 3,548 | 65,556 | 601 | 69,705 | |||||||||||||||||
Deferred swap losses and receivables | | 63,147 | | | 63,147 | |||||||||||||||||
Deferred environmental costs | 2,604 | | 28,169 | | 30,773 | |||||||||||||||||
Prepaid benefit costs | | | 113,879 | (2,104 | ) | 111,775 | ||||||||||||||||
Other | 9,401 | 26,870 | 59,007 | 3,662 | 98,940 | |||||||||||||||||
15,310 | 222,372 | 266,611 | (79,406 | ) | 424,887 | |||||||||||||||||
Investments in and Advances to Joint Ventures and Subsidiaries | 1,550,770 | 782,471 | 19,343 | (1,549,353 | ) | 803,231 | ||||||||||||||||
Property, Plant and Equipment, at cost | 48,681 | 1,103,716 | 2,889,020 | | 4,041,417 | |||||||||||||||||
Less Accumulated depreciation and depletion | 17,210 | 229,944 | 1,396,940 | | 1,644,094 | |||||||||||||||||
31,471 | 873,772 | 1,492,080 | | 2,397,323 | ||||||||||||||||||
$ | 1,615,384 | $ | 2,255,772 | $ | 2,172,525 | $ | (1,650,783 | ) | $ | 4,392,898 | ||||||||||||
LIABILITIES AND SHAREHOLDERS EQUITY | ||||||||||||||||||||||
Current Liabilities | ||||||||||||||||||||||
Accounts payable | $ | 4,123 | $ | 218,851 | $ | 98,891 | $ | (17,516 | ) | $ | 304,349 | |||||||||||
Notes payable | 260,771 | 137,762 | 221,169 | (851 | ) | 618,851 | ||||||||||||||||
Current portion of long-term debt and capital lease obligations | | 211,433 | 58,288 | | 269,721 | |||||||||||||||||
Federal income, property and other taxes payable | 1,441 | 6,965 | 61,059 | | 69,465 | |||||||||||||||||
Deferred gas cost recovery revenues | | | 14,980 | | 14,980 | |||||||||||||||||
Gas payable | | 17,332 | 25,337 | | 42,669 | |||||||||||||||||
Customer deposits | 22 | | 18,769 | | 18,791 | |||||||||||||||||
Interest payable | 2,835 | 16,519 | 10,960 | | 30,314 | |||||||||||||||||
Other | 15,502 | 8,757 | 56,262 | (2,525 | ) | 77,996 | ||||||||||||||||
284,694 | 617,619 | 565,715 | (20,892 | ) | 1,447,136 | |||||||||||||||||
Deferred Credits and Other Liabilities | ||||||||||||||||||||||
Deferred income taxes | (10,308 | ) | | 88,567 | (78,259 | ) | | |||||||||||||||
Unamortized investment tax credit | 272 | | 29,784 | | 30,056 | |||||||||||||||||
Tax benefits amortizable to customers | | | 130,120 | | 130,120 | |||||||||||||||||
Deferred swap gains and payables | | 62,956 | | | 62,956 | |||||||||||||||||
Accrued environmental costs | 3,000 | | 32,000 | | 35,000 | |||||||||||||||||
Minority interest | | 2,697 | 8,201 | | 10,898 | |||||||||||||||||
Other | 10,435 | 15,741 | 51,460 | (2,197 | ) | 75,439 | ||||||||||||||||
3,399 | 81,394 | 340,132 | (80,456 | ) | 344,469 | |||||||||||||||||
Long-Term Debt, including capital lease obligations | | 687,333 | 619,835 | | 1,307,168 | |||||||||||||||||
Redeemable Preferred Securities of Subsidiaries | 502,203 | | | | 502,203 | |||||||||||||||||
Common Shareholders Equity | ||||||||||||||||||||||
Common stock | 797 | 5 | 10,300 | (10,305 | ) | 797 | ||||||||||||||||
Additional paid-in capital | 832,966 | 1,071,390 | 230,399 | (1,301,789 | ) | 832,966 | ||||||||||||||||
Retained earnings (deficit) | 13,613 | (185,393 | ) | 406,144 | (237,341 | ) | (2,977 | ) | ||||||||||||||
Accumulated other comprehensive loss | | (16,576 | ) | | | (16,576 | ) | |||||||||||||||
Yield enhancement, contract and issuance costs | (22,288 | ) | | | | (22,288 | ) | |||||||||||||||
825,088 | 869,426 | 646,843 | (1,549,435 | ) | 791,922 | |||||||||||||||||
$ | 1,615,384 | $ | 2,255,772 | $ | 2,172,525 | $ | (1,650,783 | ) | $ | 4,392,898 | ||||||||||||
42
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS (Concluded)
MCN | Eliminations | |||||||||||||||||||||
and Other | and | Consolidated | ||||||||||||||||||||
Subsidiaries | MCNIC | MichCon | Reclasses | Total | ||||||||||||||||||
(in Thousands) | ||||||||||||||||||||||
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 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 | | (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 | |||||||||||||||||
Return of investment in joint ventures | | 1,193 | | | 1,193 | |||||||||||||||||
Other | 200 | (7,512 | ) | (558 | ) | 987 | (6,883 | ) | ||||||||||||||
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 | ||||||||||||
Six Months Ended June 30, 1998 | ||||||||||||||||||||||
Net Cash Flow From Operating Activities | $ | 19,014 | $ | (11,058 | ) | $ | 286,618 | $ | (19,354 | ) | $ | 275,220 | ||||||||||
Cash Flow From Financing Activities | ||||||||||||||||||||||
Notes payable, net | | 75,066 | (237,624 | ) | 886 | (161,672 | ) | |||||||||||||||
Capital contributions paid to affiliates, net | | (136,716 | ) | | 136,716 | | ||||||||||||||||
Dividends paid | (41,441 | ) | | | | (41,441 | ) | |||||||||||||||
Preferred securities dividends paid | (18,984 | ) | | | 18,984 | | ||||||||||||||||
Issuance of common stock | 10,374 | | | | 10,374 | |||||||||||||||||
Issuance of long-term debt | | 307,109 | 153,052 | | 460,161 | |||||||||||||||||
Long-term commercial paper, net | | 109,643 | | | 109,643 | |||||||||||||||||
Retirement of long-term debt | (100,365 | ) | (100,826 | ) | (122,263 | ) | | (323,454 | ) | |||||||||||||
Other | 263 | 8,243 | | | 8,506 | |||||||||||||||||
Net cash provided from (used for) financing activities | (150,153 | ) | 262,519 | (206,835 | ) | 156,586 | 62,117 | |||||||||||||||
Cash Flow From Investing Activities | ||||||||||||||||||||||
Capital expenditures | (5,164 | ) | (197,988 | ) | (74,503 | ) | | (277,655 | ) | |||||||||||||
Acquisitions | | (36,731 | ) | | | (36,731 | ) | |||||||||||||||
Investment in debt and equity securities | | 45,663 | (1,422 | ) | | 44,241 | ||||||||||||||||
Investment in joint ventures and subsidiaries | 136,216 | (96,161 | ) | 12 | (136,714 | ) | (96,647 | ) | ||||||||||||||
Sale of property and joint venture interests | | 81,026 | | | 81,026 | |||||||||||||||||
Return of investment in joint ventures | | 4,801 | | | 4,801 | |||||||||||||||||
Other | 117 | (16,276 | ) | 1,809 | (518 | ) | (14,868 | ) | ||||||||||||||
Net cash provided from (used for) investing activities | 131,169 | (215,666 | ) | (74,104 | ) | (137,232 | ) | (295,833 | ) | |||||||||||||
Net Increase (Decrease) in Cash and Cash Equivalents | 30 | 35,795 | 5,679 | | 41,504 | |||||||||||||||||
Cash and Cash Equivalents, January 1 | 23 | 25,119 | 14,353 | | 39,495 | |||||||||||||||||
Cash and Cash Equivalents, June 30 | $ | 53 | $ | 60,914 | $ | 20,032 | $ | | $ | 80,999 | ||||||||||||
43
Supplementary Information for Gas and Oil Producing Activities (Unaudited)
In December 1998, MCN accounted for its E&P segment as a discontinued operation as a result of its decision to sell all of its gas and oil properties. In August 1999, MCN announced a significantly revised strategic direction. Consistent with this revised strategy, as well as the result of the lowering of the bid for the Michigan E&P properties, MCN will now retain its natural gas producing properties in Michigan and continue selling its other E&P oil and gas properties. Accordingly, E&Ps operating results have been reclassified from discontinued operations to continuing operations. Refer to Managements Discussion and Analysis and Note 6 to the Consolidated Financial Statements, included herein, for additional information regarding the E&P segment and managements decision to retain the properties in Michigan. The following information is prepared in accordance with SFAS No. 69, Disclosures About Oil and Gas Producing Activities and related Securities and Exchange Commission (SEC) accounting rules. The information, as of or for the years ended December 31, would have been provided in MCNs 1998 Annual Report on Form 10-K/ A if the E&P segment had not been classified as a discontinued operation.
MCNIC Oil & Gas Company (MOG), an indirect subsidiary of MCN, is engaged in natural gas and oil exploration, development and production. The full cost accounting method prescribed by the SEC is followed for investments in gas and oil properties. Under the full cost method, substantially all acquisition, exploration and development costs are capitalized.
The unit of production method is used for calculating depreciation, depletion and amortization (DD&A) on proved gas and oil properties. The average DD&A expense per thousand cubic feet equivalent was $.82, $.75 and $.70 in 1998, 1997 and 1996, respectively. Costs directly associated with the acquisition and evaluation of unproved gas and oil properties are excluded from the amortization base until the related properties are evaluated. Such unproved properties are assessed periodically, and a provision for impairment is made when appropriate.
Capitalized Costs
1998 | 1997 | |||||||
(in Thousands) | ||||||||
Proved Properties | $ | 1,357,413 | $ | 1,033,492 | ||||
Unproved Properties | 99,611 | 265,809 | ||||||
1,457,024 | 1,299,301 | |||||||
SEC Ceiling Test Write-downs (Note 2c) | 416,977 | | ||||||
Accumulated Depreciation, Depletion and Amortization | 224,795 | 150,015 | ||||||
Net Capitalized Costs | $ | 815,252 | $ | 1,149,286 | ||||
44
Capitalized Costs Excluded From Amortization
Unproved properties held by MCN are excluded from amortization until they have been evaluated. A summary of costs excluded from amortization at December 31, 1998, and the year in which they were incurred, follows:
Year Costs Incurred | ||||||||||||||||||||
1995 & | ||||||||||||||||||||
Total | 1998 | 1997 | 1996 | Prior | ||||||||||||||||
(in Thousands) | ||||||||||||||||||||
Acquisition | $ | 43,131 | $ | 14,254 | $ | 17,119 | $ | 9,321 | $ | 2,439 | ||||||||||
Exploration | 56,480 | 13,757 | 32,655 | 9,935 | 132 | |||||||||||||||
$ | 99,611 | $ | 28,011 | $ | 49,774 | $ | 19,256 | $ | 2,571 | |||||||||||
The acquisition amount includes all costs incurred to purchase or lease property with unproved reserves.
Cost Incurred
1998 | 1997 | 1996 | |||||||||||
(in Thousands) | |||||||||||||
Acquisition: | |||||||||||||
Proved properties | $ | 53,377 | $ | 35,695 | $ | 60,340 | |||||||
Unproved properties | 7,498 | 66,721 | 136,142 | ||||||||||
60,875 | 102,416 | 196,482 | |||||||||||
Exploration | 52,948 | 143,580 | 65,160 | ||||||||||
Development | 86,607 | 129,001 | 120,569 | ||||||||||
$ | 200,430 | $ | 374,997 | $ | 382,211 | ||||||||
Results of Operations
1998 | 1997 | 1996 | |||||||||||
(in Thousands) | |||||||||||||
Operating Revenues: | |||||||||||||
Unaffiliated customers | $ | 150,504 | $ | 144,041 | $ | 94,615 | |||||||
Affiliated customers | 56,598 | 71,787 | 43,326 | ||||||||||
207,102 | 215,828 | 137,941 | |||||||||||
Production Costs | 79,245 | 68,364 | 48,255 | ||||||||||
SEC Ceiling Test Write-downs | 416,977 | | | ||||||||||
Depreciation, Depletion and Amortization | 80,576 | 73,910 | 44,469 | ||||||||||
576,798 | 142,274 | 92,724 | |||||||||||
Income (Loss) Before Income Taxes | (369,696 | ) | 73,554 | 45,217 | |||||||||
Income Taxes: | |||||||||||||
Income tax provision (benefit) | (129,698 | ) | 26,997 | 16,438 | |||||||||
Gas production tax credits | (10,485 | ) | (17,797 | ) | (15,878 | ) | |||||||
(140,183 | ) | 9,200 | 560 | ||||||||||
Results of Operations, Excluding Corporate And Interest Costs | $ | (229,513 | ) | $ | 64,354 | $ | 44,657 | ||||||
Reserve Quantity Information
MCNs proved reserves are located in the United States. Information on estimated gas and oil reserves that follows was obtained by MOG from the independent petroleum engineering
45
consultants Ryder Scott Company, Miller and Lents, Ltd., S.A. Holditch & Associates, Netherland, Sewell & Associates, Inc., and Williamson Petroleum Consultants, Inc.
1998 | 1997 | |||||||||||||||||
Gas | Oil | Gas | Oil | |||||||||||||||
(MMcf) | (MBbl) | (MMcf) | (MBbl) | |||||||||||||||
Proved Developed and Undeveloped Reserves: | ||||||||||||||||||
Beginning of year | 1,166,174 | 25,843 | 1,137,729 | 17,214 | ||||||||||||||
Revisions of previous estimates | (66,188 | ) | (2,865 | ) | (30,260 | ) | (430 | ) | ||||||||||
Extensions and discoveries | 59,729 | 534 | 165,283 | 4,435 | ||||||||||||||
Production | (82,040 | ) | (2,635 | ) | (78,218 | ) | (3,346 | ) | ||||||||||
Sales of minerals in place | (37,661 | ) | (8,389 | ) | (51,465 | ) | (1,019 | ) | ||||||||||
Purchases of minerals in place | 52,959 | 499 | 23,105 | 8,989 | ||||||||||||||
End of year | 1,092,973 | 12,987 | 1,166,174 | 25,843 | ||||||||||||||
Proved Developed Reserves: | ||||||||||||||||||
Beginning of year | 590,299 | 12,601 | 688,995 | 9,554 | ||||||||||||||
End of year | 630,130 | 6,367 | 590,299 | 12,601 |
Standardized Measure of Discounted Future Net Cash Flows
The following presentation of the standardized measure of discounted future net cash flows is intended to be neither a measure of the fair market value of MCNs gas and oil properties, nor an estimate of the present value of actual future cash flows to be obtained as a result of their development and production. It is based upon subjective estimates of proved reserves only and attributes no value to categories of reserves other than proved reserves, such as probable or possible reserves, or to unproved acreage. Furthermore, as it is based on year-end prices and costs adjusted only for existing contractual arrangements and assumes an arbitrary annual discount rate of 10%, it does not reflect the impact of future price and cost changes. Future income tax expenses were computed by applying statutory tax rates, adjusted for permanent differences and tax credits, to estimated future pre-tax net cash flows.
The standardized measure is intended to provide a better means for comparing the value of MCNs proved reserves at a given time with those of other gas and oil producing companies than is provided by a simple comparison of raw proved reserve quantities.
1998 | 1997 | 1996 | ||||||||||
(in Thousands) | ||||||||||||
Future Revenues | $ | 2,795,786 | $ | 3,121,124 | $ | 3,867,785 | ||||||
Future Production Costs | 984,042 | 1,155,734 | 1,322,108 | |||||||||
Future Development Costs | 264,631 | 328,739 | 340,190 | |||||||||
Future Net Cash Flows Before Income Taxes | 1,547,113 | 1,636,651 | 2,205,487 | |||||||||
Discount to Present Value at 10% | 806,746 | 812,605 | 1,139,507 | |||||||||
Present Value of Future Net Cash Flows Before Income Taxes | 740,367 | 824,046 | 1,065,980 | |||||||||
Future Income Taxes Discounted at 10% | | 105,371 | 226,913 | |||||||||
Future Tax Credits Discounted at 10% | | (50,889 | ) | (62,207 | ) | |||||||
Standardized Measure of Discounted Future Net Cash Flows | $ | 740,367 | $ | 769,564 | $ | 901,274 | ||||||
Future income taxes and tax credits have been excluded from the 1998 calculation since MOG is in a net operating loss position, and it is more likely than not that these tax benefits would not be realized by MOG on a stand-alone basis. However, MCN files a consolidated federal income tax return, which includes the taxable income or loss of MOG as well as MOGs tax credits.
46
Accordingly, it is managements opinion that any tax benefits earned by MOG will be utilized by MCN in its consolidated tax returns.
The principal sources of change in the standardized measure of discounted future net cash flows were as follows:
1998 | 1997 | 1996 | |||||||||||
(in Thousands) | |||||||||||||
Beginning of Year | $ | 769,564 | $ | 901,274 | $ | 521,907 | |||||||
Net changes in sales prices and production costs | (67,085 | ) | (261,154 | ) | 126,526 | ||||||||
Net change due to revisions in quantity estimates | (59,106 | ) | (26,015 | ) | 5,061 | ||||||||
Extensions, discoveries, additions and improved recovery, net of related costs | 46,739 | 153,291 | 200,026 | ||||||||||
Development costs incurred, previously estimated | 86,607 | 103,201 | 86,810 | ||||||||||
Changes in estimated future development costs | (26,573 | ) | (120,219 | ) | (81,069 | ) | |||||||
Net change in future income taxes | 105,371 | 116,366 | (85,616 | ) | |||||||||
Net change in federal tax credits | (41,997 | ) | (17,797 | ) | (15,878 | ) | |||||||
Sales of reserves in place | (56,924 | ) | (83,985 | ) | | ||||||||
Purchases of reserves in place | 41,525 | 48,685 | 193,550 | ||||||||||
Accretion of discount and other | 70,103 | 103,381 | 39,643 | ||||||||||
End of Year | $ | 740,367 | $ | 769,564 | $ | 901,274 | |||||||
Additional data relating to E&P activities follows:
1998 | 1997 | 1996 | ||||||||||
Production | ||||||||||||
Average Gas Sales Price (per Mcf) | $ | 2.04 | $ | 1.95 | $ | 1.96 | ||||||
Average Oil Sales Price (per Bbl) | $ | 12.58 | $ | 16.87 | $ | 20.18 | ||||||
Average Production Cost (per Mcf equivalent) | $ | .81 | $ | .70 | $ | .76 |
1998 | 1997 | 1996 | ||||||||||||||||||||||||
Gross | Net | Gross | Net | Gross | Net | |||||||||||||||||||||
Drilling Activity | ||||||||||||||||||||||||||
Working Interest Well Completions: | ||||||||||||||||||||||||||
Exploratory: | ||||||||||||||||||||||||||
Productive | 58 | 26 | 63 | 30 | 63 | 28 | ||||||||||||||||||||
Dry | 37 | 14 | 39 | 19 | 37 | 15 | ||||||||||||||||||||
Total Exploratory | 95 | 40 | 102 | 49 | 100 | 43 | ||||||||||||||||||||
Development: | ||||||||||||||||||||||||||
Productive | 536 | 335 | 574 | 354 | 355 | 230 | ||||||||||||||||||||
Dry | 15 | 6 | 20 | 9 | 12 | 6 | ||||||||||||||||||||
Total Development | 551 | 341 | 594 | 363 | 367 | 236 | ||||||||||||||||||||
Total Working Interest Well Completions | 646 | 381 | 696 | 412 | 467 | 279 | ||||||||||||||||||||
Wells in Process of Drilling at End of Year | 77 | 30 | 150 | 92 | 167 | 108 | ||||||||||||||||||||
1998 | 1997 | 1996 | ||||||||||||||||||||||
Gross | Net | Gross | Net | Gross | Net | |||||||||||||||||||
Producing Wells and Acreage | ||||||||||||||||||||||||
Producing Wells | ||||||||||||||||||||||||
United States | 3,143 | 1,782 | 2,917 | 1,677 | 2,890 | 1,481 | ||||||||||||||||||
Developed Lease Acreage | ||||||||||||||||||||||||
United States | 623,076 | 352,315 | 663,767 | 344,818 | 519,107 | 287,964 | ||||||||||||||||||
Undeveloped Lease Acreage | ||||||||||||||||||||||||
United States | 2,693,767 | 1,148,920 | 2,592,915 | 1,239,908 | 1,701,063 | 970,873 | ||||||||||||||||||
47
EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
Exhibit | ||||||
Number | Description | |||||
12-1 | Computation of Ratio of Earnings to Fixed Charges for MCN Energy Group Inc. | |||||
12-2 | Computation of Ratio of Earnings to Fixed Charges for MCN Investment Corporation | |||||
23-1 | Consent of Ryder Scott Company | |||||
23-2 | Consent of Miller and Lents, Ltd. | |||||
23-3 | Consent of S.A. Holditch & Associates | |||||
23-4 | Consent of Netherland, Sewell & Associates, Inc. | |||||
23-5 | Consent of Williamson Petroleum Consultants, Inc. | |||||
27-1 | Financial Data Schedule 1999. | |||||
27-2 | Financial Data Schedule 1998. |
(b) Reports on Form 8-K
Registrant filed a report on Form 8-K dated August 2, 1999, under Item 5. The contents of the Form 8-K were three press releases issued by MCN on August 2, 1999 outlining its revised strategic direction, the naming of the leadership team to implement the new strategy and the 1999 second quarter earnings release. | |
MCN announced a significantly revised strategic direction. Key aspects of the new corporate strategy include a regional rather than North American focus, and an emphasis on achieving operational efficiencies and growth through integration of existing businesses rather than building a portfolio of diverse, non-operated energy investments. Consistent with the new strategy, as well as the result of the lowering of the bid for the Michigan Exploration & Production (E&P) properties, MCN will retain its natural gas producing properties in Michigan. At year-end 1998, the E&P segment was classified as discontinued operations in preparation for the sale of the companys entire E&P business. | |
Key aspects of the new strategy include reorganizing the MCN family of businesses to include four primary operating segments (Gas Distribution, Midstream & Supply, Energy Marketing and Power) and an investment arm (Energy Holdings). Changes to the leadership team include: |
Stephen E. Ewing | President & Chief Operating Officer (COO), MCN Energy Group Inc. | |
Anne Cooke | President & CEO, MCN Energy Marketing | |
Steve Kurmas | President & CEO, MCN Midstream & Supply | |
Joseph Roberts | President & CEO, MCN Power | |
President & CEO, MCN Energy Holdings |
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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 16, 1999
By: |
/s/ GERARD KABZINSKI |
Gerard Kabzinski | |
Vice President and Controller |
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EXHIBIT INDEX
Exhibit | ||||||
Number | Description | |||||
12-1 | Computation of Ratio of Earnings to Fixed Charges for MCN Energy Group Inc. | |||||
12-2 | Computation of Ratio of Earnings to Fixed Charges for MCN Investment Corporation | |||||
23-1 | Consent of Ryder Scott Company | |||||
23-2 | Consent of Miller and Lents, Ltd. | |||||
23-3 | Consent of S.A. Holditch & Associates | |||||
23-4 | Consent of Netherland, Sewell & Associates, Inc. | |||||
23-5 | Consent of Williamson Petroleum Consultants, Inc. | |||||
27-1 | Financial Data Schedule. 1999 | |||||
27-2 | Financial Data Schedule. 1998 |
|