01—Abstract
Summary
Summary of the 10-K filed March 7, 2008. Cited figures are marked; the original filing is the authoritative source.
DTE Energy's 2007 10-K (filed March 7, 2008) shows a year dominated by one-time monetization gains.
Net income was $971 milliona, or $5.70 per diluted share, versus $433 million ($2.43) in 2006. Income from continuing operations was $787 million ($4.62 per diluted share), up from $389 million ($2.18). The jump is largely the roughly $900 million pre-tax ($580 million after-tax) gain on the sale of the Antrim shale business for $1.262 billion, partly offset by about $323 million pre-tax ($210 million after-tax) of hedge losses tied to that sale.
Investors should treat 2007 as a non-recurring year when judging the earnings base. Operating revenues rose to $8.506 billionb from $8.159 billion, and the Electric Utility segment's net income fell slightly while gas utility earnings rose. The core utilities remain the foundation.
Detroit Edison serves about 2.2 million electric customers and MichCon serves about 1.3 million gas customers. Management expects heavy capital spending, with about $5.2 billionc planned for the electric segment and $1.0 billion for gas over 2008-2012, largely for environmental compliance. Because the 2008 rate filing requests a $123 million increase, regulatory outcomes remain a major driver.
Credit ratings are investment grade but near the lower end for DTE Energy's senior unsecured debt (BBB-/Baa2/BBB). The company is also in a strategic restructuring. The synthetic fuel business ceased operations at year-end 2007 after its tax credits expired, and is reported as discontinued operations.
Management is monetizing non-utility assets: about $900 milliond of after-tax proceeds in 2007 and an expected $800 million more in 2008, including a Barnett shale sale for about $250 million and a planned 50% sale of Power and Industrial Projects for about $650 million gross. Proceeds are targeted for share repurchases (about $725 million used in 2007, with roughly $275 million more planned for 2008) and debt redemption. Key risks include Michigan's electric Customer Choice program, weather, commodity prices, the pension and retiree health obligations, and potential environmental costs.
02—Key points
Key Highlights
- 2007 net income of $971 million ($5.70 diluted EPS) was inflated by the Antrim sale gain (about $580 million after-tax) and offset by about $210 million after-tax of related hedge losses; continuing operations earned $4.62 per diluted share versus $2.18 in 2006.
- Operating revenues were $8.506 billion, up from $8.159 billion, with Electric Utility revenue of $4.9 billion and Gas Utility revenue of $1.875 billion.
- Management plans to monetize non-utility assets for about $900 million after-tax cash in 2007 and an additional roughly $800 million in 2008, including the Barnett shale sale (about $250 million) and a 50% stake sale in Power and Industrial Projects (about $650 million gross).
- Capital spending is heavy: about $5.2 billion (electric) and $1.0 billion (gas) planned for 2008-2012, with roughly $2.4 billion of emission-control investment through 2018.
- Shareholder returns: $364 million in common dividends paid in 2007 ($2.12 declared per share), and $708 million in share repurchases; $725 million has been used under authorizations, with roughly $275 million more planned for 2008.
- Synthetic fuel operations ended December 31, 2007 after production tax credits expired, and the business is reported as discontinued operations; the company expects about $200 million of synfuel-related cash impacts in 2008-2009.
- Credit ratings remain investment grade, but DTE Energy's senior unsecured rating (BBB-/Baa2/BBB) is the weakest tier, and downgrade risk could require collateral posting of about $488 million on certain guarantees.
03—One dollar
04—Financials
Financial Highlights
Figures from 10-KFY2007filed March 7, 2008Financial Statements
| Operating Expenses | $6.87B |
| Operating Income | $1.60B |
| Interest Expense | $533.00M |
| Net Income | $971.00M |
| EPS (Basic) | $5.70 |
| EPS (Diluted) | $5.69 |
| Shares Outstanding (Basic) | 170.00M |
| Shares Outstanding (Diluted) | 171.00M |
05—Questions
Frequently Asked Questions
How much of the 2007 earnings increase was from one-time items rather than core operations?
Most of it. The Antrim shale sale generated a pre-tax gain of about $900 million ($580 million after-tax), partly offset by about $323 million pre-tax ($210 million after-tax) of hedge losses. Income from continuing operations rose to $787 million from $389 million, and the Antrim net effect explains much of that gap. Investors should focus on underlying utility earnings and the 2008 outlook rather than the headline $5.70 EPS.
What is the outlook for the utility businesses?
Detroit Edison requested a $123 million average revenue increase in its April 2007 rate case, later raised by supplemental and updated filings to about $284 million for 2009. Results depend on MPSC orders, weather, and Customer Choice migration. MichCon's earnings are tied to weather, the gas cost recovery mechanism, and an uncollectible expense true-up, with a rate case moratorium through January 1, 2009.
Why are shares being repurchased, and how much capital is available?
The company repurchased about $708 million of stock in 2007 under authorizations totaling $1.55 billion through 2009, with about $725 million used to date. Management says the aim is to increase shareholder value, strengthen the balance sheet, and improve credit ratings, with repurchases dependent on monetization proceeds and cash flow. Management expects about $275 million more in buybacks in 2008 if planned asset sales close.
What are the largest risks to the investment case?
Key risks include Michigan's electric Customer Choice program, which can shift customers to alternative suppliers and create stranded costs; regulatory outcomes on rate recovery; coal and natural gas price volatility; the possibility that the planned non-utility sales are delayed by credit market conditions; underfunded retiree health obligations (about $1.1 billion); and potential environmental costs, including cooling water and air rules. Energy trading mark-to-market swings and possible IRS audits of production tax credits add further uncertainty.
06—Continue