DTE Energy Company: FY 2011 Form 10-K Summary
Business context and reporting period
DTE Energy reported for the fiscal year ended December 31, 2011. The filing includes quarterly information, including fourth-quarter 2011, but is an annual Form 10-K rather than a standalone Q4 filing. DTE operates regulated electric and gas utilities in Michigan and non-utility businesses in gas pipelines and storage, unconventional gas production, power and industrial projects, and energy trading.
Key financial metrics
| Metric | 2011 | 2010 | Change |
|---|---|---|---|
| Operating revenue | $8.897 billion | $8.557 billion | Up $340 million |
| Operating income | $1.423 billion | $1.464 billion | Down $41 million |
| Net income attributable to DTE | $711 million | $630 million | Up $81 million |
| Diluted EPS | $4.18 | $3.74 | Up $0.44 |
| Net cash from operating activities | $2.008 billion | $1.825 billion | Up $183 million |
| Capital expenditures | $1.484 billion | $1.097 billion | Up $387 million |
| Long-term debt, including capital leases | $7.187 billion | $7.089 billion | Up $98 million |
| Total assets | $26.009 billion | $24.896 billion | Up $1.113 billion |
| DTE shareholders’ equity | $7.009 billion | $6.722 billion | Up $287 million |
Operating margin was approximately 16.0% in 2011 versus 17.1% in 2010. Net margin improved to approximately 8.0% from 7.4%. Cash and cash equivalents were $68 million at year-end, while total available liquidity was approximately $1.4 billion. Revolving credit facilities had aggregate net availability of approximately $1.378 billion.
DTE paid $389 million of common-stock dividends in 2011 and declared dividends of $2.32 per share. Management stated that dividends were expected to continue for the foreseeable future, subject to earnings, cash flow, financial condition and board approval.
Material changes versus the prior comparable period
- Revenue increased 4.0%, but operating income declined because higher fuel and purchased-power costs and operating expenses offset revenue growth.
- Net income increased 12.9%, primarily due to stronger Energy Trading results and an $87 million income-tax benefit related to enactment of the Michigan Corporate Income Tax. The tax benefit was an unusual, nonrecurring contributor to 2011 earnings.
- Energy Trading net income rose to $52 million from $6 million, reflecting improved realized and unrealized trading margins and the absence of certain prior-year timing losses.
- Electric Utility net income declined to $434 million from $441 million. Revenue increased to $5.154 billion, but fuel and purchased-power costs, restoration expenses, maintenance, and a $19 million Fermi 1 decommissioning accrual pressured earnings.
- Gas Utility net income declined to $110 million from $127 million as gross margin fell, partly due to uncollectible-expense tracking, lower midstream revenues and transferred subsidiaries.
- Power and Industrial Projects net income declined to $38 million from $85 million, principally because of an expired below-market rail transportation contract, higher coal costs, reduced production tax credits and other operating pressures.
- Gas Storage and Pipelines net income increased to $57 million from $51 million. Unconventional Gas Production remained loss-making but improved to a $6 million loss from an $11 million loss.
- Electric utility capital expenditures rose substantially, and DTE retired the Connors Creek, Marysville and St. Clair Unit 5 generating plants in December 2011.
Guidance, outlook, commentary and risks
- DTE expected 2012 operating cash flow of approximately $1.9 billion and approximately $1.9 billion of capital and operating investment.
- Detroit Edison estimated 2012–2016 capital requirements of approximately $4.0 billion for base investment, $1.3–$1.8 billion for environmental requirements and $900 million for renewable-energy and energy-efficiency expenditures.
- MichCon planned major gas-main renewal and meter-relocation programs and expected to file a base-rate case in the second quarter of 2012.
- Unconventional Gas Production expected 2012 capital investment of $30–35 million, approximately 30 new wells and production of approximately 6–7 Bcfe, versus 5.1 Bcfe in 2011.
- Approximately $500 million of long-term debt was scheduled to mature within twelve months of year-end, with most Detroit Edison debt expected to be refinanced. DTE issued $280 million of 6.5% junior subordinated debentures due 2061 and redeemed trust-preferred securities.
- Major risks include rate-case outcomes, potential loss or modification of regulatory recovery mechanisms, weather, customer conservation, uncollectible accounts, energy commodity prices, energy-trading volatility, environmental compliance, nuclear operations, pension and postretirement obligations, capital-market access, credit downgrades, cyberattacks and labor negotiations.
- Detroit Edison’s October 2011 rate order approved an annual revenue increase subsequently revised to $188 million and authorized a 10.5% return on equity, but terminated several tracking mechanisms, potentially increasing earnings volatility.
- Detroit Edison accrued approximately $56 million for one pilot revenue-decoupling refund and approximately $71 million for a subsequent period. Potential refund obligations could range from $56 million to $140 million for the first period and from $10 million to $130 million for the second period, subject to regulatory resolution.
- Environmental expenditures were estimated at $2.068 billion through 2021, including approximately $1.9 billion for electric air matters. EPA proceedings involving coal plants, coal ash, cooling-water requirements and coke facilities could require additional controls, early retirements, fines or other expenditures.
- Pension and other postretirement plans were underfunded by approximately $1.3 billion and $1.5 billion, respectively, at year-end. DTE estimated 2012 pension costs of approximately $215 million and postretirement costs of approximately $155 million.
- The filing reports that management and PricewaterhouseCoopers concluded disclosure controls and internal control over financial reporting were effective as of December 31, 2011.
Most important facts for an investor to verify
- Whether 2011 earnings growth is sustainable excluding the $87 million Michigan tax benefit and favorable Energy Trading mark-to-market and timing effects.
- The final MPSC determinations on revenue-decoupling, Choice Incentive Mechanism, power-supply-cost, renewable-energy and other regulatory reconciliations.
- The financial outcome and timing of EPA environmental proceedings and related capital requirements.
- Actual 2012 operating cash flow, capital spending, debt refinancing and liquidity after scheduled maturities and pension or postretirement contributions.
- The effect of terminated electric tracking mechanisms on earnings volatility and cash recovery.
- Energy Trading’s exposure to commodity-price movements, derivative valuation changes, collateral requirements and counterparty credit risk.
- The adequacy of pension and postretirement funding, including the effect of lower discount rates and investment performance.
- Whether Unconventional Gas Production can achieve projected 2012 production and returns amid natural-gas-price and service-cost volatility.