DTE Energy Company 2012 Form 10-K Summary
Business context and reporting period
DTE Energy is a diversified Michigan energy company with regulated electric and gas utilities and non-utility businesses in gas pipelines and storage, power and industrial projects, and energy trading. DTE Electric serves approximately 2.1 million customers and DTE Gas approximately 1.2 million customers. The filing covers the fiscal year ended December 31, 2012; quarterly information is included, but this is an annual filing.
Key financial metrics
| Metric | 2012 | 2011 | Change |
|---|---|---|---|
| Operating revenues | $8.791 billion | $8.858 billion | Down $67 million |
| Operating income | $1.279 billion | $1.421 billion | Down $142 million |
| Net income attributable to DTE Energy | $610 million | $711 million | Down $101 million |
| Continuing operations attributable to DTE Energy | $666 million | $714 million | Down $48 million |
| Diluted EPS | $3.55 | $4.18 | Down $0.63 |
| Diluted EPS from continuing operations | $3.88 | $4.20 | Down $0.32 |
| Net cash from operating activities | $2.209 billion | $2.008 billion | Up $201 million |
| Capital expenditures | $1.819 billion | $1.484 billion | Up $335 million |
| Long-term debt, including capital leases | $7.014 billion | $7.187 billion | Down $173 million |
| Total assets | $26.339 billion | $26.009 billion | Up $330 million |
| DTE Energy equity | $7.373 billion | $7.009 billion | Up $364 million |
Operating margin was approximately 14.5% versus 16.0% in 2011; net income attributable to DTE Energy represented approximately 6.9% of revenue versus 8.0% in 2011. The filing does not present a single companywide adjusted EBITDA measure.
Segment performance and material changes
- Electric: Net income increased to $483 million from $434 million. Gross margin rose $97 million, primarily from rate case effects, weather, securitization and tax surcharges, and renewable energy programs. Operating income margin remained approximately 19%.
- Gas: Net income increased to $115 million from $110 million despite revenue declining to $1.315 billion from $1.505 billion, mainly because lower gas costs supported gross margin and operating income. The DTE Gas revenue decoupling mechanism was terminated effective November 1, 2012, with a new mechanism expected to begin in November 2013.
- Gas Storage and Pipelines: Net income increased to $61 million from $57 million, driven primarily by higher earnings from pipeline equity investments and continued expansion projects.
- Power and Industrial Projects: Net income increased to $42 million from $38 million. Revenue increased substantially to $1.823 billion, largely from reduced-emissions-fuel projects and acquired on-site energy projects, but much of the increase was offset by related operating costs. Production tax credits allocated to DTE increased to $43 million from $6 million.
- Energy Trading: Net income declined sharply to $12 million from $52 million as realized and unrealized margins fell because of fewer market opportunities and weaker power and gas trading results. Mark-to-market accounting may create period-to-period volatility even where positions are economically hedged.
- Corporate and Other: The segment reported a $47 million loss versus $23 million of income in 2011, principally because 2011 included an $87 million income tax benefit related to Michigan Corporate Income Tax enactment.
- Discontinued operations: DTE sold its Unconventional Gas Production business in December 2012 for approximately $255 million of gross proceeds, recording an approximately $83 million pretax loss and $55 million after-tax loss.
Cash flow, debt and liquidity
Operating cash flow was $2.209 billion, exceeding utility and non-utility capital expenditures of $1.819 billion. Investing cash flow was negative $1.769 billion, including $1.451 billion of utility spending, $369 million of non-utility spending, and a $198 million acquisition outflow, partially offset by $255 million of proceeds from the discontinued-business sale. Financing cash flow was negative $443 million, including $407 million of common dividends.
Cash and cash equivalents were $65 million at year-end. Including available revolving credit, management reported approximately $1.6 billion of available liquidity. Credit facilities totaled $1.975 billion, with reported net availability of $1.560 billion after commercial paper and letters of credit. The company had approximately $800 million of long-term debt maturing during the next twelve months and maintained debt-to-capitalization ratios of 0.48 for DTE Energy, 0.52 for DTE Electric, and 0.46 for DTE Gas.
Management expected approximately $1.8 billion of 2013 operating cash flow and approximately $2.2 billion of 2013 capital expenditures. Planned 2013 equity issuance through dividend reinvestment and employee benefit plans was approximately $300 million.
Guidance, outlook, risks and unusual items
- DTE expects long-term growth from utility infrastructure, environmental and renewable investment, and expansion of gas pipelines, storage and power and industrial projects. Near-term Energy Trading conditions were expected to remain challenging.
- Estimated 2013–2017 utility capital investments total approximately $6.85 billion, including DTE Electric base infrastructure, environmental compliance, renewable and efficiency projects and DTE Gas infrastructure and pipeline programs.
- DTE Electric’s Fermi 2 plant was manually shut down in June 2012 after a feed-water pump failure, restarted at reduced capacity in July, and was scheduled for a repair outage in the first quarter of 2013. Insurance coverage and regulatory recovery of incremental purchased-power costs were expected to mitigate the impact.
- Environmental expenditures were estimated at $1.930 billion through 2020, including approximately $367 million in 2013. Future rules concerning air emissions, coal ash, cooling-water intake, greenhouse gases and hazardous pollutants could materially increase costs.
- An EPA appeal concerning alleged Clean Air Act violations at DTE power plants remained pending. Potential outcomes included additional controls, early plant retirement, environmental programs or fines; the financial impact could not be quantified.
- Pension and postretirement plans remained materially underfunded. At year-end, pension plans were underfunded by approximately $1.4 billion and other postretirement plans by approximately $1.2 billion. Management anticipated up to $315 million of pension contributions and up to $120 million of additional postretirement contributions in 2013.
- A downgrade below investment grade could restrict capital-market access and trigger collateral requirements. The filing estimated approximately $326 million of transactions potentially subject to collateral requests upon such a downgrade.
- Other significant risks include rate recovery and regulatory timing, weather, commodity prices, nuclear operations, energy trading volatility, credit and counterparty exposure, construction execution, cybersecurity, labor negotiations, tax-credit audits and pension assumptions.
Most important facts for investors to verify
- Reconcile the decline in consolidated earnings with improved Electric, Gas, Gas Storage and Pipelines, and Power and Industrial Projects results, particularly the Energy Trading decline and the absence of the 2011 $87 million tax benefit.
- Review the sustainability and regulatory recovery of the planned $2.2 billion 2013 capital program and the larger 2013–2017 investment pipeline.
- Assess refinancing needs for approximately $800 million of debt maturing within twelve months and the adequacy of reported liquidity under adverse market conditions.
- Monitor Fermi 2 repair, insurance recovery, operating performance and potential nuclear decommissioning obligations.
- Track EPA, state environmental, coal-ash and greenhouse-gas proceedings and their potential effects on rates, capital spending and plant retirements.
- Evaluate pension and postretirement funding requirements, including sensitivity to discount rates, investment returns and healthcare-cost assumptions.
- Confirm the final purchase-price adjustments for the divested Unconventional Gas Production business and the regulatory outcomes for pending PSCR, rate-case, infrastructure-recovery and decoupling matters.