DTE Energy Company 2014 Q3 Form 10-Q Summary
Business context and reporting period
DTE Energy is a diversified energy company comprising regulated electric and gas utilities serving approximately 2.1 million and 1.2 million customers, respectively, plus gas storage and pipelines, power and industrial projects, and energy trading businesses. This unaudited Form 10-Q covers the three and nine months ended September 30, 2014, compared with the corresponding 2013 periods.
Key financial metrics
| Metric | Q3 2014 | Q3 2013 | 9M 2014 | 9M 2013 |
|---|---|---|---|---|
| Operating revenues | $2.595 billion | $2.387 billion | $9.223 billion | $7.128 billion |
| Operating income | $239 million | $329 million | $1.048 billion | $962 million |
| Net income attributable to DTE | $156 million | $198 million | $606 million | $537 million |
| Diluted EPS | $0.88 | $1.13 | $3.42 | $3.07 |
| Dividends declared per share | $0.69 | $0.66 | $2.00 | $1.93 |
Q3 operating margin was approximately 9.2%, compared with 13.8% in Q3 2013. Nine-month operating margin was approximately 11.4%, compared with 13.5% in the prior-year period. Q3 net margin was approximately 6.0%, compared with 8.3%; nine-month net margin was approximately 6.6%, compared with 7.6%.
- Cash flow from operations was $1.298 billion for the first nine months, down from $1.715 billion, primarily because of working-capital changes, lower surcharge collections and higher fuel, purchased power and gas costs.
- Capital expenditures totaled $1.502 billion, including $1.295 billion for utility projects and $207 million for non-utility projects, versus $1.371 billion in the prior-year period.
- Cash and cash equivalents were $60 million at September 30, 2014, compared with $52 million at December 31, 2013. Total assets were $26.376 billion and total equity was $8.186 billion.
- Short-term borrowings were $653 million. Long-term debt, including current maturities and capital leases, was approximately $8.183 billion. The company issued $1.289 billion of long-term debt net of issuance costs and redeemed $1.222 billion during the first nine months.
- Available liquidity was approximately $1.2 billion, including cash and availability under unsecured revolving credit facilities. Net availability under those facilities was $1.172 billion.
- The funded-debt-to-capitalization ratios for DTE Energy, DTE Electric and DTE Gas were 49%, 52% and 45%, respectively, below the 65% covenant limit.
Material changes versus the prior comparable period
- Q3 net income declined $42 million, or approximately 21%, while nine-month net income increased $69 million, or approximately 13%.
- Electric segment earnings declined to $135 million from $179 million in Q3, mainly because gross margin fell $43 million and storm restoration and PLD transition costs increased. Nine-month electric earnings increased to $400 million from $383 million, benefiting from higher cumulative gross margin, including $63 million of refundable revenue decoupling/deferred gain amortization.
- Gas segment Q3 loss increased to $16 million from $13 million, but nine-month earnings increased to $109 million from $91 million, supported by higher gross margin and infrastructure recovery.
- Gas Storage and Pipelines earnings increased to $20 million from $16 million in Q3 and to $59 million from $49 million for nine months, driven by Bluestone, Susquehanna gathering and storage growth.
- Power and Industrial Projects earnings increased to $38 million from $27 million in Q3 and to $66 million from $46 million for nine months, primarily because of higher refined-emissions-fuel volumes, biomass operations and production tax credits.
- Energy Trading reported a Q3 loss of $22 million versus a $6 million loss, while nine-month earnings improved to $6 million from a $1 million loss. Q3 results were pressured by unfavorable realized and unrealized gas, storage and power trading margins.
- Operating revenues increased substantially in the nine-month period, particularly in Energy Trading and Power and Industrial Projects, but higher corresponding fuel and operating costs limited operating-income growth.
Guidance, outlook, risks and unusual items
- Management expected approximately $1.6 billion of 2014 operating cash flow, approximately $500 million below 2013, and approximately $2.2 billion of 2014 capital expenditures.
- Management expects long-term growth from utility infrastructure, environmental and renewable investments and from Gas Storage and Pipelines and Power and Industrial Projects. Near-term funding is expected to rely on internal cash flow and debt issuance.
- DTE Electric estimated 2014 environmental capital expenditures of approximately $200 million and up to $1.2 billion of additional environmental capital expenditures through 2021 under then-current regulations. Utility capital investment plans for 2014-2018 totaled approximately $7.2 billion for DTE Electric and $1.2 billion for DTE Gas.
- Energy Trading earnings remain exposed to commodity-price volatility and mark-to-market timing differences between derivatives and related non-derivative contracts. Management expected near-term market conditions to remain challenging.
- Contracts with ratings triggers could require approximately $327 million of cash or letter-of-credit collateral if DTE Energy were downgraded below investment grade. The company had approximately $894 million of derivative net liability positions subject to hard triggers.
- Environmental and regulatory risks include Clean Air Act and CSAPR/MATS compliance, potential coal-ash and water-intake requirements, greenhouse-gas regulation, remediation obligations and pending EPA litigation. The company stated that the financial impact of certain matters cannot currently be quantified.
- Intervenors challenged recovery of up to $32 million of Fermi 2-related purchased-power costs; resolution was expected by early 2015. DTE Electric also filed for a 20-year NRC license extension for Fermi 2, whose original license was scheduled to expire in 2025.
- Approximately $300 million of long-term debt was scheduled to mature during the following 12 months. The company also had estimated purchase commitments of approximately $8.3 billion through 2051.
- The company reported that disclosure controls were effective and that no material changes affected internal control over financial reporting during the quarter.
Most important facts for an investor to verify
- Whether the lower Q3 electric and Energy Trading results represent temporary weather, storm, outage and mark-to-market effects or a more persistent earnings trend.
- The timing and recoverability of regulatory assets, surcharge collections and disputed Fermi 2 purchased-power costs.
- Actual 2014 operating cash flow and capital spending versus management’s $1.6 billion and $2.2 billion expectations.
- Debt refinancing needs, interest-rate exposure and continued compliance with the 65% funded-debt-to-capitalization covenant.
- Potential collateral requirements under ratings-trigger provisions and the effect of commodity-price movements on derivative positions.
- Environmental compliance costs, pending litigation outcomes and the ability to recover qualifying utility investments through customer rates.
- Progress on the Fermi 2 license renewal, utility infrastructure programs, Nexus pipeline development and other non-utility growth projects.