Delaware | 1-12079 | 77-0212977 |
(State or other jurisdiction of incorporation) | (Commission File Number) | (IRS Employer Identification No.) |
o | Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425) |
o | Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12) |
o | Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b)) |
o | Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c)) |
ITEM 2.02 — RESULTS OF OPERATIONS AND FINANCIAL CONDITION | ||
ITEM 9.01 — FINANCIAL STATEMENTS AND EXHIBITS | ||
SIGNATURES | ||
EXHIBIT INDEX |
(d) | Exhibits |
Exhibit No. | Description | |
99.1 | Calpine Corporation Press Release dated May 1, 2015.* |
* | Furnished herewith. |
By: | /s/ ZAMIR RAUF | |||
Zamir Rauf | ||||
Executive Vice President and | ||||
Chief Financial Officer | ||||
May 1, 2015 |
Exhibit No. | Description | |
99.1 | Calpine Corporation Press Release dated May 1, 2015.* |
* | Furnished herewith. |
Exhibit 99.1 |
CONTACTS: | NEWS RELEASE |
Media Relations: | Investor Relations: |
Brett Kerr | Bryan Kimzey |
713-830-8809 | 713-830-8777 |
brett.kerr@calpine.com | bryan.kimzey@calpine.com |
Three Months Ended March 31, | |||||||||||
2015 | 2014 | % Change | |||||||||
Operating Revenues | $ | 1,646 | $ | 1,965 | (16.2 | )% | |||||
Commodity Margin | $ | 535 | $ | 645 | (17.1 | )% | |||||
Adjusted EBITDA | $ | 338 | $ | 446 | (24.2 | )% | |||||
Adjusted Free Cash Flow | $ | 25 | $ | 130 | (80.8 | )% | |||||
Per Share (diluted) | $ | 0.07 | $ | 0.31 | (77.4 | )% | |||||
Net Loss1 | $ | (10 | ) | $ | (17 | ) | |||||
Per Share (diluted) | $ | (0.03 | ) | $ | (0.04 | ) | |||||
Net Income (Loss), As Adjusted2 | $ | (62 | ) | $ | 56 |
2015 | |||
Adjusted EBITDA | $1,900 - 2,100 | ||
Adjusted Free Cash Flow | $810 - 1,010 | ||
Per Share Estimate (diluted) | $2.10 - 2.60 |
• | Power Operations: |
— | Generated record high 26 million MWh3 of electricity in first quarter of 2015 |
— | Achieved low first quarter fleetwide forced outage factor: 1.4% |
— | Delivered strong fleetwide starting reliability: 98% |
• | Customer-Oriented Origination Efforts: |
— | Originated 710 MW of public power PPAs from our Texas power plant fleet, one of which will facilitate construction of 418 MW peaking facility in partnership with our customer |
— | Executed 65 MW PPA with Marin Clean Energy from our Delta Energy Center and northern California fleet |
— | Executed 20-year PPA for 345 MW expansion of our Mankato Energy Center |
• | Capital Allocation and Portfolio Management Progress: |
— | Completed approximately $236 million of share repurchases year-to-date, an incremental $111 million since last call |
— | Nearing completion of Garrison Energy Center: commercial operations expected during second quarter of 2015 |
— | Advanced development of York 2 Energy Center: commercial operations expected during second quarter of 2017 |
— | Filed with FERC to approve pending sale of Osprey Energy Center in January 2017 |
1 | Reported as Net Loss attributable to Calpine on our Consolidated Condensed Statements of Operations. |
2 | Refer to Table 1 for further detail of Net Income (Loss), As Adjusted. |
3 | Includes generation from power plants owned but not operated by Calpine and our share of generation from unconsolidated power plants. |
– | a significant decrease in power and natural gas prices in our East region in the first quarter of 2015 compared to the prior year period, given the unusually high price levels experienced during the polar vortex events in the first quarter of 2014; |
– | the sale of six power plants with a total capacity of 3,498 MW in our East region in July 2014 and |
– | lower regulatory capacity revenue in PJM, partially offset by |
+ | higher contribution from hedges that more than offset lower on-peak spark spreads across all of our regions, excluding the impact of the polar vortex events experienced during the first quarter of 2014, and |
+ | the acquisition of our Guadalupe and Fore River Energy Centers in February and November 2014, respectively, as well as the completion of the expansions of our Deer Park and Channel Energy Centers in June 2014. |
Three Months Ended March 31, | ||||||||
2015 | 2014 | |||||||
Net loss attributable to Calpine | $ | (10 | ) | $ | (17 | ) | ||
Debt extinguishment costs(1) | 19 | 1 | ||||||
Mark-to-market (gain) loss on derivatives(1)(2) | (71 | ) | 72 | |||||
Net Income (Loss), As Adjusted(3) | $ | (62 | ) | $ | 56 |
(1) | Shown net of tax, assuming a 0% effective tax rate for these items. |
(2) | In addition to changes in market value on derivatives not designated as hedges, changes in mark-to-market (gain) loss also includes de-designation of interest rate swap cash flow hedges and related reclassification from AOCI into earnings, hedge ineffectiveness and adjustments to reflect changes in credit default risk exposure. |
(3) | Non-GAAP financial measure, see “Regulation G Reconciliations” for further discussion of Net Income (Loss), As Adjusted. |
Three Months Ended March 31, | ||||||||||||
2015 | 2014 | Variance | ||||||||||
West | $ | 218 | $ | 202 | $ | 16 | ||||||
Texas | 149 | 121 | 28 | |||||||||
East | 168 | 322 | (154 | ) | ||||||||
Total | $ | 535 | $ | 645 | $ | (110 | ) |
+ | higher contribution from hedges and |
+ | higher renewable energy credit revenue associated with our Geysers assets resulting from more favorable pricing in 2015, partially offset by |
– | lower market spark spreads driven by lower natural gas prices and an increase in hydroelectric generation in the Pacific Northwest, despite relatively unchanged market heat rates. |
+ | the acquisition of Guadalupe Energy Center in February 2014 and the expansions of our Deer Park and Channel Energy Centers, which were completed in June 2014 |
+ | higher contribution from hedges and |
+ | higher off-peak spark spreads driven by lower systemwide coal-fired generation, partially offset by |
– | lower on-peak spark spreads resulting from lower natural gas prices. |
– | a significant decrease in power and natural gas prices in our East region in the first quarter of 2015 compared to the prior year period, given the unusually high price levels experienced during the polar vortex events in the first quarter of 2014, and |
– | lower regulatory capacity revenues in PJM, partially offset by |
+ | the acquisition of Fore River Energy Center in November 2014 and |
+ | higher contribution from hedges. |
March 31, | December 31, | |||||||
2015 | 2014 | |||||||
Cash and cash equivalents, corporate(1) | $ | 717 | $ | 460 | ||||
Cash and cash equivalents, non-corporate | 79 | 257 | ||||||
Total cash and cash equivalents | 796 | 717 | ||||||
Restricted cash | 209 | 244 | ||||||
Corporate Revolving Facility availability | 1,298 | 1,277 | ||||||
CDHI letter of credit facility availability | 65 | 86 | ||||||
Total current liquidity availability | $ | 2,368 | $ | 2,324 |
(1) | Includes $40 million and $47 million of margin deposits posted with us by our counterparties at March 31, 2015, and December 31, 2014, respectively. |
March 31, | March 31, | ||||||
2015 | 2014 | ||||||
Beginning cash and cash equivalents | $ | 717 | $ | 941 | |||
Net cash provided by (used in): | |||||||
Operating activities | (17 | ) | 123 | ||||
Investing activities | (128 | ) | (769 | ) | |||
Financing activities | 224 | 220 | |||||
Net increase (decrease) in cash and cash equivalents | 79 | (426 | ) | ||||
Ending cash and cash equivalents | $ | 796 | $ | 515 |
4 | Based upon 490.6 million shares outstanding as of June 30, 2011, immediately prior to announcement of our repurchase program. |
• | Safety Performance: |
— | Maintained top quartile5 safety metrics: 0.66 total recordable incident rate |
• | Availability Performance: |
— | Achieved low fleetwide forced outage factor: 1.4% |
— | Delivered exceptional fleetwide starting reliability: 98% |
• | Power Generation: |
— | Morgan Energy Center: 90% capacity factor |
— | Four Texas plants with capacity factors above 70%: Bosque, Brazos Valley, Channel and Deer Park Energy Centers |
— | Hermiston, Otay Mesa, Pastoria and Russell City Energy Centers: 100% starting reliability |
• | Customer-oriented Growth: During the first quarter of 2015, we entered into the following new contracts: |
— | A three-year PPA with Marin Clean Energy to provide up to 65 MW of power from our Delta Energy Center and other northern California power plants commencing in April 2015 and extending through December 2017 |
— | Our ten-year PPA with Southern California Edison for 225 MW of capacity and renewable energy from our Geysers assets commencing in June 2017 was approved by the California Public Utilities Commission |
— | A new three-year PPA with Brazos Electric Power Cooperative to provide 300 MW of power from our Texas power plant fleet commencing in January 2016 |
— | A new three-year PPA with Pedernales Electric Cooperative to provide approximately 140 MW of power from our Texas power plant fleet commencing in January 2017 |
— | A new two-year PPA with Guadalupe Valley Electric Cooperative to provide approximately 270 MW of power from our Texas power plant fleet commencing in June 2017. The execution of this PPA will facilitate the construction of a 418 MW natural gas-fired peaking power plant to be co-located with our Guadalupe Energy Center |
— | A new 20-year PPA with Xcel Energy to provide up to 345 MW of capacity and energy from our Mankato Power Plant expansion when commercial operations commence and transmission-related upgrades have been completed |
Full Year 2015 | |||
Adjusted EBITDA | $ | 1,900 - 2,100 | |
Less: | |||
Operating lease payments | 35 | ||
Major maintenance expense and maintenance capital expenditures(1) | 395 | ||
Cash interest, net(2) | 630 | ||
Cash taxes | 25 | ||
Other | 5 | ||
Adjusted Free Cash Flow | $ | 810 - 1,010 | |
Per Share Estimate (diluted) | $ | 2.10 - 2.60 | |
Debt amortization(3) | $ | (360 | ) |
Growth capital expenditures (net of debt funding) | $ | (355 | ) |
(1) | Includes projected major maintenance expense of $235 million and maintenance capital expenditures of $160 million in 2015. Capital expenditures exclude major construction and development projects. |
(2) | Includes commitment, letter of credit and other bank fees from both consolidated and unconsolidated investments, net of capitalized interest and interest income. |
(3) | Includes the repurchase of approximately $147 million of our 2023 First Lien Notes in February 2015. |
• | Financial results that may be volatile and may not reflect historical trends due to, among other things, seasonality of demand, fluctuations in prices for commodities such as natural gas and power, changes in U.S. macroeconomic conditions, fluctuations in liquidity and volatility in the energy commodities markets and our ability and extent to which we hedge risks; |
• | Laws, regulations and market rules in the markets in which we participate and our ability to effectively respond to changes in laws, regulations or market rules or the interpretation thereof including those related to the environment, derivative transactions and market design in the regions in which we operate; |
• | Our ability to manage our liquidity needs, access the capital markets when necessary and to comply with covenants under our First Lien Notes, Senior Unsecured Notes, Corporate Revolving Facility, First Lien Term Loans, CCFC Term Loans and other existing financing obligations; |
• | Risks associated with the operation, construction and development of power plants including unscheduled outages or delays and plant efficiencies; |
• | Risks related to our geothermal resources, including the adequacy of our steam reserves, unusual or unexpected steam field well and pipeline maintenance requirements, variables associated with the injection of water to the steam reservoir and potential regulations or other requirements related to seismicity concerns that may delay or increase the cost of developing or operating geothermal resources; |
• | Competition, including risks associated with marketing and selling power in the evolving energy markets; |
• | Structural changes in the supply and demand of power, resulting from the development of new fuels or technologies and demand-side management tools (such as distributed generation, power storage and other technologies); |
• | The expiration or early termination of our PPAs and the related results on revenues; |
• | Future capacity revenues may not occur at expected levels; |
• | Natural disasters, such as hurricanes, earthquakes, droughts and floods, acts of terrorism or cyber attacks that may impact our power plants or the markets our power plants serve and our corporate headquarters; |
• | Disruptions in or limitations on the transportation of natural gas, fuel oil and transmission of power; |
• | Our ability to manage our customer and counterparty exposure and credit risk, including our commodity positions; |
• | Our ability to attract, motivate and retain key employees; |
• | Present and possible future claims, litigation and enforcement actions that may arise from noncompliance with market rules promulgated by the SEC, CFTC, FERC and other regulatory bodies; and |
• | Other risks identified in this press release, in our 2014 Form 10-K and in other reports filed by us with the SEC. |
Three Months Ended March 31, | ||||||||
2015 | 2014 | |||||||
(in millions, except share and per share amounts) | ||||||||
Operating revenues: | ||||||||
Commodity revenue | $ | 1,638 | $ | 2,048 | ||||
Mark-to-market gain (loss) | 3 | (86 | ) | |||||
Other revenue | 5 | 3 | ||||||
Operating revenues | 1,646 | 1,965 | ||||||
Operating expenses: | ||||||||
Fuel and purchased energy expense: | ||||||||
Commodity expense | 1,077 | 1,370 | ||||||
Mark-to-market (gain) | (67 | ) | (13 | ) | ||||
Fuel and purchased energy expense | 1,010 | 1,357 | ||||||
Plant operating expense | 260 | 265 | ||||||
Depreciation and amortization expense | 158 | 153 | ||||||
Sales, general and other administrative expense | 37 | 33 | ||||||
Other operating expenses | 20 | 22 | ||||||
Total operating expenses | 1,485 | 1,830 | ||||||
(Income) from unconsolidated investments in power plants | (5 | ) | (9 | ) | ||||
Income from operations | 166 | 144 | ||||||
Interest expense | 154 | 166 | ||||||
Interest (income) | (1 | ) | (1 | ) | ||||
Debt extinguishment costs | 19 | 1 | ||||||
Other (income) expense, net | 2 | 10 | ||||||
Loss before income taxes | (8 | ) | (32 | ) | ||||
Income tax benefit | (1 | ) | (19 | ) | ||||
Net loss | (7 | ) | (13 | ) | ||||
Net income attributable to the noncontrolling interest | (3 | ) | (4 | ) | ||||
Net loss attributable to Calpine | $ | (10 | ) | $ | (17 | ) | ||
Basic and diluted loss per common share attributable to Calpine: | ||||||||
Weighted average shares of common stock outstanding (in thousands) | 372,935 | 420,105 | ||||||
Net loss per common share attributable to Calpine — basic and diluted | $ | (0.03 | ) | $ | (0.04 | ) |
March 31, | December 31, | ||||||
2015 | 2014 | ||||||
(in millions, except share and per share amounts) | |||||||
ASSETS | |||||||
Current assets: | |||||||
Cash and cash equivalents | $ | 796 | $ | 717 | |||
Accounts receivable, net of allowance of $5 and $4 | 503 | 648 | |||||
Inventories | 486 | 447 | |||||
Margin deposits and other prepaid expense | 150 | 148 | |||||
Restricted cash, current | 162 | 195 | |||||
Derivative assets, current | 1,858 | 2,058 | |||||
Other current assets | 17 | 7 | |||||
Total current assets | 3,972 | 4,220 | |||||
Property, plant and equipment, net | 13,178 | 13,190 | |||||
Restricted cash, net of current portion | 47 | 49 | |||||
Investments in power plants | 88 | 95 | |||||
Long-term derivative assets | 711 | 439 | |||||
Other assets | 386 | 385 | |||||
Total assets | $ | 18,382 | $ | 18,378 | |||
LIABILITIES & STOCKHOLDERS’ EQUITY | |||||||
Current liabilities: | |||||||
Accounts payable | $ | 456 | $ | 580 | |||
Accrued interest payable | 163 | 165 | |||||
Debt, current portion | 197 | 199 | |||||
Derivative liabilities, current | 1,643 | 1,782 | |||||
Other current liabilities | 385 | 473 | |||||
Total current liabilities | 2,844 | 3,199 | |||||
Debt, net of current portion | 11,520 | 11,083 | |||||
Long-term derivative liabilities | 572 | 444 | |||||
Other long-term liabilities | 241 | 221 | |||||
Total liabilities | 15,177 | 14,947 | |||||
Commitments and contingencies | |||||||
Stockholders’ equity: | |||||||
Preferred stock, $0.001 par value per share; authorized 100,000,000 shares, none issued and outstanding | — | — | |||||
Common stock, $0.001 par value per share; authorized 1,400,000,000 shares, 504,015,575 and 502,287,022 shares issued, respectively, and 373,837,359 and 381,921,264 shares outstanding, respectively | 1 | 1 | |||||
Treasury stock, at cost, 130,178,216 and 120,365,758 shares, respectively | (2,557 | ) | (2,345 | ) | |||
Additional paid-in capital | 12,453 | 12,440 | |||||
Accumulated deficit | (6,550 | ) | (6,540 | ) | |||
Accumulated other comprehensive loss | (195 | ) | (178 | ) | |||
Total Calpine stockholders’ equity | 3,152 | 3,378 | |||||
Noncontrolling interest | 53 | 53 | |||||
Total stockholders’ equity | 3,205 | 3,431 | |||||
Total liabilities and stockholders’ equity | $ | 18,382 | $ | 18,378 |
Three Months Ended March 31, | ||||||||
2015 | 2014 | |||||||
(in millions) | ||||||||
Cash flows from operating activities: | ||||||||
Net loss | $ | (7 | ) | $ | (13 | ) | ||
Adjustments to reconcile net loss to net cash provided by (used in) operating activities: | ||||||||
Depreciation and amortization expense(1) | 171 | 164 | ||||||
Deferred income taxes | — | (13 | ) | |||||
Mark-to-market activity, net | (71 | ) | 72 | |||||
(Income) from unconsolidated investments in power plants | (5 | ) | (9 | ) | ||||
Return on unconsolidated investments in power plants | — | 13 | ||||||
Stock-based compensation expense | 11 | 10 | ||||||
Other | (2 | ) | (2 | ) | ||||
Change in operating assets and liabilities: | ||||||||
Accounts receivable | 120 | (75 | ) | |||||
Derivative instruments, net | (17 | ) | (87 | ) | ||||
Other assets | (28 | ) | 29 | |||||
Accounts payable and accrued expenses | (204 | ) | 106 | |||||
Other liabilities | 15 | (72 | ) | |||||
Net cash provided by (used in) operating activities | (17 | ) | 123 | |||||
Cash flows from investing activities: | ||||||||
Purchases of property, plant and equipment | (162 | ) | (119 | ) | ||||
Purchase of Guadalupe Energy Center | — | (656 | ) | |||||
Decrease in restricted cash | 35 | 6 | ||||||
Other | (1 | ) | — | |||||
Net cash used in investing activities | $ | (128 | ) | $ | (769 | ) |
Three Months Ended March 31, | ||||||||
2015 | 2014 | |||||||
(in millions) | ||||||||
Cash flows from financing activities: | ||||||||
Borrowings under CCFC Term Loans | $ | — | $ | 420 | ||||
Repayment of CCFC Term Loans and First Lien Term Loans | (11 | ) | (11 | ) | ||||
Borrowings under Senior Unsecured Notes | 650 | — | ||||||
Repurchase of First Lien Notes | (147 | ) | — | |||||
Repayments of project financing, notes payable and other | (58 | ) | (43 | ) | ||||
Financing costs | (11 | ) | (10 | ) | ||||
Stock repurchases | (202 | ) | (140 | ) | ||||
Proceeds from exercises of stock options | 3 | 4 | ||||||
Net cash provided by financing activities | 224 | 220 | ||||||
Net increase (decrease) in cash and cash equivalents | 79 | (426 | ) | |||||
Cash and cash equivalents, beginning of period | 717 | 941 | ||||||
Cash and cash equivalents, end of period | $ | 796 | $ | 515 | ||||
Cash paid during the period for: | ||||||||
Interest, net of amounts capitalized | $ | 146 | $ | 225 | ||||
Income taxes | $ | 6 | $ | 8 | ||||
Supplemental disclosure of non-cash investing activities: | ||||||||
Change in capital expenditures included in accounts payable | $ | (22 | ) | $ | (9 | ) |
(1) | Includes depreciation and amortization included in fuel and purchased energy expense and interest expense on our Consolidated Condensed Statements of Operations. |
Three Months Ended March 31, 2015 | ||||||||||||||||||||
Consolidation | ||||||||||||||||||||
And | ||||||||||||||||||||
West | Texas | East | Elimination | Total | ||||||||||||||||
Commodity Margin | $ | 218 | $ | 149 | $ | 168 | $ | — | $ | 535 | ||||||||||
Add: Mark-to-market commodity activity, net and other(1) | 119 | 41 | (52 | ) | (7 | ) | 101 | |||||||||||||
Less: | ||||||||||||||||||||
Plant operating expense | 106 | 89 | 72 | (7 | ) | 260 | ||||||||||||||
Depreciation and amortization expense | 67 | 49 | 42 | — | 158 | |||||||||||||||
Sales, general and other administrative expense | 10 | 17 | 10 | — | 37 | |||||||||||||||
Other operating expenses | 10 | 2 | 8 | — | 20 | |||||||||||||||
(Income) from unconsolidated investments in power plants | — | — | (5 | ) | — | (5 | ) | |||||||||||||
Income (loss) from operations | $ | 144 | $ | 33 | $ | (11 | ) | $ | — | $ | 166 |
Three Months Ended March 31, 2014 | ||||||||||||||||||||
Consolidation | ||||||||||||||||||||
And | ||||||||||||||||||||
West | Texas | East | Elimination | Total | ||||||||||||||||
Commodity Margin(2) | $ | 202 | $ | 121 | $ | 322 | $ | — | $ | 645 | ||||||||||
Add: Mark-to-market commodity activity, net and other(1) | 29 | (46 | ) | (11 | ) | (9 | ) | (37 | ) | |||||||||||
Less: | ||||||||||||||||||||
Plant operating expense | 105 | 90 | 79 | (9 | ) | 265 | ||||||||||||||
Depreciation and amortization expense | 60 | 42 | 51 | — | 153 | |||||||||||||||
Sales, general and other administrative expense | 10 | 12 | 12 | (1 | ) | 33 | ||||||||||||||
Other operating expenses | 12 | 2 | 7 | 1 | 22 | |||||||||||||||
(Income) from unconsolidated investments in power plants | — | — | (9 | ) | — | (9 | ) | |||||||||||||
Income (loss) from operations | $ | 44 | $ | (71 | ) | $ | 171 | $ | — | $ | 144 |
(1) | Includes $(24) million and $(29) million of lease levelization and $4 million and $4 million of amortization expense for the three months ended March 31, 2015 and 2014, respectively. |
(2) | Commodity Margin related to the six power plants sold in our East segment on July 3, 2014, was $39 million for the three months ended March 31, 2014. |
Three Months Ended March 31, | ||||||||
2015 | 2014(6) | |||||||
Net loss attributable to Calpine | $ | (10 | ) | $ | (17 | ) | ||
Net income attributable to the noncontrolling interest | 3 | 4 | ||||||
Income tax benefit | (1 | ) | (19 | ) | ||||
Debt extinguishment costs and other (income) expense, net | 21 | 11 | ||||||
Interest expense, net of interest income | 153 | 165 | ||||||
Income from operations | $ | 166 | $ | 144 | ||||
Add: | ||||||||
Adjustments to reconcile income from operations to Adjusted EBITDA: | ||||||||
Depreciation and amortization expense, excluding deferred financing costs(1) | 157 | 151 | ||||||
Major maintenance expense | 78 | 81 | ||||||
Operating lease expense | 9 | 9 | ||||||
Mark-to-market (gain) loss on commodity derivative activity | (70 | ) | 73 | |||||
Adjustments to reflect Adjusted EBITDA from unconsolidated investments and exclude the noncontrolling interest(2) | 5 | 3 | ||||||
Stock-based compensation expense | 11 | 10 | ||||||
Loss on dispositions of assets | 1 | — | ||||||
Acquired contract amortization | 4 | 4 | ||||||
Other | (23 | ) | (29 | ) | ||||
Total Adjusted EBITDA | $ | 338 | $ | 446 | ||||
Less: | ||||||||
Operating lease payments | 9 | 9 | ||||||
Major maintenance expense and capital expenditures(3) | 143 | 133 | ||||||
Cash interest, net(4) | 155 | 168 | ||||||
Cash taxes | 6 | 6 | ||||||
Other | — | — | ||||||
Adjusted Free Cash Flow(5) | $ | 25 | $ | 130 | ||||
Weighted average shares of common stock outstanding (diluted, in thousands) | 372,935 | 420,105 | ||||||
Adjusted Free Cash Flow Per Share (diluted) | $ | 0.07 | $ | 0.31 |
(1) | Depreciation and amortization expense in the income from operations calculation on our Consolidated Condensed Statements of Operations excludes amortization of other assets. |
(2) | Adjustments to reflect Adjusted EBITDA from unconsolidated investments include (gain) loss on mark-to-market activity of nil for the three months ended March 31, 2015 and 2014. |
(3) | Includes $79 million and $83 million in major maintenance expense for the three months ended March 31, 2015 and 2014, respectively, and $64 million and $50 million in maintenance capital expenditure for the three months ended March 31, 2015 and 2014, respectively. |
(4) | Includes commitment, letter of credit and other bank fees from both consolidated and unconsolidated investments, net of capitalized interest and interest income. |
(5) | Excludes an increase in working capital of $86 million and $6 million for the three months ended March 31, 2015 and 2014, respectively. Adjusted Free Cash Flow, as reported, excludes changes in working capital, such that it is calculated on the same basis as our guidance. |
(6) | Adjusted EBITDA related to the six power plants sold in our East segment on July 3, 2014, was $20 million for the three months ended March 31, 2014. |
Three Months Ended March 31, | ||||||||
2015 | 2014 | |||||||
Commodity Margin | $ | 535 | $ | 645 | ||||
Other revenue | 4 | 3 | ||||||
Plant operating expense(1) | (173 | ) | (177 | ) | ||||
Sales, general and administrative expense(2) | (30 | ) | (29 | ) | ||||
Other operating expenses(3) | (10 | ) | (12 | ) | ||||
Adjusted EBITDA from unconsolidated investments in power plants | 14 | 16 | ||||||
Other | (2 | ) | — | |||||
Adjusted EBITDA | $ | 338 | $ | 446 |
(1) | Shown net of major maintenance expense, stock-based compensation expense, non-cash loss on dispositions of assets and other costs. |
(2) | Shown net of stock-based compensation expense and other costs. |
(3) | Shown net of operating lease expense, amortization and other costs. |
Full Year 2015 Range: | Low | High | ||||
GAAP Net Income (1) | $ | 276 | $ | 476 | ||
Plus: | ||||||
Debt extinguishment costs | 19 | 19 | ||||
Interest expense, net of interest income | 630 | 630 | ||||
Depreciation and amortization expense | 630 | 630 | ||||
Major maintenance expense | 230 | 230 | ||||
Operating lease expense | 35 | 35 | ||||
Other(2) | 80 | 80 | ||||
Adjusted EBITDA | $ | 1,900 | $ | 2,100 | ||
Less: | ||||||
Operating lease payments | 35 | 35 | ||||
Major maintenance expense and maintenance capital expenditures(3) | 395 | 395 | ||||
Cash interest, net(4) | 630 | 630 | ||||
Cash taxes | 25 | 25 | ||||
Other | 5 | 5 | ||||
Adjusted Free Cash Flow | $ | 810 | $ | 1,010 | ||
(1) | For purposes of Net Income guidance reconciliation, mark-to-market adjustments are assumed to be nil. |
(2) | Other includes stock-based compensation expense, adjustments to reflect Adjusted EBITDA from unconsolidated investments, income tax expense and other items. |
(3) | Includes projected major maintenance expense of $235 million and maintenance capital expenditures of $160 million. Capital expenditures exclude major construction and development projects. |
(4) | Includes commitment, letter of credit and other bank fees from both consolidated and unconsolidated investments, net of capitalized interest and interest income. |
Three Months Ended March 31, | ||||||
2015 | 2014 | |||||
Total MWh generated (in thousands)(1) | 25,567 | 22,977 | ||||
West | 7,253 | 8,831 | ||||
Texas | 11,544 | 6,877 | ||||
East | 6,770 | 7,269 | ||||
Average availability | 89.4 | % | 88.4 | % | ||
West | 88.3 | % | 89.0 | % | ||
Texas | 88.1 | % | 82.7 | % | ||
East | 91.7 | % | 92.2 | % | ||
Average capacity factor, excluding peakers | 52.0 | % | 43.2 | % | ||
West | 47.7 | % | 58.2 | % | ||
Texas | 58.2 | % | 39.0 | % | ||
East | 47.9 | % | 35.3 | % | ||
Steam adjusted heat rate (Btu/kWh) | 7,262 | 7,353 | ||||
West | 7,301 | 7,248 | ||||
Texas | 7,096 | 7,151 | ||||
East | 7,516 | 7,663 |
(1) | Excludes generation from unconsolidated power plants and power plants owned but not operated by us. |
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