Attached files
| file | filename |
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| 8-K - 8-K - NRG ENERGY, INC. | nrg8-kxq32018pr.htm |
Exhibit 99.1
NRG Energy, Inc. Reports Third Quarter 2018 Results and Initiates 2019 Guidance
• | Closed on sale of NRG’s interest in NRG Yield and the Renewables Platform for $1.348 billion1 |
• | Executing on second $500 million share repurchase commitment, totaling $1 billion in 2018 |
• | Announcing an additional $500 million share repurchase authorization |
• | Redeemed $485 million balance of 2022 senior notes and prepaid $155 million of Term Loans, achieving corporate debt reduction target of $640 million; on track to achieve 3.0x net debt / EBITDA for 2018 |
• | Narrowing 20182 guidance to the upper-half of range and initiating 2019 Adjusted EBITDA and FCFbG guidance |
• | C. John Wilder announces retirement from the Board of Directors |
PRINCETON, NJ - November 8, 2018 - NRG Energy, Inc. (NYSE: NRG) today reported third quarter 2018 income from continuing operations of $306 million. Income from continuing operations for the first nine months of 2018 of $601 million, or $1.91 per diluted common share, compares to income from continuing operations of $116 million, or $0.56 per diluted common share for the first nine months of 2017. Adjusted EBITDA for the three and nine months ending September 30, 2018, was $677 million and $1,580 million, respectively. Year-to-date cash from continuing operations totaled $758 million.
“Our quarterly and year to date results demonstrate the benefits of the integrated retail and generation platform,” said Mauricio Gutierrez, President and Chief Executive Officer, NRG. “We are making significant progress on achieving our Transformation Plan targets and capital allocation priorities.”
Consolidated Financial Results
On August 31, 2018, NRG completed the sale of its interest in NRG Yield and the Renewables Platform. As a result, the financial information for NRG Yield, the Renewables Platform and Carlsbad Energy Center has been deconsolidated from the current period and all historical periods have been recast to reflect the presentation of these entities as discontinued operations.
Three Months Ended | Nine Months Ended | |||||||||||||||
($ in millions) | 9/30/18 | 9/30/17 | 9/30/18 | 9/30/17 | ||||||||||||
Income from Continuing Operations | $ | 306 | $ | 185 | $ | 601 | $ | 116 | ||||||||
Cash From Continuing Operations | $ | 401 | $ | 640 | $ | 758 | $ | 558 | ||||||||
Adjusted EBITDA | $ | 677 | $ | 552 | $ | 1,580 | $ | 1,183 | ||||||||
Free Cash Flow Before Growth Investments (FCFbG) | $ | 556 | $ | 462 | $ | 856 | $ | 630 | ||||||||
1 Sale price was reduced by $27 MM to account for the agreed-upon adjustment for Patriot Wind, which is expected to be sold to a third party
1
2 Adjusted for the deconsolidation of NRG Yield, the Renewables Platform, and Carlsbad Energy Center, and the expected sale of South Central
Segment Results
Table 1: Income/(Loss) from Continuing Operations
($ in millions) | Three Months Ended | Nine Months Ended | ||||||||||||||
Segment | 9/30/18 | 9/30/17 | 9/30/18 | 9/30/17 | ||||||||||||
Retail | $ | (127 | ) | $ | 72 | $ | 733 | $ | 380 | |||||||
Generation a | 595 | 272 | 302 | 183 | ||||||||||||
Corporate | (162 | ) | (159 | ) | (434 | ) | (447 | ) | ||||||||
Income from Continuing Operations | $ | 306 | $ | 185 | $ | 601 | $ | 116 | ||||||||
a. In accordance with GAAP, 2018 and 2017 results have been restated to include full impact of the deconsolidation of GenOn, NRG Yield, the Renewables Platform and Carlsbad Energy Center
Table 2: Adjusted EBITDA
($ in millions) | Three Months Ended | Nine Months Ended | ||||||||||||||
Segment | 9/30/18 | 9/30/17 | 9/30/18 | 9/30/17 | ||||||||||||
Retail | $ | 269 | $ | 279 | $ | 755 | $ | 615 | ||||||||
Generation a | 421 | 297 | 850 | 607 | ||||||||||||
Corporate | (13 | ) | (24 | ) | (25 | ) | (39 | ) | ||||||||
Adjusted EBITDA b | $ | 677 | $ | 552 | $ | 1,580 | $ | 1,183 | ||||||||
a. In accordance with GAAP, 2018 and 2017 results have been restated to include full impact of the deconsolidation of GenOn, NRG Yield, the Renewables Platform and Carlsbad Energy Center
b. See Appendices A-1 through A-4 for Operating Segment Reg G reconciliations
Retail: Third quarter Adjusted EBITDA was $269 million, $10 million lower than third quarter 2017, driven by higher margin enhancement costs. Gross margin was $25 million higher as a result of our margin enhancement initiatives (including both value expansion and customer growth), coupled with increased usage, partially offset by higher supply costs.
Generation: Third quarter Adjusted EBITDA was $421 million, $124 million higher than third quarter 2017, driven by:
• | Gulf Coast Region: $115 million increase due to higher generation and higher realized energy prices; and |
• | East/West3: $9 million increase due to higher capacity revenues, partially offset by increased operating costs and the deconsolidation impact of the non-controlling interest in Ivanpah and Agua Caliente. |
Corporate: Third quarter Adjusted EBITDA was $(13) million, $11 million better than the third quarter 2017, driven by lower G&A expenses associated with the Transformation Plan.
2
3 Includes International and Renewables
3
Liquidity and Capital Resources
Table 3: Corporate Liquidity
($ in millions) | 9/30/18 | 12/31/17 | ||||||
Cash and Cash Equivalents | $ | 1,359 | $ | 767 | ||||
Restricted Cash | 28 | 279 | ||||||
Total | $ | 1,387 | $ | 1,046 | ||||
Total credit facility availability | 1,454 | 1,711 | ||||||
Total Liquidity, excluding collateral received | $ | 2,841 | $ | 2,757 | ||||
As of September 30, 2018, NRG-level cash was at $1.4 billion, and $1.5 billion was available under the Company’s credit facilities. Total liquidity was $2.8 billion, including restricted cash. Overall liquidity as of the end of the third quarter 2018 was $84 million higher than at the end of 2017.
NRG Strategic Developments
Transformation Plan
Through the third quarter of 2018, NRG realized $375 million of its 2018 cost savings target as part of the previously announced Transformation Plan, and is on track to realize $500 million in savings in 2018. With respect to the asset sales under the Transformation Plan, on August 31, 2018, the Company completed the sale of its interest in NRG Yield, Inc. and the Renewables Platform to GIP, for approximately $1.348 billion in cash proceeds. NRG is narrowing asset sale proceeds to $3.1 billion from $3.2 billion. The $1 billion sale of South Central is targeted to close by year end 2018 and the balance, Carlsbad and Agua Caliente, in 2019.
Agua Caliente Deconsolidation
As a result of the sale of NRG Yield and the Renewables Platform, the Company no longer controls the Agua Caliente project. Due to this change in control, the Company has deconsolidated the Agua Caliente project from its financial results and is accounting for the project as an equity method investment going forward. This is unrelated to the Company’s planned sale of its remaining interest in Agua Caliente as described in the preceding paragraph.
2018 and 2019 Guidance
NRG has narrowed the range of its Adjusted EBITDA and FCF before Growth Investments guidance for 2018 to reflect the completed sale of NRG Yield and the Renewables Platform, as well as the previously announced sale of the South Central business unit. Additionally, NRG is initiating guidance for fiscal year 2019, which also reflects the aforementioned sales.
Table 4: 2018 and 2019 Adjusted EBITDA, Cash from Operations, and FCF before Growth Investments Guidance
2018 | 2019 | |
($ in millions) | Revised Guidance4 | Guidance |
Adjusted EBITDA5 | $1,700-$1,800 | $1,850-$2,050 |
Cash From Operations | $1,240-$1,340 | $1,405-$1,605 |
Free Cash Flow Before Growth Investments (FCFbG) | $1,050-$1,150 | $1,250-$1,450 |
4 Adjusted for the deconsolidation of NRG Yield, the Renewables Platform, and Carlsbad Energy Center, and the expected sale of South Central
5 Non-GAAP financial measure; see Appendix Tables A-1 through A-5 for GAAP Reconciliation to Net Income that excludes fair value adjustments related to derivatives. The Company is unable to provide guidance for Net Income due to the impact of such fair value adjustments related to derivatives in a given year
4
Capital Allocation Update
During the third quarter of 2018, NRG executed on its second $500 million share repurchase commitment through an Accelerated Share Repurchase program. This brings the total amount of shares to be repurchased in 2018 to $1 billion. In addition, the Board of Directors of the Company has authorized an additional $500 million share repurchase program to be executed into 2019.
To remain leverage-neutral in connection with the $575 million convertible senior notes issued in second quarter of 2018, NRG completed the repurchase of $575 million of its 2022, 2027 and 2028 senior unsecured notes during the third quarter of 2018, generating approximately $20 million of annual interest expense savings7.
Additionally, the Company has completed its targeted $640 million of debt reduction through the redemption of $485 million of its outstanding 6.250% senior notes due 2022 and the prepayment of $155 million of Term Loans, and is on track to achieve a target net debt to Adjusted EBITDA ratio of 3.0x for 2018.
On October 17, 2018, NRG declared a quarterly dividend on the Company's common stock of $0.03 per share, payable November 15, 2018, to stockholders of record as of November 1, 2018, representing $0.12 on an annualized basis.
The Company’s common stock dividend, debt reduction and share repurchases are subject to available capital, market conditions and compliance with associated laws and regulations.
Board of Directors
C. John Wilder informed the Board of Directors that he will retire from the Board, effective November 8, 2018. Mr. Wilder joined the Board in February 2017 and served on the Company’s Business Review Committee (dissolved in July 2017) and Finance and Risk Management Committee. In connection with Mr. Wilder’s resignation, the size of the Board will be reduced from eleven (11) to ten (10) members.
According to C. John Wilder, Independent Director of the Board, “Today, I am announcing my retirement from the NRG Board of Directors.” Mr. Wilder continues, “I applaud the advancements made by the company in the culture and strategy since Mauricio Gutierrez took over as CEO, and most recently with the adoption and execution of the Transformation Plan. This has been a critical year in the Company’s transformation and I am proud of the course charted by my fellow directors and management in rightsizing the business, strengthening the balance sheet, achieving cost excellence and adopting capital allocation principles. I believe NRG has the right team in place to continue its relentless execution that will create significant long-term value and I am excited to remain a long-term shareholder.”
Larry Coben, Chairman of the Board, continued, "On behalf of the Board of Directors, I want to thank John for his outstanding service on the Board and valued direction on all Board matters, particularly the Company's Transformation Plan. Going forward, the Board will continue to assess our size and composition to ensure the proper level of expertise and oversight on behalf of our shareholders."
Mr. Gutierrez added, “John has provided valuable insights and thoughtful counsel as a member of the Board. I want to thank him for his service, and look forward to having him as a valued long-term shareholder."
7 Interest savings assumes average 6.2% interest rate on $575 million debt retired in 2018
5
Earnings Conference Call
On November 8, 2018, NRG will host a conference call at 9:00 a.m. Eastern to discuss these results. Investors, the news media and others may access the live webcast of the conference call and accompanying presentation materials by logging on to NRG’s website at http://www.nrg.com and clicking on “Investors” then "Presentations & Webcasts." The webcast will be archived on the site for those unable to listen in real time.
About NRG
At NRG, we’re redefining power by putting customers at the center of everything we do. We create value by generating electricity and serving nearly 3 million residential and commercial customers through our portfolio of retail electricity brands. A Fortune 500 company, NRG delivers customer-focused solutions for managing electricity, while enhancing energy choice and working towards a sustainable energy future. More information is available at www.nrg.com. Connect with NRG on Facebook, LinkedIn and follow us on Twitter @nrgenergy, @nrginsight.
Safe Harbor Disclosure
In addition to historical information, the information presented in this communication includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Exchange Act. These statements involve estimates, expectations, projections, goals, assumptions, known and unknown risks and uncertainties and can typically be identified by terminology such as “may,” “should,” “could,” “objective,” “projection,” “forecast,” “goal,” “guidance,” “outlook,” “expect,” “intend,” “seek,” “plan,” “think,” “anticipate,” “estimate,” “predict,” “target,” “potential” or “continue,” or the negative of these terms or other comparable terminology. Such forward-looking statements include, but are not limited to, statements about the Company’s future revenues, income, indebtedness, capital structure, plans, expectations, objectives, projected financial performance and/or business results and other future events, and views of economic and market conditions.
Although NRG believes that its expectations are reasonable, it can give no assurance that these expectations will prove to be correct, and actual results may vary materially. Factors that could cause actual results to differ materially from those contemplated herein include, among others, general economic conditions, hazards customary in the power industry, weather conditions, competition in wholesale power markets, the volatility of energy and fuel prices, failure of customers to perform under contracts, changes in the wholesale power markets, changes in government regulations, the condition of capital markets generally, our ability to access capital markets, cyber terrorism and inadequate cyber security, unanticipated outages at our generation facilities, adverse results in current and future litigation, failure to identify, execute or successfully implement acquisitions, repowerings or asset sales, our ability to implement value enhancing improvements to plant operations and company-wide processes, our ability to implement and execute on our publicly announced transformation plan, including any cost savings, margin enhancement, asset sale, and net debt targets, our ability to proceed with projects under development or the inability to complete the construction of such projects on schedule or within budget, the timing or completion of GenOn's emergence from bankruptcy, the inability to maintain or create successful partnering relationships, our ability to operate our businesses efficiently, our ability to retain retail customers, our ability to realize value through our commercial operations strategy, the ability to successfully integrate businesses of acquired companies, our ability to realize anticipated benefits of transactions (including expected cost savings and other synergies) or the risk that anticipated benefits may take longer to realize than expected, and our ability to execute our Capital Allocation Plan. Debt and share repurchases may be made from time to time subject to market conditions and other factors, including as permitted by United States securities laws. Furthermore, any common stock dividend is subject to available capital and market conditions.
NRG undertakes no obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as required by law. The adjusted EBITDA and free cash flow guidance are estimates as of November 8, 2018. These estimates are based on assumptions the company believed to be reasonable as of that date. NRG disclaims any current intention to update such guidance, except as required by law. The foregoing review of factors that could cause NRG’s actual results to differ materially from those contemplated in the forward-looking statements included in this Earnings press release should be considered in connection with information regarding risks and uncertainties that may affect NRG’s future results included in NRG’s filings with the Securities and Exchange Commission at www.sec.gov.
Contacts:
6
Media: | Investors: | ||
Candice Adams | Kevin L. Cole, CFA | ||
609.524.5428 | 609.524.4526 | ||
7
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
Three months ended September 30, | Nine months ended September 30, | ||||||||||||||
(In millions, except for per share amounts) | 2018 | 2017 | 2018 | 2017 | |||||||||||
Operating Revenues | |||||||||||||||
Total operating revenues | $ | 3,061 | $ | 2,740 | $ | 7,795 | $ | 7,246 | |||||||
Operating Costs and Expenses | |||||||||||||||
Cost of operations | 2,307 | 2,072 | 5,730 | 5,589 | |||||||||||
Depreciation and amortization | 112 | 163 | 370 | 490 | |||||||||||
Impairment losses | — | — | 74 | 60 | |||||||||||
Selling, general and administrative | 212 | 190 | 591 | 634 | |||||||||||
Reorganization costs | 27 | 12 | 70 | 18 | |||||||||||
Development costs | 1 | 6 | 9 | 18 | |||||||||||
Total operating costs and expenses | 2,659 | 2,443 | 6,844 | 6,809 | |||||||||||
Other income - affiliate | — | — | — | 87 | |||||||||||
Gain on sale of assets | 14 | — | 30 | 4 | |||||||||||
Operating Income | 416 | 297 | 981 | 528 | |||||||||||
Other Income/(Expense) | |||||||||||||||
Equity in earnings/(losses) of unconsolidated affiliates | 20 | 9 | 26 | (20 | ) | ||||||||||
Other income/(expense), net | 17 | 19 | (4 | ) | 43 | ||||||||||
Loss on debt extinguishment, net | (19 | ) | — | (22 | ) | — | |||||||||
Interest expense | (121 | ) | (139 | ) | (361 | ) | (432 | ) | |||||||
Total other expense | (103 | ) | (111 | ) | (361 | ) | (409 | ) | |||||||
Income from Continuing Operations Before Income Taxes | 313 | 186 | 620 | 119 | |||||||||||
Income tax expense | 7 | 1 | 19 | 3 | |||||||||||
Income from Continuing Operations | 306 | 185 | 601 | 116 | |||||||||||
Loss from discontinued operations, net of income tax | (354 | ) | (22 | ) | (320 | ) | (798 | ) | |||||||
Net (Loss)/Income | (48 | ) | 163 | 281 | (682 | ) | |||||||||
Less: Net income/(loss) attributable to noncontrolling interest and redeemable noncontrolling interests | 24 | (8 | ) | 1 | (63 | ) | |||||||||
Net (Loss)/Income Attributable to NRG Energy, Inc. common stockholders | $ | (72 | ) | $ | 171 | $ | 280 | $ | (619 | ) | |||||
(Loss)/Earnings per Share Attributable to NRG Energy, Inc. Common Stockholders | |||||||||||||||
Weighted average number of common shares outstanding — basic | 299 | 317 | 309 | 317 | |||||||||||
Income from continuing operations per weighted average common share — basic | $ | 0.94 | $ | 0.61 | $ | 1.94 | $ | 0.56 | |||||||
Loss from discontinued operations per weighted average common share — basic | $ | (1.18 | ) | $ | (0.07 | ) | $ | (1.03 | ) | $ | (2.51 | ) | |||
(Loss)/Earnings per Weighted Average Common Share — Basic | $ | (0.24 | ) | $ | 0.54 | $ | 0.91 | $ | (1.95 | ) | |||||
Weighted average number of common shares outstanding — diluted | 299 | 322 | 313 | 317 | |||||||||||
Income from continuing operations per weighted average common share — diluted | $ | 0.94 | $ | 0.60 | $ | 1.91 | $ | 0.56 | |||||||
Loss from discontinued operations per weighted average common share — diluted | $ | (1.18 | ) | $ | (0.07 | ) | $ | (1.02 | ) | $ | (2.51 | ) | |||
(Loss)/Earnings per Weighted Average Common Share — Diluted | $ | (0.24 | ) | $ | 0.53 | $ | 0.89 | $ | (1.95 | ) | |||||
Dividends Per Common Share | $ | 0.03 | $ | 0.03 | $ | 0.09 | $ | 0.09 | |||||||
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NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS)/INCOME
(Unaudited)
Three months ended September 30, | Nine months ended September 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In millions) | |||||||||||||||
Net (loss)/income | $ | (48 | ) | $ | 163 | $ | 281 | $ | (682 | ) | |||||
Other comprehensive income/(loss), net of tax | |||||||||||||||
Unrealized gain on derivatives, net of income tax expense of $0, $0, $1, and $0 | 4 | 7 | 24 | 7 | |||||||||||
Foreign currency translation adjustments, net of income tax expense of $0, $0, $0, and $0 | (2 | ) | 2 | (8 | ) | 9 | |||||||||
Available-for-sale securities, net of income tax expense of $0, $0, $0, and $0 | — | 1 | 1 | 2 | |||||||||||
Defined benefit plans, net of income tax expense of $0, $0, $0, and $0 | (1 | ) | (1 | ) | (3 | ) | 25 | ||||||||
Other comprehensive income | 1 | 9 | 14 | 43 | |||||||||||
Comprehensive (loss)/income | (47 | ) | 172 | 295 | (639 | ) | |||||||||
Less: Comprehensive income/(loss) attributable to noncontrolling interest and redeemable noncontrolling interest | 26 | (5 | ) | 15 | (61 | ) | |||||||||
Comprehensive (loss)/income attributable to NRG Energy, Inc. common stockholders | $ | (73 | ) | $ | 177 | $ | 280 | $ | (578 | ) | |||||
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NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
September 30, 2018 | December 31, 2017 | ||||||
(In millions, except shares) | (Unaudited) | ||||||
ASSETS | |||||||
Current Assets | |||||||
Cash and cash equivalents | $ | 1,359 | $ | 767 | |||
Funds deposited by counterparties | 30 | 37 | |||||
Restricted cash | 28 | 279 | |||||
Accounts receivable, net | 1,297 | 960 | |||||
Inventory | 408 | 486 | |||||
Derivative instruments | 683 | 624 | |||||
Cash collateral paid in support of energy risk management activities | 209 | 171 | |||||
Accounts receivable - affiliate | 19 | 186 | |||||
Prepayments and other current assets | 248 | 179 | |||||
Current assets - held for sale | — | 116 | |||||
Current assets - discontinued operations | 4 | 705 | |||||
Total current assets | 4,285 | 4,510 | |||||
Property, plant and equipment, net | 3,599 | 6,435 | |||||
Other Assets | |||||||
Equity investments in affiliates | 452 | 182 | |||||
Notes receivable, less current portion | 10 | 2 | |||||
Goodwill | 539 | 539 | |||||
Intangible assets, net | 602 | 507 | |||||
Nuclear decommissioning trust fund | 719 | 692 | |||||
Derivative instruments | 392 | 159 | |||||
Deferred income taxes | 11 | 6 | |||||
Other non-current assets | 281 | 294 | |||||
Non-current assets held-for-sale | — | 43 | |||||
Non-current assets - discontinued operations | 560 | 10,181 | |||||
Total other assets | 3,566 | 12,605 | |||||
Total Assets | $ | 11,450 | $ | 23,550 | |||
LIABILITIES AND STOCKHOLDERS’ EQUITY | |||||||
Current Liabilities | |||||||
Current portion of long-term debt and capital leases | $ | 593 | $ | 204 | |||
Accounts payable | 824 | 711 | |||||
Accounts payable - affiliate | 14 | 57 | |||||
Derivative instruments | 550 | 537 | |||||
Cash collateral received in support of energy risk management activities | 30 | 37 | |||||
Accrued expenses and other current liabilities | 659 | 769 | |||||
Accrued expenses and other current liabilities - affiliate | 1 | 161 | |||||
Current liabilities - held-for-sale | — | 72 | |||||
Current liabilities - discontinued operations | 52 | 864 | |||||
Total current liabilities | 2,723 | 3,412 | |||||
Non-Current Liabilities | |||||||
Long-term debt and capital leases | 6,658 | 9,180 | |||||
Nuclear decommissioning reserve | 278 | 269 | |||||
Nuclear decommissioning trust liability | 432 | 415 | |||||
Deferred income taxes | 18 | 21 | |||||
Derivative instruments | 357 | 143 | |||||
Out-of-market contracts, net | 177 | 195 | |||||
Other non-current liabilities | 1,177 | 1,002 | |||||
Non-current liabilities - held-for-sale | — | 8 | |||||
Non-current liabilities - discontinued operations | 547 | 6,859 | |||||
Total non-current liabilities | 9,644 | 18,092 | |||||
Total Liabilities | 12,367 | 21,504 | |||||
Redeemable noncontrolling interest in subsidiaries | 19 | 78 | |||||
Commitments and Contingencies | |||||||
Stockholders’ Equity | |||||||
Common stock | 4 | 4 | |||||
Additional paid-in capital | 8,453 | 8,377 | |||||
Accumulated deficit | (6,001 | ) | (6,269 | ) | |||
Less treasury stock, at cost - 129,948,876 and 101,580,045 shares, at September 30, 2018 and December 31, 2017, respectively | (3,334 | ) | (2,386 | ) | |||
Accumulated other comprehensive loss | (58 | ) | (72 | ) | |||
Noncontrolling interest | — | 2,314 | |||||
Total Stockholders’ Equity | (936 | ) | 1,968 | ||||
Total Liabilities and Stockholders’ Equity | $ | 11,450 | $ | 23,550 | |||
10
NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
Nine months ended September 30, | |||||||
(In millions) | 2018 | 2017 | |||||
Cash Flows from Operating Activities | |||||||
Net income/(loss) | $ | 281 | $ | (682 | ) | ||
Loss from discontinued operations, net of income tax | (320 | ) | (798 | ) | |||
Income from continuing operations | 601 | 116 | |||||
Adjustments to reconcile net income to net cash provided by operating activities: | |||||||
Distributions and equity in earnings of unconsolidated affiliates | 10 | — | |||||
Depreciation, amortization and accretion | 403 | 490 | |||||
Provision for bad debts | 57 | 57 | |||||
Amortization of nuclear fuel | 38 | 37 | |||||
Amortization of financing costs and debt discount/premiums | 21 | 15 | |||||
Adjustment for debt extinguishment | 22 | 3 | |||||
Amortization of intangibles and out-of-market contracts | 21 | 79 | |||||
Amortization of unearned equity compensation | 36 | 27 | |||||
Impairment losses | 89 | 60 | |||||
Changes in deferred income taxes and liability for uncertain tax benefits | (6 | ) | (1 | ) | |||
Changes in nuclear decommissioning trust liability | 50 | 20 | |||||
Changes in derivative instruments | (17 | ) | 36 | ||||
Changes in collateral deposits in support of energy risk management activities | (30 | ) | (103 | ) | |||
Gain on sale of emission allowances | (20 | ) | 21 | ||||
Gain on sale of assets | (30 | ) | (4 | ) | |||
GenOn settlement in July 2018 | (125 | ) | — | ||||
Loss on deconsolidation of business | 13 | — | |||||
Changes in other working capital | (375 | ) | (295 | ) | |||
Cash provided by continuing operations | 758 | 558 | |||||
Cash provided by discontinued operations | 324 | 178 | |||||
Net Cash Provided by Operating Activities | 1,082 | 736 | |||||
Cash Flows from Investing Activities | |||||||
Acquisitions of businesses, net of cash acquired | (209 | ) | (12 | ) | |||
Capital expenditures | (345 | ) | (172 | ) | |||
Purchases of emission allowances | (30 | ) | (47 | ) | |||
Proceeds from sale of emission allowances | 54 | 104 | |||||
Investments in nuclear decommissioning trust fund securities | (449 | ) | (402 | ) | |||
Proceeds from the sale of nuclear decommissioning trust fund securities | 398 | 382 | |||||
Proceeds from sale of assets, net of cash disposed and sale of discontinued operations, net of fees | 1,555 | 309 | |||||
Deconsolidation of business | (268 | ) | — | ||||
Changes in investments in unconsolidated affiliates | (62 | ) | 24 | ||||
Other | — | 30 | |||||
Cash provided by continuing operations | 644 | 216 | |||||
Cash used by discontinued operations | (703 | ) | (638 | ) | |||
Net Cash (Used) by Investing Activities | (59 | ) | (422 | ) | |||
Cash Flows from Financing Activities | |||||||
Payment of dividends to common stockholders | (28 | ) | (28 | ) | |||
Payment for treasury stock | (1,000 | ) | — | ||||
Proceeds from issuance of long-term debt | 995 | 308 | |||||
Payments for short and long-term debt | (970 | ) | (343 | ) | |||
Receivable from affiliate | (26 | ) | (125 | ) | |||
Net distributions to noncontrolling interests from subsidiaries | (17 | ) | (18 | ) | |||
Payment of debt issuance costs | (19 | ) | (39 | ) | |||
Other | (4 | ) | (8 | ) | |||
Cash used by continuing operations | (1,069 | ) | (253 | ) | |||
Cash provided by discontinued operations | 403 | 39 | |||||
Net Cash Used by Financing Activities | (666 | ) | (214 | ) | |||
Effect of exchange rate changes on cash and cash equivalents | 1 | (10 | ) | ||||
Change in Cash from discontinued operations | 24 | (421 | ) | ||||
Net Increase in Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash | 334 | 511 | |||||
Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash at Beginning of Period | 1,083 | 860 | |||||
Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash at End of Period | $ | 1,417 | $ | 1,371 | |||
11
Appendix Table A-1: Third Quarter 2018 Adjusted EBITDA Reconciliation by Operating Segment
The following table summarizes the calculation of Adj. EBITDA and provides a reconciliation to income/(loss) from continuing operations:
($ in millions) | Gulf Coast | East/West1 | Generation | Retail | Corp/Elim | Total | ||||||
Income/(Loss) from Continuing Operations | 417 | 178 | 595 | (127 | ) | (162 | ) | 306 | ||||
Plus: | ||||||||||||
Interest expense, net | — | 10 | 10 | 1 | 105 | 116 | ||||||
Income tax | — | — | — | — | 7 | 7 | ||||||
Loss on debt extinguishment | — | — | — | — | 19 | 19 | ||||||
Depreciation and amortization | 43 | 30 | 73 | 30 | 9 | 112 | ||||||
ARO Expense | 9 | 4 | 13 | — | — | 13 | ||||||
Contract amortization | 2 | — | 2 | — | — | 2 | ||||||
Lease amortization | — | (2 | ) | (2 | ) | — | — | (2 | ) | |||
EBITDA | 471 | 220 | 691 | (96 | ) | (22 | ) | 573 | ||||
Adjustment to reflect NRG share of adjusted EBITDA in unconsolidated affiliates | 2 | 25 | 27 | — | — | 27 | ||||||
Reorganization costs | 1 | 2 | 3 | 6 | 18 | 27 | ||||||
Deactivation costs | — | — | — | — | 3 | 3 | ||||||
Gain on sale of business | — | 1 | 1 | — | (14 | ) | (13 | ) | ||||
Other non recurring charges | 1 | (12 | ) | (11 | ) | — | 2 | (9 | ) | |||
Mark to market (MtM) (gains)/losses on economic hedges | (268 | ) | (22 | ) | (290 | ) | 359 | — | 69 | |||
Adjusted EBITDA | 207 | 214 | 421 | 269 | (13 | ) | 677 | |||||
1 Includes International, remaining renewables and Generation eliminations
Third Quarter 2018 condensed financial information by Operating Segment:
($ in millions) | Gulf Coast | East/West1 | Generation | Retail | Corp/Elim | Total | ||||||
Operating revenues | 782 | 497 | 1,279 | 2,202 | (480 | ) | 3,001 | |||||
Cost of sales | 413 | 192 | 605 | 1,702 | (477 | ) | 1,830 | |||||
Economic gross margin2 | 369 | 305 | 674 | 500 | (3 | ) | 1,171 | |||||
Operations & maintenance and other cost of operations 3 | 146 | 111 | 257 | 89 | (3 | ) | 343 | |||||
Selling, marketing, general and administrative | 29 | 25 | 54 | 144 | 14 | 212 | ||||||
Other expense/(income) 4 | (13 | ) | (45 | ) | (58 | ) | (2 | ) | (1 | ) | (61 | ) |
Adjusted EBITDA | 207 | 214 | 421 | 269 | (13 | ) | 677 | |||||
1 Includes International, remaining renewables and Generation eliminations
2 Excludes MtM loss of $69 million and contract amortization of $2 million
3 Excludes deactivation costs of $3 million
4 Excludes gain on sale of business of $13 million, reorganization costs of $27 million and loss on debt extinguishment of $19 million
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The following table reconciles the condensed financial information to Adjusted EBITDA:
($ in millions) | Condensed financial information | Interest, tax, depr., amort. | MtM | Deactivation | Other adj. | Adjusted EBITDA | ||||||
Operating revenues | 3,061 | (5 | ) | (55 | ) | — | — | 3,001 | ||||
Cost of operations | 1,961 | (7 | ) | (124 | ) | — | — | 1,830 | ||||
Gross margin | 1,100 | 2 | 69 | — | — | 1,171 | ||||||
Operations & maintenance and other cost of operations | 346 | — | — | (3 | ) | — | 343 | |||||
Selling, marketing, general & administrative | 212 | — | — | — | — | 212 | ||||||
Other expense/(income) 1 | 236 | (246 | ) | — | — | (51 | ) | (61 | ) | |||
Income/(Loss) from Continuing Operations | 306 | 248 | 69 | 3 | 51 | 677 | ||||||
1 Other adj. includes gain on sale of assets of $13 million, reorganization costs of $27 million and loss on debt extinguishment of $19 million
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Appendix Table A-2: Third Quarter 2017 Adjusted EBITDA Reconciliation by Operating Segment
The following table summarizes the calculation of Adjusted EBITDA and provides a reconciliation to income/(loss) from continuing operations:
($ in millions) | Gulf Coast | East/West1 | Generation | Retail | Corp/Elim | Total | ||||||
Income/(Loss) from Continuing Operations | 155 | 117 | 272 | 72 | (159 | ) | 185 | |||||
Plus: | ||||||||||||
Interest expense, net | — | 24 | 24 | 1 | 111 | 136 | ||||||
Income tax | — | — | — | — | 1 | 1 | ||||||
Depreciation and amortization | 69 | 59 | 128 | 28 | 7 | 163 | ||||||
ARO Expense | 4 | 3 | 7 | — | — | 7 | ||||||
Contract amortization | 3 | 1 | 4 | (1 | ) | — | 3 | |||||
Lease amortization | — | (2 | ) | (2 | ) | — | — | (2 | ) | |||
EBITDA | 231 | 202 | 433 | 100 | (40 | ) | 493 | |||||
Adjustment to reflect NRG share of adjusted EBITDA in unconsolidated affiliates | (6 | ) | 14 | 8 | — | (1 | ) | 7 | ||||
Acquisition-related transaction & integration costs | — | — | — | — | 3 | 3 | ||||||
Reorganization costs | 3 | — | 3 | 5 | 4 | 12 | ||||||
Deactivation costs | — | 2 | 2 | — | 3 | 5 | ||||||
Other non recurring charges | (1 | ) | (3 | ) | (4 | ) | 1 | 7 | 4 | |||
Mark to market (MtM) (gains)/losses on economic hedges | (135 | ) | (10 | ) | (145 | ) | 173 | — | 28 | |||
Adjusted EBITDA | 92 | 205 | 297 | 279 | (24 | ) | 552 | |||||
1 Includes International, remaining renewables and Generation eliminations
Third Quarter 2017 condensed financial information by Operating Segment:
($ in millions) | Gulf Coast | East/West1 | Generation | Retail | Corp/Elim | Total | ||||||
Operating revenues | 655 | 520 | 1,175 | 1,935 | (397 | ) | 2,713 | |||||
Cost of sales | 395 | 204 | 599 | 1,460 | (394 | ) | 1,665 | |||||
Economic gross margin2 | 260 | 316 | 576 | 475 | (3 | ) | 1,048 | |||||
Operations & maintenance and other cost of operations3 | 143 | 111 | 254 | 87 | 3 | 344 | ||||||
Selling, marketing, general & administrative | 35 | 16 | 51 | 109 | 30 | 190 | ||||||
Other expense/(income)4 | (10 | ) | (16 | ) | (26 | ) | — | (12 | ) | (38 | ) | |
Adjusted EBITDA | 92 | 205 | 297 | 279 | (24 | ) | 552 | |||||
1 Includes International, remaining renewables and Generation eliminations
2 Excludes MtM loss of $28 million and contract amortization of $3 million
3 Excludes deactivation costs of $5 million
4 Excludes acquisition-related transaction & integration costs of $3 million and reorganization costs of $12 million
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The following table reconciles the condensed financial information to Adjusted EBITDA:
($ in millions) | Condensed financial information | Interest, tax, depr., amort. | MtM | Deactivation | Other adj. | Adjusted EBITDA | ||||||
Operating revenues | 2,740 | (5 | ) | (22 | ) | — | — | 2,713 | ||||
Cost of operations | 1,723 | (8 | ) | (50 | ) | — | — | 1,665 | ||||
Gross margin | 1,017 | 3 | 28 | — | — | 1,048 | ||||||
Operations & maintenance and other cost of operations | 349 | — | — | (5 | ) | — | 344 | |||||
Selling, marketing, general & administrative | 190 | — | — | — | — | 190 | ||||||
Other expense/(income) 1 | 293 | (305 | ) | — | — | (26 | ) | (38 | ) | |||
Income/(Loss) from Continuing Operations | 185 | 308 | 28 | 5 | 26 | 552 | ||||||
1 Other adj. includes acquisition-related transaction & integration costs of $3 million and reorganization costs of $12 million
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Appendix Table A-3: YTD Third Quarter 2018 Adjusted EBITDA Reconciliation by Operating Segment
The following table summarizes the calculation of Adj. EBITDA and provides a reconciliation to income/(loss) from continuing operations:
($ in millions) | Gulf Coast | East/West1 | Generation | Retail | Corp/Elim | Total | ||||||
Income/(Loss) from Continuing Operations | 156 | 146 | 302 | 733 | (434 | ) | 601 | |||||
Plus: | ||||||||||||
Interest expense, net | — | 46 | 46 | 2 | 301 | 349 | ||||||
Income tax | — | 1 | 1 | — | 18 | 19 | ||||||
Loss on debt extinguishment | — | — | — | — | 22 | 22 | ||||||
Depreciation and amortization | 128 | 131 | 259 | 86 | 25 | 370 | ||||||
ARO Expense | 21 | 12 | 33 | — | — | 33 | ||||||
Contract Amortization | 7 | 1 | 8 | — | — | 8 | ||||||
Lease amortization | — | (6 | ) | (6 | ) | — | — | (6 | ) | |||
EBITDA | 312 | 331 | 643 | 821 | (68 | ) | 1,396 | |||||
Adjustment to reflect NRG share of adjusted EBITDA in unconsolidated affiliates | 5 | 47 | 52 | — | 1 | 53 | ||||||
Acquisition-related transaction & integration costs | — | — | — | 2 | 3 | 5 | ||||||
Reorganization costs | 5 | 5 | 10 | 10 | 50 | 70 | ||||||
Deactivation costs | — | 10 | 10 | — | 8 | 18 | ||||||
Gain on sale of business | — | 2 | 2 | — | (29 | ) | (27 | ) | ||||
Other non recurring charges | 27 | 13 | 40 | 3 | 10 | 53 | ||||||
Impairments | — | 74 | 74 | — | — | 74 | ||||||
Market to market (MtM) (gains)/losses on economic hedges | 14 | 5 | 19 | (81 | ) | — | (62 | ) | ||||
Adjusted EBITDA | 363 | 487 | 850 | 755 | (25 | ) | 1,580 | |||||
1 Includes International, remaining renewables and Generation eliminations
YTD Third Quarter 2018 condensed financial information by Operating Segment:
($ in millions) | Gulf Coast | East/West1 | Generation | Retail | Corp/Elim | Total | ||||||
Operating revenues | 1,923 | 1,286 | 3,209 | 5,502 | (897 | ) | 7,814 | |||||
Cost of sales | 1,028 | 439 | 1,467 | 4,130 | (895 | ) | 4,702 | |||||
Economic gross margin2 | 895 | 847 | 1,742 | 1,372 | (2 | ) | 3,112 | |||||
Operations & maintenance and other cost of operations3 | 494 | 363 | 857 | 236 | (10 | ) | 1,083 | |||||
Selling, marketing, general & administrative | 83 | 82 | 165 | 385 | 41 | 591 | ||||||
Other expense/(income)4 | (45 | ) | (85 | ) | (130 | ) | (4 | ) | (8 | ) | (142 | ) |
Adjusted EBITDA | 363 | 487 | 850 | 755 | (25 | ) | 1,580 | |||||
1 Includes International, remaining renewables and Generation eliminations
2 Excludes MtM gain of $62 million and contract amortization of $8 million
3 Excludes deactivation costs of $18 million
4 Excludes gain on sale of business of $27 million, acquisition-related transaction & integration costs of $5 million, reorganization costs of $70 million and loss on debt extinguishment of $22 million
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The following table reconciles the condensed financial information to Adjusted EBITDA:
($ in millions) | Condensed financial information | Interest, tax, depr., amort. | MtM | Deactivation | Other adj. | Adjusted EBITDA | ||||||
Operating revenues | 7,795 | (12 | ) | 31 | — | — | 7,814 | |||||
Cost of operations | 4,629 | (20 | ) | 93 | — | — | 4,702 | |||||
Gross margin | 3,166 | 8 | (62 | ) | — | — | 3,112 | |||||
Operations & maintenance and other cost of operations | 1,101 | — | — | (18 | ) | — | 1,083 | |||||
Selling, marketing, general & administrative | 591 | — | — | — | — | 591 | ||||||
Other expense/(income) 1 | 873 | (765 | ) | — | — | (250 | ) | (142 | ) | |||
Income/(Loss) from Continuing Operations | 601 | 773 | (62 | ) | 18 | 250 | 1,580 | |||||
1 Other adj. includes gain on sale of assets of $27 million, acquisition-related transaction & integration costs of $5 million, reorganization costs of $70 million and loss on debt extinguishment of $22 million
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Appendix Table A-4: YTD Third Quarter 2017 Adjusted EBITDA Reconciliation by Operating Segment
The following table summarizes the calculation of Adjusted EBITDA and provides a reconciliation to income/(loss) from continuing operations:
($ in millions) | Gulf Coast | East/West1 | Generation | Retail | Corp/Elim | Total | ||||||
Income/(Loss) from Continuing Operations | 50 | 133 | 183 | 380 | (447 | ) | 116 | |||||
Plus: | ||||||||||||
Interest expense, net | — | 74 | 74 | 3 | 349 | 426 | ||||||
Income tax | — | 2 | 2 | (9 | ) | 10 | 3 | |||||
Depreciation and amortization | 207 | 178 | 385 | 81 | 24 | 490 | ||||||
ARO Expense | 11 | 9 | 20 | — | — | 20 | ||||||
Contract Amortization | 10 | 3 | 13 | — | — | 13 | ||||||
Lease amortization | — | (6 | ) | (6 | ) | — | — | (6 | ) | |||
EBITDA | 278 | 393 | 671 | 455 | (64 | ) | 1,062 | |||||
Adjustment to reflect NRG share of adjusted EBITDA in unconsolidated affiliates | 15 | 43 | 58 | — | (11 | ) | 47 | |||||
Acquisition-related transaction & integration costs | — | — | — | — | 3 | 3 | ||||||
Reorganization costs | 3 | — | 3 | 5 | 10 | 18 | ||||||
Deactivation costs | — | 3 | 3 | — | 7 | 10 | ||||||
Other non recurring charges | (25 | ) | — | (25 | ) | 1 | 16 | (8 | ) | |||
Impairments | 42 | 18 | 60 | — | — | 60 | ||||||
MtM (gains)/losses on economic hedges | (152 | ) | (11 | ) | (163 | ) | 154 | — | (9 | ) | ||
Adjusted EBITDA | 161 | 446 | 607 | 615 | (39 | ) | 1,183 | |||||
1 Includes International, remaining renewables and Generation eliminations
YTD Third Quarter 2017 condensed financial information by Operating Segment:
($ in millions) | Gulf Coast | East/West1 | Generation | Retail | Corp/Elim | Total | ||||||
Operating revenues | 1,752 | 1,348 | 3,100 | 4,868 | (910 | ) | 7,058 | |||||
Cost of sales | 1,049 | 500 | 1,549 | 3,671 | (904 | ) | 4,316 | |||||
Economic gross margin2 | 703 | 848 | 1,551 | 1,197 | (6 | ) | 2,742 | |||||
Operations & maintenance and other cost of operations3 | 442 | 370 | 812 | 246 | 13 | 1,071 | ||||||
Selling, marketing, general & administrative | 97 | 73 | 170 | 334 | 130 | 634 | ||||||
Other expense/(income)4 | 3 | (41 | ) | (38 | ) | 2 | (110 | ) | (146 | ) | ||
Adjusted EBITDA | 161 | 446 | 607 | 615 | (39 | ) | 1,183 | |||||
1 Includes International, remaining renewables and Generation eliminations
2 Excludes MtM gain of $9 million and contract amortization of $13 million
2 Excludes deactivation costs of $10 million
3 Excludes acquisition-related transaction & integration costs of $3 million and reorganization costs of $18 million
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The following table reconciles the condensed financial information to Adjusted EBITDA:
($ in millions) | Condensed financial information | Interest, tax, depr., amort. | MtM | Deactivation | Other adj. | Adjusted EBITDA | ||||||
Operating revenues | 7,246 | (11 | ) | (177 | ) | — | — | 7,058 | ||||
Cost of operations | 4,508 | (24 | ) | (168 | ) | — | — | 4,316 | ||||
Gross margin | 2,738 | 13 | (9 | ) | — | — | 2,742 | |||||
Operations & maintenance and other cost of operations | 1,081 | — | — | (10 | ) | — | 1,071 | |||||
Selling, marketing, general & administrative | 634 | — | — | — | — | 634 | ||||||
Other expense/(income) 1 | 907 | (933 | ) | — | — | (120 | ) | (146 | ) | |||
Income/(Loss) from Continuing Operations | 116 | 946 | (9 | ) | 10 | 120 | 1,183 | |||||
1 Other adj. includes acquisition-related transaction & integration costs of $3 million and reorganization costs of $18 million
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Appendix Table A-5: 2018 and 2017 Three and Nine Months Ended September 30 Adjusted Cash Flow from Operations Reconciliations
The following table summarizes the calculation of adjusted cash flow operating activities providing a reconciliation to net cash provided by operating activities:
Three Months Ended | ||||||
($ in millions) | September 30, 2018 | September 30, 2017 | ||||
Net Cash Provided by Operating Activities | 402 | 555 | ||||
Reclassifying of net receipts for settlement of acquired derivatives that include financing elements | — | (2 | ) | |||
Merger, integration and cost-to-achieve expenses (1) | 27 | 14 | ||||
GenOn Settlement (2) | 132 | 13 | ||||
Adjustment for change in collateral | 27 | (86 | ) | |||
Adjusted Cash Flow from Operating Activities | 588 | 494 | ||||
Maintenance CapEx, net (3) | (30 | ) | (32 | ) | ||
Environmental CapEx, net | (1 | ) | — | |||
Distributions to non-controlling interests | (1 | ) | — | |||
Free Cash Flow Before Growth Investments (FCFbG) | 556 | 462 | ||||
(1) 2018 includes cost-to-achieve expenses associated with the Transformation Plan announced on July 2017 call.
(2) 2018 includes settlement consideration of $261 million, transition services credit of $28 million, and pension contribution of $12 million, less $151 million repayment of intercompany revolver loan, accrued interest and fees of $12 million, certain other balances due to NRG of $6 million; 2017 includes pension contribution of $13 million.
(3) Includes insurance proceeds of $4 million in 2017.
Nine Months Ended | ||||||
($ in millions) | September 30, 2018 | September 30, 2017 | ||||
Net Cash Provided by Operating Activities | 758 | 558 | ||||
Merger, integration and cost-to-achieve expenses (1) | 71 | 14 | ||||
Sale of Land | 3 | 8 | ||||
GenOn Settlement (2) | 132 | 13 | ||||
Adjustment for change in collateral (3) | 45 | 182 | ||||
Adjusted Cash Flow from Operating Activities | 1,009 | 775 | ||||
Maintenance CapEx, net (4) | (135 | ) | (102 | ) | ||
Environmental CapEx, net | (1 | ) | (25 | ) | ||
Distributions to non-controlling interests | (17 | ) | (18 | ) | ||
Free Cash Flow Before Growth Investments (FCFbG) | 856 | 630 | ||||
(1) 2018 includes cost-to-achieve expenses associated with the Transformation Plan announced on July 2017 call.
(2) 2018 includes settlement consideration of $261 million, transition services credit of $28 million, and pension contribution of $12 million, less $151 million repayment of intercompany revolver loan, accrued interest and fees of $12 million, certain other balances due to NRG of $6 million; 2017 includes pension contribution of $13 million.
(3) 2018 includes $15MM return of collateral to GenOn, and 2017 reflects change in NRG’s cash collateral balance as of 3Q2017 including $79MM of collateral postings from deconsolidated affiliate (GenOn).
(4) Includes insurance proceeds of $22 million in 2017.
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Appendix Table A-6: Third Quarter YTD 2018 Sources and Uses of Liquidity
The following table summarizes the sources and uses of liquidity through third quarter of 2018:
($ in millions) | Nine Months Ended September 30, 2018 | |
Sources: | ||
Adjusted cash flow from operations | 1,009 | |
Convertible Note Issuance | 575 | |
Asset sales | 1,468 | |
Uses: | ||
Share repurchases | (1,000 | ) |
Debt Repayment, net of proceeds | (683 | ) |
Deconsolidation of Ivanpah and Agua Caliente | (268 | ) |
Decrease in credit facility | (257 | ) |
Growth investments and acquisitions, net | (151 | ) |
GenOn Settlement | (157 | ) |
Maintenance and environmental capex, net | (136 | ) |
Cost-to-achieve expenses(1) | (114 | ) |
Nuclear Decommissioning Trust | (51 | ) |
Collateral (2) | (38 | ) |
Common Stock Dividends | (28 | ) |
Distributions to non-controlling interests | (17 | ) |
Other Investing and Financing | (68 | ) |
Change in Total Liquidity | 84 | |
(1) Includes capital expenditures associated with the Transformation Plan
(2) Excludes impact of Funds deposited by Counterparties
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Appendix Table A-7: 2018 and 2019 Adjusted EBITDA Guidance Reconciliation
The following table summarizes the calculation of Adjusted EBITDA providing reconciliation to net income:
2018 Adjusted EBITDA Revised Guidance | ||||||||
($ in millions) | Low | High | ||||||
Income from Continuing Operations 1 | 405 | 505 | ||||||
Income Tax | 15 | 15 | ||||||
Interest Expense | 445 | 445 | ||||||
Depreciation, Amortization, Contract Amortization and ARO Expense | 490 | 490 | ||||||
Adjustment to reflect NRG share of adjusted EBITDA in unconsolidated affiliates | 65 | 65 | ||||||
Other Costs 2 | 280 | 280 | ||||||
Adjusted EBITDA | 1,700 | 1,800 | ||||||
2019 Guidance | ||||||||
($ in millions) | Low | High | ||||||
Income from Continuing Operations 1 | 965 | 1,165 | ||||||
Income Tax | 15 | 15 | ||||||
Interest Expense | 350 | 350 | ||||||
Depreciation, Amortization, Contract Amortization and ARO Expense | 430 | 430 | ||||||
Adjustment to reflect NRG share of adjusted EBITDA in unconsolidated affiliates | 40 | 40 | ||||||
Other Costs 2 | 50 | 50 | ||||||
Adjusted EBITDA | 1,850 | 2,050 | ||||||
1. | For purposes of guidance, discontinued operations are excluded and fair value adjustments related to derivatives are assumed to be zero. |
2. | 2018 includes impairments, loss on debt extinguishment, deactivation costs, and cost-to-achieve expenses; 2019 includes deactivation costs and cost-to-achieve expenses |
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Appendix Table A-8: 2018 and 2019 FCFbG Guidance Reconciliation
The following table summarizes the calculation of Free Cash Flow before Growth providing reconciliation to Cash from Operations:
2018 | 2019 | ||||
($ in millions) | Revised Guidance | Guidance | |||
Adjusted EBITDA | $1,700 - $1,800 | $1,850 - $2,050 | |||
Cash Interest payments | (445 | ) | (350 | ) | |
Cash Income tax | (15 | ) | (15 | ) | |
Collateral / working capital / other | — | (80 | ) | ||
Cash From Operations | $1,240 - $1,340 | $1,405 - $1,605 | |||
Adjusted Cash flow from operations | $1,240 - $1,340 | $1,405 - $1,605 | |||
Maintenance capital expenditures, net | (170) - (180) | (145) - (165) | |||
Environmental capital expenditures, net | (0) - (5) | (0) - (5) | |||
Distributions to non-controlling interests | (10) - (20) | - | |||
Free Cash Flow - before Growth | $1,050 - $1,150 | $1,250 - $1,450 | |||
EBITDA and Adjusted EBITDA are non-GAAP financial measures. These measurements are not recognized in accordance with GAAP and should not be viewed as an alternative to GAAP measures of performance. The presentation of Adjusted EBITDA should not be construed as an inference that NRG’s future results will be unaffected by unusual or non-recurring items.
EBITDA represents net income before interest (including loss on debt extinguishment), taxes, depreciation and amortization. EBITDA is presented because NRG considers it an important supplemental measure of its performance and believes debt-holders frequently use EBITDA to analyze operating performance and debt service capacity. EBITDA has limitations as an analytical tool, and you should not consider it in isolation, or as a substitute for analysis of our operating results as reported under GAAP. Some of these limitations are:
• | EBITDA does not reflect cash expenditures, or future requirements for capital expenditures, or contractual commitments; |
• | EBITDA does not reflect changes in, or cash requirements for, working capital needs; |
• | EBITDA does not reflect the significant interest expense, or the cash requirements necessary to service interest or principal payments, on debt or cash income tax payments; |
• | Although depreciation and amortization are non-cash charges, the assets being depreciated and amortized will often have to be replaced in the future, and EBITDA does not reflect any cash requirements for such replacements; and |
• | Other companies in this industry may calculate EBITDA differently than NRG does, limiting its usefulness as a comparative measure. |
Because of these limitations, EBITDA should not be considered as a measure of discretionary cash available to use to invest in the growth of NRG’s business. NRG compensates for these limitations by relying primarily on our GAAP results and using EBITDA and Adjusted EBITDA only supplementally. See the statements of cash flow included in the financial statements that are a part of this news release.
Adjusted EBITDA is presented as a further supplemental measure of operating performance. As NRG defines it, Adjusted EBITDA represents EBITDA excluding impairment losses, gains or losses on sales, dispositions or retirements of assets, any mark-to-market gains or losses from accounting for derivatives, adjustments to exclude the Adjusted EBITDA related to the non-controlling interest, gains or losses on the repurchase, modification or extinguishment of debt, the impact of restructuring and any extraordinary, unusual or non-recurring items plus adjustments to reflect the Adjusted EBITDA from our unconsolidated investments. The reader is encouraged to evaluate each adjustment and the reasons NRG considers it appropriate for supplemental analysis. As an analytical tool, Adjusted EBITDA is subject to all of the limitations applicable to EBITDA. In addition, in evaluating Adjusted EBITDA, the reader should be aware that in the future NRG may incur expenses similar to the adjustments in this news release.
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Management believes Adjusted EBITDA is useful to investors and other users of NRG's financial statements in evaluating its operating performance because it provides an additional tool to compare business performance across companies and across periods and adjusts for items that we do not consider indicative of NRG’s future operating performance. This measure is widely used by debt-holders to analyze operating performance and debt service capacity and by equity investors to measure our operating performance without regard to items such as interest expense, taxes, depreciation and amortization, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired. Management uses Adjusted EBITDA as a measure of operating performance to assist in comparing performance from period to period on a consistent basis and to readily view operating trends, as a measure for planning and forecasting overall expectations, and for evaluating actual results against such expectations, and in communications with NRG's Board of Directors, shareholders, creditors, analysts and investors concerning its financial performance.
Adjusted cash flow from operating activities is a non-GAAP measure NRG provides to show cash from operations with the reclassification of net payments of derivative contracts acquired in business combinations from financing to operating cash flow, as well as the add back of merger, integration and related restructuring costs. The Company provides the reader with this alternative view of operating cash flow because the cash settlement of these derivative contracts materially impact operating revenues and cost of sales, while GAAP requires NRG to treat them as if there was a financing activity associated with the contracts as of the acquisition dates. The Company adds back merger, integration related restructuring costs as they are one time and unique in nature and do not reflect ongoing cash from operations and they are fully disclosed to investors.
Free cash flow (before Growth) is adjusted cash flow from operations less maintenance and environmental capital expenditures, net of funding, preferred stock dividends and distributions to non-controlling interests and is used by NRG predominantly as a forecasting tool to estimate cash available for debt reduction and other capital allocation alternatives. The reader is encouraged to evaluate each of these adjustments and the reasons NRG considers them appropriate for supplemental analysis. Because we have mandatory debt service requirements (and other non-discretionary expenditures) investors should not rely on free cash flow before Growth as a measure of cash available for discretionary expenditures.
Free Cash Flow before Growth is utilized by Management in making decisions regarding the allocation of capital. Free Cash Flow before Growth is presented because the Company believes it is a useful tool for assessing the financial performance in the current period. In addition, NRG’s peers evaluate cash available for allocation in a similar manner and accordingly, it is a meaningful indicator for investors to benchmark NRG's performance against its peers. Free Cash Flow before Growth is a performance measure and is not intended to represent net income (loss), cash from operations (the most directly comparable U.S. GAAP measure), or liquidity and is not necessarily comparable to similarly titled measures reported by other companies.
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