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NRG Energy, Inc. Reports Full Year 2017 Results, Reaffirms 2018 Financial Guidance
Investors News Release
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March 1, 2018 at 6:59 AM EST
Significant progress on Asset Sales:
Announcing sale of Boston Energy Trading and Marketing LLC (BETM)
Announced sale of NRG's interest in NRG Yield, Renewables platform, ROFO assets and South Central business for $2.8 billion1 on February 7, 2018
Exceeded Transformation Plan targets for cost reductions and working capital improvement in 2017
Reduced corporate debt by $604 million in 2017 and refinanced senior notes, resulting in approximately $55 million of recurring interest savings
Authorized $1 billion in share repurchases; first $500 million program to be launched immediately
Recorded $1.8 billion non-cash asset and goodwill impairment charge
PRINCETON, N.J.--(BUSINESS WIRE)--Mar. 1, 2018-- NRG Energy, Inc. (NYSE: NRG) today reported a full year 2017 net loss of $1,548 million, or $6.79 per diluted common share. Adjusted EBITDA for the full year 2017 was $2.4 billion, cash from operations was $1.4 billion and FCFbG was $1.3 billion. The net loss and loss per share were driven by a $1.8 billion impairment of fixed assets, goodwill, and investments of which $1.2 billion was related to the South Texas Project (STP) nuclear generation facility, primarily due to the revised outlook of future commodity prices.
"Our business continued its strong performance in a year when we announced our Transformation Plan aimed at simplifying and enhancing the business to deliver increased shareholder value," said Mauricio Gutierrez, NRG President and Chief Executive Officer. "With this announcement, we are demonstrating measurable success towards achieving the goals of cost excellence, portfolio optimization and capital structure enhancements. I'm also proud to report that we did this while realizing our second best safety year in company history."
Consolidated Financial Results
Three Months Ended Twelve Months Ended
($ in millions) 12/31/17 12/31/16 12/31/17 12/31/16
Income/(Loss) from Continuing Operations $ (1,667 ) $ (891 ) $ (1,548 ) $ (983 )
Cash From Continuing Operations $ 581 $ 533 $ 1,425 $ 2,207
Adjusted EBITDA $ 497 $ 471 $ 2,373 $ 2,706
Free Cash Flow Before Growth Investments (FCFbG) $ 497 $ 270 $ 1,304 $ 1,255
Table 1: Income/(Loss) from Continuing Operations
($ in millions) Three Months Ended Twelve Months Ended
Segment 12/31/17 12/31/16 12/31/17 12/31/16
Generation $ (1,700) $ (774) $ (1,498) $ (824)
Retail 506 317
Renewables a. (207) (223) (266) (330)
NRG Yield a. (98) (115) (23) 2
Corporate (168) (96) (647) (884)
Income/(Loss) from Continuing Operations $ (1,667) $ (891) $ (1,548) $ (983)
a. In accordance with GAAP, 2016 and 2017 results have been restated to include full impact of the assets in the NRG Yield Drop Down transactions which closed on September 1, 2016, March 27, 2017, and August 1, 2017
The net loss from continuing operations for the 12 months of 2017 was driven by a $1.8 billion impairment of fixed assets, goodwill, and investments of which $1.2 billion was related to the South Texas Project (STP) nuclear generation facility, primarily due to the revised outlook of future commodity prices. The net loss from continuing operations for the 12 months of 2016 includes a $970 million impairment of fixed assets and goodwill.
Table 2: Adjusted EBITDA
Generation $ 104 $ 117 $ 535 $ 869
Retail 214 134 825 811
Renewables a. 14 19 153 151
NRG Yield a. 204 214 933 932
Corporate (39) (13) (73) (57)
Adjusted EBITDA b. $ 497 $ 471 $ 2,373 $ 2,706
a. 2016 and 2017 results have been restated to include full impact of the assets in the NRG Yield Drop Down transactions, which closed on September 1, 2016, March 27, 2017, and August 1, 2017
b. See Appendices A-1 through A-4 for Operating Segment Reg G reconciliations
Generation: Full year 2017 Adjusted EBITDA was $535 million, $334 million lower than 2016 driven by:
Gulf Coast: $276 million decrease due to lower realized energy prices despite slightly higher generation, partially offset by lower operating expenses, net of outages due to flooding
East/West2: $58 million decrease due to lower dispatch, realized energy prices and capacity revenues, partially offset by lower operating costs, property tax and overhead expenses
Fourth quarter Adjusted EBITDA was $104 million, $13 million lower than the fourth quarter 2016 driven by:
Gulf Coast: $51 million decrease due to lower realized energy prices, partially offset by lower operating expenses
East/West2: $38 million increase due to higher capacity revenues, higher trading results at BETM and lower operating expenses
Retail: Full year 2017 Adjusted EBITDA was $825 million, $14 million higher than 2016 due to lower operating costs, partially offset by lower unit margins due to customer mix, milder weather and the impact of Hurricane Harvey.
Fourth quarter Adjusted EBITDA was $214 million, $80 million higher than the fourth quarter 2016 due to improved performance, customer growth and lower operating costs.
Renewables: Full year 2017 Adjusted EBITDA was $153 million, $2 million higher than 2016 due to increased generation and insurance recovery at Ivanpah, partially offset by lost margin from the sale of assets, a transmission outage at Agua Caliente, and increased development expenditures.
Fourth quarter Adjusted EBITDA was $14 million, $5 million lower than the fourth quarter 2016 due to lost margin from certain asset sales and plant outages, partially offset by lower operating and overhead expenses.
NRG Yield: Full year 2017 Adjusted EBITDA was $933 million, $1 million higher than 2016 due to contribution from Utah Solar assets acquired by NRG in the fourth quarter of 2016 and growth in distributed generation partnerships, partially offset by lower renewable production in 2017 driven by lower wind resources.
Fourth quarter Adjusted EBITDA was $204 million, $10 million lower than the fourth quarter 2016 due to lower wind production driven by lower wind resources, partially offset by growth in distributed generation partnerships.
Corporate: Full year 2017 Adjusted EBITDA was $(73) million, $16 million lower than 2016 due to the reduction in shared services income from GenOn, higher advisory fees, partially offset by lower corporate marketing expenses and the elimination of operating losses at Residential Solar and eVgo following their wind down of operations.
Fourth quarter Adjusted EBITDA was $(39) million, $26 million lower than the fourth quarter 2016 due to the reduction in shared services income from GenOn, partially offset by lower corporate marketing expenses and the elimination of operating losses at Residential Solar following its wind down of operations.
Table 3: Corporate Liquidity
($ in millions) 12/31/17 12/31/16
Cash at NRG-Level a. $ 769 $ 570
Revolver 1,711 989
NRG-Level Liquidity $ 2,480 $ 1,559
Restricted cash 508 446
Cash at Non-Guarantor Subsidiaries 222 368
Total Liquidity $ 3,210 $ 2,373
a. December 31, 2017 balance includes unrestricted cash held at Midwest Generation (a non-guarantor subsidiary) which can be distributed to NRG without limitation
NRG-Level cash as of December 31, 2017, was $769 million, an increase of $199 million from the end of 2016, and $1.7 billion was available under the Company's credit facilities at the end of 2017. Total liquidity was $3.2 billion, including restricted cash and cash at non-guarantor subsidiaries (primarily NRG Yield).
NRG Transformation Plan Update
As of the end of the fourth quarter of 2017, NRG realized $150 million, or 231%, of its 2017 cost savings target as part of the previously announced Transformation Plan.
Asset Sales Program
To date, NRG has announced or closed approximately $3 billion in asset sales towards its revised Transformation Plan target of $3.2 billion.
Sale of BETM
Announced today, a subsidiary of NRG has entered into a purchase and sale agreement with a subsidiary of Diamond Generating Corporation, a subsidiary of Mitsubishi Corporation, to sell Boston Energy Trading and Marketing LLC (BETM). The transaction is expected to close in the second half of 2018 and is subject to closing conditions, approvals and consents including Federal Energy Regulatory Commission (FERC) and the Committee on Foreign Investment in the United States (CFIUS).
Sale of NRG Yield and Renewables Platform
On February 6, 2018, NRG and Global Infrastructure Partners, or GIP, entered into a purchase and sale agreement to sell NRG's ownership in NRG Yield, Inc. and NRG's renewable energy development and operations platform for cash of $1.375 billion, subject to certain adjustments, and upon closing, removal of approximately $6.7 billion of consolidated debt as of 12/31/2017. The transaction is expected to close in the second half of 2018 and is subject to various customary closing conditions, approvals and consents.
Sale of South Central Business
On February 7, 2018, NRG and Cleco Corporate Holdings LLC, or Cleco, entered into a purchase and sale agreement to sell NRG's South Central business for a total cash purchase price of $1.0 billion, subject to certain adjustments. The transaction is expected to close in the second half of 2018 and is subject to various customary closing conditions, approvals and consents. Also, as part of the transaction, NRG will enter into a sale leaseback agreement for the Cottonwood plant through May of 2025.
Accelerated Drop Down Agreements
On January 24, 2018, the Company entered into an agreement with NRG Yield, Inc. to sell 100% of its ownership interest in Buckthorn Solar for cash consideration of $42 million, subject to other adjustments.
On February 6, 2018, the Company entered into an agreement with NRG Yield, Inc. to sell 100% of the membership interests in Carlsbad Energy Holdings LLC, which indirectly owns the Carlsbad project, a 527 MW natural gas fired project in Carlsbad, CA, pursuant to the ROFO Agreement. The purchase price for the transaction is $365 million in cash consideration, subject to customary working capital and other adjustments.
2018 Guidance
NRG is reaffirming its guidance range for 2018 with respect to Consolidated Adjusted EBITDA, Cash From Operations and FCFbG as set forth below.
Table 4: 2018 Adjusted EBITDA and FCF before Growth Guidance
($ in millions) Guidance
Adjusted EBITDA a. $2,800 - $3,000
Cash From Operations $2,015 - $2,215
Free Cash Flow before Growth $1,550 - $1,750
a. 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
Capital Allocation Update
In 2017, NRG reduced corporate debt by $604 million3 and refinanced and extended its 2023 senior notes realizing annual interest savings of approximately $55 million. Following the announced sale of NRG Yield and Renewables and the South Central businesses, NRG is also announcing corporate debt reduction of $640 million in 2018 and is temporarily reserving $1,200 million of additional cash to achieve it's 3.0x corporate net debt to Adjusted EBITDA ratio as part of the previously announced capital allocation guidance under the Transformation Plan.
The NRG Board of Directors has authorized $1 billion for share repurchases, with the first $500 million program to begin immediately. Following the completion of the initial program, and as NRG progress towards the closing of the announced asset sales, NRG expects to execute the remaining $500 million of the $1 billion share repurchase program.
On January 18, 2018, NRG declared a quarterly dividend on the Company's common stock of $0.03 per share, payable February 15, 2018, to stockholders of record as of February 1, 2018, representing $0.12 on an annualized basis.
The Company's common stock dividend, corporate level debt reduction and share repurchases are subject to available capital, market conditions and compliance with associated laws and regulations.
Earnings Conference Call
On March 1, 2018, NRG will host a conference call at 8:00 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.comand clicking on "Investors." The webcast will be archived on the site for those unable to listen in real time.
NRG is a leading integrated power company built on the strength of a diverse competitive electric generation portfolio and leading retail electricity platform. NRG aims to create a sustainable energy future by producing, selling and delivering electricity and related products and services in major competitive power markets in the U.S. in a manner that delivers value to all of NRG's stakeholders. The Company owns and operates approximately 30,000 MW of generation; engages in the trading of wholesale energy, capacity and related products; transacts in and trades fuel and transportation services; and directly sells energy, services, and innovative, sustainable products and services to retail customers under the names "NRG", "Reliant" and other retail brand names owned by NRG. More information is available at www.nrg.com. Connect with NRG Energy on Facebook and follow us on Twitter @nrgenergy.
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, 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 companywide 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, risks related to project siting, financing, construction, permitting, government approvals and the negotiation of project development agreements, our ability to progress development pipeline projects, 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, our ability to close the Drop Down transactions with NRG Yield, 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 March 1, 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.
NRG ENERGY, INC. AND SUBSIDIARIES
(In millions, except per share amounts)
Operating Revenues
Total operating revenues $ 10,629 $ 10,512 $ 12,328
Operating Costs and Expenses
Cost of operations 7,536 7,301 9,000
Depreciation and amortization 1,056 1,172 1,351
Impairment losses 1,709 702 4,860
Selling, general and administrative 907 1,095 1,228
Reorganization costs 44 — —
Development costs 67 89 154
Total operating costs and expenses 11,319 10,359 16,593
Other income - affiliate 87 193 193
Gain/(loss) on sale of assets 16 (80 ) —
Gain on postretirement benefits curtailment — — 21
Operating (Loss)/Income (587 ) 266 (4,051 )
Other Income/(Expense)
Equity in earnings of unconsolidated affiliates 31 27 36
Impairment losses on investments (79 ) (268 ) (56 )
Other income, net 38 34 26
Loss on sale of equity method investment — — (14 )
Net (loss)/gain on debt extinguishment (53 ) (142 ) 10
Interest expense (890 ) (895 ) (937 )
Total other expense (953 ) (1,244 ) (935 )
Loss from Continuing Operations Before Income Taxes (1,540 ) (978 ) (4,986 )
Income tax expense 8 5 1,345
Net Loss from Continuing Operations (1,548 ) (983 ) (6,331 )
(Loss)/income from discontinued operations, net of income tax (789 ) 92 (105 )
Net Loss (2,337 ) (891 ) (6,436 )
Less: Net loss attributable to noncontrolling interests and redeemable noncontrolling interests (184 ) (117 ) (54 )
Net Loss Attributable to NRG Energy, Inc. (2,153 ) (774 ) (6,382 )
Dividends for preferred shares — 5 20
Gain on redemption of preferred shares — (78 ) —
Loss Available for Common Stockholders $ (2,153 ) $ (701 ) $ (6,402 )
Loss Per Share Attributable to NRG Energy, Inc. Common Stockholders
Weighted average number of common shares outstanding — basic and diluted 317 316 329
Loss from continuing operations per weighted average common share — basic and diluted $ (4.30 ) $ (2.51 ) $ (19.14 )
(Loss)/Income from discontinued operations per weighted average common share — basic and diluted $ (2.49 ) $ 0.29 $ (0.32 )
Net Loss per Weighted Average Common Share — Basic and Diluted $ (6.79 ) $ (2.22 ) $ (19.46 )
Dividends Per Common Share $ 0.12 $ 0.24 $ 0.58
CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS)/INCOME
Net Loss $ (2,337 ) $ (891 ) $ (6,436 )
Other Comprehensive Income, net of tax
Unrealized gain/(loss) on derivatives, net of income tax expense of $1, $1, and $19 13 35 (15 )
Foreign currency translation adjustments, net of income tax benefit of $(2), $0, and $0 12 (1 ) (11 )
Available-for-sale securities, net of income tax expense/(benefit) of $10, $0, and $(3) (8 ) 1 17
Defined benefit plan, net of income tax (benefit)/expense of $(21), $0 and $69 46 3 10
Other comprehensive income 63 38 1
Comprehensive Loss (2,274 ) (853 ) (6,435 )
Less: Comprehensive loss attributable to noncontrolling interests and redeemable noncontrolling interests (179 ) (117 ) (73 )
Comprehensive Loss Attributable to NRG Energy, Inc. (2,095 ) (736 ) (6,362 )
Comprehensive Loss Available for Common Stockholders $ (2,095 ) $ (663 ) $ (6,382 )
As of December 31,
Cash and cash equivalents $ 991 $ 938
Funds deposited by counterparties 37 2
Accounts receivable — trade 1,079 1,058
Inventory 532 721
Derivative instruments 626 1,067
Cash collateral posted in support of energy risk management activities 171 150
Accounts receivable — affiliate 95 —
Current assets held-for-sale 115 9
Prepayments and other current assets 261 404
Current assets - discontinued operations — 1,919
Total current assets 4,415 6,714
Property, plant and equipment, net 13,908 15,369
Equity investments in affiliates 1,038 1,120
Notes receivable, less current portion 2 16
Goodwill 539 662
Intangible assets, net 1,746 1,973
Nuclear decommissioning trust fund 692 610
Derivative instruments 172 181
Deferred income taxes 134 225
Non-current assets held-for-sale 43 10
Other non-current assets 629 841
Non-current assets - discontinued operations — 2,961
Total other assets 4,995 8,599
Total Assets $ 23,318 $ 30,682
CONSOLIDATED BALANCE SHEETS (Continued)
(In millions, except share data)
Current portion of long-term debt and capital leases $ 688 $ 516
Accounts payable 881 782
Accounts payable - affiliate 33 31
Cash collateral received in support of energy risk management activities 37 81
Accrued interest expense 156 180
Current liabilities - held for sale 72 —
Other accrued expenses and other current liabilities 734 810
Other accrued expenses and other current liabilities - affiliate 161 —
Current liabilities - discontinued operations — 1,210
Total current liabilities 3,317 4,702
Long-term debt and capital leases 15,716 15,957
Nuclear decommissioning reserve 269 287
Nuclear decommissioning trust liability 415 339
Postretirement and other benefit obligations 458 510
Deferred income taxes 21 20
Out-of-market contracts, net 207 230
Non-current liabilities held-for-sale 8 11
Other non-current liabilities 664 666
Non-current liabilities - discontinued operations — 3,184
Total non-current liabilities 17,955 21,488
Total Liabilities 21,272 26,190
Redeemable noncontrolling interest in subsidiaries 78 46
Common stock; $0.01 par value; 500,000,000 shares authorized; 418,323,134 and 417,583,825 shares issued; and 316,743,089 and 315,443,011 shares outstanding at December 31, 2017 and 2016 4 4
Additional paid-in capital 8,376 8,358
Accumulated deficit (6,268 ) (3,787 )
Treasury stock, at cost; 101,580,045 and 102,140,814 shares at December 31, 2017 and 2016 (2,386 ) (2,399 )
Accumulated other comprehensive loss (72 ) (135 )
Noncontrolling interest 2,314 2,405
Total Liabilities and Stockholders' Equity $ 23,318 $ 30,682
CONSOLIDATED STATEMENTS OF CASH FLOW
Loss from continuing operations $ (1,548 ) $ (983 ) $ (6,331 )
Adjustments to reconcile net income/(loss) to net cash provided by operating activities:
Equity in earnings and distribution of unconsolidated affiliates 55 54 37
Provision for bad debts 68 48 64
Amortization of nuclear fuel 51 49 45
Amortization of financing costs and debt discount/premiums 60 55 47
Adjustment for debt extinguishment 53 142 (10 )
Amortization of intangibles and out-of-market contracts 108 167 151
Amortization of unearned equity compensation 35 10 39
Net (gain)/loss on sale of assets and equity method investments (34 ) 70 14
Gain on post retirement benefits curtailment — — (21 )
Changes in derivative instruments (171 ) 32 235
Changes in deferred income taxes and liability for uncertain tax benefits 91 (43 ) 1,326
Changes in collateral deposits in support of risk management activities (80 ) 398 (334 )
Proceeds from sale of emission allowances 25 34 (24 )
Changes in nuclear decommissioning trust liability 11 41 (2 )
Cash provided/(used) by changes in other working capital, net of acquisition and disposition effects:
Accounts receivable - trade (99 ) (7 ) 113
Inventory 143 71 (59 )
Prepayments and other current assets 12 (44 ) (21 )
Accounts payable 77 (39 ) (180 )
Accrued expenses and other current liabilities (60 ) (35 ) (29 )
Other assets and liabilities (216 ) 43 (40 )
Cash provided by continuing operations 1,425 2,207 1,287
Cash (used)/provided by discontinued operations (38 ) (119 ) 62
Net Cash Provided by Operating Activities 1,387 2,088 1,349
Acquisition of businesses, net of cash acquired (41 ) (209 ) (31 )
Capital expenditures (1,111 ) (976 ) (1,029 )
Net cash proceeds from notes receivable 17 17 18
Proceeds from renewable energy grants 8 36 82
Proceeds from/(purchases) of emission allowances, net of purchases 66 (1 ) 41
Investments in nuclear decommissioning trust fund securities (512 ) (551 ) (629 )
Proceeds from sales of nuclear decommissioning trust fund securities 501 510 631
Proceeds from sale of assets, net 87 73 27
Investments in unconsolidated affiliates (40 ) (23 ) (395 )
Other 12 35 16
Cash used by continuing operations (1,013 ) (1,089 ) (1,269 )
Cash (used)/provided by discontinued operations (53 ) 297 (259 )
Net Cash Used by Investing Activities (1,066 ) (792 ) (1,528 )
Payments of dividends to preferred and common stockholders (38 ) (76 ) (201 )
Net receipts from settlement of acquired derivatives that include financing elements 2 6 14
Payments for treasury stock — — (437 )
Payments for preferred shares — (226 ) —
Payments for debt extinguishment costs (42 ) (121 ) —
Distributions to, net of contributions from, noncontrolling interests in subsidiaries 95 (156 ) 47
Proceeds from sale of noncontrolling interests in subsidiaries — — 600
(Payments)/Proceeds from issuance of common stock (2 ) 1 1
Proceeds from issuance of long-term debt 2,270 5,527 1,004
Payments of debt issuance and hedging costs (63 ) (89 ) (21 )
Payments for short and long-term debt (2,348 ) (5,908 ) (1,362 )
Receivable from affiliate (125 ) — —
Other (10 ) (13 ) (22 )
Cash used by continuing operations (261 ) (1,055 ) (377 )
Cash (used)/provided by discontinued operations (224 ) 140 (55 )
Net Cash Used by Financing Activities (485 ) (915 ) (432 )
Effect of exchange rate changes on cash and cash equivalents (1 ) 1 10
Change in Cash from discontinued operations (315 ) 318 (252 )
Net Increase/(Decrease) in Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash 150 64 (349 )
Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash at Beginning of Period 1,386 1,322 1,671
Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash at End of Period $ 1,536 $ 1,386 $ 1,322
Appendix Table A-1: Fourth Quarter 2017 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/
Generation Retail Renewables NRG Yield Corp/
Income/(Loss) from Continuing Operations (1,486 ) (214 ) (1,700 ) 506 (207 ) (98 ) (168 ) (1,667 )
Interest expense, net — 5 5 2 22 68 96 193
Income tax — — — — (7 ) 57 (47 ) 3
Loss on debt extinguishment — — — — — 1 49 50
Depreciation and amortization 63 27 90 31 51 88 7 267
ARO expense 11 13 24 — 1 1 — 26
Contract amortization 6 1 7 — — 17 1 25
Lease amortization — (2 ) (2 ) — — — — (2 )
EBITDA (1,406 ) (170 ) (1,576 ) 539 (140 ) 134 (62 ) (1,105 )
Adjustment to reflect NRG share of adjusted EBITDA in unconsolidated affiliates 2 6 8 (7 ) 2 27 2 32
Acquisition-related transaction & integration costs — — — — — 1 1 2
Reorganization costs 6 1 7 6 1 — 12 26
Legal Settlement — — — (1 ) — — — (1 )
Deactivation costs 3 6 9 — — — 2 11
Gain on sale of business — (13 ) (13 ) — 5 — (8 ) (16 )
Other non recurring charges 4 (7 ) (3 ) — (4 ) 10 10 13
Impairments 1,267 196 1,463 8 130 32 (1 ) 1,632
Impairment losses on investments 69 5 74 — 1 — 4 79
Mark to market (MtM) (gains)/losses on economic hedges 100 35 135 (331 ) 19 — 1 (176 )
Adjusted EBITDA 45 59 104 214 14 204 (39 ) 497
1Includes International, BETM and generation eliminations
Fourth Quarter 2017 condensed financial information by Operating Segment:
Operating revenues 506 333 839 1,508 90 248 (227 ) 2,458
Cost of sales 289 139 428 1,099 4 17 (212 ) 1,336
Economic gross margin 217 194 411 409 86 231 (15 ) 1,122
Operations & maintenance and other cost of operations 2 143 115 258 77 36 57 21 449
Selling, marketing, general and administrative 3 27 22 49 114 13 5 30 211
Other expense/(income) 4 2 (2 ) — 4 23 (35 ) (27 ) (35 )
2Excludes deactivation costs of $11 million
3Excludes a legal settlement of $(1) million
4 Excludes impairments of $1,711 million, gain on sale of business of $16 million, acquisition-related transaction & integration costs of $2 million, reorganization costs of $26 million and loss on debt extinguishment of $50 million
The following table reconciles the condensed financial information to Adjusted EBITDA:
($ in millions)
Interest, tax,
depr., amort.
MtM Deactivation Other adj. Adjusted EBITDA
Operating revenues 2,497 15 (54 ) — — 2,458
Cost of operations 1,224 (10 ) 122 — — 1,336
Gross margin 1,273 25 (176 ) — — 1,122
Operations & maintenance and other cost of operations 460 — — (11 ) — 449
Selling, marketing, general & administrative 1 210 — — — 1 211
Other expense/(income) 2 2,270 (487 ) — — (1,818 ) (35 )
Income/(Loss) from Continuing Operations (1,667 ) 512 (176 ) 11 1,817 497
1Other adj. includes a legal settlement of $(1) million
2 Other adj, includes impairments of $1,711 million, gain on sale of business of $16 million, acquisition-related transaction & integration costs of $2 million, reorganization costs of $26 million and loss on debt extinguishment of $50 million
The following table summarizes the calculation of Adjusted EBITDA and provides a reconciliation to income/(loss) from continuing operations:
Income/(Loss) from Continuing Operations (671 ) (103 ) (774 ) 317 (223 ) (115 ) (96 ) (891 )
Interest expense, net — 1 1 — 17 67 91 176
Income tax — 1 1 — (6 ) (26 ) (39 ) (70 )
Loss on debt extinguishment — — — — — — 23 23
Depreciation and amortization 155 29 184 28 45 75 14 346
ARO Expense 3 2 5 — 1 1 1 8
Contract amortization 4 — 4 1 — 17 2 24
EBITDA (509 ) (72 ) (581 ) 346 (166 ) 19 (4 ) (386 )
Adjustment to reflect NRG share of adjusted EBITDA in unconsolidated affiliates (2 ) 8 6 — 44 7 (43 ) 14
Acquisition-related transaction & integration costs — — — — — 1 — 1
Deactivation costs — 2 2 — — — 1 3
Gain on sale of business — — — — — — 1 1
Other non recurring charges — 3 3 1 1 2 (2 ) 5
Impairments 368 36 404 1 28 185 19 637
Impairment loss on investment — — — — 106 — 15 121
Mark to market (MtM) (gains)/losses on economic hedges 239 44 283 (214 ) 6 — — 75
Economic gross margin 308 185 493 365 83 239 — 1,180
Operations & maintenance and other cost of operations 2 174 132 306 91 31 52 4 484
Selling, marketing, general and administrative 36 34 70 136 17 6 65 294
2Excludes deactivation costs of $3 million
3Excludes impairments of $758 million, acquisition-related transaction & integration costs of $1 million and loss on debt extinguishment of $23 million
($ in millions) Condensed financial information Interest, tax, depr., amort. MtM Deactivation Other adj. Adjusted EBITDA
Operating revenues 2,184 15 282 — — 2,481
Cost of operations 1,103 (9 ) 207 — — 1,301
Gross margin 1,081 24 75 — — 1,180
Operations & maintenance and other cost of operations 487 — — (3 ) — 484
Selling, marketing, general & administrative 294 — — — — 294
Other expense/(income) 1 1,191 (458 ) — — (802 ) (69 )
Income/(Loss) from Continuing Operations (891 ) 482 75 3 802 471
1Other adj. includes impairments of $758 million, acquisition-related transaction & integration costs of $1 million and loss on debt extinguishment of $23 million
Appendix Table A-3: Full Year 2017 Adjusted EBITDA Reconciliation by Operating Segment
Income/(Loss) from Continuing Operations (1,427 ) (71 ) (1,498 ) 886 (266 ) (23 ) (647 ) (1,548 )
Interest expense, net 1 26 27 5 97 303 445 877
Income tax — 2 2 (9 ) (20 ) 72 (37 ) 8
Loss on debt extinguishment — — — — 1 3 49 53
Depreciation and amortization 270 107 377 117 196 334 32 1,056
ARO expense 22 22 44 1 2 4 (1 ) 50
Contract amortization 16 4 20 1 — 69 — 90
EBITDA (1,118 ) 82 (1,036 ) 1,001 10 762 (159 ) 578
Adjustment to reflect NRG share of adjusted EBITDA in unconsolidated affiliates 17 25 42 (17 ) (12 ) 106 6 125
Reorganization costs 9 1 10 11 1 — 22 44
Deactivation costs 4 8 12 — — — 9 21
Gain on sale of assets — (20 ) (20 ) — 5 — (1 ) (16 )
Other non recurring charges (21 ) (2 ) (23 ) 1 (17 ) 18 44 23
Impairments 1,309 195 1,504 7 154 44 — 1,709
Impairment losses on investments 69 5 74 — — — 5 79
Mark to market (MtM) (gains)/losses on economic hedges (52 ) 24 (28 ) (177 ) 12 — — (193 )
Adjusted EBITDA 217 318 535 825 153 933 (73 ) 2,373
Full Year 2017 condensed financial information by Operating Segment:
Operating revenues 2,258 1,464 3,722 6,385 436 1,078 (1,175 ) 10,446
Cost of sales 1,338 639 1,977 4,768 15 63 (1,125 ) 5,698
Economic gross margin 920 825 1,745 1,617 421 1,015 (50 ) 4,748
Operations & maintenance and other cost of operations 2 612 439 1,051 322 139 263 (38 ) 1,737
Selling, marketing, general and administrative 3 123 84 207 453 56 22 170 908
Other expense/(income) 4 (32 ) (16 ) (48 ) 17 73 (203 ) (109 ) (270 )
4Excludes impairments of $1,788 million, gain on sale of assets of $16 million, reorganization costs of $44 million, acquisition-related transaction & integration costs of $4 million, and loss on debt extinguishment of $53 million
Operating revenues 10,629 56 (239 ) — — 10,446
Cost of operations 5,778 (34 ) (46 ) — — 5,698
Operations & maintenance and other cost of operations 1,758 — — (21 ) — 1,737
Other expense/(income) 2 3,734 (1,983 ) — — (2,021 ) (270 )
Income/(Loss) from Continuing Operations (1,548 ) 2,073 (193 ) 21 2,020 2,373
2 Other adj. includes impairments of $1,788 million, gain on sale of assets of $16 million, reorganization costs of $44 million, acquisition-related transaction & integration costs of $4 million, and loss on debt extinguishment of $53 million
Income/(Loss) from Continuing Operations (920 ) 96 (824 ) 1,053 (330 ) 2 (884 ) (983 )
Interest expense, net 1 24 25 — 97 283 481 886
Income tax (2 ) 1 (1 ) 1 (20 ) (1 ) 26 5
Loss on debt extinguishment — — — — — — 142 142
ARO Expense 11 4 15 — 2 3 1 21
Contract amortization 14 5 19 7 1 75 (3 ) 99
EBITDA (490 ) 232 (258 ) 1,172 (65 ) 665 (180 ) 1,334
Adjustment to reflect NRG share of adjusted EBITDA in unconsolidated affiliates 3 27 30 — 42 75 (41 ) 106
Deactivation costs — 15 15 — — — 2 17
Loss on sale of assets — — — 1 — — 79 80
Other non recurring charges 19 (2 ) 17 2 9 6 23 57
Impairment losses on investments 137 5 142 — 105 — 21 268
Mark to market (MtM) (gains)/losses on economic hedges 447 46 493 (365 ) 6 — — 134
Economic gross margin 1,278 1,013 2,291 1,649 399 1,043 1 5,383
Selling, marketing, general and administrative 132 133 265 498 61 17 254 1,095
Other expense/(income) 3 (19 ) (35 ) (54 ) 2 45 (147 ) (186 ) (340 )
3Excludes impairments of $970 million, loss on sale of assets of $80 million, acquisition-related transaction & integration costs of $8 million, and loss on debt extinguishment of $142 million
Operating revenues 10,512 56 642 — — 11,210
Gross margin 5,150 99 134 — — 5,383
Selling, marketing, general & administrative 1,095 — — — — 1,095
Income/(Loss) from Continuing Operations (983 ) 2,175 134 17 1,363 2,706
1Other adj. includes impairments of $970 million, loss on sale of assets of $80 million, acquisition-related transaction & integration costs of $8 million, and loss on debt extinguishment of $142 million
Appendix Table A-5: 2017 and 2016 Three Months Ended December 31 and Full Year Adjusted Cash Flow from Operations Reconciliations
The following table summarizes the calculation of adjusted cash flow operating activities providing a reconciliation to net cash provided by operating activities:
($ in millions) December 31, 2017 December 31, 2016
Net Cash Provided by Operating Activities 581 533
Sale of Land and other assets (3) —
Merger, integration and cost-to-achieve expenses 1 23 (7)
Return of capital from equity investments 4 11
Adjustment for change in collateral 2 (23) (137)
Adjusted Cash Flow from Operating Activities 582 400
Maintenance CapEx, net 3 (39) (41)
Environmental CapEx, net 1 (42)
Distributions to non-controlling interests (47) (47)
Free Cash Flow - before Growth 497 270
1. 2017 includes cost-to-achieve expenses associated with the Transformation Plan announced on July 2017 call; 2016 includes cost-to achieve expenses associated with the $150 million savings announced on September 2015 call.
2. Reflects change in NRG's cash collateral balance as of 4Q2017 including $79 million of collateral postings from our deconsolidated affiliate (GenOn)
3. Includes insurance proceeds of $7 million and $4 million in 2017 and 2016, respectively
Twelve Months Ended
Net Cash Provided by Operating Activities 1,425 2,207
Reclassifying of net receipts for settlement of acquired derivatives that include financing elements 2 6
Sale of Land and other assets 5 —
Merger, integration and cost-to-achieve expenses 1 37 40
Cash Contribution to GenOn pension plan 2 13 —
Return of capital from equity investments 26 17
Adjustment for change in collateral 3 159 (398)
Adjusted Cash Flow from Operating Activities 1,667 1,872
Maintenance CapEx, net 4 (164) (212)
Environmental CapEx, net (24) (240)
Preferred dividends — (2)
Distributions to non-controlling interests (175) (163)
Free Cash Flow - before Growth 1,304 1,255
1.2017 includes cost-to-achieve expenses associated with the Transformation Plan announced on July 2017 call; 2016 includes cost-to achieve expenses associated with the $150 million savings announced on September 2015 call.
2. Reflects cash contribution related to Legacy GenOn pension liability retained by NRG
4. Includes insurance proceeds of $29 million and $35 million in 2017 and 2016, respectively
Appendix Table A-6: Full Year 2017 Sources and Uses of Liquidity
The following table summarizes the sources and uses of liquidity for the full year 2017:
($ in millions) Twelve Months Ended
Adjusted cash flow from operations 1,667
Increase in credit facility 722
Issuance of Agua Caliente HoldCo debt 130
Divestitures 81
NYLD Equity Issuance 34
Debt repayments, net of proceeds (1,207)
Collateral 1 (159)
Maintenance and environmental capex, net 2 (188)
Distributions to non-controlling interests (175)
Common Stock Dividends (38)
Cost-to-achieve3 (43)
Growth investments and acquisitions, net (9)
Other Investing and Financing 22
Change in Total Liquidity 837
1. Reflects change in NRG's cash collateral balance as of 4Q2017 including $79MM of collateral postings from our deconsolidated affiliate (GenOn)
2.Includes insurance proceeds of $29 million
3.2017 includes cost-to-achieve expenses associated with the Transformation Plan announced on July 2017 call
Appendix Table A-7: 2018 Adjusted EBITDA Guidance Reconciliation
The following table summarizes the calculation of Adjusted EBITDA providing reconciliation to net income:
2018 Adjusted EBITDA
($ in millions) Low High
Income from Continuing Operations 1 410 610
Income Tax 20 20
Interest Expense 785 785
Depreciation, Amortization, Contract Amortization and ARO Expense 1,180 1,180
Adjustment to reflect NRG share of adjusted EBITDA in unconsolidated affiliates 135 135
Other Costs 2 270 270
Adjusted EBITDA 2,800 3,000
1. For purposes of guidance, discontinued operations are excluded and fair value adjustments related to derivatives are assumed to be zero.
2. Includes deactivation costs and cost-to-achieve expenses
Appendix Table A-8: 2018 FCFbG Guidance Reconciliation
The following table summarizes the calculation of Free Cash Flow before Growth providing reconciliation to Cash from Operations:
Adjusted EBITDA $2,800 - $3,000
Cash Interest payments (785 )
Cash Income tax (40 )
Collateral / working capital / other 40
Adjustments: Acquired Derivatives, Cost-to-Achieve, Return of Capital Dividends, Collateral and Other —
Adjusted Cash flow from operations $2,015 - $2,215
Maintenance capital expenditures, net (210) - (240)
Environmental capital expenditures, net (0) - (5)
Distributions to non-controlling interests (220) - (250)
Free Cash Flow - before Growth $1,550 - $1,750
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.
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.
1Excluding transaction costs, working capital, and other purchase price adjustments
2Includes International and BETM
3Cash cost of $646 million, including $42 million of debt extinguishment fees
Source: NRG Energy, Inc.
Marijke Shugrue, 609-524-5262
Kevin L. Cole, CFA, 609-524-4526
Lindsey Puchyr, 609-524-4527
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text:
CU Boulder won't hang up the 'keep out' sign on April 20
By Hart Van Denburg
CU campus to be open on 4/20 http://t.co/wikjL3W8c9 pic.twitter.com/8GKbSNM5ps
— CU Independent (@The_CUI) April 3, 2015
The University of Colorado Boulder plans to keep the campus open this year for 4/20 Day, when students like to celebrate all things weed, Chancellor Phillip P. DiStefano said in a memo.
"For the past three years, CU-Boulder closed the campus to non-affiliates on April 20 to avoid the disruptive gatherings that attracted thousands of attendees from around the state and the country in earlier years. And fortunately, those types of gatherings have not occurred since 2011," DiStefano says in the memo. "I hoped campus closures would not be necessary in the near-future and that we could go about our daily business on April 20 as we would any other day. That time has come."
But that doesn't mean the whole campus will be open.
The only exception to this will be the lawn areas of the Norlin Quad, which will be closed that afternoon. Depending on other factors, additional fields may also be closed. Those who ignore the barriers and cross onto the Norlin lawn or any additional closed fields can face a citation or arrest for trespassing.
After 3 years of closures, #CUBoulder to keep campus open on #4/20 http://t.co/QGxjocQWnI via @mitchellbyars pic.twitter.com/EV2tnsdCqO
— Daily Camera (@dailycamera) April 4, 2015
Now that 4/20's not a big deal: MT @The_CUI: CU campus to be open on 4/20 http://t.co/R0oILBS2Pn http://t.co/TOm7NFxB5b
— Gil Asakawa (@GilAsakawa) April 4, 2015

redpajama_set_name: RedPajamaCommonCrawl


It's time to show off the results of our latest quilt challenge. The theme this time around was "Steel" and boy, did we have a good time at the reveal get together! You can't go wrong with good holiday cheer, good food, and good company 🙂 Brenda added to the fun by bringing along a "naughty" quilt she made as a gift for a friend and her risque applique was a hit. In the interest of remaining family friendly however, I'll have to leave that quilt to your imagination… but I can show you the challenge quilts!
The inspiration for my quilt came while we were in Grand Rapids for the AQS Quilt show. We had already decided on our next couple of challenge themes and I had no ideas for steel. Then I started noticing all the door handles and steel locks everywhere we went. I took some photos and knew for sure I had my inspiration when I saw the beautiful patina on an old rusted lock down by the river. Some photo transfer, fusing, thread play, embellishment… and there you have it!
Candy says she had a very difficult time summoning the inspiration for our latest challenge. For every idea that popped into her mind she found she lacked the skill to bring it to life. So in the end she opted for the color steel and a paper pieced grid, steel-like pattern. Her materials were cotton fabric with steel washers.
So now we're on to a new year and a new challenge. We've decided to see what we can do when we limit ourselves to designing a quilt using just one color. "The One Color Challenge"… to be revealed in February 2013.


Türksat Cable receives A.C.E. Award | Türksat Uydu Haberleşme Kablo TV ve İşletme A.Ş.
At the 4th A.C.E. Awards 2019 (Achievement in Customer Excellence) recipients received their awards, which were given according to the results of sikayetvar.com, Turkey's customer satisfaction measurement platform.
At the awards ceremony, which was organized for the fourth time this year, Cable Services Customer Relations Directorate received first place in two different categories.
The most important thing Şikayetvar.com offers us is the customer experience measurement. Here the jury is compiled of customers. From the points they have given us, we have been able to receive first place for four years in a row. I would like to thank my team for their effort in our success.
At the A.C.E awards ceremony, which was organized by sikayetvar.com in Ankara, 38 national and international brands who manage customer experiences the best in 21 markets were given awards. According to the data obtained from surveys conducted each year by sikayetvar.com, "Customer Experience Index" identifies companies that provide the best customer experience.