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Form 8-K DYNEGY INC. For: Aug 03

August 3, 2016 4:45 PM EDT

 

 

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 8-K

 

CURRENT REPORT

PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

 

Date of Report (Date of earliest event reported)

August 3, 2016

 

DYNEGY INC.

(Exact name of registrant as specified in its charter)

 

Delaware

 

001-33443

 

20-5653152

(State or Other Jurisdiction of Incorporation)

 

(Commission File Number)

 

(I.R.S. Employer Identification No.)

 

601 Travis, Suite 1400, Houston, Texas

 

77002

(Address of principal executive offices)

 

(Zip Code)

 

(713) 507-6400

(Registrant’s telephone number, including area code)

 

N.A.

(Former name or former address, if changed since last report)

 

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

 

o    Written communications pursuant to Rule425 under the Securities Act (17 CFR 230.425)

 

o    Soliciting material pursuant to Rule14a-12 under the Exchange Act (17 CFR 240.14a-12)

 

o    Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

 

o    Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

 

 

 



 

Item 2.02                                           Results of Operations and Financial Condition.

 

On August 3, 2016, Dynegy Inc. (“Dynegy”) issued a press release announcing its second quarter financial results and the updating of its 2016 guidance estimates. A copy of Dynegy’s August 3, 2016 press release is furnished herewith as Exhibit 99.1 and is incorporated herein by this reference. Dynegy’s earnings presentation and management comments on the earnings presentation will be available on the “Investor Relations” section of Dynegy’s website (www.dynegy.com) later today. Dynegy’s management will hold an investor conference call and webcast tomorrow, August 4, 2016, at 9 a.m. ET/8 a.m. CT, to answer questions related to its second quarter financial results and related information. Participants may access the webcast from the Dynegy website.

 

Pursuant to General Instruction B.2 of Form 8-K and Securities and Exchange Commission (the “SEC”) Release No. 33-8176, the information contained in the press release furnished as an exhibit hereto shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, is not subject to the liabilities of that section and is not deemed incorporated by reference in any filing under the Securities Act of 1933, as amended, except as shall be expressly set forth by specific reference in such a filing. In addition, the press release contains statements intended as “forward-looking statements” which are subject to the cautionary statements about forward-looking statements set forth in such press release.

 

Non-GAAP Financial Information

 

In analyzing and planning for Dynegy’s business, management supplements Dynegy’s use of the Generally Accepted Accounting Principles of the United States of America (“GAAP”) financial measures with non-GAAP financial measures, including earnings before interest, taxes, depreciation and amortization (“EBITDA”) and Adjusted EBITDA. These non-GAAP financial measures reflect an additional way of viewing aspects of Dynegy’s business that, when viewed with its GAAP results and the accompanying reconciliations to corresponding GAAP financial measures, may provide a more complete understanding of factors and trends affecting its business. In this Form 8-K, Dynegy discusses such non-GAAP financial measures included in the press release, including definitions of such non-GAAP financial information, identification of the most directly comparable GAAP financial measures and the reasons why management believes these measures provide useful information regarding Dynegy’s financial condition, results of operations and cash flows, as applicable, and, to the extent material, the additional purposes, if any, for which these measures are used. Reconciliations of non-GAAP financial measures to the most directly comparable GAAP financial measures, to the extent available without unreasonable effort, are contained in the schedules attached to the press release.

 

EBITDA Measures.

 

“EBITDA” — is defined as earnings (loss) before interest expense, income tax expense (benefit), and depreciation and amortization expense.

 

“Adjusted EBITDA” — is defined as EBITDA adjusted to exclude (i) gains or losses on the sale of certain assets, (ii) the impacts of mark-to-market changes on derivatives related to Dynegy’s generation portfolio, as well as interest rate swaps and warrants, (iii) the impact of impairment charges and certain other costs such as those associated with acquisitions and (iv) other material items. Beginning in 2016, Adjusted EBITDA also excludes non-cash compensation expense.

 

Management believes EBITDA and Adjusted EBITDA provide meaningful representations of Dynegy’s operating performance. Management considers EBITDA as another way to measure financial performance on an ongoing basis. Adjusted EBITDA is meant to reflect the operating performance of Dynegy’s entire power generation fleet for the period presented; consequently, it excludes the impact of mark-to-market accounting, impairment charges, and other items that could be considered “non-operating” or “non-core” in nature. Because EBITDA and Adjusted EBITDA are financial measures that management uses to allocate resources, determine Dynegy’s ability to fund capital expenditures, assess performance against Dynegy’s peers and evaluate overall financial performance, management believes they provide useful information for Dynegy’s investors. In addition, many analysts, fund managers, and other stakeholders that communicate with Dynegy typically request its financial results in an EBITDA and Adjusted EBITDA format.

 

2



 

As prescribed by the SEC, when EBITDA or Adjusted EBITDA is discussed in reference to performance on a consolidated basis, the most directly comparable GAAP financial measure to EBITDA and Adjusted EBITDA is Net income (loss). Management does not analyze interest expense and income taxes on a segment level; therefore, the most directly comparable GAAP financial measure to EBITDA or Adjusted EBITDA when performance is discussed on a segment level is Operating income (loss).

 

Cash Flow Measure.

 

Dynegy’s non-GAAP Cash Flow measure may not be representative of the amount of residual cash flow that is available to Dynegy for discretionary expenditures, since it may not include deductions for mandatory debt service requirements and other non-discretionary expenditures. Management believes, however, that Dynegy’s non-GAAP Cash Flow measure is useful because it measures the cash generating ability of Dynegy’s operating asset-based energy business relative to its capital expenditure obligations and financial performance.

 

“Free Cash Flow” — is defined as cash flow from operations less non-discretionary maintenance and environmental capital expenditures, the cash impact of acquisition-related fees and financing costs plus the return of restricted cash. Free Cash Flow also includes receipts or payments related to interest rate swaps and excludes the impact of changes in collateral and working capital. Beginning in 2016, Free Cash Flow excludes certain capital costs related to compliance with environmental requirements. The most directly comparable GAAP financial measure to such measure is cash flow from operations.

 

Management believes that the historical non-GAAP measures and forward-looking non-GAAP measures disclosed in Dynegy’s filings are only useful as an additional tool to help management and investors make informed decisions about Dynegy’s financial and operating performance. Further there can be no assurance that the assumptions made in preparing forward-looking non-GAAP numbers will prove accurate, and actual results may be materially less or greater than those contained in the forward-looking non-GAAP numbers. By definition, non-GAAP measures do not give a full understanding of Dynegy; therefore, to be truly valuable, they must be used in conjunction with the comparable GAAP measures. In addition, non-GAAP financial measures are not standardized; therefore, it may not be possible to compare these financial measures with other companies’ non-GAAP financial measures having the same or similar names. Dynegy strongly encourages investors to review its consolidated financial statements and publicly filed reports in their entirety and not rely on any single financial measure.

 

Item 7.01                                           Regulation FD Disclosure.

 

The information set forth in Item 2.02 above is incorporated herein by reference.

 

Item 9.01                                           Financial Statements and Exhibits.

 

(d)  Exhibits:

 

Exhibit No.

 

Document

 

 

 

99.1

 

Press release dated August 3, 2016, announcing results of operations and updating of Dynegy’s 2016 guidance

 

3



 

SIGNATURE

 

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

 

 

DYNEGY INC.

 

(Registrant)

 

 

 

Dated: August 3, 2016

By:

/s/ Catherine C. James

 

Name:

Catherine C. James

 

Title:

Executive Vice President, General Counsel and Chief
Compliance Officer

 

4



 

EXHIBIT INDEX

 

Exhibit No.

 

Document

 

 

 

99.1

 

Press release dated August 3, 2016, announcing results of operations and updating of Dynegy’s 2016 guidance

 

5


Exhibit 99.1

 

NEWS RELEASE

 

 

FOR IMMEDIATE RELEASE

NR16-22

 

 

DYNEGY ANNOUNCES 2016 SECOND QUARTER RESULTS

 

Summary of Second Quarter 2016 Financial Results (in Millions):

 

 

 

 

Three Months Ended
June 30

 

Six Months Ended
June 30

 

 

 

2016

 

2015

 

2016

 

2015

 

Operating Revenues

 

$

904

 

 

$

990

 

 

$

2,027

 

 

$

1,622

 

 

Net income (loss)

 

$

(801

)

 

$

388

 

 

$

(811

)

 

$

208

 

 

Adjusted EBITDA

 

$

187

 

 

$

193

 

 

$

438

 

 

$

278

 

 

 

2016 Full-Year Guidance:

·                   Adjusted EBITDA guidance range updated to $1,000-1,100 million and Free Cash Flow guidance updated to $200-300 million

 

ENGIE Acquisition Update:

·                   Issued $2 billion term loan and $460 million in tangible equity units to substantially complete acquisition financing

·                   Acquired Energy Capital Partners’ (ECP) 35% interest in the Atlas joint venture, which was originally formed to purchase ENGIE’s U.S. fossil portfolio

·                   The Public Utility Commission of Texas (PUCT) approved Dynegy’s acquisition of ENGIE’s Texas fossil assets on July 20; the Federal Energy Regulatory Commission (FERC) is the last remaining regulatory approval

 

Recent Developments:

·                   Dynegy to sell its 50% equity interest in Elwood Energy LLC to J-Power USA Development Co. Ltd. for $172.5 million; approximately $35 million previously posted collateral to be returned

·                   Completed 197 MW of advanced gas path (AGP) uprates at five plants, exceeding target of 179 MW

·                   500 MW incremental MISO capacity from Hennepin and Joppa to be pseudo tied to PJM beginning June 1, 2017

 

HOUSTON (August 3, 2016) - Dynegy Inc. (NYSE: DYN) reported a net loss for the 2016 second quarter of $801 million, compared to net income of $388 million for the 2015 second quarter. The quarter-over-quarter decrease is primarily due to a $480 million deferred tax valuation allowance reversal in the second quarter 2015, which did not reoccur in 2016, and a $645 million asset impairment in the second quarter of 2016 primarily related to previously disclosed asset shutdowns.

 

The Company reported consolidated Adjusted EBITDA of $187 million, compared to $193 million for the 2015 second quarter. The $6 million decrease in Adjusted EBITDA was primarily driven by a net increase in operating and maintenance costs in the Gas Segment as a result of a concentration of major planned outages during the quarter partially offset by lower operating and maintenance costs at the Coal and IPH segments due to fewer planned outages.

 

1



 

The net loss for the first half of 2016 was $811 million, compared to net income of $208 million for the first half of 2015. The year-to-date decrease was primarily driven by the second quarter 2015 valuation allowance reversal and second quarter 2016 asset impairment noted above.

 

For the first half of 2016, the Company reported consolidated Adjusted EBITDA of $438 million, compared to $278 million for the first half of 2015. The $160 million increase in Adjusted EBITDA was primarily driven by assets the Company acquired during the second quarter of 2015 and higher capacity revenues in all segments. Partially offsetting these improvements were lower realized power prices and lower generation volumes at the Coal and IPH segments as well as lower spark spreads and generation volumes at the Gas segment, resulting from mild winter weather. Higher operating and maintenance costs associated with planned outages in the Gas segment also impacted results.

 

“During the quarter we continued the transformation of our portfolio. Through our disciplined approach, we completed efficient uprates, made steady progress on the ENGIE acquisition and arranged for the sale of the Elwood Energy Facility. In addition, we announced the retirement of 1,835 MW of generation, and the movement of 500 MW from MISO to PJM,” said Dynegy President and Chief Executive Officer Robert C. Flexon. “The desired outcome from all of these efforts, as well as our ongoing PRIDE improvement program, is a well-constructed portfolio composed of the right assets in the right markets supported by the right balance sheet that generates a strong return for our shareholders.”

 

Second Quarter Comparative Results

 

 

 

Quarter Ended June 30, 2016
(in millions)

 

 

 

 

Coal

 

 

IPH

 

 

Gas

 

 

Other

 

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net loss attributable to Dynegy Inc.

 

 

 

 

 

 

 

 

 

 

 

 

 

$

(801

)

 

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss attributable to noncontrolling interest

 

 

 

 

 

 

 

 

 

 

 

 

 

(2

)

 

Income tax benefit

 

 

 

 

 

 

 

 

 

 

 

 

 

(9

)

 

Other income and expense, net

 

 

 

 

 

 

 

 

 

 

 

 

 

(30

)

 

Interest expense

 

 

 

 

 

 

 

 

 

 

 

 

 

141

 

 

Earnings from unconsolidated investments

 

 

 

 

 

 

 

 

 

 

 

 

 

(1

)

 

Operating income (loss)

 

$

(749

)

 

$

3

 

 

$

90

 

 

$

(46

)

 

$

(702

)

 

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Depreciation and amortization expense

 

27

 

 

3

 

 

132

 

 

2

 

 

164

 

 

Earnings from unconsolidated investments

 

 

 

 

 

1

 

 

 

 

1

 

 

Other income and expense, net

 

6

 

 

14

 

 

12

 

 

(2

)

 

30

 

 

EBITDA (1)

 

(716

)

 

20

 

 

235

 

 

(46

)

 

(507

)

 

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Adjustments to reflect Adjusted EBITDA from unconsolidated investments and exclude noncontrolling interest

 

 

 

2

 

 

1

 

 

 

 

3

 

 

Acquisition and integration costs

 

 

 

(8

)

 

 

 

5

 

 

(3

)

 

Mark-to-market adjustments, including warrants

 

83

 

 

(2

)

 

(52

)

 

 

 

29

 

 

Impairments

 

645

 

 

 

 

 

 

 

 

645

 

 

Wood River energy margin and O&M

 

15

 

 

 

 

 

 

 

 

15

 

 

Non-cash compensation expense

 

 

 

 

 

 

 

5

 

 

5

 

 

Other

 

(1

)

 

(1

)

 

 

 

2

 

 

 

 

Adjusted EBITDA (1)

 

$

26

 

 

$

11

 

 

$

184

 

 

$

(34

)

 

$

187

 

 

 

2



 

 

 

Quarter Ended June 30, 2015

 

 

 

(in millions)

 

 

 

Coal

 

IPH

 

Gas

 

Other

 

Total

 

Net income attributable to Dynegy Inc.

 

 

 

 

 

 

 

 

 

$

388

 

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

 

Loss attributable to noncontrolling interest

 

 

 

 

 

 

 

 

 

(2)

 

Income tax benefit

 

 

 

 

 

 

 

 

 

(501)

 

Other income and expense, net

 

 

 

 

 

 

 

 

 

(4)

 

Interest expense

 

 

 

 

 

 

 

 

 

132

 

Earnings from unconsolidated investments

 

 

 

 

 

 

 

 

 

(3)

 

Operating income (loss)

 

$

(5)

 

$

(14)

 

$

86

 

$

(57)

 

$

10

 

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

 

Depreciation and amortization expense

 

38

 

11

 

124

 

1

 

174

 

Earnings from unconsolidated investments

 

 

 

3

 

 

3

 

Other income and expense, net

 

 

 

 

4

 

4

 

EBITDA (1)

 

33

 

(3)

 

213

 

(52)

 

191

 

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

 

Adjustments to reflect Adjusted EBITDA from unconsolidated investments and exclude noncontrolling interest

 

 

2

 

 

 

2

 

Acquisition and integration costs

 

 

 

 

23

 

23

 

Mark-to-market adjustments, including warrants

 

(14)

 

6

 

(10)

 

(3)

 

(21)

 

Other

 

 

 

(1)

 

(1)

 

(2)

 

Adjusted EBITDA (1)(2)

 

$

19

 

$

5

 

$

202

 

$

(33)

 

$

193

 

 


(1)         EBITDA and Adjusted EBITDA are non-GAAP financial measures and are used by management to evaluate Dynegy’s business on an ongoing basis. Please refer to Item 2.02 of Dynegy’s Form 8-K which is available on the Company’s website: www.dynegy.com and filed on August 3, 2016, for definitions, purposes and uses of such non-GAAP financial measures. General and administrative expenses are not allocated to each segment and are included in the Other segment. Management does not allocate interest expense and income taxes on a segment level and therefore uses Operating income (loss) as the most directly comparable GAAP measure.

 

(2)         Not adjusted for these items which are excluded in 2016: (i) non-cash compensation expense of $8 million, and (ii) Wood River’s energy margin and O&M costs of $9 million.

 

Segment Review of Results Quarter-over-Quarter

 

Gas - The 2016 second quarter operating income was $90 million, compared to $86 million for the same period in 2015. Adjusted EBITDA totaled $184 million during the 2016 second quarter compared to $202 million during the same period in 2015. The quarter-over-quarter decrease in Adjusted EBITDA was driven by higher operating and maintenance costs associated with planned major outages. The Company utilized these planned outages to install capacity uprates. These expenses, together with lower energy margin, were partially offset by higher capacity revenues.

 

Coal - The 2016 second quarter operating loss was $749 million, compared to $5 million for the same period in 2015. Adjusted EBITDA totaled $26 million during the 2016 second quarter compared to $19 million during the same period in 2015. The quarter-over-quarter increase in Adjusted EBITDA primarily resulted from lower operating and maintenance expense due to fewer planned outages. Lower energy margin driven by weaker power prices during the quarter was offset by higher capacity revenues and higher retail margins.

 

3



 

IPH - The 2016 second quarter operating income was $3 million, compared to an operating loss of $14 million for the same period in 2015. Adjusted EBITDA totaled $11 million during the 2016 second quarter compared to $5 million during the same period in 2015. The quarter-over-quarter increase in Adjusted EBITDA was primarily due to lower operating and maintenance expense due to fewer planned outages. An increase in capacity revenues during the period offset lower energy margin resulting from lower power prices and generation.

 

Liquidity

 

As of June 30, 2016, Dynegy’s total available liquidity was $2.2 billion as reflected in the table below, and excludes amounts classified as restricted cash in our unaudited consolidated balance sheet.

 

 

 

June 30, 2016

 

(amounts in millions)

 

Dynegy Inc.

 

IPH (1) (2)

 

Total

 

Revolving facilities and LC capacity (3)

 

$

1,480

 

$

39

 

$

1,519

 

Less: Outstanding LCs

 

(387)

 

(27)

 

(414)

 

Revolving facilities and LC availability

 

1,093

 

12

 

1,105

 

Cash and cash equivalents

 

1,066

 

76

 

1,142

 

Total available liquidity (4)

 

$

2,159

 

$

88

 

$

2,247

 

 


(1)         Includes cash and cash equivalents of $42 million related to Genco.

(2)         Due to the ring-fenced nature of IPH, cash at the IPH and Genco entities may not be moved out of these entities without meeting certain criteria. However, cash at these entities is available to support current operations of these entities.

(3)         Dynegy Includes: (i) $950 million of aggregate available capacity related to our incremental revolving credit facilities, (ii) $475 million of available capacity related to the five-year senior secured revolving credit facility, and (iii) $55 million related to a letter of credit facility.  IPH includes (i) up to a maximum of $25 million related to the two-year secured letter of credit facility and (ii) $14 million related to our fully collateralized letter of credit and reimbursement agreement.

(4)         On December 2, 2013, Dynegy and Illinois Power Resources, LLC entered into an intercompany revolving promissory note of $25 million.  At June 30, 2016, there was approximately $25 million outstanding on the note, which is not reflected in the table above.

 

Consolidated Cash Flow

 

Cash provided by operations for the first half of 2016 was $317 million. During the period, our power generation facilities and retail operations provided cash of $462 million. Corporate and other activities used cash of $250 million primarily for interest payments on various debt agreements.  Changes in working capital and other, net of general and administrative expenses, provided cash of $105 million during the period.

 

Cash used in investing activities during the first half of 2016 was $2.278 billion. During the first half of 2016, non-current restricted cash increased by $2.0 billion from proceeds from the Tranche C Term Loan being held in escrow for the ENGIE acquisition and $69 million in related pre-funded interest and original issuance discount. Additionally, the Company paid $206 million in maintenance capital expenditures, $11 million in environmental capital expenditures and $7 million in capitalized interest. These decreases were partially offset by receipt of an $8 million cash inflow related to distributions from our unconsolidated investment and receipt of $7 million in proceeds from an insurance claim.

 

Cash provided by financing activities during the first half of 2016 was $2.598 billion. During the period, the Company received (i) $2.0 billion in proceeds related to the Tranche C Term Loan, (ii) $446 million in net proceeds from our tangible equity units, and (iii) $198 million of proceeds related to our forward capacity agreement, partially offset by $20 million in repayments associated with our equipment financing agreements and Tranche B-2 Term Loan, $11 million in dividend payments on our mandatory convertible preferred stock, and $9 million in interest rate swap settlement payments.

 

4



 

ENGIE Acquisition

During the second quarter, Dynegy acquired Energy Capital Partners’ (ECP) 35% interest in the Atlas joint venture, which the two companies formed in February 2016 to purchase ENGIE’s U.S. fossil portfolio. In accordance with the agreement with ECP, Dynegy will pay ECP $375 million on the later of December 31, 2016 or three months after the closing of the transaction. Alternatively, Dynegy may pay the ECP buyout price after the first payment date, but in such case, the ECP buyout price would be subject to quarterly escalation up to a maximum of $468.5 million.

 

After reaching an agreement with ECP to acquire their interest in the Atlas joint venture, Dynegy substantially completed the transaction financing by raising a new $2 billion, seven-year, secured term loan and $460 million in tangible equity units. A total of $125 million in incremental liquidity facilities will also be available upon the completion of the acquisition. The Company will use the net proceeds from the financing, together with the proceeds of ECP’s purchase of $150 million of the Company’s common stock to occur concurrently with the closing of the acquisition and existing liquidity, to fund the acquisition and pay related fees and expenses.

 

On July 20, 2016, Dynegy received final approval for the acquisition from the PUCT and remains on schedule to complete the acquisition of ENGIE’s U.S. fossil portfolio in the fourth quarter of 2016 pending the approval of FERC.

 

Elwood Energy Facility Divestiture

Dynegy announced today that it has signed a definitive agreement to sell its 50% equity interest in the Elwood Energy Facility in Elwood, IL to its partner, J-Power USA Development Co. Ltd. for $172.5 million in cash. At closing, approximately $35 million in previously posted collateral will be returned to Dynegy, and the non-recourse asset level financing currently in place will remain with the new owner. The Company intends to use the proceeds of the sale, which is expected to close in the fourth quarter, to satisfy a portion of its buyout obligation to ECP. JP Morgan serves as financial advisor and Skadden, Arps serves as legal counsel on the transaction.

 

MISO Pathway to PJM

In late May, Dynegy filed the Illinois Generation Reliability Act to make Illinois a 100% PJM market instead of its current split between two markets, PJM and MISO. The legislation is consistent with Dynegy’s overall objective of moving all of the Company’s Illinois generating assets to PJM.

 

Outside of this process, the Company received approval for 500 MW of incremental MISO capacity from Hennepin and Joppa to be pseudo tied to PJM beginning June 1, 2017. Dynegy will continue to explore similar paths for its remaining plants in MISO while we wait for a ruling on the proposed legislation.

 

Illinois Unit Shutdowns

On May 3, 2016, Dynegy announced plans to shut down units one and three at the Baldwin Power Station in Baldwin, IL and unit two at the Newton Power Station in Newton, IL after they failed to clear the recent MISO capacity auction. MISO has approved the shutdown of Newton unit two by September 15, 2016 and the shutdown of Baldwin unit one by October 17, 2016. The Company plans to file the shutdown notice for Baldwin unit three in the third quarter. Dynegy’s Wood River Power Station retired on June 1, 2016.

 

5



 

Uprates

 

During the 2016 second quarter, Dynegy completed nearly 200 MW of AGP uprates at five plants as part of the plans the Company announced at its investor day in June 2015.

 

Facility

Amount of Uprate

Market

Total Plant MW post-
uprate

Ontelaunee

40 MW

PJM

640

Fayette

44 MW

PJM

726

Washington

47 MW

PJM

711

Independence

30 MW

NYISO

1,156

Kendall

36 MW

PJM

1,288

 

The uprates at the Company’s legacy plants are part of Pride Energized. The balance of the uprates was included in the Duke and ECP acquisition synergies.

 

2016 Guidance

 

Dynegy’s full-year Adjusted EBITDA guidance range has been updated to $1,000-1,100 million from $1,000 million to $1,200 million previously and Free Cash Flow guidance updated to $200-300 million from $200 million to $400 million previously.

 

PRIDE Energized

PRIDE Energized, the Company’s Producing Results through Innovation by Dynegy Employees program, aims to deliver an incremental $250 million in EBITDA and $400 million in balance sheet improvements by the end of 2018. The Company is on target to achieve the $135 million in Adjusted EBITDA and exceed the $200 million in balance sheet improvements it committed to for this year.

 

New Brand Represents Dynegy’s Growth and Transformation

Dynegy unveiled a new brand yesterday in recognition of how far the Company has come and where it is headed. The brand, which features a bird on a soaring trajectory under a boundless sky, is also a D monogram that represents the Company’s strength and reliability you can count on when needed.

 

“This brand change is a mile marker on Dynegy’s transformative journey. We have rebuilt and enhanced our asset base in just the past few years adding the Ameren, Duke and EquiPower asset portfolios, and with the expected acquisition of the ENGIE assets,” added Flexon. “Dynegy is a much different company today - a Company that is moving forward and upward and one that believes transparency and reliability are at the heart of our dynamic energy company.”

 

Investor Conference Call/Webcast

Dynegy’s earnings presentation and management comments on the earnings presentation will be available on the “Investor Relations” section of www.dynegy.com later today. Dynegy will answer questions about its 2016 second quarter financial results during an investor conference call and webcast tomorrow, August 4, 2016 at 9 a.m. ET/8 a.m. CT. Participants may access the webcast from the Company’s website. If you have trouble viewing the new website, please be sure to clear your cache (CTRL-F5 on Windows computers).

 

About Dynegy

At Dynegy, we generate more than just power for our customers. We are committed to being a leader in the electricity sector. Throughout the Midwest and Northeast, Dynegy operates power generating facilities capable of producing nearly 26,000 megawatts of electricity—or enough energy to power the homes of 21 million U.S. families. We’re proud of what we do, but it’s about much more than just output. We’re always striving to generate power safely and responsibly for our wholesale and retail electricity customers who depend on that energy to grow and thrive.

 

6



 

Forward-Looking Statements

This press release contains statements reflecting assumptions, expectations, projections, intentions or beliefs about future events that are intended as “forward-looking statements,” particularly those statements concerning Dynegy’s: ability to obtain FERC approval and to close the ENGIE acquisition in the fourth quarter; sale, use of proceeds and timing of closing of Dynegy’s ownership interest in its Elwood Energy Facility; expectations of the proposed Illinois Generation Reliability Act; the shutdown of certain Illinois coal-fueled units; execution of its PRIDE Energized target in balance sheet and operating improvements by year-end 2016; anticipated earnings and cash flows and Dynegy’s 2016 Adjusted EBITDA and Free Cash Flow guidance. Historically, Dynegy’s performance has deviated, in some cases materially, from its cash flow and earnings guidance. Discussion of risks and uncertainties that could cause actual results to differ materially from current projections, forecasts, estimates and expectations of Dynegy is contained in Dynegy’s filings with the Securities and Exchange Commission (the “SEC”). Specifically, Dynegy makes reference to, and incorporates herein by reference, the section entitled “Risk Factors” in its 2015 Form 10-K and subsequent Form 10-Qs. In addition to the risks and uncertainties set forth in Dynegy’s SEC filings, the forward-looking statements described in this press release could be affected by, among other things, (i) Dynegy’s expectations and beliefs related to the ENGIE acquisition and satisfying closing conditions, including obtaining FERC approval; (ii) Dynegy’s ability to successfully sell its ownership interest in its Elwood Energy Facility; (iii) Dynegy’s anticipated benefits associated with the proposed legislation (iv) beliefs and assumptions about weather and general economic conditions; (v) beliefs, assumptions, and projections regarding the demand for power, generation volumes, and commodity pricing, including natural gas prices and the timing of a recovery in power market prices, if any; (vi) beliefs and assumptions about market competition, generation capacity, and regional supply and demand characteristics of the wholesale and retail power markets, including the anticipation of plant retirements and higher market pricing over the longer term; (vii) sufficiency of, access to, and costs associated with coal, fuel oil, and natural gas inventories and transportation thereof; (viii) the effects of, or changes to, MISO, PJM, CAISO, NYISO, or ISO-NE power and capacity procurement processes; (ix) expectations regarding, or impacts of, environmental matters, including costs of compliance, availability and adequacy of emission credits, and the impact of ongoing proceedings and potential regulations or changes to current regulations, including those relating to climate change, air emissions, cooling water intake structures, coal combustion byproducts, and other laws and regulations that we are, or could become, subject to, which could increase our costs, result in an impairment of our assets, cause us to limit or terminate the operation of certain of our facilities, or otherwise have a negative financial effect; (x) beliefs about the outcome of legal, administrative, legislative, and regulatory matters; (xi) projected operating or financial results, including anticipated cash flows from operations, revenues, and profitability; (xii) our focus on safety and our ability to efficiently operate our assets so as to capture revenue generating opportunities and operating margins; (xiii) our ability to mitigate forced outage risk, including managing risk associated with CP in PJM and performance incentives in ISO-NE; (xiv) our ability to optimize our assets through targeted investment in cost effective technology enhancements; (xv) the effectiveness of our strategies to capture opportunities presented by changes in commodity prices and to manage our exposure to energy price volatility; (xvi) efforts to secure retail sales and the ability to grow the retail business; (xvii) efforts to identify opportunities to reduce congestion and improve busbar power prices; (xviii) ability to mitigate impacts associated with expiring RMR and/or capacity contracts; (xix) expectations regarding our compliance with the Credit Agreement, including collateral demands, interest expense, any applicable financial ratios, and other payments; (xx) expectations regarding performance standards and capital and maintenance expenditures; (xxi) beliefs concerning the strategic review of Genco, including any restructuring options; (xxii) the timing and anticipated benefits to be achieved through our companywide improvement programs, including our PRIDE initiative; (xxiii) anticipated timing, outcome, and impact of the expected retirement of Brayton Point and the shutdown of Baldwin Units 1 and 3 and Newton Unit 2; (xxiv) beliefs about the costs and scope of the ongoing demolition and site remediation efforts at the Vermilion and Wood River facilities and any potential future remediation obligations at the South Bay facility; (xxv) expectations regarding the synergies, completion, timing, terms, and anticipated benefits of the ENGIE acquisition; and (xxvi) beliefs regarding redevelopment efforts for the Morro Bay facility. Any or all of Dynegy’s forward-looking statements may turn out to be wrong. They can be affected by inaccurate assumptions or by known or unknown risks, uncertainties, and other factors, many of which are beyond Dynegy’s control, including those set forth under Item 1A - Risk Factors of Dynegy’s Form 10-K.

 

Dynegy Inc. Contacts: Media: Micah Hirschfield, 713.767.5800; Analysts: 713.507.6466

 

7



 

DYNEGY INC.

REPORTED UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS

(IN MILLIONS, EXCEPT PER SHARE DATA)

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

2016

 

2015

 

2016

 

2015

Revenues

 

$

904

 

$

990

 

$

2,027

 

$

1,622

Cost of sales, excluding depreciation expense

 

(493)

 

(496)

 

(1,038)

 

(873)

Gross margin

 

411

 

494

 

989

 

749

Operating and maintenance expense

 

(256)

 

(250)

 

(477)

 

(361)

Depreciation expense

 

(160)

 

(175)

 

(331)

 

(239)

Impairments

 

(645)

 

 

(645)

 

Loss on sale of assets, net

 

 

(1)

 

 

(1)

General and administrative expense

 

(39)

 

(35)

 

(76)

 

(65)

Acquisition and integration costs

 

3

 

(23)

 

(1)

 

(113)

Other

 

(16)

 

 

(16)

 

Operating income (loss)

 

(702)

 

10

 

(557)

 

(30)

Earnings from unconsolidated investments

 

1

 

3

 

3

 

3

Interest expense

 

(141)

 

(132)

 

(283)

 

(268)

Other income and expense, net

 

30

 

4

 

31

 

(1)

Loss before income taxes

 

(812)

 

(115)

 

(806)

 

(296)

Income tax benefit (expense)

 

9

 

501

 

(7)

 

501

Net income (loss)

 

(803)

 

386

 

(813)

 

205

Less: Net loss attributable to noncontrolling interest

 

(2)

 

(2)

 

(2)

 

(3)

Net income (loss) attributable to Dynegy Inc.

 

(801)

 

388

 

(811)

 

208

Less: Dividends on preferred stock

 

6

 

6

 

11

 

11

Net income (loss) attributable to Dynegy Inc. common stockholders

 

$

(807)

 

$

382

 

$

(822)

 

$

197

 

 

 

 

 

 

 

 

 

Earnings (Loss) Per Share:

 

 

 

 

 

 

 

 

Basic earnings (loss) per share attributable to Dynegy Inc. common stockholders

 

$

(6.73)

 

$

2.98

 

$

(6.97)

 

$

1.56

Diluted earnings (loss) per share attributable to Dynegy Inc. common stockholders

 

$

(6.73)

 

$

2.73

 

$

(6.97)

 

$

1.49

 

 

 

 

 

 

 

 

 

Basic shares outstanding

 

120

 

128

 

118

 

126

Diluted shares outstanding

 

120

 

142

 

118

 

140

 

8



 

DYNEGY INC.

REPORTED SEGMENTED RESULTS OF OPERATIONS

THREE MONTHS ENDED JUNE 30, 2016

(UNAUDITED) (IN MILLIONS)

 

The following table provides summary financial data regarding our Adjusted EBITDA by segment for the three months ended June 30, 2016:

 

 

 

Three Months Ended June 30, 2016

 

 

Coal

 

IPH

 

Gas

 

Other

 

Total

Net loss attributable to Dynegy Inc.

 

 

 

 

 

 

 

 

 

$

(801)

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

Loss attributable to noncontrolling interest

 

 

 

 

 

 

 

 

 

(2)

Income tax benefit

 

 

 

 

 

 

 

 

 

(9)

Interest expense

 

 

 

 

 

 

 

 

 

141

Depreciation and amortization expense

 

 

 

 

 

 

 

 

 

164

EBITDA (1)

 

$

(716)

 

$

20

 

$

235

 

$

(46)

 

$

(507)

Adjustments to reflect Adjusted EBITDA from unconsolidated investments and exclude noncontrolling interest

 

 

2

 

1

 

 

3

Acquisition and integration costs

 

 

(8)

 

 

5

 

(3)

Mark-to-market adjustments, including warrants

 

83

 

(2)

 

(52)

 

 

29

Impairments

 

645

 

 

 

 

645

Wood River energy margin and O&M

 

15

 

 

 

 

15

Non-cash compensation expense

 

 

 

 

5

 

5

Other

 

(1)

 

(1)

 

 

2

 

Adjusted EBITDA (1)

 

$

26

 

$

11

 

$

184

 

$

(34)

 

$

187

 


 

(1)         EBITDA and Adjusted EBITDA are non-GAAP financial measures.  Please refer to Item 2.02 of our Form 8-K filed on August 3, 2016, for definitions, utility and uses of such non-GAAP financial measures.  A reconciliation of EBITDA to Operating income (loss) is presented below.  Management does not allocate interest expense and income taxes on a segment level and therefore uses Operating income (loss) as the most directly comparable GAAP measure.

 

 

 

Three Months Ended June 30, 2016

 

 

Coal

 

IPH

 

Gas

 

Other

 

Total

Operating income (loss)

 

$

(749)

 

$

3

 

$

90

 

$

(46)

 

$

(702)

Depreciation and amortization expense

 

27

 

3

 

132

 

2

 

164

Earnings from unconsolidated investments

 

 

 

1

 

 

1

Other income and expense, net

 

6

 

14

 

12

 

(2)

 

30

EBITDA

 

$

(716)

 

$

20

 

$

235

 

$

(46)

 

$

(507)

 

9



 

DYNEGY INC.

REPORTED SEGMENTED RESULTS OF OPERATIONS

THREE MONTHS ENDED JUNE 30, 2015

(UNAUDITED) (IN MILLIONS)

 

The following table provides summary financial data regarding our Adjusted EBITDA by segment for the three months ended June 30, 2015:

 

 

 

Three Months Ended June 30, 2015

 

 

Coal

 

IPH

 

Gas

 

Other

 

Total

Net income attributable to Dynegy Inc.

 

 

 

 

 

 

 

 

 

$

388

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

Loss attributable to noncontrolling interest

 

 

 

 

 

 

 

 

 

(2)

Income tax benefit

 

 

 

 

 

 

 

 

 

(501)

Interest expense

 

 

 

 

 

 

 

 

 

132

Depreciation and amortization expense

 

 

 

 

 

 

 

 

 

174

EBITDA (1)

 

$

33

 

$

(3)

 

$

213

 

$

(52)

 

$

191

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

Adjustments to reflect Adjusted EBITDA from unconsolidated investments and exclude noncontrolling interest

 

 

2

 

 

 

2

Acquisition and integration costs

 

 

 

 

23

 

23

Mark-to-market adjustments, including warrants

 

(14)

 

6

 

(10)

 

(3)

 

(21)

Other

 

 

 

(1)

 

(1)

 

(2)

Adjusted EBITDA (1)(2)

 

$

19

 

$

5

 

$

202

 

$

(33)

 

$

193

 


(1)         EBITDA and Adjusted EBITDA are non-GAAP financial measures. Please refer to Item 2.02 of our Form 8-K filed on August 3, 2016, for definitions, utility and uses of such non-GAAP financial measures. A reconciliation of EBITDA to Operating income (loss) is presented below. Management does not allocate interest expense and income taxes on a segment level and therefore uses Operating income (loss) as the most directly comparable GAAP measure.

 

(2)         Not adjusted for these items which are excluded in 2016: (i) non-cash compensation expense of $8 million, and (ii) Wood River’s energy margin and O&M costs of $9 million.

 

 

 

Three Months Ended June 30, 2015

 

 

Coal

 

IPH

 

Gas

 

Other

 

Total

Operating income (loss)

 

$

(5)

 

$

(14)

 

$

86

 

$

(57)

 

$

10

Depreciation and amortization expense

 

38

 

11

 

124

 

1

 

174

Earnings from unconsolidated investments

 

 

 

3

 

 

3

Other income and expense, net

 

 

 

 

4

 

4

EBITDA

 

$

33

 

$

(3)

 

$

213

 

$

(52)

 

$

191

 

10



 

DYNEGY INC.

REPORTED SEGMENTED RESULTS OF OPERATIONS

SIX MONTHS ENDED JUNE 30, 2016

(UNAUDITED) (IN MILLIONS)

 

The following table provides summary financial data regarding our Adjusted EBITDA by segment for the six months ended June 30, 2016:

 

 

 

Six Months Ended June 30, 2016

 

 

Coal

 

IPH

 

Gas

 

Other

 

Total

Net loss attributable to Dynegy Inc.

 

 

 

 

 

 

 

 

 

$

(811)

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

Loss attributable to noncontrolling interest

 

 

 

 

 

 

 

 

 

(2)

Income tax expense

 

 

 

 

 

 

 

 

 

7

Interest expense

 

 

 

 

 

 

 

 

 

283

Depreciation and amortization expense

 

 

 

 

 

 

 

 

 

354

EBITDA (1)

 

$

(632)

 

$

44

 

$

506

 

$

(87)

 

$

(169)

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

Adjustments to reflect Adjusted EBITDA from unconsolidated investments and exclude noncontrolling interest

 

 

2

 

4

 

 

6

Acquisition and integration costs

 

 

(8)

 

 

9

 

1

Mark-to-market adjustments, including warrants

 

43

 

(5)

 

(114)

 

(1)

 

(77)

Impairments

 

645

 

 

 

 

645

Wood River energy margin and O&M

 

20

 

 

 

 

20

Non-cash compensation expense

 

 

 

1

 

11

 

12

Other

 

 

(1)

 

(1)

 

2

 

Adjusted EBITDA (1)

 

$

76

 

$

32

 

$

396

 

$

(66)

 

$

438

 


(1)         EBITDA and Adjusted EBITDA are non-GAAP financial measures. Please refer to Item 2.02 of our Form 8-K filed on August 3, 2016, for definitions, utility and uses of such non-GAAP financial measures. A reconciliation of EBITDA to Operating income (loss) is presented below. Management does not allocate interest expense and income taxes on a segment level and therefore uses Operating income (loss) as the most directly comparable GAAP measure.

 

 

 

Six Months Ended June 30, 2016

 

 

Coal

 

IPH

 

Gas

 

Other

 

Total

Operating income (loss)

 

$

(695)

 

$

17

 

$

210

 

$

(89)

 

$

(557)

Depreciation and amortization expense

 

57

 

13

 

281

 

3

 

354

Earnings from unconsolidated investments

 

 

 

3

 

 

3

Other income and expense, net

 

6

 

14

 

12

 

(1)

 

31

EBITDA

 

$

(632)

 

$

44

 

$

506

 

$

(87)

 

$

(169)

 

11



 

DYNEGY INC.

REPORTED SEGMENTED RESULTS OF OPERATIONS

SIX MONTHS ENDED JUNE 30, 2015

(UNAUDITED) (IN MILLIONS)

 

The following table provides summary financial data regarding our Adjusted EBITDA by segment for the six months ended June 30, 2015:

 

 

 

Six Months Ended June 30, 2015

 

 

Coal

 

IPH

 

Gas

 

Other

 

Total

Net income attributable to Dynegy Inc.

 

 

 

 

 

 

 

 

 

$

208

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

Loss attributable to noncontrolling interest

 

 

 

 

 

 

 

 

 

(3)

Income tax benefit

 

 

 

 

 

 

 

 

 

(501)

Interest expense

 

 

 

 

 

 

 

 

 

268

Depreciation and amortization expense

 

 

 

 

 

 

 

 

 

238

EBITDA (1)

 

$

50

 

$

29

 

$

308

 

$

(177)

 

$

210

Plus / (Less):

 

 

 

 

 

 

 

 

 

 

Adjustments to reflect Adjusted EBITDA from unconsolidated investments and exclude noncontrolling interest

 

 

3

 

 

 

3

Acquisition and integration costs

 

 

 

 

113

 

113

Mark-to-market adjustments, including warrants

 

(21)

 

(5)

 

(23)

 

2

 

(47)

Other

 

 

 

(1)

 

 

(1)

Adjusted EBITDA (1)(2)

 

$

29

 

$

27

 

$

284

 

$

(62)

 

$

278

 


(1)         EBITDA and Adjusted EBITDA are non-GAAP financial measures. Please refer to Item 2.02 of our Form 8-K filed on August 3, 2016, for definitions, utility and uses of such non-GAAP financial measures. A reconciliation of EBITDA to Operating income (loss) is presented below. Management does not allocate interest expense and income taxes on a segment level and therefore uses Operating income (loss) as the most directly comparable GAAP measure.

 

(2)         Not adjusted for these items which are excluded in 2016: (i) non-cash compensation expense of $14 million, and (ii) Wood River’s energy margin and O&M costs of $8 million.

 

 

 

Six Months Ended June 30, 2015

 

 

Coal

 

IPH

 

Gas

 

Other

 

Total

Operating income (loss)

 

$

2

 

$

8

 

$

138

 

$

(178)

 

$

(30)

Depreciation and amortization expense

 

48

 

21

 

167

 

2

 

238

Earnings from unconsolidated investments

 

 

 

3

 

 

3

Other income and expense, net

 

 

 

 

(1)

 

(1)

EBITDA

 

$

50

 

$

29

 

$

308

 

$

(177)

 

$

210

 

12



 

DYNEGY INC.

 

OPERATING DATA

 

The following table provides summary financial data regarding our Coal, IPH and Gas segment results of operations for the three and six months ended June 30, 2016 and 2015, respectively.

 

 

 

Three Months Ended June 30,

 

Six Months Ended June 30,

 

 

 

2016

 

 

2015

 

 

2016

 

 

2015

 

 

Coal

 

 

 

 

 

 

 

 

 

 

 

 

 

Million Megawatt Hours Generated (8)

 

7.7

 

 

7.5

 

 

15.3

 

 

12.3

 

 

IMA for Coal-Fired Facilities (1) (8)

 

82

%

 

72

%

 

82

%

 

79

%

 

Average Capacity Factor for Coal-Fired Facilities (2) (8)

 

52

%

 

50

%

 

49

%

 

57

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average Quoted Market On-Peak Power Prices ($/MWh) (3):

 

 

 

 

 

 

 

 

 

 

 

 

 

Indiana (Indy Hub)

 

$

31.14

 

 

$

33.15

 

 

$

28.38

 

 

$

36.21

 

 

Commonwealth Edison (NI Hub)

 

$

28.87

 

 

$

31.47

 

 

$

28.11

 

 

$

36.15

 

 

Mass Hub

 

$

28.17

 

 

$

29.16

 

 

$

31.01

 

 

$

62.67

 

 

AD Hub

 

$

30.43

 

 

$

37.58

 

 

$

29.61

 

 

$

41.42

 

 

Average Quoted Market Off-Peak Power Prices ($/MWh) (3):

 

 

 

 

 

 

 

 

 

 

 

 

 

Indiana (Indy Hub)

 

$

22.37

 

 

$

23.89

 

 

$

21.27

 

 

$

26.43

 

 

Commonwealth Edison (NI Hub)

 

$

19.32

 

 

$

19.70

 

 

$

19.93

 

 

$

23.78

 

 

Mass Hub

 

$

20.43

 

 

$

19.25

 

 

$

23.32

 

 

$

47.84

 

 

AD Hub

 

$

21.71

 

 

$

25.92

 

 

$

22.32

 

 

$

29.09

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

IPH

 

 

 

 

 

 

 

 

 

 

 

 

 

Million Megawatt Hours Generated

 

3.3

 

 

4.7

 

 

6.6

 

 

9.9

 

 

IMA for IPH Facilities (4)

 

91

%

 

91

%

 

90

%

 

92

%

 

Average Capacity Factor for IPH Facilities (5)

 

38

%

 

54

%

 

38

%

 

56

%

 

Average Quoted Market Power Prices ($/MWh) (3):

 

 

 

 

 

 

 

 

 

 

 

 

 

On-Peak: Indiana (Indy Hub)

 

$

31.14

 

 

$

33.15

 

 

$

28.38

 

 

$

36.21

 

 

Off-Peak: Indiana (Indy Hub)

 

$

22.37

 

 

$

23.89

 

 

$

21.27

 

 

$

26.43

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gas

 

 

 

 

 

 

 

 

 

 

 

 

 

Million Megawatt Hours Generated (8)

 

11.9

 

 

12.8

 

 

25.2

 

 

17.8

 

 

IMA for Combined Cycle Facilities (4) (8)

 

98

%

 

97

%

 

97

%

 

98

%

 

Average Capacity Factor for Combined Cycle Facilities (5) (8)

 

53

%

 

61

%

 

57

%

 

61

%

 

Average Market On-Peak Spark Spreads ($/MWh) (6):

 

 

 

 

 

 

 

 

 

 

 

 

 

Commonwealth Edison (NI Hub)

 

$

14.23

 

 

$

12.57

 

 

$

13.64

 

 

$

15.13

 

 

PJM West

 

$

21.15

 

 

$

29.38

 

 

$

19.94

 

 

$

23.46

 

 

North of Path 15 (NP 15)

 

$

10.76

 

 

$

14.99

 

 

$

10.74

 

 

$

13.82

 

 

New York—Zone A

 

$

23.98

 

 

$

22.34

 

 

$

20.34

 

 

$

31.07

 

 

Mass Hub

 

$

11.02

 

 

$

13.48

 

 

$

10.92

 

 

$

14.21

 

 

AD Hub

 

$

27.53

 

 

$

24.19

 

 

$

29.68

 

 

$

40.02

 

 

Average Market Off-Peak Spark Spreads ($/MWh) (6):

 

 

 

 

 

 

 

 

 

 

 

 

 

Commonwealth Edison (NI Hub)

 

$

4.68

 

 

$

0.80

 

 

$

5.47

 

 

$

2.75

 

 

PJM West

 

$

11.38

 

 

$

15.66

 

 

$

12.09

 

 

$

8.32

 

 

North of Path 15 (NP 15)

 

$

4.71

 

 

$

7.79

 

 

$

5.37

 

 

$

7.51

 

 

New York—Zone A

 

$

6.79

 

 

$

6.54

 

 

$

5.86

 

 

$

15.93

 

 

Mass Hub

 

$

3.28

 

 

$

3.58

 

 

$

3.23

 

 

$

(0.62

)

 

AD Hub

 

$

11.32

 

 

$

15.72

 

 

$

12.64

 

 

$

16.93

 

 

Average natural gas price—Henry Hub ($/MMBtu) (7)

 

$

2.11

 

 

$

2.72

 

 

$

2.04

 

 

$

2.80

 

 

 

13



 


(1)         IMA is an internal measurement calculation that reflects the percentage of generation available during periods when market prices are such that these units could be profitably dispatched. This calculation excludes certain events outside of management control such as weather related issues. The calculation excludes our Brayton Point facility and CTs.  The IMA for our facilities within MISO and PJM (excluding CTs) was 86 percent and 79 percent, respectively, for the three months ended June 30, 2016 and 76 percent and 70 percent, respectively, for the three months ended June 30, 2015.  The IMA for our facilities within MISO and PJM (excluding CTs) was 87 percent and 78 percent, respectively, for the six months ended June 30, 2016 and 86 percent and 70 percent, respectively, for the six months ended June 30, 2015.

 

(2)         Reflects actual production as a percentage of available capacity. The calculation excludes our Brayton Point facility and CTs. The average capacity factors for our facilities within MISO and PJM (excluding CTs) were 59 percent and 46 percent, respectively, for the three months ended June 30, 2016 and 56 percent and 45 percent, respectively, for the three months ended June 30, 2015. The average capacity factors for our facilities within MISO and PJM (excluding CTs) were 54 percent and 44 percent, respectively, for the six months ended June 30, 2016 and 65 percent and 45 percent, respectively, for the six months ended June 30, 2015.

 

(3)         Reflects the average of day-ahead quoted prices for the periods presented and does not necessarily reflect prices we realized.

 

(4)         IMA is an internal measurement calculation that reflects the percentage of generation available during periods when market prices are such that these units could be profitably dispatched. This calculation excludes certain events outside of management control such as weather related issues.

 

(5)         Reflects actual production as a percentage of available capacity.

 

(6)         Reflects the simple average of the on- and off-peak spark spreads available to a 7.0 MMBtu/MWh heat rate generator selling power at day-ahead prices and buying delivered natural gas at a daily cash market price and does not reflect spark spreads available to us.

 

(7)         Reflects the average of daily quoted prices for the periods presented and does not reflect costs incurred by us.

 

(8)         Reflects the activity for the period in which the Acquisitions were included in our consolidated results.

 

14



 

DYNEGY INC.

 

2016 ADJUSTED EBITDA AND FREE CASH FLOW GUIDANCE

 

(UNAUDITED) (IN MILLIONS)

 

The following table provides summary financial data regarding our 2016 Adjusted EBITDA guidance, updated based on April 19, 2016 forward curves, as presented on May 3, 2016:

 

 

 

 

 

 

 

Dynegy Consolidated

 

 

 

Low

 

 

High

 

 

Net loss attributable to Dynegy Inc. (1)

 

$

(351

)

 

$

(181

)

 

Plus / (Less):

 

 

 

 

 

 

 

Income tax expense (2)

 

16

 

 

16

 

 

Interest expense

 

540

 

 

545

 

 

Earnings from unconsolidated investments (2)

 

(2

)

 

(2

)

 

Operating Income

 

203

 

 

378

 

 

Depreciation expense

 

710

 

 

730

 

 

Amortization expense

 

30

 

 

30

 

 

Earnings from unconsolidated investments (2)

 

2

 

 

2

 

 

EBITDA (3)

 

945

 

 

1,140

 

 

Plus / (Less):

 

 

 

 

 

 

 

Earnings from unconsolidated investments (2)

 

(2

)

 

(2

)

 

Acquisition and integration costs

 

35

 

 

40

 

 

Other (4)

 

22

 

 

22

 

 

Adjusted EBITDA (3)

 

$

1,000

 

 

$

1,200

 

 

 


 

(1)         For purposes of Net loss attributable to Dynegy Inc. guidance reconciliation, mark-to-market adjustments and changes in the fair value of common stock warrants are assumed to be zero.

 

(2)         Represents actual amounts for the three months ended March 31, 2016.

 

(3)         EBITDA and Adjusted EBITDA are non-GAAP measures.

 

(4)         Represents actual amounts for three months ended March 31, 2016. Other consists primarily of cash distributions from unconsolidated investments, asset retirement obligation accretion, non-cash compensation expense, and energy margin and operating and maintenance costs associated with our Wood River facility.

 

 

The following table provides summary financial data regarding our 2016 Free Cash Flow guidance:

 

 

 

 

 

 

 

Dynegy Consolidated

 

 

 

Low

 

 

High

 

 

Adjusted EBITDA (1)

 

$

1,000

 

 

$

1,200

 

 

Cash interest payments

 

(515

)

 

(515

)

 

Acquisition and integration costs

 

(35

)

 

(40

)

 

Other cash items

 

10

 

 

10

 

 

Cash Flow from Operations

 

460

 

 

655

 

 

Maintenance capital expenditures

 

(275

)

 

(275

)

 

Environmental capital expenditures

 

(20

)

 

(20

)

 

Acquisition and integration costs

 

35

 

 

40

 

 

Free Cash Flow (1)

 

$

200

 

 

$

400

 

 

 


(1)         Adjusted EBITDA and Free Cash Flow are non-GAAP measures.

 

15



 

DYNEGY INC.

 

2016 ADJUSTED EBITDA AND FREE CASH FLOW GUIDANCE

 

(UNAUDITED) (IN MILLIONS)

 

The following table provides summary financial data regarding our 2016 Adjusted EBITDA guidance, updated based on July 14, 2016 forward curves, as presented on August 3, 2016:

 

 

 

 

 

 

 

Dynegy Consolidated

 

 

 

Low

 

 

High

 

 

Net loss attributable to Dynegy Inc. (1)

 

$

(1,038

)

 

$

(968

)

 

Plus / (Less):

 

 

 

 

 

 

 

Loss attributable to noncontrolling interest (2)

 

(2

)

 

(2

)

 

Income tax expense (2)

 

7

 

 

7

 

 

Other income and expense, net (2)

 

(31

)

 

(31

)

 

Interest expense

 

605

 

 

610

 

 

Earnings from unconsolidated investments (2)

 

(3

)

 

(3

)

 

Operating loss

 

(462

)

 

(387

)

 

Depreciation and amortization expense

 

700

 

 

720

 

 

Earnings from unconsolidated investments (2)

 

3

 

 

3

 

 

Other income and expense, net (2)

 

31

 

 

31

 

 

EBITDA (3)

 

272

 

 

367

 

 

Plus / (Less):

 

 

 

 

 

 

 

Acquisition and integration costs

 

45

 

 

50

 

 

Impairments (2)

 

645

 

 

645

 

 

Other (4)

 

38

 

 

38

 

 

Adjusted EBITDA (3)

 

$

1,000

 

 

$

1,100

 

 

 


(1)         For purposes of Net loss attributable to Dynegy Inc. guidance reconciliation, mark-to-market adjustments and changes in the fair value of common stock warrants are assumed to be zero.

 

(2)         Represents actual amounts for the six months ended June 30, 2016.

 

(3)         EBITDA and Adjusted EBITDA are non-GAAP measures.

 

(4)         Represents actual amounts for six months ended June 30, 2016. Other consists primarily of adjustments to reflect Adjusted EBITDA from unconsolidated investment and exclude noncontrolling interest, non-cash compensation expense, and Wood River’s energy margin and operating and maintenance costs.

 

16



 

The following table provides summary financial data regarding our 2016 Free Cash Flow guidance:

 

 

 

 

 

 

Dynegy Consolidated

 

 

 

Low

 

 

High

 

 

Adjusted EBITDA (1)

 

$

1,000

 

 

$

1,100

 

 

Cash interest payments (2)

 

(515

)

 

(515

)

 

Acquisition and integration costs

 

(45

)

 

(50

)

 

Other cash items

 

10

 

 

10

 

 

Cash Flow from Operations

 

450

 

 

545

 

 

Maintenance capital expenditures

 

(275

)

 

(275

)

 

Environmental capital expenditures

 

(20

)

 

(20

)

 

Acquisition and integration costs

 

45

 

 

50

 

 

Free Cash Flow (1)

 

$

200

 

 

$

300

 

 

 


(1)         Adjusted EBITDA and Free Cash Flow are non-GAAP measures.

 

(2)         Excludes payments to an escrow account of (i) $50 million of pre-funded interest and (ii) $20 million of prefunded original issue discount which are contingent upon the closing of the ENGIE acquisition.

 

17




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