Market Overview

Dynegy Announces 2017 First Quarter Results

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Dynegy Inc. (NYSE:DYN):

 

Summary of First Quarter 2017 Financial Results (in millions):

 
 

Three Months Ended
March 31,

2017   2016
Operating Revenues $ 1,247 $ 1,123
Net Income (loss) $ 597 $ (10 )
Adjusted EBITDA (1) $ 230 $ 251
 

2017 Guidance Ranges (in millions):

 
Adjusted EBITDA (1)   $1,200 - $1,400
Adjusted Free Cash Flow (1) $300 - $500; increased from the prior range of $150 - $350
 

Operating Highlights:

  • Adjusted free cash flow guidance increased by $150 million due to
    modified capital and outage plan
  • $1.4 billion in liquidity at March 31, 2017
  • Generated nearly 26 million megawatt hours in first quarter 2017
  • Safety performance improved by nearly 50% in the first quarter as
    compared to 2016

Portfolio Transformation:

  • Completed the Illinois Power Holdings (Genco) financial restructuring
    in February 2017, resulting in a simplified, more efficient corporate
    structure and a strengthened balance sheet with more than $640 million
    of debt eliminated
  • Signed an agreement with LS Power to sell Armstrong and Troy PJM
    peaking units, 1,269 MW total, for $480 million ($378/kW) and received
    early termination of the Hart-Scott-Rodino Act waiting period;
    proceeds will go toward debt reduction
  • Currently in the second round of the mitigation sales process for
    Milford (MA) and Dighton, 364 MW total
  • Signed agreements with joint operating partners, AEP and AES, to
    retire the Stuart and Killen power plants, nearly 3,000 MW total, by
    mid-2018
  • Agreed to purchase AES' 28.1% ownership interest in Zimmer Power
    Station and 36% interest in Miami Fort Power Station, approximately
    740 MW total, for $50 million plus working capital
___________________________________
    (1) Adjusted EBITDA and Adjusted Free Cash Flow are non-GAAP financial
measures; see "Regulation G Reconciliations" for further details.
 

Dynegy Inc. (NYSE:DYN) reported net income of $597 million for the
first quarter of 2017, compared to a net loss of $10 million for the
first quarter of 2016. The quarter-over-quarter increase is mainly due
to a $483 million gain from the cancellation of debt resulting from the
Genco restructuring and a $313 million tax benefit primarily resulting
from the partial release of a deferred tax valuation allowance as a
result of the ENGIE acquisition. These benefits were offset by a $194
million decrease in operating income due to reduced spark spreads from
mild winter weather, lower gains on our hedging transactions and
incremental acquisition and integration costs as a result of the ENGIE
acquisition.

The Company reported consolidated Adjusted EBITDA of $230 million for
the 2017 first quarter compared to $251 million for the 2016 first
quarter. While the assets acquired from ENGIE during the first quarter
of 2017 contributed $15 million in Adjusted EBITDA, consolidated results
declined as a result of lower capacity revenues and energy margin, net
of hedges, at the PJM and NY/NE segments as mild winter weather and
increased gas costs lowered energy margin compared to the first quarter
of 2016.

"Protection provided by our hedging program and our growth in retail
contracting has enabled us to remain on track financially despite the
lack of weather and a persistently low commodity price environment,"
said Robert Flexon, Dynegy President and Chief Executive Officer.
"Additionally, we made significant progress during the quarter on our
multiple delevering strategies which consist of various asset sales,
cash generated by our portfolio including the newly acquired ENGIE fleet
and other portfolio optimization efforts."

 

First Quarter Comparative Results

 
  Quarter Ended March 31,
2017   2016
(in millions)

Operating Income
(Loss)

  Adjusted EBITDA (1)

Operating Income
(Loss)

  Adjusted EBITDA (1)
PJM $ 86 $ 191 $ 177 $ 209
NY/NE (41 ) 42 (2 ) 53
ERCOT (28 ) (9 )
MISO 17 10 13 (1 )
IPH 18 31 14 21
CAISO (14 ) (3 ) (14 )
Other (87 ) (32 ) (43 ) (31 )
Total $ (49 ) $ 230   $ 145   $ 251  
___________________________________
    (1) Adjusted EBITDA is a non-GAAP financial measure, see "Regulation G
Reconciliations" for further details.
 

Segment Review of Results Quarter-over-Quarter

PJM - Operating income for the 2017 first quarter totaled $86
million, compared to $177 million for the same period of 2016, as
non-cash mark-to-market losses on derivatives, a non-cash impairment
related to the Killen facility, lower capacity revenues and lower energy
margin, net of hedges pressured results. Adjusted EBITDA totaled $191
million during the 2017 first quarter compared to $209 million during
the same period in 2016 as lower energy margins, net of hedges, together
with lower capacity revenues more than offset contributions from the new
assets acquired from ENGIE.

NY/NE - Operating loss for the 2017 first quarter totaled $41
million, compared to $2 million for the same period in 2016, primarily
due to non-cash mark-to-market losses on derivatives. Adjusted EBITDA
totaled $42 million during the 2017 first quarter, compared to $53
million during the same period in 2016 as lower energy margins, net of
hedges, and lower capacity revenues more than offset contributions from
the new assets acquired from ENGIE.

ERCOT - Operating loss for the 2017 first quarter totaled $28
million, while Adjusted EBITDA was a loss of $9 million for the same
period. Results for the quarter include $4 million in operations support
overhead allocation and reflect the impact of five unit outages in
February and March without the benefit of ownership in January.

MISO/IPH - Operating income for the 2017 first quarter totaled
$35 million, compared to $27 million for the same period in 2016, as
higher capacity revenues and lower O&M costs more than offset non-cash
mark-to-market losses on derivatives and lower energy margin, net of
hedges. Adjusted EBITDA totaled $41 million during the 2017 first
quarter compared to $20 million during the same period in 2016 as the
capacity revenue and O&M benefits noted above more than offset lower
energy margin, net of hedges.

CAISO - Operating loss for the 2017 first quarter totaled $14
million, unchanged from the same period in 2016. Adjusted EBITDA loss
totaled $3 million during the 2017 first quarter compared to breakeven
during the same period in 2016 due to lower energy margin, net of hedges.

Liquidity

As of March 31, 2017, Dynegy's total available liquidity was $1.4
billion as reflected in the table below.

 
(amounts in millions)    
Revolving facilities and LC capacity (1) $ 1,675
Less:
Outstanding revolvers (300 )
Outstanding LCs (476 )
Revolving facilities and LC availability 899
Cash and cash equivalents 467  
Total available liquidity $ 1,366  
___________________________________
    (1) Dynegy Inc. includes $1.5 billion in senior secured revolving credit
facilities and $130 million related to LCs.
 

Consolidated Cash Flow

Cash provided by operations totaled $149 million for the first quarter
2017. During the period, our power generation facilities and retail
operations provided cash of $261 million. Corporate activities,
primarily related to general and administrative, interest and
acquisition-related expenses, as well as other working capital changes
used cash of $112 million during the period.

Cash used in investing activities totaled $3.3 billion during the first
quarter 2017 as Dynegy used $3,263 million at the closing of the ENGIE
acquisition and invested $31 million in capital expenditures.

Cash used in financing activities totaled $228 million for the first
quarter 2017. Cash uses include (i) $375 million paid for the Energy
Capital Partners Buyout, (ii) $119 million of payments related to the
termination of the Genco senior notes (iii) $99 million in financing
costs related to our debt issuances, (iv) $75 million for debt reduction
related to Dynegy's equipment financing agreements and tangible equity
units (TEUs), (v) $5 million in dividend payments on our preferred stock
and (vi) $4 million in interest rate swap settlement payments. Partially
offsetting these cash outflows were (i) $300 million in cash proceeds
from a revolver draw and (ii) $150 million in cash proceeds from the
issuance of Dynegy Inc. common stock to ECP at the closing of the ENGIE
acquisition.

2017 Guidance

Dynegy's full-year 2017 Adjusted EBITDA guidance range remains unchanged
at $1,200-1,400 million. The Company's Adjusted free cash flow range is
being increased by $150 million, to $300 million to $500 million,
primarily as a result of deferring and changing the scope of previously
scheduled maintenance capital expenditures.

Environmental Update/Capital Allocation

As previously disclosed, Dynegy has continued to evaluate the timing of
ELG-related projects and related expenditures and has determined that,
based on existing rules, most of the projects originally scheduled for
2017 and 2018 will be delayed for approximately two years. As a result,
approximately $40 million in ELG-related capital expenditures originally
expected in 2017 have been rescheduled to 2019 and approximately $140
million in 2018 spend has been rescheduled to 2020.

Additionally, the Company recently restructured the first tranche of an
existing PJM capacity monetization to defer settlement of the obligation
from planning year 2017-2018 to planning year 2019-2020. As a result,
$64 million in payments originally scheduled for 2017 have been deferred
to 2019, and $45 million in payments originally scheduled for 2018 have
been deferred to 2020.

The funds previously allocated to these items have been reallocated to
debt reduction.

Retail Growth

Dynegy's retail business has grown to become one of the top five
residential suppliers in Ohio and is committed to expanding its presence
in the state. Recently, the retail business finalized its largest
aggregation contract, a three-year municipal agreement to supply
electricity to the residents of the City of Cincinnati. Dynegy currently
has a successful integrated wholesale and retail platform in Ohio and
Illinois and is actively pursuing broadening it to other locations where
the Company has generation.

Safety

Total safety performance in the first quarter of 2017 improved by nearly
50% as compared to 2016. Dynegy's gas facilities continued to perform in
the top decile, while coal-fueled units improved significantly due to
focus on rigorous safety initiatives.

Environmental Improvements

Dynegy's transformation to a largely gas-fueled portfolio of assets has
significantly improved the Company's environmental footprint. Between
2014 and 2017, sulfur dioxide (SO2), greenhouse gases (GHG)
and nitrogen oxides (NOx) emissions intensities (lb/MWh) will have
declined by 48%, 25% and 17% respectively. (1)

In addition, the Company is well on its way to realizing its stated goal
of recycling 100% of coal combustion byproduct (CCB) for beneficial
reuse by 2020, with Dynegy reusing more than 70% of CCB last year and on
track to achieve 80% by the end of 2017. Applications include serving as
a substitute for cement in concrete and as a replacement for gypsum in
wallboard. This lessens landfill needs and directly offsets CO2
generated by manufacturing these products. It not only makes good
environmental sense, it makes good financial sense by eliminating a cost
stream and turning it into a revenue stream.

(1) 2017 emissions are based on expected asset ownership and
forecasted production.

Updates to Asset Portfolio

Peaker Sales to LS Power

On February 23, Dynegy signed an agreement with LS Power to sell
Armstrong and Troy, two PJM peaking units totaling 1,269 MW, for $480
million ($378/kW). On April 6, the United States Department of
Justice and Federal Trade Commission granted early termination of the
Hart-Scott-Rodino Act waiting period. The transaction close is pending
Federal Energy Regulatory Commission (FERC) approval.

Southeastern New England (SENE) Mitigation

Dynegy is engaged in the second round of its auction process for assets
the Company intends to sell to meet FERC's market mitigation
requirements associated with the ENGIE acquisition approval.

Asset Retirements

Dynegy and its joint operating partners, AEP and AES, have formally
agreed to shut down the Stuart and Killen coal-fueled facilities
totaling approximately 3,000 MW by mid-2018. Current ownership interests
will be retained through the shutdown date, and the Company's portion of
previously cleared capacity from Stuart and Killen will be transferred
to other Dynegy plants.

Ownership Consolidation of Jointly Owned Units

On April 24, Dynegy agreed to purchase AES' 28.1% ownership interest in
Zimmer and 36% in Miami Fort stations, totaling approximately 740 MW of
generating capacity, for $50 million, subject to certain adjustments. As
previously disclosed, Dynegy will also acquire AEP's ownership interest
in Zimmer and sell its ownership interest in Conesville to AEP. No
consideration will be exchanged between AEP and Dynegy, however AEP will
return a previously issued letter of credit totaling $58 million to
Dynegy. Upon closing, the Company will fully own and operate Miami Fort
and Zimmer with no additional debt incurred and no material impact to
liquidity.

PRIDE Update and ENGIE Integration

Dynegy's PRIDE Energized (Producing Results through Innovation by Dynegy
Employees) program is on track to meet its 2017 target of $65 million in
EBITDA by the end of the fourth quarter and already exceeded its
three-year balance sheet goal of $400 million in 2016 with $422 million
in improvements. Dynegy has identified over $75 million in additional
balance sheet improvements for 2017 to further exceed the three-year
target.

To date, Dynegy has secured $95 million of the $120 million
ENGIE synergies target and remains on track to achieve 90% of the
targeted ENGIE synergies by year end.

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. The Company will answer questions about its 2017 first
quarter financial results during an investor conference call and webcast
tomorrow, May 5, 2017 at 9 a.m. ET/8 a.m. CT. Participants may access
the webcast from the Company's website.

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
Northeast, Mid-Atlantic, Midwest and Texas, Dynegy operates power
generating facilities capable of producing more than 31,000 megawatts of
electricity—or enough energy to power about 25 million American homes.
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.

Forward-Looking Statement

This news 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 beliefs and expectations regarding sale
of Dynegy's PJM peaking units, the sale process to satisfy the FERC
market mitigation requirements, anticipated asset retirements, and
ownership consolidation of Zimmer and Miami Fort units; execution of its
PRIDE Energized target in balance sheet and operating improvements; the
execution and timing of debt repayments and various delevering
strategies; broadening the retail platform; achievement of Dynegy's CCB
goals; anticipated earnings and cash flows and Dynegy's 2017 Adjusted
EBITDA and Adjusted 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 2016 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) beliefs and assumptions about weather and general economic
conditions;(ii) 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; (iii) 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;
(iv) sufficiency of, access to, and costs associated with coal, fuel
oil, and natural gas inventories and transportation thereof; (v) the
effects of, or changes to the power and capacity procurement processes
in the markets in which we operate; (vi) 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; (vii) beliefs about the
outcome of legal, administrative, legislative, and regulatory matters,
including any impacts from the change in administration to these
matters; (viii) projected operating or financial results, including
anticipated cash flows from operations, revenues, and profitability;
(ix) our focus on safety and our ability to operate our assets
efficiently so as to capture revenue generating opportunities and
operating margins; (x) our ability to mitigate forced outage risk,
including managing risk associated with CP in PJM and performance
incentives in ISO-NE; (xi) our ability to optimize our assets through
targeted investment in cost effective technology enhancements; (xii) the
effectiveness of our strategies to capture opportunities presented by
changes in commodity prices and to manage our exposure to energy price
volatility; (xiii) efforts to secure retail sales and the ability to
grow the retail business; (xiv) efforts to identify opportunities to
reduce congestion and improve busbar power prices; (xv) ability to
mitigate impacts associated with expiring reliability must run "RMR"
and/or capacity contracts; (xvi) expectations regarding our compliance
with the Credit Agreement, including collateral demands, interest
expense, any applicable financial ratios, and other payments;
(xvii) expectations regarding performance standards and capital and
maintenance expenditures; (xviii) the timing and anticipated benefits to
be achieved through our Company-wide improvement programs, including our
PRIDE initiative; (xix) expectations regarding strengthening the balance
sheet, managing debt and improving Dynegy's leverage profile; (xx)
expectations, timing and benefits of the AES and AEP transactions; (xxi)
efforts to divest assets and the associated timing of such divestitures,
and anticipated use of proceeds from such divestitures; (xxii)
anticipated timing, outcome and impact of expected retirements; (xxiii)
beliefs about the costs and scope of the ongoing demolition and site
remediation efforts; and (xxiv) expectations regarding the synergies and
anticipated benefits of the ENGIE Acquisition. 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.
REPORTED UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS
(IN MILLIONS, EXCEPT PER SHARE DATA)
 
  Three Months Ended March 31,
2017   2016
Revenues $ 1,247 $ 1,123
Cost of sales, excluding depreciation expense (757 ) (545 )
Gross margin 490 578
Operating and maintenance expense (232 ) (221 )
Depreciation expense (200 ) (171 )
Impairments (20 )
General and administrative expense (40 ) (37 )
Acquisition and integration costs (45 ) (4 )
Other (2 )  
Operating income (loss) (49 ) 145
Bankruptcy reorganization items 483
Earnings (losses) from unconsolidated investments (1 ) 2
Interest expense (167 ) (142 )
Other income and expense, net 17   1  
Income before income taxes 283 6
Income tax benefit (expense) 313   (16 )
Net income (loss) 596 (10 )
Less: Net loss attributable to noncontrolling interest (1 )  
Net income (loss) attributable to Dynegy Inc. 597 (10 )
Less: Dividends on preferred stock 5   5  
Net income (loss) attributable to Dynegy Inc. common stockholders $ 592   $ (15 )
 
Earnings (Loss) Per Share:
Basic earnings (loss) per share attributable to Dynegy Inc. common
stockholders
$ 4.00 $ (0.13 )
Diluted earnings (loss) per share attributable to Dynegy Inc. common
stockholders
$ 3.57 $ (0.13 )
 
Basic shares outstanding 148 117
Diluted shares outstanding 167 117
 

The following table reflects significant components of our weighted
average shares outstanding used in the basic and diluted loss per share
calculations for the three months ended March 31, 2017 and 2016:

 
  Three Months Ended March 31,
(in millions) 2017   2016
Shares outstanding at the beginning of the period (1) 140 117
Weighted-average shares outstanding during the period of:
Shares issued under the PIPE Transaction 8
Basic weighted-average shares outstanding 148 117
Dilution from potentially dilutive shares (2) 19
Diluted weighted-average shares outstanding 167 117
___________________________________
   
(1) The minimum settlement amount of the TEUs, or 23,092,460 shares, are
considered to be outstanding since the issuance date of June 21,
2016, and are included in the computation of basic earnings (loss)
per share for the three months ended March 31, 2017. No such amounts
were considered outstanding for the three months ended March 31,
2016.
(2) Shares included in the computation of diluted earnings (loss) per
share for the three months ended March 31, 2017 primarily consist of
approximately 5.4 million shares related to our TEUs and 12.9
million shares related to our mandatory convertible preferred stock.
 

Entities with a net loss from continuing operations are prohibited from
including potential common shares in the computation of diluted per
share amounts. Accordingly, we have utilized the basic shares
outstanding amount to calculate both basic and diluted loss per share
for the three months ended March 31, 2016.

DYNEGY INC.
OPERATING DATA

The following table provides summary financial data regarding our PJM,
NY/NE, ERCOT, MISO, IPH and CAISO segment results of operations for the
three months ended March 31, 2017 and 2016, respectively.

 
  Three Months Ended March 31,
  2017       2016  
PJM
Million Megawatt Hours Generated (1) 13.4 13.0
IMA (1)(2):
Combined Cycle Facilities 89 % 98 %
Coal-Fueled Facilities 65 % 77 %
Average Capacity Factor (1)(3):
Combined Cycle Facilities 68 % 83 %
Coal-Fueled Facilities 60 % 43 %
CDDs (4) 2 2
HDDs (4) 2,226 2,449
Average Market On-Peak Spark Spreads ($/MWh) (5):
PJM West $ 11.38 $ 18.73
AD Hub $ 12.63 $ 19.81
Average Market On-Peak Power Prices ($/MWh) (6):
PJM West $ 32.52 $ 31.49
AD Hub $ 31.39 $ 28.80
Average natural gas price—TetcoM3 ($/MMBtu) (7) $ 3.02 $ 1.82
 
NY/NE
Million Megawatt Hours Generated (1) 4.7 3.9
IMA for Combined Cycle Facilities (1)(2) 98 % 89 %
Average Capacity Factor for Combined Cycle Facilities (1)(3) 37 % 40 %
CDDs (4)
HDDs (4) 2,772 2,719
Average Market On-Peak Spark Spreads ($/MWh) (5):
New York—Zone A $ 10.99 $ 16.69
Mass Hub $ 6.63 $ 10.82
Average Market On-Peak Power Prices ($/MWh) (6):
Mass Hub $ 37.76 $ 33.85
Average natural gas price—Algonquin Citygates ($/MMBtu) (7) $ 4.45 $ 3.29
 
ERCOT
Million Megawatt Hours Generated (1) 0.6
IMA (1)(2):
Combined-Cycle Facilities 97 % %
Coal-Fueled Facility 93 % %
Average Capacity Factor (1)(3):
Combined-Cycle Facilities 9 % %
Coal-Fueled Facility 18 % %
CDDs (4) 267 120
HDDs (4) 494 758
Average Market On-Peak Spark Spreads ($/MWh) (5):
ERCOT North $ 4.11 $ 6.65
Average Market On-Peak Power Prices ($/MWh) (6):
ERCOT North $ 23.54 $ 19.62
Average natural gas price—Waha Hub ($/MMBtu) (7) $ 2.78 $ 1.85
 
MISO
Million Megawatt Hours Generated 2.7 3.3
IMA for Coal-Fueled Facilities (2) 89 % 89 %
Average Capacity Factor for Coal-Fueled Facilities (3) 65 % 50 %
CDDs (4) 57 28
HDDs (4) 2,203 2,424
Average Market On-Peak Power Prices ($/MWh) (6):
Indiana (Indy Hub) $ 32.65 $ 25.61
Commonwealth Edison (NI Hub) $ 30.27 $ 27.34
 
IPH
Million Megawatt Hours Generated 3.8 3.3
IMA for IPH Facilities (2) 86 % 86 %
Average Capacity Factor for IPH Facilities (3) 52 % 39 %
CDDs (4) 57 28
HDDs (4) 2,203 2,424
Average Market On-Peak Power Prices ($/MWh) ($/MWh) (6):
Indiana (Indy Hub) $ 32.65 $ 25.61
Commonwealth Edison (NI Hub) $ 30.27 $ 27.34
 
CAISO
Million Megawatt Hours Generated 0.3 0.7
IMA for Combined Cycle Facilities (2) 95 % 99 %
Average Capacity Factor for Combined Cycle Facilities (3) 14 % 29 %
CDDs (4) 25 44
HDDs (4) 717 594
Average Market On-Peak Spark Spreads ($/MWh) (5):
North of Path 15 (NP 15) $ 8.34 $ 10.71
Average natural gas price—PG&E Citygate ($/MMBtu) (7) $ 3.34 $ 2.20
___________________________________
   
(1) Adjusted EBITDA includes the activity of the assets acquired in the
ENGIE acquisition for our period of ownership. Million Megawatt
Hours Generated and Average Capacity Factor include such activity
for the full month of February. IMA includes such activity for March
only.
(2) 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. The
calculation excludes certain events outside of management control
such as weather related issues. The calculation excludes our Brayton
Point facility and CTs.
(3) Reflects actual production as a percentage of available capacity.
The calculation excludes our Brayton Point facility and CTs.
(4) Reflects CDDs or HDDs for the region based on NOAA data.
(5) Reflects the simple average of the on-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.
(6) Reflects the average of day-ahead settled prices for the periods
presented and does not necessarily reflect prices we realized.
(7) Reflects the average of daily quoted prices for the periods
presented and does not reflect costs incurred by us.
 

DYNEGY INC.
REG G RECONCILIATIONS - ADJUSTED EBITDA
THREE
MONTHS ENDED MARCH 31, 2017

(UNAUDITED) (IN MILLIONS)

The following table provides summary financial data regarding our
Adjusted EBITDA by segment for the three months ended March 31, 2017:

 
  Three Months Ended March 31, 2017
PJM   NY/NE   ERCOT   MISO   IPH   CAISO   Other   Total
Net income attributable to Dynegy Inc. $ 597
Plus / (Less):
Loss attributable to noncontrolling interest (1 )
Income tax benefit (313 )
Other income and expense, net (17 )
Interest expense 167
Loss from unconsolidated investments 1
Bankruptcy reorganization items (483 )
Operating income (loss) $ 86 $ (41 ) $ (28 ) $ 17 $ 18 $ (14 ) $ (87 ) $ (49 )
Depreciation and amortization expense 100 68 13 8 14 15 2 220
Bankruptcy reorganization items 498 (15 ) 483
Loss from unconsolidated investments (1 ) (1 )
Other income and expense, net         1     16   17  
EBITDA (1) 185 27 (15 ) 25 531 1 (84 ) 670
Plus / (Less):
Adjustments to reflect Adjusted EBITDA from unconsolidated
investment and exclude noncontrolling interest
1 1
Acquisition, integration costs and restructuring costs 46 46
Bankruptcy reorganization items (498 ) 15 (483 )
Mark-to-market adjustments, including warrants (15 ) 15 6 (15 ) (1 ) (4 ) (12 ) (26 )
Impairments 20 20
Non-cash compensation expense 5 5
Other         (1 )   (2 ) (3 )
Adjusted EBITDA (1)(2) $ 191   $ 42   $ (9 ) $ 10   $ 31   $ (3 ) $ (32 ) $ 230  
___________________________________
   
(1) EBITDA and Adjusted EBITDA are non-GAAP financial measures. Please
refer to Item 2.02 of our Form 8-K filed on May 4, 2017, for
definitions, utility and uses of such non-GAAP financial measures. A
reconciliation of EBITDA to Operating income (loss) is presented
above. Management does not allocate G&A, 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 to exclude Wood River's energy margin and O&M costs.
 

DYNEGY INC.
REG G RECONCILIATIONS - ADJUSTED EBITDA
THREE
MONTHS ENDED MARCH 31, 2016

(UNAUDITED) (IN MILLIONS)

The following table provides summary financial data regarding our
Adjusted EBITDA by segment for the three months ended March 31, 2016:

 
  Three Months Ended March 31, 2016
PJM   NY/NE   ERCOT   MISO   IPH   CAISO   Other   Total
Net loss attributable to Dynegy Inc. $ (10 )
Plus / (Less):
Income tax expense 16
Other income and expense, net (1 )
Interest expense 142
Earnings from unconsolidated investments (2 )
Operating income (loss) $ 177 $ (2 ) $ $ 13 $ 14 $ (14 ) $ (43 ) $ 145
Depreciation and amortization expense 83 75 9 10 12 1 190
Earnings from unconsolidated investments 2 2
Other income and expense, net             1   1  
EBITDA (1) 262 73 22 24 (2 ) (41 ) 338
Plus / (Less):
Adjustment to reflect Adjusted EBITDA from unconsolidated investment 3 3
Acquisition and integration costs 4 4
Mark-to-market adjustments, including warrants (56 ) (20 ) (28 ) (3 ) 2 (1 ) (106 )
Non-cash compensation expense 7 7
Other (2)       5         5  
Adjusted EBITDA (1) $ 209   $ 53   $   $ (1 ) $ 21   $   $ (31 ) $ 251  
___________________________________
   
(1) EBITDA and Adjusted EBITDA are non-GAAP financial measures. Please
refer to Item 2.02 of our Form 8-K filed on May 4, 2017, for
definitions, utility and uses of such non-GAAP financial measures. A
reconciliation of EBITDA to Operating income (loss) is presented
above. Management does not allocate G&A, interest expense and income
taxes on a segment level and therefore uses Operating income (loss)
as the most directly comparable GAAP measure.
(2) Other includes an adjustment to exclude Wood River's energy margin
and O&M costs of $5 million.
 

DYNEGY INC.
REG G RECONCILIATIONS - UPDATED 2017 GUIDANCE
(UNAUDITED)
(IN MILLIONS)

The following table provides summary financial data regarding our 2017
Adjusted EBITDA and Adjusted Free Cash Flow guidance:

   
Dynegy Consolidated
Low   High
Net income attributable to Dynegy Inc. (1) $ 455 $ 655
Plus / (Less):
Interest expense 655 660
Tax benefit (310 ) (320 )
Depreciation and amortization expense 815   835  
EBITDA (2) 1,615 1,830
Plus / (Less):
Acquisition, integration and restructuring costs 45 50
Bankruptcy reorganization items (480 ) (500 )
Impairments 20   20  
Adjusted EBITDA (2) $ 1,200 $ 1,400
Cash interest payments (600 ) (600 )
Acquisition, integration and restructuring costs (45 ) (50 )
Other cash items (80 ) (80 )
Cash Flow from Operations 475 670
Maintenance capital expenditures (210 ) (210 )
Environmental capital expenditures (10 ) (10 )
Acquisition, integration and restructuring costs 45   50  
Adjusted Free Cash Flow (2) $ 300   $ 500  
___________________________________
   
(1) For purposes of our 2017 guidance, fair value adjustments related to
derivatives and our common stock warrants are assumed to be zero.
(2) EBITDA, Adjusted EBITDA and Adjusted Free Cash Flow are non-GAAP
measures. Please refer to Item 2.02 of our Form 8-K filed on May 4,
2017, for definitions, utility and uses of such non-GAAP financial
measures.
 

DYNEGY INC.
REG G RECONCILIATIONS - ORIGINAL 2017 GUIDANCE
(UNAUDITED)
(IN MILLIONS)

The 2017 guidance was prepared using reasonable efforts and based on
currently available information assuming the following: (a) the Delta
transaction closed on February 7, 2017, (b) all of the purchase price is
allocated to property, plant and equipment, (c) property, plant and
equipment is depreciated over an average useful life of 20 years, and
(d) Genco restructuring completed on February 2, 2017.

The following table provides summary financial data regarding our 2017
Adjusted EBITDA and Adjusted Free Cash Flow guidance, updated based on
February 7, 2017 forward curves, as presented on February 23, 2017:

   
Dynegy Consolidated
Low   High
Net loss attributable to Dynegy Inc. (1) $ (265 ) $ (95 )
Plus / (Less):
Interest expense 660 665
Depreciation and amortization expense 765   785  
EBITDA (2) 1,160 1,355
Plus / (Less):
Acquisition, integration and restructuring costs 40   45  
Adjusted EBITDA (2) 1,200 1,400
Cash interest payments (625 ) (625 )
Acquisition, integration and restructuring costs (40 ) (45 )
Other cash items (35 ) (35 )
Cash Flow from Operations 500 695
Maintenance capital expenditures (370 ) (370 )
Environmental capital expenditures (20 ) (20 )
Acquisition, integration and restructuring costs 40   45  
Adjusted Free Cash Flow (2) $ 150   $ 350  
___________________________________
   
(1) For purposes of our 2017 guidance, fair value adjustments related to
derivatives and our common stock warrants are assumed to be zero.
(2)

EBITDA, Adjusted EBITDA and Adjusted Free Cash Flow are non-GAAP
measures. Please refer to Item 2.02 of our Form 8-K filed on May
4, 2017, for definitions, utility and uses of such non-GAAP
financial measures.

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