Combined Notes to Condensed Consolidated Financial Statements (Unaudited)
1
. Business and Basis of Presentation
Capitalized terms and abbreviations appearing in the unaudited combined notes to condensed consolidated financial statements are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted. As Talen Energy Corporation is substantially comprised of Talen Energy Supply, LLC and its subsidiaries, to avoid repetition, most disclosures refer to Talen Energy which indicates the disclosure applies to Talen Energy Corporation and Talen Energy Supply, LLC. This presentation has been applied where identification of particular subsidiaries is not material to the matter being disclosed, and to conform narrative disclosures to the presentation of financial information on a consolidated basis. When identification of a particular registrant or subsidiary is considered important to understanding the matter being disclosed, the specific entity's name is used, in particular, for those few disclosures that apply only to Talen Energy Corporation. Each disclosure referring to a subsidiary applies to both Talen Energy Corporation and Talen Energy Supply and each disclosure referring to Talen Energy Supply applies to Talen Energy Corporation through consolidation.
Business
Talen Energy Corporation, through its principal subsidiary Talen Energy Supply, is a North American competitive power generation and marketing company primarily engaged in the production and sale of electricity, capacity and ancillary products. Talen Energy is headquartered in Allentown, Pennsylvania and owns and operates a portfolio of generation assets principally located in the Northeast, Mid-Atlantic and Southwest regions of the U.S. See "Item 1. Business" in Talen Energy's
2015
Form 10-K for a discussion of Talen Energy's business, including the June 2015 spinoff from PPL and formation of Talen Energy Corporation.
In June 2016, Talen Energy Corporation announced the Merger with an affiliate of Riverstone Holdings LLC, a private investment firm, in which all outstanding shares of common stock not owned by Riverstone affiliated entities will be acquired, subject to certain exceptions. The transaction is expected to be completed by the end of 2016, subject to NRC approval and satisfaction of other customary closing conditions. Stockholder approval was received in October 2016. See Note
7
for additional information.
Spinoff from PPL
Following the June 2015 spinoff from PPL, certain services, including information technology, financial and accounting, human resource and other specified services are provided by PPL on a transition basis pursuant to the TSA. The TSA with PPL is for a period of up to
two
years from the date of the spinoff. For the
three and nine
months ended
September 30, 2016
, the costs incurred for these services were
$8 million
and
$30 million
. The costs incurred for these services during the
three and nine
months ended
September 30, 2015
were
$9 million
and
$14 million
.
In connection with the spinoff transaction in 2015, additional employee-related costs were incurred by Talen Energy, which primarily related to accelerated stock-based compensation and pro-rated performance-based cash incentive and stock-based compensation awards previously issued under PPL stock incentive programs, primarily for Talen Energy Supply employees and for PPL employees who became Talen Energy Supply employees in connection with the transaction. These costs were recognized at the closing of the spinoff. During the
nine
months ended
September 30, 2015
, Talen Energy Supply recorded
$25 million
related to these accelerated stock-based compensation and pro-rated stock-based compensation awards. The vesting for all Talen Energy Supply employees was accelerated and all remaining unrecognized compensation expense was accelerated concurrently with the spinoff. See Note 8 in Talen Energy's
2015
Form 10-K for additional information on stock-based compensation.
In addition, during the
nine
months ended
September 30, 2015
, Talen Energy incurred
$10 million
of restructuring costs related to the spinoff transaction which are recorded in "Operation and maintenance" on the Statements of Income.
Basis of Presentation
The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X and, therefore, do not include all of the information and footnotes required by GAAP for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation in accordance with GAAP are reflected in the condensed consolidated financial statements. All adjustments are of a normal recurring nature, except as otherwise disclosed. The Balance Sheets at
December 31, 2015
are derived from Talen Energy's
2015
audited Balance Sheet. The financial
statements and notes thereto should be read in conjunction with the financial statements and notes contained in Talen Energy's
2015
Form 10-K. The results of operations for the
three and nine
months ended
September 30, 2016
are not necessarily indicative of the results to be expected for the full year ending
December 31, 2016
or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations.
Talen Energy Supply is considered the accounting predecessor of Talen Energy Corporation. Therefore, the financial information prior to the June 2015 spinoff presented in this Quarterly Report on Form 10-Q for both registrants includes only legacy Talen Energy Supply information. From June 1, 2015, upon completion of the spinoff and acquisition, Talen Energy Corporation's and Talen Energy Supply's consolidated financial information also includes RJS. As such, Talen Energy Corporation's and Talen Energy Supply's consolidated financial information presented in this Quarterly Report on Form 10-Q for the 2015 periods represents
three and nine
months of legacy Talen Energy Supply information consolidated with three and four months of RJS information from June 1, 2015.
Talen Energy completed the acquisition of MACH Gen in November 2015. MACH Gen's operating results for the
three and nine
months ended
September 30, 2016
are included in Talen Energy's results of operations with no comparable amounts for the same periods in 2015.
The assets and liabilities related to the Holtwood, Lake Wallenpaupack, C.P. Crane and Ironwood facilities were classified as "Assets held for sale" and "Liabilities held for sale" at December 31, 2015. See Note
8
for additional information on these divestitures.
The sales of Talen Ironwood Holdings, LLC and C.P. Crane LLC were completed in February 2016 and the sale of the Holtwood and Lake Wallenpaupack hydroelectric facilities was completed in April 2016. The sales satisfied the requirement to divest certain PJM assets to comply with a December 2014 FERC order approving the combination with RJS Power.
The classification of certain prior period amounts has been changed to conform to the presentation in the
September 30, 2016
financial statements as discussed below.
In these financial statements, revenue and expense from derivatives is recorded based on Talen Energy's economic hedging strategy. For example, all purchases and sales associated with economic hedging of the sale of energy using contracts accounted for as derivatives are recorded within "Operating Revenues" and all purchases and sales associated with economic hedging of the procurement of fuel or purchasing energy using contracts accounted for as derivatives are recorded as "Operating Expenses" on the Statements of Income. Prior to the fourth quarter of 2015, Talen Energy classified all non-trading commodity hedge transactions as revenue or expense based upon whether each specific transaction was a sale or purchase, which in certain instances, created losses within revenue and gains within expense. As a result of this change in presentation to previously reported 2015 amounts, there were equal and offsetting changes between "Operating Revenues" and "Operating Expenses" with no impact on "Operating Income (Loss)" on the 2015 Statement of Income. This change in presentation resulted in a decrease of
$135 million
and
$115 million
for the
three and nine
months ended
September 30, 2015
in "Wholesale energy" and "Fuel and energy purchases" on the Statement of Income.
Also, presentation on the 2015 Statement of Income was modified to combine "Fuel" and "Energy purchases" in a single line item and to reclassify certain "Operating Expenses" to align the presentation of these operating expenses with how Talen Energy management views these costs. This change in presentation for certain operating expenses resulted in an increase of
$17 million
and
$50 million
for the
three and nine
months ended
September 30, 2015
to "Fuel and energy purchases" with offsetting decreases, primarily to "Taxes, other than income," but also to "Operation and maintenance" and "Energy-related businesses." This change had no impact on "Operating Income (Loss)" for the
three and nine
months ended
September 30, 2015
.
In addition, the operating results of the Sapphire plants for the
three and nine
months ended
September 30, 2015
were reclassified to continuing operations as a result of the November 2015 FERC order approving the third mitigation package relating to the transactions that formed Talen Energy. This change in presentation resulted in an increase for the
three and nine
months ended
September 30, 2015
of
$36 million
and
$44 million
to "Operating Revenues" and
$136 million
and
$143 million
to "Operating Expenses." This change decreased "Operating Income (Loss)" for the
three and nine
months ended
September 30, 2015
by
$62 million
and
$61 million
. See Note 1 in Talen Energy's
2015
Form 10-K for additional information on the initial classification as discontinued operations and the November 2015 FERC Order.
During the
three and nine
months ended
September 30, 2015
, Talen Energy recorded a
$7 million
decrease to "Retail energy" revenues on the Statements of Income. Prior to this date, Talen Energy billed and collected amounts from a third party that had a transmission operating agreement with Talen Energy's former affiliate, PPL Electric Utilities Corporation. Such amounts
should have been recognized as an affiliate payable, but were inadvertently recorded as revenue. The
$4 million
after-tax (
$0.04
per share for Talen Energy Corporation) impact of correcting this overstatement of "Retail energy" revenues decreased "Net Income (Loss)" during the
three and nine
months ended
September 30, 2015
. The impact of the overstatement was not material to the previously-issued financial statements and the correction was not material to the full year results for 2015.
2
. Summary of Significant Accounting Policies
The following accounting policy disclosure represents an update to Note 1 to the Financial Statements in Talen Energy's
2015
Form 10-K and should be read in conjunction with those disclosures.
New Accounting Guidance Adopted
Simplifying the Presentation of Debt Issuance Costs
Effective January 1, 2016, Talen Energy adopted accounting guidance that simplifies the presentation of debt issuance costs by requiring debt issuance costs to be presented on the balance sheet as a direct deduction from the carrying amount of the associated debt liability, consistent with the presentation of debt discounts. Because this guidance did not address the treatment of debt issuance costs related to line-of-credit arrangements, additional guidance was issued in August 2015 stating that an entity may defer and amortize debt issuance costs over the term of a line-of-credit arrangement, regardless of whether there are any related outstanding borrowings.
The initial adoption of this guidance required Talen Energy to reclassify long-term debt issuance costs on the Balance Sheet from assets to long-term debt. During the first quarter of 2016, Talen Energy retrospectively adopted this guidance. The December 31, 2015 Balance Sheet reflects a reclassification of
$17 million
between "Other noncurrent assets" and "Long-term debt" for the implementation. Issuance costs related to line-of-credit arrangements remain deferred as a long-term asset and amortized over the life of the arrangement.
Accounting for Cloud Computing Arrangements
Effective January 1, 2016, Talen Energy prospectively adopted guidance that clarifies how to determine if a cloud computing arrangement includes a software license. If a cloud computing arrangement contains a software license, the license should be accounted for in a manner consistent with the acquisition of other software licenses. If a cloud computing arrangement does not contain a software license, the arrangement should be accounted for as a service contract.
The initial adoption of this guidance did not have a significant impact on Talen Energy. Because Talen Energy may enter into cloud computing arrangements that fall within the scope of this guidance, this guidance may have an impact in future periods.
3
. Segment and Related Information
See Note 2 in Talen Energy's
2015
Form 10-K for a discussion of reportable segments and related information.
Financial data for the segments and reconciliation to consolidated results for the periods ended
September 30
are:
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Talen Energy Corporation - Income Statement Data
|
|
|
|
|
|
|
|
|
|
Revenues from external customers (a)
|
|
|
|
|
|
|
|
|
|
East
|
|
$
|
1,060
|
|
|
$
|
1,175
|
|
|
$
|
2,783
|
|
|
$
|
3,117
|
|
|
West
|
|
178
|
|
|
145
|
|
|
325
|
|
|
242
|
|
|
Total
|
|
$
|
1,238
|
|
|
$
|
1,320
|
|
|
$
|
3,108
|
|
|
$
|
3,359
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Income (Loss)
|
|
|
|
|
|
|
|
|
|
East
|
|
$
|
221
|
|
|
$
|
(345
|
)
|
|
$
|
765
|
|
|
$
|
33
|
|
|
West
|
|
16
|
|
|
39
|
|
|
(64
|
)
|
|
18
|
|
|
Other
|
|
(44
|
)
|
|
(40
|
)
|
|
(149
|
)
|
|
(184
|
)
|
|
Total
|
|
$
|
193
|
|
|
$
|
(346
|
)
|
|
$
|
552
|
|
|
$
|
(133
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Talen Energy Supply - Income Statement Data
|
|
|
|
|
|
|
|
|
|
Revenues from external customers (a)
|
|
|
|
|
|
|
|
|
|
East
|
|
$
|
1,060
|
|
|
$
|
1,175
|
|
|
$
|
2,783
|
|
|
$
|
3,117
|
|
|
West
|
|
178
|
|
|
145
|
|
|
325
|
|
|
242
|
|
|
Total
|
|
$
|
1,238
|
|
|
$
|
1,320
|
|
|
$
|
3,108
|
|
|
$
|
3,359
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Income (Loss)
|
|
|
|
|
|
|
|
|
|
East
|
|
$
|
221
|
|
|
$
|
(345
|
)
|
|
$
|
765
|
|
|
$
|
33
|
|
|
West
|
|
16
|
|
|
39
|
|
|
(64
|
)
|
|
18
|
|
|
Other
|
|
(42
|
)
|
|
(40
|
)
|
|
(136
|
)
|
|
(184
|
)
|
|
Total
|
|
$
|
195
|
|
|
$
|
(346
|
)
|
|
$
|
565
|
|
|
$
|
(133
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Talen Energy Corporation
|
|
Talen Energy Supply
|
|
Balance Sheet Data
|
|
September 30, 2016
|
|
December 31, 2015
|
|
September 30, 2016
|
|
December 31, 2015
|
|
Assets
|
|
|
|
|
|
|
|
|
|
East
|
|
$
|
9,741
|
|
|
$
|
11,430
|
|
|
$
|
9,741
|
|
|
$
|
11,430
|
|
|
West
|
|
1,299
|
|
|
1,231
|
|
|
1,299
|
|
|
1,231
|
|
|
Other (b)
|
|
1,389
|
|
|
148
|
|
|
1,398
|
|
|
148
|
|
|
Total Assets
|
|
$
|
12,429
|
|
|
$
|
12,809
|
|
|
$
|
12,438
|
|
|
$
|
12,809
|
|
|
|
|
|
(a)
|
Includes unrealized gains and losses from derivatives. See Note
14
for additional information.
|
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|
|
(b)
|
Primarily consists of unallocated items, including cash and PP&E.
|
4
. Earnings (Loss) Per Share for Talen Energy Corporation
On June 1, 2015, the spinoff date, Talen Energy Corporation issued
128,499,023
shares of common stock, including
83,524,365
shares issued to PPL's shareholders and
44,974,658
shares issued in a private placement to the Riverstone Holders. To calculate basic and diluted EPS for periods presented prior to June 1, 2015, Talen Energy Corporation used the shares issued to PPL's shareholders on the date of the spinoff as Talen Energy Corporation was a wholly owned subsidiary of PPL and no shares were outstanding prior to that date. The calculation of basic and diluted earnings per share for the
three and nine
months ended
September 30, 2015
utilized the weighted-average shares outstanding during this period assuming the shares issued to PPL's shareholders were outstanding during the entire period and reflects the impact of the private placement of shares to the Riverstone Holders on the spinoff date.
Basic EPS is computed by dividing income by the weighted-average number of common shares outstanding during the applicable period. Diluted EPS is computed by dividing income by the weighted-average number of common shares outstanding, increased by incremental shares that would be outstanding if potentially dilutive non-participating securities were converted to common shares as calculated using the Treasury Stock Method.
Reconciliations of the amounts of income and shares of Talen Energy Corporation common stock (in thousands) for the
periods
ended
September 30
used in the EPS calculation are:
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|
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|
|
Three Months
|
|
Nine Months
|
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|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Income (Numerator)
|
|
|
|
|
|
|
|
|
|
Net Income (Loss)
|
|
$
|
88
|
|
|
$
|
(401
|
)
|
|
$
|
236
|
|
|
$
|
(279
|
)
|
|
Shares of Common Stock (Denominator)
|
|
|
|
|
|
|
|
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|
Weighted-average shares - Basic EPS
|
|
128,527
|
|
|
128,509
|
|
|
128,527
|
|
|
103,627
|
|
|
Add incremental non-participating securities:
|
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|
|
|
|
|
|
|
Share-based payment awards
|
|
1,616
|
|
|
—
|
|
|
1,175
|
|
|
—
|
|
|
Weighted-average shares - Diluted EPS
|
|
130,143
|
|
|
128,509
|
|
|
129,702
|
|
|
103,627
|
|
Share-based payment awards of
985 thousand
shares were excluded from the computations of diluted EPS for the
three and nine
months ended
September 30, 2016
and
1,263 thousand
and
525 thousand
for the
three and nine
months ended
September 30, 2015
because the effect would have been antidilutive.
5
. Income Taxes
Selected information regarding the income tax provision for the
periods
ended
September 30
was as follows:
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|
|
|
|
|
Three Months
|
|
Nine Months
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Talen Energy Corporation
|
|
|
|
|
|
|
|
|
Income (Loss) Before Income Taxes
|
$
|
142
|
|
|
$
|
(400
|
)
|
|
$
|
393
|
|
|
$
|
(268
|
)
|
|
Income Taxes
|
$
|
54
|
|
|
$
|
1
|
|
|
$
|
157
|
|
|
$
|
11
|
|
|
Effective Tax Rate
|
38
|
%
|
|
—
|
%
|
|
40
|
%
|
|
(4
|
)%
|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Talen Energy Supply
|
|
|
|
|
|
|
|
|
Income (Loss) Before Income Taxes
|
$
|
144
|
|
|
$
|
(400
|
)
|
|
$
|
406
|
|
|
$
|
(268
|
)
|
|
Income Taxes
|
$
|
55
|
|
|
$
|
1
|
|
|
$
|
162
|
|
|
$
|
11
|
|
|
Effective Tax Rate
|
38
|
%
|
|
—
|
%
|
|
40
|
%
|
|
(4
|
)%
|
Talen Energy recorded income taxes during the
nine
month
periods
at an interim period annualized effective tax rate of
39.65%
in
2016
compared with
31.81%
in
2015
. However, Talen Energy's income tax expense reflected in the table above does not bear a customary relationship to income (loss) before income taxes primarily as a result of the impact of the recognition of an impairment of non-deductible goodwill, uncertain tax benefits, state deferred rate changes, tax return adjustments, tax credits and the impact of state and local income taxes.
In February 2015, PPL and the IRS Appeals division reached a tentative settlement on PPL's open audits for the years 1998 - 2011. The settlement was required to be reviewed and approved by the Joint Committee on Taxation (JCT) before considered final. In April 2015, PPL was notified that the JCT approved PPL's settlement. During the nine months ended September 30, 2015, Talen Energy recorded a tax benefit of
$12 million
for its portion of the settlement of previously unrecognized tax benefits.
Also in 2015, Talen Energy recorded a tax benefit of
$17 million
during the nine months ended
September 30,
related to its state deferred tax liabilities for changes in state apportionment and the impact on the future estimated state income tax rate as a result of the acquisition of RJS Power.
6
.
Financing Activities
Credit Arrangements and Short-term Debt
Talen Energy maintains credit arrangements to enhance liquidity and provide credit support. For reporting purposes, on a consolidated basis, the credit arrangements of Talen Energy Supply and its subsidiaries also apply to Talen Energy Corporation.
Revolving Credit Facilities
The following secured revolving credit facilities were in place at:
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September 30, 2016
|
|
December 31, 2015
|
|
|
Expiration
Date
|
|
Capacity
|
|
Borrowed
|
|
Letters of
Credit
Issued
|
|
Unused
Capacity
|
|
Borrowed
|
|
Letters of Credit Issued
|
|
Talen Energy Supply RCF (a)
|
June 2020
|
|
$
|
1,850
|
|
|
$
|
350
|
|
|
$
|
195
|
|
|
$
|
1,305
|
|
|
$
|
500
|
|
|
$
|
163
|
|
|
New MACH Gen RCF (b)
|
July 2021
|
|
160
|
|
|
105
|
|
|
32
|
|
|
23
|
|
|
108
|
|
|
31
|
|
|
Total Credit Facilities
|
|
|
$
|
2,010
|
|
|
$
|
455
|
|
|
$
|
227
|
|
|
$
|
1,328
|
|
|
$
|
608
|
|
|
$
|
194
|
|
|
|
|
|
(a)
|
The facility is syndicated and provides Talen Energy Supply the ability to make revolving cash borrowings and to request the lenders to issue up to
$925 million
of letters of credit, which in combination cannot exceed the capacity of the facility at any given time. The weighted average interest rate on outstanding borrowings was
2.77%
and
2.67%
at September 30, 2016 and December 31, 2015. The amounts borrowed are recorded as "Short-term debt" on the Balance Sheets. See Note 7 for information on expected changes to the facility capacity at the time of closing of the Merger.
|
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|
(b)
|
The facility provides New MACH Gen the ability to make revolving cash borrowings and to request the lenders to issue up to
$120 million
of letters of credit, which in combination cannot exceed the capacity of the facility at any given time. The weighted average interest rate on outstanding borrowings was
5.51%
and
5.04%
at September 30, 2016 and December 31, 2015. The amounts borrowed are recorded on the Balance Sheets as "Long-term debt" at September 30, 2016 and as "Short-term debt" at December 31, 2015. The classification as current at December 31, 2015 was based on Talen Energy's intent and ability to repay outstanding borrowings within the next year.
|
Other Facilities
Talen Energy Supply is party to a
$500 million
agreement expiring
June 2017
that provides Talen Energy Supply the ability to request up to
$500 million
of committed unsecured letter of credit capacity at fees to be agreed upon at the time of each request, based on certain market conditions. At
September 30, 2016
, Talen Energy Supply had
no
letters of credit issued under this agreement.
Talen Energy Supply is party to a
$1.3 billion
Amended STF Agreement that allows Talen Energy Supply to receive credit to satisfy collateral posting obligations related to Talen Energy's energy marketing and trading activities with counterparties participating in the facility. The facility became effective in December 2015 and has a
five
-year term ending December 2020 which automatically extends
one
-year on each anniversary of the effective date, subject to certain conditions. There were
$22 million
of secured obligations outstanding under this facility at
September 30, 2016
.
Long-term Debt
In December 2015, Talen Energy Supply announced an "exchange offer" for its
6.5%
Senior Unsecured Notes due 2025 that were issued in a private offering in May 2015. Pursuant to the terms of the notes, Talen Energy Supply offered to exchange all of the outstanding notes for a like principal amount of its
6.5%
Senior Notes due 2025 that were registered under the Securities Act of 1933, as amended. In January 2016, the exchange offer was completed with all of the notes exchanged.
In connection with the sale of Talen Ironwood Holdings, LLC, in January 2016, a Talen Ironwood Holdings, LLC subsidiary completed the redemption of
$41 million
of its
8.857%
Senior Secured Notes due 2025 prior to the closing of the sale transaction, which occurred in February 2016. The redemption included the payment of a make whole premium of
$14 million
, which is reflected in "(Gain) loss on sale" on the Statement of Income and "Cash from operating activities" on the Statement of Cash Flows for the nine months ended September 30, 2016. See Note
8
for additional information on the sale.
In May 2016,
$350 million
of Talen Energy Supply's
6.2%
Senior Unsecured Notes matured. Talen Energy Supply repaid the debt using short-term borrowings under the Talen Energy Supply RCF.
In June 2016, Parent and Merger Sub obtained a commitment letter from several lenders to provide Talen Energy Supply, on a several but not joint basis, a senior secured Term Loan B in an aggregate amount of up to
$1.1 billion
that would be issued substantially concurrently with the closing of the Merger (the Committed Financing).
$850 million
of the Committed Financing was to be utilized as a backstop facility in connection with the potential repurchase obligations of Talen Energy Supply resulting from the Merger. In August 2016, Parent and Merger Sub provided the lenders that are party to the commitment letter with notice of the expiration of all specified time periods during which a repurchase obligation may be triggered and, in accordance with the terms of the commitment letter, the Committed Financing was subsequently reduced to an aggregate amount of up to
$250 million
. The Committed Financing will only be utilized to the extent the Permanent Financing (as defined below) is not funded substantially concurrently with the closing of the Merger. If used, the Committed Financing would bear interest at a rate per annum of (i) LIBOR plus
5.75%
, with a
1.00%
LIBOR floor or (ii) a defined base rate plus
4.75%
, as elected by Talen Energy Supply, and would have a
seven
year maturity.
Additionally, Parent and Merger Sub entered into a separate "best efforts" financing arrangement with the lenders party to the June 2016 commitment letter to arrange a
$600 million
senior secured Term Loan B that will be funded substantially concurrently with the closing of the Merger (the Permanent Financing). The Permanent Financing was successfully priced and allocated in October 2016 and will be funded at
98.5%
of its face value, will bear interest at a rate per annum of (i) LIBOR plus
5.00%
, with a
1.00%
LIBOR floor or (ii) a defined base rate plus
4.00%
as elected by Talen Energy Supply, and will have a
seven
year maturity.
For both the Committed Financing and the Permanent Financing, the term loans contemplated thereby will be, to the extent funded, secured by the same collateral securing, and will be guaranteed by the same direct and indirect wholly owned subsidiaries of Talen Energy Supply that are guarantors of, the Talen Energy Supply RCF. See Note
7
for information on subsidiary guarantees of certain long-term debt in connection with the Merger.
The net proceeds of either financing arrangement are expected to be used to fund the payment of fees and expenses in connection with the term loan issuance and the Merger, for working capital needs and other general corporate purposes of Talen Energy. The net proceeds of the Permanent Financing
are also expected to be used to repay indebtedness under the Talen Energy Supply RCF.
In connection with the issuance of the Permanent Financing, Talen Energy will pay the lenders a customary fee that is calculated as a specified percentage of the
5.00%
LIBOR margin and based on the number of days after allocation of commitments and before closing of the Merger. The fee accrues beginning on the date that is
30
calendar days after the date of allocation of commitments under the Permanent Financing and is payable only if the Merger is consummated.
Either financing satisfies the provisions for a new debt issuance set forth in the Merger Agreement. The closing of either financing is subject to customary closing conditions and the closing of the Merger.
7
.
Merger Agreement
On June 2, 2016, Talen Energy Corporation entered into an Agreement and Plan of Merger (the Merger Agreement) with RPH Parent LLC, SPH Parent LLC, CRJ Parent LLC (each, an affiliate of Riverstone, and collectively referred to as "Parent"), and RJS Merger Sub Inc. (a wholly owned subsidiary of Parent referred to as "Merger Sub"), pursuant to which Merger Sub will merge with and into Talen Energy Corporation (the Merger), with Talen Energy Corporation continuing as the surviving corporation on the terms and conditions set forth in the Merger Agreement. On October 6, 2016, the stockholders of Talen Energy Corporation approved the Merger. Talen Energy Corporation currently expects the transaction to be completed by the end of 2016, subject to NRC approval and satisfaction of other customary closing conditions.
At the effective time of the Merger, each share of Talen Energy Corporation common stock outstanding immediately before the effective time of the Merger (excluding shares held by Parent, Merger Sub or certain affiliates of Riverstone and excluding shares pursuant to which dissenting rights under Delaware law have been properly exercised and not withdrawn or lost) will be automatically converted into the right to receive
$14.00
in cash, without interest (the Merger Consideration). In addition, affiliates of Riverstone will convert, at the Effective Time, their existing ownership of approximately
35%
of the issued and outstanding shares of Talen Energy Corporation common stock into shares of the surviving corporation.
The Merger Consideration will be funded by Talen Energy's cash on hand and the proceeds of a new senior secured term loan. The Talen Energy Supply RCF will be reduced from
$1.85 billion
to
$1.4 billion
upon closing of the transaction. See Note 6 for additional information on merger-related financing arrangements.
Consummation of the Merger is conditioned on Talen Energy Corporation's satisfaction or receipt of a waiver of certain requirements of the separation agreement entered into in connection with the spinoff of Talen Energy Corporation from PPL (and certain related transactions), generally requiring the delivery of an IRS ruling or a tax opinion from a tax expert to the effect that the Merger will not jeopardize the intended tax-free treatment of the spinoff and certain related transactions.
Consummation of the Merger is not subject to a financing condition, but is subject to a condition that Talen Energy Corporation has unrestricted cash and cash equivalents and undrawn revolver capacity equal to at least
$350 million
at closing, subject to certain exceptions, and after taking into account
the proceeds of the new senior secured term loan discussed above.
Consummation of the Merger is also subject to the condition that immediately prior to the closing, certain specified defaults and events of default under the Talen Energy Supply RCF shall not have occurred. The Merger Agreement contains certain termination rights, including the right of Talen Energy Corporation to terminate the Merger Agreement to accept a superior proposal, subject to specified limitations, and provides that, upon termination of the Merger Agreement by Talen Energy Corporation or Parent upon specified conditions, Talen Energy Corporation will be required to pay Parent a termination fee of
$50 million
. Upon termination of the Merger Agreement by Talen Energy Corporation or Parent under specified conditions, Parent will be required to pay Talen Energy Corporation a termination fee of
$85 million
.
The Merger Agreement permitted Talen Energy Corporation and its advisors to actively solicit and negotiate alternative acquisition proposals from third parties during a "go-shop" period that began on June 2, 2016 and expired on July 12, 2016. No alternative proposals were received that would constitute a superior proposal under the Merger Agreement. Talen Energy Corporation is now subject to customary "no shop" restrictions prohibiting Talen Energy Corporation, its subsidiaries, directors, officers, employees and other representatives from soliciting alternative proposals from third parties or providing information to or participating in any discussions or negotiations with third parties regarding alternative proposals. These non-solicitation provisions are subject to a "fiduciary out" provision that allows Talen Energy Corporation to provide non-public information and participate in discussions and negotiations with respect to certain unsolicited written acquisition proposals and upon payment of the termination fee to terminate the Merger Agreement and enter into an alternative acquisition agreement if the
Board of Directors determines in good faith after consultation with outside legal and financial advisors that such proposal constitutes a superior proposal under the terms of the Merger Agreement.
In connection with entering into the Merger Agreement, the Riverstone Holders entered into a support agreement pursuant to which such parties committed to vote their shares of Talen Energy Corporation common stock in favor of, and take certain other actions in furtherance of, the transactions contemplated by the Merger Agreement, including the Merger.
On June 2, 2016, the subsidiaries that guarantee the Talen Energy Supply RCF agreed to unconditionally guarantee, effective upon the closing of the Merger and the other transactions contemplated by the Merger Agreement, all of Talen Energy Supply's obligations with respect to its
6.5%
Senior Notes due
2025
and Exempt Facilities Revenue Refunding Bonds, Series 2009A, Series 2009B and Series 2009C.
Two
purported class actions lawsuits have been filed in the State of Delaware in connection with the proposed Merger. In October 2016, plaintiffs in these matters filed a consolidated putative class action complaint in the Court of Chancery of the State of Delaware. See Note
10
for additional information.
The Merger Agreement and the above summary of certain of its terms have been included to provide information regarding the terms of the Merger Agreement. Factual disclosures about Talen Energy Corporation contained in this report may supplement, update or modify the factual disclosures about Talen Energy Corporation contained in the Merger Agreement. The representations, warranties and covenants made in the Merger Agreement by Talen Energy Corporation, Parent and Merger Sub were qualified and subject to important limitations agreed to by Talen Energy Corporation, Parent and Merger Sub in connection with negotiating the terms of the Merger Agreement. The representations and warranties contained in the Merger Agreement were negotiated with the principal purposes of establishing the circumstances in which a party to the Merger Agreement may have the right not to close the Merger if the representations and warranties of the other party prove to be untrue due to a change in circumstance or otherwise, and allocating risk between the parties to the Merger Agreement, rather than establishing matters as facts. The representations and warranties may also be subject to a contractual standard of materiality different from those generally applicable to stockholders and reports and documents filed with the SEC. Moreover, information concerning the subject matter of the representations and warranties, which do not purport to be accurate as of the date of this report, (i) is contained, in part, on schedules to the Merger Agreement that have not been filed with the SEC in reliance upon applicable SEC regulations and (ii) may have changed since the date of the Merger Agreement and subsequent developments or new information qualifying a representation or warranty may or may not have been included in this report.
For further information on the Merger, the Merger Agreement, the consent agreement, the support agreement and other Merger-related agreements, please refer to the Current Report on Form 8-K filed on June 6, 2016 and the proxy statement filed on September 2, 2016 by Talen Energy Corporation. The foregoing descriptions of the Merger Agreement, the consent agreement and the support agreement are subject to, and qualified in their entirety by, the full text of those agreements as attached as exhibits to the Form 8-K filed on June 6, 2016, each of which is incorporated by reference herein.
During the
three and nine
months ended
September 30, 2016
, Talen Energy Corporation has recorded
an insignificant amount and
$15 million
of expenses related to the Merger, primarily for investment banking, legal and other professional services, and of which an insignificant amount was recorded at Talen Energy Supply for the
three and nine
months ended
September 30, 2016
. These expenses are reflected in "Operation and maintenance" on the Statement of Income. In addition, Talen Energy will record accelerated stock-based compensation expense at close, which is currently estimated to be approximately
$14 million
. For information on other expenses estimated to be incurred by Talen Energy, as well as legal, financing and other advisory fees estimated to be incurred by Merger Sub and/or Parent, in connection with the Merger and on executive compensation matters, see the proxy statement filed on September 2, 2016 by Talen Energy Corporation.
8
.
Acquisitions, Development and Divestitures
Talen Energy from time to time evaluates opportunities for potential acquisitions, divestitures and development projects. Development projects are periodically reexamined based on market conditions and other factors to determine whether to proceed with the projects, sell, cancel or expand them, execute tolling agreements or pursue other options. Any resulting transactions may impact future financial results.
Acquisitions
MACH Gen
See Note 6 in Talen Energy's
2015
Form 10-K for information on the November 2015 acquisition of the membership interests of MACH Gen. Various purchase accounting adjustments were made during the first and second quarters of 2016 that had an insignificant impact to PP&E and related deferred income taxes. The statement of income effect of these adjustments during the measurement period was also insignificant. The purchase price allocation is considered by Talen Energy's management to be final as of June 30, 2016.
RJS Power
Actual operating revenue and net income of RJS, since the June 1, 2015 acquisition, included in Talen Energy's results for the periods ended
September 30, 2015
were:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
|
|
Operating Revenues(a)
|
|
Net Income (Loss)(b)
|
|
Operating Revenues (a)
|
|
Net Income (Loss)(b)
|
|
|
|
$
|
273
|
|
|
$
|
(44
|
)
|
|
$
|
383
|
|
|
$
|
(30
|
)
|
|
|
|
|
(a)
|
Operating Revenues have been adjusted to present Sapphire within continuing operations. See Note
1
for additional information on the reclassification.
|
|
|
|
|
(b)
|
Net Income (loss) includes certain asset impairments and excludes the impact of a goodwill impairment recorded during the third quarter of 2015. See Notes
13
and
15
for information on the impairments.
|
Pro forma information for Talen Energy for the periods ended
September 30, 2015
as if the acquisition had occurred January 1, 2015, is as follows:
|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
|
|
Operating Revenues
|
|
Income (Loss) After Tax from Continuing Operations
|
|
Operating Revenues
|
|
Income (Loss) After Tax from Continuing Operations
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma
|
|
$
|
1,320
|
|
|
$
|
(406
|
)
|
|
$
|
3,698
|
|
|
$
|
(311
|
)
|
|
Basic and diluted earnings per share for Talen Energy Corporation
|
|
|
|
(3.16
|
)
|
|
|
|
(2.42
|
)
|
The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of results of operations that would have been achieved had the acquisition taken place on the date indicated, or the future consolidated results of operations of Talen Energy. The pro forma financial information presented above has been derived from the historical condensed consolidated financial statements of Talen Energy and from the historical consolidated and combined financial statements of RJS Power.
The pro forma financial information presented above includes adjustments for: (1) alignment of accounting policies, (2) incremental depreciation and amortization expense related to fair value adjustments to PP&E and identifiable intangible assets and liabilities, (3) incremental interest expense for outstanding borrowings to reflect the terms of the new syndicated credit facility, (4) nonrecurring items (discussed below), (5) the tax effect of the above adjustments, and (6) the issuance of Talen Energy Corporation common stock in connection with the spinoff from PPL and the acquisition of RJS Power. The pro forma financial information presented includes the impact of impairments recorded during the third quarter of 2015. See Notes
13
and 15 for information on the impairments.
Nonrecurring acquisition, integration and other costs of
$6 million
directly related to the acquisition were incurred during the nine months ended
September 30, 2015
, which are recorded in "Operation and maintenance" on the Statements of Income. Adjustments were made in the calculation of pro forma amounts to remove the effect of these nonrecurring items and related income taxes. The pro forma financial information does not include adjustments for potential future cost savings.
See Note 6 in Talen Energy's
2015
Form 10-K for additional information on the June 2015 acquisition of RJS Power.
Divestitures
Ironwood, C.P. Crane, Holtwood and Lake Wallenpaupack Power Plants
In February 2016, Talen Generation completed the sale of Talen Ironwood Holdings, LLC, which through its subsidiaries owned and operated the Ironwood natural gas combined-cycle plant in Pennsylvania, for
$657 million
. Talen Energy recorded a pre-tax gain, net of transaction costs including the make-whole premium on the debt as described in Note
6
, of
$148 million
for the
nine
months ended
September 30, 2016
, which is recorded to "(Gain) loss on sale" on the Statement of Income. Proceeds from the sale of Talen Ironwood Holdings, LLC were used to repay the majority of Talen Energy's then outstanding short-term debt. At December 31, 2015, Talen Ironwood Holdings, LLC was considered an individually significant component of Talen Energy whose pre-tax income (loss) for the
nine
months ended
September 30, 2016
was
$4 million
and for the
three and nine
months ended
September 30, 2015
was
$17 million
and
$50 million
. See Note
6
for additional information on the redemption of debt in connection with the sale.
In February 2016, Raven Power Marketing LLC, a wholly owned, indirect subsidiary of Talen Energy, completed the sale of C.P. Crane LLC, which owned and operated the C.P. Crane coal-fired power plant in Maryland. For the nine months ended
September 30, 2016
, Talen Energy recorded a
$6 million
pre-tax loss, which is recorded in "(Gain) loss on sale" on the Statement of Income.
In April 2016, Holtwood, LLC, a wholly owned, indirect subsidiary of Talen Energy, completed the sale of the Holtwood and Lake Wallenpaupack hydroelectric facilities in Pennsylvania for
$859 million
. Talen Energy recorded a pre-tax gain of
$421 million
in "(Gain) loss on sale" on the Statement of Income for the nine months ended
September 30, 2016
related to this sale.
The sales mentioned above satisfied the requirement to divest certain PJM assets to comply with a December 2014 FERC order approving the combination with RJS Power. See Note 1 in Talen Energy's
2015
Form 10-K for additional information.
Development
Bell Bend COLA
In 2008, a Talen Energy subsidiary, Bell Bend, LLC submitted a COLA to the NRC for the proposed Bell Bend nuclear generating unit (Bell Bend) to be built adjacent to the Susquehanna plant. Also in 2008, Bell Bend, LLC submitted an application for a federal loan guarantee for Bell Bend to the DOE.
The NRC safety review of the Bell Bend COLA was suspended in early 2014 due to a lack of progress by the reactor vendor with respect to its NRC design certification application, approval of which is a prerequisite to issuance of a combined license for Bell Bend. The vendor subsequently suspended the NRC review in early 2015, and has not announced when they plan to restart it. Accordingly, Talen Energy had supported the licensing process with a near term focus on obtaining the Final Environmental Impact Statement (FEIS). In April 2016, Talen Energy received notification from the NRC of the completion of its FEIS. Following receipt of the FEIS, during the second quarter of 2016, Talen Energy reassessed its alternatives with respect to Bell Bend and determined it will no longer pursue the development of the COLA. In making this decision, Talen Energy considered the following factors: forecasted energy and capacity prices; operating costs; lack of government incentives for new nuclear generation; continually rising nuclear plant construction costs; and the lack of progress by Talen Energy's current nuclear reactor vendor with respect to its NRC design certification process. Talen Energy concluded that these factors resulted in a triggering event requiring the COLA, a definite lived intangible asset, to be tested for impairment. Based on its evaluation, management determined that the amounts capitalized for the COLA are not recoverable.
Management used a market approach to estimate the fair value of the incomplete COLA, considering the highest and best use from a market participant perspective, and concluded that there was no value to another market participant given the factors management utilized in making the decision to no longer pursue the COLA and the lack of usefulness to a standalone market participant.
As a result, for the
nine
months ended
September 30, 2016
, Talen Energy recorded a pre-tax impairment charge of
$204 million
to the East segment that is reflected in "Impairments" on the 2016 Statement of Income. The impairment charge represents all of the COLA costs reflected on the Balance Sheet. At December 31, 2015,
$201 million
of costs, which included capitalized interest, associated with the licensing application were capitalized and were included on the Balance Sheets in noncurrent "Other intangibles." In September 2016, the NRC accepted Talen Energy's request to withdraw the COLA, and Talen Energy notified the DOE that it has withdrawn its application for a federal loan guarantee for Bell Bend.
Co-firing Projects
The Brunner Island Unit 3 co-fire project is currently in commercial operation and Unit 2 is expected to be in commercial operation by the end of 2016. In order to avoid an outage during the winter demand season, Talen Energy has decided to defer completion and commercial operation of Unit 1 from 2016 until the first half of 2017. The Brunner Island project previously was expected to be completed by the end of 2016. See Note 6 in Talen Energy's 2015 Form 10-K for additional information.
In June 2016, Talen Energy announced it plans to make modifications to its Montour coal-fired generating facility, which will enable it to co-fire using natural gas. The estimated capital expenditure for plant modifications is approximately
$70 million
. Talen Energy is currently further evaluating this project to consider the operating experience and results from the Brunner Island Unit 3 co-fire project, and at this time has no timetable for completing the Montour project. Costs incurred for the Montour project as of September 30, 2016 were insignificant.
9
.
Defined Benefits
The table below provides the components of net periodic defined benefit costs for Talen Energy pension plans for the periods ended
September 30
, for which the nine months of 2015 includes four months of costs under the new Talen Energy pension plan. The net periodic defined benefit costs for Talen Energy's other postretirement benefit plans for the
three and nine
months ended
September 30, 2016
and
2015
were insignificant.
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Pension Benefits
|
|
|
Three Months
|
|
Nine Months
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Service cost
|
$
|
10
|
|
|
$
|
12
|
|
|
$
|
31
|
|
|
$
|
19
|
|
|
Interest cost
|
19
|
|
|
18
|
|
|
57
|
|
|
28
|
|
|
Expected return on plan assets
|
(23
|
)
|
|
(23
|
)
|
|
(69
|
)
|
|
(37
|
)
|
|
Amortization of:
|
|
|
|
|
|
|
|
|
Actuarial (gain) loss
|
5
|
|
|
6
|
|
|
15
|
|
|
9
|
|
|
Net periodic defined benefit costs (credits)
|
$
|
11
|
|
|
$
|
13
|
|
|
$
|
34
|
|
|
$
|
19
|
|
For the nine months ended
September 30, 2015
, Talen Energy Supply was also allocated
$18 million
of costs of defined benefit plans sponsored by PPL Services based on Talen Energy Supply's participation in those plans prior to the spinoff, which management believes were reasonable at the time.
Separation Benefits
In 2016, Talen Energy identified approximately
85
management positions to be eliminated. As a result, Talen Energy recorded a charge of
$9 million
(
$5 million
after tax) for the
nine
months ended
September 30, 2016
to "Operation and maintenance" on the Statement of Income. The charges consisted primarily of benefits under Talen Energy's severance benefits plan. At
September 30, 2016
,
$4 million
is reflected in "Other current liabilities" on the Balance Sheet. Management continues to review its staffing levels to determine if additional eliminations are necessary.
In July 2016, Talen Energy gave notice to Local Union No. 1600 of the International Brotherhood of Electrical Workers (Local 1600) of its intent to eliminate approximately
130
bargaining unit positions at the Susquehanna, Montour, and Brunner Island plants and at Talen Energy's headquarters. Talen Energy and Local 1600 are in the process of finalizing the identification of impacted employees, some of whom may be eligible to receiv
e enhance
d pension and severance benefits in accordance with the terms of the collective bargaining agreement. F
or the
three and nine
months ended
September 30, 2016
, Talen Energy recorded an insignificant charge related to these eliminations to "Operation and maintenance" on the Statement of Income and "Other current liabilities" on the Balance Sheet. As the identification of employees is finalized, management expects to update its estimate in future periods.
10
.
Commitments and Contingencies
Energy Purchase Commitments
Talen Energy has entered into long-term purchase contracts to supply the coal requirements for its coal-fired generating facilities. These contracts include commitments to purchase coal through 2019. As a result of low market prices for natural gas, coal utilization has decreased. To mitigate the risk of oversupply, Talen Energy incurred pre-tax charges of
$41 million
during the three and nine months ended September 30, 2015 to reduce its contracted coal deliveries in 2015 through 2018. These charges were recorded to "Fuel and energy purchases" on the Statement of Income.
Legal Matters
Talen Energy is involved in the following legal proceedings, claims and litigation. Talen Energy believes that it has meritorious defenses in connection with its current legal proceedings, claims and litigation, and it intends to vigorously contest each of them. However, Talen Energy cannot provide assurance that it will be successful in its efforts.
No estimate of the possible loss or range of loss in excess of amounts accrued, if any, can be made at this time regarding any of the matters specifically described below because the inherently unpredictable nature of legal proceedings may be exacerbated by various factors such as ongoing discovery, significant facts that are in dispute, the stage of the proceeding and the wide range of potential outcomes for any such matter. As a result, any losses actually incurred could be substantial.
Sierra Club Litigation
In March 2013, the Sierra Club and MEIC filed a complaint in the U.S. District Court, District of Montana, Billings Division against Talen Montana and the other Colstrip Steam Electric Station (Colstrip) owners: Avista Corporation, Puget Sound Energy, Portland General Electric Company, NorthWestern Corporation and PacifiCorp. Talen Montana operates Colstrip on behalf of the owners. The complaint alleged certain violations of the Clean Air Act, including New Source Review, Title V and opacity requirements and listed
39
separate claims for relief. The complaint requested injunctive relief and civil penalties on average of
$36,000
per day per violation, including a request that the owners remediate environmental damage and that
$100,000
of the civil penalties be used for beneficial mitigation projects.
In July 2013, the Sierra Club and MEIC filed an additional Notice of Intent to Sue, identifying additional plant projects that are alleged not to be in compliance with the Clean Air Act and, in September 2013, filed an amended complaint. The amended complaint dropped all claims regarding pre-2001 plant projects, as well as the plaintiffs' Title V and opacity claims. It did, however, add claims with respect to a number of post-2000 plant projects, which effectively increased the number of projects subject to the litigation by about
40
. Talen Montana and the other Colstrip owners filed a motion to dismiss the amended complaint in October 2013. In May 2014, the court dismissed the plaintiffs' independent Best Available Control Technology claims and their Prevention of Significant Deterioration (PSD) claims for
three
projects, but denied the owners' motion to dismiss the plaintiffs' other PSD claims on statute of limitation grounds. In August 2014, the Sierra Club and MEIC filed a second amended complaint. This complaint includes the same causes of action articulated in the first amended complaint, but in regard to only
eight
projects done between 2001 and 2013. In September 2014, the Colstrip owners filed an answer to the second amended complaint. Discovery closed in the first quarter of 2015, and in April, the plaintiffs indicated they intend to pursue claims related to only
four
of the remaining projects. The magistrate judge entered an order on the parties' motions for summary judgment on December 31, 2015. The judgment dismissed
two
of the plaintiffs'
four
remaining claims and provided more preferable legal standards for the remaining
two
claims. The case has been bifurcated as to liability and remedy. The liability trial initially was set for May 2016 and the remedy trial, in the case of any finding of liability, was to be set at a later date. However, based on a joint motion filed by the parties, the liability trial date was stayed to allow settlement discussions to proceed. In July 2016, a settlement agreement was reached that includes a commitment by the defendants to cease operations of Colstrip Units 1 and 2 on or before July 1, 2022 and liability releases for the owners of all Colstrip units, without requiring monetary payments to the plaintiffs. Apart from outright dismissal of all claims against Colstrip Units 3 and 4, those units are not affected by the proposed settlement. The settlement agreement was approved by the U.S. District Court, District of Montana, Billings Division, in September 2016. As result of the court approval, in the third quarter of 2016, management reduced the remaining useful life of Colstrip Units 1 and 2, adjusted associated AROs and assessed the Colstrip plant assets for impairment. The change in useful life resulted in an insignificant increase to depreciation for the three and nine months ended September 30, 2016 and is expected to have a similar impact on calendar year 2016. In future periods, the change in the useful life is expected to increase depreciation for the units by
$6 million
annually. The change to the AROs was insignificant. Also in the third quarter of 2016, management completed an impairment assessment of the Colstrip plant assets and concluded that no impairment was necessary. At
September 30, 2016
, the carrying value of Talen Montana's interest in the Colstrip plant was approximately
$91 million
.
Notice of Intent to File Suit
In October 2014, Talen Energy received a notice letter from the Chesapeake Bay Foundation (CBF) alleging violations of the Clean Water Act and Pennsylvania Clean Streams Law at the Brunner Island generation plant. The letter was sent to Brunner Island, LLC and the PADEP and was intended to provide notice of the alleged violations and CBF's intent to file suit in Federal court after expiration of the 60 day statutory notice period. Among other things, the letter alleged that Brunner Island, LLC
failed to comply with the terms of its National Pollutant Discharge Elimination System permit and associated regulations related to the application of nutrient credits to the facility's discharges of nitrogen into the Susquehanna River. The letter also alleged that PADEP failed to ensure that credits generated from nonpoint source pollution reduction activities that Brunner Island, LLC applies to its discharges meet the eligibility and certification requirements under PADEP's nutrient trading program regulations. In July 2016, the CBF withdrew its notice of alleged violations and intent to file suit.
Montana Regional Haze
In September 2012, the EPA Region 8 developed a regional haze Federal Implementation Plan (FIP) for Montana. The final FIP assumed no additional controls for Corette or Colstrip Units 3 and 4 but proposed stricter limits for Corette and Colstrip Units 1 and 2. Talen Montana was meeting these stricter permit limits at Corette without any significant changes to operations, although other requirements led to the suspension of operations and retirement of Corette in March 2015. The stricter limits at Colstrip Units 1 and 2 would require additional controls to meet more stringent nitrogen oxides and sulfur dioxide limits, the cost of which could be significant. Both Talen Montana and environmental groups appealed the final FIP to the U.S. Court of Appeals for the Ninth Circuit where oral argument was heard in May 2014. On June 9, 2015, the Ninth Circuit issued a decision that vacated as arbitrary and capricious the portions of the FIP setting stricter emissions limits for Colstrip Units 1 and 2 and Corette. The Ninth Circuit upheld the EPA's decision not to require further emissions reductions at Colstrip Units 3 and 4. The Ninth Circuit opinion requires the EPA to now reissue a FIP that is consistent with the opinion.
Colstrip Wastewater Facility Administrative Order on Consent
Talen Montana is party to an Administrative Order on Consent (AOC) with the MDEQ related to operation of the wastewater facilities at the Colstrip power plant. In September 2012, Earthjustice, on behalf of Sierra Club, MEIC, and the National Wildlife Federation, filed an affidavit under Montana's Major Facility Siting Act (MFSA) that sought review of the AOC by Montana's Board of Environmental Review. Talen Montana elected to have this proceeding conducted in Montana state district court, and in October 2012, Earthjustice filed a petition for review in Montana state district court in Rosebud County. This matter was stayed in December 2012 pending the outcome of separate litigation where the same environmental groups challenged the AOC in a writ of mandamus. That litigation was resolved in May 2013 when defendants Talen Montana and MDEQ won their motions to dismiss the matter, and the environmental groups did not appeal. In April 2014, Earthjustice filed successful motions for leave to amend the petition for review and to lift the stay. Talen Montana and the MDEQ responded to the amended petition and filed partial motions to dismiss in July 2014, which were denied in October 2014. Trial was set for April 2016. However, based on a motion filed by the parties, the trial date was vacated to allow settlement discussions to proceed. In July 2016, Talen Montana and the other Colstrip owners entered into a settlement agreement that was filed with the court. Under the terms of the settlement, the Colstrip owners will convert to a "non-liquid" disposal system for CCR generated by the Unit 3 and 4 scrubbers no later than July 1, 2022. In exchange, the environmental groups agree to release the Colstrip owners from certain claims related to operation of the CCR Units and alleged groundwater contamination. This settlement is not expected to have a material adverse effect on Talen Energy's financial condition or results of operations.
Montana Hydroelectric Litigation
In February 2012, the U.S. Supreme Court issued a unanimous decision overturning judgments by the Montana First Judicial District Court and the Montana Supreme Court in pending litigation, which had held that the streambeds underlying the Talen Montana hydroelectric generating facilities were owned by the State of Montana and that Talen Montana owed the State of Montana compensation for its prior use of those streambeds. The case was remanded by the U.S. Supreme Court to the Montana Supreme Court for further proceedings in accordance with the decision and, in April 2012, was similarly remanded by the Montana Supreme Court to the Montana First Judicial District Court. In the interim, nothing further was done by the State of Montana to formally prosecute the action until April 2016, when the State filed a Complaint on Remand against Talen Montana and NorthWestern Corporation, the latter of which had purchased the facilities from Talen Montana in November 2014. The allegations of the complaint are very similar to the claims made by the State in the prior state court litigation. NorthWestern Corporation has since removed the case to the Federal District Court in Montana and motions have been filed to dismiss certain of the claims. The State opposed removal and filed a motion to remand the case to the First Judicial District Court. Further proceedings have not been scheduled by the federal court and, as a result, Talen Energy cannot estimate a range of reasonably possible losses, if any, related to this matter.
Topaz Power Holdings, LLC (Topaz) Gas Supply Litigation
In November 2014, Southwest Energy, L.P. (SWE) filed a petition alleging breach of contract against Topaz, a wholly owned indirect subsidiary of Talen Energy, in the 269
th
Judicial District Court, Harris County, Texas. SWE and Topaz were parties to a natural gas supply contract that was terminated in October 2014. SWE seeks damages in the approximate amount of
$7 million
for Topaz's alleged failure to terminate the contract in accordance with its terms. SWE subsequently amended the petition to join additional parties, including other Talen Energy affiliates, and assert additional claims relating to the contract termination and the circumstances under which Topaz obtained an alternative natural gas supply for 2015. In April 2016, the court granted SWE's motion for partial summary judgment on the breach of contract claim, holding that the contract had not been properly terminated and as a result, Talen Energy recorded an insignificant charge to "Operation and maintenance" on the Statement of Income for the
nine
months ended
September 30, 2016
. Further proceedings are required to determine SWE's damages on the breach of contract claim and Talen Energy's liability and damages, if any, on SWE's other claims in the litigation. Talen Energy continues to believe that all of SWE's claims are without merit and unsupported by the facts and law, and it intends to vigorously contest each of them.
Litigation Relating to the Merger
In August 2016, a purported stockholder of Talen Energy Corporation commenced a putative class action lawsuit in the Court of Chancery of the State of Delaware captioned Manuel Abt, individually and on behalf of all others similarly situated. The complaint named as defendants Talen Energy Corporation, the directors of Talen Energy Corporation and Riverstone and certain of its affiliates.
Also in August 2016,
two
purported stockholders of Talen Energy Corporation commenced a separate putative class action lawsuit in the Court of Chancery of the State of Delaware captioned Wendell R. Hunt and Kenneth J. Melchiorre, individually and on behalf of all others similarly situated. The complaint named as defendants Talen Energy Corporation, the directors of Talen Energy Corporation and Riverstone and certain of its affiliates.
In October 2016, the plaintiffs in the above-referenced matters filed a consolidated putative class action complaint in the Court of Chancery of the State of Delaware alleging, among other things, that (i) the directors of Talen Energy Corporation breached fiduciary duties owed to Talen Energy Corporation's public stockholders in approving the Merger, (ii) Riverstone and certain of its affiliates have aided and abetted the directors of Talen Energy Corporation in the alleged breaches of their fiduciary duties, and (iii) Riverstone, as a de facto controlling stockholder of Talen Energy Corporation, breached fiduciary duties that it owed Talen Energy Corporation and its minority stockholders in the Merger. The consolidated complaint seeks to rescind the Merger and also seeks damages, costs and attorney's fees. Talen Energy believes the allegations are without merit and intends to defend vigorously against the allegations. At this time Talen Energy cannot predict the outcome of these matters or their effects on Talen Energy or the Merger, however a material adverse judgment for monetary damages could have an adverse effect on the results of operations and liquidity of Talen Energy.
Other
In addition to the above matters, from time-to-time in the ordinary course of its business Talen Energy may be subject to other legal proceedings, claims and litigation. While the outcome of these legal proceedings, claims and litigation is uncertain, the likely results are not expected, either individually or in the aggregate, to have a material adverse effect on Talen Energy's financial condition or results of operations, although the effect could be material to Talen Energy's results of operations in any interim reporting period.
Regulatory Matters
Talen Energy is subject to regulation by federal and state agencies in the various regions where it conducts business, including with respect to the following matters.
New Jersey Capacity Legislation
In January 2011, New Jersey enacted a law (the Act) that Talen Energy believes would intervene in the wholesale capacity market to create incentives for the development of new, in-state electricity generation facilities even when, under the FERC- approved PJM economic model, such new generation would not be economic. The Act could have the effect of depressing capacity prices in PJM in the short term, which could impact Talen Energy's revenues, and also could harm the long-term ability of the PJM capacity market to encourage necessary generation investment throughout PJM.
In February 2011, certain Talen Energy subsidiaries and several other companies filed a complaint in U.S. District Court in New Jersey challenging the Act on the grounds that it violates the Supremacy and Commerce clauses of the U.S. Constitution and requesting relief barring implementation. In October 2013, the U.S. District Court in New Jersey issued a decision finding the Act unconstitutional under the Supremacy Clause on the grounds that it infringes upon the FERC's exclusive authority to
regulate the wholesale sale of electricity in interstate commerce. The decision was appealed to the U.S. Court of Appeals for the Third Circuit (Third Circuit) by CPV Power Development, Inc., Hess Newark, LLC and the State of New Jersey (the Appellants). In September 2014, the Third Circuit affirmed the District Court's decision. In December 2014, the Appellants filed a petition for certiorari
before the U.S. Supreme Court. In March 2015, the U.S. Supreme Court requested the U.S. Solicitor General to submit briefs expressing its views as to the issues raised in this case. In September 2015, the U.S. Solicitor General filed a brief expressing the view of the United States that the case was rightly decided and that the petition for certiorari should be denied. In April 2016, in light of the decision in the Maryland case described below, the U.S. Supreme Court denied all petitions for certiorari, allowing the Third Circuit's decision to become final.
Maryland Capacity Order
In April 2012, the Maryland Public Service Commission (MD PSC) ordered (the Order)
three
electric utilities in Maryland to enter into long-term contracts to support the construction of new electricity generating facilities in Maryland, the intent of which, Talen Energy believed, was to encourage the construction of new generation even when, under the FERC-approved PJM economic model, such new generation would not be economic. The MD PSC action could have the effect of depressing capacity prices in PJM in the short term, which could impact Talen Energy's revenues, and also could harm the long-term ability of the PJM capacity market to encourage necessary generation investment throughout PJM.
In April 2012, Talen Energy subsidiaries and several other companies filed a complaint in U.S. District Court (District Court) in Maryland challenging the Order on the grounds that it violates the Supremacy and Commerce clauses of the U.S. Constitution, and requested declaratory and injunctive relief barring implementation of the Order by the MD PSC Commissioners. In September 2013, the District Court issued a decision finding the order unconstitutional under the Supremacy Clause on the grounds that it infringes upon the FERC's exclusive authority to regulate the wholesale sale of electricity in interstate commerce. The decision was appealed to the U.S. Court of Appeals for the Fourth Circuit (Fourth Circuit) by CPV Power Development, Inc. and the State of Maryland (Appellants). In June 2014, the Fourth Circuit affirmed the District Court's opinion and subsequently denied the Appellants' motion for rehearing. In December 2014, the Appellants filed a petition for certiorari before the U.S. Supreme Court. In March 2015, the U.S. Supreme Court requested the U.S. Solicitor General to submit briefs expressing its views as to the issues raised in this case. In September 2015, the U.S. Solicitor General filed a brief expressing the view of the United States that the case was rightly decided and that the petition for certiorari should be denied. In October 2015, the U.S. Supreme Court granted certiorari of the case. In April 2016, the U.S. Supreme Court issued a unanimous decision affirming the Fourth Circuit's decision and finding that Maryland's program is preempted by the Federal Power Act because it sets an interstate wholesale rate, contravening the Federal Power Act's division of authority between state and federal regulators.
Pacific Northwest Markets
Talen Energy Marketing and Talen Montana made spot market bilateral sales of power in the Pacific Northwest during the period from December 2000 through June 2001. Several parties subsequently claimed refunds at the FERC as a result of these sales. In June 2003, the FERC terminated proceedings to consider whether to order refunds for spot market bilateral sales made in the Pacific Northwest, including sales made by Talen Montana, during the period December 2000 through June 2001. In August 2007, the U.S. Court of Appeals for the Ninth Circuit reversed the FERC's decision and ordered the FERC to consider additional evidence. In October 2011, the FERC initiated proceedings to consider additional evidence. In December 2015, the United States Court of Appeals for the Ninth Circuit affirmed the FERC's October 2011 order setting out the remand process that the FERC has followed from 2011 to the present.
In July 2012, Talen Montana and the City of Tacoma,
one
of the
two
parties claiming refunds at the FERC, reached a settlement whereby Talen Montana paid
$75 thousand
to resolve the City of Tacoma's
$23 million
claim. The settlement does not resolve the remaining claim outstanding by the City of Seattle for approximately
$50 million
. Hearings before a FERC Administrative Law Judge (ALJ) regarding the City of Seattle's refund claims were completed in October 2013 and briefing was completed in January 2014. In March 2014, the ALJ issued an initial decision denying the City of Seattle's complaint against Talen Montana. In May 2015, the FERC issued an order affirming the ALJ's March 2014 decision, and in January 2016 the FERC denied requests for a rehearing of its order affirming the ALJ's decision. In February 2016, the City of Seattle appealed the FERC's decision to the United States Court of Appeals for the Ninth Circuit.
In October 2016, Talen Montana and the City of Seattle reached a settlement whereby Talen Montana agreed to pay
$15 thousand
to resolve the remaining outstanding claims. The settlement was approved by the court in November 2016.
Electricity - Reliability Standards
The NERC is responsible for establishing and enforcing reliability standards (Reliability Standards) regarding the bulk power system. The FERC oversees this process and independently enforces the Reliability Standards.
The Reliability Standards have the force and effect of law and apply to certain users of the bulk power electricity system, including electric utility companies, generators and marketers. Under the Federal Power Act, the FERC may assess civil penalties of up to
$1 million
per day, per violation, for certain violations.
Talen Energy monitors its subsidiaries' compliance with the Reliability Standards and self-reports potential violations of certain applicable reliability requirements and submits accompanying mitigation plans, as required. The resolution of a number of potential violations is pending.
In the course of implementing their programs to ensure compliance with the Reliability Standards by those Talen Energy subsidiaries subject to the standards, certain other instances of potential non-compliance may be identified from time to time. Talen Energy cannot predict the outcome of these matters and cannot estimate a range of reasonably possible losses, if any.
Other
In addition to the regulatory matters discussed above, Talen Energy and its subsidiaries are party to other regulatory proceedings arising in the ordinary course of business or have other regulatory exposure. While the outcome of these other regulatory matters and proceedings is uncertain, the likely results are not expected, either individually or in the aggregate, to have a material adverse effect on Talen Energy's financial condition or results of operations, although the effect could be material to Talen Energy's results of operations in any interim reporting period.
Environmental Matters
Environmental Laws and Regulations
Extensive federal, state and local environmental laws and regulations are applicable to Talen Energy's power generation operations, including air emissions, water discharges and the management of hazardous and solid waste, as well as other aspects of its business. In addition, many of these environmental considerations are also applicable to the operations of key suppliers, or customers, such as coal producers and industrial power users, and may impact the cost for their products or their demand for Talen Energy's services.
It may be necessary for Talen Energy to modify, curtail, replace or cease operation of certain facilities or performance of certain operations to comply with statutes, regulations and other requirements imposed by regulatory bodies, courts or environmental groups. Talen Energy may incur costs to comply with environmental laws and regulations, including increased capital expenditures or operation and maintenance expenses, monetary fines, penalties or other restrictions, which could be material. Legal challenges to environmental permits or rules add to the uncertainty of estimating the future cost of complying with these permits and rules. In addition, costs may increase significantly if the requirements or scope of environmental laws or regulations, or similar rules, are expanded or changed.
Other
From time-to-time, in the ordinary course of its business, Talen Energy may become involved in other environmental matters or become subject to other environmental statutes, regulations or requirements. In the opinion of management, based upon information currently available to Talen Energy, while the outcome of these other environmental matters and proceedings is uncertain, the likely results are not expected, either individually or in the aggregate, to have a material adverse effect on Talen Energy's financial condition or results of operations, although the effect could be material to Talen Energy's results of operations in any interim reporting period.
Other Commitments and Contingencies
Nuclear Insurance
The Price-Anderson Act is a United States Federal law which governs liability-related issues and ensures the availability of funds for public liability claims arising from an incident at any of the U.S. licensed nuclear facilities. It also seeks to limit the
liability of nuclear reactor owners for such claims from any single incident. At
September 30, 2016
, the liability limit per incident is
$13.4 billion
for such claims, which is funded by insurance coverage from American Nuclear Insurers and an industry retroactive assessment program.
Under the industry retroactive assessment program, in the event of a nuclear incident at any of the reactors covered by the Price-Anderson Act, as amended, Susquehanna Nuclear could be assessed deferred premiums of up to
$255 million
per incident, payable at a maximum of
$38 million
per year.
Additionally, Susquehanna Nuclear purchases property insurance programs from NEIL, an industry mutual insurance company of which Susquehanna Nuclear is a member. At
September 30, 2016
, facilities at the Susquehanna plant are insured against property damage losses up to
$2.0 billion
. Susquehanna Nuclear also purchases an insurance program that provides coverage for the cost of replacement power during prolonged outages of nuclear units caused by certain specified conditions.
Under the NEIL property and replacement power insurance programs, Susquehanna Nuclear could be assessed retrospective premiums in the event of the insurers' adverse loss experience. This maximum assessment is
$61 million
at
September 30, 2016
. Talen Energy has additional coverage that, under certain conditions, may reduce this exposure.
Guarantees and Other Assurances
In the normal course of business, Talen Energy enters into agreements that provide financial performance assurance to third parties on behalf of certain subsidiaries. Such agreements include, for example, guarantees, stand-by letters of credit issued by financial institutions and surety bonds issued by insurance companies. These agreements are entered into primarily to support or enhance the creditworthiness attributed to a subsidiary on a stand-alone basis or to facilitate the commercial activities in which these subsidiaries engage.
The table below details guarantees provided as of
September 30, 2016
. "Exposure" represents the estimated maximum potential amount of future payments that could be required to be made under the guarantee. The probability of expected payment/performance for the guarantees described below is remote. There was
no
recorded liability at
September 30, 2016
or
December 31, 2015
.
Talen Energy Supply has indemnifications related to sales of assets that are governed by the specific sales agreement and include breach of the representations, warranties and covenants, and liabilities for certain other matters. Talen Energy's maximum exposure with respect to certain indemnifications and the expiration of the indemnifications cannot be estimated because the maximum potential liability is not always capped by the transaction documents and the expiration date is based on the applicable statute of limitations. The exposure and expiration date noted is based on those cases in which the agreements provide for specific limits. Talen Energy's exposure and related expiration dates are:
|
|
|
|
|
|
|
|
|
|
|
|
Exposure at
September 30, 2016
|
|
Expiration
Date
|
|
Indemnifications for sales of assets
|
$
|
2,796
|
|
|
|
2025 - 2036
|
In connection with the acquisition of RJS Power and the spinoff from PPL, Talen Energy Supply agreed to indemnify PPL and its affiliates following the spinoff for liabilities primarily relating to the Talen Energy Supply business prior to the spinoff, as well as for losses arising out of breaches of Talen Energy's failure to perform covenants and agreements in the transaction agreements following the spinoff or arising out of breaches by the Riverstone Holders of certain representations and warranties in the transaction agreements. Talen Energy Supply also agreed to indemnify PPL for liabilities relating to the employment or termination of service of PPL employees who primarily supported the Talen Energy Supply business prior to the spinoff (excluding however defined benefit pension obligations of PPL employees who terminated service prior to July 1, 2000 or who were not employed by Talen Energy Supply or its subsidiaries at the time of termination). Talen Energy Supply also agreed to indemnify PPL from tax liabilities resulting from actions by Talen Energy following the closing resulting in the transaction failing to qualify for its intended tax-free treatment.
Talen Energy and/or its subsidiaries provide other miscellaneous guarantees through contracts entered into in the normal course of business. These guarantees are primarily in the form of indemnification or warranties related to services or equipment and vary in duration. The amounts of these guarantees often are not explicitly stated, and the overall maximum amount of the obligation under such guarantees cannot be reasonably estimated. Historically, no significant payments have been made with respect to these types of guarantees and the probability of payment/performance under these guarantees is remote.
Talen Energy, on behalf of itself and certain of its subsidiaries, maintains insurance that may cover liability assumed under contract for bodily injury and property damage. The coverage provides maximum aggregate coverage of
$100 million
. This insurance may be applicable to obligations under certain of these contractual arrangements.
11
. Related Party Transactions
Prior to the spinoff, PPL Services was an affiliate of Talen Energy. The disclosures below, related to PPL Services, provide information regarding transactions that occurred prior to June 1, 2015. After June 1, 2015, transactions with PPL Services, or any other PPL subsidiaries are not related party transactions.
Support Costs
Prior to the spinoff, Talen Energy was provided with administrative, management and support services, primarily from PPL Services. Where applicable, the costs of these services were charged to Talen Energy Supply as direct support costs. General costs that could not be directly attributed to a specific affiliate were allocated and charged to the respective affiliates, including Talen Energy Supply, as indirect support costs. PPL Services used a three-factor methodology that includes the affiliates invested capital, operation and maintenance expenses and number of employees to allocate indirect costs, which methodology Talen Energy believes was reasonable.
Talen Energy Supply was charged, primarily by PPL Services,
$67 million
for the nine months ended
September 30,
2015, including amounts applied to accounts that are further distributed between capital and expense.
Transition Services Agreement
As part of the spinoff transaction, Talen Energy Supply entered into a TSA with Topaz Power Management, LP (an affiliate of Riverstone) for certain business administrative services. The TSA expired in January 2016. For the nine months ended September 30, 2016 these costs, which are recorded in "Operation and maintenance" on the Statement of Income, were insignificant. For the three and nine months ended
September 30,
2015 these costs were
$4 million
and
$5 million
.
Gas Supply Contract
A subsidiary of Jade has gas supply contracts in place with TrailStone NA Logistics LLC (TrailStone), an affiliate of Riverstone, under which TrailStone supplies gas to the generation facilities owned by Jade. For the periods ended
September 30,
Talen Energy incurred the costs reflected below for these gas purchases, which are primarily recorded in "Fuel and energy purchases" on the Statement of Income.
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
|
|
$
|
22
|
|
|
$
|
26
|
|
|
$
|
43
|
|
|
$
|
32
|
|
Other
See Notes
5
and
9
for information regarding intercompany allocations prior to the spinoff associated with income taxes and defined benefits.
12
. Other Income (Expense) - net
Talen Energy's "Other Income (Expense) - net" for the
three and nine
months ended
September 30, 2016
and
2015
was primarily earnings on securities in NDT funds.
13
.
Fair Value Measurements and Credit Concentration
Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price). A market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models), and/or a cost approach (generally, replacement cost) are used to measure the fair value of an asset or liability, as appropriate. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The fair value of a group of financial assets and liabilities is measured on a net basis. Transfers between levels are recognized at end-of-reporting-period values. During the
three and nine
months ended
September 30, 2016
and
2015
, there were no transfers between Level 1 and Level 2. See Note 1 in Talen Energy's
2015
Form 10-K for information on the levels in the fair value hierarchy.
Recurring Fair Value Measurements
The assets and liabilities measured at fair value were:
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|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2016
|
|
December 31, 2015
|
|
|
Total
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Total
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
$
|
1,358
|
|
|
$
|
1,358
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
141
|
|
|
$
|
141
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
Restricted cash and cash equivalents (a)
|
46
|
|
|
46
|
|
|
—
|
|
|
—
|
|
|
106
|
|
|
106
|
|
|
—
|
|
|
—
|
|
|
Price risk management assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Energy commodities
|
544
|
|
|
—
|
|
|
494
|
|
|
50
|
|
|
693
|
|
|
—
|
|
|
597
|
|
|
96
|
|
|
Total price risk management assets
|
544
|
|
|
—
|
|
|
494
|
|
|
50
|
|
|
693
|
|
|
—
|
|
|
597
|
|
|
96
|
|
|
NDT funds:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
5
|
|
|
5
|
|
|
—
|
|
|
—
|
|
|
11
|
|
|
11
|
|
|
—
|
|
|
—
|
|
|
Equity securities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
U.S. large-cap
|
662
|
|
|
490
|
|
|
172
|
|
|
—
|
|
|
616
|
|
|
457
|
|
|
159
|
|
|
—
|
|
|
U.S. mid/small-cap
|
95
|
|
|
40
|
|
|
55
|
|
|
—
|
|
|
87
|
|
|
37
|
|
|
50
|
|
|
—
|
|
|
Debt securities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
U.S. Treasury
|
114
|
|
|
114
|
|
|
—
|
|
|
—
|
|
|
98
|
|
|
98
|
|
|
—
|
|
|
—
|
|
|
U.S. government sponsored agency
|
3
|
|
|
—
|
|
|
3
|
|
|
—
|
|
|
6
|
|
|
—
|
|
|
6
|
|
|
—
|
|
|
Municipality
|
86
|
|
|
—
|
|
|
86
|
|
|
—
|
|
|
83
|
|
|
—
|
|
|
83
|
|
|
—
|
|
|
Investment-grade corporate
|
46
|
|
|
—
|
|
|
46
|
|
|
—
|
|
|
47
|
|
|
—
|
|
|
47
|
|
|
—
|
|
|
Other
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
3
|
|
|
—
|
|
|
3
|
|
|
—
|
|
|
Receivables (payables), net
|
1
|
|
|
(1
|
)
|
|
2
|
|
|
—
|
|
|
—
|
|
|
(2
|
)
|
|
2
|
|
|
—
|
|
|
Total NDT funds
|
1,012
|
|
|
648
|
|
|
364
|
|
|
—
|
|
|
951
|
|
|
601
|
|
|
350
|
|
|
—
|
|
|
Auction rate securities (b)
|
3
|
|
|
—
|
|
|
—
|
|
|
3
|
|
|
6
|
|
|
—
|
|
|
—
|
|
|
6
|
|
|
Total assets
|
$
|
2,963
|
|
|
$
|
2,052
|
|
|
$
|
858
|
|
|
$
|
53
|
|
|
$
|
1,897
|
|
|
$
|
848
|
|
|
$
|
947
|
|
|
$
|
102
|
|
|
Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Price risk management liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Energy commodities
|
$
|
398
|
|
|
$
|
—
|
|
|
$
|
392
|
|
|
$
|
6
|
|
|
$
|
539
|
|
|
$
|
—
|
|
|
$
|
497
|
|
|
$
|
42
|
|
|
Total price risk management liabilities
|
$
|
398
|
|
|
$
|
—
|
|
|
$
|
392
|
|
|
$
|
6
|
|
|
$
|
539
|
|
|
$
|
—
|
|
|
$
|
497
|
|
|
$
|
42
|
|
|
|
|
|
(a)
|
Current portion is included in "Restricted cash and cash equivalents" and long-term portion, when applicable, is included in "Other noncurrent assets" on the Balance Sheets.
|
|
|
|
|
(b)
|
Included in "Other investments" on the Balance Sheets.
|
A reconciliation of net assets and liabilities classified as Level 3 for the
periods
ended
September 30, 2016
is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
|
|
|
Three Months
|
|
Nine Months
|
|
|
Energy Commodities, net
|
|
Auction Rate Securities
|
|
Total
|
|
Energy Commodities, net
|
|
Auction Rate Securities
|
|
Total
|
|
Balance at beginning of period
|
$
|
12
|
|
|
$
|
6
|
|
|
$
|
18
|
|
|
$
|
54
|
|
|
$
|
6
|
|
|
$
|
60
|
|
|
Total realized/unrealized gains (losses) included in earnings
|
61
|
|
|
—
|
|
|
61
|
|
|
83
|
|
|
—
|
|
|
83
|
|
|
Sales
|
—
|
|
|
(3
|
)
|
|
(3
|
)
|
|
—
|
|
|
(3
|
)
|
|
(3
|
)
|
|
Settlements
|
(33
|
)
|
|
—
|
|
|
(33
|
)
|
|
(100
|
)
|
|
—
|
|
|
(100
|
)
|
|
Transfers into Level 3
|
4
|
|
|
—
|
|
|
4
|
|
|
5
|
|
|
—
|
|
|
5
|
|
|
Transfers out of Level 3
|
—
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|
—
|
|
|
2
|
|
|
Balance at end of period
|
$
|
44
|
|
|
$
|
3
|
|
|
$
|
47
|
|
|
$
|
44
|
|
|
$
|
3
|
|
|
$
|
47
|
|
A reconciliation of net assets and liabilities classified as Level 3 for the
periods
ended
September 30, 2015
is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
|
|
|
Three Months
|
|
Nine Months
|
|
|
Energy Commodities, net
|
|
Auction Rate Securities
|
|
Total
|
|
Energy Commodities, net
|
|
Auction Rate Securities
|
|
Total
|
|
Balance at beginning of period
|
$
|
10
|
|
|
$
|
7
|
|
|
$
|
17
|
|
|
$
|
111
|
|
|
$
|
8
|
|
|
$
|
119
|
|
|
Total realized/unrealized gains (losses) included in earnings
|
(7
|
)
|
|
—
|
|
|
(7
|
)
|
|
(148
|
)
|
|
—
|
|
|
(148
|
)
|
|
Purchases (a)
|
—
|
|
|
—
|
|
|
—
|
|
|
(39
|
)
|
|
—
|
|
|
(39
|
)
|
|
Sales
|
—
|
|
|
(1
|
)
|
|
(1
|
)
|
|
65
|
|
|
(2
|
)
|
|
63
|
|
|
Settlements
|
(9
|
)
|
|
—
|
|
|
(9
|
)
|
|
(6
|
)
|
|
—
|
|
|
(6
|
)
|
|
Transfers into Level 3
|
—
|
|
|
—
|
|
|
—
|
|
|
10
|
|
|
—
|
|
|
10
|
|
|
Transfers out of Level 3
|
11
|
|
|
—
|
|
|
11
|
|
|
12
|
|
|
—
|
|
|
12
|
|
|
Balance at end of period
|
$
|
5
|
|
|
$
|
6
|
|
|
$
|
11
|
|
|
$
|
5
|
|
|
$
|
6
|
|
|
$
|
11
|
|
|
|
|
|
(a)
|
Positions acquired through the acquisition of RJS Power.
|
The significant unobservable inputs used in and quantitative information about the fair value measurement of assets and liabilities classified as Level 3 are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2016
|
|
|
Fair Value, net
Asset
(Liability)
|
|
Valuation
Technique
|
|
Significant Unobservable
Input(s)
|
|
Range
(Weighted
Average) (a)
|
|
Energy commodities
|
|
|
|
|
|
|
|
|
Natural gas contracts (b)
|
$
|
31
|
|
|
Discounted cash flow
|
|
Proprietary model used to calculate forward prices
|
|
13% - 100% (69%)
|
|
Power sales contracts (c)
|
12
|
|
|
Discounted cash flow
|
|
Proprietary model used to calculate forward prices
|
|
100% (100%)
|
|
FTR purchase contracts (d)
|
1
|
|
|
Discounted cash flow
|
|
Historical settled prices used to model forward prices
|
|
100% (100%)
|
|
Heat rate call options (e)
|
1
|
|
|
Discounted cash flow
|
|
Proprietary model used to calculate forward prices
|
|
100% (100%)
|
|
CRR purchase contracts (d)
|
(1
|
)
|
|
Discounted cash flow
|
|
Proprietary model used to calculate forward prices
|
|
100% (100%)
|
|
Auction rate securities (f)
|
3
|
|
|
Discounted cash flow
|
|
Modeled from SIFMA Index
|
|
38% (38%)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2015
|
|
|
Fair Value, net
Asset
(Liability)
|
|
Valuation
Technique
|
|
Significant Unobservable
Input(s)
|
|
Range
(Weighted
Average) (a)
|
|
Energy commodities
|
|
|
|
|
|
|
|
|
Natural gas contracts (b)
|
$
|
55
|
|
|
Discounted cash flow
|
|
Proprietary model used to calculate forward prices
|
|
10% - 100% (50%)
|
|
Power sales contracts (c)
|
13
|
|
|
Discounted cash flow
|
|
Proprietary model used to calculate forward prices
|
|
10% - 100% (100%)
|
|
FTR purchase contracts (d)
|
(2
|
)
|
|
Discounted cash flow
|
|
Historical settled prices used to model forward prices
|
|
100% (100%)
|
|
Heat rate call options (e)
|
(10
|
)
|
|
Discounted cash flow
|
|
Proprietary model used to calculate forward prices
|
|
100% (100%)
|
|
CRR purchase contracts (d)
|
(2
|
)
|
|
Discounted cash flow
|
|
Proprietary model used to calculate forward prices
|
|
100% (100%)
|
|
Auction rate securities (f)
|
6
|
|
|
Discounted cash flow
|
|
Modeled from SIFMA Index
|
|
46% - 47% (46.5%)
|
|
|
|
|
(a)
|
The range and weighted average represent the percentage of fair value derived from the unobservable inputs.
|
|
|
|
|
(b)
|
As the forward price of natural gas increases/(decreases), the fair value of purchase contracts increases/(decreases). As the forward price of natural gas increases/(decreases), the fair value of sales contracts (decreases)/increases.
|
|
|
|
|
(c)
|
As forward market prices increase/(decrease), the fair value of contracts (decreases)/increases. As volumetric assumptions for contracts in a gain position increase/(decrease), the fair value of contracts increases/(decreases). As volumetric assumptions for contracts in a loss position increase/(decrease), the fair value of the contracts (decreases)/increases.
|
|
|
|
|
(d)
|
As the forward implied spread increases/(decreases), the fair value of the contracts increases/(decreases).
|
|
|
|
|
(e)
|
The proprietary model used to calculate fair value incorporates market heat rates, correlations and volatilities. As the market implied heat rate increases/(decreases), the fair value of purchased calls increases/(decreases). As the market implied heat rate increases/(decreases), the fair value of sold calls (decreases)/increases.
|
|
|
|
|
(f)
|
The model used to calculate fair value incorporates an assumption that the auctions will continue to fail. As the modeled forward rates of the SIFMA Index increase/(decrease), the fair value of the securities increases/(decreases).
|
Net gains and losses on assets and liabilities classified as Level 3 and included in earnings for the periods ended
September 30
are reported in the Statements of Income as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
|
|
Energy Commodities, net
|
|
|
|
Wholesale Energy
|
|
Retail Energy
|
|
Fuel and Energy Purchases
|
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Total gains (losses) included in earnings
|
|
$
|
37
|
|
|
$
|
2
|
|
|
$
|
28
|
|
|
$
|
(1
|
)
|
|
$
|
(4
|
)
|
|
$
|
(8
|
)
|
|
Change in unrealized gains (losses) relating
to positions still held at the reporting date
|
|
19
|
|
|
8
|
|
|
21
|
|
|
12
|
|
|
(3
|
)
|
|
(1
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months
|
|
|
|
Energy Commodities, net
|
|
|
|
Wholesale Energy
|
|
Retail Energy
|
|
Fuel and Energy Purchases
|
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Total gains (losses) included in earnings
|
|
$
|
68
|
|
|
$
|
(108
|
)
|
|
$
|
19
|
|
|
$
|
(33
|
)
|
|
$
|
(4
|
)
|
|
$
|
(7
|
)
|
|
Change in unrealized gains (losses) relating
to positions still held at the reporting date
|
|
12
|
|
|
(31
|
)
|
|
2
|
|
|
9
|
|
|
(2
|
)
|
|
(5
|
)
|
Price Risk Management Assets/Liabilities - Energy Commodities
Energy commodity contracts are generally valued using the income approach, except for exchange-traded derivative contracts, which are valued using the market approach and are classified as Level 1. Level 2 contracts are valued using inputs which may include quotes obtained from an exchange (where there is insufficient market liquidity to warrant inclusion in Level 1), binding and non-binding broker quotes, prices posted by ISOs or published tariff rates. Furthermore, independent quotes are obtained from the market to validate the forward price curves. Energy commodity contracts include forwards, futures, swaps, options and structured transactions and may be offset with similar positions in exchange-traded markets. To the extent possible, fair value measurements utilize various inputs that include quoted prices for similar contracts or market-corroborated inputs. In certain instances, these contracts may be valued using models, including standard option valuation models and other standard industry models. When the lowest level inputs that are significant to the fair value measurement of a contract are observable, the contract is classified as Level 2.
When unobservable inputs are significant to the fair value measurement, a contract is classified as Level 3. Level 3 contracts are valued using Talen Energy's proprietary models which may include significant unobservable inputs such as delivery at a location where pricing is unobservable, delivery dates that are beyond the dates for which independent quotes are available, volumetric assumptions, implied volatilities, implied correlations, and market implied heat rates. Forward transactions, including forward transactions classified as Level 3, are analyzed by Talen Energy's Risk Management department. Accounting personnel interpret the analysis quarterly to appropriately classify the fair value measurements in the fair value hierarchy. Valuation techniques are evaluated periodically. Additionally, Level 2 and Level 3 fair value measurements include adjustments for credit risk based on Talen Energy's own creditworthiness (for net liabilities) and its counterparties' creditworthiness (for net assets). Talen Energy's credit department assesses all reasonably available market information which is used by accounting personnel to calculate the credit valuation adjustment.
In certain instances, energy commodity contracts are transferred between Level 2 and Level 3. The primary reasons for the transfers during 2016 were changes in the availability of market information and changes in the significance of the unobservable inputs utilized in the valuation of the contracts.
NDT Funds
The market approach is used to measure the fair value of equity securities held in the
NDT funds.
|
|
|
|
•
|
The fair value measurements of equity securities classified as Level 1 are based on quoted prices in active markets.
|
|
|
|
|
•
|
The fair value measurements of investments in commingled equity funds are classified as Level 2. These fair value measurements are based on firm quotes of net asset values per share, which are not obtained from a quoted price in an active market.
|
The fair value of debt securities is generally measured using a market approach, including the use of pricing models which incorporate observable inputs. Common inputs include benchmark yields, relevant trade data, broker/dealer bid/ask prices, benchmark securities and credit valuation adjustments. When necessary, the fair value of debt securities is measured using the income approach, which incorporates similar observable inputs as well as payment data, future predicted cash flows, collateral performance and new issue data.
Auction Rate Securities
The fair value of auction rate securities is estimated using an income approach that includes readily observable inputs, such as principal payments and discount curves for bonds with credit ratings and maturities similar to the securities, and unobservable inputs, such as future interest rates that are estimated based on the SIFMA Index, creditworthiness, and liquidity assumptions driven by the impact of auction failures. The probability of realizing losses on these securities is not significant. When the present value of future interest payments is significant to the overall valuation, the auction rate securities are classified as Level 3.
Auction rate securities are valued by the Treasury department. Accounting personnel interpret the analysis quarterly to classify the fair value measurements in the fair value hierarchy. Valuation techniques are evaluated periodically.
Nonrecurring Fair Value Measurements
The following nonrecurring fair value measurements occurred during the reporting periods resulting in impairments:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Carrying
Amount (a)
|
|
Fair Value Measurements Using
Level 3 Inputs (b)
|
|
Pre-tax Loss (c)
|
|
Harquahala plant (September 30, 2016) (d)
|
$
|
1
|
|
|
$
|
—
|
|
|
$
|
1
|
|
|
Bell Bend COLA (June 30, 2016)
|
204
|
|
|
—
|
|
|
204
|
|
|
Harquahala plant (June 30, 2016)
|
9
|
|
|
—
|
|
|
9
|
|
|
Sapphire plants and C.P. Crane plant (September 30, 2015)
|
388
|
|
|
266
|
|
|
122
|
|
|
|
|
|
(a)
|
Represents carrying value before fair value measurement.
|
|
|
|
|
(b)
|
For the Sapphire plants and C.P. Crane plant, fair value is net of estimated costs to sell. See Note 1 in Talen Energy's 2015 Form 10-K for information on the classification of the Sapphire plants in continuing operations and Note 8 to these financial statements for information on the sale of the C.P. Crane plant.
|
|
|
|
|
(c)
|
The losses are included in "Impairments" on the Statement of Income.
|
|
|
|
|
(d)
|
In the third quarter of 2016, management determined that the impairment charge for the three and six months ended June 30, 2016 was overstated by an insignificant amount, which was corrected during the three and nine months ended September 30, 2016. The adjustment resulted in a reclassification between "Impairments" and "Operation and maintenance" and had no impact on "Operating Expenses," "Operating Income (Loss)" or "Net Income (Loss)" on the Statement of Income.
|
The significant unobservable inputs used in and the quantitative information about the nonrecurring fair value measurement of assets and liabilities classified as Level 3 are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair Value, net
Asset
(Liability)
|
|
Valuation
Technique
|
|
Significant
Unobservable
Input(s)
|
|
Range
(Weighted
Average)(a)
|
|
|
|
|
|
|
Harquahala plant (September 30, 2016)
|
$
|
—
|
|
|
Discounted cash flow
|
|
Proprietary model to calculate value
|
|
100% (100%)
|
|
|
Bell Bend COLA (June 30, 2016)
|
—
|
|
|
Market approach
|
|
Described below
|
|
100% (100%)
|
|
|
Harquahala plant (June 30, 2016)
|
—
|
|
|
Discounted cash flow
|
|
Proprietary model to calculate value
|
|
100% (100%)
|
|
|
Sapphire plants and C.P. Crane plant (September 30, 2015)
|
266
|
|
|
Discounted cash flow
|
|
Proprietary model used to calculate plant value
|
|
100% (100%)
|
|
|
|
|
(a)
|
The range and weighted average represent the percentage of fair value derived from the unobservable inputs.
|
Bell Bend COLA
After receiving the Final Environmental Impact Statement in the second quarter of 2016, Talen Energy reassessed its options with respect to the Bell Bend project and decided it will no longer pursue the development of the COLA. Management concluded that the amounts capitalized for the COLA are not recoverable. Management used a market approach to estimate the fair value of the incomplete COLA, considering the highest and best use from a market participant perspective, and concluded that there was no value to another market participant given current and forecasted capacity and energy prices and forecasted operating costs combined with the high cost to build a nuclear facility, as well as the lack of progress by the COLA specified nuclear reactor vendor on its NRC design certification and lack of usefulness to a standalone market participant. The COLA was valued by Talen Energy's financial department. Through this analysis, Talen Energy determined the fair value of the COLA to be negligible. Accounting personnel interpreted the analysis to appropriately classify the fair value measurement in the fair value hierarchy. See Note
8
for additional information.
Harquahala
Upon acquisition of the MACH Gen assets in November 2015, Talen Energy assigned no value to the plant and equipment of the Harquahala plant. Talen Energy determined that the cash flows of the plant are not recoverable and for the
three and nine
months ended
September 30, 2016
,
recorded impairment charges to the East segment for all amounts capitalized since acquisition. To estimate cash flows of the Harquahala plant, Talen Energy performed an internal analysis primarily using an income approach based on discounted cash flows (a proprietary Talen Energy model) to assess the fair value of these assets. Assumptions used in the Talen Energy proprietary model were forward energy price curves, forecasted generation, and forecasted operation, maintenance and capital expenditures and a market participant discount rate. The analysis was performed by Talen Energy's financial department. Accounting personnel interpreted the analysis to appropriately classify the fair value measurement in the fair value hierarchy. All future amounts capitalized are expected to be impaired until the carrying value of the plant is recoverable.
Sapphire Plants and C.P. Crane Plant
In the third quarter of 2015, Talen Energy updated its fundamental pricing models in conjunction with market information gained as a result of the 2018/2019 planning year PJM capacity auction completed in August 2015. As a result, Talen Energy assessed certain long-lived assets for impairment and determined that the C.P. Crane coal-fired plant failed a recoverability test and as a result, recorded an impairment charge based on the plant's estimated fair value at September 30, 2015. Additionally, because the Sapphire plants were classified as held for sale and had to be carried at the lower of their current carrying value or fair value less cost to sell, Talen Energy used updated cash flow information to calculate the estimated fair value of the Sapphire plants at September 30, 2015 and determined a write-down was necessary based on estimated fair value. The Sapphire plants were subsequently reclassified from assets of discontinued operations to held and used in November 2015 as a result of the FERC's approval of the third mitigation package relating to the formation of Talen Energy. See Note 1 in Talen Energy's
2015
Form 10-K for additional information on the classification of the Sapphire plants and Note
8
to these financial statements for additional information on the sale of the C.P. Crane plant.
To estimate the fair value of the Sapphire plants and C.P. Crane plant, Talen Energy performed an internal analysis primarily using an income approach based on discounted cash flows (a proprietary Talen Energy model) to assess the fair value of these
assets. Assumptions used in the Talen Energy proprietary model were the forward energy and capacity price curves, forecasted generation, and forecasted operation, maintenance and capital expenditures and a market participant discount rate. Through this analysis, Talen Energy determined the fair value of the Sapphire plants and the C.P. Crane plant at September 30, 2015.
The assets were valued by Talen Energy's financial planning and analysis personnel and accounting personnel interpreted the analysis to appropriately classify the fair value measurements in the fair value hierarchy.
Financial Instruments Not Recorded at Fair Value
The carrying amounts of long-term debt on the Balance Sheets and its estimated fair values are set forth below. The fair value of fixed rate debt was primarily estimated using an income approach by discounting future cash flows at estimated current cost of funding rates, which incorporates the credit risk of Talen Energy Supply. The carrying amounts of borrowings under the New MACH Gen RCF and the New MACH Gen Term Loan B approximate fair value due to the variable interest rates associated with the debt. Long-term debt is primarily classified as Level 2.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2016
|
|
December 31, 2015
|
|
|
Carrying Amount
|
|
Fair Value
|
|
Carrying Amount
|
|
Fair Value
|
|
Long-term debt
|
$
|
3,899
|
|
|
$
|
3,523
|
|
|
$
|
4,186
|
|
|
$
|
3,343
|
|
The carrying amount of short-term debt, when outstanding, approximates fair value due to the variable interest rates associated with the debt and is classified as Level 2.
Credit Concentration Associated with Financial Instruments
Contracts are entered into with many entities for the purchase and sale of energy. When NPNS is elected, the fair value of these contracts is not reflected in the financial statements. However, the fair value of these contracts is considered when committing to new business from a credit perspective. See Note
14
for information on credit procedures used to manage credit risk, including master netting arrangements and collateral requirements.
At
September 30, 2016
, Talen Energy had credit exposure of
$524 million
from energy trading partners, excluding the effects of netting arrangements, reserves and collateral. As a result of netting arrangements, reserves and collateral, Talen Energy's credit exposure was reduced to
$349 million
. The top ten counterparties, including their affiliates, accounted for
$156 million
, or
45%
, of these exposures.
Seven
of these counterparties had an investment grade credit rating from S&P or Moody's and accounted for
83%
of the top ten exposures. The remaining counterparties have not been rated by S&P or Moody's and are current on their obligations.
14
. Derivative Instruments and Hedging Activities
Risk Management Objectives
Talen Energy has a risk management policy approved by the Talen Energy Corporation Board of Directors to manage market risk associated with commodities, interest rates on debt issuances and foreign exchange (including price, liquidity and volumetric risk) and credit risk (including non-performance risk and payment default risk). A risk management committee, comprised of senior management and chaired by the Director-Risk Management, oversees the risk management function. Key risk control activities designed to ensure compliance with the risk policy include, but are not limited to, credit review and approval, validation of transactions and market prices, verification of risk and transaction limits, VaR analysis, portfolio stress tests, gross margin at risk analysis, sensitivity analysis and daily portfolio reporting.
Market Risk
Market risk includes the potential loss that may be incurred as a result of price changes associated with a particular financial or commodity instrument as well as market liquidity and volumetric risks. Forward and futures contracts, options, swaps and structured transactions are utilized as part of risk management strategies to minimize unanticipated fluctuations in earnings caused by changes in commodity prices, volumes of full-requirement sales contracts, basis exposure and interest rates. Many of the contracts meet the definition of a derivative. All derivatives are recognized on the Balance Sheets at their fair value, unless NPNS is elected.
Talen Energy is subject to market risks, which are actively mitigated through the risk management policy described above. Such risks include:
|
|
|
|
•
|
Commodity price risk, including basis and volumetric risk
|
Commodity price risk
|
|
|
|
•
|
Talen Energy is exposed to commodity price risk for energy and energy-related products associated with the sale of electricity from its generating assets and other electricity and gas marketing activities and the purchase of fuel and fuel-related commodities for generating assets, as well as for proprietary trading activities.
|
Interest rate risk
|
|
|
|
•
|
Talen Energy is exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances.
|
Credit Risk
Credit risk is the potential loss that may be incurred due to a counterparty's non-performance.
Talen Energy is exposed to credit risk from "in-the-money" commodity derivatives with its energy trading partners, which include other energy companies, fuel suppliers, financial institutions and other wholesale and retail customers.
The majority of Talen Energy's credit risk stems from commodity derivatives for multi-year contracts for energy sales and purchases. If Talen Energy's counterparties fail to perform their obligations under such contracts and Talen Energy could not replace the sales or purchases at the same or better prices as those under the defaulted contracts, Talen Energy would incur financial losses. Those losses would be recognized immediately or through lower revenues or higher costs in future years, depending on the accounting treatment for the defaulted contracts.
Talen Energy has credit procedures in place to manage credit risk, including the use of an established credit approval process, daily monitoring of counterparty positions and the use of master netting agreements or provisions. These agreements generally include credit mitigation provisions, such as margin, prepayment or collateral requirements. Talen Energy may request additional credit assurance, in certain circumstances, in the event that the counterparties' credit ratings fall below investment grade or their exposures exceed an established credit limit. See Note
13
for credit concentration associated with energy trading partners.
Master Netting Arrangements
Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.
Talen Energy's obligation to return counterparty cash collateral under master netting arrangements was insignificant at
September 30, 2016
and there was no obligation at
December 31, 2015
.
Talen Energy did not post any cash collateral under master netting arrangements at
September 30, 2016
and
December 31, 2015
.
See "Offsetting Derivative Investments" below for a summary of derivative positions presented in the balance sheets where a right of setoff exists under these arrangements.
Commodity Price Risk (Non-trading)
Commodity price risk, including basis and volumetric risk, is among Talen Energy's most significant risks due to the level of investment that Talen Energy maintains in its competitive generation assets. Several factors influence price levels and volatilities. These factors include, but are not limited to, seasonal changes in demand, weather conditions, available generating assets within regions, transportation/transmission availability and reliability within and between regions, market liquidity, and the nature and extent of current and potential federal and state regulations.
Talen Energy has a formal hedging program to economically hedge the forecasted purchase and sale of electricity and related fuels for its competitive generation fleet. Talen Energy's portfolio also includes full-requirement sales contracts and related supply contracts and retail natural gas and electricity sale contracts. The strategies that Talen Energy uses to hedge its full-requirement sales contracts include supplying the energy, capacity and RECs from its generation assets and purchasing energy (at a liquid trading hub or directly at the load delivery zone), capacity and RECs in the market.
Talen Energy enters into financial and physical derivative contracts, including forwards, futures, swaps and options, to hedge the price risk associated with electricity, natural gas, oil and other commodities. Certain contracts are non-derivatives or NPNS is elected and therefore they are not reflected in the financial statements until delivery. Talen Energy segregates its non-trading activities into two categories: cash flow hedges and economic activity as discussed below.
Cash Flow Hedges
Certain derivative contracts have qualified for hedge accounting so that the effective portion of a derivative's gain or loss is deferred in AOCI and reclassified into earnings when the forecasted transaction occurs. In
2016
and
2015
, there were no active cash flow hedges and there was no hedge ineffectiveness associated with energy derivatives. At
September 30, 2016
, the accumulated net unrecognized after-tax gains (losses) that are expected to be reclassified into earnings during the next 12 months were
$21 million
. Cash flow hedges are discontinued if it is no longer probable that the original forecasted transaction will occur by the end of the originally specified time periods and any amounts previously recorded in AOCI are reclassified into earnings once it is determined that the hedge transaction is probable of not occurring. There were no such reclassifications for the
three and nine
months ended
September 30, 2016
and
2015
.
Economic Activity
Many derivative contracts economically hedge the commodity price risk associated with electricity, natural gas, oil and other commodities but do not receive hedge accounting treatment because they were not eligible for hedge accounting or because hedge accounting was not elected. These derivatives hedge a portion of the economic value of Talen Energy's competitive generation assets and competitive full-requirement and retail contracts, which are subject to changes in fair value due to market price volatility and volume expectations. The derivative contracts in this category that existed at
September 30, 2016
range in maturity through
2020
.
Examples of economic activity may include hedges on sales of nuclear, coal and hydroelectric generation, certain purchase contracts used to supply full-requirement sales contracts, FTRs, CRRs, or basis swaps used to hedge basis risk associated with the sale of competitive generation or supplying full-requirement sales contracts, Spark Spread hedging contracts, retail electric and natural gas activities, and fuel oil swaps used to hedge price escalation clauses in coal transportation and other fuel-related contracts. Talen Energy also uses options, which include the sale of call options and the purchase of put options tied to a particular generating unit. Since the physical generating capacity is owned, price exposure is generally capped at the price at which the generating unit would be dispatched and therefore does not expose Talen Energy to uncovered market price risk.
The unrealized gains (losses) for economic activity for the periods ended
September 30
were as follows.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Operating Revenues
|
|
|
|
|
|
|
|
|
Wholesale energy (a)
|
$
|
79
|
|
|
$
|
26
|
|
|
$
|
(55
|
)
|
|
$
|
65
|
|
|
Retail energy
|
11
|
|
|
(3
|
)
|
|
(24
|
)
|
|
(25
|
)
|
|
Operating Expenses
|
|
|
|
|
|
|
|
|
Fuel and energy purchases (a)
|
4
|
|
|
24
|
|
|
105
|
|
|
84
|
|
|
|
|
|
(a)
|
In the third quarter of 2015, Talen Energy refined an input used in the valuation technique for certain PJM based curves as observable inputs became available. This change resulted in the recording of a
$30 million
net unrealized gain, primarily reflected in "Wholesale energy" revenue on the Statement of Income.
|
Commodity Price Risk (Trading)
Talen Energy has a proprietary trading strategy which is utilized to take advantage of market opportunities primarily in its geographic footprint. As a result, Talen Energy may at times create a net open position in its portfolio that could result in losses if prices do not move in the manner or direction anticipated. Net energy trading margins, which are included in "Wholesale energy" on the Statements of Income, were insignificant for the
three and nine
months ended
September 30, 2016
and
2015
.
Commodity Volumes
At
September 30, 2016
, the net volumes of derivative (sales)/purchase contracts used in support of the various strategies discussed above were as follows.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Volumes (a)
|
|
Commodity
|
|
Unit of Measure
|
|
2016 (b)
|
|
2017
|
|
2018
|
|
Thereafter
|
|
Power
|
|
MWh
|
|
(11,082,701
|
)
|
|
(28,328,401
|
)
|
|
(7,295,545
|
)
|
|
(719,594
|
)
|
|
Capacity
|
|
MW-Month
|
|
(1,407
|
)
|
|
(3,750
|
)
|
|
(3,746
|
)
|
|
(1,559
|
)
|
|
Gas
|
|
MMBtu
|
|
49,141,090
|
|
|
27,105,885
|
|
|
10,700,938
|
|
|
2,832,312
|
|
|
FTRs
|
|
MW-Month
|
|
3,774
|
|
|
3,503
|
|
|
—
|
|
|
—
|
|
|
Oil
|
|
Barrels
|
|
15,699
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
CRRs
|
|
MWh
|
|
453,072
|
|
|
641,989
|
|
|
—
|
|
|
—
|
|
|
Emission Allowances
|
|
Tons
|
|
3,866,753
|
|
|
(82,540
|
)
|
|
—
|
|
|
—
|
|
|
|
|
|
(a)
|
Volumes for option contracts factor in the probability of an option being exercised and may be less than the notional amount of the option.
|
|
|
|
|
(b)
|
Represents balance of the current year.
|
Accounting and Reporting
All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless NPNS is elected. NPNS contracts for Talen Energy include certain full-requirement sales contracts, other physical purchase and sales contracts and certain retail energy and physical capacity contracts. Changes in the fair value of derivatives not designated as NPNS are recognized currently in earnings. Talen Energy has many physical and financial commodity purchases and sales contracts that economically hedge commodity price risk. Certain of the economic hedging strategies employed by Talen Energy utilize a combination of financial purchases and sales contracts. Realized and unrealized gains (losses) on these contracts are recorded currently in earnings. Generally each contract is considered a unit of account and Talen Energy presents gains (losses) on physical and financial commodity contracts based upon their economic hedging strategy. Generation revenue hedge strategies are recorded in "Wholesale energy" on the Statements of Income. Retail sales strategies are recorded in "Retail energy" on the Statements of Income. Gas, oil and coal generation supply strategies and non-generation power and fuel supply strategies are recorded in "Fuel and energy purchases" on the Statements of Income. Certain Talen Energy subsidiaries participate in RTOs and ISOs. Talen Energy accounts for these transactions on a net hourly basis because the transactions are settled on a net hourly basis. Talen Energy records realized hourly net sales or purchases of physical power with RTOs and ISOs in its Statements of Income as "Wholesale energy" if in a net sales position and "Fuel and energy purchases" if in a net purchase position.
See Notes 1 and 15 in Talen Energy's
2015
Form 10-K for additional information on accounting policies related to derivative instruments.
The following table presents the fair value and location of commodity derivative instruments not designated as hedging instruments recorded on the Balance Sheets.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2016
|
|
December 31, 2015
|
|
|
|
Assets
|
|
Liabilities
|
|
Assets
|
|
Liabilities
|
|
Current:
|
|
|
|
|
|
|
|
|
|
Price Risk Management Assets/Liabilities
|
|
$
|
350
|
|
|
$
|
272
|
|
|
$
|
562
|
|
|
$
|
431
|
|
|
Noncurrent:
|
|
|
|
|
|
|
|
|
|
Price Risk Management Assets/Liabilities
|
|
194
|
|
|
126
|
|
|
131
|
|
|
108
|
|
|
Total derivatives
|
|
$
|
544
|
|
|
$
|
398
|
|
|
$
|
693
|
|
|
$
|
539
|
|
The following tables present the pre-tax effect of derivative instruments recognized in income for the
periods
ended
September 30, 2016
.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gain (Loss) Reclassified from AOCI into Income
(Effective Portion)
|
|
Derivative
Relationships
|
|
Location of Gain (Loss) Recognized in Income on Derivative
|
|
Three Months
|
|
Nine Months
|
|
Cash Flow Hedges:
|
|
|
|
|
|
|
|
Commodity contracts
|
|
Wholesale energy
|
|
$
|
(5
|
)
|
|
$
|
(9
|
)
|
|
|
|
Fuel and energy purchases
|
|
7
|
|
|
22
|
|
|
|
|
Depreciation
|
|
1
|
|
|
2
|
|
|
|
|
Total
|
|
$
|
3
|
|
|
$
|
15
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Derivatives Not Designated as
Hedging Instruments
|
|
Location of Gain (Loss) Recognized in
Income on Derivative
|
|
Three Months
|
|
Nine Months
|
|
Commodity contracts
|
|
Wholesale energy
|
|
$
|
169
|
|
|
$
|
341
|
|
|
|
|
Retail energy
|
|
29
|
|
|
26
|
|
|
|
|
Fuel and energy purchases
|
|
(68
|
)
|
|
(96
|
)
|
|
|
|
Total
|
|
$
|
130
|
|
|
$
|
271
|
|
The following tables present the pre-tax effect of derivative instruments recognized in income for the
periods
ended
September 30, 2015
.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gain (Loss) Reclassified from AOCI into Income
(Effective Portion)
|
|
Derivative
Relationships
|
|
Location of Gain (Loss) Recognized in Income on Derivative
|
|
Three Months
|
|
Nine Months
|
|
Cash Flow Hedges:
|
|
|
|
|
|
|
|
Commodity contracts
|
|
Wholesale energy
|
|
$
|
(3
|
)
|
|
$
|
(3
|
)
|
|
|
|
Fuel and energy purchases
|
|
9
|
|
|
25
|
|
|
|
|
Depreciation
|
|
—
|
|
|
1
|
|
|
|
|
Total
|
|
$
|
6
|
|
|
$
|
23
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Derivatives Not Designated as
Hedging Instruments
|
|
Location of Gain (Loss) Recognized in
Income on Derivative
|
|
Three Months
|
|
Nine Months
|
|
Commodity contracts
|
|
Wholesale energy
|
|
$
|
164
|
|
|
$
|
217
|
|
|
|
|
Retail energy
|
|
15
|
|
|
(16
|
)
|
|
|
|
Fuel and energy purchases
|
|
(55
|
)
|
|
(63
|
)
|
|
|
|
Total
|
|
$
|
124
|
|
|
$
|
138
|
|
Offsetting Derivative Instruments
Certain subsidiaries of Talen Energy have master netting arrangements or similar agreements in place including derivative clearing agreements with futures commission merchants (FCMs) to permit the trading of cleared derivative products on one or more futures exchanges. The clearing arrangements permit a FCM to use and apply any property in its possession as a setoff to pay amounts or discharge obligations owed by a customer upon default of the customer and typically do not place any restrictions on the FCM's use of collateral posted by the customer. Certain subsidiaries of Talen Energy also enter into agreements pursuant to which they trade certain energy and other products. Under the agreements, upon termination of the agreement as a result of a default or other termination event, the non-defaulting party typically would have a right to offset amounts owed under the agreement against any other obligations arising between the two parties (whether under the agreement or not), whether matured or contingent and irrespective of the currency, place of payment or place of booking of the obligation.
Talen Energy has elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivatives agreements. The table below summarizes the energy commodities derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Assets
|
|
Liabilities
|
|
|
|
|
|
|
|
Eligible for Offset
|
|
|
|
|
|
Eligible for Offset
|
|
|
|
|
|
|
|
Gross
|
|
Derivative
Instruments
|
|
Cash Collateral Received
|
|
Net
|
|
Gross
|
|
Derivative
Instruments
|
|
Cash Collateral Pledged
|
|
Net
|
|
September 30, 2016
|
|
$
|
544
|
|
|
$
|
378
|
|
|
$
|
42
|
|
|
$
|
124
|
|
|
$
|
398
|
|
|
$
|
378
|
|
|
$
|
—
|
|
|
$
|
20
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2015
|
|
$
|
693
|
|
|
$
|
437
|
|
|
$
|
74
|
|
|
$
|
182
|
|
|
$
|
539
|
|
|
$
|
437
|
|
|
$
|
30
|
|
|
$
|
72
|
|
Credit Risk-Related Contingent Features
Certain derivative contracts contain credit risk-related contingent features which, when Talen Energy is in a net liability position, would permit the counterparties to require the transfer of additional collateral upon a decrease in the credit ratings of Talen Energy. Most of these features would require the transfer of additional collateral or permit the counterparty to terminate the contract if the applicable credit rating were to fall below investment grade. Some of these features also would allow the counterparty to require additional collateral upon each downgrade in the credit rating at levels that remain above investment grade. In either case, if the credit rating were to fall below investment grade, most of these credit contingent features require either immediate payment of the net liability as a termination payment or immediate and ongoing full collateralization on derivative instruments in net liability positions. Talen Energy's credit rating is currently below investment grade.
Additionally, certain derivative contracts contain credit risk-related contingent features that require adequate assurance of performance be provided if the other party has reasonable concerns regarding the performance of Talen Energy's obligation under the contract. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, amounts disclosed below represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features.
At
September 30, 2016
, the value of derivative contracts in a net liability position that contain credit risk-related contingent features was
$19 million
. Collateral posted on those positions was
$19 million
, and the additional potential collateral requirements, primarily related to further adequate assurance features, were
$9 million
, which is net of receivables and payables already recorded on the Balance Sheet.
15
. Goodwill and Other Asset Impairments
U.S. GAAP requires that a long-lived asset (or asset group) be tested for recoverability whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. Similarly, a goodwill impairment test is performed annually or more frequently if events or changes in circumstances indicate that more likely than not the carrying amount of a reporting unit may be greater than its fair value. During the second quarter of 2015, due to the impairment of its investment in PPL Energy Supply, LLC recorded by PPL (Talen Energy's former parent) at the time of the spinoff, coupled with, and, primarily driven by, Talen Energy Corporation's stock price at the spinoff date, Talen Energy's management concluded that these factors could be indicators of potential impairment with respect to certain long-lived assets and goodwill. After considering additional information, Talen Energy determined that the undiscounted cash flows for potentially affected long-lived assets would not be directly impacted by these factors and therefore concluded that the undiscounted cash flows continued to exceed the carrying value and no further testing of long-lived assets was necessary in the second quarter. Management also performed an interim goodwill impairment assessment as of June 1, 2015, the spinoff and acquisition date. The goodwill impairment analysis is a two-step process. The first step, used to identify potential impairment, is a comparison of the reporting unit's estimated fair value to its carrying value, including goodwill. If the fair value of the reporting unit exceeds its carrying value, applicable goodwill is not considered to be impaired. If the carrying value exceeds the fair value, there is an indication of impairment and the second step is performed to measure the amount of the impairment, if any. The second step requires a company to calculate an implied fair value of goodwill based on a hypothetical purchase price allocation. The East reporting unit, which is equivalent to the East segment continuing operations, failed step one as of June 1, 2015. The step two analysis was not able to be completed by the filing of the second quarter 2015 Form 10-Q. As provided for in the applicable accounting guidance, no goodwill impairment charge was recorded based on management's best estimate at that time, which was confirmed when the second quarter analysis was subsequently completed.
In the third quarter of 2015, Talen Energy updated its fundamental pricing models in conjunction with market information gained as a result of the 2018/2019 planning year PJM capacity auction completed in August 2015. As a result, Talen Energy assessed certain long-lived assets for impairment and determined that the C.P. Crane coal-fired plant failed a recoverability test and as a result, recorded an impairment charge to the East segment based on the plant's estimated fair value at September 30,
2015. Additionally, because the Sapphire plants were classified as held for sale at September 30, 2015 and therefore it was required to be carried at the lower of its current carrying value or fair value less cost to sell, Talen Energy used updated cash flow information to calculate the estimated fair value of the Sapphire plants at September 30, 2015 and recorded an impairment charge to the East segment based on estimated fair value. See Note 13 for additional information on these fair value estimates and the resulting non-cash asset impairment charges. Also, see Notes
8
and
13
for information on non-cash impairment charges recorded in 2016 related to the Bell Bend COLA and the Harquahala plant.
Talen Energy Corporation's stock price declined significantly throughout the third quarter of 2015, indicating a significant change in the financial markets' view of the value of Talen Energy's business and/or the industry in which it operates and potential risks associated with an investment in Talen Energy Corporation's common stock. As a result, Talen Energy management concluded that these factors could be indicators of goodwill impairment and reconsidered certain inputs incorporated in its assessment of fair value of both Talen Energy's overall business and the East reporting unit, where all of the goodwill was assigned. These inputs include risk premiums, growth rates, Talen Energy Corporation's stock price expectations and implied multiples from comparable companies' stock prices. Based on this reassessment, the East reporting unit further declined in fair value, when compared to the value calculated in the second quarter of 2015 and again failed step one as of September 30, 2015. The step two analysis was also completed during the third quarter of 2015 and resulted in a non-cash goodwill impairment charge of
$466 million
pre-tax recorded for the East segment included within "Operating Income (Loss)" in the Statement of Income for the three and nine months ended September 30, 2015. The impairment charge represented all of the goodwill reflected on the Balance Sheet. Most of the impaired goodwill is not deductible for tax purposes and there is no cash tax benefit related to the impairment. To estimate the fair value of Talen Energy's overall business and the East reporting unit, Talen Energy performed an internal analysis using a combination of a market approach using comparable businesses and an income approach based on discounted cash flows. Assumptions used in the discounted cash flow model, in addition to those discussed above, were forward energy and capacity price curves, forecasted generation, and forecasted operation, maintenance and capital expenditures and a market participant discount rate. The market approach primarily applies EBITDA multiples, based on the implied market value of comparable publicly traded companies, to Talen Energy's and the East reporting unit's EBITDA to determine estimated fair values.
16
. Asset Retirement Obligations
The changes in the carrying amounts of Talen Energy's AROs were as follows.
|
|
|
|
|
|
|
|
Balance at December 31, 2015
|
$
|
501
|
|
|
Accretion expense
|
29
|
|
|
Changes in estimate of cash flow or settlement date
|
(9
|
)
|
|
Obligations incurred
|
1
|
|
|
Obligations settled
|
(6
|
)
|
|
Balance at September 30, 2016
|
$
|
516
|
|
Substantially all of the ARO balances are classified as noncurrent at
September 30, 2016
and
December 31, 2015
.
Talen Energy's most significant ARO recorded relates to the decommissioning of the Susquehanna nuclear plant. See Notes
13
and
17
for additional information on the assets in the NDT funds that are legally restricted for the purposes of settling this ARO.
17
. NDT Funds
Securities held by Talen Energy's NDT funds are classified as available-for-sale.
The following table shows the amortized cost, the gross unrealized gains and losses recorded in AOCI and the fair value of Talen Energy's available-for-sale securities.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2016
|
|
December 31, 2015
|
|
|
Amortized
Cost
|
|
Gross
Unrealized
Gains
|
|
Gross
Unrealized
Losses
|
|
Fair Value
|
|
Amortized
Cost
|
|
Gross
Unrealized
Gains
|
|
Gross
Unrealized
Losses
|
|
Fair Value
|
|
NDT funds:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
$
|
5
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
5
|
|
|
$
|
11
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
11
|
|
|
Equity securities
|
316
|
|
|
441
|
|
|
—
|
|
|
757
|
|
|
297
|
|
|
406
|
|
|
—
|
|
|
703
|
|
|
Debt securities
|
236
|
|
|
13
|
|
|
—
|
|
|
249
|
|
|
230
|
|
|
7
|
|
|
—
|
|
|
237
|
|
|
Receivables/payables, net
|
1
|
|
|
—
|
|
|
—
|
|
|
1
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
Total NDT funds
|
$
|
558
|
|
|
$
|
454
|
|
|
$
|
—
|
|
|
$
|
1,012
|
|
|
$
|
538
|
|
|
$
|
413
|
|
|
$
|
—
|
|
|
$
|
951
|
|
See Note
13
for details on the securities held by the NDT funds.
There were
no
securities with credit losses at
September 30, 2016
and
December 31, 2015
.
The following table shows the scheduled maturity dates of debt securities held at
September 30, 2016
.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Maturity
Less Than
1 Year
|
|
Maturity
1-5
Years
|
|
Maturity
6-10
Years
|
|
Maturity
in Excess
of 10 Years
|
|
Total
|
|
Amortized cost
|
$
|
8
|
|
|
$
|
102
|
|
|
$
|
78
|
|
|
$
|
48
|
|
|
$
|
236
|
|
|
Fair value
|
8
|
|
|
105
|
|
|
81
|
|
|
55
|
|
|
249
|
|
The following table shows proceeds from and realized gains and losses on sales of available-for-sale securities for the
periods
ended
September 30
.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Proceeds from sales of NDT securities (a)
|
$
|
29
|
|
|
$
|
43
|
|
|
$
|
121
|
|
|
$
|
143
|
|
|
Gross realized gains (b)
|
11
|
|
|
6
|
|
|
28
|
|
|
19
|
|
|
Gross realized losses (b)
|
6
|
|
|
7
|
|
|
19
|
|
|
16
|
|
|
|
|
|
(a)
|
These proceeds are used to pay income taxes and fees related to managing the trust. Remaining proceeds are reinvested in the trust.
|
|
|
|
|
(b)
|
Excludes the impact of other-than-temporary impairment charges recognized on the Statements of Income.
|
18
. Accumulated Other Comprehensive Income (Loss)
The after-tax changes in Talen Energy's AOCI by component for the periods ended
September 30
were as follows.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Unrealized gains (losses)
|
|
Defined benefit plans
|
|
|
|
|
Available-
for-sale
securities
|
|
Qualifying
derivatives
|
|
Prior
service
costs
|
|
Actuarial
gain
(loss)
|
|
Total
|
|
December 31, 2015
|
$
|
194
|
|
|
$
|
44
|
|
|
$
|
3
|
|
|
$
|
(267
|
)
|
|
$
|
(26
|
)
|
|
Amounts arising during the period
|
24
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
24
|
|
|
Reclassifications from AOCI
|
(4
|
)
|
|
(9
|
)
|
|
—
|
|
|
9
|
|
|
(4
|
)
|
|
Net OCI during the period
|
20
|
|
|
(9
|
)
|
|
—
|
|
|
9
|
|
|
20
|
|
|
September 30, 2016
|
$
|
214
|
|
|
$
|
35
|
|
|
$
|
3
|
|
|
$
|
(258
|
)
|
|
$
|
(6
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2014
|
$
|
202
|
|
|
$
|
63
|
|
|
$
|
7
|
|
|
$
|
(295
|
)
|
|
$
|
(23
|
)
|
|
Amounts arising during the period
|
(21
|
)
|
|
—
|
|
|
(4
|
)
|
|
46
|
|
|
21
|
|
|
Reclassifications from AOCI
|
(1
|
)
|
|
(14
|
)
|
|
(1
|
)
|
|
12
|
|
|
(4
|
)
|
|
Net OCI during the period
|
(22
|
)
|
|
(14
|
)
|
|
(5
|
)
|
|
58
|
|
|
17
|
|
|
September 30, 2015
|
$
|
180
|
|
|
$
|
49
|
|
|
$
|
2
|
|
|
$
|
(237
|
)
|
|
$
|
(6
|
)
|
The following table presents the gains (losses) and related income taxes for reclassifications from Talen Energy's AOCI for the periods ended
September 30
. The defined benefit plan components of AOCI are not reflected in their entirety in the statement of income during the periods; rather, they are included in the computation of net periodic defined benefit costs (credits). See Note
9
for additional information.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
Affected Line Item on the
|
|
Details about AOCI
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Statements of Income
|
|
Available-for-sale securities
|
|
$
|
5
|
|
|
$
|
(1
|
)
|
|
$
|
9
|
|
|
$
|
3
|
|
|
Other Income (Expense) - net
|
|
Income Taxes
|
|
(3
|
)
|
|
—
|
|
|
(5
|
)
|
|
(2
|
)
|
|
|
|
Total After-tax
|
|
2
|
|
|
(1
|
)
|
|
4
|
|
|
1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Qualifying derivatives
|
|
|
|
|
|
|
|
|
|
|
|
Commodity contracts
|
|
(5
|
)
|
|
(3
|
)
|
|
(9
|
)
|
|
(3
|
)
|
|
Wholesale energy
|
|
|
|
7
|
|
|
9
|
|
|
22
|
|
|
25
|
|
|
Fuel and energy purchases
|
|
|
|
1
|
|
|
—
|
|
|
2
|
|
|
1
|
|
|
Other
|
|
Total Pre-tax
|
|
3
|
|
|
6
|
|
|
15
|
|
|
23
|
|
|
|
|
Income Taxes
|
|
(1
|
)
|
|
(2
|
)
|
|
(6
|
)
|
|
(9
|
)
|
|
|
|
Total After-tax
|
|
2
|
|
|
4
|
|
|
9
|
|
|
14
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Defined benefit plans
|
|
|
|
|
|
|
|
|
|
|
|
Prior service costs
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1
|
|
|
|
|
Net actuarial loss
|
|
(4
|
)
|
|
(5
|
)
|
|
(15
|
)
|
|
(20
|
)
|
|
|
|
Total Pre-tax
|
|
(4
|
)
|
|
(5
|
)
|
|
(15
|
)
|
|
(19
|
)
|
|
|
|
Income Taxes
|
|
2
|
|
|
2
|
|
|
6
|
|
|
8
|
|
|
|
|
Total After-tax
|
|
(2
|
)
|
|
(3
|
)
|
|
(9
|
)
|
|
(11
|
)
|
|
|
|
Total reclassifications during the period
|
|
$
|
2
|
|
|
$
|
—
|
|
|
$
|
4
|
|
|
$
|
4
|
|
|
|
19
. New Accounting Guidance Pending Adoption
Accounting for Revenue from Contracts with Customers
In May 2014, the FASB issued accounting guidance that establishes a comprehensive new model for the recognition of revenue from contracts with customers. This model is based on the core principle that revenue should be recognized to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. In March 2016, the FASB issued guidance to clarify the implementation of principal versus agent considerations, and in April 2016, the FASB issued guidance to clarify the identification of performance obligations contained within the original standard.
This guidance can be applied using either a full retrospective or modified retrospective transition method. In August 2015, the FASB issued guidance that defers the effective date of the standard by one year, which for public business entities, results in initial application of this guidance in annual reporting periods beginning after December 15, 2017 and interim periods within those years. Entities may early adopt the guidance as of the original effective date of the standard, which for public business entities is annual reporting periods beginning after December 15, 2016. Talen Energy expects to adopt this guidance effective January 1, 2018.
Talen Energy is currently assessing the impact of adopting this guidance on its consolidated financial statements, as well as the transition method it will use.
Reporting Uncertainties about an Entity's Ability to Continue as a Going Concern
In August 2014, the FASB issued accounting guidance which will require management to assess, for each interim and annual period, whether there are conditions or events that raise substantial doubt about an entity's ability to continue as a going concern. Substantial doubt about an entity's ability to continue as a going concern exists when relevant conditions and events, considered in the aggregate, indicate that it is probable that the entity will be unable to meet its obligations as they become due within one year after the date the financial statements are issued.
When management identifies conditions or events that raise substantial doubt about an entity's ability to continue as a going concern, management is required to disclose information that enables users of the financial statements to understand the principal conditions or events that raised substantial doubt about the entity's ability to continue as a going concern and management's evaluation of the significance of those conditions or events. If substantial doubt about the entity's ability to continue as a going concern has been alleviated as a result of management's plan, the entity should disclose information that allows the users of the financial statements to understand those plans. If the substantial doubt about the entity's ability to continue as a going concern is not alleviated by management's plans, management's plans to mitigate the conditions or events that gave rise to the substantial doubt about the entity's ability to continue as a going concern should be disclosed, as well as a statement that there is substantial doubt the entity's ability to continue as a going concern within one year after the date the financial statements are issued.
This guidance should be applied prospectively within the annual reporting periods ending after December 15, 2016, and for annual periods and interim periods thereafter. Early adoption is permitted.
Talen Energy will adopt this guidance for the annual period ending December 31, 2016 and the adoption of this guidance is not expected to have a significant impact on its consolidated financial statements.
Recognition of Measurement of Financial Assets and Financial Liabilities
In January 2016, the FASB issued accounting guidance that affects the accounting for equity investments, financial liabilities under the fair value option, and the disclosure requirements for financial instruments. This guidance generally requires entities to measure equity investments that are not accounted for under the equity method of accounting and do not result in consolidation at fair value and recognize any changes in fair value in net income. Entities may elect to record equity investments without readily determinable fair values at cost, less impairment, adjusted for observable price changes. The impairment model for equity investments subject to this election is a single-step qualitative assessment performed each quarter. For financial liabilities measured using the fair value option, changes in fair value related to instrument-specific credit risk to be presented separately within OCI.
This guidance should generally be applied prospectively for financial statements issued for fiscal years beginning after December 15, 2017 and interim periods within those fiscal years. Early adoption is generally not permitted, although entities may early adopt the provision related to financial liabilities under the fair value option.
Talen Energy expects to adopt this guidance effective January 1, 2018. Upon adoption, an entity will record a cumulative-effect adjustment to beginning retained earnings as of the beginning of the first reporting period in which the guidance is adopted, with the exception that the amendments related to equity securities with readily determined fair values should be applied prospectively. Talen Energy is currently assessing the impact of adopting this guidance on its consolidated financial statements, which may be significant for equity securities held in the NDT funds.
Accounting for Leases
In February 2016, the FASB issued accounting guidance that updates the accounting for leases. The updated guidance will require lessees to recognize assets and liabilities for the rights and obligations created by their leases with lease terms of more than 12 months. Consistent with current accounting guidance, the recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee primarily will depend on its classification as a finance (similar to the current capital lease) or an operating lease. However, unlike current accounting guidance, which requires only capital leases to be recognized on the balance sheet, the new accounting guidance will require both types of leases to be recognized on the balance sheet.
The new accounting guidance also will require disclosures to help investors and other financial statement users better understand the amount, timing, and uncertainty of cash flows arising from leases. These disclosures include qualitative and quantitative requirements, providing additional information about the amounts recorded in the financial statements.
The accounting by lessors will remain largely unchanged. However, the new accounting guidance contains some targeted improvements that are intended to align, where necessary, lessor accounting with the lessee accounting model and with the updated revenue recognition guidance issued in 2014 and discussed above.
This guidance is effective for annual reporting periods beginning after December 15, 2018 and interim periods within those years. Early application is permitted. In transition, lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes a number of optional practical expedients that entities may elect to apply. These practical expedients relate to the identification and classification of leases that commenced before the effective date, initial direct costs for leases that commenced before the effective date, and the ability to use hindsight in evaluating lessee options to extend or terminate a lease or to purchase the underlying asset. An entity that elects to apply the practical expedients will, in effect, continue to account for leases that commence before the effective date in accordance with previous accounting guidance unless the lease is modified, except that lessees are required to recognize a right-of-use asset and a lease liability for all operating leases at each reporting date based on the present value of the remaining minimum rental payments that were tracked and disclosed under previous accounting guidance.
Talen Energy is currently assessing the impact of adopting this guidance on its consolidated financial statements and expects to adopt this guidance effective January 1, 2019.
Share-Based Payment Accounting
In March 2016, the FASB issued accounting guidance that changes the accounting for certain aspects of share-based payments to employees. This guidance requires the income tax effects of awards to be recognized in the income statement when the awards vest or are settled. For interim reporting purposes, excess tax benefits and tax deficiencies will be accounted for as discrete items in the period in which they occur and are excluded from the estimated annual effective tax rate. These amendments are applied prospectively. Excess tax benefits will be presented as an operating activity on the statement of cash flows, and this amendment can be applied retrospectively or prospectively.
In addition, the requirement that excess tax benefits be realized before companies can recognize them will be eliminated; and this amendment will be applied using a modified retrospective transition method with a cumulative effect adjustment in retained earnings for excess tax benefits that have not previously been recognized. The guidance also requires an assessment of the realizability of any deferred tax assets it records upon adoption as a result of recognizing excess tax benefits and a valuation allowance will be recorded in retained earnings, if necessary.
The guidance will increase the amount an employer can withhold to cover income taxes on awards and still qualify for the liability exception for shares used to satisfy the employer's statutory income tax withholding obligation. The amendments related to outstanding liability awards at the date of adoption will be applied using a modified retrospective transition method, with a cumulative-effect adjustment to retained earnings. Cash paid to a tax authority when shares are withheld to satisfy its statutory income tax withholding obligation will be recorded as a financing activity on the statement of cash flows.
Companies will have to elect how to account for forfeitures of share-based payments by either recognizing forfeitures of awards as they occur or estimating the number of awards expected to be forfeited and adjusting the estimate when it is likely to change, as is currently required. This election is required at the entity level using a modified retrospective transition method, with a cumulative-effect adjustment to retained earnings.
This guidance is effective for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years. Early adoption is permitted. Talen Energy is currently assessing the impact of adopting this guidance on its consolidated financial statements and expects to adopt this guidance effective January 1, 2017.
Accounting for Credit Losses on Financial Instruments
In June 2016, the FASB issued accounting guidance that changes the impairment model for most financial assets and certain other instruments. The standard will replace today's incurred loss approach with an expected loss model for instruments measured at amortized cost and will require allowances for available-for-sale debt securities rather than reduce the carry amount, as they do today under the other-than-temporary impairment model. The guidance will also simplify the accounting model for purchased credit-impaired debt securities and loans.
The new expected credit loss model will apply to most financial assets measured at amortized cost and certain other instruments, including trade and other receivables, loans, held-to-maturity debt securities, net investments in leases and off-balance-sheet credit exposures. The existing loss contingency model will apply to instruments outside the scope of these models. The guidance also eliminates today's accounting model for purchased credit impaired loans and debt securities. Instead, the initial amortized cost for purchased assets will equal the purchase price plus the estimated allowance for credit loss at the date of acquisition.
The new expected credit loss model requires an estimate of expected credit loss to be made and recorded as an allowance. When deducted from the amortized cost basis of the financial asset, it will present the net amount expected to be collected on the financial asset. An expected credit loss estimate should be based on the asset's amortized cost, reflect losses expected over the remaining contractual life, consider available information about collectability of cash flows, and reflect the risk of loss even when remote.
The amendment to the impairment model for available-for-sale debt securities will measure credit losses in a manner similar to current guidance, except that losses will be recognized as allowances rather than reductions in the amortized cost of securities. This will result in a remeasurement of credit losses on available-for-sale debt securities in each reporting period.
This guidance is effective for fiscal years beginning after December 15, 2019, and interim periods therein. The guidance's provisions will be applied as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. Early adoption is permitted for annual periods beginning after December 15, 2018. Talen Energy is currently assessing the impact of adopting this guidance on its consolidated financial statements and expects to adopt this guidance effective January 1, 2020.
Classification of Certain Cash Receipts and Cash Payments
In August 2016, the FASB issued accounting guidance related to how an entity classifies certain cash receipts and cash payments on its statement of cash flows. The guidance clarifies eight specific cash flow presentation issues that have developed due to diversity in practice, including debt prepayment or extinguishment costs; settlement of zero-coupon debt; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance; distributions received from equity method investees; and cash receipts from payments on beneficial interests in securitization transactions; and separately identifiable cash flows and application of the predominance principle.
This guidance is effective for fiscal years beginning after December 15, 2017, and interim periods therein. Early adoption is permitted and the guidance's provisions are required to be applied retrospectively. Talen Energy is currently assessing the impact and timing of adopting this guidance on its consolidated financial statements and expects to adopt this guidance effective January 1, 2018.
Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations
This "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" is separately filed by Talen Energy Corporation and Talen Energy Supply. Any information contained herein relating to an individual registrant is filed by such registrant solely on its own behalf, and neither registrant makes any representation as to information relating to the other registrant except that information relating to Talen Energy Supply and its subsidiaries is also attributed to Talen Energy Corporation and information relating to the subsidiaries of Talen Energy Supply is also attributed to Talen Energy Supply. As Talen Energy Corporation is substantially comprised of Talen Energy Supply and its subsidiaries, most disclosures refer to Talen Energy and are intended to be applicable to both registrants. When identification of a particular entity is considered important to understanding the matter being disclosed, the specific entity's name is used, in particular, for those few disclosures that apply only to Talen Energy Corporation.
Talen Energy Supply is considered the accounting predecessor of Talen Energy Corporation. Therefore, the financial information prior to the June 2015 spinoff presented in this Quarterly Report on Form 10-Q for both registrants includes only legacy Talen Energy Supply information. From June 1, 2015, upon completion of the spinoff and acquisition, Talen Energy Corporation's and Talen Energy Supply's consolidated financial information also includes RJS. As such, Talen Energy Corporation's and Talen Energy Supply's consolidated financial information presented in this Quarterly Report on Form 10-Q for the 2015 periods represents
three and nine
months of legacy Talen Energy Supply information consolidated with three and four months of RJS information from June 1, 2015. See Note 1 in Talen Energy's
2015
Form 10-K for a discussion of the June 2015 spinoff from PPL and formation of Talen Energy.
The following should be read in conjunction with Talen Energy's Condensed Consolidated Financial Statements and accompanying Notes and with Talen Energy's
2015
Form 10-K. Capitalized terms and abbreviations are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted.
Overview
Introduction
Talen Energy is a North American competitive power generation and marketing company headquartered in Allentown, Pennsylvania. Talen Energy produces and sells electricity, capacity and ancillary services from its fleet of power plants totaling approximately 16,000 MW, principally located in the Northeast, Mid-Atlantic and Southwest regions of the U.S.
Business Strategy
Talen Energy seeks to optimize the value from its competitive power generation assets and marketing portfolios while mitigating near-term volatility in both cash flow and earnings metrics. Talen Energy endeavors to accomplish this by matching projected output from its generation assets with forward power sales in the wholesale and retail markets while effectively managing exposure to fuel price volatility, counterparty credit risk and operational risk. Talen Energy is focused on safe, reliable, and resilient operations, disciplined capital investment, portfolio optimization, cost management and the pursuit of value enhancing growth opportunities.
To manage financing costs and access to credit markets, and to fund capital expenditures and growth opportunities, a key objective of Talen Energy is to maintain adequate liquidity capacity. In addition, Talen Energy has a financial risk management policy and operational procedures that, among other things, are designed to monitor and manage exposure to earnings and cash flow volatility related to, as applicable, changes in energy and fuel prices, interest rates, counterparty credit quality and the operating performance of generating units. To manage these risks, Talen Energy generally uses contracts such as forwards, options, swaps and insurance contracts primarily focused on mitigating cash flow volatility within the next 12 month period.
Merger Agreement
On June 2, 2016, Talen Energy Corporation entered into an Agreement and Plan of Merger (the Merger Agreement) with RPH Parent LLC, SPH Parent LLC, CRJ Parent LLC (each, an affiliate of Riverstone, and collectively referred to as "Parent"), and RJS Merger Sub Inc. (a wholly owned subsidiary of Parent referred to as "Merger Sub"), pursuant to which Merger Sub will merge with and into Talen Energy Corporation (the Merger), with Talen Energy Corporation continuing as the surviving corporation on the terms and conditions set forth in the Merger Agreement. On October 6, 2016, the stockholders of Talen Energy Corporation approved the Merger. Talen Energy Corporation currently expects the transaction to be completed by the end of 2016, subject to NRC approval and satisfaction of other customary closing conditions.
At the effective time of the Merger, each share of Talen Energy Corporation common stock outstanding immediately before the effective time of the Merger (excluding shares held by Parent, Merger Sub or certain affiliates of Riverstone and excluding shares pursuant to which dissenting rights under Delaware law have been properly exercised and not withdrawn or lost) will be automatically converted into the right to receive
$14.00
in cash, without interest (the Merger Consideration). In addition, affiliates of Riverstone will convert, at the Effective Time, their existing ownership of approximately
35%
of the issued and outstanding shares of Talen Energy Corporation common stock into shares of the surviving corporation.
The Merger Consideration will be funded by Talen Energy's cash on hand and the proceeds of a new senior secured term loan. The Talen Energy Supply RCF will be reduced from
$1.85 billion
to
$1.4 billion
upon closing of the transaction. See Note 6 for additional information on merger-related financing arrangements.
Consummation of the Merger is conditioned on Talen Energy Corporation's satisfaction or receipt of a waiver of certain requirements of the separation agreement entered into in connection with the spinoff of Talen Energy Corporation from PPL (and certain related transactions), generally requiring the delivery of an IRS ruling or a tax opinion from a tax expert to the effect that the Merger will not jeopardize the intended tax-free treatment of the spinoff and certain related transactions.
Consummation of the Merger is not subject to a financing condition, but is subject to a condition that Talen Energy Corporation has unrestricted cash and cash equivalents and undrawn revolver capacity equal to at least
$350 million
at closing, subject to certain exceptions, and after taking into account
the proceeds of the new senior secured term loan discussed above.
Consummation of the Merger is also subject to the condition that immediately prior to the closing, certain specified defaults and events of default under the Talen Energy Supply RCF shall not have occurred. The Merger Agreement contains certain termination rights, including the right of Talen Energy Corporation to terminate the Merger Agreement to accept a superior proposal, subject to specified limitations, and provides that, upon termination of the Merger Agreement by Talen Energy Corporation or Parent upon specified conditions, Talen Energy Corporation will be required to pay Parent a termination fee of
$50 million
. Upon termination of the Merger Agreement by Talen Energy Corporation or Parent under specified conditions, Parent will be required to pay Talen Energy Corporation a termination fee of
$85 million
.
The Merger Agreement permitted Talen Energy Corporation and its advisors to actively solicit and negotiate alternative acquisition proposals from third parties during a "go-shop" period that began on June 2, 2016 and expired on July 12, 2016. No alternative proposals were received that would constitute a superior proposal under the Merger Agreement. Talen Energy Corporation is now subject to customary "no shop" restrictions prohibiting Talen Energy Corporation, its subsidiaries, directors, officers, employees and other representatives from soliciting alternative proposals from third parties or providing information to or participating in any discussions or negotiations with third parties regarding alternative proposals. These non-solicitation provisions are subject to a "fiduciary out" provision that allows Talen Energy Corporation to provide non-public information and participate in discussions and negotiations with respect to certain unsolicited written acquisition proposals and upon payment of the termination fee to terminate the Merger Agreement and enter into an alternative acquisition agreement if the Board of Directors determines in good faith after consultation with outside legal and financial advisors that such proposal constitutes a superior proposal under the terms of the Merger Agreement.
In connection with entering into the Merger Agreement, the Riverstone Holders entered into a support agreement pursuant to which such parties committed to vote their shares of Talen Energy Corporation common stock in favor of, and take certain other actions in furtherance of, the transactions contemplated by the Merger Agreement, including the Merger.
On June 2, 2016, the subsidiaries that guarantee the Talen Energy Supply RCF agreed to unconditionally guarantee, effective upon the closing of the Merger and the other transactions contemplated by the Merger Agreement, all of Talen Energy Supply's obligations with respect to its
6.5%
Senior Notes due
2025
and Exempt Facilities Revenue Refunding Bonds, Series 2009A, Series 2009B and Series 2009C.
The Merger Agreement and the above summary of certain of its terms have been included to provide information regarding the terms of the Merger Agreement. Factual disclosures about Talen Energy Corporation contained in this report may supplement, update or modify the factual disclosures about Talen Energy Corporation contained in the Merger Agreement. The representations, warranties and covenants made in the Merger Agreement by Talen Energy Corporation, Parent and Merger Sub were qualified and subject to important limitations agreed to by Talen Energy Corporation, Parent and Merger Sub in connection with negotiating the terms of the Merger Agreement. The representations and warranties contained in the Merger Agreement were negotiated with the principal purposes of establishing the circumstances in which a party to the Merger Agreement may have the right not to close the Merger if the representations and warranties of the other party prove to be untrue due to a change in circumstance or otherwise, and allocating risk between the parties to the Merger Agreement, rather than establishing matters as facts. The representations and warranties may also be subject to a contractual standard of materiality different from those generally applicable to stockholders and reports and documents filed with the SEC. Moreover, information concerning the subject matter of the representations and warranties, which do not purport to be accurate as of the date of this
report, (i) is contained, in part, on schedules to the Merger Agreement that have not been filed with the SEC in reliance upon applicable SEC regulations and (ii) may have changed since the date of the Merger Agreement and subsequent developments or new information qualifying a representation or warranty may or may not have been included in this report.
For further information on the Merger, the Merger Agreement, the consent agreement, the support agreement and other Merger-related agreements, please refer to the Current Report on Form 8-K filed on June 6, 2016 and the proxy statement filed on September 2, 2016 by Talen Energy Corporation. The foregoing descriptions of the Merger Agreement, the consent agreement and the support agreement are subject to, and qualified in their entirety by, the full text of those agreements as attached as exhibits to the Form 8-K filed on June 6, 2016, each of which is incorporated by reference herein.
The Merger poses certain risks to Talen Energy during the pendency of the transaction. See "Item 1A. Risk Factors" in Part II of this Form 10-Q for additional information.
Key Performance Measures
In addition to operating income (loss), Talen Energy utilizes Adjusted EBITDA and Margins, both non-GAAP financial measures, as indicators of performance for its business, with Adjusted EBITDA as the primary financial performance measure used by management to evaluate its business and monitor results of operations. Results for the periods ended
September 30
were as follows:
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Three Months
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Nine Months
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2016
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2015
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Change
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2016
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2015
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Change
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Net Income (Loss) - Talen Energy Corporation
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$
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88
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$
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(401
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)
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$
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489
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$
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236
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$
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(279
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)
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$
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515
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Net Income (Loss) - Talen Energy Supply
|
89
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|
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(401
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)
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|
490
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|
|
244
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(279
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)
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523
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Operating Income (Loss) - Talen Energy Corporation
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193
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(346
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)
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539
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552
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(133
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)
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685
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Operating Income (Loss) - Talen Energy Supply
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195
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(346
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)
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541
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565
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(133
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)
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698
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Adjusted EBITDA - Talen Energy
|
247
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357
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(110
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)
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|
614
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765
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(151
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)
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Margins - Talen Energy
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442
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569
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(127
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)
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1,314
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1,408
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(94
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)
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See "Results of Operations" and for a detailed analysis of Talen Energy's results, the definitions of Margins and Adjusted EBITDA and reconciliation of these non-GAAP measures to related GAAP measures.
Executive Summary
For the three months ended September 30, 2016 compared with 2015, net income (loss) and operating income (loss) increased primarily due to the impact of non-recurring, non-cash goodwill and asset impairment charges of $588 million and a coal contract modification charge of $41 million, both pre-tax, that were recorded during the 2015 period, and unrealized gains from hedging activities of $46 million, partially offset by factors that affected Adjusted EBITDA, as described below. Net income (loss) was negatively impacted by the $53 million increase in income tax expense primarily due to higher 2016 pre-tax income resulting from changes in asset impairments mentioned above.
For the three months ended September 30, 2016 compared with 2015, Adjusted EBITDA decreased primarily due to lower margins as described below, partially offset by lower operation and maintenance expenses resulting from reduced non-outage costs at the Susquehanna plant and lower expenses associated with plants sold in 2016 as described below and offset by additional costs associated with the MACH Gen assets acquired in 2015.
The decrease in Margins, a primary driver to changes in the other three earnings measures reflected above, for the three months ended September 30, 2016 compared with 2015, was primarily due to lower realized energy prices and spark spreads of $70 million and lost energy and capacity of $50 million from plants sold in 2016 as described below, and lower capacity prices of $49 million. Offsetting these decreases was $47 million of additional margins from the MACH Gen assets acquired in 2015.
For the nine months ended September 30, 2016 compared with 2015, net income (loss) and operating income (loss) increased primarily due to pre-tax gains of $563 million on plants sold in 2016 as described below, and the impact of pre-tax changes between the periods of non-recurring, non-cash goodwill and asset impairment charges of $377 million, and a coal contract modification charge of $41 million that was recorded in the third quarter of 2015, partially offset by unrealized losses from hedging activities of $71 million, higher depreciation of $71 million driven by assets acquired in 2015, and factors that affected Adjusted EBITDA, as described below.
In addition, net income (loss) for the nine months ended September 30, 2016 compared with 2015 was negatively impacted from higher interest and income tax expenses. Interest expense increased by $34 million partially as a result of the assumption through consolidation of RJS and MACH Gen related debt. Income tax expense increased by $146 million primarily from an increase in 2016 pre-tax income due to changes in impairments in 2016 compared with 2015 and due to net gains from the plants sold in 2016 as described below.
For the nine months ended September 30, 2016 compared with 2015, Adjusted EBITDA decreased primarily due to lower margins as described below and higher operation and maintenance expenses. Operation and maintenance expenses increased primarily due to the RJS and MACH Gen assets acquired in 2015, partially offset by lower expenses associated with plants sold in 2016 as described below.
The decrease in Margins for the nine months ended September 30, 2016 compared with 2015 was due to a $254 million decrease from Talen Energy's legacy assets, partially due to lost energy and capacity from plants sold in 2016 described below of $111 million, lower realized energy prices and spark spreads of $98 million and lower nuclear plant availability of $36 million. Offsetting these decreases was $160 million of additional margins from the RJS and MACH Gen assets acquired in 2015.
The key financial and operational developments that impacted results in 2016 were as follows:
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•
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Merger
Agreement
- In June 2016, Talen Energy Corporation entered into the Merger Agreement. In connection with the Merger:
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▪
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In June 2016, the Antitrust Division of the U.S. Department of Justice and the U.S. Federal Trade Commission granted early termination of the mandatory waiting period under the Hart-Scott Rodino Antitrust Improvements Act of 1976, as amended, expiration or early termination of which was a condition to consummation of the Merger.
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▪
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Merger approvals were received from the New York Public Service Commission in September 2016 and the FERC in October 2016. NRC approval is the final regulatory approval remaining.
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▪
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In October 2016, Talen Energy Corporation's stockholders approved the Merger.
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▪
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Parent and Merger Sub entered into a "best efforts" financing arrangement with lenders to arrange a $600 million senior secured Term Loan B that will be funded substantially concurrently with the closing of the Merger. The arrangement was successfully priced and allocated in October 2016 and is an alternative to a June 2016 commitment obtained. See Note 6 to the Financial Statements for information on merger-related financing arrangements.
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▪
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For the
three and nine
months ended
September 30, 2016
, an insignificant amount and
$15 million
of costs related to the transaction, primarily for investment banking, legal and other professional services, were recorded in "Operation and maintenance" on Talen Energy Corporation's Statement of Income.
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•
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Divestitures of Ironwood, C.P. Crane, Holtwood and Lake Wallenpaupack Power Plants
- In October 2015, Talen Energy announced agreements for the sales of these plants, with an aggregate generating capacity of approximately 1,400 MW, to satisfy a December 2014 FERC order approving the combination of Talen Energy Supply and RJS Power. The sales of the Ironwood and C.P. Crane plants were completed in February 2016 and the Holtwood and Lake Wallenpaupack sale was completed in April 2016. Talen Energy generated $1.5 billion in pre-tax cash proceeds from these sales. Talen Energy used $600 million of these proceeds during the first quarter of
2016
to repay short-term debt. Talen Energy's operating results for the
nine
months ended
September 30, 2016
include net pre-tax gains of $563 million ($338 million after-tax) related to the sales. See Note
8
to the Financial Statements for additional information.
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•
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Bell Bend COLA
- For the nine months ended September 30, 2016, Talen Energy recorded a pre-tax asset impairment charge of $204 million ($122 million after-tax) to fully impair the Bell Bend COLA costs. In September 2016, the NRC accepted Talen Energy's request to withdraw the COLA, while Talen Energy notified the DOE that it has withdrawn its application for a federal loan guarantee for Bell Bend. See Notes
8
and
13
to the Financial Statements for additional information.
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•
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Susquehanna Nuclear Plant
- In October 2016, Unit 2 of the Susquehanna nuclear plant experienced a brief maintenance outage as part of its continuing turbine blade modification and replacement project to address the causes of turbine blade cracking first identified in 2011. Susquehanna has determined the root cause of the issue and is expected to complete the final, permanent modifications on the Unit 2 turbine during the 2017 refueling outage and on the Unit 1 turbine during the 2018 refueling outage.
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•
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Co-firing Projects
- The Brunner Island co-fire project, which allows the units to use either coal or gas to generate electricity with the flexibility to seamlessly change the fuel blend during operation based on market conditions, is progressing. Unit 3 is currently in commercial operation, while Unit 2 is expected to be in commercial operation by the end of 2016 as originally planned. In order to avoid an outage during the winter demand season, Talen Energy has decided to defer completion and commercial operation of Unit 1 until the first half of 2017.
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The Montour co-fire project, announced in June 2016, has an estimated capital cost of approximately $70 million. Talen Energy is currently further evaluating this project to consider the operating experience and results from the Brunner Island Unit 3 co-fire project, and at this time has no timetable for completing the Montour project. Therefore, the Montour project cost has been excluded from forecasted capital expenditures within "Liquidity and Capital Resources - Capital Expenditures." See Note
8
to the Financial Statements for additional information.
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•
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PJM Capacity Auction Results
- In May 2016, PJM completed the Base Residual Auction (BRA) for procuring capacity for the 2019/2020 planning year. Talen Energy cleared 6,994 MW (about 67%) of its total PJM capacity compared with 8,378 MW (about 81%) in the prior BRA for the 2018/2019 planning year. This result was primarily driven by lower than expected clearing prices in zones where the majority of Talen Energy's capacity is located. Based on the auction clearing prices and cleared MW in the auction, Talen Energy expects its PJM capacity revenues to be approximately $257 million for the 2019/2020 planning year. The expected capacity revenues do not include any value for capacity that did not clear either the base or Capacity Performance (CP) products. Any uncleared capacity has the capability to be bid into subsequent incremental auctions or sold to third parties in bilateral transactions. Under the CP construct, uncleared capacity also has the potential to provide additional value as portfolio insurance against unit non-performance or through participation in penalty revenues.
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•
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Electricity and Natural Gas Prices
- During 2016, average delivered prices for electricity continued to trend lower compared with 2015. Average electricity prices declined 20% to 38% for the nine month period across the regions where Talen Energy operates as natural gas prices continued to decline and the regions experienced milder winter weather compared with 2015. Average spot Henry Hub natural gas prices declined during the nine month 2016 period by about 16% compared with 2015. Spot natural gas prices in close proximity to Talen Energy's operations in the Northeastern U.S. declined by almost 50% during the nine month 2016 period compared with 2015.
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•
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Sierra Club Settlement
- In September 2016, the U.S. District Court, District of Montana, Billings Division approved the July 2016 settlement that was reached in the Sierra Club environmental litigation, which includes a commitment to retire Colstrip Units 1 and 2 no later than July 2022. As a result of this agreement, in the third quarter of 2016, Talen Energy updated the useful life of the units, and in future periods, this change is expected to increase depreciation by $6 million annually. See Note
10
to the Financial Statements for additional information.
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Regulatory Matters
Maryland and New Jersey Capacity Matters
In April 2012, the Maryland Public Service Commission ordered three electric utilities in Maryland to enter into long-term contracts to support the construction of new electricity generating facilities in Maryland, the intent of which, Talen Energy believed, was to encourage the construction of new generation even when, under the FERC-approved PJM economic model, such new generation would not be economic. In April 2012, Talen Energy subsidiaries and several other companies filed a complaint in federal court in Maryland challenging the order on the grounds that it violates the Supremacy and Commerce clauses of the U.S. Constitution and requested declaratory and injunctive relief barring implementation of the order by the Maryland PSC Commissioners. Following certain lower court rulings, in April 2016, the U.S. Supreme Court issued a unanimous decision finding that Maryland's program is preempted by the Federal Power Act because it sets an interstate wholesale rate, contravening the Federal Power Act's division of authority between state and federal regulators.
Also in April 2016, the U.S. Supreme Court denied all petitions for certiorari in a similar case in New Jersey. The effect of the denial was to let stand lower court rulings finding that a similar law enacted by New Jersey was unconstitutional under the Supremacy Clause on the grounds that it infringes upon the FERC's exclusive authority to regulate the wholesale sale of electricity in interstate commerce.
See Note
10
to the Financial Statements for background information on these cases.
Ohio
There have been attempts in Ohio by certain companies to have their utilities be permitted to subsidize several uneconomic merchant generation assets owned by non-utility affiliates. Those attempts are being opposed by many generator and consumer interests both in Ohio and at the FERC. In April 2016, the FERC rescinded waivers it granted to certain Ohio companies that allowed them to purchase power from their affiliate generators. The Ohio companies must seek approval from the FERC that the contracts are consistent with the FERC's affiliate regulations before those contracts can be made effective. Additional efforts to oppose on grounds of federal preemption may also be made in Federal Court. If approved and not reversed, out-of-market subsidies could be disruptive to the market signals for competitive generation and threaten the long-term viability of PJM's markets. It is too early to predict the outcome of these efforts to subsidize uneconomic generators in Ohio.
Talen Energy cannot predict the impact that future economic and market conditions and regulatory requirements may have on its financial condition or results of operations.
Other
In June 2016, the FERC issued Order 825 that is expected to improve "Price Formation" in the energy and ancillary service markets by reducing the settlement interval period and triggering shortage pricing in any interval where there is a shortage of energy or operating reserves. Implementation of these changes in PJM is expected to occur as early as February 2018.
Results of Operations
As a result of the RJS Power acquisition on June 1, 2015, results for RJS are included in Talen Energy's results for the
three and nine
months ended
September 30, 2016
with only three and
four
months of comparable amounts in
2015
. As a result of the MACH Gen acquisition on November 2, 2015, results for MACH Gen are included in Talen Energy's results for the
three and nine
months ended
September 30, 2016
with no comparable amounts in
2015
. When discussing Talen Energy's results of operations for
2016
compared with
2015
, when significant, the results of RJS and MACH Gen are isolated for purposes of comparability.
The classification of certain prior period amounts has been changed to conform to the presentation in the
September 30, 2016
financial statements, including, but not limited to, reclassifying the Sapphire plants from discontinued operations to continuing operations. See Note 1 to the Financial Statements for additional information.
Talen Energy is organized in two segments: East and West, based on geographic location. The East segment includes the generating, marketing and trading activities in PJM, NYISO and ISO-NE. The West segment includes the generating, marketing and trading activities located in ERCOT and WECC. In addition, Talen Energy has an "Other" category that primarily includes wages, benefits, services, certain insurance, rent, financing costs incurred primarily at Talen Energy, which have not been allocated or assigned to the segments and inter-company eliminations, and is presented to reconcile segment information to consolidated results.
The discussion within "Statement of Income Analysis" addresses significant changes in principal line items on the Statements of Income comparing the
three and nine
months ended
September 30, 2016
with the same
periods
in
2015
on a GAAP basis. The "Margins" discussion, presented by segment, includes a reconciliation of that non-GAAP financial measure to operating income. The "EBITDA and Adjusted EBITDA" discussion, also presented by segment, includes a reconciliation of those non-GAAP financial measures to operating income and consolidated net income (loss).
The results for interim periods can be disproportionately influenced by numerous factors and developments and by seasonal variations. As such, the results of operations for interim periods do not necessarily indicate results or trends for the year or future periods.
Earnings in future periods are subject to various risks and uncertainties. See "Forward-Looking Information," the rest of this "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" and Note
10
to the Financial Statements in this Form 10-Q and "Item 1. Business" and "Item 1A. Risk Factors" in Talen Energy's
2015
Form 10-K for a discussion of the risks, uncertainties and factors that may impact future earnings.
Statement of Income Analysis, Margins, EBITDA and Adjusted EBITDA
Statement of Income Analysis --
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
Nine Months Ended September 30,
|
|
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
|
Talen Energy Corporation
|
|
|
|
|
|
|
|
|
|
|
|
|
Wholesale energy (a) (b) (c) (d)
|
$
|
893
|
|
|
$
|
887
|
|
|
$
|
6
|
|
|
$
|
2,082
|
|
|
$
|
2,124
|
|
|
$
|
(42
|
)
|
|
Retail energy (a) (b)
|
202
|
|
|
277
|
|
|
(75
|
)
|
|
650
|
|
|
831
|
|
|
(181
|
)
|
|
Energy-related businesses
|
143
|
|
|
156
|
|
|
(13
|
)
|
|
376
|
|
|
404
|
|
|
(28
|
)
|
|
Total operating revenues
|
1,238
|
|
|
1,320
|
|
|
(82
|
)
|
|
3,108
|
|
|
3,359
|
|
|
(251
|
)
|
|
Fuel and energy purchases (a) (b) (c) (e)
|
564
|
|
|
589
|
|
|
(25
|
)
|
|
1,402
|
|
|
1,486
|
|
|
(84
|
)
|
|
Operation and maintenance (c)
|
221
|
|
|
235
|
|
|
(14
|
)
|
|
780
|
|
|
760
|
|
|
20
|
|
|
(Gain) loss on sale
|
—
|
|
|
—
|
|
|
—
|
|
|
(563
|
)
|
|
—
|
|
|
(563
|
)
|
|
Impairments (c)
|
1
|
|
|
588
|
|
|
(587
|
)
|
|
214
|
|
|
591
|
|
|
(377
|
)
|
|
Depreciation
|
112
|
|
|
95
|
|
|
17
|
|
|
330
|
|
|
259
|
|
|
71
|
|
|
Taxes, other than income (c)
|
12
|
|
|
9
|
|
|
3
|
|
|
34
|
|
|
17
|
|
|
17
|
|
|
Energy-related businesses (c)
|
135
|
|
|
150
|
|
|
(15
|
)
|
|
359
|
|
|
379
|
|
|
(20
|
)
|
|
Total operating expenses
|
1,045
|
|
|
1,666
|
|
|
(621
|
)
|
|
2,556
|
|
|
3,492
|
|
|
(936
|
)
|
|
Operating Income (Loss)
|
193
|
|
|
(346
|
)
|
|
539
|
|
|
552
|
|
|
(133
|
)
|
|
685
|
|
|
Other Income (Expense) - net
|
9
|
|
|
1
|
|
|
8
|
|
|
21
|
|
|
11
|
|
|
10
|
|
|
Interest Expense
|
60
|
|
|
55
|
|
|
5
|
|
|
180
|
|
|
146
|
|
|
34
|
|
|
Income Taxes
|
54
|
|
|
1
|
|
|
53
|
|
|
157
|
|
|
11
|
|
|
146
|
|
|
Net Income (Loss)
|
$
|
88
|
|
|
$
|
(401
|
)
|
|
$
|
489
|
|
|
$
|
236
|
|
|
$
|
(279
|
)
|
|
$
|
515
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Talen Energy Supply
|
|
|
|
|
|
|
|
|
|
|
|
|
Wholesale energy (a) (b) (c) (d)
|
$
|
893
|
|
|
$
|
887
|
|
|
$
|
6
|
|
|
$
|
2,082
|
|
|
$
|
2,124
|
|
|
$
|
(42
|
)
|
|
Retail energy (a) (b)
|
202
|
|
|
277
|
|
|
(75
|
)
|
|
650
|
|
|
831
|
|
|
(181
|
)
|
|
Energy-related businesses
|
143
|
|
|
156
|
|
|
(13
|
)
|
|
376
|
|
|
404
|
|
|
(28
|
)
|
|
Total operating revenues
|
1,238
|
|
|
1,320
|
|
|
(82
|
)
|
|
3,108
|
|
|
3,359
|
|
|
(251
|
)
|
|
Fuel and energy purchases (a) (b) (c) (e)
|
564
|
|
|
589
|
|
|
(25
|
)
|
|
1,402
|
|
|
1,486
|
|
|
(84
|
)
|
|
Operation and maintenance (c)
|
219
|
|
|
235
|
|
|
(16
|
)
|
|
767
|
|
|
760
|
|
|
7
|
|
|
(Gain) loss on sale
|
—
|
|
|
—
|
|
|
—
|
|
|
(563
|
)
|
|
—
|
|
|
(563
|
)
|
|
Impairments (c)
|
1
|
|
|
588
|
|
|
(587
|
)
|
|
214
|
|
|
591
|
|
|
(377
|
)
|
|
Depreciation
|
112
|
|
|
95
|
|
|
17
|
|
|
330
|
|
|
259
|
|
|
71
|
|
|
Taxes, other than income (c)
|
12
|
|
|
9
|
|
|
3
|
|
|
34
|
|
|
17
|
|
|
17
|
|
|
Energy-related businesses (c)
|
135
|
|
|
150
|
|
|
(15
|
)
|
|
359
|
|
|
379
|
|
|
(20
|
)
|
|
Total operating expenses
|
1,043
|
|
|
1,666
|
|
|
(623
|
)
|
|
2,543
|
|
|
3,492
|
|
|
(949
|
)
|
|
Operating Income (Loss)
|
195
|
|
|
(346
|
)
|
|
541
|
|
|
565
|
|
|
(133
|
)
|
|
698
|
|
|
Other Income (Expense) - net
|
9
|
|
|
1
|
|
|
8
|
|
|
21
|
|
|
11
|
|
|
10
|
|
|
Interest Expense
|
60
|
|
|
55
|
|
|
5
|
|
|
180
|
|
|
146
|
|
|
34
|
|
|
Income Taxes
|
55
|
|
|
1
|
|
|
54
|
|
|
162
|
|
|
11
|
|
|
151
|
|
|
Net Income (Loss)
|
$
|
89
|
|
|
$
|
(401
|
)
|
|
$
|
490
|
|
|
$
|
244
|
|
|
$
|
(279
|
)
|
|
$
|
523
|
|
|
|
|
|
(a)
|
Includes the impact from energy-related economic activity. See "Commodity Price Risk (Non-trading) - Economic Activity" within Note
14
to the Financial Statements. "Wholesale Energy" also includes unrealized gains (losses) on trading activity of insignificant losses for the three months ended
September 30, 2016
and 2015, and $(8) million and $(35) million for the nine months ended September 30, 2016 and 2015.
|
|
|
|
|
(b)
|
Amounts included in "Margins" and are not discussed separately.
|
|
|
|
|
(c)
|
Amounts for prior years have been reclassified to conform to the current presentation. See Note
1
to the Financial Statements for additional information.
|
|
|
|
|
(d)
|
The three and nine months ended September 30, 215 include a $7 million decrease related to prior periods and the receipt of revenue under a transmission operating agreement with Talen Energy's former affiliate, PPL Electric Utilities Corporation. See Note 1 to the Financial Statements for additional information.
|
|
|
|
|
(e)
|
The 2015 periods include a $41 million charge to reduce contracted coal deliveries. See Note
10
to the Financial Statements for additional information.
|
See below for a discussion of the components of the changes to Net Income (Loss) for the periods. The changes in Net Income (Loss) and Operating Income (Loss) from period to period were, in part, attributable to the acquisitions of RJS Power and
MACH Gen and several items that management believes are not indicative of ongoing operations. See "EBITDA and Adjusted EBITDA" discussion below for information on the items management does not believe are indicative of ongoing operations.
Energy-Related Businesses
Net contributions from energy-related businesses decreased by $8 million for the
nine
months ended
September 30, 2016
compared with
2015
, primarily due to a decrease in construction projects at the mechanical contracting and engineering subsidiaries in 2016.
Operation and Maintenance
The increase (decrease) in operation and maintenance for the
periods
ended
September 30, 2016
compared with
2015
was due to:
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
East segment:
|
|
|
|
|
RJS - Raven and Sapphire (a)
|
$
|
2
|
|
|
$
|
53
|
|
|
MACH Gen - Athens and Millennium (a)
|
4
|
|
|
16
|
|
|
Nuclear (b)
|
(12
|
)
|
|
(16
|
)
|
|
Ironwood, Holtwood and Lake Wallenpaupack (c)
|
(8
|
)
|
|
(19
|
)
|
|
Other
|
(10
|
)
|
|
(8
|
)
|
|
West segment:
|
|
|
|
|
RJS - Jade (a)
|
—
|
|
|
22
|
|
|
MACH Gen - Harquahala (a)
|
8
|
|
|
15
|
|
|
Montana
|
—
|
|
|
(10
|
)
|
|
Other
|
3
|
|
|
5
|
|
|
Other:
|
|
|
|
|
|
TSA costs
|
(6
|
)
|
|
13
|
|
|
Transaction and restructuring costs (d)
|
1
|
|
|
(10
|
)
|
|
Stock-based compensation (e)
|
1
|
|
|
(31
|
)
|
|
Separation benefits (f)
|
3
|
|
|
10
|
|
|
Other (g)
|
(2
|
)
|
|
(33
|
)
|
|
Total Talen Energy Supply
|
$
|
(16
|
)
|
|
$
|
7
|
|
|
Other:
|
|
|
|
|
Merger costs (h)
|
2
|
|
|
13
|
|
|
Total Talen Energy Corporation
|
$
|
(14
|
)
|
|
$
|
20
|
|
|
|
|
|
(a)
|
Amounts are not comparable for the
three and nine
month periods for MACH Gen as it was acquired in November 2015 and for the
nine
month period for RJS as it was acquired in June 2015.
|
|
|
|
|
(b)
|
The decrease for the three and nine month period was primarily due to lower expenses, which were primarily a result of cost reductions.
|
|
|
|
|
(c)
|
Facilities sold in 2016. See Note
8
to the Financial Statements for additional information.
|
|
|
|
|
(d)
|
Costs related to the spinoff transaction, including expenses associated with the FERC-required mitigation and legal and professional fees.
|
|
|
|
|
(e)
|
See Note
1
to the Financial Statements for additional information on acceleration of expense recorded in connection with the spinoff.
|
|
|
|
|
(f)
|
Primarily due to charges under Talen Energy's severance benefits plan recorded in 2016. See Note
9
to the Financial Statements for additional information.
|
|
|
|
|
(g)
|
The decrease for the nine month period was primarily due to lower corporate expenses, which were primarily a result of cost reductions following the spinoff from PPL.
|
|
|
|
|
(h)
|
Primarily represents investment banking, legal and other professional services incurred directly by Talen Energy Corporation. See Note
7
for the Financial Statements for additional information on the Merger.
|
(Gain) loss on sale
(Gain) loss on sale for the
nine
months ended
September 30, 2016
primarily represents the $421 million gain on the sale of the Holtwood and Lake Wallenpaupack hydroelectric facilities and the $148 million gain on the sale of the Ironwood plant. See Note
8
to the Financial Statements for additional information.
Impairments
Impairments for the
nine
months ended
September 30, 2016
primarily includes a $204 million pre-tax charge to fully impair capitalized costs related to the Bell Bend COLA. Impairments for the
three and nine
months ended
September 30, 2015
includes a $466 million goodwill impairment, a $109 million impairment of the Sapphire plants and a $13 million impairment of the C.P. Crane plant. See Notes
8
,
13
and
15
to the Financial Statements for additional information.
Depreciation
The increase (decrease) in depreciation for the
periods
ended
September 30, 2016
compared with
2015
was due to:
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
East segment:
|
|
|
|
|
RJS - Raven and Sapphire (a)
|
$
|
9
|
|
|
$
|
40
|
|
|
MACH Gen - Athens and Millennium (a)
|
11
|
|
|
32
|
|
|
Ironwood, Holtwood and Lake Wallenpaupack (b)
|
(9
|
)
|
|
(26
|
)
|
|
Other
|
2
|
|
|
—
|
|
|
West segment:
|
|
|
|
|
RJS - Jade (a)
|
2
|
|
|
21
|
|
|
Other
|
—
|
|
|
1
|
|
|
Other (c)
|
2
|
|
|
3
|
|
|
Total
|
$
|
17
|
|
|
$
|
71
|
|
|
|
|
|
(a)
|
Amounts are not comparable for the
three and nine
month periods for MACH Gen as it was acquired in November 2015 and for the
nine
month period for RJS as it was acquired in June 2015.
|
|
|
|
|
(b)
|
Facilities sold in 2016. See Note
8
to the Financial Statements for additional information.
|
|
|
|
|
(c)
|
The increase was primarily related to software additions.
|
Taxes, Other Than Income
The increase (decrease) in taxes, other than income for the
periods
ended
September 30, 2016
compared with
2015
was primarily due to the acquisitions of RJS Power and MACH Gen. Periods in 2015 include three and four months of operations for RJS, acquired in June 2015, and no amounts for MACH Gen, acquired in November 2015.
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
East segment:
|
|
|
|
|
RJS - Raven and Sapphire
|
$
|
—
|
|
|
$
|
4
|
|
|
MACH Gen - Athens and Millennium
|
2
|
|
|
5
|
|
|
West segment:
|
|
|
|
|
RJS - Jade
|
—
|
|
|
5
|
|
|
MACH Gen - Harquahala
|
2
|
|
|
5
|
|
|
Total
|
$
|
4
|
|
|
$
|
19
|
|
Other Income (Expense) - net
Other income (expense) - net increased by $8 million and $10 million for the
three and nine
months ended
September 30, 2016
compared with
2015
, primarily due to higher earnings on NDT funds.
Interest Expense
The increase (decrease) in interest expense for the
periods
ended
September 30, 2016
compared with
2015
was due to:
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
Long-term debt interest expense (a)
|
$
|
(10
|
)
|
|
$
|
19
|
|
|
MACH Gen (b)
|
9
|
|
|
28
|
|
|
Short-term debt interest expense
|
2
|
|
|
(3
|
)
|
|
Amortization (c)
|
1
|
|
|
(11
|
)
|
|
Other
|
3
|
|
|
1
|
|
|
Total
|
$
|
5
|
|
|
$
|
34
|
|
|
|
|
|
(a)
|
The decrease for the three month period was due to debt maturities in May 2016 and October 2015. The increase for the nine months period was due to a debt issuance in May 2015 and the assumption of an RJS Power subsidiary's debt in June 2015 in connection with the RJS Power acquisition, partially offset by debt maturities in May 2016 and October 2015. The increase in expense from the RJS Power related debt was $24 million for the nine month period.
|
|
|
|
|
(b)
|
There are no comparable amounts in the 2015 periods as MACH Gen was acquired in November 2015.
|
|
|
|
|
(c)
|
The decrease for the nine month period was due to the write-off of fees in 2015 associated with Talen Energy Supply's $3 billion syndicated credit facility that was terminated in connection with the spinoff.
|
Income Taxes
The increase (decrease) in income taxes for the
periods
ended
September 30, 2016
compared with
2015
was due to:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Talen Energy Corporation
|
|
Talen Energy Supply
|
|
|
Three Months
|
|
Nine Months
|
|
Three Months
|
|
Nine Months
|
|
Change in pre-tax income at current tax rates (a)
|
$
|
27
|
|
|
$
|
129
|
|
|
$
|
28
|
|
|
$
|
135
|
|
|
RJS (b) (c)
|
19
|
|
|
(11
|
)
|
|
19
|
|
|
(11
|
)
|
|
MACH Gen (b)
|
4
|
|
|
(8
|
)
|
|
4
|
|
|
(8
|
)
|
|
State deferred tax rate change (d)
|
—
|
|
|
17
|
|
|
—
|
|
|
17
|
|
|
Federal and state uncertain tax benefits recognized (e)
|
—
|
|
|
12
|
|
|
—
|
|
|
12
|
|
|
Federal and state tax return adjustments (f)
|
5
|
|
|
5
|
|
|
5
|
|
|
5
|
|
|
Other
|
(2
|
)
|
|
2
|
|
|
(2
|
)
|
|
1
|
|
|
Total
|
$
|
53
|
|
|
$
|
146
|
|
|
$
|
54
|
|
|
$
|
151
|
|
|
|
|
|
(a)
|
Excludes income taxes related to RJS and MACH Gen due to timing of the acquisitions as described in (b).
|
|
|
|
|
(b)
|
Amounts are not comparable for the
three and nine
month periods for MACH Gen as it was acquired in November 2015 and for the
nine
month period for RJS as it was acquired in June 2015.
|
|
|
|
|
(c)
|
Includes income taxes related to plant impairments recorded during the three and nine months ended September 30, 2015.
|
|
|
|
|
(d)
|
The nine months ended September 30, 2015, included a tax benefit of $17 million related to state deferred tax liabilities for changes in state apportionment and the impact on the future estimated state income tax rate as a result of the acquisition of RJS Power.
|
|
|
|
|
(e)
|
In 2015, open audits for the years 2008-2011 were settled with the IRS resulting in a tax benefit of $12 million, which was recorded during the nine months ended September 30, 2015.
|
|
|
|
|
(f)
|
The three and nine months ended September 30, 2015, included a tax benefit of $7 million for federal and state return adjustments.
|
See Note 5 for additional information.
Margins
Management utilizes "Margins," a non-GAAP financial measure, as an indicator of performance for its business.
"Margins" is defined as energy revenues offset by the cost of fuel and energy purchases. Management believes this performance measure is relevant due to the volatility in the individual revenue and expense lines on the Statements of Income that comprise "Margins." This volatility stems from a number of factors, including the required netting of certain transactions with ISOs, RTOs and significant fluctuations in unrealized gains and losses. Such factors could result in gains or losses being recorded in either "Wholesale energy," "Retail energy" or "Fuel and energy purchases" on the Statements of Income. "Margins" excludes unrealized (gains) losses on: energy related economic activity, which includes the changes in fair value of positions used to economically hedge a portion of the economic value of the competitive generation assets, full-requirement sales contracts and retail activities; and trading activities. These derivatives are subject to changes in fair value due to market price volatility of the input and output commodities (e.g., fuel and power) prior to the delivery period that was hedged or when realized. Energy related economic activity includes premium amortization associated with options. Unrealized gains and
losses related to derivatives and premium amortization associated with options are deferred and included in "Margins" over the delivery period of the item that was hedged or upon realization.
This measure is not intended to replace "Operating Income (Loss)," which is determined in accordance with GAAP, as an indicator of overall operating performance. Other companies may use different measures to analyze and report their results of operations. Management believes this measure provides additional useful criteria to make investment decisions. This performance measure is used, in conjunction with other information, by senior management to manage Talen Energy's operations and analyze actual results compared with budget.
Reconciliation of Margins
The following tables contain the components from the Statements of Income that are included in Margins and a reconciliation to "Operating Income (Loss)" for the periods ended
September 30
.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
|
2016
|
|
2015
|
|
|
East Segment Margins
|
|
West Segment Margins
|
|
Reconciling Items (a)
|
|
Operating Income (Loss) (b)
|
|
East Segment Margins
|
|
West Segment Margins
|
|
Reconciling Items (a)
|
|
Operating Income (Loss) (b)
|
|
Wholesale energy
|
$
|
656
|
|
|
$
|
169
|
|
|
$
|
68
|
(c)
|
|
$
|
893
|
|
|
$
|
747
|
|
|
$
|
122
|
|
|
$
|
18
|
(c)
|
|
$
|
887
|
|
|
Retail energy
|
179
|
|
|
6
|
|
|
17
|
(c)
|
|
202
|
|
|
261
|
|
|
19
|
|
|
(3
|
) (c)
|
|
277
|
|
|
Fuel and energy purchases
|
449
|
|
|
119
|
|
|
(4
|
) (c)
|
|
564
|
|
|
510
|
|
|
70
|
|
|
9
|
(c)
|
|
589
|
|
|
Other (d)
|
—
|
|
|
—
|
|
|
336
|
|
|
336
|
|
|
—
|
|
|
—
|
|
|
921
|
|
|
921
|
|
|
Total Talen Energy Supply
|
$
|
386
|
|
|
$
|
56
|
|
|
$
|
(247
|
)
|
|
$
|
195
|
|
|
$
|
498
|
|
|
$
|
71
|
|
|
$
|
(915
|
)
|
|
$
|
(346
|
)
|
|
Merger expenses (e)
|
—
|
|
|
—
|
|
|
(2
|
)
|
|
(2
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
Total Talen Energy Corporation
|
$
|
386
|
|
|
$
|
56
|
|
|
$
|
(249
|
)
|
|
$
|
193
|
|
|
$
|
498
|
|
|
$
|
71
|
|
|
$
|
(915
|
)
|
|
$
|
(346
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months
|
|
|
2016
|
|
2015
|
|
|
East Segment Margins
|
|
West Segment Margins
|
|
Reconciling Items (a)
|
|
Operating Income (Loss) (b)
|
|
East Segment Margins
|
|
West Segment Margins
|
|
Reconciling Items (a)
|
|
Operating Income (Loss) (b)
|
|
Wholesale energy
|
$
|
1,858
|
|
|
$
|
294
|
|
|
$
|
(70
|
) (c)
|
|
$
|
2,082
|
|
|
$
|
1,897
|
|
|
$
|
184
|
|
|
$
|
43
|
(c)
|
|
$
|
2,124
|
|
|
Retail energy
|
630
|
|
|
38
|
|
|
(18
|
) (c)
|
|
650
|
|
|
808
|
|
|
56
|
|
|
(33
|
) (c)
|
|
831
|
|
|
Fuel and energy purchases
|
1,263
|
|
|
243
|
|
|
(104
|
) (c)
|
|
1,402
|
|
|
1,408
|
|
|
129
|
|
|
(51
|
) (c)
|
|
1,486
|
|
|
Other (d)
|
—
|
|
|
—
|
|
|
765
|
|
|
765
|
|
|
—
|
|
|
—
|
|
|
1,602
|
|
|
1,602
|
|
|
Total Talen Energy Supply
|
$
|
1,225
|
|
|
$
|
89
|
|
|
$
|
(749
|
)
|
|
$
|
565
|
|
|
$
|
1,297
|
|
|
$
|
111
|
|
|
$
|
(1,541
|
)
|
|
$
|
(133
|
)
|
|
Merger expenses (e)
|
—
|
|
|
—
|
|
|
(13
|
)
|
|
(13
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
Total Talen Energy Corporation
|
$
|
1,225
|
|
|
$
|
89
|
|
|
$
|
(762
|
)
|
|
$
|
552
|
|
|
$
|
1,297
|
|
|
$
|
111
|
|
|
$
|
(1,541
|
)
|
|
$
|
(133
|
)
|
|
|
|
|
(a)
|
Represents amounts excluded from Margins.
|
|
|
|
|
(b)
|
As reported on the Statements of Income.
|
|
|
|
|
(c)
|
Includes unrealized gains (losses) on energy-related economic activity, which is subject to fluctuations in value due to market price volatility.
See "Commodity Price Risk (Non-trading) - Economic Activity" within Note
14
to the Financial Statements. "Wholesale Energy" also includes unrealized gains (losses) on trading activity of insignificant losses for the three months ended
September 30, 2016
and 2015, and $(8) million and $(35) million for the nine months ended September 30, 2016 and 2015. Amounts have been adjusted for option premiums of $3 million and $5 million for the three months ended
September 30, 2016
and
2015
, and $8 million and $14 million for the
nine
months ended
September 30, 2016
and
2015
. The 2015 periods include a $41 million charge recorded to "Fuel and energy purchases" related to reducing contracted coal deliveries. See Note
10
to the Financial Statements for additional information.
|
|
|
|
|
(d)
|
Other includes all Income Statement line items that are fully excluded from Margins, including Operation and maintenance, (Gain) loss on sale, Impairments, Depreciation, Taxes, other than income and Energy-related businesses, net.
|
|
|
|
|
(e)
|
Represents Merger-related transaction costs, primarily investment banking, legal and other professional services incurred directly by Talen Energy Corporation. See Note
7
for the Financial Statements for additional information on the Merger.
|
Changes in Margins
The following table shows Margins by segments, for the periods ended
September 30
as well as the change between the periods. The factors that gave rise to the changes are described following the table. Periods in 2015 include three and four months of operations for the RJS assets, acquired in June 2015, and no amounts for the MACH Gen assets, acquired in November 2015.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
|
East segment
|
$
|
386
|
|
|
$
|
498
|
|
|
$
|
(112
|
)
|
|
$
|
1,225
|
|
|
$
|
1,297
|
|
|
$
|
(72
|
)
|
|
West segment
|
56
|
|
|
71
|
|
|
(15
|
)
|
|
89
|
|
|
111
|
|
|
(22
|
)
|
|
Total
|
$
|
442
|
|
|
$
|
569
|
|
|
$
|
(127
|
)
|
|
$
|
1,314
|
|
|
$
|
1,408
|
|
|
$
|
(94
|
)
|
East Segment
East segment Margins decreased by $112 million for the three month period due to lost energy and capacity revenues from assets sold in 2016 of $50 million, lower capacity prices of $49 million, lower realized energy prices of $29 million, lower spark spreads of $12 million, and lower gas plant availability of $6 million. Partially offsetting these amounts is an increase from the additions of Athens and Millennium of $33 million, as well as higher other portfolio margins of $6 million.
East segment Margins increased for the
nine
month period from the additions of Raven and Sapphire of $93 million, as well as $64 million from the additions of Athens and Millennium.
Excluding the impact of the Raven, Sapphire, Athens, and Millennium acquisitions, East segment Margins decreased by $229 million for the
nine
month period primarily due to lost energy and capacity revenues from assets sold in 2016 of $111 million, lower realized energy prices of $60 million, lower nuclear plant availability of $36 million, lower spark spreads of $20 million, lower capacity prices of $19 million, lower wholesale gas activity of $12 million and lower gas plant availability of $6 million. Partially offsetting these amounts is an increase in retail electric activity of $16 million and full-requirement sales contracts of $14 million.
West Segment
West segment Margins decreased for the three month period due to lower realized energy prices in Texas of $22 million and lower realized energy prices in Montana of $7 million. These amounts were partially offset by additional margins of $14 million from Harquahala acquired in 2015.
West segment Margins decreased for the
nine
month period as the result of a $25 million decrease in Montana due to lower realized energy prices and lower generation. This amount was partially offset by additional margins of $3 million from Harquahala and Jade.
EBITDA and Adjusted EBITDA
In addition to operating income (loss), management utilizes EBITDA and Adjusted EBITDA, which are both non-GAAP financial measures, as indicators of performance for Talen Energy's business, with Adjusted EBITDA as the primary financial performance measure used by management to evaluate its business and monitor results of operations.
EBITDA represents net income (loss) before interest expense, income taxes, depreciation and certain amortization. Adjusted EBITDA represents EBITDA further adjusted for certain non-cash and other items that management believes are not indicative of ongoing operations including, but not limited to, unrealized gains and losses on derivative contracts, stock-based compensation expense, asset retirement obligation accretion (net of gains (losses) on retirements), impairments, gains and losses on securities in the NDT funds, gains or losses on sales, dispositions or retirements of assets, debt extinguishments and transition, transaction and restructuring costs.
EBITDA and Adjusted EBITDA are not intended to represent cash flows from operations, operating income (loss) or net income (loss) as defined by GAAP as indicators of operating performance and are not necessarily comparable to similarly-titled measures reported by other companies. Management cautions investors that amounts presented in accordance with Talen Energy's definitions of EBITDA and Adjusted EBITDA may not be comparable to similar measures disclosed by other companies because not all companies calculate EBITDA and Adjusted EBITDA in the same manner. Talen Energy believes EBITDA and Adjusted EBITDA are useful to investors and other users of these financial statements in evaluating Talen
Energy's operating performance because they provide additional tools to compare business performance across companies and across periods. Talen Energy believes that EBITDA is widely used by investors to measure a company's operating performance without regard to such items as interest expense, income taxes, depreciation and amortization, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired. Additionally, Talen Energy believes that investors commonly adjust EBITDA information to eliminate the effect of restructuring and other expenses, which vary widely from company to company and impair comparability. Talen Energy adjusts for these and other items; as management believes that these items would distort their ability to efficiently view and assess the company's core operating trends. In summary, management primarily uses Adjusted EBITDA as a measure of operating performance to assist in comparing performance from period to period on a consistent basis and to readily view operating trends, as a measure for planning and forecasting overall expectations and for evaluating actual results against such expectations, as a measure of certain corporate financial goals used to determine variable compensation and in communications with the Talen Energy Corporation Board of Directors, senior management, shareholders, creditors, analysts and investors concerning Talen Energy's financial performance.
Reconciliations of EBITDA and Adjusted EBITDA
The table below provides reconciliations of EBITDA and Adjusted EBITDA to operating income (loss) on a segment basis and to net income (loss) on a consolidated basis for the periods ended
September 30
.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
|
2016
|
|
2015
|
|
|
East
|
|
West
|
|
Other
|
|
Talen Energy Supply
|
|
Merger Costs (a)
|
|
Talen Energy Corp
|
|
East
|
|
West
|
|
Other
|
|
Talen Energy
|
|
Net income (loss)
|
|
|
|
|
|
|
$
|
89
|
|
|
$
|
(1
|
)
|
|
$
|
88
|
|
|
|
|
|
|
|
|
$
|
(401
|
)
|
|
Interest expense
|
|
|
|
|
|
|
60
|
|
|
—
|
|
|
60
|
|
|
|
|
|
|
|
|
55
|
|
|
Income taxes
|
|
|
|
|
|
|
55
|
|
|
(1
|
)
|
|
54
|
|
|
|
|
|
|
|
|
1
|
|
|
Other (income) expense - net
|
|
|
|
|
|
|
(9
|
)
|
|
—
|
|
|
(9
|
)
|
|
|
|
|
|
|
|
(1
|
)
|
|
Operating income (loss)
|
$
|
221
|
|
|
$
|
16
|
|
|
$
|
(42
|
)
|
|
$
|
195
|
|
|
$
|
(2
|
)
|
|
$
|
193
|
|
|
$
|
(345
|
)
|
|
$
|
39
|
|
|
$
|
(40
|
)
|
|
$
|
(346
|
)
|
|
Depreciation
|
97
|
|
|
12
|
|
|
3
|
|
|
112
|
|
|
—
|
|
|
112
|
|
|
84
|
|
|
10
|
|
|
1
|
|
|
95
|
|
|
Other income (expense) - net
|
9
|
|
|
—
|
|
|
—
|
|
|
9
|
|
|
—
|
|
|
9
|
|
|
1
|
|
|
—
|
|
|
—
|
|
|
1
|
|
|
EBITDA
|
$
|
327
|
|
|
$
|
28
|
|
|
$
|
(39
|
)
|
|
$
|
316
|
|
|
$
|
(2
|
)
|
|
$
|
314
|
|
|
$
|
(260
|
)
|
|
$
|
49
|
|
|
$
|
(39
|
)
|
|
$
|
(250
|
)
|
|
Margins:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Unrealized (gain) loss on derivative contracts (b)
|
(85
|
)
|
|
(9
|
)
|
|
—
|
|
|
(94
|
)
|
|
—
|
|
|
(94
|
)
|
|
(50
|
)
|
|
—
|
|
|
—
|
|
|
(50
|
)
|
|
Coal contract adjustment (e)
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
41
|
|
|
—
|
|
|
—
|
|
|
41
|
|
|
Other (f)
|
5
|
|
|
—
|
|
|
—
|
|
|
5
|
|
|
—
|
|
|
5
|
|
|
5
|
|
|
—
|
|
|
—
|
|
|
5
|
|
|
Operation and maintenance:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock-based compensation expense (g)
|
—
|
|
|
—
|
|
|
2
|
|
|
2
|
|
|
—
|
|
|
2
|
|
|
—
|
|
|
—
|
|
|
1
|
|
|
1
|
|
|
ARO accretion, net
|
10
|
|
|
1
|
|
|
—
|
|
|
11
|
|
|
—
|
|
|
11
|
|
|
8
|
|
|
—
|
|
|
—
|
|
|
8
|
|
|
Impairments (Notes 13 and 15)
|
—
|
|
|
1
|
|
|
—
|
|
|
1
|
|
|
—
|
|
|
1
|
|
|
588
|
|
|
—
|
|
|
—
|
|
|
588
|
|
|
TSA costs
|
—
|
|
|
—
|
|
|
8
|
|
|
8
|
|
|
—
|
|
|
8
|
|
|
—
|
|
|
—
|
|
|
14
|
|
|
14
|
|
|
Separation benefits (Note 9)
|
—
|
|
|
—
|
|
|
3
|
|
|
3
|
|
|
—
|
|
|
3
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
Transaction and restructuring costs (i)
|
—
|
|
|
—
|
|
|
2
|
|
|
2
|
|
|
2
|
|
|
4
|
|
|
—
|
|
|
—
|
|
|
1
|
|
|
1
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Gain) loss from NDT funds
|
(7
|
)
|
|
—
|
|
|
—
|
|
|
(7
|
)
|
|
—
|
|
|
(7
|
)
|
|
(1
|
)
|
|
—
|
|
|
—
|
|
|
(1
|
)
|
|
Adjusted EBITDA
|
$
|
250
|
|
|
$
|
21
|
|
|
$
|
(24
|
)
|
|
$
|
247
|
|
|
$
|
—
|
|
|
$
|
247
|
|
|
$
|
331
|
|
|
$
|
49
|
|
|
$
|
(23
|
)
|
|
$
|
357
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months
|
|
|
2016
|
|
2015
|
|
|
East
|
|
West
|
|
Other
|
|
Talen Energy Supply
|
|
Merger Costs (a)
|
|
Talen Energy Corp
|
|
East
|
|
West
|
|
Other
|
|
Talen Energy
|
|
Net income (loss)
|
|
|
|
|
|
|
$
|
244
|
|
|
$
|
(8
|
)
|
|
$
|
236
|
|
|
|
|
|
|
|
|
$
|
(279
|
)
|
|
Interest expense
|
|
|
|
|
|
|
180
|
|
|
—
|
|
|
180
|
|
|
|
|
|
|
|
|
146
|
|
|
Income taxes
|
|
|
|
|
|
|
162
|
|
|
(5
|
)
|
|
157
|
|
|
|
|
|
|
|
|
11
|
|
|
Other (income) expense - net
|
|
|
|
|
|
|
(21
|
)
|
|
—
|
|
|
(21
|
)
|
|
|
|
|
|
|
|
(11
|
)
|
|
Operating income (loss)
|
$
|
765
|
|
|
$
|
(64
|
)
|
|
$
|
(136
|
)
|
|
$
|
565
|
|
|
$
|
(13
|
)
|
|
$
|
552
|
|
|
$
|
33
|
|
|
$
|
18
|
|
|
$
|
(184
|
)
|
|
$
|
(133
|
)
|
|
Depreciation
|
289
|
|
|
36
|
|
|
5
|
|
|
330
|
|
|
—
|
|
|
330
|
|
|
243
|
|
|
14
|
|
|
2
|
|
|
259
|
|
|
Other income (expense) - net
|
18
|
|
|
—
|
|
|
3
|
|
|
21
|
|
|
—
|
|
|
21
|
|
|
12
|
|
|
—
|
|
|
(1
|
)
|
|
11
|
|
|
EBITDA
|
$
|
1,072
|
|
|
$
|
(28
|
)
|
|
$
|
(128
|
)
|
|
$
|
916
|
|
|
$
|
(13
|
)
|
|
$
|
903
|
|
|
$
|
288
|
|
|
$
|
32
|
|
|
$
|
(183
|
)
|
|
$
|
137
|
|
|
Margins:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Unrealized (gain) loss on derivative contracts (b)
|
(29
|
)
|
|
3
|
|
|
—
|
|
|
(26
|
)
|
|
—
|
|
|
(26
|
)
|
|
(120
|
)
|
|
17
|
|
|
—
|
|
|
(103
|
)
|
|
Terminated derivative contracts (c)
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(13
|
)
|
|
—
|
|
|
—
|
|
|
(13
|
)
|
|
Revenue adjustment (d)
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
7
|
|
|
—
|
|
|
—
|
|
|
7
|
|
|
Coal contract adjustment (e)
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
41
|
|
|
—
|
|
|
—
|
|
|
41
|
|
|
Other (f)
|
10
|
|
|
—
|
|
|
—
|
|
|
10
|
|
|
—
|
|
|
10
|
|
|
9
|
|
|
—
|
|
|
—
|
|
|
9
|
|
|
Operation and maintenance:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock-based compensation expense (g)
|
—
|
|
|
—
|
|
|
10
|
|
|
10
|
|
|
—
|
|
|
10
|
|
|
—
|
|
|
—
|
|
|
41
|
|
|
41
|
|
|
ARO accretion, net
|
25
|
|
|
2
|
|
|
—
|
|
|
27
|
|
|
—
|
|
|
27
|
|
|
25
|
|
|
—
|
|
|
—
|
|
|
25
|
|
|
Impairments (Notes 13 and 15)
|
204
|
|
|
10
|
|
|
—
|
|
|
214
|
|
|
—
|
|
|
214
|
|
|
591
|
|
|
—
|
|
|
—
|
|
|
591
|
|
|
(Gain) loss on dispositions (Note 8)
|
(563
|
)
|
|
—
|
|
|
—
|
|
|
(563
|
)
|
|
—
|
|
|
(563
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
TSA costs
|
—
|
|
|
—
|
|
|
32
|
|
|
32
|
|
|
—
|
|
|
32
|
|
|
—
|
|
|
—
|
|
|
19
|
|
|
19
|
|
|
Separation benefits (Note 9)
|
—
|
|
|
—
|
|
|
12
|
|
|
12
|
|
|
—
|
|
|
12
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|
2
|
|
|
Corette closure costs (h)
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
4
|
|
|
—
|
|
|
4
|
|
|
Transaction and restructuring costs (i)
|
—
|
|
|
—
|
|
|
6
|
|
|
6
|
|
|
13
|
|
|
19
|
|
|
—
|
|
|
—
|
|
|
16
|
|
|
16
|
|
|
Legal contingency (j)
|
—
|
|
|
4
|
|
|
—
|
|
|
4
|
|
|
—
|
|
|
4
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
Other
|
(8
|
)
|
|
—
|
|
|
—
|
|
|
(8
|
)
|
|
—
|
|
|
(8
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Gain) loss from NDT funds
|
(20
|
)
|
|
—
|
|
|
—
|
|
|
(20
|
)
|
|
—
|
|
|
(20
|
)
|
|
(11
|
)
|
|
—
|
|
|
—
|
|
|
(11
|
)
|
|
Adjusted EBITDA
|
$
|
691
|
|
|
$
|
(9
|
)
|
|
$
|
(68
|
)
|
|
$
|
614
|
|
|
$
|
—
|
|
|
$
|
614
|
|
|
$
|
817
|
|
|
$
|
53
|
|
|
$
|
(105
|
)
|
|
$
|
765
|
|
|
|
|
|
(a)
|
Represents Merger-related transaction costs, primarily investment banking, legal and other professional services incurred directly by Talen Energy Corporation. See Note
7
for the Financial Statements for additional information on the Merger.
|
|
|
|
|
(b)
|
Represents unrealized gains (losses) on derivatives.
See "Commodity Price Risk (Non-trading) - Economic Activity" within Note
14
to the Financial Statements. "Wholesale Energy" also includes unrealized gains (losses) on trading activity of insignificant losses for the three months ended
September 30, 2016
and 2015, and $(8) million and $(35) million for the nine months ended September 30, 2016 and 2015. Amounts have been adjusted for option premiums of $3 million and $5 million for the three months ended
September 30, 2016
and
2015
, and $8 million and $14 million for the
nine
months ended
September 30, 2016
and
2015
.
|
|
|
|
|
(c)
|
Represents net realized gains on certain derivative contracts that were terminated due to the spinoff transaction.
|
|
|
|
|
(d)
|
Related to a prior period revenue adjustment for the receipt of revenue under a transmission operating agreement with Talen Energy Supply's former affiliate, PPL Electric Utilities Corporation. See Note
1
to the Financial Statements for additional information.
|
|
|
|
|
(e)
|
To mitigate the risk of oversupply, Talen Energy incurred pre-tax charges for the three and nine months ended September 30, 2015 to reduce its contracted coal deliveries. See Note
10
to the Financial Statements for additional information.
|
|
|
|
|
(f)
|
Includes OCI amortization on non-active derivative positions.
|
|
|
|
|
(g)
|
For the periods prior to June 2015, represents the portion of PPL's stock-based compensation cost allocable to Talen Energy.
|
|
|
|
|
(h)
|
Operations were suspended and the Corette plant was retired in March 2015.
|
|
|
|
|
(i)
|
Costs related to the spinoff transaction, including expenses associated with FERC-required mitigation and legal and professional fees. Also see "(a)" above.
|
|
|
|
|
(j)
|
Contingency relates to the termination of a gas supply contract. See Note
10
to the Financial Statements for additional information.
|
Changes in Adjusted EBITDA
The following table shows Talen Energy's Adjusted EBITDA by segment for the periods ended
September 30
as well as the change between periods. The factors that gave rise to the changes are described following the table. Periods in 2015 include three and four months of operations for the RJS assets, acquired in June 2015, and no amounts for the MACH Gen assets, acquired in November 2015.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
Nine Months
|
|
|
2016
|
|
2015
|
|
Change
|
|
2016
|
|
2015
|
|
Change
|
|
East
|
$
|
250
|
|
|
$
|
331
|
|
|
$
|
(81
|
)
|
|
$
|
691
|
|
|
$
|
817
|
|
|
$
|
(126
|
)
|
|
West
|
21
|
|
|
49
|
|
|
(28
|
)
|
|
(9
|
)
|
|
53
|
|
|
(62
|
)
|
|
Other
|
(24
|
)
|
|
(23
|
)
|
|
(1
|
)
|
|
(68
|
)
|
|
(105
|
)
|
|
37
|
|
|
Total
|
$
|
247
|
|
|
$
|
357
|
|
|
$
|
(110
|
)
|
|
$
|
614
|
|
|
$
|
765
|
|
|
$
|
(151
|
)
|
East Segment
The decrease for the three month period for the East segment was driven by lower margins, partially offset by lower operation and maintenance expenses. The decrease in margins was primarily due to lost energy and capacity revenue from plants sold in 2016, lower capacity prices, realized energy prices and spark spreads, partially offset by additional margins from the Athens and Millennium operations acquired in 2015. Operation and maintenance expenses decreased partially due to reduced non-outage costs at the Susquehanna plant and lower expenses relating to plants sold in 2016.
The decrease for the nine month period for the East segment was driven by lower margins and higher operation and maintenance expenses. The decrease in margins was primarily due to lost energy and capacity revenues from plants sold in 2016, lower realized energy prices, nuclear plant availability, spark spreads, capacity prices and wholesale gas activity, partially offset by additional margins from the Raven, Sapphire, Athens and Millennium operations acquired in 2015, and increased retail electricity sales and full-requirement sales contracts. Operation and maintenance expenses increased primarily due to the Raven, Sapphire, Athens and Millennium operations acquired in 2015, partially offset by lower expenses relating to plants sold in 2016.
West Segment
The decrease for the three month period for the West segment was driven by lower margins and higher operation and maintenance expenses. The decrease in margins was primarily due to lower realized energy prices at the Jade and Montana operations, partially offset by additional margins from the Harquahala operations acquired in 2015. Operation and maintenance expenses increased primarily from the addition of Harquahala.
The decrease for the nine month period for the West segment was driven by lower margins and higher operation and maintenance expenses. The decrease in margins was primarily due to lower realized energy prices and lower generation at Montana, partially offset by additional margins from Harquahala and Jade operations acquired in 2015. Operation and maintenance expenses increased primarily due to the additions of Jade and Harquahala.
Other
The increase for the nine month periods was primarily due to lower corporate expenses, which were primarily a result of cost reductions following the spinoff from PPL.
See "Margins" and "Statement of Income Analysis" above for a more detailed analysis of the changes.
Financial Condition
Liquidity and Capital Resources
Talen Energy had the following at:
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2016
|
|
December 31, 2015
|
|
Cash and cash equivalents
|
$
|
1,358
|
|
|
$
|
141
|
|
|
Short-term debt (a)
|
350
|
|
|
608
|
|
|
|
|
|
(a)
|
December 31, 2015 includes $108 million related to the New MACH Gen RCF, which at September 30, 2016 is classified as "Long-term debt" on the Balance Sheet based on New MACH Gen's intent to refinance on a long-term basis.
|
Net cash provided by (used in) operating, investing and financing activities for the
nine
months ended
September 30,
and the changes between periods were as follows.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2016
|
|
2015
|
|
Change - Cash Provided (Used)
|
|
Operating activities
|
$
|
549
|
|
|
$
|
731
|
|
|
$
|
(182
|
)
|
|
Investing activities
|
1,219
|
|
|
(173
|
)
|
|
1,392
|
|
|
Financing activities
|
(551
|
)
|
|
(262
|
)
|
|
(289
|
)
|
Operating Activities
The components of the change in cash provided by (used in) operating activities for the
nine
months ended
September 30, 2016
compared with
2015
were as follows.
|
|
|
|
|
|
|
|
|
|
|
|
|
Talen Energy Corporation
|
|
Talen Energy Supply
|
|
Change - Cash Provided (Used)
|
|
|
|
|
Net income (loss)
|
$
|
515
|
|
|
$
|
523
|
|
|
Non-cash components
|
(825
|
)
|
|
(820
|
)
|
|
Working capital
|
81
|
|
|
69
|
|
|
Defined benefit plan funding
|
34
|
|
|
34
|
|
|
Other operating activities
|
13
|
|
|
12
|
|
|
Total
|
$
|
(182
|
)
|
|
$
|
(182
|
)
|
The change in non-cash components primarily resulted from $595 million of net gains from generation assets sold in 2016 and $379 million related to asset impairments, partially offset by a $77 million increase in unrealized losses on hedging and other hedging activities and a $71 million increase in depreciation. The increase in cash from operations from changes in working capital was primarily due to an increase in accounts payable, accrued taxes payable and decreases in fuels, materials and supplies, partially offset by a decrease in counterparty collateral (due in part to market price movement) and increases in accounts receivable and unbilled revenues. The increase in accrued taxes payable is primarily due to higher 2016 taxable income resulting from gains on the aforementioned sales of generation assets. The change in accounts payable was related to decreases that occurred in 2015 due to lower settled values on realized gas hedges, timing of payments and the settlement of PPL affiliated accounts payable in advance of the June 1, 2015 spinoff. The decrease in inventory is related to declines in coal inventory. The increases in accounts receivable are primarily related to decreases in 2015 from the settlement of PPL affiliated accounts receivable in advance of the June 1, 2015 spinoff, while changes in unbilled revenues resulted primarily from decreases in 2015 related to expiring contracts and lower hedging activity.
Investing Activities
The $1.4 billion increase in cash provided by investing activities for the
nine
months ended
September 30, 2016
compared with 2015 primarily reflects $1.5 billion in pre-tax cash proceeds received in 2016 from sale of the Ironwood, Holtwood, Lake Wallenpaupak and C.P. Crane power generation facilities. See Note
8
to the Financial Statements for additional information. Partially offsetting this increase was the $84 million increase in expenditures for property, plant and equipment, primarily from the Brunner Island co-fire project in 2016, from the RJS and MACH Gen plants that were acquired in June and November 2015 and from information technology system projects that are being implemented as a result of the separation from PPL, partially offset by a decrease in 2016 compared to 2015 at Susquehanna primarily due to the timing of fuel purchases.
Financing Activities
The components of the change in cash provided by (used in) financing activities for the
nine
months ended
September 30, 2016
compared with
2015
were as follows.
|
|
|
|
|
|
|
|
|
|
|
|
|
Talen Energy Corporation
|
|
Talen Energy Supply
|
|
Change - Cash Provided (Used)
|
|
|
|
|
Capital contributions from/distributions to predecessor member, net
|
$
|
132
|
|
|
$
|
133
|
|
|
Debt issuances/redemptions, net
|
(962
|
)
|
|
(962
|
)
|
|
Change in revolving credit facilities borrowings, net (a)
|
514
|
|
|
514
|
|
|
Other
|
27
|
|
|
26
|
|
|
Total
|
$
|
(289
|
)
|
|
$
|
(289
|
)
|
|
|
|
|
(a)
|
Includes activity under the New MACH Gen RCF which at
September 30, 2016
is classified as "Long-term debt" on the Balance Sheet.
|
In 2015, Talen Energy made a distribution to its predecessor member prior to the June 2015 spinoff, with no such distributions occurring in 2016. In 2016, Talen Energy used a portion of the proceeds from the February 2016 sales of the Ironwood and C.P. Crane power generation facilities to repay all then outstanding $600 million of short-term borrowings under Talen Energy Supply's RCF and later used borrowings under Talen Energy's Supply's RCF to repay a May 2016 $350 million debt maturity. In 2015, Talen Energy used the proceeds from its May 2015 $600 million debt issuance to repay all then outstanding, $630 million, of short-term borrowings under Talen Energy Supply's RCF.
Talen Energy may from time to time seek to retire or repurchase outstanding debt (including publicly issued debt) through cash purchases and/or exchanges, in open market purchases, privately negotiated transactions, by tender offer or otherwise. Such repurchases or exchanges, if any, will depend on prevailing market conditions, liquidity requirements, contractual restrictions and other factors. The amounts involved may be material.
See Note
6
to the Financial Statements for information on
2016
short and long-term debt activity. See Note 5 in Talen Energy's
2015
Form 10-K for information on
2015
activity. See "Merger Agreement" below for information on the impact of the Merger on future debt issuances and credit facility capacity.
Revolving Credit Facilities
Talen Energy Supply and a subsidiary maintain credit facilities to enhance liquidity and provide credit support. The total committed borrowing capacity under outstanding credit facilities and the use of this borrowing capacity were:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2016
|
|
December 31, 2015
|
|
|
Committed
Capacity
|
|
Borrowed
|
|
Letters of Credit Issued
|
|
Unused
Capacity
|
|
Borrowed
|
|
Letters of Credit Issued
|
|
Unused
Capacity
|
|
Credit facilities
|
$
|
2,010
|
|
|
$
|
455
|
|
|
$
|
227
|
|
|
$
|
1,328
|
|
|
$
|
608
|
|
|
$
|
194
|
|
|
$
|
1,208
|
|
The amounts "Borrowed" are recorded as either "Short-term debt" or "Long-term debt" on the Balance Sheets depending on the facility utilized and management's ability and intent to repay or refinance borrowings.
The Talen Energy Supply RCF provides capacity for revolving cash borrowings and up to $925 million of letters of credit, which in combination cannot exceed the capacity of the facility at any given time. The commitments at
September 30, 2016
under the Talen Energy Supply RCF are provided by a diverse bank group, with no one bank or its affiliates providing an aggregate commitment of more than 8% of the total committed capacity. See "Merger Agreement" below for information on future reduction in the capacity of this facility.
The New MACH Gen RCF provides capacity for revolving cash borrowings and up to $120 million of letters of credit, which in combination cannot exceed the capacity of the facility at any given time.
Other Facilities
Talen Energy Supply is party to a $1.3 billion Amended STF Agreement whereby Talen Energy Supply will receive credit to be applied to satisfy collateral posting obligations related to Talen Energy's energy marketing and trading activities with counterparties participating in the facility.
See Note
6
to the Financial Statements for further discussion of Talen Energy Supply's credit and other agreements.
Merger Agreement
The consideration payable in the Merger with affiliates of Riverstone will be funded by Talen Energy's cash on hand and the proceeds of a new secured term loan. See Note 6 of the Financial Statements for information on merger-related financing arrangements. In accordance with a consent agreement entered into with the administrative agent and lenders under the Talen Energy Supply RCF, the Talen Energy Supply RCF will be reduced from $1.85 billion to $1.4 billion upon closing of the transaction.
Consummation of the Merger is not subject to a financing condition, but is subject to a condition that Talen Energy Corporation has unrestricted cash and cash equivalents and undrawn revolver capacity equal to at least
$350 million
at closing, subject to certain exceptions, and after taking into account
the proceeds of the new senior secured term loan discussed above.
Consummation of the Merger is also subject to the condition that immediately prior to the Merger, certain specified defaults and events of default under the Talen Energy Supply RCF shall not have occurred. See Note
7
of the Financial Statements for additional information.
Long-term Debt
See Note 6 to the Financial Statements for information on Talen Energy Supply's long-term debt activity.
Rating Agencies and Credit Considerations
A credit rating reflects an assessment by the rating agency of the creditworthiness associated with an issuer and particular securities that it issues. The ratings issued by rating agencies are not recommendations to buy, sell or hold any debt securities of Talen Energy, and they are often based in part on information provided by Talen Energy and other sources. Such ratings may be subject to revisions or withdrawal by the agencies at any time and should be evaluated independently of each other and any other rating that may be assigned to the securities. Talen Energy's credit ratings may affect its liquidity, access to capital markets and cost of borrowing.
The following table sets forth the credit ratings issued by Moody's and Standard & Poor's for outstanding debt securities or credit facilities of Talen Energy Supply at:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2016
|
|
December 31, 2015
|
|
|
|
Moody's
|
|
S&P
|
|
Moody's
|
|
S&P
|
|
Senior Unsecured
|
|
B1
|
|
B+
|
|
Ba3
|
|
B+
|
|
Senior Secured
|
|
Baa3
|
|
BB
|
|
Baa2
|
|
BB
|
|
Corporate Issuer Rating
|
|
Ba3
|
|
B+
|
|
Ba2
|
|
B+
|
|
Outlook
|
|
Ratings Under Review
|
|
Stable
|
|
Negative
|
|
Stable
|
In June 2016, following the announcement of the Merger, Moody's placed the ratings of Talen Energy Supply, including its corporate issuer rating, senior secured rating, and the rating on a majority of its senior unsecured debt obligations under review for downgrade. Additionally, the rating of approximately $830 million of Talen Energy Supply's senior unsecured debt was placed under review for upgrade as a result of guarantees that become effective upon the closing of the Merger as described in Note
7
to the Financial Statements. In October 2016, Moody's assigned a Ba1 rating to the $600 million senior secured Term Loan B that is expected to be issued by Talen Energy Supply upon the closing of the Merger. See Note
6
for further discussion of the senior secured Term Loan B.
In June 2016, following the announcement of the Merger, S&P affirmed the ratings of Talen Energy Supply. In October 2016, S&P assigned a BB rating to the $600 million senior secured Term Loan B that is expected to be issued by Talen Energy Supply upon the closing of the Merger. See Note
6
for further discussion of the senior secured Term Loan B.
Various derivative and non-derivative contracts, including contracts for the sale and purchase of electricity and fuel, commodity transportation and storage and interest rate instruments contain provisions that require the posting of additional collateral, or
permit the counterparty to terminate the contract, upon a downgrade in Talen Energy Supply's credit rating. See Note
14
to the Financial Statements for a discussion of "Credit Risk-Related Contingent Features," including a discussion of the potential additional collateral requirements for Talen Energy for derivative contracts in a net liability position at
September 30, 2016
.
Talen Energy has no credit rating triggers that, by themselves, would result in the reduction of access to capital markets or the acceleration of maturity dates of outstanding debt.
Capital Expenditures
The table below shows Talen Energy's current capital expenditure projections for the years
2016
through
2020
.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Projected
|
|
|
|
Total
|
|
2016
|
|
2017
|
|
2018
|
|
2019
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Sustenance
|
|
$
|
1,290
|
|
|
$
|
213
|
|
|
$
|
305
|
|
|
$
|
295
|
|
|
$
|
257
|
|
|
$
|
220
|
|
|
Nuclear fuel
|
|
600
|
|
|
74
|
|
|
114
|
|
|
132
|
|
|
137
|
|
|
143
|
|
|
Growth
|
|
99
|
|
|
97
|
|
|
2
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
Information technology
|
|
120
|
|
|
54
|
|
|
15
|
|
|
20
|
|
|
17
|
|
|
14
|
|
|
Environmental
|
|
137
|
|
|
17
|
|
|
15
|
|
|
16
|
|
|
50
|
|
|
39
|
|
|
Regulatory
|
|
61
|
|
|
26
|
|
|
26
|
|
|
8
|
|
|
1
|
|
|
—
|
|
|
Discretionary
|
|
31
|
|
|
6
|
|
|
6
|
|
|
7
|
|
|
6
|
|
|
6
|
|
|
Total (a) (b)
|
|
$
|
2,338
|
|
|
$
|
487
|
|
|
$
|
483
|
|
|
$
|
478
|
|
|
$
|
468
|
|
|
$
|
422
|
|
|
|
|
|
(a)
|
Does not include the Holtwood and Lake Wallenpaupack hydroelectric projects, the Ironwood natural gas combined-cycle plant, and the C.P. Crane coal-fired power plant, which have been sold. See Note
8
to the Financial Statements for additional information on the divestitures.
|
|
|
|
|
(b)
|
Includes capitalized interest, which over all years, is expected to total approximately $52 million.
|
Capital expenditure plans are revised periodically to reflect changes in operational, market and regulatory conditions. The above table has been revised from what was presented in the
2015
Form 10-K primarily to remove expenditures (including capitalized interest) related to the Bell Bend project. Also, the table excludes the estimated $70 million project cost of the Montour co-fire project announced in June 2016 that is currently being further evaluated. See Note
8
to the Financial Statements for additional information on the Bell Bend COLA and the Montour co-fire project.
Risk Management
Market Risk
See Notes
13
and
14
to the Financial Statements for information about Talen Energy's risk management objectives, valuation techniques and accounting designations.
The forward-looking information presented below provides estimates of what may occur in the future, assuming certain adverse market conditions and model assumptions. Actual future results may differ materially from those presented. These disclosures are not precise indicators of expected future losses, but only indicators of possible losses under normal market conditions at a given confidence level.
Commodity Price Risk (Non-trading)
Talen Energy's non-trading activity includes economic hedge transactions that address a specific risk. This activity includes the changes in fair value of positions used to hedge a portion of the economic value of Talen Energy's competitive generation assets and full-requirement sales and retail contracts. This economic activity is subject to changes in fair value due to market price volatility of the input and output commodities (e.g., fuel and power). See Note
14
to the Financial Statements for additional information.
To hedge the impact of market price volatility on Talen Energy's energy-related assets, liabilities and other contractual arrangements, Talen Energy subsidiaries both sell and purchase physical energy at the wholesale level under FERC market-based tariffs throughout the U.S. and enter into financial exchange-traded and over-the-counter contracts. Talen Energy's non-trading commodity derivative contracts range in maturity through
2020
.
The following table sets forth the changes in the net fair value of non-trading commodity derivative contracts for the periods ended
September 30
. See Notes
13
and
14
to the Financial Statements for additional information.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gains (Losses)
|
|
|
Three Months
|
|
Nine Months
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Fair value of contracts outstanding at the beginning of the period
|
$
|
57
|
|
|
$
|
61
|
|
|
$
|
144
|
|
|
$
|
53
|
|
|
Contracts realized or otherwise settled during the period
|
(31
|
)
|
|
(71
|
)
|
|
(235
|
)
|
|
(8
|
)
|
|
Fair value of new contracts entered into during the period (a)
|
(2
|
)
|
|
(3
|
)
|
|
(31
|
)
|
|
11
|
|
|
Other changes in fair value
|
121
|
|
|
119
|
|
|
267
|
|
|
50
|
|
|
Fair value of contracts outstanding at the end of the period
|
$
|
145
|
|
|
$
|
106
|
|
|
$
|
145
|
|
|
$
|
106
|
|
|
|
|
|
(a)
|
Represents the fair value of contracts at the end of the quarter of their inception. 2015 includes the impact of contracts acquired as part of the RJS Power acquisition.
|
The following table segregates the net fair value of non-trading commodity derivative contracts at
September 30, 2016
, based on the observability of the information used to determine the fair value.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Asset (Liability)
|
|
|
Maturity
Less Than
1 Year
|
|
Maturity
1-3 Years
|
|
Maturity
4-5 Years
|
|
Maturity in Excess
of 5 Years
|
|
Total Fair
Value
|
|
Source of Fair Value
|
|
|
|
|
|
|
|
|
|
|
Prices based on significant observable inputs (Level 2)
|
$
|
48
|
|
|
$
|
55
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
103
|
|
|
Prices based on significant unobservable inputs (Level 3)
|
25
|
|
|
17
|
|
|
—
|
|
|
—
|
|
|
42
|
|
|
Fair value of contracts outstanding at the end of the period
|
$
|
73
|
|
|
$
|
72
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
145
|
|
Talen Energy subsidiaries sell electricity, capacity and related services and buy fuel on a forward basis to hedge the value of energy from Talen Energy's generation assets. If these Talen Energy subsidiaries were unable to deliver firm capacity and energy or to accept the delivery of fuel under their agreements, under certain circumstances they could be required to pay liquidated damages. These damages would be based on the difference between the market price and the contract price of the commodity. Depending on price changes in the wholesale energy markets, such damages could be significant. Extreme weather conditions, unplanned power plant outages, transmission disruptions, nonperformance by counterparties (or their counterparties) with which it has energy contracts and other factors could affect Talen Energy's ability to meet its obligations, or cause significant increases in the market price of replacement energy. Although Talen Energy attempts to mitigate these risks, it cannot be assured that it will be able to fully meet its firm obligations, that it will not be required to pay damages for failure to perform, or that it will not experience counterparty nonperformance in the future.
Commodity Price Risk (Trading)
Talen Energy's trading commodity derivative contracts range in maturity through
2019
. The following table sets forth changes in the net fair value of trading commodity derivative contracts for the periods ended
September 30
. See Notes
13
and
14
to the Financial Statements for additional information.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gains (Losses)
|
|
|
Three Months
|
|
Nine Months
|
|
|
2016
|
|
2015
|
|
2016
|
|
2015
|
|
Fair value of contracts outstanding at the beginning of the period
|
$
|
5
|
|
|
$
|
14
|
|
|
$
|
9
|
|
|
$
|
48
|
|
|
Contracts realized or otherwise settled during the period
|
(7
|
)
|
|
(5
|
)
|
|
(19
|
)
|
|
(64
|
)
|
|
Fair value of new contracts entered into during the period (a)
|
1
|
|
|
2
|
|
|
4
|
|
|
3
|
|
|
Other changes in fair value
|
2
|
|
|
1
|
|
|
7
|
|
|
25
|
|
|
Fair value of contracts outstanding at the end of the period
|
$
|
1
|
|
|
$
|
12
|
|
|
$
|
1
|
|
|
$
|
12
|
|
|
|
|
|
(a)
|
Represents the fair value of contracts at the end of the quarter of their inception.
|
The following table segregates the net fair value of trading commodity derivative contracts at
September 30, 2016
, based on the observability of the information used to determine the fair value.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Asset (Liability)
|
|
|
Maturity
Less Than
1 Year
|
|
Maturity
1-3 Years
|
|
Maturity
4-5 Years
|
|
Maturity
in Excess
of 5 Years
|
|
Total Fair
Value
|
|
Source of Fair Value
|
|
|
|
|
|
|
|
|
|
|
Prices based on significant observable inputs (Level 2)
|
$
|
3
|
|
|
$
|
(3
|
)
|
|
$
|
(1
|
)
|
|
$
|
—
|
|
|
$
|
(1
|
)
|
|
Prices based on significant unobservable inputs (Level 3)
|
2
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|
Fair value of contracts outstanding at the end of the period
|
$
|
5
|
|
|
$
|
(3
|
)
|
|
$
|
(1
|
)
|
|
$
|
—
|
|
|
$
|
1
|
|
VaR Models
A VaR model is utilized to measure commodity price risk in margins for the non-trading and trading portfolios. VaR is a statistical model that attempts to estimate the value of potential loss over a given holding period under normal market conditions at a given confidence level. VaR is calculated using a Monte Carlo simulation technique based on a five-day holding period at a 95% confidence level. Given Talen Energy's disciplined hedging program, the non-trading VaR exposure is expected to be limited in the short-term. The VaR for portfolios using end-of-month results for the
nine
months ended
September 30, 2016
was as follows.
|
|
|
|
|
|
|
|
|
|
|
|
|
Trading VaR
|
|
Non-Trading VaR
|
|
95% Confidence Level, Five-Day Holding Period
|
|
|
|
|
Period End
|
$
|
—
|
|
|
$
|
14
|
|
|
Average for the Period
|
—
|
|
|
18
|
|
|
High
|
—
|
|
|
31
|
|
|
Low
|
—
|
|
|
14
|
|
The trading portfolio includes all proprietary trading positions, regardless of the delivery period. All positions not considered proprietary trading are considered non-trading. The non-trading portfolio includes the entire portfolio, including generation, with delivery periods through the next 12 months. Both the trading and non-trading VaR computations exclude FTRs due to the absence of reliable spot and forward markets. The fair value of the non-trading and trading FTR positions was insignificant
at
September 30, 2016
.
Interest Rate Risk
Talen Energy, directly or through its subsidiaries, may issue debt to finance its operations, which would expose it to interest rate risk. Talen Energy may utilize various financial derivative instruments to adjust the mix of fixed and floating interest rates in its debt portfolio, adjust the duration of its debt portfolio and lock in components of current market interest rates in anticipation of future financing, when appropriate. Risk limits under the risk management policy are designed to mitigate interest rate exposure and volatility in interest expense.
Talen Energy had no interest rate hedges outstanding at
September 30, 2016
.
Talen Energy is exposed to a potential increase in interest expense and to changes in the fair value of its debt portfolio. The estimated impact of a 10% adverse movement in interest rates at
September 30, 2016
would cause an insignificant increase in interest expense and a $99 million increase in the fair value of debt.
NDT Funds - Securities Price Risk
In connection with certain NRC requirements, Susquehanna Nuclear maintains trust funds to fund certain costs of decommissioning the Susquehanna Nuclear plant. At
September 30, 2016
, these funds were invested primarily in domestic equity securities and fixed-rate, fixed-income securities and are reflected at fair value on the balance sheet. The mix of securities is designed to provide returns sufficient to fund Susquehanna Nuclear's decommissioning and to compensate for inflationary increases in decommissioning costs. However, the equity securities included in the trusts are exposed to price fluctuation in equity markets, and the values of fixed-rate, fixed-income securities are primarily exposed to changes in interest rates. Talen Energy actively monitors the investment performance and periodically reviews asset allocation in accordance with its nuclear decommissioning trust policy statement. At
September 30, 2016
, a hypothetical 10% increase in interest rates and a
10% decrease in equity prices would have resulted in an estimated $78 million reduction in the fair value of the trust assets. See Notes
13
and
17
to the Financial Statements for additional information regarding the NDT funds.
Credit Risk
See Notes
13
and
14
to the Financial Statements and "Risk Management - Credit Risk" in Talen Energy's
2015
Form 10-K for additional information.
Acquisitions, Development and Divestitures
Talen Energy from time to time evaluates opportunities for potential acquisitions, divestitures and development projects. Development projects are reexamined periodically based on market conditions and other factors to determine whether to proceed with the projects, sell, cancel or expand them, execute tolling agreements or pursue other options. See Note
8
to the Financial Statements for information on the acquisitions of MACH Gen and RJS Power, the divestitures of the Ironwood, Holtwood, Lake Wallenpaupack and C.P. Crane power plants and the developments regarding the Bell Bend COLA and the Brunner Island and Montour co-firing projects.
Environmental Matters
The following is a discussion of the more significant environmental matters impacting Talen Energy's business this fiscal year. See "Item 1. Business" in Talen Energy's
2015
Form 10-K for additional information on environmental matters.
CSAPR
Annual and seasonal nitrogen oxide emission allowance trading programs, as well as annual sulfur dioxide emission allowance trading, commenced in 2015 for 28 states under the EPA's CSAPR Rule. In September 2016, the EPA finalized an update to its CSAPR Rule to address the 2008 ozone NAAQS. The "CSAPR Update Rule" establishes more stringent ozone season nitrogen oxide budgets for 22 states, including several where Talen Energy owns generation. Additional capital and/or operation and maintenance expenses (including the purchase of additional allowances), could be imposed on Talen Energy plants in Maryland, New Jersey, New York, Pennsylvania and Texas as a result of this action. At this time, Talen Energy does not expect this matter will have a material impact on Talen Energy's results of operation or financial condition.
NAAQS
The Connecticut Department of Energy & Environmental Protection and the Delaware Department of Natural Resources and Environmental Control recently petitioned the EPA to find that emissions from the Brunner Island plant are significantly contributing to the nonattainment of the 2008 and/or 2015 eight-hour NAAQS for ozone in their respective states. The EPA extended the deadline to respond to both petitions to January and March of 2017, respectively. If the EPA grants either petition, and finds that Brunner Island has significantly contributed to nonattainment or interfered with maintenance of a NAAQS in either state, Talen Energy could be required to cease operations at Brunner Island within three months of such finding or comply with EPA-imposed emission limits. Talen Energy is evaluating the above petitions and cannot predict at this time, whether either of them will be granted or denied by the EPA or the impact, if any, on Talen Energy's financial condition or operations.
Pertaining to the EPA's 2010 NAAQS for sulfur dioxide, the EPA and the Sierra Club entered into an approved consent decree in March, 2015 that establishes deadlines for remaining area designations. Several of Talen's affected plants are in undesignated areas and various actions occurred in the third quarter of 2016 to advance these characterizations including the EPA's final designation of the area around Brandon Shores and Wagner as non-attainment. Compliance with regulations or site-specific obligations, that could be developed to address the standard, could lead to increased capital and/or operation and maintenance expenses for some of Talen Energy's coal plants.
Regional Haze
The EPA's regional haze programs were developed under the Clean Air Act to eliminate man-made visibility degradation by 2064. Under the programs, states are required to make reasonable progress every decade, through the application of, among other things, Best Available Retrofit Technology on power plants commissioned between 1962 and 1977. The primary power plant emissions affecting visibility are sulfur dioxide, nitrogen oxides and particulates. While the focus of regional haze regulation has been on the western U.S., in December 2015, a final federal implementation plan for Texas was released with an emphasis on coal plants. That rule was stayed by the U.S. Courts of Appeals for the 5th Circuit in July 2016.
GHG Regulations
The EPA's final rules for new and existing power plants were published in the Federal Register in October 2015, along with a proposed federal implementation plan for those states that fail to submit an acceptable state implementation plan for the existing plant rule. The EPA's existing plant rule was stayed by the U.S. Supreme Court in the first quarter of 2016 pending the outcome of other legal challenges to the rule. The new plant rule remains in effect and challenges are also outstanding in federal court. The D.C. Circuit heard oral arguments on challenges to the merits of the EPA's rule in September 2016. Talen Energy is unable to determine if the rules will have a material adverse effect on Talen Energy's financial condition or results of operations, but increased capital and operation and maintenance costs could be imposed.
New Accounting Guidance
See Notes
2
and
19
to the Financial Statements for a discussion of new accounting guidance adopted and pending adoption.
Application of Critical Accounting Policies
Financial condition and results of operations are impacted by the methods, assumptions and estimates used in the application of critical accounting policies. Certain accounting policies are particularly important to an understanding of the reported financial condition or results of operations, and require management to make estimates or other judgments of matters that are inherently uncertain, including policies for defined benefits, income taxes, asset impairments (excluding investments), AROs, business combinations and price risk management.
See "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations," in Talen Energy's
2015
Form 10-K for a discussion of each critical accounting policy.
TALEN ENERGY CORPORATION
TALEN ENERGY SUPPLY, LLC