Attached files
file | filename |
---|---|
8-K - FORM 8-K - Talen Energy Corp | d22473d8k.htm |
Exhibit 99.1
Year ended December 31, 2014 compared to year ended December 31, 2013 and year ended December 31, 2013 compared to year ended December 31, 2012.
The discussion for Talen Energy Supply includes Statement of Income Analysis. The Margins discussion includes a reconciliation of a non-GAAP financial measure to Operating Income and Statement of Income Analysis and addresses significant changes in principal line items on the Statements of Income comparing year-to-year changes. The EBITDA and Adjusted EBITDA discussion, also presented by segment, includes a reconciliation of the non-GAAP financial measures to operating income and consolidated net income.
Statement of Income Analysis, Margins, EBITDA and Adjusted EBITDA
Statement of Income Analysis
Net Income Attributable to Talen Energy Supply Member includes the following results.
$ Change | ||||||||||||||||||||
2014 | 2013 | 2012 | 2014 vs. 2013 | 2013 vs. 2012 | ||||||||||||||||
Unregulated wholesale energy (a) |
$ | 1,808 | $ | 2,909 | $ | 3,976 | $ | (1,101 | ) | $ | (1,067 | ) | ||||||||
Unregulated wholesale energy to affiliate |
84 | 51 | 78 | 33 | (27 | ) | ||||||||||||||
Unregulated retail energy (a) |
1,243 | 1,027 | 844 | 216 | 183 | |||||||||||||||
Energy-related businesses |
601 | 527 | 448 | 74 | 79 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||
Total operating revenues |
3,736 | 4,514 | 5,346 | (778 | ) | (832 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||
Fuel (a) |
1,196 | 1,049 | 965 | 147 | 84 | |||||||||||||||
Energy Purchases (a) |
209 | 1,171 | 1,821 | (962 | ) | (650 | ) | |||||||||||||
Other operation and maintenance |
1,007 | 1,026 | 997 | (19 | ) | 29 | ||||||||||||||
Loss on lease termination (b) |
| 697 | | (697 | ) | 697 | ||||||||||||||
Depreciation |
297 | 299 | 272 | (2 | ) | 27 | ||||||||||||||
Taxes, other than income |
57 | 53 | 55 | 4 | (2 | ) | ||||||||||||||
Energy-related businesses |
573 | 512 | 432 | 61 | 80 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||
Total operating expenses |
3,339 | 4,807 | 4,542 | (1,468 | ) | 265 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||
Operating Income (Loss) |
397 | (293 | ) | 804 | 690 | (1,097 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||
Other Income (Expense) - net |
30 | 32 | 19 | (2 | ) | 13 | ||||||||||||||
Interest Expense |
124 | 159 | 158 | (35 | ) | 1 | ||||||||||||||
Income Taxes |
116 | (159 | ) | 236 | 275 | (395 | ) | |||||||||||||
Income (Loss) from Discontinued Operations (b) |
223 | 32 | 46 | 191 | (14 | ) | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||
Net Income |
410 | (229 | ) | 475 | 639 | (704 | ) | |||||||||||||
Net Income Attributable to Noncontrolling Interests |
1 | 1 | (1 | ) | ||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||
Net Income Attributable to Talen Energy Supply Member |
$ | 410 | $ | (230 | ) | $ | 474 | $ | 640 | $ | (704 | ) | ||||||||
|
|
|
|
|
|
|
|
|
|
(a) | Includes the impact from energy-related economic activity. See Commodity Price Risk (Non-trading) - Economic Activity in Note 13 to the audited consolidated financial statements of Talen Energy Supply for additional information. |
(b) | See Note 4 to the audited consolidated financial statements of Talen Energy Supply 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 several items that management believes are not indicative of ongoing operations. See the EBITDA and Adjusted EBITDA discussion below for information on these items.
Certain Operating Revenues and Expenses Included in Margins
The following Statement of Income line items to the unaudited condensed consolidated financial statement of Talen Energy Supply are included above within Margins and are not discussed separately.
2014 vs. 2013 | 2013 vs. 2012 | |||||||
Unregulated wholesale energy |
$ | (1,101 | ) | $ | (1,067 | ) | ||
Unregulated wholesale energy to affiliate |
33 | (27 | ) | |||||
Unregulated retail energy |
216 | 183 | ||||||
Fuel |
147 | 84 | ||||||
Energy purchases |
(962 | ) | (650 | ) |
1
Energy-Related Businesses
Net contributions from energy-related businesses increased by $13 million in 2014 compared with 2013. During 2014, Talen Energy Supply recorded a $17 million increase to Energy-related businesses revenues on the Statement of Income related to prior periods and the timing of revenue recognition for a mechanical contracting and engineering subsidiary. See Note 1 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information.
Talen Energy Supply is presently considering divesting its mechanical contracting subsidiaries. See Managements Discussion and Analysis of Financial Condition and Results of OperationsOverviewOther Financial and Operational DevelopmentsMechanical Contracting Subsidiaries and Renewable Energy Business.
Other Operation and Maintenance
The increase (decrease) in other operation and maintenance was due to:
2014 vs. 2013 | 2013 vs. 2012 | |||||||
Fossil and hydroelectric plants (a) |
$ | (78 | ) | $ | 41 | |||
Susquehanna Nuclear (b) |
28 | (3 | ) | |||||
Talen Energy Marketing (c) |
1 | (18 | ) | |||||
Bargaining unit one-time voluntary retirement benefits (Note 9) |
17 | |||||||
Separation benefits related to spinoff of Talen Energy Supply (Note 4) |
16 | |||||||
Other |
(3 | ) | 9 | |||||
|
|
|
|
|||||
Total |
$ | (19 | ) | $ | 29 | |||
|
|
|
|
(a) | The decrease in 2014 compared with 2013 was primarily due to a $65 million impairment charge in 2013 related to the Corette plant and the elimination of $20 million of rent expense associated with the Colstrip lease which was terminated in December 2013. The increase in 2013 compared with 2012 was primarily due to the $65 million impairment charge in 2013 related to the Corette plant, partially offset by lower fossil and hydroelectric expenses of $24 million, largely driven by lower outage expenses in 2013. See Note 12 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information on the Corette plant impairment. |
(b) | The increase in 2014 compared with 2013 was primarily due to project expenses, including refueling outage expenses. |
(c) | The decrease in 2013 compared with 2012 was primarily due to SMGT filing under Chapter 11 of the U.S. Bankruptcy Code. $11 million of receivables billed to SMGT were fully reserved in 2012. |
Loss on Lease Termination
A $697 million charge was recorded in 2013 for the termination of the Colstrip operating lease to facilitate the sale of the Montana hydroelectric generating facilities. See Note 4 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information.
Depreciation
Depreciation decreased by $2 million in 2014 compared with 2013, primarily due to decreases of $15 million from the impairment recorded at Talen Montana for the Corette plant and the write-down of assets in conjunction with the termination of the operating lease at the Colstrip facility, both of which occurred in 2013. These decreases were partially offset by increases of $13 million from PP&E additions in part due to the completed Holtwood project in 2013. See Notes 4 and 12 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for information on the Colstrip operating lease termination and the Corette impairment, respectively.
Depreciation increased by $27 million in 2013 compared with 2012, primarily due to net PP&E additions.
2
Taxes, Other Than Income
Taxes, other than income increased by $4 million in 2014 compared with 2013 due to an $8 million increase in state gross receipts tax offset by a $4 million increase in state capital stock tax.
Other Income (Expense)net
Other income (expense)net decreased by $2 million in 2014 compared with 2013 and increased by $13 million in 2013 compared with 2012. The decrease in 2014 compared with 2013 resulted from 2013 including a gain of $8 million related to adjustments to liabilities for a former mining subsidiary of Talen Energy Supply partially offset by a $5 million increase in 2014 in net earnings on NDT funds. The increase in 2013 compared with 2012 primarily related to the former mining subsidiarys gains discussed above.
Interest Expense
The increase (decrease) in interest expense was due to:
2014 vs. 2013 | 2013 vs. 2012 | |||||||
Long-term debt interest expense (a) |
$ | (50 | ) | $ | 1 | |||
Short-term debt interest expense |
7 | (2 | ) | |||||
Capitalized interest (b) |
14 | 2 | ||||||
Net amortization of debt discounts, premiums and issuance costs |
(4 | ) | (1 | ) | ||||
Other |
(2 | ) | 1 | |||||
|
|
|
|
|||||
Total |
$ | (35 | ) | $ | 1 | |||
|
|
|
|
(a) | The decrease in 2014 compared with 2013 was primarily due to the repayment of debt in July and December 2013. |
(b) | The increase in 2014 compared with 2013 was primarily due to the Holtwood hydroelectric expansion project placed in service in November 2013. |
Income Taxes
The increase (decrease) in income taxes was due to:
2014 vs. 2013 | 2013 vs. 2012 | |||||||
Change in pre-tax income at current period tax rates |
$ | 298 | $ | (439 | ) | |||
State deferred tax rate change (a) |
(16 | ) | 34 | |||||
Federal income tax credits (b) |
8 | 3 | ||||||
Federal and state tax reserve adjustments (c) |
(6 | ) | 8 | |||||
Other |
(9 | ) | (1 | ) | ||||
|
|
|
|
|||||
Total |
$ | 275 | $ | (395 | ) | |||
|
|
|
|
(a) | Changes in state apportionment resulted in reductions to the future estimated state tax rate at December 31, 2014 and 2012 and an increase to the future estimated state tax rate at December 2013. Talen Energy Supply recorded an insignificant deferred tax benefit in 2014, a $15 million deferred tax expense in 2013, and a $19 million deferred tax benefit in 2012 related to its state deferred tax liabilities. |
(b) | During 2013 and 2012, Talen Energy Supply recorded deferred tax benefits related to investment tax credits on progress expenditures related to the Holtwood hydroelectric plant expansion. See Note 4 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information. |
(c) | During 2013, Talen Energy Supply reversed $3 million in tax benefits related to a 2008 change in method of accounting for certain expenditures for tax purposes and recorded $4 million in federal tax expense related to differences in over (under) payment interest rates applied to audit claims as a result of the U.S. Supreme Court decision related to Windfall Profits Tax. |
See Note 2 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information on income taxes.
3
Income (Loss) from Discontinued Operations (net of income taxes)
Income (Loss) from Discontinued Operations (net of income taxes) primarily includes the results of operations of the Montana hydroelectric generating facilities for all periods presented. See Discontinued OperationsMontana Hydro Sale in Note 4 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information. Income (Loss) from Discontinued Operations (net of income taxes) increased by $191 million in 2014 compared with 2013 primarily due to the gain on the sale of the Montana hydroelectric generating facilities, and decreased by $14 million in 2013 compared with 2012 primarily due to lower energy margins due to lower energy prices.
Margins
Margins is a non-GAAP financial performance measure that management utilizes as indicators of financial performance of its business. See Results of OperationsSix months ended June 30, 2015 compared to six months ended June 30, 2014Earnings, EBITDA, Adjusted EBITDA, Margins and Statements of Income AnalysisMargins above for information why management believes this measurement is useful.
The following tables contain the components from the Statements of Income that are included in this non-GAAP financial measure and a reconciliation to Operating Income for the years ended December 31.
2014 | 2013 | |||||||||||||||||||||||
Margins | Reconciling Items(a) |
Operating Income(b) |
Margins | Reconciling Items (a) |
Operating Income (b) |
|||||||||||||||||||
Operating Revenues |
||||||||||||||||||||||||
Unregulated wholesale energy |
$ | 1,474 | $ | 334 | (c) | $ | 1,808 | $ | 3,642 | $ | (733 | )(c) | $ | 2,909 | ||||||||||
Unregulated wholesale energy to affiliate |
84 | 84 | 51 | 51 | ||||||||||||||||||||
Unregulated retail energy (d) |
1,216 | 27 | (c) | 1,243 | 1,015 | 12 | (c) | 1,027 | ||||||||||||||||
Energy-related businesses |
601 | 601 | 527 | 527 | ||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
Total Operating Revenues |
2,774 | 962 | 3,736 | 4,708 | (194 | ) | 4,514 | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
Operating Expenses |
||||||||||||||||||||||||
Fuel |
1,169 | 27 | (e) | 1,196 | 1,045 | 4 | (e) | 1,049 | ||||||||||||||||
Energy purchases |
(121 | ) | 330 | (c) | 209 | 1,745 | (574 | )(c) | 1,171 | |||||||||||||||
Other operation and maintenance |
22 | 985 | 1,007 | 20 | 1,006 | 1,026 | ||||||||||||||||||
Loss on lease termination (Note 4) |
697 | 697 | ||||||||||||||||||||||
Depreciation |
297 | 297 | 299 | 299 | ||||||||||||||||||||
Taxes, other than income |
43 | 14 | 57 | 37 | 16 | 53 | ||||||||||||||||||
Energy-related businesses |
8 | 565 | 573 | 7 | 505 | 512 | ||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
Total Operating Expenses |
1,121 | 2,218 | 3,339 | 2,854 | 1,953 | 4,807 | ||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
Total |
$ | 1,653 | $ | (1,256 | ) | $ | 397 | $ | 1,854 | $ | (2,147 | ) | $ | (293 | ) | |||||||||
|
|
|
|
|
|
|
|
|
|
|
|
4
2012 | ||||||||||||
Margins | Reconciling Items (a) |
Operating Income (b) |
||||||||||
Operating Revenues |
||||||||||||
Unregulated wholesale energy |
$ | 4,250 | $ | (274 | )(c) | $ | 3,976 | |||||
Unregulated wholesale energy to affiliate |
78 | 78 | ||||||||||
Unregulated retail energy (d) |
861 | (17 | )(c) | 844 | ||||||||
Energy-related businesses |
448 | 448 | ||||||||||
|
|
|
|
|
|
|||||||
Total Operating Revenues |
5,189 | 157 | 5,346 | |||||||||
|
|
|
|
|
|
|||||||
Operating Expenses |
||||||||||||
Fuel |
931 | 34 | (e) | 965 | ||||||||
Energy purchases |
2,204 | (386 | )(c) | 1,818 | ||||||||
Energy purchases from affiliate |
3 | 3 | ||||||||||
Other operation and maintenance |
19 | 978 | 997 | |||||||||
Depreciation |
272 | 272 | ||||||||||
Taxes, other than income |
34 | 21 | 55 | |||||||||
Energy-related businesses |
432 | 432 | ||||||||||
|
|
|
|
|
|
|||||||
Total Operating Expenses |
3,191 | 1,351 | 4,542 | |||||||||
|
|
|
|
|
|
|||||||
Total |
$ | 1,998 | $ | (1,194 | ) | $ | 804 | |||||
|
|
|
|
|
|
(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 13 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A. Also includes unrealized gains (losses) on trading activity of $27 million, $(6) million and $27 million for 2014, 2013 and 2012. For 2012, Unregulated wholesale energy and Energy purchases include a net pre-tax loss of $35 million related to the monetization of certain full-requirement sales contracts. Amounts have been adjusted for option premiums of $10 million in 2014 and insignificant amounts for 2013 and 2012. |
(d) | Although retail energy revenues continue to grow, the net margins related to these activities are not currently a significant component of Margins. |
(e) | Includes economic activity related to fuel as described in Commodity Price Risk (Non-trading) Economic Activity within Note 13 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A. 2012 includes a net pre-tax loss of $29 million related to coal contract modification payments. |
Changes in Margins
The following table shows Margins, all within the East segment, by component for the year ended December 31 as well as the change between periods. The factors that gave rise to the changes are described following the table.
$ Change | ||||||||||||||||||||
2014 | 2013 | 2012 | 2014 vs. 2013 | 2013 vs. 2012 | ||||||||||||||||
Eastern U.S. |
$ | 1,575 | $ | 1,775 | $ | 1,851 | $ | (200 | ) | $ | (76 | ) | ||||||||
Western U.S. |
78 | 79 | 147 | (1 | ) | (68 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||
Total |
$ | 1,653 | $ | 1,854 | $ | 1,998 | $ | (201 | ) | $ | (144 | ) | ||||||||
|
|
|
|
|
|
|
|
|
|
Eastern U.S.
Eastern margins decreased in 2014 compared with 2013 primarily due to lower baseload energy prices of $354 million and lower capacity prices of $34 million, partially offset by net gains on commodity positions of $75 million, favorable asset performance of $70 million, $38 million related to weather as discussed below and gas optimization of $26 million.
During the first quarter of 2014, the PJM region experienced unusually cold weather conditions, higher demand and congestion patterns, causing rising natural gas and electricity prices in spot and near-term forward markets. Due to these market dynamics, Talen Energy Supply captured opportunities on unhedged generation, which were primarily offset by under-hedged full-requirement sales contracts and retail electric.
5
Eastern margins decreased in 2013 compared with 2012 primarily due to $435 million of lower baseload energy prices, partially offset by $198 million of higher capacity prices and $100 million of increased nuclear generation volume.
Western U.S.
Western margins decreased in 2013 compared with 2012 primarily due to $69 million of lower wholesale energy prices and $15 million of lower net economic availability of coal units.
EBITDA and Adjusted EBITDA
EBITDA and Adjusted EBITDA are non-GAAP financial performance measures that management utilizes as indicators of financial performance of its business. See Results of OperationsSix months ended June 30, 2015 compared to six months ended June 30, 2014Earnings, EBITDA, Adjusted EBITDA, Margins and Statements of Income AnalysisEBITDA and Adjusted EBITDA above for information why management believes this measure is useful.
The EBITDA and Adjusted EBITDA discussion, presented by segment, includes a reconciliation of the non-GAAP financial measures to operating income and consolidated net income.
Reconciliations of EBITDA and Adjusted EBITDA
The tables below provide reconciliations of EBITDA and Adjusted EBITDA to operating income on a segment basis and to net income (loss) on a consolidated basis for the years ended December 31.
2014 | ||||||||||||
East | Other | Total | ||||||||||
Net income (loss) |
$ | 410 | ||||||||||
Income (loss) from discontinued operations (net of tax) |
223 | |||||||||||
Interest expense |
124 | |||||||||||
Income taxes |
116 | |||||||||||
Other income (expense) net |
30 | |||||||||||
|
|
|||||||||||
Operating income (loss) |
$ | 629 | $ | (232 | ) | $ | 397 | |||||
Depreciation |
297 | | 297 | |||||||||
Other income (expense) net |
29 | 1 | 30 | |||||||||
|
|
|
|
|
|
|||||||
EBITDA |
$ | 955 | $ | (231 | ) | $ | 724 | |||||
Special Items: |
||||||||||||
Unrealized (gain) loss on derivative contracts (a) |
(17 | ) | | (17 | ) | |||||||
Stock-based compensation expense (b) |
| 18 | 18 | |||||||||
(Gain) loss from NDT fund |
(26 | ) | | (26 | ) | |||||||
ARO accretion |
32 | | 32 | |||||||||
Separation benefits (c) |
| 33 | 33 | |||||||||
Mechanical contracting and engineering subsidiary revenue adjustments (d) |
(17 | ) | | (17 | ) | |||||||
Other (e) |
12 | | 12 | |||||||||
|
|
|
|
|
|
|||||||
Adjusted EBITDA |
$ | 939 | $ | (180 | ) | $ | 759 | |||||
|
|
|
|
|
|
6
2013 | ||||||||||||
East | Other | Total | ||||||||||
Net income (loss) |
$ | (230 | ) | |||||||||
Income (loss) from discontinued operations (net of tax) |
32 | |||||||||||
Income (Loss) Attributable to Noncontrolling Interests |
1 | |||||||||||
Interest expense |
159 | |||||||||||
Income taxes |
(159 | ) | ||||||||||
Other income (expense) net |
32 | |||||||||||
|
|
|||||||||||
Operating income (loss) |
$ | (100 | ) | $ | (195 | ) | $ | (295 | ) | |||
Other income (expense) net |
30 | 2 | 32 | |||||||||
Income (Loss) Attributable to Noncontrolling Interests |
1 | | 1 | |||||||||
Depreciation |
299 | | 299 | |||||||||
|
|
|
|
|
|
|||||||
EBITDA |
$ | 230 | $ | (193 | ) | $ | 37 | |||||
Special Items: |
||||||||||||
Unrealized (gain) loss on derivative contracts (a) |
136 | | 136 | |||||||||
Stock-based compensation expense (b) |
| 16 | 16 | |||||||||
(Gain) loss from NDT fund |
(22 | ) | | (22 | ) | |||||||
ARO accretion |
29 | | 29 | |||||||||
Loss on of Colstrip operating lease termination (f) |
697 | | 697 | |||||||||
Corette impairment (g) |
65 | | 65 | |||||||||
Counterparty bankruptcy (h) |
(2 | ) | (2 | ) | ||||||||
Other (e) |
13 | | 13 | |||||||||
|
|
|
|
|
|
|||||||
Adjusted EBITDA |
$ | 1,146 | $ | (177 | ) | $ | 969 | |||||
|
|
|
|
|
|
2012 | ||||||||||||
East | Other | Total | ||||||||||
Net Income (Loss) |
$ | 474 | ||||||||||
Income (loss) from Discontinued Operations (net of tax) |
46 | |||||||||||
Income (Loss) Attributable to Noncontrolling Interests |
1 | |||||||||||
Interest expense |
158 | |||||||||||
Income taxes |
236 | |||||||||||
Other income (expense) net |
19 | |||||||||||
|
|
|||||||||||
Operating income (loss) |
$ | 991 | $ | (189 | ) | $ | 802 | |||||
Depreciation |
272 | | 272 | |||||||||
Income (Loss) Attributable to Noncontrolling Interests |
1 | | 1 | |||||||||
Other income (expense) net |
17 | 2 | 19 | |||||||||
|
|
|
|
|
|
|||||||
EBITDA |
$ | 1,281 | $ | (187 | ) | $ | 1,094 | |||||
Special Items: |
||||||||||||
Unrealized (gain) loss on derivative contracts (a) |
(91 | ) | | (91 | ) | |||||||
Stock-based compensation expense (b) |
| 14 | 14 | |||||||||
(Gain) loss from NDT fund |
(21 | ) | | (21 | ) | |||||||
ARO accretion |
28 | | 28 | |||||||||
Counter party bankruptcy (h) |
11 | | 11 | |||||||||
Coal contract modification payments (i) |
29 | | 29 | |||||||||
Other (e) |
9 | | 9 | |||||||||
|
|
|
|
|
|
|||||||
Adjusted EBITDA |
$ | 1,246 | $ | (173 | ) | $ | 1,073 | |||||
|
|
|
|
|
|
(a) | Represents unrealized gains (losses), after-tax, on economic and trading activity. See Commodity Price Risk (Non-trading)Economic Activity in Note 13 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information. Also includes unrealized gains (losses) on trading activity of $27 million, $(6) million and $27 million for 2014, 2013 and 2012. Amounts have also been adjusted for $10 million in 2014 and insignificant amounts in 2013 and 2012 for option premiums. |
7
(b) | Represents a certain portion of PPLs stock-based compensation cost allocable to Talen Energy. Amounts for the 20142012 were cash settled with a former affiliate. |
(c) | Talen Energy Supply recorded during 2014, separation benefits related to the anticipated spinoff transaction. See Note 4 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information. In addition, in June 2014, Talen Energy Supplys largest IBEW local ratified a new three-year labor agreement. In connection with the new agreement, bargaining unit one-time voluntary retirement benefits were recorded. See Note 9 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information. |
(d) | In 2014, Talen Energy Supply recorded $17 million to Energy-related businesses revenues on the 2014 Statement of Income related to prior periods and the timing of revenue recognition for a mechanical contracting and engineering subsidiary. See Note 1 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information. |
(e) | All periods include OCI amortization on non-active derivative positions. |
(f) | In September 2013, Talen Montana executed a definitive agreement to sell to NorthWestern certain hydroelectric generating facilities located in Montana. To facilitate the sale, Talen Montana terminated its operating lease arrangement related to partial interests in Units 1, 2 and 3 of the Colstrip coal-fired electric generating facility in December 2013 and acquired those interests, collectively, for $271 million. At lease termination, the existing lease-related assets on the balance sheet were written-off and the acquired Colstrip assets were recorded at fair value as of the acquisition date. Talen Energy Supply recorded a pre-tax charge of $697 million for the termination of the lease. See Note 4 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information. |
(g) | In 2013, Talen Energy Supply determined its Corette plant was impaired and recorded a pre-tax charge of $65 million for the plant and related emission allowances. See Note 12 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information. |
(h) | In October 2011, a wholesale customer, SMGT, filed for bankruptcy protection under Chapter 11 of the U.S. Bankruptcy Code. In 2012, Talen Energy Marketing recorded an additional allowance for unpaid amounts under the long-term power contract. In March 2012, the U.S. Bankruptcy Court for the District of Montana approved the request to terminate the contract, effective April 1, 2012. In June 2013, Talen Energy Marketing received an approval for an administrative claim in the amount of $2 million |
(i) | As a result of lower electricity and natural gas prices, coal-fired generation output decreased during 2012. Contract modification payments were incurred to reduce 2012 and 2013 coal deliveries. |
Changes in Adjusted EBITDA
The following table shows Adjusted EBITDA by segment for the years ended December 31 as well as the change between periods. The factors that gave rise to the changes are described following the table.
2014 | 2013 | Change | 2013 | 2012 | Change | |||||||||||||||||||
East |
$ | 966 | $ | 1,179 | $ | (213 | ) | $ | 1,179 | $ | 1,284 | $ | (105 | ) | ||||||||||
Other |
(207 | ) | (215 | ) | 8 | (215 | ) | (211 | ) | (4 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
Total |
$ | 759 | $ | 964 | $ | (205 | ) | $ | 964 | $ | 1,073 | $ | (109 | ) | ||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
The decrease in Adjusted EBITDA in 2014 compared with 2013 was primarily due to lower margins resulting from lower energy and capacity prices, partially offset by favorable baseload asset performance, gains on certain commodity positions and net benefits of unusually cold weather in the first quarter of 2014.
The decrease in Adjusted EBITDA in 2013 compared with 2012 was primarily due to lower baseload energy prices, partially offset by higher capacity prices, higher nuclear generation volume and lower operation and maintenance expense.
8
Our Fleet
Asset |
Location | Fuel Type |
Ownership | Owned Capacity (MW) (1) |
Commercial Operation Date |
Region/ ISO |
||||||||||||
Ironwood |
PA | Natural Gas |
100 | % | 660 | 2001 | PJM | |||||||||||
Lower Mt. Bethel |
PA | Natural Gas |
100 | % | 538 | 2004 | PJM | |||||||||||
York |
PA | Natural Gas |
100 | % | 47 | 1989 | PJM | |||||||||||
Martins Creek 3 & 4 |
PA | Natural Gas / Oil |
100 | % | 1,700 | 1975 1977 | PJM | |||||||||||
Peakers |
PA | Natural Gas / Oil |
100 | % | 354 | 1967 1973 | PJM | |||||||||||
Bayonne |
NJ | Natural Gas / Oil |
100 | % | 164 | 1988 | PJM | |||||||||||
Camden |
NJ | Natural Gas / Oil |
100 | % | 145 | 1993 | PJM | |||||||||||
Pedricktown (2) |
NJ | Natural Gas / Oil |
100 | % | 118 | 1992 | PJM | |||||||||||
Newark Bay |
NJ | Natural Gas / Oil |
100 | % | 123 | 1993 | PJM | |||||||||||
Elmwood Park |
NJ | Natural Gas / Oil |
100 | % | 71 | 1989 | PJM | |||||||||||
Susquehanna |
PA | Nuclear |
90 | % | 2,245 | 1983 1985 | PJM | |||||||||||
Montour |
PA | Coal |
100 | % | 1,504 | 1972 1973 | PJM | |||||||||||
Brunner Island |
PA | Coal |
100 | % | 1,411 | 1961 1969 | PJM | |||||||||||
Brandon Shores |
MD | Coal |
100 | % | 1,284 | 1984 1991 | PJM | |||||||||||
C.P. Crane |
MD | Coal |
100 | % | 404 | 1961 1967 | PJM | |||||||||||
Conemaugh |
PA | Coal |
16 | % | 278 | 1970 1971 | PJM | |||||||||||
Keystone |
PA | Coal |
12 | % | 211 | 1967 1968 | PJM | |||||||||||
H.A. Wagner |
MD | Coal / Natural Gas / Oil |
100 | % | 982 | 1956 1972 | PJM | |||||||||||
Eastern Hydro (3) |
PA | Hydro |
100 | % | 293 | 1910 1926 | PJM | |||||||||||
Colstrip 1 & 2 |
MT | Coal |
50 | % | 307 | 1975 1976 | WECC | |||||||||||
Colstrip 3 |
MT | Coal |
30 | % | 222 | 1984 | WECC | |||||||||||
Dartmouth |
MA | Natural Gas / Oil |
100 | % | 83 | 1996 | ISO-NE | |||||||||||
Nueces Bay 7 |
TX | Natural Gas |
100 | % | 648 | 2010 | ERCOT | |||||||||||
Barney Davis 2 |
TX | Natural Gas |
100 | % | 646 | 2010 | ERCOT | |||||||||||
Barney Davis 1 |
TX | Natural Gas |
100 | % | 318 | 1974 | ERCOT | |||||||||||
Laredo 4 |
TX | Natural Gas |
100 | % | 92 | 2008 | ERCOT | |||||||||||
Laredo 5 |
TX | Natural Gas |
100 | % | 89 | 2008 | ERCOT | |||||||||||
Renewables (4) |
NH, NJ, PA, VT | Renewables |
100 | % | 25 | Various | Various | |||||||||||
|
|
|||||||||||||||||
Total | 14,962 | |||||||||||||||||
|
|
(1) | Summer Rating at June 30, 2015. The capacity of generation units is based on a number of factors, including the operating experience and physical conditions of the units, and may be revised periodically to reflect changed circumstances. Does not reflect the sale or other disposition of between 1,300 and 1,400 MW of generating capacity that is required to obtain regulatory approval for the Talen Transactions. See The Talen TransactionsMitigation Plans. |
(2) | Pedricktown capacity includes capacity dedicated to serving landlord load (which has historically averaged 9 MW). |
(3) | Includes Holtwood and Wallenpaupack. |
(4) | We have agreed to sell our renewables plants representing 19 MW of capacity as shown herein. Subject to receipt of regulatory approvals, we expect to close the sale of these plants by the end of 2015. See Managements Discussion and Analysis of Financial Condition and Results of OperationsOverviewFinancial and Operational DevelopmentsMechanical Contracting Subsidiaries and Renewable Energy Business. |
Power Supply
Talen Energy Supply owned or controlled generating capacity (summer rating) of 14,962 MW at June 30, 2015. Generating capacity controlled by Talen Generation and other Talen Energy Supply subsidiaries includes power obtained through Talen Energy Marketings power purchase agreements.
Talen Energy Supplys generation subsidiaries are exempt wholesale generators (EWGs) that sell electricity into wholesale markets. EWGs are subject to regulation by the FERC, which has authorized these EWGs to sell the electricity generated at market-based prices. A portion of this electricity is sold to Talen Energy Marketing under FERC-jurisdictional power purchase agreements. Susquehanna Nuclear is subject to the jurisdiction of the NRC in connection with the operation of its Susquehanna nuclear units. Certain of Talen Energy Supplys other subsidiaries are subject to the jurisdiction of the NRC in connection with the operation of their fossil plants with respect to certain level and density monitoring devices. Certain operations of Talen Generations subsidiaries are also subject to OSHA and comparable state statutes.
9
Fuel Supply
Oil and Natural Gas
Pennsylvania
Talen Generations Martins Creek Units 3 and 4 burn both oil and natural gas. During 2014, 100% of the physical gas requirements for the Martins Creek units were purchased on the spot market using either delivered supply or a combination of spot market supply and short-term capacity and oil requirements were supplied from inventory and replenished by purchases made in the spot market. At December 31, 2014, there were no long-term agreements for oil or natural gas for these units.
Short-term and long-term gas transportation contracts are in place for approximately 38% of the maximum daily requirements of the Lower Mt. Bethel combined-cycle facility.
For Talens Ironwood combined-cycle facility, Talen Energy Marketing has long-term transportation contracts that can deliver up to approximately 25% of Ironwoods maximum daily gas requirements. Daily gas requirements can also be met through a combination of short-term transportation capacity release transactions coupled with upstream supply.
In addition, Talen Energy Marketing has secured long-term natural gas supply for approximately 10% of the combined needs of Ironwood and Lower Mt. Bethel through 2016.
New Jersey and Texas
Sapphires Bayonne, Camden, Pedricktown, Newark Bay, Elmwood and Dartmouth stations are co-fired with natural gas and oil. Natural gas is the primary fuel at each station. There are no long-term supply or pipeline capacity agreements for oil or natural gas for these units. Oil storage capability exists at each station and is replenished on a spot market basis.
Jades Nueces Bay, Barney Davis and Laredo stations in Texas currently have a comprehensive gas supply agreement in place designed to cover 100% of the plants requirements. See Certain Relationships and Related Party Transactions TrailStone Agreement. There are no long-term pipeline capacity contracts in place on the upstream interstate pipelines that serve these units.
Coal
Pennsylvania
Talen Energy Marketing actively manages Talen Energy Supplys coal requirements for the Pennsylvania plants by purchasing coal principally from mines located in northern Appalachia.
Coal inventory is maintained at levels estimated to be necessary to avoid operational disruptions at coal-fired generating units. Reliability of coal deliveries can be affected from time to time by a number of factors including fluctuations in demand, coal mine production issues and other supplier or transporter operating difficulties. Talen Generation, by and through its agent Talen Energy Marketing, has agreements in place that satisfy the majority of projected coal needs for the Pennsylvania power plants through 2018 and will augment with spot market purchases, as needed.
A Talen Generation subsidiary owns a 12.34% interest in the Keystone plant and a 16.25% interest in the Conemaugh plant. Talen Generation owns a 12.34% interest in Keystone Fuels, LLC and a 16.25% interest in Conemaugh Fuels, LLC. The Keystone plant contracts with Keystone Fuels, LLC for its coal requirements, which provided 4.5 million tons of coal to the Keystone plant in 2014. The Conemaugh plant requirements are purchased under contract from Conemaugh Fuels, LLC, which provided 4.5 million tons of coal to the Conemaugh plant in 2014.
10
All wholly owned Talen Generation coal plants within Pennsylvania are equipped with Flue Gas Desulferization equipment (FGD) or Scrubbers, which use limestone in their operations. Acting as agent for Talen Generation, Talen Energy Marketing has entered into limestone contracts with suppliers that will provide limestone for those plants through 2016. Annual limestone requirements range from approximately 400,000-500,000 tons.
Maryland
Talen Energy Marketing actively manages Talen Energy Supplys coal requirements for the Maryland plants by purchasing coal principally from mines located in central and northern Appalachia and the western U.S.
Coal inventory is maintained at levels estimated to be necessary to avoid operational disruptions at coal-fired generating units. Reliability of coal deliveries can be affected from time to time by a number of factors including fluctuations in demand, coal mine production issues and other supplier or transporter operating difficulties. Raven subsidiaries, by and through their agent Talen Energy Marketing, have agreements in place that satisfy the majority of projected coal needs for the Maryland power plants through 2018 and will augment with spot market purchases, as needed.
Coal is transported to the Maryland plants by rail car and/or barge service. See Certain Relationships and Related Party Transactions BargeCo Agreement.
The Brandon Shores station is equipped with Flue Gas Desulfurization equipment (FGD) or Scrubbers, which use limestone in their operations. Acting as agent for a Raven subsidiary, Talen Energy Marketing has entered into limestone contracts with suppliers that will provide limestone for this plant through 2016.
Montana
Talen Montana owns a 30% interest in Colstrip Unit 3 and NorthWestern owns a 30% interest in Colstrip Unit 4. Talen Montana and NorthWestern have a sharing agreement that governs each partys responsibilities and rights relating to the operation of Colstrip Units 3 and 4. Under the terms of that agreement, each party is responsible for 15% of the total non-coal operating and construction costs of Colstrip Units 3 and 4, regardless of whether a particular cost is specific to Colstrip Unit 3 or 4, and is entitled to take up to 15% of the available generation from Units 3 and 4. Each party is responsible for its own coal costs. Talen Montana, with the other Colstrip owners, is party to contracts to purchase 100% of its coal requirements with defined coal quality characteristics and specifications. Talen Montana, with the other Colstrip Units 1 and 2 owner, has a long-term purchase and supply agreement with the current supplier for Units 1 and 2, which provides these units 85% to 100% of their coal requirements (at owners option) from January 2015 through December 2019. Talen Montana, with the other Colstrip Units 3 and 4 owners, has a long-term coal supply contract for Units 3 and 4, which provides these units 100% of their coal requirements through December 2019.
These units were originally built containing Scrubbers and Talen Montana has entered into a long-term contract to purchase the limestone requirements for these units. The contract extends through December 2030.
Coal supply contracts are in place to purchase low-sulfur coal with defined quality characteristics and specifications for Talen Montanas Corette plant. The contracts covered 100% of the plants coal requirements in 2014 and similar contracts are in place to supply 100% of the expected coal requirements through the suspension of plant operations which occurred in March 2015. The plant was then retired in March 2015.
Nuclear
The nuclear fuel cycle consists of several material and service components: the mining and milling of uranium ore to produce uranium concentrates; the conversion of these concentrates into uranium hexafluoride, a gas component; the enrichment of the hexafluoride gas; the fabrication of fuel assemblies for insertion and use in the reactor core; and the temporary storage and final disposal of spent nuclear fuel.
11
Susquehanna Nuclear has a portfolio of supply contracts, with varying expiration dates, for nuclear fuel materials and services. These contracts are expected to provide sufficient fuel to permit Unit 1 to operate into the first quarter of 2020 and Unit 2 to operate into the first quarter of 2019. Susquehanna Nuclear anticipates entering into additional contracts to ensure continued operation of the nuclear units.
Federal law requires the U.S. government to provide for the permanent disposal of commercial spent nuclear fuel, but there is no definitive date by which a repository will be operational. As a result, it was necessary to expand Susquehanna nuclear plants on-site spent fuel storage capacity. To support this expansion, PPL Susquehanna contracted for the design and construction of a spent fuel storage facility employing dry cask fuel storage technology. The facility is modular, so that additional storage capacity can be added as needed. The facility began receiving spent nuclear fuel in 1999. Susquehanna Nuclear estimates, under current operating conditions, that there is sufficient storage capacity in the spent nuclear fuel pools and the on-site spent fuel storage facility at the Susquehanna nuclear plant to accommodate spent fuel discharged through approximately 2017. If necessary, the on-site spent fuel storage facility can be expanded, assuming appropriate regulatory approvals are obtained, such that, together, the spent fuel pools and the expanded dry fuel storage facility will accommodate all of the spent fuel expected to be discharged through 2044, the current licensed life of the plant.
In 1996, the U.S. Court of Appeals for the District of Columbia Circuit ruled that the Nuclear Waste Policy Act imposed on the DOE an unconditional obligation to begin accepting spent nuclear fuel on or before January 31, 1998. In January 2004, Susquehanna Nuclear filed suit in the U.S. Court of Federal Claims for unspecified damages suffered as a result of the DOEs breach of its contract to accept and dispose of spent nuclear fuel. In May 2011, Susquehanna Nuclear entered into a settlement agreement with the U.S. Government relating to Susquehanna Nuclears lawsuit. The settlement included reimbursement of certain costs to store spent nuclear fuel at the Susquehanna nuclear plant incurred from 1998 through December 31, 2013, and Susquehanna Nuclear received payments for its claimed costs for those periods. In exchange, Susquehanna Nuclear waived any claims against the U.S. government for costs paid or injuries sustained related to storing spent nuclear fuel at the Susquehanna nuclear plant through December 31, 2013. In January 2014, Susquehanna Nuclear entered into a new agreement with the DOE to extend the settlement agreement on the same terms as the prior agreement for an additional three years to the end of 2016.
12
On June 9, 2014, PPL, HoldCo, Talen Energy, Talen Energy Supply and the Riverstone Holders entered into the Separation Agreement and, with Merger Sub, the Transaction Agreement, pursuant to which a newly formed entity, HoldCo, owning the Talen Energy Supply business would be spun off to PPLs shareholders and combined with the RJS Power business to create Talen Energy, an independent publicly traded company.
On June 1, 2015, PPL completed the spinoff to PPL shareholders of a newly formed entity, HoldCo, which at such time owned all of the membership interests of Talen Energy Supply and all of the common stock of Talen Energy Corporation. Immediately following the spinoff, HoldCo merged with a special purpose subsidiary of Talen Energy Corporation, with HoldCo continuing as the surviving company to the merger and as a wholly owned subsidiary of Talen Energy Corporation and the sole owner of Talen Energy Supply. Substantially contemporaneously with the Merger, the RJS Power business was contributed by its owner to Talen Energy through the contribution, directly or indirectly, of all of the equity interests of RJS Power, in exchange for 44,974,658 shares of Talen Energy Corporation common stock issued in a private placement transaction. Following the Combination, PPL shareholders owned 65% of Talen Energys outstanding common stock and affiliates of the Riverstone Holders own the remaining 35%. PPL has no continuing ownership interest in, control of or affiliation with Talen Energy following the Distribution and Combination, other than satisfying their obligations under a Transition Services Agreement between PPL and Talen Energy Supply.
The Unaudited Pro Forma Condensed Combined Financial Information (the pro forma financial information) has been derived from the audited consolidated financial statements of Talen Energy Supply and the historical consolidated and combined financial statements of RJS Power (the historical financial statements).
The Unaudited Pro Forma Condensed Combined Statement of Income (the pro forma statement of income) for the year ended December 31, 2014 gives effect to the spinoff of HoldCo and the Combination with RJS Power as if they were completed on January 1, 2014. The Unaudited Pro Forma Condensed Combined Balance Sheet (the pro forma balance sheet) as of December 31, 2014 gives effect to the spinoff and the Combination as if they were completed on December 31, 2014. The historical financial statements have been adjusted in the pro forma financial information to give effect to pro forma events that are: (i) directly attributable to the spinoff and Combination; (ii) factually supportable; and (iii) with respect to the statement of income, expected to have a continuing impact on results. The pro forma financial information: (a) reflects the replacement of Talen Energy Supplys and RJS Powers then existing $3.0 billion and $150 million credit facilities, respectively, with the $1.85 billion Credit Agreement; (b) adjusts the pro forma statement of income for the anticipated disposal of certain generating facilities to satisfy the FERC Order, and adjusts the pro forma balance sheet to reflect certain related assets and liabilities for these facilities as divested for cash at carrying value; (c) adjusts for certain assets and liabilities that were reallocated between PPL and Talen Energy Supply or that were settled as outlined in the Separation Agreement or the Transaction Agreement; (d) conforms certain RJS Power accounting policies with those of Talen Energy Supply; and (e) reflects the issuance of Talen Energy Corporation common stock in connection with the Combination.
The pro forma financial information was prepared using the acquisition method of accounting, with Talen Energy Supply considered the accounting acquirer of RJS Power. Under the acquisition method of accounting, the purchase price is allocated to the underlying tangible and intangible assets acquired and liabilities assumed based on their respective fair values at the acquisition date, with any remaining purchase price allocated to goodwill. Talen Energy Supply has considered multiple factors in arriving at the estimated fair values which were based on a preliminary review of the assets and liabilities of the RJS Power business. These estimates are subject to change pending further review of the assets acquired and liabilities assumed. Generally accepted accounting principles in the United States require the purchase price allocation to be determined as of the date of the Combination, and also permit adjustments to the purchase price allocation for the RJS Power business during the measurement period, which may be up to one year from the date of the Combination. Therefore, the final goodwill and fair value amounts recorded for the assets and liabilities of the RJS Power business, effective as of the date of the Combination, may differ materially from the information presented in the pro forma financial information. The purchase price (total consideration) for the acquisition was deemed to be $902 million based on the fair value of the Talen Energy Corporation common stock issued for the acquisition using the June 1, 2015 closing when-issued market price.
Throughout the periods covered by the pro forma financial information, the operations of Talen Energy Supplys business were conducted and accounted for as part of PPL. As a result, the Talen Energy Supply historical
13
financial statements reflect significant allocations of costs and expenses. All of the allocations and estimates in these historical financial statements are based on assumptions that the management of Talen Energy Supplys business believes are reasonable. However, the Talen Energy Supply historical financial statements do not necessarily represent the costs and expenses of Talen Energy Supplys business had it been operated as a separate independent entity. The pro forma financial information does not reflect the costs of any integration activities or benefits that may result from realization of future cost savings from operating efficiencies or synergies expected to result from the spinoff and Combination.
Assumptions and estimates underlying the pro forma adjustments are described in the accompanying notes, which should be read in conjunction with the pro forma financial information.
The pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the results of operations and financial position that would have been achieved had the pro forma events taken place on the dates indicated, or the future consolidated results of operations or financial position of Talen Energy Supply.
The following pro forma financial information should be read in conjunction with:
| the accompanying notes to the pro forma financial information; |
| the audited consolidated financial statements of Talen Energy Supply as of and for the year ended December 31, 2014, which are included elsewhere in this Appendix A; |
| the audited consolidated and combined financial statements of RJS Power as of and for the year ended December 31, 2014, which are included elsewhere in this Appendix A; and |
| the unaudited condensed consolidated financial statements of Talen Energy Supply as of and for the six months ended June 30, 2015, which are included elsewhere in this Appendix A. |
14
Pro Forma Condensed Combined Balance Sheet
(Unaudited)
(Millions of dollars)
December 31, 2014 | ||||||||||||||||
Talen Energy Supply |
RJS Power | Pro Forma Adjustments (Note 2) |
Pro Forma Combined Entity |
|||||||||||||
Current Assets |
||||||||||||||||
Cash and cash equivalents |
$ | 352 | $ | 30 | $ | 656 | (c)(g)(i) | $ | 1,038 | |||||||
Restricted cash and cash equivalents |
176 | 1 | (1 | )(c) | 176 | |||||||||||
Accounts receivable |
325 | 34 | 33 | (f) | 392 | |||||||||||
Unbilled revenues |
218 | 218 | ||||||||||||||
Fuel, materials and supplies |
455 | 193 | (93 | )(a)(c) | 555 | |||||||||||
Prepayments |
70 | 13 | (60 | )(c)(f) | 23 | |||||||||||
Price risk management assets |
1,079 | 26 | 23 | (a) | 1,128 | |||||||||||
Other current assets |
26 | 14 | 15 | (a)(b)(f) | 55 | |||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total Current Assets |
2,701 | 311 | 573 | 3,585 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Investments |
||||||||||||||||
Nuclear plant decommissioning trust funds |
950 | 950 | ||||||||||||||
Other investments |
30 | 30 | ||||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total Investments |
980 | 980 | ||||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Property, Plant and Equipment, net |
||||||||||||||||
Property, plant and equipment |
12,678 | 1,740 | (530 | ) | 13,888 | |||||||||||
Less accumulated depreciation |
6,242 | 329 | (388 | ) | 6,183 | |||||||||||
|
|
|
|
|
|
|
|
|||||||||
Property, plant and equipment, net |
6,436 | 1,411 | (142 | )(b)(c) | 7,705 | |||||||||||
|
|
|
|
|
|
|
|
|||||||||
Other Noncurrent Assets |
||||||||||||||||
Goodwill |
72 | 267 | (b)(c) | 339 | ||||||||||||
Other intangibles |
257 | 17 | 1 | 275 | ||||||||||||
Price risk management assets |
239 | 3 | 242 | |||||||||||||
Other noncurrent assets |
75 | 56 | (46 | )(b)(c)(g) | 85 | |||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total Other Noncurrent Assets |
643 | 76 | 222 | 941 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total Assets |
$ | 10,760 | $ | 1,798 | $ | 653 | $ | 13,211 | ||||||||
|
|
|
|
|
|
|
|
See accompanying Unaudited Notes to Pro Forma Condensed Combined Financial Information.
15
Pro Forma Condensed Combined Balance Sheet
(Unaudited)
(Millions of dollars)
December 31, 2014 | ||||||||||||||||
Talen Energy Supply |
RJS Power | Pro Forma Adjustments (Note 2) |
Pro Forma Combined Entity |
|||||||||||||
Liabilities and Equity |
||||||||||||||||
Current Liabilities |
||||||||||||||||
Short-term debt |
$ | 630 | $ | 8 | $ | 50 | (i) | $ | 688 | |||||||
Long-term debt due within one year |
535 | (4 | )(c) | 531 | ||||||||||||
Accounts payable |
411 | 50 | 3 | (c)(f) | 464 | |||||||||||
Taxes |
28 | 86 | (c)(f) | 114 | ||||||||||||
Interest |
16 | 16 | ||||||||||||||
Price risk management liabilities |
1,024 | 43 | 23 | (a) | 1,090 | |||||||||||
Other current liabilities |
246 | 133 | (95 | )(a)(b)(c)(f) | 284 | |||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total Current Liabilities |
2,890 | 234 | 63 | 3,187 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Long-term Debt |
1,683 | 1,275 | (70 | )(c)(i) | 2,888 | |||||||||||
Deferred Credits and Other Noncurrent Liabilities |
||||||||||||||||
Deferred income taxes |
1,250 | 233 | (b)(c)(f) | 1,483 | ||||||||||||
Price risk management liabilities |
193 | 20 | 213 | |||||||||||||
Asset retirement obligations |
415 | 20 | (4 | )(c) | 431 | |||||||||||
Other deferred credits and noncurrent liabilities |
422 | (6 | )(b)(c)(f) | 416 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total Deferred Credits and Other Noncurrent Liabilities |
2,280 | 40 | 223 | 2,543 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Members Equity |
3,907 | 249 | 437 | (b)(f)(g)(i) | 4,593 | |||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total Liabilities and Equity |
$ | 10,760 | $ | 1,798 | $ | 653 | $ | 13,211 | ||||||||
|
|
|
|
|
|
|
|
See accompanying Unaudited Notes to Pro Forma Condensed Combined Financial Information.
16
Pro Forma Condensed Combined Statement of Income
(Unaudited)
(Millions of dollars)
For the Year Ended December 31, 2014 | ||||||||||||||||
Talen Energy Supply |
RJS Power |
Pro Forma Adjustments (Note 2) |
Pro Forma Combined Entity |
|||||||||||||
Operating Revenues |
||||||||||||||||
Unregulated wholesale energy |
$ | 1,892 | $ | 1,045 | $ | (507 | )(c) | $ | 2,430 | |||||||
Unregulated retail energy |
1,243 | 1,243 | ||||||||||||||
Energy-related businesses |
601 | 601 | ||||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total Operating Revenues |
3,736 | 1,045 | (507 | ) | 4,274 | |||||||||||
|
|
|
|
|
|
|
|
|||||||||
Operating Expenses |
||||||||||||||||
Operation |
||||||||||||||||
Fuel |
1,196 | 577 | (299 | )(c) | 1,474 | |||||||||||
Energy purchases |
209 | 209 | ||||||||||||||
Other operation and maintenance |
1,007 | 305 | (115 | )(a)(c)(d) | 1,197 | |||||||||||
Depreciation |
297 | 90 | (50 | )(c)(d) | 337 | |||||||||||
Taxes, other than income |
57 | 21 | 78 | |||||||||||||
Energy-related businesses |
573 | 573 | ||||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total Operating Expenses |
3,339 | 993 | (464 | ) | 3,868 | |||||||||||
|
|
|
|
|
|
|
|
|||||||||
Operating Income (Loss) |
397 | 52 | (43 | ) | 406 | |||||||||||
Other Income (Expense)net |
30 | 3 | (1 | )(c) | 32 | |||||||||||
Interest Expense |
124 | 110 | (16 | )(c)(e) | 218 | |||||||||||
|
|
|
|
|
|
|
|
|||||||||
Income (Loss) from Continuing Operations Before Income Taxes |
303 | (55 | ) | (28 | ) | 220 | ||||||||||
Income Taxes |
116 | (34 | )(c)(h) | 82 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Income (Loss) from Continuing Operations After Income Taxes Attributable to Member |
$ | 187 | $ | (55 | ) | $ | 6 | $ | 138 | |||||||
|
|
|
|
|
|
|
|
See accompanying Unaudited Notes to Pro Forma Condensed Combined Financial Information.
17
Unaudited Notes to Pro Forma Condensed Combined Financial Information
(Millions of Dollars, except share data)
Note 1. Basis of Pro Forma Presentation
The pro forma financial information has been derived from the historical consolidated financial statements of Talen Energy Supply and the historical consolidated and combined financial statements of RJS Power.
The pro forma statement of income for the year ended December 31, 2014 give effect to the spinoff of HoldCo and Combination of the Talen Energy Supply business with the RJS Power business as if they were completed on January 1, 2014. The pro forma balance sheet as of December 31, 2014 gives effect to the spinoff and the Combination as if they were completed on December 31, 2014.
The pro forma financial information was prepared using the acquisition method of accounting, with Talen Energy Supply considered the accounting acquirer of RJS Power. Under the acquisition method of accounting, the purchase price is allocated to the underlying tangible and intangible assets acquired and liabilities assumed based on their respective fair values at the acquisition date, with any remaining purchase price allocated to goodwill. The pro forma purchase price allocation was based on an estimate of the fair values of the tangible and intangible assets and liabilities of RJS Power and assumes an acquisition date of December 31, 2014. Talen Energy Supply has considered multiple factors in arriving at the estimated fair market values which were based on a preliminary review of the assets and liabilities of the RJS Power business. These estimates are subject to change pending further review of the assets acquired and liabilities assumed. Generally accepted accounting principles in the United States require the purchase price allocation to be determined as of the date of the Combination, and also permit adjustments to the purchase price allocation for the RJS Power business during the measurement period, which may be up to one year from the date of the Combination. Therefore, the final goodwill and fair value amounts recorded for the assets and liabilities of the RJS Power business, effective as of the date of the Combination, may differ materially from the information presented in the pro forma financial information. The total consideration for the acquisition was deemed to be $902 million based on the fair value of the Talen Energy Corporation common stock issued for the acquisition using the June 1, 2015 closing when-issued market price.
The historical financial statements have been adjusted in the pro forma financial information to give effect to pro forma events that are: (i) directly attributable to the spinoff and Combination; (ii) factually supportable; and (iii) with respect to the statements of income, expected to have a continuing impact on results. The pro forma financial information: (a) reflects the replacement of Talen Energy Supplys and RJS Powers then existing $3.0 billion and $150 million credit facilities, respectively, with the $1.85 billion Credit Agreement; (b) adjusts the pro forma statement of income for the anticipated disposal of certain generating facilities to satisfy the FERC Order, and adjusts the pro forma balance sheet to reflect certain related assets and liabilities for these facilities as divested for cash at carrying value; (c) adjusts for certain assets and liabilities that were reallocated between PPL and Talen Energy Supply or that were settled as outlined in the Separation Agreement or the Transaction Agreement; (d) conforms certain RJS Power accounting policies with those of Talen Energy Supply; and (e) reflects the issuance of Talen Energy Corporation common stock in connection with the Combination. The preliminary result of these adjustments, as well as other adjustments, is presented in Note 2. The pro forma financial information does not reflect the costs of any integration activities or benefits that may result from realization of future cost savings from operating efficiencies or synergies expected to result from the spinoff and Combination. Other items that are not included in the pro forma financial information are presented in Note 3.
Assumptions and estimates underlying the pro forma adjustments are described in the accompanying notes, which should be read in conjunction with the pro forma financial information.
For the purpose of measuring the estimated fair value of the assets acquired and liabilities assumed, accounting guidance for fair value measurements has been applied. Fair value is defined as 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.
Certain items normally included in the statement of income have been excluded from the pro forma statements of income.
18
Note 2. Purchase Price Allocation and Pro Forma Adjustments
(a) | Adjustments to conform certain RJS Power accounting policies with those of Talen Energy Supply for the balance sheet classification of emission allowances, financial instrument netting and the capitalization of overhauls. |
Debit (Credit) |
||||
Balance Sheet: |
||||
Fuel, materials and supplies |
$ | (77 | ) | |
Price risk management assets |
23 | |||
Other current assets |
5 | |||
Price risk management liabilities |
(23 | ) | ||
Other current liabilities |
72 | |||
Statement of Income: |
||||
Other operation and maintenance |
(33 | ) |
(b) | The pro forma allocation of the purchase price of the RJS Power business to the fair value of assets acquired and liabilities assumed includes pro forma adjustments primarily related to the fair value of property, plant and equipment, intangible assets, contractual arrangements, and deferred income taxes based on an estimate of the fair values and assumes an acquisition date of December 31, 2014. Talen Energy Supply arrived at the estimated fair values based on a preliminary review of the assets and liabilities of the RJS Power business and using assumptions for multiple factors that impact those values including various forecasted long-term energy, capacity and fuel commodity prices, discount rates and expected future cash flows. In addition the fair value measurements of the underlying assets and liabilities on RJS Powers balance sheet could change materially as these measurements will be applied to the assets and liabilities on the balance sheet as of the date of the Combination. These estimates are also subject to change pending further review by Talen Energy Supply of the assets acquired and liabilities assumed and any changes in market conditions and the assumptions used when determining the final purchase price allocation as of the date of the Combination. Generally accepted accounting principles in the United States require the purchase price allocation to be determined as of the date of the Combination, and also permit adjustments to the purchase price allocation for the RJS Power business during the measurement period, which may be up to one year from the date of the Combination. The preliminary purchase price allocation in the pro forma financial information is based upon the total consideration for the acquisition, which was deemed to be $902 million based on the fair value of the Talen Energy Corporation common stock issued for the acquisition using the June 1, 2015 closing when-issued market price. The preliminary allocation of the purchase price, after first applying the adjustments from (a) above and (i) below within this Note 2, and the resulting goodwill and pro forma adjustments are as follows: |
Debt (Credit) |
||||||||
Purchase Price Allocations |
Resulting Pro Forma Adjustments |
|||||||
Current assets |
$ | 236 | $ | 4 | (1) | |||
Property, plant and equipment, net |
2,153 | 742 | (2) | |||||
Goodwill |
322 | 322 | (3) | |||||
Other intangibles |
18 | 1 | (4) | |||||
Price risk management assets |
3 | |||||||
Other noncurrent assets |
26 | (30 | )(5) | |||||
Current liabilities |
(244 | ) | (9 | )(6) | ||||
Long-term debt |
(1,250 | ) | ||||||
Deferred income taxes |
(296 | ) | (296 | )(7) | ||||
Price risk management liabilities |
(20 | ) | ||||||
Asset retirement obligations |
(20 | ) | ||||||
Other deferred credits and noncurrent liabilities |
(26 | ) | (26 | )(8) | ||||
|
|
|
|
|||||
Net assets acquired |
$ | 902 | $ | (708 | )(9) | |||
|
|
|
|
19
(1) | Represents a $4 million debit to record a deferred tax asset. See (6) below for additional information regarding the blended statutory income tax rate and the treatment of income taxes in RJS Powers historical combined financial statements. |
(2) | Reflects an adjustment to record the estimated fair value of RJS Powers property, plant and equipment. The remaining estimated useful lives of RJS Powers property, plant and equipment range between 3 - 35 years. |
(3) | Reflects the preliminary estimate of the remaining purchase price after allocation to the net fair value of the RJS Power assets acquired and liabilities assumed based on the assumed acquisition date of December 31, 2014. The amount of goodwill calculated in this pro forma information differs from the goodwill provisionally included in the unaudited condensed consolidated financial statements of Talen Energy Supply and the accompanying notes contained elsewhere in this Appendix A due primarily to differences in working capital as of the date of the Combination. |
(4) | Reflects an adjustment primarily to record the fair value of a RJS Power license with an estimated amortization period of 22 years. |
(5) | Reflects an adjustment of $30 million to remove unamortized deferred financing fees of RJS Power which will not be allocated a fair value in purchase accounting. |
(6) | Reflects an adjustment, primarily to record the fair value of a RJS Power coal supply contracts with an estimated life of one year or less. |
(7) | Reflects deferred income tax liabilities recorded at a blended statutory income tax rate of 40.00%. The legal entities included in RJS Powers historical combined financial statements are primarily limited liability companies or partnerships and have previously elected to be treated as disregarded entities for federal tax purposes. As such, no provision for federal or state corporate income taxes was made in RJS Powers historical combined financial statements. |
(8) | Reflects an adjustment primarily to record the fair value of an RJS Power coal supply contract with an estimated life of 4 years. |
(9) | Members Equity, as a result of purchase accounting, was adjusted by the following: |
i. | The total consideration for the acquisition was deemed to be $902 million based on the fair value of the Talen Energy Corporation common stock issued for the acquisition using the June 1, 2015 closing when-issued market price. The $902 million is reflected as a contribution to Talen Energy Supply by its member, Talen Energy Corporation. |
ii. | Elimination of RJS Powers equity of $194 million. Includes the impact of the equity distribution described in (i) below within this Note 2. |
(c) | The pro forma statement of income includes adjustments for the anticipated disposal of generating facilities to satisfy the FERC Order, while the pro forma balance sheet reflects certain related assets and liabilities for these facilities as divested for cash at carrying value. These adjustments are based on certain assumptions related to: (1) which facilities and related assets and liabilities are anticipated to be divested to satisfy the FERC Order; and (2) the preliminary fair value of such assets and liabilities of RJS Power. Fair values were determined as described in (b) above within this Note 2. Final adjustments will be based on which generation facilities are actually divested, the related contractual terms and sales price, and timing of the divestitures. Therefore actual results could be materially different from the adjustments below. These adjustments are as follows: |
Balance Sheet: |
Debit (Credit) |
|||
Cash |
$ | 892 | ||
Current assets, other than cash |
(18 | ) | ||
Property, plant and equipment, net |
(884 | ) | ||
Goodwill |
(55 | ) | ||
Other noncurrent assets |
(17 | ) | ||
Current liabilities |
(74 | ) | ||
Long-term debt |
45 | |||
Deferred income taxes |
94 | |||
Asset retirement obligations |
4 | |||
Other deferred credits and noncurrent liabilities |
13 |
20
Balance Sheet: |
Debit (Credit) |
|||
Statement of Income: |
||||
Operating Revenues |
507 | |||
Operating Expenses |
(449 | ) | ||
Other income (expense), net |
1 | |||
Interest Expense |
(21 | ) | ||
Income Taxes |
(16 | ) |
The taxes payable related to the mitigation divestures are included in Current liabilities above.
(d) | The year ended December 31, 2014 reflects a $25 million increase in depreciation as a result of changes in the value of property, plant and equipment, a $1 million decrease in amortization expense as a result of changes in the value of intangible assets and a $7 million decrease in depreciation to reclassify ARO accretion to other operation and maintenance (consistent with Talen Energy Supplys presentation). See (b) above, within this Note 2 for information on the preliminary purchase price allocation. |
(e) | The year ended December 31, 2014 reflects an increase in interest expense of $5 million, primarily driven by higher short-term borrowing costs under the terms of the new $1.85 billion revolving credit facility, compared to historical interest expense related to outstanding commercial paper and letters of credit outstanding on Talen Energy Supplys and RJS Powers existing $3.0 billion and $150 million credit facilities, respectively. Interest expense was calculated based upon committed terms of the new $1.85 billion revolving credit facility for the historical outstanding borrowings and letters of credit using an estimated rate of 2.43%. See Description of Material Indebtedness for additional information on the revolving credit facility. |
(f) | To adjust certain Talen Energy Supply assets and liabilities associated with income taxes (to reflect settlement with a non-affiliate subsequent to the spinoff), pension and post-retirement benefit plans (to reflect separation of the plan obligations and allocation of plan assets as required by ERISA), other items as required, in accordance with the Separation Agreement or the Transaction Agreement and related deferred taxes. The following table presents the composition of these items: |
Debit (Credit) |
||||
Accounts receivable |
$ | 33 | ||
Prepayments |
(59 | ) | ||
Other current assets |
6 | |||
Accounts payable |
(7 | ) | ||
Taxes |
6 | |||
Other current liabilities |
22 | |||
Deferred income taxes |
(31 | ) | ||
Other deferred credits and noncurrent liabilities |
19 | |||
Members Equity |
11 |
(g) | To reflect $15 million for the payment of fees, which were deferred, for the new $1.85 billion Revolving Facility, which were effective upon closing of the spinoff and the Combination and replaced Talen Energy Supplys and RJS Powers existing $3.0 billion and $150 million credit facilities, respectively. Unamortized deferred fees from the existing $3.0 billion credit facility of $14 million were written off to Members Equity. |
(h) | Reflects the income tax effects of (1) the pro forma adjustments and (2) the Income (Loss) from Continuing Operations Before Income Taxes of RJS Power, which were calculated at a blended statutory income tax rate of 40.00%. See (b)(7) above, within this Note 2 for further discussion regarding the blended statutory income tax rate and the treatment of income taxes in RJS Powers historical combined financial statements. |
(i) | Under the terms of the Transaction Agreement, RJS Power was permitted to distribute cash to its members under certain circumstances. It was expected that at or prior to the spinoff, RJS Power would distribute |
21
available cash up to the maximum amount allowable under the Transaction Agreement, which at December 31, 2014 was $55 million. A pro forma adjustment has been made to reflect the distribution of that amount from equity, which included $30 million of available cash and a drawdown on the RJS Power credit facility of $25 million. In addition, it was expected that such drawdown, together with outstanding borrowings under the RJS Power credit facility of $25 million at December 31, 2014 would be replaced by borrowings of $50 million under the new $1.85 billion Talen Energy Supply credit facility. Such borrowings were expected to be of a short-term nature and have been reclassified to Short-term debt on the Balance Sheet. Also, in accordance with the terms of the Transaction Agreement, a $191 million cash distribution was made from Talen Energy Supply to PPL during the first quarter of 2015 and a pro forma adjustment has been made to reflect such distribution. |
Note 3. Items Excluded from the Unaudited Pro Forma Financial Information and Unusual Items
The unaudited pro forma financial information does not reflect:
(a) | the costs of any integration activities or benefits that may result from realization of future cost savings from operating efficiencies or synergies expected to result from the spinoff and Combination. |
(b) | the impact of divesting an alternative asset portfolio identified in the FERC Order. If such alternative asset portfolio were divested instead of the asset portfolio adjusted for within the pro forma financial information, pro forma operating revenues would have increased by approximately $150 million, pro forma operating income would have increased approximately $25 million, and pro forma cash would have decreased approximately $50 million. |
In addition, although Talen Energy expects to employ a growth strategy and proceeds from the anticipated FERC Order mitigation divestitures may be used for future acquisitions, for the purposes of the pro forma information, the proceeds from divestitures included have not been assumed to be invested in similar business operations and accordingly are reflected in cash on the pro forma balance sheet.
(c) | additional costs of $25 million that were incurred and recognized at the spinoff date for accelerated stock-based compensation and prorated performance-based cash incentive and stock-based compensation awards primarily for Talen Energy Supply employees and for PPL employees who became Talen Energy Supply employees in connection with the transaction. |
(d) | adjustments for the announced planned acquisition of MACH Gen, LLC or the announced planned disposition of the renewables business, both of which are not required under pro forma rules as the businesses to not meet the significance thresholds. |
(e) | the increase in Talen Energy Supplys long-term debt, and corresponding decrease in short-term debt, as a result of the issuance of $600 million of 6.50% Senior Unsecured Notes in May 2015 and corresponding use of proceeds. |
The unaudited pro forma financial information includes the following unusual items:
(a) | Other operation and maintenance on Talen Energy Supplys Statement of Income includes charges of $33 million ($20 million after-tax) associated with separation benefits related to a bargaining unit voluntary program and the spinoff transaction. |
(b) | Energy-related businesses on Talen Energy Supplys Statement of Income includes an increase to revenues of $17 million ($10 million after-tax) to correct an error related to prior periods and the timing of revenue recognition for a mechanical contracting and engineering subsidiary. See Note 1 to the audited consolidated financial statements of Talen Energy Supply included elsewhere in this Appendix A for additional information. |
(c) | Interest expense on RJS Powers Statement of Income includes losses on extinguishment of debt of $36 million ($21 million after-tax). |
22
Note 4. Reconciliation of Cash and Cash Equivalents Pro Forma Adjustments
The following table presents a reconciliation of the cash and cash equivalents pro forma adjustments:
Debit (Credit) |
||||||
Proceeds from anticipated disposal of generating facilities |
Note 2 (c) | $ | 892 | |||
Payment of fees on new revolving credit facility |
Note 2 (g) | (15 | ) | |||
RJS Power distribution of available cash |
Note 2 (i) | (30 | ) | |||
Talen Energy Supply distribution |
Note 2 (i) | (191 | ) | |||
|
|
|||||
Net cash and cash equivalents pro forma adjustments |
$ | 656 | ||||
|
|
23