Attached files
| file | filename |
|---|---|
| 8-K - ENTERGY CORP /DE/ | a01413.htm |
| EX-99.2 - ENTERGY CORP /DE/ | a01413992.htm |
| EX-99.3 - ENTERGY CORP /DE/ | a01413993.htm |
|
For further information:
Paula Waters, VP, Investor Relations
504/576-4380
pwater1@entergy.com
|
INVESTOR NEWS
Exhibit 99.1
April 25, 2013
ENTERGY REPORTS FIRST QUARTER EARNINGS
NEW ORLEANS – Entergy Corporation (NYSE: ETR) reported earnings of $0.90 per share on an as-reported basis and $0.94 per share on an operational basis for first quarter 2013, as shown in Table 1 below. A more detailed discussion of quarterly results begins on page 2 of this release.
|
Table 1: Consolidated Earnings – Reconciliation of GAAP to Non-GAAP Measures
|
||||||
|
First Quarter 2013 vs. 2012
|
||||||
|
(Per share in U.S. $)
|
||||||
|
First Quarter
|
||||||
|
2013
|
2012
|
Change
|
||||
|
As-Reported Earnings
|
0.90
|
(0.86)
|
1.76
|
|||
|
Less Special Items
|
(0.04)
|
(1.30)
|
1.26
|
|||
|
Operational Earnings
|
0.94
|
0.44
|
0.50
|
|||
|
Weather Impact
|
(0.10)
|
(0.18)
|
0.08
|
|||
Operational Earnings Highlights for First Quarter 2013
|
·
|
Utility earnings were higher driven by higher net revenue and lower income tax expense, partially offset by increased non-fuel operation and maintenance expense and higher depreciation expense.
|
|
·
|
Entergy Wholesale Commodities earnings increased due primarily to an increase in net revenue.
|
|
·
|
Parent & Other results declined due to several individually insignificant items.
|
“First quarter results reflected top-line growth in both the Utility and EWC businesses,” said Leo Denault, Entergy’s chairman and chief executive officer. “Stronger Utility results were driven by major generation investments in 2012 that benefited our customers through portfolio enhancements by adding modern, efficient natural-gas facilities and capital improvements to the nuclear fleet. The Utility’s positive results also reflect efficient regulatory processes that recognize the benefits of prudent investment and include those investments in rates. At EWC, stronger spot northeast power prices resulted in average prices significantly above expectations. Prices reflected tight regional gas supplies and high delivered-gas prices into New England markets this winter, demonstrating the value of diversity as well as low marginal cost and highly reliable and virtually emission-free resources.
“These developments are part of ongoing efforts to create sustainable value for all of our stakeholders – owners, customers, employees and the communities we serve. Strategic imperatives key to our success include growing Utility earnings, improving EWC results, executing on our transmission initiatives, and optimizing the organization through human capital management.”
Entergy’s business highlights also included the following:
|
·
|
ITC shareholders approved the merger with Entergy’s transmission business, one of the steps in the proposed spin-merge transaction.
|
|
·
|
EAI has reached agreement on a long-term contract for a new, large-scale industrial facility, a steel mill near Osceola, Ark. EAI expects a public service commission ruling on its contract by May 20.
|
|
·
|
For the second year in a row, the U.S. EPA has recognized ETI with a 2013 ENERGY STAR Partner of the Year Award for its outstanding contributions to reducing greenhouse gas emissions through energy efficiency programs for its customers.
|
|
·
|
Vermont Yankee nuclear power plant completed another breaker-to-breaker run, operating continuously for the full operating cycle, 493 days straight.
|
|
·
|
Entergy has been included on Corporate Responsibility Magazine’s 100 Best Corporate Citizens List.
|
A teleconference will be held at 10 a.m. CT on Thursday, April 25, 2013, to discuss Entergy’s first quarter 2013 earnings announcement and may be accessed by dialing (719) 457-2080, confirmation code 9708842, no more than 15 minutes prior to the start of the call. The call and presentation slides can also be accessed via Entergy’s website at www.entergy.com. A replay of the teleconference will be available by telephone and on Entergy’s website at www.entergy.com as soon as practical after the transcript is filed with the U.S. Securities and Exchange Commission due to filing requirements associated with the proposed spin-off and merger of Entergy’s transmission business with ITC. The telephone replay will be available through May 2, 2013, by dialing (719) 457-0820, confirmation code 9708842.
|
I.
|
Consolidated Results
|
Consolidated Earnings
Table 2 provides a comparative summary of consolidated earnings per share for first quarter 2013 versus 2012, including a reconciliation of GAAP as-reported earnings to non-GAAP operational earnings. A detailed discussion of the factors driving quarterly results at each business segment follows.
|
Table 2: Consolidated Earnings – Reconciliation of GAAP to Non-GAAP Measures
First Quarter 2013 vs. 2012 (see Appendix F for definitions of certain measures)
|
|||||
|
(Per share in U.S. $)
|
|||||
|
First Quarter
|
|||||
|
2013
|
2012
|
Change
|
|||
|
As-Reported
|
|||||
|
Utility
|
0.69
|
0.35
|
0.34
|
||
|
Entergy Wholesale Commodities
|
0.46
|
(0.99)
|
1.45
|
||
|
Parent & Other
|
(0.25)
|
(0.22)
|
(0.03)
|
||
|
Consolidated As-Reported Earnings
|
0.90
|
(0.86)
|
1.76
|
||
|
Less Special Items
|
|||||
|
Utility
|
(0.04)
|
(0.03)
|
(0.01)
|
||
|
Entergy Wholesale Commodities
|
-
|
(1.26)
|
1.26
|
||
|
Parent & Other
|
-
|
(0.01)
|
0.01
|
||
|
Consolidated Special Items
|
(0.04)
|
(1.30)
|
1.26
|
||
|
Operational
|
|||||
|
Utility
|
0.73
|
0.38
|
0.35
|
||
|
Entergy Wholesale Commodities
|
0.46
|
0.27
|
0.19
|
||
|
Parent & Other
|
(0.25)
|
(0.21)
|
(0.04)
|
||
|
Consolidated Operational Earnings
|
0.94
|
0.44
|
0.50
|
||
|
Weather Impact
|
(0.10)
|
(0.18)
|
0.08
|
||
Detailed earnings variance analysis is included in Appendix B-1 to this release. In addition, Appendix B-2 provides details of special items shown in Table 2 above.
Consolidated Net Cash Flow Provided by Operating Activities
Entergy’s net cash flow provided by operating activities in first quarter 2013 was $544 million compared to $601 million in first quarter 2012. The overall quarterly decrease was due primarily to higher deferred fuel refunds and non-capital storm spending associated with Hurricane Isaac and the late December 2012 Arkansas ice storm. These decreases were partially offset by higher EWC net revenue.
Table 3 provides the components of net cash flow provided by operating activities contributed by each business with current quarter comparisons.
|
Table 3: Consolidated Net Cash Flow Provided by Operating Activities
|
|||
|
First Quarter 2013 vs. 2012
|
|||
|
(U.S. $ in millions)
|
|||
|
First Quarter
|
|||
|
2013
|
2012
|
Change
|
|
|
Utility
|
369
|
483
|
(114)
|
|
Entergy Wholesale Commodities
|
235
|
164
|
71
|
|
Parent & Other
|
(60)
|
(46)
|
(14)
|
|
Total Net Cash Flow Provided by Operating Activities
|
544
|
601
|
(57)
|
|
II.
|
Utility
|
In first quarter 2013, Utility earnings were $0.69 per share on an as-reported basis and $0.73 per share on an operational basis, compared to as-reported earnings per share of $0.35 and operational earnings per share of $0.38 in first quarter 2012. The quarter-over-quarter increase in Utility operational earnings per share was due largely to higher net revenue. Lower income tax expense associated with Entergy’s write off of an EGSL regulatory asset in first quarter 2012 also contributed to the earnings increase.
Higher net revenue was attributable to both volume and pricing factors. Utility net revenue in the current quarter reflected the net effect of pricing adjustments from regulatory actions and investments, primarily from placing in service the Grand Gulf extended power uprate, Waterford 3 steam generator replacement and the Hinds and Hot Spring power plant acquisitions. A portion of the net revenue increase was for recovery of costs below the net revenue line including depreciation, taxes other than income taxes and non-fuel operation and maintenance expenses.
Net revenue also reflected higher retail sales volume, attributable to weather. Both periods had negative weather effects, but the weather in the current quarter was not as mild as first quarter 2012. On a weather-adjusted basis, billed retail sales were flat quarter-over-quarter. Increased sales in residential and commercial and governmental segments offset declining sales in the industrial segment. Industrial sales declined quarter over quarter due largely to moderating global economic growth and little to no growth in exports. These effects were felt especially in the chemicals segment resulting in reduced capacity factors.
Retail electric sales in billed gigawatt-hours are summarized in Table 4. Overall, total billed retail sales on a weather-adjusted basis were flat quarter over quarter, but varied by segment as follows:
|
·
|
Residential sales in first quarter 2013, on a weather-adjusted basis, increased 0.8 percent compared to first quarter 2012.
|
|
·
|
Commercial and governmental sales, on a weather-adjusted basis, increased 0.5 percent quarter over quarter.
|
|
·
|
Industrial sales in the first quarter decreased (0.9) percent compared to the same quarter of 2012.
|
These items were partially offset by higher non-fuel operation and maintenance expense and higher depreciation expense. As noted above, some of the increased expenses were associated with plant acquisitions and regulatory actions which were offset in net revenue.
Table 4 provides a comparative summary of Utility operational performance measures.
|
Table 4: Utility Operational Performance Measures
|
|||||
|
First Quarter 2013 vs. 2012 (see Appendix F for definitions of certain measures)
|
|||||
|
First Quarter
|
|||||
|
2013
|
2012
|
% Change
|
% Weather Adjusted
|
||
|
GWh billed
|
|||||
|
Residential
|
8,344
|
7,760
|
7.5%
|
0.8%
|
|
|
Commercial and governmental
|
7,005
|
6,992
|
0.2%
|
0.5%
|
|
|
Industrial
|
9,868
|
9,958
|
(0.9)%
|
(0.9)%
|
|
|
Total Retail Sales
|
25,217
|
24,710
|
2.1%
|
-
|
|
|
Wholesale
|
630
|
732
|
(13.9)%
|
||
|
Total Sales
|
25,847
|
25,442
|
1.6%
|
||
|
O&M expense per MWh (a)
|
$21.02
|
$20.08
|
4.7%
|
||
|
Number of retail customers
|
|||||
|
Residential
|
2,388,522
|
2,373,715
|
0.6%
|
||
|
Commercial and governmental
|
356,809
|
354,675
|
0.6%
|
||
|
Industrial
|
38,744
|
38,314
|
1.1%
|
||
|
Total Retail Customers
|
2,784,075
|
2,766,704
|
0.6%
|
||
|
|
(a)
|
Excludes the special item associated with the proposed spin-merge of the transmission business.
|
Appendix C provides information on selected pending local and federal regulatory cases.
|
III.
|
Entergy Wholesale Commodities
|
EWC operational adjusted EBITDA was $194 million in the first quarter of 2013, compared to $144 million in the same period a year ago, as shown in Table 5.
|
Table 5: Entergy Wholesale Commodities Operational Adjusted EBITDA – Reconciliation of GAAP to Non-GAAP Measures
|
|||
|
First Quarter 2013 vs. 2012 (see Appendix F for definitions of certain measures)
|
|||
|
($ in millions)
|
|||
|
First Quarter
|
|||
|
2013
|
2012
|
Change
|
|
|
Net income
|
82
|
(176)
|
258
|
|
Add back: interest expense
|
3
|
6
|
(3)
|
|
Add back: income tax expense
|
57
|
(92)
|
149
|
|
Add back: depreciation and amortization
|
49
|
51
|
(2)
|
|
Subtract: interest and investment income
|
28
|
31
|
(3)
|
|
Add back: decommissioning expense
|
31
|
30
|
1
|
|
Adjusted EBITDA
|
194
|
(212)
|
406
|
|
Add back: special item for asset impairment
|
-
|
356
|
(356)
|
|
Operational adjusted EBITDA
|
194
|
144
|
50
|
The EWC operational adjusted EBITDA increase was due largely to higher net revenue from the nuclear portfolio on higher energy and capacity prices. Average realized revenue per megawatt hour for the nuclear fleet was approximately $58 in the current quarter, up from approximately $50 in the same period last year. The effect of higher prices was partially offset by an increase in nuclear refueling and unplanned outage days.
EWC earnings per share for first quarter 2013 were $0.46 on an as-reported and an operational basis, compared to the first quarter 2012 as-reported loss of $(0.99) per share and operational earnings of $0.27 per share. The increase in operational earnings was largely attributable to the operational adjusted EBITDA drivers noted above. An asset impairment of the Vermont Yankee nuclear power plant recorded in first quarter 2012 contributed to the as-reported increase.
Table 6 provides a comparative summary of EWC operational performance measures.
|
Table 6: Entergy Wholesale Commodities Operational Performance Measures
|
||||
|
First Quarter 2013 vs. 2012 (see Appendix F for definitions of certain measures)
|
||||
|
First Quarter
|
||||
|
2013
|
2012
|
% Change
|
||
|
Owned capacity (MW)
|
6,612
|
6,612
|
-
|
|
|
GWh billed
|
10,387
|
11,281
|
(7.9)%
|
|
|
Net revenue ($ millions)
|
493
|
452
|
9.1%
|
|
|
Average realized revenue per MWh
|
$58.66
|
$49.29
|
19.0%
|
|
|
Non-fuel O&M expense per MWh (b)
|
$25.22
|
$23.93
|
5.4%
|
|
|
EWC Nuclear Fleet
|
||||
|
Capacity factor
|
83%
|
88%
|
(5.7)%
|
|
|
GWh billed
|
9,246
|
9,838
|
(6.0)%
|
|
|
Average realized revenue per MWh
|
$57.82
|
$50.32
|
14.9%
|
|
|
Production cost per MWh
|
$25.94
|
$25.85
|
0.3%
|
|
|
Refueling outage days
|
||||
|
Indian Point 2
|
-
|
27
|
||
|
Indian Point 3
|
28
|
-
|
||
|
Vermont Yankee (c)
|
22
|
-
|
||
|
|
(b)
|
First quarter 2012 excludes the effect of the special item for impairment of the Vermont Yankee assets.
|
|
|
(c)
|
Vermont Yankee had four refueling outage days in second quarter 2013.
|
Table 7 provides information on current forward capacity and generation contracts for EWC’s fleet, as well as total revenue projections based on market prices as of March 31, 2013. EWC uses a combination of forward physical and financial contracts, including swaps, collars, put and/or call options, to manage forward commodity price risk. Certain hedge volumes have price downside and upside relative to market price movements. The contracted minimum, current expected value and sensitivity are provided to show potential variations. While the sensitivity reflects the minimum, it may not reflect the total maximum upside potential from higher market prices. Information contained in Table 7 represents projections at a point in time and will vary over time based on numerous factors, such as future market prices, contracting activities and generation.
|
Table 7: Entergy Wholesale Commodities Capacity and Generation
|
|||||
|
Second Quarter 2013 through 2017 (see Appendix F for definitions of certain measures)
|
|||||
|
(based on market prices as of March 31, 2013) (d)
|
|||||
|
Balance of 2013
|
2014
|
2015
|
2016
|
2017
|
|
|
EWC Nuclear Portfolio
|
|||||
|
Energy
|
|||||
|
Planned TWh of generation
|
31
|
41
|
41
|
40
|
41
|
|
Percent of planned generation under contract
|
|||||
|
Unit-contingent
|
41%
|
22%
|
12%
|
12%
|
13%
|
|
Unit-contingent with availability guarantees
|
20%
|
15%
|
13%
|
13%
|
13%
|
|
Firm LD
|
23%
|
58%
|
14%
|
-%
|
-%
|
|
Offsetting positions
|
-%
|
(19)%
|
-%
|
-%
|
-%
|
|
Total
|
84%
|
76%
|
39%
|
25%
|
26%
|
|
Average revenue per MWh on contracted volumes
|
|||||
|
Minimum
|
$44
|
$44
|
$45
|
$50
|
$51
|
|
Expected based on current market prices
|
$45
|
$47
|
$48
|
$51
|
$52
|
|
Sensitivity: -/+ $10 per MWh market price change
|
$44 - $48
|
$44 - $51
|
$45 - $54
|
$50 - $54
|
$51 - $55
|
|
Capacity
|
|||||
|
Planned net MW in operation
|
5,011
|
5,011
|
5,011
|
5,011
|
5,011
|
|
Percent of capacity sold forward
|
|||||
|
Bundled capacity and energy contracts
|
16%
|
16%
|
16%
|
16%
|
16%
|
|
Capacity contracts
|
35%
|
17%
|
12%
|
18%
|
9%
|
|
Total
|
51%
|
33%
|
28%
|
34%
|
25%
|
|
Average revenue under contract per kW per month
(applies to capacity contracts only)
|
$2.0
|
$2.4
|
$3.3
|
$3.2
|
$3.2
|
|
Total Nuclear Energy and Capacity Revenues
|
|||||
|
Expected sold and market total revenue per MWh
|
$48
|
$47
|
$47
|
$49
|
$51
|
|
Sensitivity: -/+ $10 per MWh market price change
|
$46 - $53
|
$44 - $53
|
$40 - $55
|
$42 - $57
|
$43 - $58
|
|
EWC Non-Nuclear Portfolio
|
|||||
|
Energy
|
|||||
|
Planned TWh of generation
|
5
|
6
|
6
|
6
|
6
|
|
Percent of planned generation under contract
|
|||||
|
Cost-based contracts
|
35%
|
32%
|
35%
|
32%
|
32%
|
|
Firm LD
|
6%
|
6%
|
6%
|
6%
|
6%
|
|
Total
|
41%
|
38%
|
41%
|
38%
|
38%
|
|
Capacity
|
|||||
|
Planned net MW in operation
|
1,052
|
1,052
|
1,052
|
1,052
|
977
|
|
Percent of capacity sold forward
|
|||||
|
Cost-based contracts
|
30%
|
24%
|
24%
|
24%
|
26%
|
|
Bundled capacity and energy contracts
|
9%
|
8%
|
8%
|
8%
|
8%
|
|
Capacity contracts
|
45%
|
50%
|
48%
|
47%
|
21%
|
|
Total
|
84%
|
82%
|
80%
|
79%
|
55%
|
|
Total Non-Nuclear Net Revenue
|
|||||
|
Expected portfolio net revenue in $ millions
|
$59
|
$84
|
$83
|
$96
|
$96
|
|
(d)
|
Assumes uninterrupted normal operation at all plants. NRC license renewal applications are in process for both Indian Point units; current license expirations are 9/28/13 for Indian Point 2 and 12/12/15 for Indian Point 3.
|
|
IV.
|
Parent & Other
|
Parent & Other reported a loss of $(0.25) per share on an as-reported and an operational basis in first quarter 2013, compared to an as-reported loss of $(0.22) per share and an operational loss of $(0.21) per share in first quarter 2012. The decrease was attributable to several individually insignificant items.
|
V.
|
2013 Earnings Guidance
|
Entergy updated its 2013 earnings guidance range to be $4.56 to $5.36 per share on an as-reported basis and affirmed operational guidance of $4.60 to $5.40 per share. The revised as-reported guidance range reflects special items recorded in the current quarter for expenses in connection with the proposed spin-off and merger of Entergy’s transmission business with ITC.
The 2013 earnings guidance is detailed in Table 8. Year-over-year changes are shown as point estimates and are applied to 2012 earnings to compute the 2013 guidance midpoint. Drivers for the 2013 earnings guidance range are listed separately. Because there is a range of possible outcomes associated with each earnings driver, a range is applied to the guidance midpoint to produce Entergy’s guidance range. As-reported earnings guidance for 2013 does not reflect potential future expenses for the proposed spin-merge of the transmission business with ITC. The as-reported 2013 guidance will be updated throughout the year as these transaction-related expenses are incurred.
|
Table 8: 2013 Earnings Per Share Guidance – As-Reported and Operational
|
|||||
|
(Per share in U.S. $) – As-reported last updated April 2013 (e)
|
|||||
|
Segment
|
Description of Drivers
|
2012 Earnings per Share
|
Expected Change
|
2013
Guidance
Midpoint
|
2013 Guidance Range
|
|
Utility
|
2012 Operational Earnings per Share
|
5.51
|
|||
|
Adjustment to normalize weather
|
0.09
|
||||
|
Increased net revenue due to absence of second quarter 2012 regulatory charge
|
0.57
|
||||
|
Increased net revenue due to retail sales growth and rate actions
|
1.25
|
||||
|
Increased non-fuel operation and maintenance expense
|
(0.40)
|
||||
|
Increased taxes other than income taxes
|
(0.10)
|
||||
|
Increased depreciation expense
|
(0.35)
|
||||
|
Decreased other income
|
(0.05)
|
||||
|
Increased interest and other charges
|
(0.10)
|
||||
|
Higher effective income tax rate
|
(1.85)
|
||||
|
Other
|
0.13
|
||||
|
Subtotal
|
5.51
|
(0.81)
|
4.70
|
||
|
Entergy Wholesale Commodities
|
2012 Operational Earnings per Share
|
1.49
|
|||
|
Decreased net revenue due primarily to lower pricing on nuclear assets
|
(0.40)
|
||||
|
Increased non-fuel operation and maintenance expense
|
(0.15)
|
||||
|
Increased decommissioning expense
|
(0.15)
|
||||
|
Increased depreciation expense
|
(0.10)
|
||||
|
Lower effective income tax rate
|
0.10
|
||||
|
Other
|
0.01
|
||||
|
Subtotal
|
1.49
|
(0.69)
|
0.80
|
||
|
Parent & Other
|
2012 Operational Earnings per Share
|
(0.77)
|
|||
|
Increased Parent interest expense
|
(0.05)
|
||||
|
Lower income tax expense
|
0.30
|
||||
|
Other
|
0.02
|
||||
|
Subtotal
|
(0.77)
|
0.27
|
(0.50)
|
||
|
Consolidated Operational
|
2013 Operational Earnings per Share Guidance Range
|
6.23
|
(1.23)
|
5.00
|
4.60 – 5.40
|
|
Consolidated As-Reported
|
2012 As-Reported Earnings per Share
|
4.76
|
|||
|
Changes detailed above
|
(1.23)
|
||||
|
2012 Expenses associated with the proposed spin-merge of Entergy’s transmission business
|
0.21
|
||||
|
2012 Asset impairment on Vermont Yankee nuclear power plant
|
1.26
|
||||
|
Year-to-date 2013 special item for expenses associated with proposed spin-merge of Entergy’s transmission business
|
(0.04)
|
||||
|
2013 As-Reported Earnings per Share Guidance Range
|
4.76
|
0.20
|
4.96
|
4.56 – 5.36
|
|
|
(e)
|
Originally prepared November 2012 and updated February 2013 to reflect 2012 final results; also updated the as-reported guidance range in April 2013.
|
Key assumptions supporting 2013 operational earnings guidance are as follows:
Utility
|
·
|
Normal weather
|
|
·
|
Increased net revenue due to the absence of the second quarter 2012 regulatory charge
|
|
·
|
Retail sales growth of around 1.25 percent on a weather-adjusted basis
|
|
·
|
Increased net revenue from rate actions, including those associated with the Waterford 3 steam generator replacement project, a full year of the Grand Gulf extended power uprate and the Hinds and Hot Spring acquisitions, which are partially offset by increases in non-fuel operation and maintenance expense, depreciation expense and taxes other than income taxes
|
|
·
|
Increased non-fuel operation and maintenance expense due to plant acquisitions and other general expense increases
|
|
·
|
Increased taxes other than income taxes resulting largely from new plant acquisitions as well as increased franchise taxes
|
|
·
|
Increased depreciation expense associated with capital spending at the Utility and the new depreciation rates established in the ETI rate case in July 2012
|
|
·
|
Decreased other income due primarily to lower allowance for equity funds used during construction as significant projects moved into service (Waterford 3 steam generator, Grand Gulf extended power uprate)
|
|
·
|
Increased interest expense due primarily to a higher level of debt outstanding
|
|
·
|
Higher effective income tax rate in 2013, due largely to the net effect of items recorded in 2012
|
Entergy Wholesale Commodities
|
·
|
EWC drivers represent expected variances at the segment level for 2013
|
|
·
|
46 TWh of output for the total fleet, reflecting an approximate 92 percent nuclear capacity factor compared to an 89 percent nuclear capacity factor in 2012; 2013 includes approximately 30- to 35-day scheduled refueling outages at Indian Point 3, Pilgrim and Vermont Yankee in Spring 2013 and Palisades in Fall 2013 (outage days vary depending on the scope of the outage)
|
|
·
|
Assumes full year operations for all nuclear plants
|
|
·
|
$47/MWh average total energy and capacity revenues for EWC-nuclear fleet based on published market prices at the end of September 2012
|
|
o
|
$45/MWh average revenue per MWh on contracted energy volumes, representing 84 percent of planned generation (prepared November 2012)
|
|
o
|
$43/MWh average market price on 16 percent unsold energy volumes (prepared November 2012); as of the end of March 2013, average market energy price for unsold volumes was approximately $50/MWh
|
|
o
|
$2.3/kW-month average capacity revenue under contract on 28 percent capacity (excludes bundled capacity contracts, which are priced within the contracted energy volumes above) (prepared November 2012)
|
|
o
|
$1.8/kW-month average capacity price on 56 percent unsold capacity (prepared November 2012); as of the end of March 2013, average market capacity price for unsold volumes was approximately $3.2/kW-month
|
|
·
|
$77 million non-nuclear portfolio net revenue based on prices at the end of September 2012
|
|
·
|
Nuclear fuel expense around $6.5/MWh for 2013 compared to approximately $5.9/MWh for 2012
|
|
·
|
Decreased purchased power expense reflected in net revenue
|
|
·
|
Non-fuel operation and maintenance expense, including nuclear refueling outage expenses, around $24.3/MWh reflecting increases in refueling outage amortization for Vermont Yankee following a reduction in 2012 due to the asset impairment, general expense increases and higher costs at RISEC due to higher maintenance outage costs
|
|
·
|
Increased decommissioning expense due to the absence of a reduction in the asset retirement obligation resulting from updated decommissioning cost studies completed in the second quarter 2012, which reduced decommissioning expense in the prior year period
|
|
·
|
Increased depreciation expense on nuclear assets due to higher depreciable plant balances as well as declining useful life of nuclear assets; also contributing was the absence of the third quarter 2012 DOE litigation awards for Indian Point 2 which resulted in a reversal of previously recorded depreciation expense
|
|
·
|
Lower effective income tax rate in 2013
|
Parent & Other
|
·
|
Higher Parent interest expense due largely to higher average debt outstanding
|
|
·
|
Lower income tax expense on Parent & Other activities
|
Other
|
·
|
2013 average fully diluted shares outstanding of approximately 177 million
|
|
·
|
Overall effective income tax rate of 34 percent in 2013, the timing and segment of which may ultimately vary
|
|
·
|
Pension discount rate of 5.1 percent; the final average pension discount rate is 4.36 percent
|
Earnings guidance for 2013 should be considered in association with earnings sensitivities as shown in Table 9. These sensitivities illustrate the estimated change in operational earnings per share resulting from changes in various revenue and expense drivers. Traditionally, the most significant variables for earnings drivers are retail sales for the Utility and energy prices for EWC. In addition, the earnings guidance range for 2013 takes into consideration a number of regulatory initiatives (rate actions) underway across the Utility jurisdictions.
Estimated annual impacts shown in Table 9 are intended to be indicative rather than precise guidance.
|
Table 9: 2013 Earnings Sensitivities
|
|||
|
(Per share in U.S. $) – Prepared November 2012
|
|||
|
Variable
|
2013 Guidance Assumption
|
Description of Change
|
Estimated
Annual Impact
|
|
Utility
|
|||
|
Retail sales growth
Residential
Commercial / Governmental
Industrial
|
Around 1.25% retail sales growth on a weather adjusted basis
|
1% change in Residential MWh sold
1% change in Comm / Govt MWh sold
1% change in Industrial MWh sold
|
- / + 0.05
- / + 0.04
- / + 0.02
|
|
Rate base
|
Growing rate base
|
$100 million change in rate base
|
- / + 0.03
|
|
Return on equity
|
Authorized regulatory ROEs
|
1% change in allowed ROE
|
- / + 0.41
|
|
Non-fuel operation and maintenance expense
|
Increased due to plant acquisitions and general expenses
|
1% change in expense
|
+ / - 0.08
|
|
Entergy Wholesale Commodities (f)
|
|||
|
Nuclear capacity factor
|
92% capacity factor
|
1% change in capacity factor
|
- / + 0.06
|
|
EWC revenue
|
$47/MWh nuclear revenue;
$77M non-nuclear net revenue
|
$10/MWh market price change
|
- 0.25 / + 0.49
|
|
Total non-fuel operation and maintenance expense
|
$24.3/MWh non-fuel operation and maintenance expense
|
1% change in expense
|
+ / - 0.04
|
|
Nuclear Outage (lost revenue only)
|
92% capacity factor, including refueling outages for four EWC nuclear units
|
1,000 MW plant for 10 days at average portfolio energy price of $45/MWh for contracted volumes and $43/MWh for unsold volumes in 2013 (assuming no resupply option exercise)
|
- 0.03 / n/a
|
|
Consolidated
|
|||
|
Interest expense
|
Higher debt outstanding balances
|
1% change in interest rate on $1 billion debt
|
+ / - 0.03
|
|
Pension and other postretirement costs (expense portion only)
|
Discount rate of 5.1%
|
0.25% change
|
- / + 0.07
|
|
Effective income tax rate
|
34% effective income tax rate
|
1% change in overall effective income tax rate
|
+ / - 0.08
|
|
(f)
|
Assumes uninterrupted normal operation at all nuclear plants.
|
|
VI.
|
Long-term Financial Outlook
|
Entergy believes it offers a long-term, competitive utility investment opportunity combined with a valuable option represented by a unique, clean, non-utility generation business located in attractive power markets. Table 10 summarizes the current five-year financial outlook for 2010 through 2014. Entergy also noted that the five-year financial outlook does not reflect the effects of the proposed spin-merge of the transmission business discussed in Appendix A.
|
Table 10: Long-term Financial Outlook (see Appendix F for definitions of certain measures)
|
||
|
As of April 2013
|
||
|
Category
|
Long-term Outlook
|
Assumption
|
|
Earnings
|
Utility net income
|
Around 6 percent compound annual net income growth rate over the 2010 – 2014 horizon (2009 base year).
|
|
Entergy Wholesale Commodities results
|
Revenue projections through 2014 will experience volatility due to commodity market activities – one of the most important fundamental drivers for this business. At current sold and forward prices with its existing asset portfolio and contracts, EWC is expected to deliver declining adjusted EBITDA for the period through 2014 compared to 2010. However, EWC offers a valuable long-term option from the potential positive effects of economic growth (driving increased load, market heat rates, capacity prices and natural gas prices), aging and unprofitable unit retirements (driving market heat rate expansion and capacity price increases), rationalization of supply and growth of demand in natural gas markets and impacts from environmental legislation.
|
|
|
Corporate results
|
Results will vary depending upon factors including future effective income tax and interest rates and the amount / timing of share repurchases, if any.
|
|
|
Capital Deployment
|
A balanced capital investment / return program
|
Entergy continues to see value-added investment opportunities at the Utility that benefit customers, as well as an investment outlook at EWC that supports continued safe, secure and reliable operations and opportunistic investments. Entergy aspires to fund this capital program without issuing traditional common equity, while maintaining a competitive capital return program. Given the company’s financial profile with a mix of utility and non-utility businesses, both common stock dividends and share repurchases will be considered in establishing return of capital policies. Over the five year period from 2010 – 2014 under the current long-term business outlook, capital deployment through dividends and share repurchases is projected to total around $4 billion. The amount of share repurchases may vary as a result of material changes in business results, capital spending or new investment opportunities.
|
|
Credit Quality
|
Strong liquidity.
|
|
|
Solid credit metrics that support ready access to capital on reasonable terms.
|
||
|
VII.
|
Appendices
|
Seven appendices are presented in this section as follows:
|
·
|
Appendix A includes information on Entergy’s plan to spin off the Utility transmission business and merge that business with a subsidiary of ITC.
|
|
·
|
Appendix B includes earnings per share variance analysis and detail on special items that relate to the current quarter results.
|
|
·
|
Appendix C provides information on selected pending local and federal Utility regulatory cases and events.
|
|
·
|
Appendix D provides financial metrics for both current and historical periods. In addition, historical financial and operating performance metrics are included for the trailing eight quarters.
|
|
·
|
Appendix E provides a summary of planned capital expenditures for the next three years.
|
|
·
|
Appendix F provides definitions of the operational performance measures, GAAP and non-GAAP financial measures and abbreviations or acronyms that are used in this release.
|
|
·
|
Appendix G provides a reconciliation of GAAP to non-GAAP financial measures used in this release.
|
|
A.
|
Spin-Merge of Transmission Business
|
In December 2011, the Entergy and ITC boards of directors approved a definitive agreement under which Entergy will spin off and then merge its electric transmission business with a subsidiary of ITC. The transaction is targeted to close in 2013 and is subject to the satisfaction of certain closing conditions. Regulatory filings include the Entergy Utility operating companies’ retail regulators and the Missouri Public Service Commission, as well as several federal agencies. ITC shareholders approved the transaction on April 16, 2013.
Appendix A provides a summary of certain activities that are pending.
|
Appendix A: Regulatory Summary Table for Spin-Merge of Transmission Business (see Appendix F for definitions of certain abbreviations or acronyms)
|
|
|
Proceeding
|
Pending Activities
|
|
Retail Regulators
|
Request / Recent Activity: On Feb. 19, 2013, ETI, in conjunction with ITC Holdings Corp. and ITC MidSouth LLC, collectively ITC, filed a joint application with the PUCT seeking approval for the Entergy companies’ proposal to spin off and merge the Utility’s transmission business with ITC, including approval for change of control of the transmission assets and transaction-related steps in the spin-merge. Separately, ETI filed for recovery of ITC-related costs post closing through the transmission rider mechanism. In April 2013, the LPSC Staff, APSC Staff and other parties filed testimony in the proceedings pending at the LPSC and APSC, respectively, identifying concerns with the proposed transaction and concluding that the transaction in its current form does not satisfy the applicable criteria for approval. The LPSC Staff testimony also included a comprehensive set of conditions should the LPSC determine that the transaction is in the public interest. Conditions were also recommended by the Arkansas Attorney General should the APSC consider approving the transaction. Intervening parties previously filed testimony in the CCNO and MPSC proceedings.
Although EAI serves no retail customers in Missouri, a joint application was also filed with the Missouri PSC on Feb. 14, 2013 out of an abundance of caution related to EAI’s limited transmission assets located in Missouri. On April 17, 2013, the Missouri PSC voted to consolidate the ITC transaction proceeding with EAI’s MISO notice proceeding also pending before the Missouri PSC for purposes of hearing.
Next Steps: PUCT Staff and CCNO Advisors will file testimony in May 2013. MPSC Staff will file testimony in June 2013. The Utility operating companies will file rebuttal testimony from mid-May through mid-July. A hearing in the PUCT proceeding is scheduled in late May 2013. The Missouri PSC has scheduled a hearing in June 2013. Hearings are scheduled in July 2013 in the APSC, LPSC and CCNO proceedings; the MPSC hearing is scheduled for early August 2013. The jurisdictional deadline for a decision in Texas is Aug. 18, 2013. In ETI’s transmission rider proceeding, a procedural schedule was set that provides for a hearing in July 2013; other parties have appealed that schedule to the PUCT.
|
|
Federal Energy Regulatory Commission
|
Sections 203, 205 and 305(a) Filings Recent Activity: On March 22, 2013, FERC extended by 180 days the timing for action on the Utility operating companies’ and ITC’s Sept. 24, 2012 joint application requesting certain approvals related to the proposal to spin off and merge the Utility’s transmission business with ITC. The FERC tolling order was based on the two comment period extensions provided in the docket.
Next Steps: FERC is anticipated to issue a decision, set for hearing and settlement procedures, or otherwise act on the application by Sept. 18, 2013.
|
|
Section 204 Filings Recent Activity: On Oct. 31, 2012, three separate applications under Section 204 of the FPA were submitted to FERC (two by Entergy and one by ITC). The Entergy applications seek authorization related to certain debt financings necessary to effectuate the ITC transaction. The ITC application seeks authorizations related to certain post-closing financings. The applications request that FERC grant the requested authorizations within ninety days from the date of the application. Entergy has responded to the lone protest filed in these dockets, as well as a request for additional information from FERC Staff.
Next Steps: There is no set deadline for FERC to take action on the application.
|
|
|
Internal Revenue Service
|
Request / Recent Activity: In July 2012, Entergy Corporation submitted a request to the IRS seeking a private letter ruling substantially to the effect that certain requirements for the tax-free treatment of the distribution of TransCo are met.
Next Steps: The IRS is expected to make a determination on the request in the first half of 2013.
|
|
Nuclear Regulatory Commission
|
Request / Recent Activity: On Sept. 27, 2012, Entergy Operations, Inc. on behalf of EAI, EGSL, ELL and SERI submitted an application to the NRC for approval of certain nuclear plant license transfers and amendments as part of the steps to complete the transaction.
Next Steps: The NRC is expected to complete its formal review by mid-2013.
|
|
Securities and Exchange Commission
|
Request / Recent Activity: ITC filed Amendment No. 3 to Form S-4 Registration Statement on Feb. 20, 2013 and the Proxy Statement / 424(b) Prospectus on Feb. 27, 2013. The Form S-4 became effective on Feb. 25, 2013. ITC shareholders approved the merger agreement at a special meeting of shareholders on April 16, 2013.
Next Steps: The newly-formed TransCo will prepare and file a registration statement for the TransCo common units. The filing is expected to be made in mid-2013.
|
|
Hart-Scott-Rodino Notification
|
Request / Recent Activity: On Dec. 14, 2012, Entergy and ITC each filed a premerger notification under the HSR Act. The 30-day waiting period required under the HSR Act expired on Jan. 14, 2013.
|
Additional Information and Where to Find It
ITC filed a registration statement on Form S-4 (Registration No. 333-184073) with the SEC registering the offer and sale of shares of ITC common stock to be issued to Entergy shareholders in connection with the proposed transactions. This registration statement was declared effective by the SEC on Feb. 25, 2013. ITC shareholders are urged to read the prospectus included in the ITC registration statement and any other relevant documents because they contain important information about TransCo and the proposed transactions. In addition, TransCo will file a registration statement with the SEC registering the offer and sale of TransCo common units to be issued to Entergy shareholders in connection with the proposed transactions. Entergy shareholders are urged to read the prospectus included in the ITC registration statement and the prospectus to be included in the TransCo registration statement (when available) and any other relevant documents, because they contain important information about ITC, TransCo and the proposed transactions. The registration statements, prospectuses and other documents relating to the proposed transactions (when they are available) can be obtained free of charge from the SEC’s website at www.sec.gov. The documents, when available, can also be obtained free of charge from Entergy upon written request to Entergy Corporation, Investor Relations, P.O. Box 61000, New Orleans, LA 70161 or by calling Entergy’s Investor Relations information line at 1-888-ENTERGY (368-3749), or from ITC upon written request to ITC Holdings Corp., Investor Relations, 27175 Energy Way, Novi, MI 48377 or by calling 248-946-3000.
|
B.
|
Variance Analysis and Special Items
|
Appendix B-1 provides details of first quarter 2013 vs. 2012 as-reported and operational earnings variance analysis for Utility, Entergy Wholesale Commodities, Parent & Other and Consolidated.
|
Appendix B-1: As-Reported and Operational Earnings Per Share Variance Analysis
|
|||||||||||
|
First Quarter 2013 vs. 2012
|
|||||||||||
|
(Per share in U.S. $, sorted in consolidated operational column, most to least favorable)
|
|||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
||||||||
|
As-Reported
|
Opera-
tional
|
As-Reported
|
Opera-tional
|
As- Reported
|
Opera-tional
|
As- Reported
|
Opera-tional
|
||||
|
2012 earnings
|
0.35
|
0.38
|
(0.99)
|
0.27
|
(0.22)
|
(0.21)
|
(0.86)
|
0.44
|
|||
|
Net revenue
|
0.41
|
0.41
|
(g)
|
0.14
|
0.14
|
(h)
|
0.01
|
0.01
|
0.56
|
0.56
|
|
|
Income taxes - other
|
0.23
|
0.23
|
(i)
|
-
|
-
|
-
|
-
|
0.23
|
0.23
|
||
|
Nuclear refueling outage expense
|
(0.01)
|
(0.01)
|
0.02
|
0.02
|
-
|
-
|
0.01
|
0.01
|
|||
|
Asset impairment
|
-
|
-
|
1.26
|
-
|
(j)
|
-
|
-
|
1.26
|
-
|
||
|
Other income (deductions) - other
|
(0.04)
|
(0.04)
|
0.01
|
0.01
|
-
|
-
|
(0.03)
|
(0.03)
|
|||
|
Interest expense and other charges
|
(0.03)
|
(0.03)
|
0.01
|
0.01
|
(0.02)
|
(0.02)
|
(0.04)
|
(0.04)
|
|||
|
Taxes other than income taxes
|
(0.04)
|
(0.04)
|
(0.01)
|
(0.01)
|
-
|
-
|
(0.05)
|
(0.05)
|
|||
|
Depreciation / amortization expense
|
(0.08)
|
(0.08)
|
(k)
|
0.01
|
0.01
|
-
|
-
|
(0.07)
|
(0.07)
|
||
|
Other operation & maintenance expense
|
(0.10)
|
(0.09)
|
(l)
|
0.01
|
0.01
|
(0.02)
|
(0.03)
|
(0.11)
|
(0.11)
|
||
|
2013 earnings
|
0.69
|
0.73
|
0.46
|
0.46
|
(0.25)
|
(0.25)
|
0.90
|
0.94
|
|||
|
(g)
|
The increase was due to both volume and pricing factors. Current quarter net revenue reflected the net effect of pricing adjustments from regulatory actions and investments, primarily from placing the Grand Gulf extended power uprate, Waterford 3 steam generator replacement and the Hinds and Hot Spring power plant acquisitions in service. The ETI 2012 rate case order and the EAI energy efficiency rider also contributed. A portion of the net revenue increase was for recovery of costs below the net revenue line including non-fuel operation and maintenance expense, depreciation expense and taxes other than income taxes. Net revenue also reflected higher retail sales volume attributable to weather. Both periods had negative weather effects, but the weather in the current quarter was not as mild as the first quarter 2012.
|
|
Utility Net Revenue Variance Analysis
2013 vs. 2012 ($ EPS)
|
|
|
First Quarter
|
|
|
Weather
|
0.08
|
|
Sales growth / pricing
|
0.31
|
|
Other
|
0.02
|
|
Total
|
0.41
|
|
(h)
|
The increase was due primarily to higher nuclear energy and capacity pricing, partially offset by a decline in nuclear generation due to an increase in refueling and unplanned outage days.
|
|
(i)
|
The increase was due primarily to a prior period item. First quarter 2012 income tax expense included a write off of an EGSL regulatory asset for income taxes to align the regulatory treatment of income taxes associated with certain items (primarily pension expense) and the financial accounting treatment of those taxes.
|
|
(j)
|
The as-reported increase was due to a prior period item. In first quarter 2012, an impairment charge was recorded to write down the carrying values of Vermont Yankee and related assets to their fair value, in accordance with GAAP.
|
|
(k)
|
The decrease was due primarily to additions to plant in service, including the Grand Gulf extended power uprate, the Waterford 3 steam generator replacement and the Hinds and Hot Spring power plant acquisitions. Higher depreciation rates at ETI resulting from the 2012 rate case order also contributed.
|
|
(l)
|
The decrease was due to several factors: higher compensation and benefits costs (largely post-employment benefits), higher nuclear expenses, higher fossil plant spending associated with the Hinds and Hot Spring power plant acquisitions and higher energy efficiency costs at EAI (offset in net revenue, as discussed in (g)).
|
Appendix B-2 lists special items by business with quarter-to-quarter comparisons. Amounts are shown on both an earnings per share basis and a net income basis. Special items are those events that are not routine, are related to prior periods or are related to discontinued businesses. Special items are included in as-reported earnings per share consistent with GAAP, but are excluded from operational earnings per share. As a result, operational earnings per share is considered a non-GAAP measure.
|
Appendix B-2: Special Items (shown as positive / (negative) impact on earnings)
|
|||
|
First Quarter 2013 vs. 2012
|
|||
|
(Per share in U.S. $)
|
|||
|
First Quarter
|
|||
|
2013
|
2012
|
Change
|
|
|
Utility
|
|||
|
Transmission business spin-merge expenses
|
(0.04)
|
(0.03)
|
(0.01)
|
|
Entergy Wholesale Commodities
|
|||
|
Vermont Yankee asset impairment
|
-
|
(1.26)
|
1.26
|
|
Parent & Other
|
|||
|
Transmission business spin-merge expenses
|
-
|
(0.01)
|
0.01
|
|
Total Special Items
|
(0.04)
|
(1.30)
|
1.26
|
|
(U.S. $ in millions)
|
|||
|
First Quarter
|
|||
|
2013
|
2012
|
Change
|
|
|
Utility
|
|||
|
Transmission business spin-merge expenses
|
(6.3)
|
(5.8)
|
(0.5)
|
|
Entergy Wholesale Commodities
|
|||
|
Vermont Yankee asset impairment
|
-
|
(223.5)
|
223.5
|
|
Parent & Other
|
|||
|
Transmission business spin-merge expenses
|
-
|
(1.4)
|
1.4
|
|
Total Special Items
|
(6.3)
|
(230.7)
|
224.4
|
|
C.
|
Regulatory Summary
|
Appendix C provides a summary of selected regulatory cases and events that are pending.
|
Appendix C: Regulatory Summary Table (see Appendix F for definitions of certain abbreviations or acronyms)
|
|||
|
Company
|
Pending Cases / Events
|
||
|
Retail Regulation
|
|||
|
Entergy Arkansas
Authorized ROE: 10.2%
Last Filed Rate Base: see next column
|
Rate Case Recent Activity: On March 1, 2013, EAI filed a rate case reflecting a requested ROE of 10.4 percent and based on a test year period ending Dec. 31, 2012 with known and measurable changes through Dec. 31, 2013. In the primary scenario, which assumes that EAI will transition to MISO in December 2013, EAI is requesting a rate increase of $174 million based on rate base of $5.0 billion. The alternate scenario, which also assumes completion of the proposed spin-merge of the transmission business with ITC, reflects a $218 million rate increase request based on rate base of $4.3 billion. Both scenarios propose a capacity cost recovery rider and a rider to recover costs associated with MISO and ITC (if the ITC transaction is completed). Staff and intervenor direct testimony is due in early August 2013. Hearings are scheduled to begin in October 2013. New rates are expected to become effective January 2014.
|
||
|
Entergy Gulf States Louisiana
Authorized ROE Range:
9.9% - 11.4% (electric)
10.0% - 11.0% (gas)
Last Filed Rate Base: see next column for electric
$0.05 billion (gas) filed 1/13 based on 9/30/12 test yr
|
Rate Case Recent Activity: On Feb. 15, 2013, EGSL filed a rate case reflecting a requested ROE of 10.4 percent and based on a test year period ending June 30, 2012 with known and measurable changes through Dec. 31, 2013. In the scenario that assumes that both the MISO transition and the proposed spin-merge of the transmission business with ITC are completed, EGSL is requesting a rate increase of $28 million based on rate base of $2.1 billion. The alternate scenario, which assumes only the transition to MISO, reflects a $24 million rate increase request based on rate base of $2.7 billion. Both scenarios propose a new transmission rider, continuation of the capacity rider and a new three-year FRP for 2013-2015 test years. The proposed FRP reflects a bandwidth of +/- 75 basis points and 60 percent / 40 percent sharing between customers and the company. New rates are expected to become effective in February 2014.
Other Recent Activity: On Feb. 27, 2013, the LPSC approved EGSL’s 2011 test year FRP for its electric operations based on the Dec. 21, 2012 revised evaluation report. The ROE reflected in the report was 11.86 percent, which is above the authorized earnings bandwidth, resulting in a cost of service rate decrease of $(5.7) million.
On March 8, 2013, the ALJ issued a final recommendation in the proceeding to review the allowed ROE in EGSL’s Gas Rate Stabilization Plan. The recommendation reflected a 9.4 percent ROE for gas operations. The matter will be referred to the LPSC for decision at a future B&E meeting.
|
||
|
Entergy Louisiana
Authorized ROE Range:
9.45% - 11.05%
Last Filed Rate Base: see next column
|
Rate Case Recent Activity: On Feb. 15, 2013, ELL filed a rate case reflecting a requested ROE of 10.4 percent and based on a test year period ending June 30, 2012 with known and measurable changes through Dec. 31, 2013. In the scenario that assumes that both the MISO transition and the proposed spin-merge of the transmission business with ITC are completed, ELL is requesting a rate increase of $168 million based on rate base of $3.8 billion. The alternate scenario, which assumes only the transition to MISO, reflects a $144 million rate increase request based on rate base of $4.5 billion. Both scenarios propose a new transmission rider, continuation of the capacity rider and a new three-year FRP for 2013-2015 test years. The proposed FRP reflects a bandwidth of +/- 75 basis points and 60 percent / 40 percent sharing between customers and the company. New rates are expected to become effective in February 2014.
On March 28, 2013, ELL filed a rate case for its Algiers area, which is regulated by the CCNO. ELL is requesting a rate increase of $13 million (phased in over three years), including a 10.4 percent ROE and an FRP mechanism identical to the ELL request. New rates are expected to become effective in April 2014.
Other Recent Activity: On April 17, 2013, the LPSC approved the April 3, 2013 joint report of ELL and the LPSC Staff resolving the 2011 test year FRP. The joint report resolved recovery related to the Grand Gulf extended power uprate and accepted the remainder of ELL’s Dec. 21, 2012 revised evaluation report. The ROE reflected in the report was 10.38 percent, which was within the authorized earnings bandwidth, resulting in no cost of service rate change.
|
||
|
Entergy Mississippi
Authorized ROE Range:
9.74% - 11.81%
(per 3/13 FRP filing)
Last Filed Rate Base:
$1.7 billion filed 3/13 based on 12/31/12 test yr
|
Recent Activity: On March 15, 2013, EMI filed its evaluation report for the 2012 test year. The filing reflected a 7.91 percent earned ROE, which was below the bandwidth of 9.74 – 11.81 percent, resulting in a requested rate increase of $36 million. The calculated 10.78 percent FRP midpoint ROE included the benefit of a 0.72 percent performance incentive. Rate changes are expected to be effective in July 2013.
On March 14, 2013, the Mississippi Public Utilities Staff filed its consultant report in the ROE inquiry proceeding, recommending no changes to ROE formulas at this time.
Background: EMI’s FRP includes an opportunity to reset the ROE and bandwidth based upon performance ratings. Returns inside the bandwidth result in no change in rates while returns outside the bandwidth reset rates prospectively to or within the bandwidth depending on performance, subject to a 4 percent revenue limit. The annual filing occurs each March with rates effective each June (if no hearing) or July (if hearing). EMI’s FRP does not have an expiration date.
|
||
|
Entergy New Orleans
Authorized ROE Range:
10.7% - 11.5% (electric)
10.25% - 11.25% (gas)
Last Filed Rate Base:
$0.3 billion (electric) and $0.09 billion (gas) filed 5/12 based on 12/31/11 test yr
|
Formula Rate Plan Recent Activity: The CCNO revised the procedural schedule to resolve the remaining disputed items in the 2011 test year FRP. The hearing is now scheduled in May 2013. ENOI is also in discussions with the CCNO Advisors regarding a possible extension of the FRP, which would require CCNO approval.
Background: A three-year FRP beginning with the 2009 test year was adopted in April 2009. Key provisions include an 11.1 percent electric ROE with a +/- 40 basis points bandwidth and a 10.75 percent gas ROE with a +/- 50 basis points bandwidth. Earnings outside the bandwidth reset to the midpoint ROE. Rates change on a prospective basis depending on whether ENOI is over- or under-earning. The FRP also includes a recovery mechanism for CCNO-approved capacity additions plus provisions for extraordinary cost changes and force majeure.
In October 2012, ENOI implemented, subject to refund pending resolution of remaining disputed items, rate changes reflected in its revised evaluation report for the 2011 test year FRP. The ROEs reflected in the revised report were 9.57 percent earned ROE for electric (which is below the bandwidth, resulting in an electric base revenue increase of $4.9 million) and a 10.83 percent earned ROE for gas (which is within the bandwidth, resulting in no change in gas base rates). As part of its initial 2011 test year FRP filing, ENOI requested to accelerate the funding of its storm reserve fund to allow it to meet the $75 million target balance established by the CCNO by 2017. The proposed increase was intended to replenish the $20 million expended for hurricanes Gustav and Ike.
|
||
|
Appendix C: Regulatory Summary Table (continued) (see Appendix F for definitions of certain abbreviations or acronyms)
|
|||
|
Company
|
Pending Cases / Events
|
||
|
Retail Regulation
|
|||
|
Entergy Texas
Authorized ROE: 9.8%
Last Filed Rate Base:
$1.7 billion filed 11/11 based on 6/30/11 adjusted test yr
|
Recent Activity: On March 15, 2013, the PUCT Staff and intervenors filed a joint motion to dismiss ETI’s application seeking special circumstances recovery of capacity costs. ETI filed a response on April 4, 2013 and the matter remains pending. At the April 11, 2013 open meeting, the PUCT found that a purchased power capacity rider was in the public interest. The PUCT subsequently proposed a second draft of the rule that incorporates a pre-approval process as discussed at the meeting. Because of this addition, the PUCT may decide to republish the draft rule on an expedited basis. A final decision is expected by the end of June 2013 given the comments by the commissioners at the meeting. If the PUCT finalizes the rule, ETI would have the option to recover its capacity costs under the new rider mechanism or could proceed with a full base rate proceeding.
Background: ETI implemented a $27.7 million overall retail rate increase effective July 2012 pursuant to a final PUCT order authorizing an allowed ROE of 9.8 percent. On Nov. 28, 2012 and Jan. 11, 2013, ETI filed appeals of the PUCT final order and order on rehearing, respectively, in Travis County district court. The appeals remain pending. On Nov. 30, 2012, ETI filed a pleading seeking a PUCT finding that special circumstances exist for limited cost recovery of capacity costs associated with two PPAs until such time that these costs are included in base rates or a purchased capacity recovery rider or other recovery mechanism. The PUCT published a draft purchased power capacity rider in November 2012.
|
||
|
Wholesale Regulation
|
|||
|
System Energy Resources, Inc.
ROE and last calculated rate base: see next column
|
Recent Activity: None.
Background: 10.94 percent ROE approved by July 2001 FERC order.
Last Calculated Rate Base: $1.6 billion for March 31, 2013 monthly cost of service.
|
||
|
Transmission, Proposal to Join MISO and System Agreement
Authorized ROE:
11.0% (m)
Last Filed OATT Rate Base:
$2.3 billion (n) filed 5/12 based on 12/31/11 test year
|
Proposal to Join MISO Recent Activity: On March 21, 2013, EAI filed a notification with the Missouri PSC of EAI’s intent to transfer functional control of EAI’s transmission assets to MISO. The filing seeks confirmation from the Missouri PSC that it has no jurisdiction over EAI's proposal to join MISO or, in the alternative, requests granting the change in control based on the MISO orders of the Utility operating companies’ retail regulators. On April 17, 2013, the Missouri PSC voted to consolidate EAI’s MISO notice proceeding with the ITC transaction proceeding also pending before the Missouri PSC for purposes of hearing. A hearing is scheduled in June 2013. On April 8, 2013, the APSC issued an order resolving the outstanding issues in EAI’s change of control docket and granted EAI’s application subject to the conditions set forth in its Oct. 26, 2012 order.
On April 3, 2013, the PUCT Staff filed a study performed by its independent consultant assessing ETI’s Jan. 15, 2013 updated analysis of the effect of termination of certain PPAs on ETI’s costs upon ETI’s exit from the System Agreement. While the independent consultant study concluded that the adjustments made in ETI’s updated analysis was analytically correct, the consultant also recommended further study regarding the effect of the termination of the PPAs on the benefits associated with ETI joining MISO. On April 5, 2013, ETI filed a response to the consultant study, noting a number of errors in the analysis and recommending against any further study of this matter.
The Utility operating companies continue to target joining MISO in December 2013.
Background: Between June 2012 and November 2012, the LPSC, PUCT, APSC, CCNO and MPSC each issued orders approving, subject to certain conditions, the Utility operating companies’ requests for MISO membership. The Oct. 26, 2012 PUCT order approving ETI’s request to join MISO included a requirement that ETI give notice to exit the System Agreement by October 2013 subject to certain conditions, and pursue a consensual means by which ETI may request to FERC that the mandatory 96-month notice period for exiting the System Agreement be shortened. On Dec. 21, 2012, the PUCT Staff filed a memo in the proceeding established by the PUCT to track compliance with its Oct. 26, 2012 order. In the memo, the PUCT Staff expressed concerns about the effect of ETI’s exit from the System Agreement on PPAs for gas and oil fired generation units owned by ETI and EGSL that were entered into upon the Dec. 31, 2007 Jurisdictional Separation of Entergy Gulf States, Inc. and, further, expressed concerns about the implications of these issues as they relate to the continuing validity of the PUCT’s Oct. 26, 2012 order. On Jan. 15, 2013, ETI filed an updated analysis of the effect of termination of the PPAs indicating that termination would have little or no impact on ETI’s costs.
|
||
|
System Agreement Recent Activity: A hearing is scheduled in May 2013 in the FERC proceeding regarding wholesale opportunity sales of energy by EAI to third parties for the period 2000 through 2009. In April 2013, the Utility operating companies filed rebuttal testimony in that proceeding, including a revised illustrative rerun of the intra-system bills for the years 2003, 2004 and 2006. The revised calculation resulted in an increase in the potential cost for EAI over those three years of $2.3 million from the potential costs identified in the Utility operating companies’ prior submissions in September and October 2012. No payments will be made or received by the Utility operating companies until a decision is issued by FERC in this phase of the proceeding.
Background: On June 21, 2012, FERC issued an order relating to an LPSC complaint involving Entergy’s accounting for wholesale opportunity sales of energy by EAI to third parties during the period 2000 through 2009. The order found that, although the sales at issue were permitted under the System Agreement and were made and priced in good faith, the after-the-fact accounting methodology used to allocate the energy used to supply the sales was inconsistent with the System Agreement. The Utility operating companies’ request for rehearing remains pending. The June 2012 FERC decision established further hearing procedures to determine the calculations. In September and October 2012, the Utility operating companies submitted testimony that included a proposed illustrative re-run of intra-system bills for 2003, 2004 and 2006 (the three years with the highest volume of opportunity sales) consistent with the directives in FERC’s order. The proposed illustrative re-run of intra-system bills shows that the potential cost for EAI would be up to $12 million for those three years, and the potential benefit would be significantly less than that for each of the other Utility operating companies; effects to other System Agreement pricing schedules may offset these costs and benefits. On Dec. 21, 2012, the LPSC filed testimony concluding that EAI should refund approximately $75 million to the other Utility operating companies for those three years, and that EAI “shareholders” should pay EAI customers $34 million. On Feb. 1, 2013, FERC Staff and certain intervenors filed testimony in the proceeding taking positions on the opposing calculations proposed by the LPSC and the Utility operating companies.
|
|||
|
(m)
|
Applies to sales made under Entergy’s FERC OATT.
|
|
(n)
|
Reflects transmission rate base in Entergy’s FERC OATT filing, which is also included in the rate base figures for each of the Utility operating companies shown above.
|
|
D.
|
Financial and Historical Performance Measures
|
Appendix D-1 provides comparative financial performance measures for the current quarter. Appendix D-2 provides historical financial performance measures and operating performance metrics for the trailing eight quarters. Financial performance measures in both tables include those calculated and presented in accordance with GAAP, as well as those that are considered non-GAAP measures.
As-reported measures are computed in accordance with GAAP as they include all components of net income, including special items. Operational measures are non-GAAP measures as they are calculated using operational net income, which excludes the impact of special items. A reconciliation of operational measures to as-reported measures is provided in Appendix G.
|
Appendix D-1: GAAP and Non-GAAP Financial Performance Measures
|
||||
|
First Quarter 2013 vs. 2012 (see Appendix F for definitions of certain measures)
|
||||
|
For 12 months ending March 31
|
2013
|
2012
|
Change
|
|
|
GAAP Measures
|
||||
|
Return on average invested capital – as-reported
|
6.9%
|
6.0%
|
0.9%
|
|
|
Return on average common equity – as-reported
|
12.8%
|
10.8%
|
2.0%
|
|
|
Cash flow interest coverage
|
5.9
|
7.5
|
(1.6)
|
|
|
Book value per share
|
$51.73
|
$50.32
|
$1.41
|
|
|
End of period shares outstanding (millions)
|
178.1
|
177.2
|
0.9
|
|
|
Non-GAAP Measures
|
||||
|
Return on average invested capital – operational
|
7.0%
|
7.2%
|
(0.2%)
|
|
|
Return on average common equity – operational
|
13.2%
|
13.6%
|
(0.4%)
|
|
|
As of March 31 ($ in millions)
|
2013
|
2012
|
Change
|
|
|
GAAP Measures
|
||||
|
Cash and cash equivalents
|
263
|
685
|
(422)
|
|
|
Revolver capacity
|
3,542
|
2,825
|
717
|
|
|
Commercial paper outstanding
|
883
|
-
|
883
|
|
|
Total debt
|
13,471
|
12,619
|
852
|
|
|
Securitization debt
|
952
|
1,049
|
(97)
|
|
|
Debt to capital ratio
|
58.7%
|
57.9%
|
0.8%
|
|
|
Off-balance sheet liabilities:
|
||||
|
Debt of joint ventures – Entergy’s share
|
90
|
93
|
(3)
|
|
|
Leases – Entergy’s share
|
505
|
508
|
(3)
|
|
|
Total off-balance sheet liabilities
|
595
|
601
|
(6)
|
|
|
Non-GAAP Measures
|
||||
|
Debt to capital ratio, excluding securitization debt
|
56.9%
|
55.7%
|
1.2%
|
|
|
Total gross liquidity
|
3,805
|
3,510
|
295
|
|
|
Net debt to net capital ratio, excluding securitization debt
|
56.3%
|
54.2%
|
2.1%
|
|
|
Net debt to net capital ratio including off-balance sheet liabilities, excluding securitization debt
|
57.5%
|
55.5%
|
2.0%
|
|
|
Appendix D-2: Historical Performance Measures
(see Appendix F for definitions of certain measures)
|
||||||||||||
|
2Q11
|
3Q11
|
4Q11
|
1Q12
|
2Q12
|
3Q12
|
4Q12
|
1Q13
|
13YTD
|
12YTD
|
|||
|
Financial
|
||||||||||||
|
EPS – as-reported ($)
|
1.76
|
3.53
|
0.87
|
(0.86)
|
2.06
|
1.89
|
1.66
|
0.90
|
0.90
|
(0.86)
|
||
|
Less – special items ($)
|
-
|
-
|
(0.07)
|
(1.30)
|
(0.05)
|
(0.06)
|
(0.06)
|
(0.04)
|
(0.04)
|
(1.30)
|
||
|
EPS – operational ($)
|
1.76
|
3.53
|
0.94
|
0.44
|
2.11
|
1.95
|
1.72
|
0.94
|
0.94
|
0.44
|
||
|
Trailing twelve months
|
||||||||||||
|
ROIC – as-reported (%)
|
7.7
|
8.2
|
8.0
|
6.0
|
6.2
|
4.8
|
5.5
|
6.9
|
||||
|
ROIC – operational (%)
|
7.9
|
8.2
|
8.0
|
7.2
|
7.4
|
6.0
|
6.6
|
7.0
|
||||
|
ROE – as-reported (%)
|
14.8
|
16.1
|
15.4
|
10.8
|
11.3
|
7.8
|
9.3
|
12.8
|
||||
|
ROE – operational (%)
|
15.2
|
16.1
|
15.6
|
13.6
|
14.2
|
10.7
|
12.2
|
13.2
|
||||
|
Cash flow interest coverage
|
7.6
|
6.6
|
7.1
|
7.5
|
7.2
|
6.8
|
6.1
|
5.9
|
||||
|
Debt to capital ratio (%)
|
58.1
|
57.3
|
57.3
|
57.9
|
57.4
|
57.7
|
58.7
|
58.7
|
||||
|
Debt to capital ratio, excluding securitization debt (%)
|
56.3
|
55.1
|
55.0
|
55.7
|
55.3
|
55.7
|
56.9
|
56.9
|
||||
|
Net debt to net capital ratio, excluding securitization debt (%)
|
55.1
|
52.8
|
53.5
|
54.2
|
54.7
|
54.1
|
55.8
|
56.3
|
||||
|
Utility
|
||||||||||||
|
GWh billed
|
||||||||||||
|
Residential
|
7,993
|
12,376
|
7,274
|
7,760
|
7,940
|
11,605
|
7,360
|
8,344
|
8,344
|
7,760
|
||
|
Commercial & Governmental
|
7,548
|
9,344
|
7,270
|
6,992
|
7,753
|
9,101
|
7,313
|
7,005
|
7,005
|
6,992
|
||
|
Industrial
|
10,140
|
11,024
|
10,130
|
9,958
|
10,408
|
10,748
|
10,067
|
9,868
|
9,868
|
9,958
|
||
|
Wholesale
|
1,036
|
1,038
|
1,090
|
732
|
836
|
833
|
798
|
630
|
630
|
732
|
||
|
O&M expense per MWh (o)
|
$19.09
|
$14.93
|
$21.99
|
$20.08
|
$19.94
|
$16.66
|
$22.19
|
$21.02
|
$21.02
|
$20.08
|
||
|
Entergy Wholesale Commodities
|
||||||||||||
|
Owned Capacity in MW
|
6,016
|
6,016
|
6,599
|
6,612
|
6,612
|
6,612
|
6,612
|
6,612
|
6,612
|
6,612
|
||
|
GWh billed
|
10,567
|
11,255
|
11,121
|
11,281
|
11,674
|
12,002
|
11,221
|
10,387
|
10,387
|
11,281
|
||
|
Net revenue ($ millions)
|
474
|
542
|
504
|
452
|
444
|
495
|
463
|
493
|
493
|
452
|
||
|
Operational adjusted EBITDA
($ millions)
|
174
|
241
|
193
|
144
|
127
|
185
|
161
|
194
|
194
|
144
|
||
|
Avg realized revenue per MWh
|
$52.74
|
$56.02
|
$52.48
|
$49.29
|
$48.27
|
$51.88
|
$50.56
|
$58.66
|
$58.66
|
$49.29
|
||
|
Non-fuel O&M expense per MWh (o)
|
$25.45
|
$23.71
|
$24.61
|
$23.93
|
$24.07
|
$23.15
|
$23.52
|
$25.22
|
$25.22
|
$23.93
|
||
|
EWC Nuclear Operational Measures
|
||||||||||||
|
Capacity factor (%)
|
91
|
98
|
93
|
88
|
85
|
90
|
90
|
83
|
83
|
88
|
||
|
GWh billed
|
9,993
|
10,645
|
10,367
|
9,838
|
10,426
|
10,480
|
10,298
|
9,246
|
9,246
|
9,838
|
||
|
Avg realized revenue per MWh
|
$52.38
|
$56.07
|
$53.00
|
$50.32
|
$48.67
|
$52.27
|
$49.88
|
$57.82
|
$57.82
|
$50.32
|
||
|
Production cost per MWh
|
$25.96
|
$24.92
|
$25.92
|
$25.85
|
$26.61
|
$26.14
|
$26.18
|
$25.94
|
$25.94
|
$25.85
|
||
|
(o)
|
Excludes effect of special items, including the proposed spin-merge of the transmission business at Utility (2012 and 2013) and the impairment of the Vermont Yankee plant at EWC (first quarter 2012).
|
|
E.
|
Planned Capital Expenditures
|
The capital plan for 2013 through 2015 anticipates $6.7 billion for investment, including $3.3 billion of maintenance capital, as shown in Appendix E. EWC planned maintenance capital includes capital investment for non-nuclear plants, which can vary from year to year depending on planned maintenance and generation and other technical milestones.
The $3.4 billion in other capital commitments is for specific investments and initiatives such as:
|
·
|
Utility: the Utility’s portfolio transformation investment of $0.5 billion for ELL’s Ninemile 6 new CCGT project, approximately $0.3 billion for environmental compliance projects (included in generation); and transmission other capital of approximately $0.7 billion. Total transmission investment, including maintenance capital, is approximately $1.4 billion including spending to support the Utility’s plan to join the MISO RTO in December 2013.
|
|
·
|
Entergy Wholesale Commodities: other capital commitments reflect significant projects required to continue the operation of the current generation fleet including dry cask storage, nuclear license renewal efforts, component replacement and identified repairs across the nuclear fleet, NYPA value sharing (including the last payment to be made in January 2015 for 2014 generation) and potential wedgewire screens at the Indian Point site.
|
Estimated capital expenditures are subject to periodic review and modification, and actual spending may vary based on a number of factors. The capital plan described in Appendix E did not include significant capital for potential projects as a result of the NRC post-Fukushima requirements. The current preliminary cost estimate (both capital and operation and maintenance expense) for post-Fukushima requirements is approximately $500 million, split roughly 50 / 50 between Utility and EWC. Entergy noted these costs are expected to be incurred over the 2012 through 2018 time period, and do not include any amounts for filtered vents, for which the NRC initiated a rulemaking in first quarter 2013. The capital plan also does not reflect the expected delay in spending associated with potential wedgewire screens at the Indian Point site.
The capital plan also does not reflect the effects of the proposed spin-off and merger of the transmission business with ITC discussed in Appendix A.
|
Appendix E: 2013 – 2015 Capital Expenditure Plan
|
||||
|
($ in millions) – Prepared February 2013
|
||||
|
2013
|
2014
|
2015
|
Total
|
|
|
Maintenance capital
|
||||
|
Utility
|
||||
|
Generation
|
133
|
127
|
135
|
395
|
|
Transmission
|
253
|
229
|
202
|
684
|
|
Distribution
|
504
|
494
|
489
|
1,487
|
|
Other
|
97
|
107
|
105
|
309
|
|
Utility Total
|
987
|
957
|
931
|
2,875
|
|
Entergy Wholesale Commodities
|
108
|
131
|
176
|
415
|
|
Maintenance capital subtotal
|
1,095
|
1,088
|
1,107
|
3,290
|
|
Other capital commitments
|
||||
|
Utility
|
||||
|
Generation
|
716
|
415
|
392
|
1,523
|
|
Transmission
|
162
|
240
|
303
|
705
|
|
Distribution
|
45
|
21
|
16
|
82
|
|
Other
|
92
|
88
|
92
|
272
|
|
Utility Total
|
1,015
|
764
|
803
|
2,582
|
|
Entergy Wholesale Commodities
|
257
|
242
|
281
|
780
|
|
Other capital commitments subtotal
|
1,272
|
1,006
|
1,084
|
3,362
|
|
Total Planned Capital Expenditures
|
2,367
|
2,094
|
2,191
|
6,652
|
|
F.
|
Definitions
|
Appendix F provides definitions of certain operational performance measures, as well as GAAP and non-GAAP financial measures, all of which are referenced in this release. Financial measures defined in the below table include measures prepared in accordance with GAAP, as well as non-GAAP measures. Non-GAAP measures are included in this release in order to provide metrics that remove the effect of not routine financial impacts from commonly used financial metrics.
|
Appendix F: Definitions of Operational Performance Measures, GAAP and Non-GAAP Financial Measures and Abbreviations or Acronyms
|
|
|
Utility Operational Performance Measures
|
|
|
GWh billed
|
Total number of GWh billed to all retail and wholesale customers
|
|
O&M expense per MWh
|
Operation, maintenance and refueling expenses per MWh of billed sales, excluding fuel
|
|
Number of retail customers
|
Number of customers at end of period
|
|
Entergy Wholesale Commodities Operational Performance Measures
|
|
|
Net revenue
|
Operating revenue less fuel, fuel related expenses and purchased power
|
|
Owned capacity
|
Installed capacity owned and operated by EWC, including investments in wind generation accounted for under the equity method of accounting; EWC acquired RISEC, a 583 MW natural gas-fired combined-cycle generating plant, on Dec. 20, 2011
|
|
GWh billed
|
Total number of GWh billed to customers, excluding investments in wind generation accounted for under the equity method of accounting
|
|
Average realized revenue per MWh
|
As-reported revenue per MWh billed, excluding revenue from the amortization of the Palisades below-market PPA and/or investments in wind generation accounted for under the equity method of accounting
|
|
Non-fuel O&M expense per MWh
|
Operation, maintenance and refueling expenses per MWh billed, excluding fuel and investments in wind generation accounted for under the equity method of accounting
|
|
Capacity factor
|
Normalized percentage of the period that the nuclear plants generate power
|
|
Production cost per MWh
|
Fuel and non-fuel operation and maintenance expenses according to accounting standards that directly relate to the production of electricity per MWh (based on net generation)
|
|
Refueling outage days
|
Number of days lost for scheduled refueling outage during the period
|
|
Planned TWh of generation
|
Amount of output expected to be generated by EWC resources considering plant operating characteristics, outage schedules and expected market conditions which impact dispatch, assuming timely renewal of plant operating licenses and uninterrupted normal operations at all plants; non-nuclear also includes purchases from affiliated and non-affiliated counterparties under long-term contracts and excludes energy and capacity from EWC’s wind investment accounted for under the equity method of accounting and Ritchie
|
|
Percent of planned generation under contract
|
Percent of planned generation output sold or purchased forward under contracts, forward physical contracts, forward financial contracts or options that mitigate price uncertainty (consistent with assumptions used in earnings guidance) that may or may not require regulatory approval or approval of transmission rights
|
|
Unit-contingent
|
Transaction under which power is supplied from a specific generation asset; if the asset is not operating, seller is generally not liable to buyer for any damages
|
|
Unit-contingent with availability guarantees
|
Transaction under which power is supplied from a specific generation asset; if the asset is not operating, seller is generally not liable to buyer for any damages, unless the actual availability over a specified period of time is below an availability threshold specified in the contract
|
|
Firm LD
|
Transaction that requires receipt or delivery of energy at a specified delivery point (usually at a market hub not associated with a specific asset) or settles financially on notional quantities; if a party fails to deliver or receive energy, defaulting party must compensate the other party as specified in the contract; a portion of which may be capped through the use of risk management products
|
|
Offsetting positions
|
Transactions for the purchase of energy, generally to offset a Firm LD transaction
|
|
Cost-based contracts
|
Contracts priced in accordance with cost-based rates, a ratemaking concept used for the design and development of rate schedules to ensure that the filed rate schedules recover only the cost of providing the service; these contracts are on owned non-utility resources located within Entergy’s utility service territory, which do not operate under market-based rate authority
|
|
Planned net MW in operation
|
Amount of capacity to be available to generate power and/or sell capacity; non-nuclear also includes purchases from affiliated and non-affiliated counterparties under long-term contracts and excludes energy and capacity from EWC’s wind investment accounted for under the equity method of accounting and Ritchie
|
|
Percent of capacity sold forward
|
Percent of planned qualified capacity sold to mitigate price uncertainty under physical or financial transactions
|
|
Bundled capacity and energy contract
|
A contract for the sale of installed capacity and related energy, priced per megawatt-hour sold
|
|
Capacity contract
|
A contract for the sale of the installed capacity product in regional markets managed by ISO New England and the New York Independent System Operator
|
|
Appendix F: Definitions of Operational Performance Measures, GAAP and Non-GAAP Financial Measures and Abbreviations or Acronyms (continued)
|
||
|
Entergy Wholesale Commodities Operational Performance Measures (continued)
|
||
|
Average revenue per MWh on contracted volumes
|
Revenue on a per unit basis at which generation output reflected in contracts is expected to be sold to third parties (including offsetting positions) at the minimum contract prices and at forward market prices at a point in time, given existing contract or option exercise prices based on expected dispatch or capacity, excluding the revenue associated with the amortization of the below-market PPA for Palisades; revenue will fluctuate due to factors including market price changes affecting revenue received on puts, collars and call options, positive or negative basis differentials, option premiums and market prices at time of option expiration, costs to convert firm LD to unit-contingent and other risk management cost; also, excludes payments owed under the value sharing agreements, if any
|
|
|
Average revenue under contract per kW per month (applies to capacity contracts only)
|
Revenue on a per unit basis at which capacity is expected to be sold to third parties, given existing contract prices and/or auction awards
|
|
|
Expected sold and market revenue per MWh
|
Total energy and capacity revenue on a per unit basis at which total planned generation output, capacity or a combination is expected to be sold given contract terms and market prices at a point in time, including estimates for market price changes affecting revenue received on puts, collars and call options, positive or negative basis differentials, option premiums and market prices at time of option expiration, costs to convert Firm LD to unit-contingent and other risk management cost
|
|
|
Financial Measures – GAAP
|
||
|
Return on average invested capital – as-reported
|
12-months rolling net income attributable to Entergy Corporation (Net Income) adjusted to include preferred dividends and tax-effected interest expense divided by average invested capital
|
|
|
Return on average common equity – as-reported
|
12-months rolling Net Income divided by average common equity
|
|
|
Cash flow interest coverage
|
12-months cash flow from operating activities plus 12-months rolling interest paid, divided by interest expense
|
|
|
Book value per share
|
Common equity divided by end of period shares outstanding
|
|
|
Revolver capacity
|
Amount of undrawn capacity remaining on corporate and subsidiary revolvers
|
|
|
Total debt
|
Sum of short-term and long-term debt, notes payable, capital leases and preferred stock with sinking fund on the balance sheet less non-recourse debt, if any
|
|
|
Debt of joint ventures (Entergy’s share)
|
Debt issued by business joint ventures at EWC
|
|
|
Leases (Entergy’s share)
|
Operating leases held by subsidiaries capitalized at implicit interest rate
|
|
|
Debt to capital ratio
|
Gross debt divided by total capitalization
|
|
|
Securitization debt
|
Debt associated with securitization bonds issued to recover storm costs from hurricanes Rita, Ike and Gustav at ETI; the 2009 ice storm at EAI and investment recovery of costs associated with the cancelled Little Gypsy repowering project at ELL
|
|
|
Financial Measures – Non-GAAP
|
||
|
Operational earnings
|
As-reported Net Income adjusted to exclude the impact of special items
|
|
|
Adjusted EBITDA
|
Earnings before interest, income taxes, depreciation and amortization and interest and investment income excluding decommissioning expense and other than temporary impairment losses on decommissioning trust fund assets
|
|
|
Operational adjusted EBITDA
|
Adjusted EBITDA excluding effects of special items
|
|
|
Return on average invested capital – operational
|
12-months rolling operational Net Income adjusted to include preferred dividends and tax-effected interest expense divided by average invested capital
|
|
|
Return on average common equity – operational
|
12-months rolling operational Net Income divided by average common equity
|
|
|
Total gross liquidity
|
Sum of cash and revolver capacity
|
|
|
Debt to capital ratio, excluding securitization debt
|
Gross debt divided by total capitalization, excluding securitization debt
|
|
|
Net debt to net capital ratio, excluding securitization debt
|
Gross debt less cash and cash equivalents divided by total capitalization less cash and cash equivalents, excluding securitization debt
|
|
|
Net debt to net capital ratio, including off-balance sheet liabilities, excluding securitization debt
|
Sum of gross debt and off-balance sheet debt less cash and cash equivalents divided by sum of total capitalization and off-balance sheet debt less cash and cash equivalents, excluding securitization debt
|
|
|
Appendix F: Definitions of Operational Performance Measures, GAAP and Non-GAAP Financial Measures and Abbreviations or Acronyms (continued)
|
|
|
Abbreviations or Acronyms
|
|
|
APSC
|
Arkansas Public Service Commission
|
|
B&E
|
LPSC Business and Executive Session
|
|
CCNO
|
Council of the City of New Orleans
|
|
DOE
|
U.S. Department of Energy
|
|
EAI
|
Entergy Arkansas, Inc.
|
|
EGSL
|
Entergy Gulf States Louisiana, L.L.C.
|
|
ELL
|
Entergy Louisiana, LLC
|
|
EMI
|
Entergy Mississippi, Inc.
|
|
EPA
|
U.S. Environmental Protection Agency
|
|
ENOI
|
Entergy New Orleans, Inc.
|
|
ETI
|
Entergy Texas, Inc.
|
|
EWC
|
Entergy Wholesale Commodities
|
|
FERC
|
Federal Energy Regulatory Commission
|
|
FPA
|
Federal Power Act
|
|
FRP
|
Formula rate plan
|
|
GAAP
|
Generally accepted accounting principles
|
|
IRS
|
Internal Revenue Service
|
|
ITC
|
ITC Holdings Corp.
|
|
HSR
|
Hart-Scott-Rodino Antitrust Improvements Act
|
|
LPSC
|
Louisiana Public Service Commission
|
|
MISO
|
Midwest Independent Transmission System Operator
|
|
MPSC
|
Mississippi Public Service Commission
|
|
NRC
|
Nuclear Regulatory Commission
|
|
OATT
|
FERC-jurisdictional Open Access Transmission Tariff
|
|
PPA
|
Power purchase agreement
|
|
PSC
|
Public Service Commission
|
|
PUCT
|
Public Utility Commission of Texas
|
|
SERI
|
System Energy Resources, Inc.
|
|
RISEC
|
Rhode Island State Energy Center
|
|
ROE
|
Return on equity
|
|
RTO
|
Regional transmission organization
|
|
SEC
|
U.S. Securities and Exchange Commission
|
|
G.
|
GAAP to Non-GAAP Reconciliations
|
Appendix G-1, Appendix G-2 and Appendix G-3 provide reconciliations of various non-GAAP financial measures disclosed in this release to their most comparable GAAP measure.
|
Appendix G-1: Reconciliation of GAAP to Non-GAAP Financial Measures – Return on Equity, Return on Invested Capital Metrics
|
||||||||
|
($ in millions)
|
||||||||
|
2Q11
|
3Q11
|
4Q11
|
1Q12
|
2Q12
|
3Q12
|
4Q12
|
1Q13
|
|
|
As-reported net income-rolling 12 months (A)
|
1,285
|
1,421
|
1,346
|
946
|
996
|
705
|
847
|
1,160
|
|
Preferred dividends
|
20
|
20
|
21
|
21
|
21
|
22
|
22
|
22
|
|
Tax effected interest expense
|
320
|
320
|
316
|
322
|
329
|
342
|
350
|
356
|
|
As-reported net income, rolling 12 months including preferred dividends and tax effected interest expense (B)
|
1,625
|
1,761
|
1,683
|
1,289
|
1,346
|
1,069
|
1,219
|
1,538
|
|
Special items in prior quarters
|
(32)
|
(7)
|
-
|
(13)
|
(244)
|
(253)
|
(251)
|
(31)
|
|
Special items in current quarter
|
||||||||
|
Asset impairment
|
-
|
-
|
-
|
(224)
|
-
|
-
|
-
|
-
|
|
Transmission spin-merge
|
-
|
-
|
(13)
|
(7)
|
(9)
|
(11)
|
(11)
|
(6)
|
|
Total special items (C)
|
(32)
|
(7)
|
(13)
|
(244)
|
(253)
|
(264)
|
(262)
|
(37)
|
|
Operational earnings, rolling 12 months including preferred dividends and tax effected interest expense (B-C)
|
1,657
|
1,768
|
1,696
|
1,533
|
1,599
|
1,333
|
1,481
|
1,575
|
|
Operational earnings, rolling 12 months (A-C)
|
1,317
|
1,428
|
1,359
|
1,190
|
1,249
|
969
|
1,109
|
1,197
|
|
Average invested capital (D)
|
21,101
|
21,509
|
21,126
|
21,339
|
21,556
|
22,065
|
22,290
|
22,389
|
|
Average common equity (E)
|
8,684
|
8,849
|
8,729
|
8,725
|
8,814
|
9,078
|
9,079
|
9,064
|
|
ROIC – as-reported % (B/D)
|
7.7
|
8.2
|
8.0
|
6.0
|
6.2
|
4.8
|
5.5
|
6.9
|
|
ROIC – operational % ((B-C)/D)
|
7.9
|
8.2
|
8.0
|
7.2
|
7.4
|
6.0
|
6.6
|
7.0
|
|
ROE – as-reported % (A/E)
|
14.8
|
16.1
|
15.4
|
10.8
|
11.3
|
7.8
|
9.3
|
12.8
|
|
ROE – operational % ((A-C)/E)
|
15.2
|
16.1
|
15.6
|
13.6
|
14.2
|
10.7
|
12.2
|
13.2
|
|
Appendix G-2: Reconciliation of GAAP to Non-GAAP Financial Measures – Credit and Liquidity Metrics
|
||||||||
|
($ in millions)
|
||||||||
|
2Q11
|
3Q11
|
4Q11
|
1Q12
|
2Q12
|
3Q12
|
4Q12
|
1Q13
|
|
|
Gross debt (A)
|
12,360
|
12,452
|
12,387
|
12,619
|
12,533
|
12,931
|
13,473
|
13,471
|
|
Less securitization debt (B)
|
896
|
1,086
|
1,071
|
1,049
|
1,020
|
1,003
|
973
|
952
|
|
Gross debt, excluding securitization debt (C)
|
11,464
|
11,366
|
11,316
|
11,570
|
11,513
|
11,928
|
12,500
|
12,519
|
|
Less cash and cash equivalents (D)
|
530
|
987
|
694
|
685
|
283
|
750
|
533
|
263
|
|
Net debt, excluding securitization debt (E)
|
10,934
|
10,379
|
10,622
|
10,885
|
11,230
|
11,178
|
11,967
|
12,256
|
|
Total capitalization (F)
|
21,268
|
21,728
|
21,629
|
21,813
|
21,844
|
22,402
|
22,951
|
22,965
|
|
Less securitization debt (B)
|
896
|
1,086
|
1,071
|
1,049
|
1,020
|
1,003
|
973
|
952
|
|
Total capitalization, excluding securitization debt (G)
|
20,372
|
20,642
|
20,558
|
20,764
|
20,824
|
21,399
|
21,978
|
22,013
|
|
Less cash and cash equivalents (D)
|
530
|
987
|
694
|
685
|
283
|
750
|
533
|
263
|
|
Net capital, excluding securitization debt (H)
|
19,842
|
19,655
|
19,864
|
20,079
|
20,541
|
20,649
|
21,445
|
21,750
|
|
Debt to capital ratio % (A/F)
|
58.1
|
57.3
|
57.3
|
57.9
|
57.4
|
57.7
|
58.7
|
58.7
|
|
Debt to capital ratio, excluding securitization debt % (C/G)
|
56.3
|
55.1
|
55.0
|
55.7
|
55.3
|
55.7
|
56.9
|
56.9
|
|
Net debt to net capital ratio, excluding securitization debt % (E/H)
|
55.1
|
52.8
|
53.5
|
54.2
|
54.7
|
54.1
|
55.8
|
56.3
|
|
Off-balance sheet liabilities (I)
|
647
|
645
|
604
|
601
|
600
|
599
|
595
|
595
|
|
Net debt to net capital ratio including off-balance sheet liabilities, excluding securitization debt % ((E+I)/(H+I))
|
56.5
|
54.3
|
54.8
|
55.5
|
56.0
|
55.4
|
57.0
|
57.5
|
|
Revolver capacity (J)
|
1,993
|
2,116
|
2,001
|
2,825
|
2,762
|
2,917
|
3,462
|
3,542
|
|
Gross liquidity (D+J)
|
2,523
|
3,103
|
2,695
|
3,510
|
3,045
|
3,667
|
3,995
|
3,805
|
|
Appendix G-3: Reconciliation of GAAP to Non-GAAP Financial Measures – Entergy Wholesale Commodities Operational Adjusted EBITDA
|
||||||||
|
($ in millions)
|
||||||||
|
2Q11
|
3Q11
|
4Q11
|
1Q12
|
2Q12
|
3Q12
|
4Q12
|
1Q13
|
|
|
Net income
|
99
|
122
|
156
|
(176)
|
71
|
87
|
59
|
82
|
|
Add back: interest expense
|
9
|
10
|
6
|
6
|
5
|
3
|
3
|
3
|
|
Add back: income tax expense
|
18
|
59
|
18
|
(92)
|
47
|
57
|
50
|
57
|
|
Add back: depreciation and amortization
|
44
|
45
|
46
|
51
|
48
|
29
|
47
|
49
|
|
Subtract: interest and investment income
|
24
|
24
|
29
|
31
|
27
|
20
|
28
|
28
|
|
Add back: decommissioning expense
|
28
|
29
|
(4)
|
30
|
(17)
|
29
|
30
|
31
|
|
Adjusted EBITDA
|
174
|
241
|
193
|
(212)
|
127
|
185
|
161
|
194
|
|
Add back: special item for asset impairment
|
-
|
-
|
-
|
356
|
-
|
-
|
–
|
–
|
|
Operational adjusted EBITDA
|
174
|
241
|
193
|
144
|
127
|
185
|
161
|
194
|
Entergy Corporation’s common stock is listed on the New York and Chicago exchanges under the symbol “ETR.”
Additional investor information can be accessed online at
www.entergy.com/investor_relations
*********************************************************************************************************************************
In this news release, and from time to time, Entergy makes certain “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. Except to the extent required by the federal securities laws, Entergy undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise.
Forward-looking statements involve a number of risks and uncertainties. There are factors that could cause actual results to differ materially from those expressed or implied in the forward-looking statements, including (a) those factors discussed in: (i) Entergy’s Form 10-K for the year ended Dec. 31, 2012 and (ii) Entergy’s other reports and filings made under the Securities Exchange Act of 1934; (b) uncertainties associated with rate proceedings, formula rate plans and other cost recovery mechanisms; (c) uncertainties associated with efforts to remediate the effects of major storms and recover related restoration costs; (d) nuclear plant relicensing, operating and regulatory risks, including any changes resulting from the nuclear crisis in Japan following its catastrophic earthquake and tsunami; (e) legislative and regulatory actions and risks and uncertainties associated with claims or litigation by or against Entergy and its subsidiaries; (f) conditions in commodity and capital markets during the periods covered by the forward-looking statements, in addition to other factors described elsewhere in this release and subsequent securities filings and (g) risks inherent in the proposed spin-off and subsequent merger of Entergy’s electric transmission business with a subsidiary of ITC Holdings Corp. Entergy cannot provide any assurances that the spin-off and merger transaction will be completed and cannot give any assurance as to the terms on which such transaction will be consummated. The spin-off and merger transaction is subject to certain conditions precedent, including regulatory approvals.
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Balance Sheet
|
||||||||||||||||
|
March 31, 2013
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
ASSETS
|
||||||||||||||||
|
CURRENT ASSETS
|
||||||||||||||||
|
Cash and cash equivalents:
|
||||||||||||||||
|
Cash
|
$ | 50,236 | $ | 15,081 | $ | 797 | $ | 66,114 | ||||||||
|
Temporary cash investments
|
47,550 | 146,746 | 2,521 | 196,817 | ||||||||||||
|
Total cash and cash equivalents
|
97,786 | 161,827 | 3,318 | 262,931 | ||||||||||||
|
Securitization recovery trust account
|
44,438 | - | - | 44,438 | ||||||||||||
|
Notes receivable
|
- | 440,024 | (440,024 | ) | - | |||||||||||
|
Accounts receivable:
|
||||||||||||||||
|
Customer
|
489,831 | 146,863 | - | 636,694 | ||||||||||||
|
Allowance for doubtful accounts
|
(32,122 | ) | - | - | (32,122 | ) | ||||||||||
|
Associated companies
|
28,097 | 7,985 | (36,082 | ) | - | |||||||||||
|
Other
|
146,329 | 11,386 | 263 | 157,978 | ||||||||||||
|
Accrued unbilled revenues
|
268,839 | 171 | - | 269,010 | ||||||||||||
|
Total accounts receivable
|
900,974 | 166,405 | (35,819 | ) | 1,031,560 | |||||||||||
|
Deferred fuel costs
|
83,758 | - | - | 83,758 | ||||||||||||
|
Accumulated deferred income taxes
|
251,524 | 3,225 | (61,933 | ) | 192,816 | |||||||||||
|
Fuel inventory - at average cost
|
208,482 | 10,495 | 1 | 218,978 | ||||||||||||
|
Materials and supplies - at average cost
|
587,364 | 340,739 | - | 928,103 | ||||||||||||
|
Deferred nuclear refueling outage costs
|
146,178 | 171,846 | - | 318,024 | ||||||||||||
|
System agreement cost equalization
|
16,880 | - | - | 16,880 | ||||||||||||
|
Prepayments and other
|
122,095 | 399,803 | (296,513 | ) | 225,385 | |||||||||||
|
TOTAL
|
2,459,479 | 1,694,364 | (830,970 | ) | 3,322,873 | |||||||||||
|
OTHER PROPERTY AND INVESTMENTS
|
||||||||||||||||
|
Investment in affiliates - at equity
|
1,097,271 | 45,865 | (1,097,159 | ) | 45,977 | |||||||||||
|
Decommissioning trust funds
|
1,991,555 | 2,461,152 | - | 4,452,707 | ||||||||||||
|
Non-utility property - at cost (less accumulated depreciation)
|
179,674 | 69,438 | 10,956 | 260,068 | ||||||||||||
|
Other
|
172,809 | 15,664 | - | 188,473 | ||||||||||||
|
TOTAL
|
3,441,309 | 2,592,119 | (1,086,203 | ) | 4,947,225 | |||||||||||
|
PROPERTY, PLANT, AND EQUIPMENT
|
||||||||||||||||
|
Electric
|
37,349,025 | 4,712,172 | 3,419 | 42,064,616 | ||||||||||||
|
Property under capital lease
|
934,495 | - | - | 934,495 | ||||||||||||
|
Natural gas
|
356,988 | - | - | 356,988 | ||||||||||||
|
Construction work in progress
|
1,021,823 | 391,696 | 378 | 1,413,897 | ||||||||||||
|
Nuclear fuel
|
899,158 | 708,194 | - | 1,607,352 | ||||||||||||
|
TOTAL PROPERTY, PLANT AND EQUIPMENT
|
40,561,489 | 5,812,062 | 3,797 | 46,377,348 | ||||||||||||
|
Less - accumulated depreciation and amortization
|
17,967,918 | 1,099,594 | 395 | 19,067,907 | ||||||||||||
|
PROPERTY, PLANT AND EQUIPMENT - NET
|
22,593,571 | 4,712,468 | 3,402 | 27,309,441 | ||||||||||||
|
DEFERRED DEBITS AND OTHER ASSETS
|
||||||||||||||||
|
Regulatory assets:
|
||||||||||||||||
|
Regulatory asset for income taxes - net
|
752,696 | - | - | 752,696 | ||||||||||||
|
Other regulatory assets
|
4,860,886 | - | - | 4,860,886 | ||||||||||||
|
Deferred fuel costs
|
172,202 | - | - | 172,202 | ||||||||||||
|
Goodwill
|
374,099 | 3,073 | - | 377,172 | ||||||||||||
|
Accumulated deferred income taxes
|
11,359 | 54,180 | 1,294 | 66,833 | ||||||||||||
|
Other
|
259,934 | 749,942 | (26,231 | ) | 983,645 | |||||||||||
|
TOTAL
|
6,431,176 | 807,195 | (24,937 | ) | 7,213,434 | |||||||||||
| - | ||||||||||||||||
|
TOTAL ASSETS
|
$ | 34,925,535 | $ | 9,806,146 | $ | (1,938,708 | ) | $ | 42,792,973 | |||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Balance Sheet
|
||||||||||||||||
|
March 31, 2013
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
LIABILITIES AND SHAREHOLDERS' EQUITY
|
||||||||||||||||
|
CURRENT LIABILITIES
|
||||||||||||||||
|
Currently maturing long-term debt
|
$ | 613,246 | $ | 17,376 | $ | - | $ | 630,622 | ||||||||
|
Notes payable and commercial paper:
|
||||||||||||||||
|
Associated companies
|
- | - | - | - | ||||||||||||
|
Other
|
190,989 | - | 882,899 | 1,073,888 | ||||||||||||
|
Account payable:
|
||||||||||||||||
|
Associated companies
|
12,232 | 11,348 | (23,580 | ) | - | |||||||||||
|
Other
|
741,840 | 293,791 | 491 | 1,036,122 | ||||||||||||
|
Customer deposits
|
361,299 | - | - | 361,299 | ||||||||||||
|
Taxes accrued
|
623,506 | - | (325,435 | ) | 298,071 | |||||||||||
|
Accumulated deferred income taxes
|
14,480 | 61,434 | (60,910 | ) | 15,004 | |||||||||||
|
Interest accrued
|
145,716 | 941 | 7,438 | 154,095 | ||||||||||||
|
Deferred fuel costs
|
27,684 | - | - | 27,684 | ||||||||||||
|
Obligations under capital leases
|
3,495 | - | - | 3,495 | ||||||||||||
|
Pension and other postretirement liabilities
|
90,518 | 6,886 | - | 97,404 | ||||||||||||
|
System agreement cost equalization
|
16,880 | - | - | 16,880 | ||||||||||||
|
Other
|
109,721 | 70,303 | 1,832 | 181,856 | ||||||||||||
|
TOTAL
|
2,951,606 | 462,079 | 482,735 | 3,896,420 | ||||||||||||
|
NON-CURRENT LIABILITIES
|
||||||||||||||||
|
Accumulated deferred income taxes and taxes accrued
|
6,822,853 | 946,998 | 579,125 | 8,348,976 | ||||||||||||
|
Accumulated deferred investment tax credits
|
270,912 | - | - | 270,912 | ||||||||||||
|
Obligations under capital leases
|
33,976 | - | - | 33,976 | ||||||||||||
|
Other regulatory liabilities
|
1,046,106 | - | - | 1,046,106 | ||||||||||||
|
Decommissioning and retirement cost liabilities
|
2,000,444 | 1,525,243 | - | 3,525,687 | ||||||||||||
|
Accumulated provisions
|
111,400 | 4,015 | 1,127 | 116,542 | ||||||||||||
|
Pension and other postretirement liabilities
|
2,910,037 | 847,041 | - | 3,757,078 | ||||||||||||
|
Long-term debt
|
9,566,847 | 92,980 | 2,069,307 | 11,729,134 | ||||||||||||
|
Other
|
719,697 | 598,738 | (743,880 | ) | 574,555 | |||||||||||
|
TOTAL
|
23,482,272 | 4,015,015 | 1,905,679 | 29,402,966 | ||||||||||||
|
Subsidiaries' preferred stock without sinking fund
|
186,511 | - | - | 186,511 | ||||||||||||
|
EQUITY
|
||||||||||||||||
|
Common Shareholders' Equity:
|
||||||||||||||||
|
Common stock, $.01 par value, authorized 500,000,000 shares;
|
||||||||||||||||
|
issued 254,752,788 shares in 2013
|
2,161,268 | 301,097 | (2,459,817 | ) | 2,548 | |||||||||||
|
Paid-in capital
|
2,417,644 | 1,907,405 | 1,024,836 | 5,349,885 | ||||||||||||
|
Retained earnings
|
3,963,644 | 3,212,798 | 2,541,729 | 9,718,171 | ||||||||||||
|
Accumulated other comprehensive income (loss)
|
(211,410 | ) | (92,248 | ) | - | (303,658 | ) | |||||||||
|
Less - treasury stock, at cost (76,656,819 shares in 2013)
|
120,000 | - | 5,433,870 | 5,553,870 | ||||||||||||
|
Total common shareholders' equity
|
8,211,146 | 5,329,052 | (4,327,122 | ) | 9,213,076 | |||||||||||
|
Subsidiaries' preferred stock without sinking fund
|
94,000 | - | - | 94,000 | ||||||||||||
|
TOTAL
|
8,305,146 | 5,329,052 | (4,327,122 | ) | 9,307,076 | |||||||||||
|
TOTAL LIABILITIES AND EQUITY
|
$ | 34,925,535 | $ | 9,806,146 | $ | (1,938,708 | ) | $ | 42,792,973 | |||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Balance Sheet
|
||||||||||||||||
|
December 31, 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
ASSETS
|
||||||||||||||||
|
CURRENT ASSETS
|
||||||||||||||||
|
Cash and cash equivalents:
|
||||||||||||||||
|
Cash
|
$ | 104,378 | $ | 8,224 | $ | 390 | $ | 112,992 | ||||||||
|
Temporary cash investments
|
275,755 | 132,697 | 11,125 | 419,577 | ||||||||||||
|
Total cash and cash equivalents
|
380,133 | 140,921 | 11,515 | 532,569 | ||||||||||||
|
Securitization recovery trust account
|
46,040 | - | - | 46,040 | ||||||||||||
|
Notes receivable
|
- | 446,356 | (446,356 | ) | - | |||||||||||
|
Accounts receivable:
|
||||||||||||||||
|
Customer
|
374,403 | 194,468 | - | 568,871 | ||||||||||||
|
Allowance for doubtful accounts
|
(31,956 | ) | - | - | (31,956 | ) | ||||||||||
|
Associated companies
|
28,729 | 5,365 | (34,094 | ) | - | |||||||||||
|
Other
|
149,681 | 10,984 | 743 | 161,408 | ||||||||||||
|
Accrued unbilled revenues
|
303,264 | 128 | - | 303,392 | ||||||||||||
|
Total accounts receivable
|
824,121 | 210,945 | (33,351 | ) | 1,001,715 | |||||||||||
|
Deferred fuel costs
|
150,363 | - | - | 150,363 | ||||||||||||
|
Accumulated deferred income taxes
|
348,881 | 1,272 | (43,251 | ) | 306,902 | |||||||||||
|
Fuel inventory - at average cost
|
205,468 | 8,363 | - | 213,831 | ||||||||||||
|
Materials and supplies - at average cost
|
588,657 | 339,873 | - | 928,530 | ||||||||||||
|
Deferred nuclear refueling outage costs
|
123,975 | 119,399 | - | 243,374 | ||||||||||||
|
System agreement cost equalization
|
16,880 | - | - | 16,880 | ||||||||||||
|
Prepayments and other
|
70,777 | 413,333 | (241,188 | ) | 242,922 | |||||||||||
|
TOTAL
|
2,755,295 | 1,680,462 | (752,631 | ) | 3,683,126 | |||||||||||
|
OTHER PROPERTY AND INVESTMENTS
|
||||||||||||||||
|
Investment in affiliates - at equity
|
1,097,271 | 46,626 | (1,097,159 | ) | 46,738 | |||||||||||
|
Decommissioning trust funds
|
1,855,959 | 2,334,149 | - | 4,190,108 | ||||||||||||
|
Non-utility property - at cost (less accumulated depreciation)
|
174,219 | 70,546 | 11,274 | 256,039 | ||||||||||||
|
Other
|
422,139 | 14,095 | - | 436,234 | ||||||||||||
|
TOTAL
|
3,549,588 | 2,465,416 | (1,085,885 | ) | 4,929,119 | |||||||||||
|
PROPERTY, PLANT, AND EQUIPMENT
|
||||||||||||||||
|
Electric
|
37,264,453 | 4,676,696 | 3,418 | 41,944,567 | ||||||||||||
|
Property under capital lease
|
935,199 | - | - | 935,199 | ||||||||||||
|
Natural gas
|
353,492 | - | - | 353,492 | ||||||||||||
|
Construction work in progress
|
973,071 | 391,749 | 879 | 1,365,699 | ||||||||||||
|
Nuclear fuel
|
907,293 | 691,137 | - | 1,598,430 | ||||||||||||
|
TOTAL PROPERTY, PLANT AND EQUIPMENT
|
40,433,508 | 5,759,582 | 4,297 | 46,197,387 | ||||||||||||
|
Less - accumulated depreciation and amortization
|
17,840,387 | 1,058,069 | 386 | 18,898,842 | ||||||||||||
|
PROPERTY, PLANT AND EQUIPMENT - NET
|
22,593,121 | 4,701,513 | 3,911 | 27,298,545 | ||||||||||||
|
DEFERRED DEBITS AND OTHER ASSETS
|
||||||||||||||||
|
Regulatory assets:
|
||||||||||||||||
|
Regulatory asset for income taxes - net
|
742,030 | - | - | 742,030 | ||||||||||||
|
Other regulatory assets
|
5,025,912 | - | - | 5,025,912 | ||||||||||||
|
Deferred fuel costs
|
172,202 | - | - | 172,202 | ||||||||||||
|
Goodwill
|
374,099 | 3,073 | - | 377,172 | ||||||||||||
|
Accumulated deferred income taxes
|
10,461 | 20,749 | 6,538 | 37,748 | ||||||||||||
|
Other
|
215,422 | 752,132 | (30,906 | ) | 936,648 | |||||||||||
|
TOTAL
|
6,540,126 | 775,954 | (24,368 | ) | 7,291,712 | |||||||||||
| - | ||||||||||||||||
|
TOTAL ASSETS
|
$ | 35,438,130 | $ | 9,623,345 | $ | (1,858,973 | ) | $ | 43,202,502 | |||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Balance Sheet
|
||||||||||||||||
|
December 31, 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
LIABILITIES AND SHAREHOLDERS' EQUITY
|
||||||||||||||||
|
CURRENT LIABILITIES
|
||||||||||||||||
|
Currently maturing long-term debt
|
$ | 701,090 | $ | 17,426 | $ | - | $ | 718,516 | ||||||||
|
Notes payable and commercial paper:
|
||||||||||||||||
|
Associated companies
|
28,000 | 1,437 | (29,437 | ) | - | |||||||||||
|
Other
|
131,399 | - | 664,603 | 796,002 | ||||||||||||
|
Account payable:
|
||||||||||||||||
|
Associated companies
|
15,798 | 11,010 | (26,808 | ) | - | |||||||||||
|
Other
|
957,193 | 259,462 | 525 | 1,217,180 | ||||||||||||
|
Customer deposits
|
359,078 | - | - | 359,078 | ||||||||||||
|
Taxes accrued
|
664,891 | - | (331,172 | ) | 333,719 | |||||||||||
|
Accumulated deferred income taxes
|
7,955 | 40,431 | (35,277 | ) | 13,109 | |||||||||||
|
Interest accrued
|
160,151 | 321 | 24,192 | 184,664 | ||||||||||||
|
Deferred fuel costs
|
96,439 | - | - | 96,439 | ||||||||||||
|
Obligations under capital leases
|
3,880 | - | - | 3,880 | ||||||||||||
|
Pension and other postretirement liabilities
|
89,400 | 6,500 | - | 95,900 | ||||||||||||
|
System agreement cost equalization
|
25,848 | - | - | 25,848 | ||||||||||||
|
Other
|
106,052 | 154,019 | 1,915 | 261,986 | ||||||||||||
|
TOTAL
|
3,347,174 | 490,606 | 268,541 | 4,106,321 | ||||||||||||
|
NON-CURRENT LIABILITIES
|
||||||||||||||||
|
Accumulated deferred income taxes and taxes accrued
|
6,844,329 | 819,998 | 647,429 | 8,311,756 | ||||||||||||
|
Accumulated deferred investment tax credits
|
273,696 | - | - | 273,696 | ||||||||||||
|
Obligations under capital leases
|
34,541 | - | - | 34,541 | ||||||||||||
|
Other regulatory liabilities
|
898,614 | - | - | 898,614 | ||||||||||||
|
Decommissioning and retirement cost liabilities
|
1,970,362 | 1,543,272 | - | 3,513,634 | ||||||||||||
|
Accumulated provisions
|
357,801 | 978 | 3,447 | 362,226 | ||||||||||||
|
Pension and other postretirement liabilities
|
2,891,787 | 834,099 | - | 3,725,886 | ||||||||||||
|
Long-term debt
|
9,533,760 | 92,304 | 2,294,254 | 11,920,318 | ||||||||||||
|
Other
|
709,182 | 611,814 | (743,086 | ) | 577,910 | |||||||||||
|
TOTAL
|
23,514,072 | 3,902,465 | 2,202,044 | 29,618,581 | ||||||||||||
|
Subsidiaries' preferred stock without sinking fund
|
186,511 | - | - | 186,511 | ||||||||||||
|
EQUITY
|
||||||||||||||||
|
Common Shareholders' Equity:
|
||||||||||||||||
|
Common stock, $.01 par value, authorized 500,000,000 shares;
|
||||||||||||||||
|
issued 254,752,788 shares in 2012
|
2,161,268 | 301,097 | (2,459,817 | ) | 2,548 | |||||||||||
|
Paid-in capital
|
2,417,644 | 1,861,355 | 1,078,853 | 5,357,852 | ||||||||||||
|
Retained earnings
|
4,052,441 | 3,145,925 | 2,506,225 | 9,704,591 | ||||||||||||
|
Accumulated other comprehensive income (loss)
|
(214,980 | ) | (78,103 | ) | - | (293,083 | ) | |||||||||
|
Less - treasury stock, at cost (78,396,988 shares in 2012)
|
120,000 | - | 5,454,819 | 5,574,819 | ||||||||||||
|
Total common shareholders' equity
|
8,296,373 | 5,230,274 | (4,329,558 | ) | 9,197,089 | |||||||||||
|
Subsidiaries' preferred stock without sinking fund
|
94,000 | - | - | 94,000 | ||||||||||||
|
TOTAL
|
8,390,373 | 5,230,274 | (4,329,558 | ) | 9,291,089 | |||||||||||
|
TOTAL LIABILITIES AND EQUITY
|
$ | 35,438,130 | $ | 9,623,345 | $ | (1,858,973 | ) | $ | 43,202,502 | |||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Balance Sheet
|
||||||||||||||||
|
March 31, 2013 vs December 31, 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
ASSETS
|
||||||||||||||||
|
CURRENT ASSETS
|
||||||||||||||||
|
Cash and cash equivalents:
|
||||||||||||||||
|
Cash
|
$ | (54,142 | ) | $ | 6,857 | $ | 407 | $ | (46,878 | ) | ||||||
|
Temporary cash investments
|
(228,205 | ) | 14,049 | (8,604 | ) | (222,760 | ) | |||||||||
|
Total cash and cash equivalents
|
(282,347 | ) | 20,906 | (8,197 | ) | (269,638 | ) | |||||||||
|
Securitization recovery trust account
|
(1,602 | ) | - | - | (1,602 | ) | ||||||||||
|
Notes receivable
|
- | (6,332 | ) | 6,332 | - | |||||||||||
|
Accounts receivable:
|
||||||||||||||||
|
Customer
|
115,428 | (47,605 | ) | - | 67,823 | |||||||||||
|
Allowance for doubtful accounts
|
(166 | ) | - | - | (166 | ) | ||||||||||
|
Associated companies
|
(632 | ) | 2,620 | (1,988 | ) | - | ||||||||||
|
Other
|
(3,352 | ) | 402 | (480 | ) | (3,430 | ) | |||||||||
|
Accrued unbilled revenues
|
(34,425 | ) | 43 | - | (34,382 | ) | ||||||||||
|
Total accounts receivable
|
76,853 | (44,540 | ) | (2,468 | ) | 29,845 | ||||||||||
|
Deferred fuel costs
|
(66,605 | ) | - | - | (66,605 | ) | ||||||||||
|
Accumulated deferred income taxes
|
(97,357 | ) | 1,953 | (18,682 | ) | (114,086 | ) | |||||||||
|
Fuel inventory - at average cost
|
3,014 | 2,132 | 1 | 5,147 | ||||||||||||
|
Materials and supplies - at average cost
|
(1,293 | ) | 866 | - | (427 | ) | ||||||||||
|
Deferred nuclear refueling outage costs
|
22,203 | 52,447 | - | 74,650 | ||||||||||||
|
System agreement cost equalization
|
- | - | - | - | ||||||||||||
|
Prepayments and other
|
51,318 | (13,530 | ) | (55,325 | ) | (17,537 | ) | |||||||||
|
TOTAL
|
(295,816 | ) | 13,902 | (78,339 | ) | (360,253 | ) | |||||||||
|
OTHER PROPERTY AND INVESTMENTS
|
||||||||||||||||
|
Investment in affiliates - at equity
|
- | (761 | ) | - | (761 | ) | ||||||||||
|
Decommissioning trust funds
|
135,596 | 127,003 | - | 262,599 | ||||||||||||
|
Non-utility property - at cost (less accumulated depreciation)
|
5,455 | (1,108 | ) | (318 | ) | 4,029 | ||||||||||
|
Other
|
(249,330 | ) | 1,569 | - | (247,761 | ) | ||||||||||
|
TOTAL
|
(108,279 | ) | 126,703 | (318 | ) | 18,106 | ||||||||||
|
PROPERTY, PLANT, AND EQUIPMENT
|
||||||||||||||||
|
Electric
|
84,572 | 35,476 | 1 | 120,049 | ||||||||||||
|
Property under capital lease
|
(704 | ) | - | - | (704 | ) | ||||||||||
|
Natural gas
|
3,496 | - | - | 3,496 | ||||||||||||
|
Construction work in progress
|
48,752 | (53 | ) | (501 | ) | 48,198 | ||||||||||
|
Nuclear fuel
|
(8,135 | ) | 17,057 | - | 8,922 | |||||||||||
|
TOTAL PROPERTY, PLANT AND EQUIPMENT
|
127,981 | 52,480 | (500 | ) | 179,961 | |||||||||||
|
Less - accumulated depreciation and amortization
|
127,531 | 41,525 | 9 | 169,065 | ||||||||||||
|
PROPERTY, PLANT AND EQUIPMENT - NET
|
450 | 10,955 | (509 | ) | 10,896 | |||||||||||
|
DEFERRED DEBITS AND OTHER ASSETS
|
||||||||||||||||
|
Regulatory assets:
|
||||||||||||||||
|
Regulatory asset for income taxes - net
|
10,666 | - | - | 10,666 | ||||||||||||
|
Other regulatory assets
|
(165,026 | ) | - | - | (165,026 | ) | ||||||||||
|
Deferred fuel costs
|
- | - | - | - | ||||||||||||
|
Goodwill
|
- | - | - | - | ||||||||||||
|
Accumulated deferred income taxes
|
898 | 33,431 | (5,244 | ) | 29,085 | |||||||||||
|
Other
|
44,512 | (2,190 | ) | 4,675 | 46,997 | |||||||||||
|
TOTAL
|
(108,950 | ) | 31,241 | (569 | ) | (78,278 | ) | |||||||||
|
TOTAL ASSETS
|
$ | (512,595 | ) | $ | 182,801 | $ | (79,735 | ) | $ | (409,529 | ) | |||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Balance Sheet
|
||||||||||||||||
|
March 31, 2013 vs December 31, 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
LIABILITIES AND SHAREHOLDERS' EQUITY
|
||||||||||||||||
|
CURRENT LIABILITIES
|
||||||||||||||||
|
Currently maturing long-term debt
|
$ | (87,844 | ) | $ | (50 | ) | $ | - | $ | (87,894 | ) | |||||
|
Notes payable and commercial paper:
|
||||||||||||||||
|
Associated companies
|
(28,000 | ) | (1,437 | ) | 29,437 | - | ||||||||||
|
Other
|
59,590 | - | 218,296 | 277,886 | ||||||||||||
|
Account payable:
|
||||||||||||||||
|
Associated companies
|
(3,566 | ) | 338 | 3,228 | - | |||||||||||
|
Other
|
(215,353 | ) | 34,329 | (34 | ) | (181,058 | ) | |||||||||
|
Customer deposits
|
2,221 | - | - | 2,221 | ||||||||||||
|
Taxes accrued
|
(41,385 | ) | - | 5,737 | (35,648 | ) | ||||||||||
|
Accumulated deferred income taxes
|
6,525 | 21,003 | (25,633 | ) | 1,895 | |||||||||||
|
Interest accrued
|
(14,435 | ) | 620 | (16,754 | ) | (30,569 | ) | |||||||||
|
Deferred fuel costs
|
(68,755 | ) | - | - | (68,755 | ) | ||||||||||
|
Obligations under capital leases
|
(385 | ) | - | - | (385 | ) | ||||||||||
|
Pension and other postretirement liabilities
|
1,118 | 386 | - | 1,504 | ||||||||||||
|
System agreement cost equalization
|
(8,968 | ) | - | - | (8,968 | ) | ||||||||||
|
Other
|
3,669 | (83,716 | ) | (83 | ) | (80,130 | ) | |||||||||
|
TOTAL
|
(395,568 | ) | (28,527 | ) | 214,194 | (209,901 | ) | |||||||||
|
NON-CURRENT LIABILITIES
|
||||||||||||||||
|
Accumulated deferred income taxes and taxes accrued
|
(21,476 | ) | 127,000 | (68,304 | ) | 37,220 | ||||||||||
|
Accumulated deferred investment tax credits
|
(2,784 | ) | - | - | (2,784 | ) | ||||||||||
|
Obligations under capital leases
|
(565 | ) | - | - | (565 | ) | ||||||||||
|
Other regulatory liabilities
|
147,492 | - | - | 147,492 | ||||||||||||
|
Decommissioning and retirement cost liabilities
|
30,082 | (18,029 | ) | - | 12,053 | |||||||||||
|
Accumulated provisions
|
(246,401 | ) | 3,037 | (2,320 | ) | (245,684 | ) | |||||||||
|
Pension and other postretirement liabilities
|
18,250 | 12,942 | - | 31,192 | ||||||||||||
|
Long-term debt
|
33,087 | 676 | (224,947 | ) | (191,184 | ) | ||||||||||
|
Other
|
10,515 | (13,076 | ) | (794 | ) | (3,355 | ) | |||||||||
|
TOTAL
|
(31,800 | ) | 112,550 | (296,365 | ) | (215,615 | ) | |||||||||
|
Subsidiaries' preferred stock without sinking fund
|
- | - | - | - | ||||||||||||
|
EQUITY
|
||||||||||||||||
|
Common Shareholders' Equity:
|
||||||||||||||||
|
Common stock, $.01 par value, authorized 500,000,000 shares;
|
||||||||||||||||
|
issued 254,752,788 shares in 2012 and in 2011
|
- | - | - | - | ||||||||||||
|
Paid-in capital
|
- | 46,050 | (54,017 | ) | (7,967 | ) | ||||||||||
|
Retained earnings
|
(88,797 | ) | 66,873 | 35,504 | 13,580 | |||||||||||
|
Accumulated other comprehensive income (loss)
|
3,570 | (14,145 | ) | - | (10,575 | ) | ||||||||||
|
Less - treasury stock, at cost
|
- | - | (20,949 | ) | (20,949 | ) | ||||||||||
|
Total common shareholders' equity
|
(85,227 | ) | 98,778 | 2,436 | 15,987 | |||||||||||
|
Subsidiaries' preferred stock without sinking fund
|
- | - | - | - | ||||||||||||
|
TOTAL
|
(85,227 | ) | 98,778 | 2,436 | 15,987 | |||||||||||
|
TOTAL LIABILITIES AND EQUITY
|
$ | (512,595 | ) | $ | 182,801 | $ | (79,735 | ) | $ | (409,529 | ) | |||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Three Months Ended March 31, 2013
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 1,950,120 | $ | - | $ | (840 | ) | $ | 1,949,280 | |||||||
|
Natural gas
|
53,321 | - | - | 53,321 | ||||||||||||
|
Competitive businesses
|
- | 613,733 | (7,460 | ) | 606,273 | |||||||||||
|
Total
|
2,003,441 | 613,733 | (8,300 | ) | 2,608,874 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
411,320 | 99,411 | (398 | ) | 510,333 | |||||||||||
|
Purchased power
|
363,532 | 21,221 | (11,624 | ) | 373,129 | |||||||||||
|
Nuclear refueling outage expenses
|
30,076 | 30,643 | - | 60,719 | ||||||||||||
|
Asset impairment
|
- | - | - | - | ||||||||||||
|
Other operation and maintenance
|
519,756 | 231,359 | 3,143 | 754,258 | ||||||||||||
|
Decommissioning
|
28,527 | 30,577 | - | 59,104 | ||||||||||||
|
Taxes other than income taxes
|
118,063 | 32,748 | 284 | 151,095 | ||||||||||||
|
Depreciation and amortization
|
250,531 | 49,243 | 1,102 | 300,876 | ||||||||||||
|
Other regulatory charges (credits) - net
|
5,315 | - | - | 5,315 | ||||||||||||
|
Total
|
1,727,120 | 495,202 | (7,493 | ) | 2,214,829 | |||||||||||
|
OPERATING INCOME
|
276,321 | 118,531 | (807 | ) | 394,045 | |||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
12,751 | - | - | 12,751 | ||||||||||||
|
Interest and investment income
|
41,578 | 28,199 | (31,471 | ) | 38,306 | |||||||||||
|
Miscellaneous - net
|
(6,865 | ) | (4,612 | ) | (2,146 | ) | (13,623 | ) | ||||||||
|
Total
|
47,464 | 23,587 | (33,617 | ) | 37,434 | |||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
130,063 | 3,068 | 20,018 | 153,149 | ||||||||||||
|
Allowance for borrowed funds used during construction
|
(5,188 | ) | - | - | (5,188 | ) | ||||||||||
|
Total
|
124,875 | 3,068 | 20,018 | 147,961 | ||||||||||||
|
INCOME BEFORE INCOME TAXES
|
198,910 | 139,050 | (54,442 | ) | 283,518 | |||||||||||
|
Income taxes
|
71,075 | 56,936 | (11,475 | ) | 116,536 | |||||||||||
|
CONSOLIDATED NET INCOME
|
127,835 | 82,114 | (42,967 | ) | 166,982 | |||||||||||
|
Preferred dividend requirements of subsidiaries
|
4,332 | - | 1,250 | 5,582 | ||||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 123,503 | $ | 82,114 | $ | (44,217 | ) | $ | 161,400 | |||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 0.70 | $ | 0.46 | $ | (0.25 | ) | $ | 0.91 | |||||||
|
DILUTED
|
$ | 0.69 | $ | 0.46 | $ | (0.25 | ) | $ | 0.90 | |||||||
|
AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
|
||||||||||||||||
|
BASIC
|
178,027,961 | |||||||||||||||
|
DILUTED
|
178,413,287 | |||||||||||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Three Months Ended March 31, 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 1,785,632 | $ | - | $ | (791 | ) | $ | 1,784,841 | |||||||
|
Natural gas
|
46,008 | - | - | 46,008 | ||||||||||||
|
Competitive businesses
|
- | 560,251 | (7,441 | ) | 552,810 | |||||||||||
|
Total
|
1,831,640 | 560,251 | (8,232 | ) | 2,383,659 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
444,438 | 94,701 | (302 | ) | 538,837 | |||||||||||
|
Purchased power
|
281,190 | 13,875 | (10,099 | ) | 284,966 | |||||||||||
|
Nuclear refueling outage expenses
|
26,702 | 37,181 | - | 63,884 | ||||||||||||
|
Asset impairment
|
- | 355,524 | - | 355,524 | ||||||||||||
|
Other operation and maintenance
|
490,227 | 232,759 | (1,350 | ) | 721,635 | |||||||||||
|
Decommissioning
|
28,231 | 29,672 | - | 57,903 | ||||||||||||
|
Taxes other than income taxes
|
107,099 | 29,770 | 301 | 137,170 | ||||||||||||
|
Depreciation and amortization
|
228,086 | 51,072 | 1,058 | 280,215 | ||||||||||||
|
Other regulatory charges (credits) - net
|
382 | - | - | 382 | ||||||||||||
|
Total
|
1,606,355 | 844,554 | (10,392 | ) | 2,440,516 | |||||||||||
|
OPERATING INCOME (LOSS)
|
225,285 | (284,303 | ) | 2,160 | (56,857 | ) | ||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
24,307 | - | - | 24,307 | ||||||||||||
|
Interest and investment income
|
43,273 | 30,198 | (32,479 | ) | 40,992 | |||||||||||
|
Miscellaneous - net
|
(7,863 | ) | (7,781 | ) | (2,345 | ) | (17,990 | ) | ||||||||
|
Total
|
59,717 | 22,417 | (34,824 | ) | 47,309 | |||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
127,474 | 6,204 | 13,067 | 146,745 | ||||||||||||
|
Allowance for borrowed funds used during construction
|
(9,391 | ) | - | - | (9,391 | ) | ||||||||||
|
Total
|
118,083 | 6,204 | 13,067 | 137,354 | ||||||||||||
|
INCOME (LOSS) BEFORE INCOME TAXES
|
166,919 | (268,090 | ) | (45,731 | ) | (146,902 | ) | |||||||||
|
Income taxes
|
99,707 | (92,141 | ) | (7,728 | ) | (162 | ) | |||||||||
|
CONSOLIDATED NET INCOME (LOSS)
|
67,212 | (175,949 | ) | (38,003 | ) | (146,740 | ) | |||||||||
|
Preferred dividend requirements of subsidiaries
|
4,332 | - | 611 | 4,943 | ||||||||||||
|
NET INCOME (LOSS) ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 62,880 | $ | (175,949 | ) | $ | (38,614 | ) | $ | (151,683 | ) | |||||
|
EARNINGS (LOSS) PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 0.35 | $ | (0.99 | ) | $ | (0.22 | ) | $ | (0.86 | ) | |||||
|
DILUTED
|
$ | 0.35 | $ | (0.99 | ) | $ | (0.22 | ) | $ | (0.86 | ) | |||||
|
AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
|
||||||||||||||||
|
BASIC
|
176,865,363 | |||||||||||||||
|
DILUTED
|
177,388,045 | |||||||||||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Three Months Ended March 31, 2013 vs. 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 164,488 | $ | - | $ | (49 | ) | $ | 164,439 | |||||||
|
Natural gas
|
7,313 | - | - | 7,313 | ||||||||||||
|
Competitive businesses
|
- | 53,482 | (19 | ) | 53,463 | |||||||||||
|
Total
|
171,801 | 53,482 | (68 | ) | 225,215 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
(33,118 | ) | 4,710 | (96 | ) | (28,504 | ) | |||||||||
|
Purchased power
|
82,342 | 7,346 | (1,525 | ) | 88,163 | |||||||||||
|
Nuclear refueling outage expenses
|
3,374 | (6,538 | ) | - | (3,165 | ) | ||||||||||
|
Asset impairment
|
- | (355,524 | ) | - | (355,524 | ) | ||||||||||
|
Other operation and maintenance
|
29,529 | (1,400 | ) | 4,493 | 32,623 | |||||||||||
|
Decommissioning
|
296 | 905 | - | 1,201 | ||||||||||||
|
Taxes other than income taxes
|
10,964 | 2,978 | (17 | ) | 13,925 | |||||||||||
|
Depreciation and amortization
|
22,445 | (1,829 | ) | 44 | 20,661 | |||||||||||
|
Other regulatory charges (credits )- net
|
4,933 | - | - | 4,933 | ||||||||||||
|
Total
|
120,765 | (349,352 | ) | 2,899 | (225,687 | ) | ||||||||||
|
OPERATING INCOME
|
51,036 | 402,834 | (2,967 | ) | 450,902 | |||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
(11,556 | ) | - | - | (11,556 | ) | ||||||||||
|
Interest and investment income
|
(1,695 | ) | (1,999 | ) | 1,008 | (2,686 | ) | |||||||||
|
Miscellaneous - net
|
998 | 3,169 | 199 | 4,367 | ||||||||||||
|
Total
|
(12,253 | ) | 1,170 | 1,207 | (9,875 | ) | ||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
2,589 | (3,136 | ) | 6,951 | 6,404 | |||||||||||
|
Allowance for borrowed funds used during construction
|
4,203 | - | - | 4,203 | ||||||||||||
|
Total
|
6,792 | (3,136 | ) | 6,951 | 10,607 | |||||||||||
|
INCOME BEFORE INCOME TAXES
|
31,991 | 407,140 | (8,711 | ) | 430,420 | |||||||||||
|
Income taxes
|
(28,632 | ) | 149,077 | (3,747 | ) | 116,698 | ||||||||||
|
CONSOLIDATED NET INCOME
|
60,623 | 258,063 | (4,964 | ) | 313,722 | |||||||||||
|
Preferred dividend requirements of subsidiaries
|
- | - | 639 | 639 | ||||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 60,623 | $ | 258,063 | $ | (5,603 | ) | $ | 313,083 | |||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 0.35 | $ | 1.45 | $ | (0.03 | ) | $ | 1.77 | |||||||
|
DILUTED
|
$ | 0.34 | $ | 1.45 | $ | (0.03 | ) | $ | 1.76 | |||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Twelve Months Ended March 31, 2013
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 8,038,743 | $ | - | $ | (3,656 | ) | $ | 8,035,087 | |||||||
|
Natural gas
|
138,148 | - | - | 138,148 | ||||||||||||
|
Competitive businesses
|
- | 2,379,791 | (25,733 | ) | 2,354,059 | |||||||||||
|
Total
|
8,176,891 | 2,379,791 | (29,389 | ) | 10,527,294 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
1,642,901 | 367,116 | (1,685 | ) | 2,008,332 | |||||||||||
|
Purchased power
|
1,267,746 | 117,673 | (41,457 | ) | 1,343,962 | |||||||||||
|
Nuclear refueling outage expenses
|
114,210 | 128,225 | - | 242,435 | ||||||||||||
|
Asset impairment
|
- | - | - | - | ||||||||||||
|
Other operation and maintenance
|
2,109,049 | 956,441 | 12,525 | 3,078,016 | ||||||||||||
|
Decommissioning
|
112,961 | 73,001 | - | 185,962 | ||||||||||||
|
Taxes other than income taxes
|
443,386 | 126,619 | 1,219 | 571,223 | ||||||||||||
|
Depreciation and amortization
|
986,626 | 174,218 | 4,402 | 1,165,245 | ||||||||||||
|
Other regulatory charges (credits) - net
|
180,036 | - | - | 180,036 | ||||||||||||
|
Total
|
6,856,915 | 1,943,293 | (24,996 | ) | 8,775,211 | |||||||||||
|
OPERATING INCOME
|
1,319,976 | 436,498 | (4,393 | ) | 1,752,083 | |||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
81,202 | - | - | 81,202 | ||||||||||||
|
Interest and investment income
|
148,597 | 103,063 | (126,570 | ) | 125,090 | |||||||||||
|
Miscellaneous - net
|
(24,846 | ) | (15,901 | ) | (8,099 | ) | (48,846 | ) | ||||||||
|
Total
|
204,953 | 87,162 | (134,669 | ) | 157,446 | |||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
516,385 | 14,764 | 81,850 | 613,001 | ||||||||||||
|
Allowance for borrowed funds used during construction
|
(33,109 | ) | - | - | (33,109 | ) | ||||||||||
|
Total
|
483,276 | 14,764 | 81,850 | 579,892 | ||||||||||||
|
INCOME BEFORE INCOME TAXES
|
1,041,653 | 508,896 | (220,912 | ) | 1,329,637 | |||||||||||
|
Income taxes
|
20,708 | 210,406 | (83,562 | ) | 147,552 | |||||||||||
|
CONSOLIDATED NET INCOME
|
1,020,945 | 298,490 | (137,350 | ) | 1,182,085 | |||||||||||
|
Preferred dividend requirements of subsidiaries
|
17,329 | - | 5,000 | 22,329 | ||||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 1,003,616 | $ | 298,490 | $ | (142,350 | ) | $ | 1,159,756 | |||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 5.65 | $ | 1.68 | $ | (0.80 | ) | $ | 6.53 | |||||||
|
DILUTED
|
$ | 5.63 | $ | 1.68 | $ | (0.80 | ) | $ | 6.51 | |||||||
|
AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
|
||||||||||||||||
|
BASIC
|
177,612,730 | |||||||||||||||
|
DILUTED
|
178,156,757 | |||||||||||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Twelve Months Ended March 31, 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 8,595,145 | $ | - | $ | (2,686 | ) | $ | 8,592,459 | |||||||
|
Natural gas
|
140,704 | - | - | 140,704 | ||||||||||||
|
Competitive businesses
|
- | 2,363,877 | (25,517 | ) | 2,338,361 | |||||||||||
|
Total
|
8,735,849 | 2,363,877 | (28,203 | ) | 11,071,524 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
2,189,840 | 334,896 | (878 | ) | 2,523,859 | |||||||||||
|
Purchased power
|
1,472,923 | 57,078 | (42,686 | ) | 1,487,315 | |||||||||||
|
Nuclear refueling outage expenses
|
105,227 | 150,290 | - | 255,516 | ||||||||||||
|
Asset impairment
|
- | 355,524 | - | 355,524 | ||||||||||||
|
Other operation and maintenance
|
1,992,590 | 929,182 | 11,875 | 2,933,646 | ||||||||||||
|
Decommissioning
|
110,213 | 83,019 | - | 193,233 | ||||||||||||
|
Taxes other than income taxes
|
435,127 | 111,322 | 1,512 | 547,961 | ||||||||||||
|
Depreciation and amortization
|
925,933 | 187,032 | 4,567 | 1,117,532 | ||||||||||||
|
Other regulatory charges (credits) - net
|
211,452 | - | - | 211,452 | ||||||||||||
|
Total
|
7,443,305 | 2,208,343 | (25,610 | ) | 9,626,038 | |||||||||||
|
OPERATING INCOME
|
1,292,544 | 155,534 | (2,593 | ) | 1,445,486 | |||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
91,323 | - | - | 91,323 | ||||||||||||
|
Interest and investment income
|
165,416 | 107,730 | (129,907 | ) | 143,239 | |||||||||||
|
Miscellaneous - net
|
(28,739 | ) | (28,181 | ) | (10,940 | ) | (67,861 | ) | ||||||||
|
Total
|
228,000 | 79,549 | (140,847 | ) | 166,701 | |||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
500,055 | 30,295 | 31,781 | 562,131 | ||||||||||||
|
Allowance for borrowed funds used during construction
|
(38,750 | ) | - | - | (38,750 | ) | ||||||||||
|
Total
|
461,305 | 30,295 | 31,781 | 523,381 | ||||||||||||
|
INCOME BEFORE INCOME TAXES
|
1,059,239 | 204,788 | (175,221 | ) | 1,088,806 | |||||||||||
|
Income taxes
|
36,814 | 3,355 | 81,683 | 121,852 | ||||||||||||
|
CONSOLIDATED NET INCOME
|
1,022,425 | 201,433 | (256,904 | ) | 966,954 | |||||||||||
|
Preferred dividend requirements of subsidiaries
|
17,329 | 2,562 | 970 | 20,861 | ||||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 1,005,096 | $ | 198,871 | $ | (257,874 | ) | $ | 946,093 | |||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 5.68 | $ | 1.13 | $ | (1.46 | ) | $ | 5.35 | |||||||
|
DILUTED
|
$ | 5.65 | $ | 1.12 | $ | (1.45 | ) | $ | 5.32 | |||||||
|
AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
|
||||||||||||||||
|
BASIC
|
176,944,489 | |||||||||||||||
|
DILUTED
|
177,975,165 | |||||||||||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Twelve Months Ended March 31, 2013 vs. 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | (556,402 | ) | $ | - | $ | (970 | ) | $ | (557,372 | ) | |||||
|
Natural gas
|
(2,556 | ) | - | - | (2,556 | ) | ||||||||||
|
Competitive businesses
|
- | 15,914 | (216 | ) | 15,698 | |||||||||||
|
Total
|
(558,958 | ) | 15,914 | (1,186 | ) | (544,230 | ) | |||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
(546,939 | ) | 32,220 | (807 | ) | (515,527 | ) | |||||||||
|
Purchased power
|
(205,177 | ) | 60,595 | 1,229 | (143,353 | ) | ||||||||||
|
Nuclear refueling outage expenses
|
8,983 | (22,065 | ) | - | (13,081 | ) | ||||||||||
|
Asset impairment
|
- | (355,524 | ) | - | (355,524 | ) | ||||||||||
|
Other operation and maintenance
|
116,459 | 27,259 | 650 | 144,370 | ||||||||||||
|
Decommissioning
|
2,748 | (10,018 | ) | - | (7,271 | ) | ||||||||||
|
Taxes other than income taxes
|
8,259 | 15,297 | (293 | ) | 23,262 | |||||||||||
|
Depreciation and amortization
|
60,693 | (12,814 | ) | (165 | ) | 47,713 | ||||||||||
|
Other regulatory charges (credits )- net
|
(31,416 | ) | - | - | (31,416 | ) | ||||||||||
|
Total
|
(586,390 | ) | (265,050 | ) | 614 | (850,827 | ) | |||||||||
|
OPERATING INCOME
|
27,432 | 280,964 | (1,800 | ) | 306,597 | |||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
(10,121 | ) | - | - | (10,121 | ) | ||||||||||
|
Interest and investment income
|
(16,819 | ) | (4,667 | ) | 3,337 | (18,149 | ) | |||||||||
|
Miscellaneous - net
|
3,893 | 12,280 | 2,841 | 19,015 | ||||||||||||
|
Total
|
(23,047 | ) | 7,613 | 6,178 | (9,255 | ) | ||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
16,330 | (15,531 | ) | 50,069 | 50,870 | |||||||||||
|
Allowance for borrowed funds used during construction
|
5,641 | - | - | 5,641 | ||||||||||||
|
Total
|
21,971 | (15,531 | ) | 50,069 | 56,511 | |||||||||||
|
INCOME BEFORE INCOME TAXES
|
(17,586 | ) | 304,108 | (45,691 | ) | 240,831 | ||||||||||
|
Income taxes
|
(16,106 | ) | 207,051 | (165,245 | ) | 25,700 | ||||||||||
|
CONSOLIDATED NET INCOME
|
(1,480 | ) | 97,057 | 119,554 | 215,131 | |||||||||||
|
Preferred dividend requirements of subsidiaries
|
- | (2,562 | ) | 4,030 | 1,468 | |||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | (1,480 | ) | $ | 99,619 | $ | 115,524 | $ | 213,663 | |||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | (0.03 | ) | $ | 0.55 | $ | 0.66 | $ | 1.18 | |||||||
|
DILUTED
|
$ | (0.02 | ) | $ | 0.56 | $ | 0.65 | $ | 1.19 | |||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||
|
Consolidated Cash Flow Statement
|
||||||||||||
|
Three Months Ended March 31, 2013 vs. 2012
|
||||||||||||
|
(Dollars in thousands)
|
||||||||||||
|
(Unaudited)
|
||||||||||||
|
2013
|
2012
|
Variance
|
||||||||||
|
OPERATING ACTIVITIES
|
||||||||||||
|
Consolidated net income (loss)
|
$ | 166,982 | $ | (146,740 | ) | $ | 313,722 | |||||
|
Adjustments to reconcile consolidated net income (loss) to net cash
|
||||||||||||
|
flow provided by operating activities:
|
||||||||||||
|
Depreciation, amortization, and decommissioning, including nuclear fuel amortization
|
472,933 | 450,009 | 22,924 | |||||||||
|
Deferred income taxes, investment tax credits, and non-current taxes accrued
|
98,671 | 38,858 | 59,813 | |||||||||
|
Asset impairment
|
- | 355,524 | (355,524 | ) | ||||||||
|
Changes in working capital:
|
||||||||||||
|
Receivables
|
(29,845 | ) | 156,202 | (186,047 | ) | |||||||
|
Fuel inventory
|
(5,147 | ) | (20,213 | ) | 15,066 | |||||||
|
Accounts payable
|
(40,861 | ) | (145,599 | ) | 104,738 | |||||||
|
Prepaid taxes and taxes accrued
|
(35,648 | ) | (89,583 | ) | 53,935 | |||||||
|
Interest accrued
|
(30,570 | ) | (32,194 | ) | 1,624 | |||||||
|
Deferred fuel
|
(2,149 | ) | 77,405 | (79,554 | ) | |||||||
|
Other working capital accounts
|
(151,958 | ) | (34,753 | ) | (117,205 | ) | ||||||
|
Changes in provisions for estimated losses
|
(245,972 | ) | (15,030 | ) | (230,942 | ) | ||||||
|
Changes in other regulatory assets
|
167,634 | 60,857 | 106,777 | |||||||||
|
Changes in pensions and other postretirement liabilities
|
32,696 | (4,764 | ) | 37,460 | ||||||||
|
Other
|
147,223 | (49,479 | ) | 196,702 | ||||||||
|
Net cash flow provided by operating activities
|
543,989 | 600,500 | (56,511 | ) | ||||||||
|
INVESTING ACTIVITIES
|
||||||||||||
|
Construction/capital expenditures
|
(631,857 | ) | (563,539 | ) | (68,318 | ) | ||||||
|
Allowance for equity funds used during construction
|
13,672 | 25,448 | (11,776 | ) | ||||||||
|
Nuclear fuel purchases
|
(145,168 | ) | (201,059 | ) | 55,891 | |||||||
|
Changes in transition charge account
|
1,601 | 940 | 661 | |||||||||
|
NYPA value sharing payment
|
(71,736 | ) | (72,000 | ) | 264 | |||||||
|
Payments to storm reserve escrow account
|
(2,219 | ) | (1,483 | ) | (736 | ) | ||||||
|
Receipts from storm reserve escrow account
|
252,482 | 861 | 251,621 | |||||||||
|
Decrease (increase) in other investments
|
(44,298 | ) | 93,786 | (138,084 | ) | |||||||
|
Proceeds from nuclear decommissioning trust fund sales
|
398,010 | 535,551 | (137,541 | ) | ||||||||
|
Investment in nuclear decommissioning trust funds
|
(432,247 | ) | (567,780 | ) | 135,533 | |||||||
|
Net cash flow used in investing activities
|
(661,760 | ) | (749,275 | ) | 87,515 | |||||||
|
FINANCING ACTIVITIES
|
||||||||||||
|
Proceeds from the issuance of:
|
||||||||||||
|
Long-term debt
|
564,717 | 1,034,945 | (470,228 | ) | ||||||||
|
Mandatorily redeemable preferred membership units of subsidiary
|
- | 51,000 | (51,000 | ) | ||||||||
|
Treasury stock
|
8,102 | 32,826 | (24,724 | ) | ||||||||
|
Retirement of long-term debt
|
(849,860 | ) | (859,648 | ) | 9,788 | |||||||
|
Changes in credit borrowings and commercial paper - net
|
277,886 | 32,782 | 245,104 | |||||||||
|
Dividends paid:
|
||||||||||||
|
Common stock
|
(147,902 | ) | (146,674 | ) | (1,228 | ) | ||||||
|
Preferred stock
|
(5,582 | ) | (5,582 | ) | - | |||||||
|
Net cash flow provided by (used in) financing activities
|
(152,639 | ) | 139,649 | (292,288 | ) | |||||||
|
Effect of exchange rates on cash and cash equivalents
|
772 | (310 | ) | 1,082 | ||||||||
|
Net increase (decrease) in cash and cash equivalents
|
(269,638 | ) | (9,436 | ) | (260,202 | ) | ||||||
|
Cash and cash equivalents at beginning of period
|
532,569 | 694,438 | (161,869 | ) | ||||||||
|
Cash and cash equivalents at end of period
|
$ | 262,931 | $ | 685,002 | $ | (422,071 | ) | |||||
|
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
|
||||||||||||
|
Cash paid (received) during the period for:
|
||||||||||||
|
Interest - net of amount capitalized
|
$ | 138,217 | $ | 134,655 | $ | 3,562 | ||||||
|
Income taxes
|
$ | 12,341 | $ | 35,992 | $ | (23,651 | ) | |||||
|
Entergy Corporation
|
||||||||||||
|
Consolidated Cash Flow Statement
|
||||||||||||
|
Twelve Months Ended March 31, 2013 vs. 2012
|
||||||||||||
|
(Dollars in thousands)
|
||||||||||||
|
(Unaudited)
|
||||||||||||
|
2013
|
2012
|
Variance
|
||||||||||
|
OPERATING ACTIVITIES
|
||||||||||||
|
Consolidated net income
|
$ | 1,182,085 | $ | 966,954 | $ | 215,131 | ||||||
|
Adjustments to reconcile consolidated net income to net cash flow
|
||||||||||||
|
provided by operating activities:
|
||||||||||||
|
Depreciation, amortization, and decommissioning, including nuclear fuel amortization
|
1,794,573 | 1,773,053 | 21,520 | |||||||||
|
Deferred income taxes, investment tax credits, and non-current taxes accrued
|
33,334 | (414,955 | ) | 448,289 | ||||||||
|
Asset impairment
|
- | 355,524 | (355,524 | ) | ||||||||
|
Changes in working capital:
|
||||||||||||
|
Receivables
|
(200,249 | ) | 81,582 | (281,831 | ) | |||||||
|
Fuel inventory
|
3,462 | (2,312 | ) | 5,774 | ||||||||
|
Accounts payable
|
97,959 | (123,171 | ) | 221,130 | ||||||||
|
Prepaid taxes and taxes accrued
|
109,419 | 554,377 | (444,958 | ) | ||||||||
|
Interest accrued
|
2,776 | 1,612 | 1,164 | |||||||||
|
Deferred fuel
|
(179,541 | ) | 88,267 | (267,808 | ) | |||||||
|
Other working capital accounts
|
(269,194 | ) | 109,416 | (378,610 | ) | |||||||
|
Changes in provisions for estimated losses
|
(255,750 | ) | (25,337 | ) | (230,413 | ) | ||||||
|
Changes in other regulatory assets
|
(291,651 | ) | (661,276 | ) | 369,625 | |||||||
|
Changes in pensions and other postretirement liabilities
|
681,559 | 1,148,655 | (467,096 | ) | ||||||||
|
Other
|
174,992 | (446,173 | ) | 621,165 | ||||||||
|
Net cash flow provided by operating activities
|
2,883,774 | 3,406,216 | (522,442 | ) | ||||||||
|
INVESTING ACTIVITIES
|
||||||||||||
|
Construction/capital expenditures
|
(2,742,968 | ) | (2,117,005 | ) | (625,963 | ) | ||||||
|
Allowance for equity funds used during construction
|
84,355 | 94,411 | (10,056 | ) | ||||||||
|
Nuclear fuel purchases
|
(502,069 | ) | (541,577 | ) | 39,508 | |||||||
|
Payment for purchase of plant
|
(456,356 | ) | (646,137 | ) | 189,781 | |||||||
|
Proceeds from sale of assets and businesses
|
- | 6,531 | (6,531 | ) | ||||||||
|
Changes in securitization account
|
4,926 | (12,680 | ) | 17,606 | ||||||||
|
NYPA value sharing payment
|
(71,736 | ) | (72,000 | ) | 264 | |||||||
|
Payments to storm reserve escrow account
|
(9,693 | ) | (6,172 | ) | (3,521 | ) | ||||||
|
Receipts from storm reserve escrow account
|
279,505 | 861 | 278,644 | |||||||||
|
Decrease (increase) in other investments
|
(122,909 | ) | 103,375 | (226,284 | ) | |||||||
|
Litigation proceeds for reimbursement of spent nuclear fuel storage costs
|
109,105 | - | 109,105 | |||||||||
|
Proceeds from nuclear decommissioning trust fund sales
|
1,936,514 | 1,403,215 | 533,299 | |||||||||
|
Investment in nuclear decommissioning trust funds
|
(2,060,956 | ) | (1,512,125 | ) | (548,831 | ) | ||||||
|
Net cash flow used in investing activities
|
(3,552,282 | ) | (3,299,303 | ) | (252,979 | ) | ||||||
|
FINANCING ACTIVITIES
|
||||||||||||
|
Proceeds from the issuance of:
|
||||||||||||
|
Long-term debt
|
3,008,133 | 3,614,382 | (606,249 | ) | ||||||||
|
Mandatorily redeemable preferred membership units of subsidiary
|
- | 51,000 | (51,000 | ) | ||||||||
|
Common stock and treasury stock
|
38,162 | 66,731 | (28,569 | ) | ||||||||
|
Retirement of long-term debt
|
(3,120,445 | ) | (3,018,936 | ) | (101,509 | ) | ||||||
|
Repurchase of common stock
|
- | (180,228 | ) | 180,228 | ||||||||
|
Redemption of subsidiary common and preferred stock
|
- | (30,308 | ) | 30,308 | ||||||||
|
Changes in credit borrowings and commercial paper - net
|
932,779 | (41,963 | ) | 974,742 | ||||||||
|
Dividends paid:
|
||||||||||||
|
Common stock
|
(590,437 | ) | (587,601 | ) | (2,836 | ) | ||||||
|
Preferred stock
|
(22,329 | ) | (21,500 | ) | (829 | ) | ||||||
|
Net cash flow provided by (used in) financing activities
|
245,863 | (148,423 | ) | 394,286 | ||||||||
|
Effect of exchange rates on cash and cash equivalents
|
574 | 275 | 299 | |||||||||
|
Net increase (decrease) in cash and cash equivalents
|
(422,071 | ) | (41,235 | ) | (380,836 | ) | ||||||
|
Cash and cash equivalents at beginning of period
|
685,002 | 726,237 | (41,235 | ) | ||||||||
|
Cash and cash equivalents at end of period
|
$ | 262,931 | $ | 685,002 | $ | (422,071 | ) | |||||
|
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
|
||||||||||||
|
Cash paid (received) during the period for:
|
||||||||||||
|
Interest - net of amount capitalized
|
$ | 549,687 | $ | 502,363 | $ | 47,324 | ||||||
|
Income taxes
|
$ | 25,563 | $ | 38,330 | $ | (12,767 | ) | |||||