Attached files
| file | filename |
|---|---|
| 8-K - ENTERGY CORP /DE/ | a06213.htm |
| EX-99.2 - ENTERGY CORP /DE/ | a06213992.htm |
| EX-99.3 - ENTERGY CORP /DE/ | a06213993.htm |
Exhibit 99.1
|
For further information:
Paula Waters, VP, Investor Relations
504/576-4380
pwater1@entergy.com
|
INVESTOR NEWS
Oct. 29, 2013
ENTERGY REPORTS THIRD QUARTER EARNINGS,
ISSUES FORWARD-LOOKING FINANCIAL UPDATE
NEW ORLEANS – Entergy Corporation (NYSE: ETR) reported earnings of $1.34 per share on an as-reported basis and $2.41 per share on an operational basis for third quarter 2013, as shown in Table 1 below. A more detailed discussion of quarterly results begins on page 2 of this release. Entergy also affirmed 2013 operational earnings guidance and initiated operational earnings guidance for 2014 as well as issued a preliminary three-year capital plan for 2014 through 2016, all on a business as usual basis.
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Table 1: Consolidated Earnings – Reconciliation of GAAP to Non-GAAP Measures
|
||||||
|
Third Quarter and Year-to-Date 2013 vs. 2012
|
||||||
|
(Per share in U.S. $)
|
||||||
|
Third Quarter
|
Year-to-Date
|
|||||
|
2013
|
2012
|
Change
|
2013
|
2012
|
Change
|
|
|
As-Reported Earnings
|
1.34
|
1.89
|
(0.55)
|
3.16
|
3.10
|
0.06
|
|
Less Special Items
|
(1.07)
|
(0.06)
|
(1.01)
|
(1.20)
|
(1.41)
|
0.21
|
|
Operational Earnings
|
2.41
|
1.95
|
0.46
|
4.36
|
4.51
|
(0.15)
|
|
Weather Impact
|
0.01
|
0.08
|
(0.07)
|
(0.11)
|
(0.01)
|
(0.10)
|
Operational Earnings Highlights for Third Quarter 2013
|
·
|
Utility earnings were higher driven largely by increased net revenue and a lower effective income tax rate, partially offset by higher non-fuel operation and maintenance and depreciation expenses.
|
|
·
|
Entergy Wholesale Commodities earnings decreased due primarily to higher non-fuel operation and maintenance and depreciation expenses, partially offset by a lower effective income tax rate on operational earnings.
|
|
·
|
Parent & Other results increased due to lower income tax expense.
|
“During the quarter, we saw positive results in Utility top-line growth, reflecting strong industrial sales during the quarter,” said Leo Denault, Entergy’s chairman and chief executive officer. “EWC net revenue reflected higher capacity prices, which were offset by other declines. As we look ahead, we see opportunities in each of our businesses. At the Utility, we’re aggressively pursuing initiatives that benefit customers such as the proposed spin-merge of the transmission business with ITC as well as growth prospects and investment opportunities presented by the strong economic development pipeline. At EWC, we remain focused on optimizing financial performance at each of the assets. In addition, savings realized from the Human Capital Management effort benefit both businesses, helping to maintain reasonable rates at the Utility and improving the cost position of EWC.”
Entergy’s business highlights also included the following:
|
·
|
The FERC issued its decision accepting NYISO’s new capacity zone for Lower Hudson Valley.
|
|
·
|
EMI and ENOI received orders in August on formula rate plan filings.
|
|
·
|
EGSL signed an agreement with Methanex USA LLC to supply up to 30 megawatts of power to Methanex’s new methanol facility in Geismar, La., for an initial 10-year term.
|
|
·
|
Entergy was included in the 2013/2014 Dow Jones Sustainability World and North America Indices.
|
|
·
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Entergy was added to the CDP S&P 500 Climate Performance Leadership Index, the only utility added to the performance index this year. Entergy was also named to the CDP S&P 500 Climate Disclosure Leadership Index.
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A teleconference will be held at 10 a.m. CT on Tuesday, Oct. 29, 2013, to discuss Entergy’s third quarter 2013 earnings announcement and the company’s financial performance. The teleconference may be accessed by dialing (719) 457-2080, confirmation code 8044514, no more than 15 minutes prior to the start of the call or by visiting Entergy’s website at www.entergy.com. The presentation slides also are now available on Entergy’s website concurrent with this release, which was issued before market open on the day of the call. 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 SEC 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 Nov. 5, 2013, by dialing (719) 457-0820, confirmation code 8044514.
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I.
|
Consolidated Results
|
Consolidated Earnings
Table 2 provides a comparative summary of consolidated earnings per share for third quarter and year-to-date 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
Third Quarter and Year-to-Date 2013 vs. 2012 (see Appendix F for definitions of certain measures)
|
||||||
|
(Per share in U.S. $)
|
||||||
|
Third Quarter
|
Year-to-Date
|
|||||
|
2013
|
2012
|
Change
|
2013
|
2012
|
Change
|
|
|
As-Reported
|
||||||
|
Utility
|
1.95
|
1.66
|
0.29
|
3.74
|
3.73
|
0.01
|
|
Entergy Wholesale Commodities
|
(0.52)
|
0.49
|
(1.01)
|
-
|
(0.10)
|
0.10
|
|
Parent & Other
|
(0.09)
|
(0.26)
|
0.17
|
(0.58)
|
(0.53)
|
(0.05)
|
|
Consolidated As-Reported Earnings
|
1.34
|
1.89
|
(0.55)
|
3.16
|
3.10
|
0.06
|
|
Less Special Items
|
||||||
|
Utility
|
(0.09)
|
(0.06)
|
(0.03)
|
(0.21)
|
(0.15)
|
(0.06)
|
|
Entergy Wholesale Commodities
|
(0.98)
|
-
|
(0.98)
|
(0.99)
|
(1.26)
|
0.27
|
|
Parent & Other
|
-
|
-
|
-
|
-
|
-
|
-
|
|
Consolidated Special Items
|
(1.07)
|
(0.06)
|
(1.01)
|
(1.20)
|
(1.41)
|
0.21
|
|
Operational
|
||||||
|
Utility
|
2.04
|
1.72
|
0.32
|
3.95
|
3.88
|
0.07
|
|
Entergy Wholesale Commodities
|
0.46
|
0.49
|
(0.03)
|
0.99
|
1.16
|
(0.17)
|
|
Parent & Other
|
(0.09)
|
(0.26)
|
0.17
|
(0.58)
|
(0.53)
|
(0.05)
|
|
Consolidated Operational Earnings
|
2.41
|
1.95
|
0.46
|
4.36
|
4.51
|
(0.15)
|
|
Weather Impact
|
0.01
|
0.08
|
(0.07)
|
(0.11)
|
(0.01)
|
(0.10)
|
Detailed earnings variance analyses are included in Appendix B-1 and Appendix B-2 to this release. In addition, Appendix B-3 provides details of special items shown in Table 2 above.
Consolidated Operating Cash Flow
Entergy’s operating cash flow in third quarter 2013 was $1,084 million compared to $1,032 million in third quarter 2012. The overall quarterly increase was due to several factors, including EAI’s receipt of damages from DOE litigation for spent nuclear fuel costs in third quarter 2013. Variations in cash flow from net revenue also contributed to the period-over-period cash flow variance. Higher income tax payments provided a partial offset.
Table 3 provides the components of operating cash flow contributed by each business with current quarter and year-to-date comparisons.
|
Table 3: Consolidated Operating Cash Flow
|
||||||
|
Third Quarter and Year-to-Date 2013 vs. 2012
|
||||||
|
(U.S. $ in millions)
|
||||||
|
Third Quarter
|
Year-to-Date
|
|||||
|
2013
|
2012
|
Change
|
2013
|
2012
|
Change
|
|
|
Utility
|
921
|
821
|
100
|
1,302
|
1,797
|
(495)
|
|
Entergy Wholesale Commodities
|
220
|
273
|
(53)
|
535
|
566
|
(31)
|
|
Parent & Other
|
(57)
|
(62)
|
5
|
362
|
(143)
|
505
|
|
Total Operating Cash Flow
|
1,084
|
1,032
|
52
|
2,199
|
2,220
|
(21)
|
|
II.
|
Utility
|
In third quarter 2013, Utility earnings were $1.95 per share on an as-reported basis and $2.04 per share on an operational basis, compared to as-reported earnings per share of $1.66 and operational earnings per share of $1.72 in third quarter 2012. The quarter-over-quarter increase in operational earnings per share was due largely to higher net revenue and a lower effective income tax rate, partially offset by higher non-fuel operation and maintenance and depreciation expenses.
Utility net revenue was higher than a year ago. Pricing adjustments contributed to the net revenue increase. Current quarter net revenue reflected regulatory actions from placing major generation investments in service. A portion of the net revenue increase was for recovery of costs below the net revenue line. Also contributing to the increase in net revenue was higher volume, including effects in unbilled retail sales. Weather was less favorable in third quarter 2013 compared to one year ago.
Retail electric sales in billed gigawatt-hours by customer segment are summarized in Table 4. Current quarter sales reflected the following:
|
·
|
Residential sales in third quarter 2013, on a weather-adjusted basis, increased 0.1 percent compared to third quarter 2012.
|
|
·
|
Commercial and governmental sales, on a weather-adjusted basis, increased 0.4 percent quarter over quarter.
|
|
·
|
Industrial sales in the third quarter increased 2.7 percent compared to the same quarter of 2012.
|
Billed retail sales increased 1.1 percent on a weather-adjusted basis, driven largely by strong growth in the industrial segment. The industrial sales increase was due primarily to growth in the chemicals and refining segments. Residential and commercial weather-adjusted sales reflected continued sluggish regional economic growth and increasing emphasis on energy efficiency and demand-side management programs.
As noted above, a portion of the higher non-fuel operation and maintenance and depreciation expense increases were offset in net revenue. Also contributing to the O&M increase was higher compensation and benefits costs, primarily pension expenses.
Table 4 provides a comparative summary of Utility operational performance measures.
|
Table 4: Utility Operational Performance Measures
|
||||||||
|
Third Quarter and Year-to-Date 2013 vs. 2012 (see Appendix F for definitions of certain measures)
|
||||||||
|
Third Quarter
|
Year-to-Date
|
|||||||
|
2013
|
2012
|
% Change
|
% Weather Adjusted
|
2013
|
2012
|
% Change
|
% Weather Adjusted
|
|
|
GWh billed
|
||||||||
|
Residential
|
11,359
|
11,605
|
(2.1%)
|
0.1%
|
27,080
|
27,305
|
(0.8%)
|
(0.7%)
|
|
Commercial and governmental
|
9,041
|
9,101
|
(0.7%)
|
0.4%
|
23,312
|
23,846
|
(2.2%)
|
(0.5%)
|
|
Industrial
|
11,038
|
10,748
|
2.7%
|
2.7%
|
31,264
|
31,114
|
0.5%
|
0.5%
|
|
Total Retail Sales
|
31,438
|
31,454
|
(0.1%)
|
1.1%
|
81,656
|
82,265
|
(0.7%)
|
(0.2%)
|
|
Wholesale
|
667
|
833
|
(19.9%)
|
1,887
|
2,402
|
(21.4%)
|
||
|
Total Sales
|
32,105
|
32,287
|
(0.6%)
|
83,543
|
84,667
|
(1.3%)
|
||
|
Non-fuel O&M expense per MWh (a)
|
$18.15
|
$16.66
|
8.9%
|
$20.65
|
$18.73
|
10.3%
|
||
|
Number of electric retail customers
|
||||||||
|
Residential
|
2,397,877
|
2,379,080
|
0.8%
|
|||||
|
Commercial and governmental
|
359,232
|
356,014
|
0.9%
|
|||||
|
Industrial
|
48,709
|
47,209
|
3.2%
|
|||||
|
Total Retail Customers
|
2,805,818
|
2,782,303
|
0.8%
|
|||||
|
(a)
|
Third quarter and year-to-date 2012 and 2013 exclude the special item associated with the proposed spin-merge of the transmission business; third quarter and year-to-date 2013 exclude the special item for HCM implementation expenses.
|
Appendix C provides information on selected pending local and federal regulatory cases.
|
III.
|
Entergy Wholesale Commodities
|
EWC operational adjusted EBITDA was $165 million in third quarter 2013, compared to $185 million in the same period a year ago, as shown in Table 5.
|
Table 5: Entergy Wholesale Commodities Operational Adjusted EBITDA – Reconciliation of GAAP to Non-GAAP Measures
|
||||||
|
Third Quarter and Year-to-Date 2013 vs. 2012 (see Appendix F for definitions of certain measures)
|
||||||
|
($ in millions)
|
||||||
|
Third Quarter
|
Year-to-Date
|
|||||
|
2013
|
2012
|
Change
|
2013
|
2012
|
Change
|
|
|
Net income
|
(93)
|
87
|
(180)
|
1
|
(18)
|
19
|
|
Add back: interest expense
|
4
|
3
|
1
|
11
|
15
|
(4)
|
|
Add back: income tax expense
|
(107)
|
57
|
(164)
|
(65)
|
11
|
(76)
|
|
Add back: depreciation and amortization
|
55
|
29
|
26
|
155
|
129
|
26
|
|
Subtract: interest and investment income
|
21
|
20
|
1
|
72
|
78
|
(6)
|
|
Add back: decommissioning expense
|
32
|
29
|
3
|
92
|
42
|
50
|
|
Adjusted EBITDA
|
(130)
|
185
|
(315)
|
122
|
101
|
21
|
|
Add back: special item for HCM implementation expenses (pre-tax)
|
3
|
-
|
3
|
5
|
-
|
5
|
|
Add back: special item for VY asset impairments / related charges (pre-tax)
|
292
|
-
|
292
|
292
|
356
|
(64)
|
|
Operational adjusted EBITDA
|
165
|
185
|
(20)
|
419
|
457
|
(38)
|
The EWC operational adjusted EBITDA decrease was due largely to an increase in period-over-period non-fuel operation and maintenance expense, driven largely by higher compensation and benefits costs, primarily pension expenses. Contributions to operational adjusted EBTIDA from VY, scheduled to be closed at the end of its current operating cycle next year, were $1.1 million in third quarter 2013 and $19.6 million year-to-date 2013.
EWC reported an as-reported loss of $(0.52) per share and operational earnings of $0.46 per share for third quarter 2013, compared to third quarter 2012 earnings of $0.49 per share on both an as-reported and an operational basis. The decrease in operational earnings was partially attributable to the operational adjusted EBITDA drivers noted above. Also contributing was higher depreciation expense, mostly driven by a prior period item. An adjustment reducing depreciation expense was recorded in the third quarter of 2012 as a result of a favorable court decision on IP2 litigation against the DOE related to spent nuclear fuel disposal. The overall decrease was partially offset by a lower effective income tax rate on operational earnings.
Table 6 provides a comparative summary of EWC operational performance measures.
|
Table 6: Entergy Wholesale Commodities Operational Performance Measures
|
||||||
|
Third Quarter and Year-to-Date 2013 vs. 2012 (see Appendix F for definitions of certain measures)
|
||||||
|
Third Quarter
|
Year-to-Date
|
|||||
|
2013
|
2012
|
% Change
|
2013
|
2012
|
% Change
|
|
|
Owned capacity (MW)
|
6,612
|
6,612
|
-
|
6,612
|
6,612
|
-
|
|
GWh billed
|
11,630
|
12,002
|
(3.1%)
|
33,189
|
34,957
|
(5.1%)
|
|
Net revenue ($ millions)
|
494
|
495
|
(0.2%)
|
1,370
|
1,391
|
(1.5%)
|
|
Average realized revenue per MWh
|
$53.22
|
$51.88
|
2.6%
|
$52.95
|
$49.84
|
6.2%
|
|
Non-fuel O&M expense per MWh (b)
|
$25.28
|
$23.15
|
9.2%
|
$25.40
|
$23.70
|
7.2%
|
|
EWC Nuclear Fleet
|
||||||
|
Capacity factor
|
94%
|
90%
|
4.4%
|
86%
|
88%
|
(2.3%)
|
|
GWh billed
|
10,274
|
10,480
|
(2.0%)
|
29,309
|
30,744
|
(4.7%)
|
|
Average realized revenue per MWh
|
$53.16
|
$52.27
|
1.7%
|
$52.37
|
$50.42
|
3.9%
|
|
Production cost per MWh
|
$25.32
|
$26.14
|
(3.1%)
|
$26.73
|
$26.19
|
2.1%
|
|
Refueling outage days
|
||||||
|
FitzPatrick
|
-
|
15
|
-
|
15
|
||
|
IP2
|
-
|
-
|
-
|
28
|
||
|
IP3
|
-
|
-
|
28
|
-
|
||
|
Palisades
|
-
|
-
|
-
|
34
|
||
|
Pilgrim
|
-
|
-
|
45
|
-
|
||
|
VY
|
-
|
-
|
27
|
-
|
||
|
(b)
|
Third quarter and year-to-date 2013 exclude the special item for HCM implementation expenses; year-to-date 2012 and third quarter and year-to-date 2013 exclude the effect of the special item for VY asset impairments / related charges.
|
Table 7 provides information on current forward capacity and generation contracts for EWC’s fleet. It also provides total revenue projections using market prices as of Sept. 30, 2013 and adjusted for internal expectations for the new NYISO Lower Hudson Valley capacity zone starting in May 2014. 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 sensitivities are provided to show potential variations. Although the sensitivities reflect the minimum, they 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
|
||||||
|
Fourth Quarter 2013 through 2018 (see Appendix F for definitions of certain measures)
|
||||||
|
(based on market prices as of Sept. 30, 2013) (c)
|
||||||
|
Balance of 2013
|
2014
|
2015
|
2016
|
2017
|
2018
|
|
|
EWC Nuclear Portfolio
|
||||||
|
Energy
|
||||||
|
Planned TWh of generation
|
11
|
40
|
35
|
36
|
35
|
35
|
|
Percent of planned generation under contract
|
||||||
|
Unit-contingent
|
45%
|
21%
|
15%
|
16%
|
14%
|
14%
|
|
Unit-contingent with availability guarantees
|
13%
|
16%
|
14%
|
14%
|
15%
|
3%
|
|
Firm LD
|
24%
|
64%
|
23%
|
-
|
-
|
-
|
|
Offsetting positions
|
-
|
(20%)
|
-
|
-
|
-
|
-
|
|
Total
|
82%
|
81%
|
52%
|
30%
|
29%
|
17%
|
|
Average revenue per MWh on contracted volumes
|
||||||
|
Minimum
|
$43
|
$44
|
$44
|
$50
|
$51
|
$56
|
|
Expected based on current market prices
|
$44
|
$47
|
$48
|
$50
|
$52
|
$56
|
|
Sensitivity: -/+ $10 per MWh market price change
|
$43 - $46
|
$44 - $50
|
$44 - $53
|
$50 - $53
|
$51 - $54
|
$56
|
|
Capacity
|
||||||
|
Planned net MW in operation
|
5,011
|
5,011
|
4,406
|
4,406
|
4,406
|
4,406
|
|
Percent of capacity sold forward
|
||||||
|
Bundled capacity and energy contracts
|
16%
|
16%
|
18%
|
18%
|
18%
|
18%
|
|
Capacity contracts (d)
|
53%
|
19%
|
15%
|
15%
|
6%
|
-
|
|
Total
|
69%
|
35%
|
33%
|
33%
|
24%
|
18%
|
|
Average revenue under contract per kW per month
(applies to capacity contracts only)
|
$3.0
|
$2.4
|
$3.2
|
$3.4
|
$3.6
|
-
|
|
Total Nuclear Energy and Capacity Revenues (e)
|
||||||
|
Expected sold and market total revenue per MWh
|
$47
|
$51
|
$50
|
$50
|
$50
|
$51
|
|
Sensitivity: -/+ $10 per MWh market price change
|
$44 - $51
|
$47 - $55
|
$44 - $57
|
$43 - $57
|
$43 - $57
|
$44 - $59
|
|
EWC Non-Nuclear Portfolio
|
||||||
|
Energy
|
||||||
|
Planned TWh of generation
|
2
|
6
|
6
|
6
|
6
|
6
|
|
Percent of planned generation under contract
|
||||||
|
Cost-based contracts
|
33%
|
34%
|
35%
|
34%
|
32%
|
33%
|
|
Firm LD
|
5%
|
6%
|
7%
|
6%
|
6%
|
7%
|
|
Total (f)
|
38%
|
40%
|
42%
|
40%
|
38%
|
40%
|
|
Capacity
|
||||||
|
Planned net MW in operation
|
1,052
|
1,052
|
1,052
|
1,052
|
977
|
977
|
|
Percent of capacity sold forward
|
||||||
|
Cost-based contracts
|
24%
|
24%
|
24%
|
24%
|
26%
|
26%
|
|
Bundled capacity and energy contracts
|
8%
|
8%
|
8%
|
8%
|
8%
|
8%
|
|
Capacity contracts (g)
|
53%
|
53%
|
53%
|
53%
|
23%
|
0%
|
|
Total
|
85%
|
85%
|
85%
|
85%
|
57%
|
34%
|
|
Total Non-Nuclear Net Revenue
|
||||||
|
Expected portfolio net revenue in $ millions
|
$22
|
$94
|
$93
|
$105
|
$108
|
$106
|
|
(c)
|
Assumes shutdown of VY in fourth quarter 2014 and uninterrupted normal operation at the remaining nuclear plants. NRC license renewal applications are in process for both Indian Point units; at midnight on 9/28/13, IP2 entered the period of extended operations under its current license and the current license for IP3 expires 12/12/15.
|
|
(d)
|
The decrease in capacity contracts sold in 2016 and 2017 is due to the decision to close VY in 2014. VY has offset its ISO-NE FCA 7 commitments through a combination of third party bilateral purchases and prorated MWs from the Pilgrim and RISEC units; these offsets are subject to ISO approval, which is expected in May 2014.
|
|
(e)
|
Includes expectations for the new NYISO LHV capacity zone starting in May 2014.
|
|
(f)
|
A portion of the planned generation sold is subject to approval of transmission rights.
|
|
(g)
|
The increase in capacity contracts sold in 2016 and 2017 is due to prorated MWs from RISEC offsetting VY commitments in ISO-NE FCA 7.
|
|
IV.
|
Parent & Other
|
Parent & Other reported a loss of $(0.09) per share on an as-reported and an operational basis in the current quarter, compared to a third quarter 2012 as-reported and operational loss of $(0.26) per share. The period-over-period improvement was due to a decrease in income tax expense.
|
V.
|
2013 Earnings Guidance
|
Entergy affirmed its 2013 operational earnings guidance range of $4.60 to $5.40 per share, noting that current expectations point to around the middle of the range. The 2013 operational earnings guidance is detailed in Table 8. Year-over-year changes are shown as point estimates and are applied to 2012 operational earnings to compute the 2013 guidance midpoint. Drivers for the 2013 operational 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.
|
Table 8: 2013 Operational Earnings Per Share Guidance
|
|||||
|
(Per share in U.S. $) – Prepared November 2012 (h)
|
|||||
|
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
|
|
(h)
|
Originally prepared November 2012 and updated February 2013 to reflect 2012 final results.
|
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 IP3, Pilgrim and VY in Spring 2013 and Palisades in Fall 2013 (outage days vary depending on the scope of the outage); as of second quarter 2013, the Palisades Fall 2013 refueling outage has been rescheduled to early 2014
|
|
·
|
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 September 2013, average market energy price for 2013 unsold volumes was approximately $47.4/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 September 2013, average market capacity price for 2013 unsold volumes was approximately $4.0/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 VY 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 IP2 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
|
|
VI.
|
2014 Earnings Guidance
|
Entergy is initiating 2014 operational earnings guidance in the range of $4.60 to $5.40 per share. Operational guidance is based on Entergy’s current business operations, and does not reflect any impacts from the proposed spin-merge of the transmission business with ITC discussed in Appendix A. Year-over-year changes are shown as point estimates and are applied to the 2013 operational guidance midpoint to compute the 2014 guidance midpoint. While Entergy affirmed its 2013 operational earnings guidance range, the 2013 starting point by business segment was adjusted consistent with current indications. Drivers for the 2014 operational 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. Entergy’s 2014 operational earnings guidance is detailed in Table 9 below.
|
Table 9: 2014 Operational Earnings Per Share Guidance
|
|||||
|
(Per share in U.S. $) – Prepared October 2013
|
|||||
|
Segment
|
Description of Drivers
|
2013
Guidance
Midpoint (i)
|
Expected Change
|
2014
Guidance
Midpoint
|
2014 Guidance Range
|
|
Utility
|
Revised 2013 Operational EPS Guidance Midpoint
|
4.60
|
|||
|
Adjustment to normalize weather
|
0.11
|
||||
|
Increased net revenue due to retail sales growth and rate changes
|
0.35
|
||||
|
Other decreases in net revenue, including rate changes associated with offsets in other line items
|
(0.25)
|
||||
|
Decreased non-fuel operation and maintenance expense
|
0.35
|
||||
|
Increased depreciation expense
|
(0.15)
|
||||
|
Increased other income
|
0.15
|
||||
|
Lower effective income tax rate
|
0.05
|
||||
|
Other
|
(0.01)
|
||||
|
Subtotal
|
4.60
|
0.60
|
5.20
|
||
|
Entergy Wholesale Commodities
|
Revised 2013 Operational EPS Guidance Midpoint
|
1.25
|
|||
|
Increased net revenue due primarily to higher capacity pricing for nuclear assets
|
0.15
|
||||
|
Decreased non-fuel operation and maintenance expense
|
0.15
|
||||
|
Increased decommissioning expense
|
(0.05)
|
||||
|
Increased depreciation expense
|
(0.25)
|
||||
|
Gain on sale of District Energy business in 2013
|
(0.15)
|
||||
|
Higher effective income tax rate
|
(0.25)
|
||||
|
1.25
|
(0.40)
|
0.85
|
|||
|
Parent & Other
|
Revised 2013 Operational EPS Guidance Midpoint
|
(0.85)
|
|||
|
Higher Parent non-fuel operation and maintenance expense
|
(0.05)
|
||||
|
Higher income tax expense
|
(0.10)
|
||||
|
Other
|
(0.05)
|
||||
|
Subtotal
|
(0.85)
|
(0.20)
|
(1.05)
|
||
|
Consolidated Operational
|
2014 Operational EPS Guidance Range
|
5.00
|
–
|
5.00
|
4.60 – 5.40
|
|
(i)
|
Reflects adjustments to the segment midpoints, which net to zero on consolidated basis.
|
Key assumptions supporting 2014 operational earnings guidance are as follows:
Utility
|
·
|
Does not reflect the proposed spin-off and merger of the transmission business with ITC
|
|
·
|
Normal weather
|
|
·
|
Retail sales growth of around 1.9 percent on a weather-adjusted basis, driven largely by growth in the industrial segment; retail sales growth excluding the effect of industrial expansions is around 0.6 percent
|
|
·
|
Increased net revenue from rate changes, including EAI, EGSL, ELL and ETI rate case adjustments, net of lower net revenue for Grand Gulf recovery attributable to lower rate base
|
|
·
|
Other decreases in net revenue, approximately half due to rate changes with offsets in other line items and approximately half due to other items, including items recorded in 2013
|
|
·
|
Decreased non-fuel operation and maintenance expense due largely to HCM and lower compensation and benefits costs (largely post-employment benefits); also reflects increased expenses associated with joining MISO (largely offset in net revenue) as well as other general cost increases
|
|
·
|
Utility O&M savings from HCM assumed to be approximately $125 million (pre-tax) in 2014, exclusive of any cost to achieve the expected savings
|
|
·
|
Increased depreciation expense associated with capital spending at the Utility, partially offset by lower depreciation rates at EAI (offset in net revenue)
|
|
·
|
Increased other income due largely to higher allowance for equity funds used during construction including AFUDC from the Ninemile project and higher interest and investment income which reflects higher affiliate dividend income (offset at Parent & Other), assuming Hurricane Isaac financing is completed in early- to mid-2014
|
|
·
|
Lower effective income tax rate; effective income tax rate estimated at approximately 33 percent in 2014
|
Entergy Wholesale Commodities
|
·
|
46 TWh of output for the total fleet, reflecting an approximate 90 percent nuclear capacity factor compared to an estimated 89 percent nuclear capacity factor in 2013; 2014 includes approximately 30- to 45-day scheduled refueling outages at Palisades in early 2014, IP2 in Spring 2014 and FitzPatrick in Fall 2014 (outage days vary depending on the scope of the outage)
|
|
·
|
Assumes full year operations for all nuclear plants, including VY which is assumed to begin ramping down power production in fourth quarter 2014 for final shutdown by year end
|
|
·
|
$51/MWh average price for EWC-nuclear fleet’s total energy and capacity revenues, using published market prices at the end of September 2013 and adjusting capacity prices for expectations for the new LHV capacity zone expected to be in place starting with the April 2014 summer strip auction
|
|
o
|
$47/MWh average revenue per MWh on contracted energy volumes, representing 81 percent of planned generation
|
|
o
|
$39/MWh average market price on 19 percent unsold energy volumes
|
|
o
|
$2.4/kW-month average capacity revenue under contract on 19 percent capacity (excludes bundled capacity contracts, which are priced within the contracted energy volumes above)
|
|
o
|
$5.2/kW-month average capacity price on 65 percent unsold capacity; assumes uplift associated with the LHV capacity zone of approximately $3/kW-month on an annualized basis
|
|
·
|
Nuclear fuel expense around $6.6/MWh for 2014 compared to approximately $6.5/MWh for 2013 (average nuclear fuel expense in both years affected by VY impairments)
|
|
·
|
Decreased purchased power expense reflected in net revenue
|
|
·
|
Non-fuel operation and maintenance expense, including nuclear refueling outage expenses, around
|
|
|
$24.3/MWh reflecting lower expense resulting from HCM and lower compensation and benefits costs (largely post-employment benefits) and lower expense resulting from the planned sale of the District Energy business in fourth quarter 2013; decreases were partially offset by higher refueling outage amortization as well as other general cost increases
|
|
·
|
Excludes VY spending that would have been capital except for the shutdown decision, which will be reported as part of the Asset impairment and related charges line item, and any VY severance and retention expenses; these items will be reflected as special items
|
|
·
|
EWC O&M savings from HCM assumed to be approximately $55 million (pre-tax) in 2014, exclusive of any cost to achieve the expected savings
|
|
·
|
Increased decommissioning expense, reflecting accretion of asset retirement obligation largely at VY
|
|
·
|
Increased depreciation expense due to higher depreciation expense for VY resulting from the shutdown decision in third quarter 2013 and higher depreciable plant balances; also reflects an estimated effect of revised depreciation rates based on a new depreciation rate study
|
|
·
|
Higher effective income tax rate
|
|
·
|
VY contribution to operational adjusted EBITDA approximately $50 million in 2014 compared to approximately $25 million in 2013
|
Parent & Other
|
·
|
Increased Parent non-fuel operation and maintenance expense due partly to the elimination of intercompany expense (offset at other business segments)
|
|
·
|
Higher income tax expense
|
Other
|
·
|
2014 average fully diluted shares outstanding of approximately 178 million
|
|
·
|
Overall effective income tax rate of 36 percent in 2014
|
|
·
|
HCM savings in 2014 projected to total approximately $200 million, including non-fuel operation and maintenance expense and capital; HCM savings estimate is exclusive of any cost to achieve the expected savings
|
|
·
|
Pension discount rate of 4.75 percent in 2014, compared to a final average pension discount rate of 4.36 percent in 2013
|
Operational earnings guidance for 2014 should be considered in association with earnings sensitivities as shown in Table 10. 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 operational earnings guidance range for 2014 takes into consideration a number of regulatory initiatives underway across the Utility jurisdictions and potential variations in the pension discount rate to be measured at Dec. 31, 2013.
Estimated annual impacts shown in Table 10 are intended to be indicative rather than precise guidance.
|
Table 10: 2014 Earnings Sensitivities
|
|||
|
(Per share in U.S. $) – Prepared October 2013
|
|||
|
Variable
|
2014 Guidance Assumption
|
Description of Change
|
Estimated
Annual Impact
|
|
Utility
|
|||
|
Retail sales growth
Residential
Commercial / Governmental
Industrial
|
Around 1.9% retail sales growth on a weather adjusted basis, 0.6% excluding industrial expansions
|
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
|
- / + 0.44
|
|
Non-fuel operation and maintenance expense
|
Lower due to HCM and compensation and benefits costs, partially offset by other increases
|
1% change in expense
|
+ / - 0.08
|
|
Entergy Wholesale Commodities (j)
|
|||
|
Nuclear capacity factor
|
90% capacity factor
|
1% change in capacity factor
|
- / + 0.06
|
|
EWC revenue (energy)
|
$51/MWh nuclear revenue;
Non-nuclear net revenue
|
$10/MWh market price change
|
- 0.49 / + 0.60
|
|
EWC revenue (capacity)
|
$5.2/kW-month average capacity price on 65% unsold nuclear capacity (including VY)
|
$0.50/kW-month change in capacity price on nuclear capacity
|
- / + 0.06
|
|
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)
|
90% capacity factor, including refueling outages for three EWC nuclear units
|
1,000 MW plant for 10 days at average portfolio energy price of $47/MWh for contracted volumes and $39/MWh for unsold volumes in 2014 (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) (k)
|
Discount rate of 4.75%
|
0.25% change
|
- / + 0.07
|
|
Effective income tax rate
|
36% effective income tax rate
|
1% change in overall effective income tax rate
|
+ / - 0.08
|
|
(j)
|
Assumes shutdown of VY in fourth quarter 2014 and uninterrupted normal operation at the remaining nuclear plants.
|
|
(k)
|
Based on 2013 rules of thumb for pension and other post-retirement employee benefit costs.
|
|
VII.
|
Appendices
|
Seven appendices are presented in this section as follows:
|
·
|
Appendix A includes information on the status of 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 and year-to-date 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 preliminary planned capital expenditures for 2014 through 2016.
|
|
·
|
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 subject to the satisfaction of certain closing conditions including retail regulatory approvals, which remain pending. A revised closing date in 2014 has not yet been settled upon. The definitive agreement provides that it may be terminated by either party if the transaction has not been consummated by Dec. 31, 2013.
Appendix A provides a summary of certain pending activities and events.
|
Appendix A: Regulatory Summary Table for Spin-Merge of Transmission Business (l)
(see Appendix F for definitions of certain abbreviations or acronyms)
|
|
|
Proceeding
|
Pending Activities / Events
|
|
Retail Regulators
|
Recent Activity: On Aug. 9, 2013, ETI and ITC withdrew their joint change of control application pending before the PUCT. As a result, the APSC, LPSC and CCNO issued orders suspending their respective proceedings. On Sept. 23, 2013, ETI and ITC filed an updated application with the PUCT. After providing notice of the filing of the updated application in Texas, a revised LPSC procedural schedule was set.
Next Steps: Post-hearing briefing in the LPSC proceeding concludes on Nov. 8, 2013. A hearing will be held before the Commissioners of the PUCT beginning Nov. 21, 2013. The APSC and CCNO proceedings remain suspended awaiting revised procedural schedules. Decisions from the MPSC and Missouri PSC are pending.
|
|
Federal Energy Regulatory Commission
|
Sections 203, 205 and 305(a) Filings Recent Activity: On June 20, 2013, FERC issued an order approving the Utility operating companies’ and ITC’s Sept. 24, 2012 joint application related to the proposed transaction, subject to the outcome of a hearing or settlement judge procedures on certain rate issues and transaction-related agreements. The hearing is held in abeyance for settlement procedures. Settlement conferences are under way.
Next Steps: The parties will continue discussions toward reaching settlement of the rate and agreement on pending unresolved issues. The transaction can close, subject to refund, with these issues pending.
|
|
Section 204 Filings Recent Activity: On May 16, 2013, FERC approved Entergy’s applications seeking authorization related to certain debt financings necessary to effectuate the ITC transaction and ITC’s application seeking authorizations related to certain post-closing financings. The FERC authorization granted to Entergy expires on Oct. 31, 2013. Entergy is in the process of preparing new applications to be filed by the end of 2013.
|
|
|
Internal Revenue Service
|
Recent Activity: On May 31, 2013, the IRS issued a private letter ruling that certain requirements for the tax-free treatment of the distribution of TransCo have been met.
|
|
Nuclear Regulatory Commission
|
Recent Activity: On May 3, 2013, the NRC approved the license transfer requests and amendments as part of the steps to complete the transaction. The NRC approval expires on May 3, 2014, and the companies expect to be able to be able to obtain an extension if necessary.
|
|
Securities and Exchange Commission
|
Recent Activity: Entergy filed the Mid South TransCo registration statement on July 24, 2013. The registration statement reflects Entergy’s intent to pursue a combination partial split-off and spin-off prior to the merger of the transmission business with ITC. In a split-off, Entergy shareholders will be offered the opportunity to exchange their Entergy common stock for TransCo common units at a to-be-determined exchange ratio (as described in the registration statement), subject to an upper limit on the exchange ratio. The terms of the exchange offer (including the number of TransCo units to be offered in the exchange offer, the discount to ITC’s stock price and the upper limit) will be determined immediately prior to the launch of the exchange offer and announced pursuant to a press release. Entergy also retains the option to contribute up to 4.999 percent of ITC shares at closing of the transmission business merger into an exchange trust to offer to exchange for Entergy common stock up to six months after close.
Next Steps: Mid South TransCo will respond to SEC comments on the registration statement.
|
|
Hart-Scott-Rodino Notification
|
Recent Activity: The ability to close the transaction based on the Dec. 14, 2012 premerger notification filings under the HSR Act expires on Jan. 14, 2014. Entergy and ITC are in the process of preparing new notifications targeted to be filed by the end of 2013.
|
|
(l)
|
It is a condition to the closing of the proposed spin-merge transaction that all state and federal regulatory approvals required to join an acceptable RTO shall have been obtained. See Appendix C for the status of regulatory approvals required to join MISO.
|
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 is also expected to file a post-effective amendment to the above registration statement. ITC shareholders are urged to read the prospectus included in the ITC registration statement (and the post-effective amendment to the ITC registration statement, when available) and any other relevant documents because they contain important information about TransCo and the proposed transactions. In addition, on July 24, 2013, TransCo filed a registration statement on Form S-4/S-1 (Registration No. 333-190094) with the SEC registering the offer and sale of TransCo common units to be issued to Entergy shareholders in connection with the proposed transactions. This registration statement includes a prospectus of TransCo related to the proposed transactions. Entergy will file a tender offer statement on Schedule TO with the SEC related to the exchange of shares of Entergy common stock for the TransCo common units. Entergy shareholders are urged to read the prospectuses included in the ITC registration statement (and the post-effective amendment to the ITC registration statement, when available), the TransCo registration statement, the tender offer statement on Schedule TO (when available) and any other relevant documents because they contain important information about ITC, TransCo and the proposed transactions. The registration statements, prospectuses, tender offer statement 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 and Appendix B-2 provide details of third quarter and year-to-date 2013 versus 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
|
|||||||||||
|
Third 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
|
1.66
|
1.72
|
0.49
|
0.49
|
(0.26)
|
(0.26)
|
1.89
|
1.95
|
|||
|
Income taxes - other
|
0.17
|
0.17
|
(m)
|
0.14
|
0.14
|
(n)
|
0.15
|
0.15
|
(o)
|
0.46
|
0.46
|
|
Net revenue
|
0.41
|
0.41
|
(p)
|
-
|
-
|
0.01
|
0.01
|
0.42
|
0.42
|
||
|
Preferred dividend requirements
|
-
|
-
|
-
|
-
|
0.01
|
0.01
|
0.01
|
0.01
|
|||
|
Other income (deductions) - other
|
(0.01)
|
(0.01)
|
0.01
|
0.01
|
-
|
-
|
-
|
-
|
|||
|
Asset impairment / related charges
|
-
|
-
|
(0.97)
|
-
|
(q)
|
-
|
-
|
(0.97)
|
-
|
||
|
Nuclear refueling outage expense
|
(0.01)
|
(0.01)
|
-
|
-
|
-
|
-
|
(0.01)
|
(0.01)
|
|||
|
Interest expense and other charges
|
(0.02)
|
(0.02)
|
-
|
-
|
0.01
|
0.01
|
(0.01)
|
(0.01)
|
|||
|
Decommissioning expense
|
-
|
-
|
(0.01)
|
(0.01)
|
-
|
-
|
(0.01)
|
(0.01)
|
|||
|
Taxes other than income taxes
|
(0.01)
|
(0.01)
|
(0.02)
|
(0.02)
|
-
|
-
|
(0.03)
|
(0.03)
|
|||
|
Depreciation / amortization expense
|
(0.06)
|
(0.06)
|
(r)
|
(0.09)
|
(0.09)
|
(s)
|
-
|
-
|
(0.15)
|
(0.15)
|
|
|
Other operation & maintenance expense
|
(0.18)
|
(0.15)
|
(t)
|
(0.07)
|
(0.06)
|
(u)
|
(0.01)
|
(0.01)
|
(0.26)
|
(0.22)
|
|
|
2013 earnings
|
1.95
|
2.04
|
(0.52)
|
0.46
|
(0.09)
|
(0.09)
|
1.34
|
2.41
|
|||
|
|
|
Appendix B-2: As-Reported and Operational Earnings Per Share Variance Analysis
|
|||||||||||
|
Year-to-Date 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
|
3.73
|
3.88
|
(0.10)
|
1.16
|
(0.53)
|
(0.53)
|
3.10
|
4.51
|
|||
|
Net revenue
|
1.58
|
1.58
|
(p)
|
(0.07)
|
(0.07)
|
(v)
|
0.02
|
0.02
|
1.53
|
1.53
|
|
|
Preferred dividend requirements
|
-
|
-
|
-
|
-
|
0.01
|
0.01
|
0.01
|
0.01
|
|||
|
Asset impairment / related charges
|
-
|
-
|
0.29
|
-
|
(q)
|
-
|
-
|
0.29
|
-
|
||
|
Nuclear refueling outage expense
|
(0.04)
|
(0.04)
|
0.01
|
0.01
|
-
|
-
|
(0.03)
|
(0.03)
|
|||
|
Other income (deductions) - other
|
(0.04)
|
(0.04)
|
(0.01)
|
(0.01)
|
0.01
|
0.01
|
(0.04)
|
(0.04)
|
|||
|
Interest expense and other charges
|
(0.07)
|
(0.07)
|
(w)
|
0.01
|
0.01
|
(0.02)
|
(0.02)
|
(0.08)
|
(0.08)
|
||
|
Taxes other than income taxes
|
(0.07)
|
(0.07)
|
(x)
|
(0.02)
|
(0.02)
|
-
|
-
|
(0.09)
|
(0.09)
|
||
|
Decommissioning expense
|
(0.01)
|
(0.01)
|
(0.17)
|
(0.17)
|
(y)
|
-
|
-
|
(0.18)
|
(0.18)
|
||
|
Depreciation / amortization expense
|
(0.21)
|
(0.21)
|
(r)
|
(0.09)
|
(0.09)
|
(s)
|
-
|
-
|
(0.30)
|
(0.30)
|
|
|
Income taxes – other
|
(0.62)
|
(0.62)
|
(m)
|
0.23
|
0.23
|
(n)
|
(0.03)
|
(0.03)
|
(0.42)
|
(0.42)
|
|
|
Other operation & maintenance expense
|
(0.51)
|
(0.45)
|
(t)
|
(0.08)
|
(0.06)
|
(u)
|
(0.04)
|
(0.04)
|
(0.63)
|
(0.55)
|
|
|
2013 earnings
|
3.74
|
3.95
|
-
|
0.99
|
(0.58)
|
(0.58)
|
3.16
|
4.36
|
|||
|
(m)
|
The increase in the current quarter was due largely to favorable interest settlements on the filing of state income tax adjustments in third quarter 2013 totaling approximately $27 million. The year-to-date decrease was due primarily to items recorded in the prior year. Second quarter 2012 included a decrease in income tax expense resulting from an agreement reached with the IRS associated with certain storm cost financings in Louisiana. The decrease was partially offset by the first quarter 2012 write off of an EGSL regulatory asset for income taxes. The tax item recorded in the current quarter also provided a partial offset to the year-to-date decrease.
|
|
(n)
|
The current quarter and year-to-date increases reflected resolution of a tax basis issue in third quarter 2013, which resulted in the reversal of an income tax reserve on that issue for approximately $22 million. The year-to-date increase also included a state income tax benefit of approximately $17 million recorded in second quarter 2013.
|
|
(o)
|
The increase in the current quarter was due primarily to the reversal of a state valuation allowance of approximately $28 million.
|
|
Utility Net Revenue Variance Analysis
2013 vs. 2012 ($ EPS)
|
||
|
Third Quarter
|
Year-to-Date
|
|
|
Weather
|
(0.07)
|
(0.10)
|
|
Sales growth / pricing
|
0.34
|
0.94
|
|
Regulatory agreement
|
-
|
0.57
|
|
Other
|
0.14
|
0.17
|
|
Total
|
0.41
|
1.58
|
|
(p)
|
The current quarter and year-to-date increases reflected the net effect of pricing adjustments from regulatory actions, primarily from placing the Waterford 3 steam generator replacement and the Hinds and Hot Spring power plant acquisitions in service around the end of 2012. The volume variances in net revenue reflected weather-adjusted sales growth and an increase in the unbilled sales period, both in third quarter 2013, and less favorable weather. The EAI energy efficiency rider and the effect of prior year charges associated with the September 2012 ETI rate order contributed to the current quarter and year-to-date increases. The current quarter increase also reflected lower regulatory charges from a decrease in earnings on nuclear decommissioning trusts. The year-to-date increase also included the Grand Gulf extended power uprate completed around midyear last year and the effect of the second quarter 2012 regulatory charge for sharing of tax benefits from an IRS agreement discussed in (m). A portion of these items in the current quarter and year-to-date periods were for recovery of costs below the net revenue line.
|
|
(q)
|
The as-reported decrease in the current quarter reflected Entergy’s decision to shut down VY at the end of its current operating cycle in 2014. This decision resulted in a non-cash impairment of the carrying values of VY and related assets to their fair value, in accordance with GAAP, and other related charges including the effect of capital spending now chargeable to expense because of the plant’s shortened life. In first quarter 2012, an impairment charge was also recorded for VY. The year-to-date increase reflected the net effect of the two charges.
|
|
(r)
|
The decrease in the current quarter and year-to-date was due to additions to plant in service, including the Waterford 3 steam generator replacement and the Hinds and Hot Spring power plant acquisitions. The Grand Gulf extended power uprate and higher depreciation rates at ETI resulting from the 2012 rate case order also contributed to decreases in the year-to-date period.
|
|
(s)
|
The current quarter and year-to-date decreases were due primarily to an item recorded in the prior year. In the third quarter 2012, an approximate $19 million pre-tax reduction in depreciation expense was recorded as a result of an award for a claim by IP2 against the DOE for spent nuclear fuel storage costs.
|
|
(t)
|
The decreases in the current quarter and year-to-date periods were due to several factors. Higher compensation and benefits costs were a primary factor, driven by post-employment benefits and a charge recorded in third quarter 2013 related to lump sum benefits out of the non-qualified pension plan. In addition, higher fossil plant spending due primarily to the Hinds and Hot Spring power plant acquisitions and energy efficiency spending at EAI, which are offset in net revenue as discussed in (p), contributed to the decreases. The year-to-date decrease also included higher nuclear spending, including costs related to the generator stator accident at ANO. The as-reported decreases also included HCM implementation expenses.
|
|
(u)
|
The current quarter and year-to-date decreases were due largely to higher compensation and benefits costs driven by post-employment benefits and a charge recorded in third quarter 2013 related to lump sum benefits out of the non-qualified pension plan. The as-reported decreases also included HCM implementation expenses.
|
|
(v)
|
The year-to-date decrease reflected a decline in nuclear generation due to an increase in refueling and unplanned outage days. The decrease was partially offset by higher capacity pricing.
|
|
(w)
|
The year-to-date decrease was due primarily to higher debt balances as well as lower allowance for funds used during construction due to completion of several major projects in mid- to late-2012.
|
|
(x)
|
The year-to-date decrease was due primarily to increase in ad valorem taxes resulting from 2013 higher assessments as well as an increase in local franchise taxes resulting from higher residential and commercial revenues compared to the prior year.
|
|
(y)
|
The year-to-date decrease was largely attributable to reductions in the asset retirement obligation recorded in second quarter 2012, which factored in, among other things, an updated decommissioning cost study for Pilgrim.
|
Appendix B-3 lists special items by business with quarter-to-quarter and year-to-year 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. 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-3: Special Items (shown as positive / (negative) impact on earnings)
|
||||||
|
Third Quarter and Year-to-Date 2013 vs. 2012
|
||||||
|
(Per share in U.S. $)
|
||||||
|
Third Quarter
|
Year-to-Date
|
|||||
|
2013
|
2012
|
Change
|
2013
|
2012
|
Change
|
|
|
Utility
|
||||||
|
Transmission business spin-merge expenses
|
(0.06)
|
(0.06)
|
-
|
(0.16)
|
(0.15)
|
(0.01)
|
|
HCM implementation expenses
|
(0.03)
|
-
|
(0.03)
|
(0.05)
|
-
|
(0.05)
|
|
Total Utility
|
(0.09)
|
(0.06)
|
(0.03)
|
(0.21)
|
(0.15)
|
(0.06)
|
|
Entergy Wholesale Commodities
|
||||||
|
VY asset impairments / related charges
|
(0.97)
|
-
|
(0.97)
|
(0.97)
|
(1.26)
|
0.29
|
|
HCM implementation expenses
|
(0.01)
|
-
|
(0.01)
|
(0.02)
|
-
|
(0.02)
|
|
Total Entergy Wholesale Commodities
|
(0.98)
|
-
|
(0.98)
|
(0.99)
|
(1.26)
|
0.27
|
|
Parent & Other
|
||||||
|
Transmission business spin-merge expenses
|
-
|
-
|
-
|
-
|
-
|
-
|
|
Total Special Items
|
(1.07)
|
(0.06)
|
(1.01)
|
(1.20)
|
(1.41)
|
0.21
|
|
(U.S. $ in millions)
|
||||||
|
Third Quarter
|
Year-to-Date
|
|||||
|
2013
|
2012
|
Change
|
2013
|
2012
|
Change
|
|
|
Utility
|
||||||
|
Transmission business spin-merge expenses
|
(10.1)
|
(10.7)
|
0.6
|
(28.6)
|
(26.4)
|
(2.2)
|
|
HCM implementation expenses
|
(5.2)
|
-
|
(5.2)
|
(7.9)
|
-
|
(7.9)
|
|
Total Utility
|
(15.3)
|
(10.7)
|
(4.6)
|
(36.5)
|
(26.4)
|
(10.1)
|
|
Entergy Wholesale Commodities
|
||||||
|
VY asset impairments / related charges
|
(173.1)
|
-
|
(173.1)
|
(173.1)
|
(223.5)
|
50.4
|
|
HCM implementation expenses
|
(2.1)
|
-
|
(2.1)
|
(3.2)
|
-
|
(3.2)
|
|
Total Entergy Wholesale Commodities
|
(175.2)
|
-
|
(175.2)
|
(176.3)
|
(223.5)
|
47.2
|
|
Parent & Other
|
||||||
|
Transmission business spin-merge expenses
|
-
|
-
|
-
|
-
|
(1.0)
|
1.0
|
|
Total Special Items
|
(190.5)
|
(10.7)
|
(179.8)
|
(212.8)
|
(250.9)
|
38.1
|
|
C.
|
Regulatory Summary
|
Appendix C provides a summary of selected regulatory cases and events that are pending.
|
Appendix C: Regulatory Summary (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 / Next Steps: In revised surrebuttal testimony filed Oct. 21, 2013 and errata filed Sept. 23, 2013, the APSC Staff recommended a revenue deficiency of $110 million on rate base of $4.797 billion and an ROE of 9.6 percent. Staff supports the MISO rider and the capacity cost recovery rider proposed by EAI. On Sept. 23, 2013, EAI filed sur-surrebuttal testimony reflecting an updated rate increase request of $145 million on rate base of $4.84 billion based on 12 months of actuals, with no change to its requested ROE of 10.4 percent. Hearings began in October 2013. An APSC decision is expected by year end. New rates are expected to become effective January 2014.
Rate Case Background: 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. EAI also proposed a capacity cost recovery rider and a rider to recover costs associated with MISO and ITC (if the ITC transaction is completed).
|
|
Entergy Gulf States Louisiana
Authorized ROE Range:
9.9% - 11.4% (electric)
9.45% - 10.45% (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 / Next Steps: Discovery is in progress. Staff and intervenor testimony is due Dec. 6, 2013. EGSL will work with the parties to come up with proposed new dates for the remainder of the procedural schedule. New rates are expected to become effective in May 2014.
Rate Case Background: On Feb. 15, 2013, EGSL filed an electric 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.
|
|
Entergy Louisiana
Authorized ROE Range:
9.45% - 11.05%
Last Filed Rate Base: see next column
|
LPSC Rate Case Recent Activity / Next Steps: Staff and intervenor direct testimony is due Nov. 15, 2013 and hearings are scheduled in January 2014. New rates are expected to become effective in May 2014.
LPSC Rate Case Background: 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.
Other Recent Activity: Discovery is in progress in ELL’s rate case for its Algiers territory, 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. Advisors’ direct testimony is due Nov. 29, 2013. Hearings are scheduled for April 2014. New rates are expected to become effective in second quarter 2014.
|
|
Entergy Mississippi
Authorized ROE Range:
9.76% - 11.83%
(per 4/13 revised FRP filing)
Last Filed Rate Base: $1.7 billion filed 4/13 based on 12/31/12 test yr
|
Recent Activity: On Aug. 13, 2013, the MPSC approved a stipulation resolving EMI’s 2012 test year FRP. Without agreeing to any specific disallowances, the stipulation provides for a rate increase of approximately $22.3 million, which brings EMI up to the equity “point of adjustment” of 10.59 percent from an 8.96 percent earned ROE for 2012. The annualized change was effective with September 2013 bills.
Background: EMI’s FRP includes an annual redetermination of the benchmark ROE based on a formula tied to interest rates and equity risk premiums, with an adjustment 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.
On April 30, 2013, EMI filed its revised evaluation report for the 2012 test year. The revised filing reflected a 7.91 percent earned ROE, which was below the bandwidth of 9.76 to 11.83 percent. The calculated 10.8 percent FRP midpoint ROE included the benefit of a 0.74 percent performance incentive.
|
|
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
|
Recent Activity: On Aug. 8, 2013, the CCNO approved a “black box” settlement resolving the remaining open items in ENOI’s 2011 test year FRP. The settlement provides for a $(6.5) million electric rate decrease. When combined with the $4.9 million electric rate increase previously implemented in October 2012, the settlement results in a net $(1.6) million decrease from pre-October 2012 rates. There was no change in gas rates. ENOI likely will make a base rate case filing in mid-2014. However, ENOI is in discussions with the CCNO and its Advisors regarding various ratemaking alternatives to a full base rate case.
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.
|
|
Appendix C: Regulatory Summary (see Appendix F for definitions of certain abbreviations or acronyms) (continued)
|
|
|
Company
|
Pending Cases / Events
|
|
Retail Regulation
|
|
|
Entergy Texas
Authorized ROE: 9.8%
Last Filed Rate Base: $1.6 billion filed 9/13 based on 3/31/13 adjusted test yr
|
Recent Activity: On Sept. 25, 2013, ETI filed a rate case requesting a $38.6 million base rate increase and a 10.4 percent ROE based on a test year period ending March 31, 2013. With additional riders for rate case expenses, reserve equalization payments and transmission cost recovery rider, the increase would be $44 million initially. Special circumstances recovery as fuel of approximately $22 million of historical purchased power capacity costs was reflected in the fuel reconciliation. A procedural schedule has been set that includes Staff testimony due Dec. 16, 2013 and hearings in January 2014. The jurisdictional deadline for a PUCT decision is March 31, 2014.
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.
|
|
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: $1.5 billion for Sept. 30, 2013 monthly cost of service.
|
|
Transmission, Proposal to Join MISO and System Agreement
Authorized ROE:
11.0% (z)
Last Filed OATT Rate Base:
$2.5 billion (aa) filed 5/13 based on 12/31/12 test year
|
Proposal to Join MISO Recent Activity: On Oct. 9, 2013, the Missouri PSC issued an order approving EAI’s request to join MISO, subject to various conditions. EAI intends to request rehearing of the order. On Oct. 15, 2013, EAI filed an OATT at FERC under which EAI will continue to provide transmission service over its limited Missouri transmission facilities, rather than transferring operational control of those facilities to MISO. Comments and protests on the FERC application are due Nov. 5, 2013. The Utility operating companies continue to target joining MISO in December 2013.
Background: Between June 2012 and April 2013, the LPSC, PUCT, APSC, CCNO and MPSC each issued orders approving, subject to certain conditions, the Utility operating companies’ requests for MISO membership.
|
|
System Agreement Recent Activity: On Aug. 28, 2013, the presiding judge issued his initial decision in the FERC proceeding regarding calculations for re-pricing wholesale opportunity sales of energy by EAI to third parties for the period 2000 through 2009. The initial decision concluded that the methodology proposed by the LPSC rather than the methodologies proposed by Entergy or FERC Staff, should be used to calculate payments EAI is to make to the other Utility operating companies. Recognizing that the LPSC methodology would result in an inequitable windfall to the other Utility operating companies, the initial decision concludes that any payment by EAI should be reduced by 20 percent. The initial decision and record in the case have been submitted to FERC and various parties, including Entergy, have filed briefs on exceptions. 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 and Entergy submits a subsequent filing to comply with that decision.
On Oct. 11, 2013, Entergy filed an amendment to the Entergy System Agreement to modify the notice period for a Utility operating company to terminate its participation in the System Agreement to 60 months from 96 months with a proposed effective date of Oct. 12, 2013. Comments or protests on the amendment filing are due Nov. 12, 2013 and FERC is expected to act in January 2014. On Oct. 18, 2013, ETI filed its notice to terminate its participation in the Entergy System Agreement following the 60-month notice period or such other notice period as approved by FERC.
On Oct. 16, 2013, FERC issued orders in various bandwidth-related proceedings. In the 2007 bandwidth filing, FERC specified its own method for calculating the functionalization ratio to apply to the net operating loss accumulated deferred income taxes for bandwidth purposes and denied Entergy’s request for rehearing of FERC’s prior ruling requiring interest be included on comprehensive recalculated payment and receipt true-up amounts. FERC rejected Entergy’s argument that the ordering of interest was contrary to Commission precedent and determined that due to the length of time that had passed, it was appropriate to allow interest to be paid. Entergy is required to make an additional compliance filing by Nov. 15, 2013.
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 determine the cost of 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. 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. In April 2013, the Utility operating companies filed rebuttal testimony, including a revised illustrative rerun of the intra-system bills for the three years. The revised calculation resulted in an increase in the potential cost for EAI over those three years of $2.3 million compared to prior submissions.
In 2005, FERC issued orders that require each Utility operating company’s production costs to be within +/- 11 percent of System average production costs and set 2007 as the first possible year of payments among the Utility operating companies, based on calendar year 2006 actual production costs. A subsequent FERC order concluded that the prospective bandwidth remedy should begin on June 1, 2005 (the date of its initial order in the proceeding). Annual bandwidth filings have been made for each year starting with 2007 through 2013, as well as a compliance filing associated with calculations for the period of June through December 2005.
|
|
|
(z)
|
Applies to sales made under Entergy’s FERC OATT.
|
|
(aa)
|
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
|
||||
|
Third Quarter 2013 vs. 2012 (see Appendix F for definitions of certain measures)
|
||||
|
For 12 months ending Sept. 30
|
2013
|
2012
|
Change
|
|
|
GAAP Measures
|
||||
|
Return on average invested capital – as-reported
|
5.5%
|
4.8%
|
0.7%
|
|
|
Return on average common equity – as-reported
|
9.3%
|
7.8%
|
1.5%
|
|
|
Cash flow interest coverage
|
5.9
|
6.8
|
(0.9)
|
|
|
Book value per share
|
$52.77
|
$51.73
|
$1.04
|
|
|
End of period shares outstanding (millions)
|
178.3
|
177.7
|
0.6
|
|
|
Non-GAAP Measures
|
||||
|
Return on average invested capital – operational
|
6.4%
|
6.0%
|
0.4%
|
|
|
Return on average common equity – operational
|
11.7%
|
10.7%
|
1.0%
|
|
|
As of Sept. 30 ($ in millions)
|
2013
|
2012
|
Change
|
|
|
GAAP Measures
|
||||
|
Cash and cash equivalents
|
365
|
750
|
(385)
|
|
|
Revolver capacity
|
4,129
|
2,917
|
1,212
|
|
|
Commercial paper outstanding
|
1,015
|
-
|
1,015
|
|
|
Total debt
|
13,623
|
12,931
|
692
|
|
|
Securitization debt
|
910
|
1,003
|
(93)
|
|
|
Debt to capital ratio
|
58.4%
|
57.7%
|
0.7%
|
|
|
Off-balance sheet liabilities:
|
||||
|
Debt of joint ventures – Entergy’s share
|
87
|
91
|
(4)
|
|
|
Leases – Entergy’s share
|
505
|
508
|
(3)
|
|
|
Total off-balance sheet liabilities
|
592
|
599
|
(7)
|
|
|
Non-GAAP Measures
|
||||
|
Debt to capital ratio, excluding securitization debt
|
56.7%
|
55.7%
|
1.0%
|
|
|
Gross liquidity
|
4,494
|
3,667
|
827
|
|
|
Net debt to net capital ratio, excluding securitization debt
|
56.0%
|
54.1%
|
1.9%
|
|
|
Net debt to net capital ratio including off-balance sheet liabilities, excluding securitization debt
|
57.2%
|
55.4%
|
1.8%
|
|
|
Appendix D-2: Historical Performance Measures (see Appendix F for definitions of certain measures)
|
|||||||||||||||||||||
|
4Q11
|
1Q12
|
2Q12
|
3Q12
|
4Q12
|
1Q13
|
2Q13
|
3Q13
|
13YTD
|
12YTD
|
||||||||||||
|
Financial
|
|||||||||||||||||||||
|
EPS – as-reported ($)
|
0.87
|
(0.86)
|
2.06
|
1.89
|
1.66
|
0.90
|
0.92
|
1.34
|
3.16
|
3.10
|
|||||||||||
|
Less – special items ($)
|
(0.07)
|
(1.30)
|
(0.05)
|
(0.06)
|
(0.06)
|
(0.04)
|
(0.09)
|
(1.07)
|
(1.20)
|
(1.41)
|
|||||||||||
|
EPS – operational ($)
|
0.94
|
0.44
|
2.11
|
1.95
|
1.72
|
0.94
|
1.01
|
2.41
|
4.36
|
4.51
|
|||||||||||
|
Trailing twelve months
|
|||||||||||||||||||||
|
ROIC – as-reported (%)
|
8.0
|
6.0
|
6.2
|
4.8
|
5.5
|
6.9
|
5.9
|
5.5
|
|||||||||||||
|
ROIC – operational (%)
|
8.0
|
7.2
|
7.4
|
6.0
|
6.6
|
7.0
|
6.1
|
6.4
|
|||||||||||||
|
ROE – as-reported (%)
|
15.4
|
10.8
|
11.3
|
7.8
|
9.3
|
12.8
|
10.5
|
9.3
|
|||||||||||||
|
ROE – operational (%)
|
15.6
|
13.6
|
14.2
|
10.7
|
12.2
|
13.2
|
10.9
|
11.7
|
|||||||||||||
|
Cash flow interest coverage
|
7.1
|
7.5
|
7.2
|
6.8
|
6.1
|
5.9
|
5.8
|
5.9
|
|||||||||||||
|
Debt to capital ratio (%)
|
57.3
|
57.9
|
57.4
|
57.7
|
58.7
|
58.7
|
59.0
|
58.4
|
|||||||||||||
|
Debt to capital ratio, excluding securitization debt (%)
|
55.0
|
55.7
|
55.3
|
55.7
|
56.9
|
56.9
|
57.3
|
56.7
|
|||||||||||||
|
Net debt to net capital ratio, excluding securitization debt (%)
|
53.5
|
54.2
|
54.7
|
54.1
|
55.8
|
56.3
|
56.7
|
56.0
|
|||||||||||||
|
Utility
|
|||||||||||||||||||||
|
GWh billed
|
|||||||||||||||||||||
|
Residential
|
7,274
|
7,760
|
7,940
|
11,605
|
7,360
|
8,344
|
7,377
|
11,359
|
27,080
|
27,305
|
|||||||||||
|
Commercial & Governmental
|
7,270
|
6,992
|
7,753
|
9,101
|
7,313
|
7,005
|
7,267
|
9,041
|
23,312
|
23,846
|
|||||||||||
|
Industrial
|
10,130
|
9,958
|
10,408
|
10,748
|
10,067
|
9,868
|
10,357
|
11,038
|
31,264
|
31,114
|
|||||||||||
|
Wholesale
|
1,090
|
732
|
836
|
833
|
798
|
630
|
590
|
667
|
1,887
|
2,402
|
|||||||||||
|
Non-fuel O&M expense per
MWh (bb)
|
$21.99
|
$20.08
|
$19.94
|
$16.66
|
$22.19
|
$21.02
|
$23.44
|
$18.15
|
$20.65
|
$18.73
|
|||||||||||
|
Entergy Wholesale Commodities
|
|||||||||||||||||||||
|
Owned Capacity in MW
|
6,599
|
6,612
|
6,612
|
6,612
|
6,612
|
6,612
|
6,612
|
6,612
|
6,612
|
6,612
|
|||||||||||
|
GWh billed
|
11,121
|
11,281
|
11,674
|
12,002
|
11,221
|
10,387
|
11,172
|
11,630
|
33,189
|
34,957
|
|||||||||||
|
Net revenue ($ millions)
|
504
|
452
|
444
|
495
|
463
|
493
|
383
|
494
|
1,370
|
1,391
|
|||||||||||
|
Operational adjusted EBITDA
($ millions)
|
193
|
144
|
127
|
185
|
161
|
194
|
61
|
165
|
419
|
457
|
|||||||||||
|
Avg realized revenue per MWh
|
$52.48
|
$49.29
|
$48.27
|
$51.88
|
$50.56
|
$58.66
|
$47.36
|
$53.22
|
$52.95
|
$49.84
|
|||||||||||
|
Non-fuel O&M expense per
MWh (bb)
|
$24.61
|
$23.93
|
$24.07
|
$23.15
|
$23.52
|
$25.22
|
$25.69
|
$25.28
|
$25.40
|
$23.70
|
|||||||||||
|
EWC Nuclear Operational Measures
|
|||||||||||||||||||||
|
Capacity factor (%)
|
93
|
88
|
85
|
90
|
90
|
83
|
82
|
94
|
86
|
88
|
|||||||||||
|
GWh billed
|
10,367
|
9,838
|
10,426
|
10,480
|
10,298
|
9,246
|
9,789
|
10,274
|
29,309
|
30,744
|
|||||||||||
|
Avg realized revenue per MWh
|
$53.00
|
$50.32
|
$48.67
|
$52.27
|
$49.88
|
$57.82
|
$46.40
|
$53.16
|
$52.37
|
$50.42
|
|||||||||||
|
Production cost per MWh
|
$25.92
|
$25.85
|
$26.61
|
$26.14
|
$26.18
|
$25.94
|
$29.16
|
$25.32
|
$26.73
|
$26.19
|
|||||||||||
|
(bb)
|
Excludes effect of special items: the proposed spin-merge of the transmission business at Utility (2012 and 2013 quarterly and year-to-date periods), HCM implementation expenses (second and third quarters and year-to-date 2013) at Utility and EWC and the asset impairments and related charges of the VY plant at EWC (first quarter and year-to-date 2012 and third quarter and year-to-date 2013).
|
|
E.
|
Preliminary Planned Capital Expenditures
|
Entergy is developing its capital investment plan for 2014 through 2016. As shown in Appendix E, Entergy currently anticipates $6.8 billion for investment, including $5.8 billion for Utility and $1.0 billion for EWC. Utility depreciation expense over the comparable period is expected to total approximately $3.2 billion. In addition to routine maintenance, the preliminary capital investment plan includes specific investments and initiatives such as:
|
·
|
Utility: generation investments of $0.2 billion for ELL’s Ninemile 6 new CCGT project, $0.2 billion for post-Fukushima requirements for the Utility nuclear fleet, $0.4 billion for environmental spending (included in generation) for potential scrubbers at the White Bluff plant to meet pending Arkansas state requirements under the Clean Air Visibility Rule as well as compliance with the EPA’s MATS rule; transmission spending to support economic development projects, reliability and new compliance requirements.
|
|
·
|
Entergy Wholesale Commodities: significant projects required to continue the operation of the current generation fleet including component replacements, software and security; $0.14 billion for NYPA value sharing (the last estimated $72 million payment to be made in January 2015 for 2014 generation); dry cask storage and license renewal and $0.2 billion for post-Fukushima requirements for the EWC nuclear fleet. The preliminary capital plan does not include any amounts for VY. The current preliminary cost estimate for post-Fukushima capital requirements expected to be incurred over the 2012 through 2018 time period has been updated from second quarter 2013 to exclude VY. As a result, total planned capital costs through 2018 for EWC’s post-Fukushima requirements have been reduced by $45 million.
|
Estimated capital expenditures are subject to periodic review and modification, and actual spending may vary based on a number of factors. The preliminary capital plan does not reflect the effects of the proposed spin-off and merger of the transmission business with ITC discussed in Appendix A. The preliminary total transmission investment is approximately $1.7 billion for 2014 through 2016.
|
Appendix E: 2014 – 2016 Preliminary Capital Expenditure Plan
|
|
Prepared October 2013
|
|
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. Non-GAAP measures are included in this release to provide metrics that remove the effect of financial events that are not routine, 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
|
|
Non-fuel O&M expense per MWh
|
Operation, maintenance and refueling expenses per MWh of billed sales, excluding fuel, fuel-related expenses and purchased power
|
|
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, fuel-related expenses and purchased power 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 shutdown of VY in fourth quarter 2014, uninterrupted normal operation at the remaining nuclear plants and timely renewal of plant operating licenses; 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, or other conditions precedent
|
|
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 installed capacity 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 contracts
|
A contract for the sale of installed capacity and related energy, priced per megawatt-hour sold
|
|
Capacity contracts
|
A contract for the sale of the installed capacity product in regional markets managed by ISO-NE, the NYISO and MISO
|
|
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 the 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 total revenue per MWh
|
Total energy and capacity revenue on a per unit basis at which total planned generation output and capacity 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, excluding the revenue associated with the amortization of the below market PPA for Palisades; also excludes payments owed under value sharing agreements, if any
|
|
|
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 and commercial paper and capital leases 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
|
Total 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
|
|
|
Gross liquidity
|
Sum of cash and revolver capacity
|
|
|
Debt to capital ratio, excluding securitization debt
|
Total debt divided by total capitalization, excluding securitization debt
|
|
|
Net debt to net capital ratio, excluding securitization debt
|
Total 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 total 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
|
|
|
ANO
|
Arkansas Nuclear One (nuclear)
|
|
APSC
|
Arkansas Public Service Commission
|
|
B&E
|
LPSC Business and Executive session
|
|
CCGT
|
Combined cycle gas turbine
|
|
CCNO
|
Council of the City of New Orleans, La.
|
|
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.
|
|
ENOI
|
Entergy New Orleans, Inc.
|
|
EPA
|
U.S. Environmental Protection Agency
|
|
ETI
|
Entergy Texas, Inc.
|
|
EWC
|
Entergy Wholesale Commodities
|
|
FCA 7
|
Forward Capacity Auction #7 for the June 2016 through May 2017 period
|
|
FERC
|
Federal Energy Regulatory Commission
|
|
FRP
|
Formula rate plan
|
|
GAAP
|
Generally accepted accounting principles
|
|
HCM
|
Human Capital Management strategic imperative
|
|
HSR
|
Hart-Scott-Rodino Antitrust Improvements Act of 1976
|
|
IP2
|
Indian Point Energy Center Unit 2 (nuclear)
|
|
IP3
|
Indian Point Energy Center Unit 3 (nuclear)
|
|
IRS
|
Internal Revenue Service
|
|
ISO
|
Independent system operator
|
|
ISO-NE
|
ISO New England
|
|
ITC
|
ITC Holdings Corp.
|
|
FitzPatrick
|
James A. FitzPatrick Nuclear Power Plant (nuclear)
|
|
LHV
|
Lower Hudson Valley
|
|
LPSC
|
Louisiana Public Service Commission
|
|
MATS
|
Mercury and Air Toxics Standards
|
|
MISO
|
Midcontinent Independent System Operator, Inc.
|
|
MPSC
|
Mississippi Public Service Commission
|
|
NRC
|
Nuclear Regulatory Commission
|
|
NYISO
|
New York Independent System Operator, Inc.
|
|
NYPA
|
New York Power Authority
|
|
OATT
|
FERC-jurisdictional Open Access Transmission Tariff
|
|
Palisades
|
Palisades Power Plant (nuclear)
|
|
Pilgrim
|
Pilgrim Nuclear Power Station (nuclear)
|
|
PPA
|
Power purchase agreement
|
|
PSC
|
Public Service Commission
|
|
PUCT
|
Public Utility Commission of Texas
|
|
RISEC
|
Rhode Island State Energy Center
|
|
ROE
|
Return on equity
|
|
ROIC
|
Return on invested capital
|
|
RTO
|
Regional transmission organization
|
|
SEC
|
U.S. Securities and Exchange Commission
|
|
TransCo
|
Mid South TransCo LLC, a wholly owned subsidiary of Entergy Corp. that will become the holding company for Entergy’s transmission business prior to the close of the merger with ITC
|
|
VY
|
Vermont Yankee Nuclear Power Station (nuclear)
|
|
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)
|
||||||||
|
4Q11
|
1Q12
|
2Q12
|
3Q12
|
4Q12
|
1Q13
|
2Q13
|
3Q13
|
|
|
As-reported net income-rolling 12 months (A)
|
1,346
|
946
|
996
|
705
|
847
|
1,160
|
958
|
861
|
|
Preferred dividends
|
21
|
21
|
21
|
22
|
22
|
22
|
21
|
20
|
|
Tax effected interest expense
|
316
|
322
|
329
|
342
|
350
|
356
|
363
|
365
|
|
As-reported net income, rolling 12 months including preferred dividends and tax effected interest expense (B)
|
1,683
|
1,289
|
1,346
|
1,069
|
1,219
|
1,538
|
1,342
|
1,246
|
|
Special items in prior quarters
|
-
|
(13)
|
(244)
|
(253)
|
(251)
|
(31)
|
(28)
|
(33)
|
|
Special items in current quarter
|
||||||||
|
VY asset impairments / related charges
|
-
|
(224)
|
-
|
-
|
-
|
-
|
-
|
(173)
|
|
Transmission spin-merge
|
(13)
|
(7)
|
(9)
|
(11)
|
(11)
|
(6)
|
(12)
|
(10)
|
|
HCM expenses
|
-
|
-
|
-
|
-
|
-
|
-
|
(4)
|
(7)
|
|
Total special items (C)
|
(13)
|
(244)
|
(253)
|
(264)
|
(262)
|
(37)
|
(44)
|
(224)
|
|
Operational earnings, rolling 12 months including preferred dividends and tax effected interest expense (B-C)
|
1,696
|
1,533
|
1,599
|
1,333
|
1,481
|
1,575
|
1,386
|
1,470
|
|
Operational earnings, rolling 12 months (A-C)
|
1,359
|
1,190
|
1,249
|
969
|
1,109
|
1,197
|
1,002
|
1,085
|
|
Average invested capital (D)
|
21,126
|
21,339
|
21,556
|
22,065
|
22,290
|
22,389
|
22,573
|
22,857
|
|
Average common equity (E)
|
8,729
|
8,725
|
8,814
|
9,078
|
9,079
|
9,064
|
9,152
|
9,299
|
|
ROIC – as-reported % (B/D)
|
8.0
|
6.0
|
6.2
|
4.8
|
5.5
|
6.9
|
5.9
|
5.5
|
|
ROIC – operational % ((B-C)/D)
|
8.0
|
7.2
|
7.4
|
6.0
|
6.6
|
7.0
|
6.1
|
6.4
|
|
ROE – as-reported % (A/E)
|
15.4
|
10.8
|
11.3
|
7.8
|
9.3
|
12.8
|
10.5
|
9.3
|
|
ROE – operational % ((A-C)/E)
|
15.6
|
13.6
|
14.2
|
10.7
|
12.2
|
13.2
|
10.9
|
11.7
|
|
Appendix G-2: Reconciliation of GAAP to Non-GAAP Financial Measures – Credit and Liquidity Metrics
|
||||||||
|
($ in millions)
|
||||||||
|
4Q11
|
1Q12
|
2Q12
|
3Q12
|
4Q12
|
1Q13
|
2Q13
|
3Q13
|
|
|
Total debt (A)
|
12,387
|
12,619
|
12,533
|
12,931
|
13,473
|
13,471
|
13,747
|
13,623
|
|
Less securitization debt (B)
|
1,071
|
1,049
|
1,020
|
1,003
|
973
|
952
|
927
|
910
|
|
Total debt, excluding securitization debt (C)
|
11,316
|
11,570
|
11,513
|
11,928
|
12,500
|
12,519
|
12,820
|
12,713
|
|
Less cash and cash equivalents (D)
|
694
|
685
|
283
|
750
|
533
|
263
|
311
|
365
|
|
Net debt, excluding securitization debt (E)
|
10,622
|
10,885
|
11,230
|
11,178
|
11,967
|
12,256
|
12,509
|
12,348
|
|
Total capitalization (F)
|
21,629
|
21,813
|
21,844
|
22,402
|
22,951
|
22,965
|
23,302
|
23,312
|
|
Less securitization debt (B)
|
1,071
|
1,049
|
1,020
|
1,003
|
973
|
952
|
927
|
910
|
|
Total capitalization, excluding securitization debt (G)
|
20,558
|
20,764
|
20,824
|
21,399
|
21,978
|
22,013
|
22,375
|
22,402
|
|
Less cash and cash equivalents (D)
|
694
|
685
|
283
|
750
|
533
|
263
|
311
|
365
|
|
Net capital, excluding securitization debt (H)
|
19,864
|
20,079
|
20,541
|
20,649
|
21,445
|
21,750
|
22,064
|
22,037
|
|
Debt to capital ratio % (A/F)
|
57.3
|
57.9
|
57.4
|
57.7
|
58.7
|
58.7
|
59.0
|
58.4
|
|
Debt to capital ratio, excluding securitization debt % (C/G)
|
55.0
|
55.7
|
55.3
|
55.7
|
56.9
|
56.9
|
57.3
|
56.7
|
|
Net debt to net capital ratio, excluding securitization debt % (E/H)
|
53.5
|
54.2
|
54.7
|
54.1
|
55.8
|
56.3
|
56.7
|
56.0
|
|
Off-balance sheet liabilities (I)
|
604
|
601
|
600
|
599
|
595
|
595
|
594
|
592
|
|
Net debt to net capital ratio including off-balance sheet liabilities, excluding securitization debt % ((E+I)/(H+I))
|
54.8
|
55.5
|
56.0
|
55.4
|
57.0
|
57.5
|
57.8
|
57.2
|
|
Revolver capacity (J)
|
2,001
|
2,825
|
2,762
|
2,917
|
3,462
|
3,542
|
3,819
|
4,129
|
|
Gross liquidity (D+J)
|
2,695
|
3,510
|
3,045
|
3,667
|
3,995
|
3,805
|
4,130
|
4,494
|
|
Appendix G-3: Reconciliation of GAAP to Non-GAAP Financial Measures – Entergy Wholesale Commodities Operational Adjusted EBITDA
|
||||||||
|
($ in millions)
|
||||||||
|
4Q11
|
1Q12
|
2Q12
|
3Q12
|
4Q12
|
1Q13
|
2Q13
|
3Q13
|
|
|
Net income
|
156
|
(176)
|
71
|
87
|
59
|
82
|
12
|
(93)
|
|
Add back: interest expense
|
6
|
6
|
5
|
3
|
3
|
3
|
4
|
4
|
|
Add back: income tax expense
|
18
|
(92)
|
47
|
57
|
50
|
57
|
(15)
|
(107)
|
|
Add back: depreciation and amortization
|
46
|
51
|
48
|
29
|
47
|
49
|
50
|
55
|
|
Subtract: interest and investment income
|
29
|
31
|
27
|
20
|
28
|
28
|
22
|
21
|
|
Add back: decommissioning expense
|
(4)
|
30
|
(17)
|
29
|
30
|
31
|
30
|
32
|
|
Adjusted EBITDA
|
193
|
(212)
|
127
|
185
|
161
|
194
|
59
|
(130)
|
|
Add back: special item for HCM implementation expenses (pre-tax)
|
-
|
-
|
-
|
-
|
–
|
–
|
2
|
3
|
|
Add back: VY asset impairments / related charges (pre-tax)
|
-
|
356
|
-
|
-
|
–
|
–
|
–
|
292
|
|
Operational adjusted EBITDA
|
193
|
144
|
127
|
185
|
161
|
194
|
61
|
165
|
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 Corporation 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 this news release and in: (i) Entergy’s most recent Annual Report on Form 10-K, any subsequent Quarterly Reports on Form 10-Q 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 news 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 and the availability of financing.
|
VIII.
|
Financial Statements
|
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Balance Sheet
|
||||||||||||||||
|
September 30, 2013
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
ASSETS
|
||||||||||||||||
|
CURRENT ASSETS
|
||||||||||||||||
|
Cash and cash equivalents:
|
||||||||||||||||
|
Cash
|
$ | 99,955 | $ | 2,547 | $ | 447 | $ | 102,949 | ||||||||
|
Temporary cash investments
|
135,348 | 122,965 | 4,070 | 262,383 | ||||||||||||
|
Total cash and cash equivalents
|
235,303 | 125,512 | 4,517 | 365,332 | ||||||||||||
|
Securitization recovery trust account
|
49,741 | - | - | 49,741 | ||||||||||||
|
Notes receivable
|
- | 633,989 | (633,989 | ) | - | |||||||||||
|
Accounts receivable:
|
||||||||||||||||
|
Customer
|
619,483 | 133,550 | - | 753,033 | ||||||||||||
|
Allowance for doubtful accounts
|
(33,482 | ) | - | - | (33,482 | ) | ||||||||||
|
Associated companies
|
35,426 | 4,416 | (39,842 | ) | - | |||||||||||
|
Other
|
150,618 | 20,084 | (82 | ) | 170,620 | |||||||||||
|
Accrued unbilled revenues
|
377,261 | 327 | - | 377,588 | ||||||||||||
|
Total accounts receivable
|
1,149,306 | 158,377 | (39,924 | ) | 1,267,759 | |||||||||||
|
Deferred fuel costs
|
119,338 | - | - | 119,338 | ||||||||||||
|
Accumulated deferred income taxes
|
82,005 | 933 | (47,025 | ) | 35,913 | |||||||||||
|
Fuel inventory - at average cost
|
187,092 | 10,317 | - | 197,409 | ||||||||||||
|
Materials and supplies - at average cost
|
594,439 | 311,680 | - | 906,119 | ||||||||||||
|
Deferred nuclear refueling outage costs
|
108,943 | 137,049 | - | 245,992 | ||||||||||||
|
System agreement cost equalization
|
6,256 | - | - | 6,256 | ||||||||||||
|
Prepayments and other
|
187,871 | 414,794 | (355,080 | ) | 247,585 | |||||||||||
|
TOTAL
|
2,720,294 | 1,792,651 | (1,071,501 | ) | 3,441,444 | |||||||||||
|
OTHER PROPERTY AND INVESTMENTS
|
||||||||||||||||
|
Investment in affiliates - at equity
|
1,097,271 | 44,306 | (1,097,159 | ) | 44,418 | |||||||||||
|
Decommissioning trust funds
|
2,096,265 | 2,531,509 | - | 4,627,774 | ||||||||||||
|
Non-utility property - at cost (less accumulated depreciation)
|
180,525 | 70,060 | 9,491 | 260,076 | ||||||||||||
|
Other
|
169,409 | 16,550 | - | 185,959 | ||||||||||||
|
TOTAL
|
3,543,470 | 2,662,425 | (1,087,668 | ) | 5,118,227 | |||||||||||
|
PROPERTY, PLANT, AND EQUIPMENT
|
||||||||||||||||
|
Electric
|
37,879,974 | 4,778,958 | 3,388 | 42,662,320 | ||||||||||||
|
Property under capital lease
|
933,058 | - | - | 933,058 | ||||||||||||
|
Natural gas
|
361,441 | - | - | 361,441 | ||||||||||||
|
Construction work in progress
|
1,243,239 | 355,509 | 379 | 1,599,127 | ||||||||||||
|
Nuclear fuel
|
877,375 | 682,801 | - | 1,560,176 | ||||||||||||
|
TOTAL PROPERTY, PLANT AND EQUIPMENT
|
41,295,087 | 5,817,268 | 3,767 | 47,116,122 | ||||||||||||
|
Less - accumulated depreciation and amortization
|
18,360,230 | 1,188,043 | 410 | 19,548,683 | ||||||||||||
|
PROPERTY, PLANT AND EQUIPMENT - NET
|
22,934,857 | 4,629,225 | 3,357 | 27,567,439 | ||||||||||||
|
DEFERRED DEBITS AND OTHER ASSETS
|
||||||||||||||||
|
Regulatory assets:
|
||||||||||||||||
|
Regulatory asset for income taxes - net
|
860,169 | - | - | 860,169 | ||||||||||||
|
Other regulatory assets
|
4,750,482 | - | - | 4,750,482 | ||||||||||||
|
Deferred fuel costs
|
172,202 | - | - | 172,202 | ||||||||||||
|
Goodwill
|
374,099 | 3,073 | - | 377,172 | ||||||||||||
|
Accumulated deferred income taxes
|
12,820 | 53,495 | 48,292 | 114,607 | ||||||||||||
|
Other
|
215,563 | 722,488 | (15,555 | ) | 922,496 | |||||||||||
|
TOTAL
|
6,385,335 | 779,056 | 32,737 | 7,197,128 | ||||||||||||
| - | ||||||||||||||||
|
TOTAL ASSETS
|
$ | 35,583,956 | $ | 9,863,357 | $ | (2,123,075 | ) | $ | 43,324,238 | |||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Balance Sheet
|
||||||||||||||||
|
September 30, 2013
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
LIABILITIES AND SHAREHOLDERS' EQUITY
|
||||||||||||||||
|
CURRENT LIABILITIES
|
||||||||||||||||
|
Currently maturing long-term debt
|
$ | 188,884 | $ | 17,376 | $ | - | $ | 206,260 | ||||||||
|
Notes payable and commercial paper:
|
||||||||||||||||
|
Associated companies
|
- | 204,063 | (204,063 | ) | - | |||||||||||
|
Other
|
90,963 | - | 1,015,076 | 1,106,039 | ||||||||||||
|
Account payable:
|
||||||||||||||||
|
Associated companies
|
15,630 | 20,517 | (36,147 | ) | - | |||||||||||
|
Other
|
707,326 | 192,520 | 285 | 900,131 | ||||||||||||
|
Customer deposits
|
366,151 | - | - | 366,151 | ||||||||||||
|
Taxes accrued
|
- | - | 327,569 | 327,569 | ||||||||||||
|
Accumulated deferred income taxes
|
24,500 | 46,550 | (46,223 | ) | 24,827 | |||||||||||
|
Interest accrued
|
149,596 | 2,253 | 7,229 | 159,078 | ||||||||||||
|
Deferred fuel costs
|
21,995 | - | - | 21,995 | ||||||||||||
|
Obligations under capital leases
|
2,717 | - | - | 2,717 | ||||||||||||
|
Pension and other postretirement liabilities
|
46,165 | 7,657 | - | 53,822 | ||||||||||||
|
System agreement cost equalization
|
6,256 | - | - | 6,256 | ||||||||||||
|
Other
|
137,641 | 116,011 | 263 | 253,915 | ||||||||||||
|
TOTAL
|
1,757,824 | 606,947 | 1,063,989 | 3,428,760 | ||||||||||||
|
NON-CURRENT LIABILITIES
|
||||||||||||||||
|
Accumulated deferred income taxes and taxes accrued
|
7,103,683 | 871,639 | 365,725 | 8,341,047 | ||||||||||||
|
Accumulated deferred investment tax credits
|
266,547 | - | - | 266,547 | ||||||||||||
|
Obligations under capital leases
|
32,814 | - | - | 32,814 | ||||||||||||
|
Other regulatory liabilities
|
1,189,579 | - | - | 1,189,579 | ||||||||||||
|
Decommissioning and retirement cost liabilities
|
2,062,020 | 1,640,861 | - | 3,702,881 | ||||||||||||
|
Accumulated provisions
|
110,365 | 4,093 | 1,049 | 115,507 | ||||||||||||
|
Pension and other postretirement liabilities
|
2,871,661 | 847,489 | - | 3,719,150 | ||||||||||||
|
Long-term debt
|
10,531,749 | 94,334 | 1,649,409 | 12,275,492 | ||||||||||||
|
Other
|
734,403 | 578,160 | (749,064 | ) | 563,499 | |||||||||||
|
TOTAL
|
24,902,821 | 4,036,576 | 1,267,119 | 30,206,516 | ||||||||||||
|
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 | 301,095 | (2,459,815 | ) | 2,548 | |||||||||||
|
Paid-in capital
|
2,417,644 | 2,013,134 | 931,646 | 5,362,424 | ||||||||||||
|
Retained earnings
|
4,382,837 | 2,950,186 | 2,492,630 | 9,825,653 | ||||||||||||
|
Accumulated other comprehensive income (loss)
|
(198,949 | ) | (44,581 | ) | - | (243,530 | ) | |||||||||
|
Less - treasury stock, at cost (76,446,813 shares in 2013)
|
120,000 | - | 5,418,644 | 5,538,644 | ||||||||||||
|
Total common shareholders' equity
|
8,642,800 | 5,219,834 | (4,454,183 | ) | 9,408,451 | |||||||||||
|
Subsidiaries' preferred stock without sinking fund
|
94,000 | - | - | 94,000 | ||||||||||||
|
TOTAL
|
8,736,800 | 5,219,834 | (4,454,183 | ) | 9,502,451 | |||||||||||
|
TOTAL LIABILITIES AND EQUITY
|
$ | 35,583,956 | $ | 9,863,357 | $ | (2,123,075 | ) | $ | 43,324,238 | |||||||
|
*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 (76,945,239 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
|
||||||||||||||||
|
September 30, 2013 vs December 31, 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
ASSETS
|
||||||||||||||||
|
CURRENT ASSETS
|
||||||||||||||||
|
Cash and cash equivalents:
|
||||||||||||||||
|
Cash
|
$ | (4,423 | ) | $ | (5,677 | ) | $ | 57 | $ | (10,043 | ) | |||||
|
Temporary cash investments
|
(140,407 | ) | (9,732 | ) | (7,055 | ) | (157,194 | ) | ||||||||
|
Total cash and cash equivalents
|
(144,830 | ) | (15,409 | ) | (6,998 | ) | (167,237 | ) | ||||||||
|
Securitization recovery trust account
|
3,701 | - | - | 3,701 | ||||||||||||
|
Notes receivable
|
- | 187,633 | (187,633 | ) | - | |||||||||||
|
Accounts receivable:
|
||||||||||||||||
|
Customer
|
245,080 | (60,918 | ) | - | 184,162 | |||||||||||
|
Allowance for doubtful accounts
|
(1,526 | ) | - | - | (1,526 | ) | ||||||||||
|
Associated companies
|
6,697 | (949 | ) | (5,748 | ) | - | ||||||||||
|
Other
|
937 | 9,100 | (825 | ) | 9,212 | |||||||||||
|
Accrued unbilled revenues
|
73,997 | 199 | - | 74,196 | ||||||||||||
|
Total accounts receivable
|
325,185 | (52,568 | ) | (6,573 | ) | 266,044 | ||||||||||
|
Deferred fuel costs
|
(31,025 | ) | - | - | (31,025 | ) | ||||||||||
|
Accumulated deferred income taxes
|
(266,876 | ) | (339 | ) | (3,774 | ) | (270,989 | ) | ||||||||
|
Fuel inventory - at average cost
|
(18,376 | ) | 1,954 | - | (16,422 | ) | ||||||||||
|
Materials and supplies - at average cost
|
5,782 | (28,193 | ) | - | (22,411 | ) | ||||||||||
|
Deferred nuclear refueling outage costs
|
(15,032 | ) | 17,650 | - | 2,618 | |||||||||||
|
System agreement cost equalization
|
(10,624 | ) | - | - | (10,624 | ) | ||||||||||
|
Prepayments and other
|
117,094 | 1,461 | (113,892 | ) | 4,663 | |||||||||||
|
TOTAL
|
(35,001 | ) | 112,189 | (318,870 | ) | (241,682 | ) | |||||||||
|
OTHER PROPERTY AND INVESTMENTS
|
||||||||||||||||
|
Investment in affiliates - at equity
|
- | (2,320 | ) | - | (2,320 | ) | ||||||||||
|
Decommissioning trust funds
|
240,306 | 197,360 | - | 437,666 | ||||||||||||
|
Non-utility property - at cost (less accumulated depreciation)
|
6,306 | (486 | ) | (1,783 | ) | 4,037 | ||||||||||
|
Other
|
(252,730 | ) | 2,455 | - | (250,275 | ) | ||||||||||
|
TOTAL
|
(6,118 | ) | 197,009 | (1,783 | ) | 189,108 | ||||||||||
|
PROPERTY, PLANT, AND EQUIPMENT
|
||||||||||||||||
|
Electric
|
615,521 | 102,262 | (30 | ) | 717,753 | |||||||||||
|
Property under capital lease
|
(2,141 | ) | - | - | (2,141 | ) | ||||||||||
|
Natural gas
|
7,949 | - | - | 7,949 | ||||||||||||
|
Construction work in progress
|
270,168 | (36,240 | ) | (500 | ) | 233,428 | ||||||||||
|
Nuclear fuel
|
(29,918 | ) | (8,336 | ) | - | (38,254 | ) | |||||||||
|
TOTAL PROPERTY, PLANT AND EQUIPMENT
|
861,579 | 57,686 | (530 | ) | 918,735 | |||||||||||
|
Less - accumulated depreciation and amortization
|
519,843 | 129,974 | 24 | 649,841 | ||||||||||||
|
PROPERTY, PLANT AND EQUIPMENT - NET
|
341,736 | (72,288 | ) | (554 | ) | 268,894 | ||||||||||
|
DEFERRED DEBITS AND OTHER ASSETS
|
||||||||||||||||
|
Regulatory assets:
|
||||||||||||||||
|
Regulatory asset for income taxes - net
|
118,139 | - | - | 118,139 | ||||||||||||
|
Other regulatory assets
|
(275,430 | ) | - | - | (275,430 | ) | ||||||||||
|
Deferred fuel costs
|
- | - | - | - | ||||||||||||
|
Goodwill
|
- | - | - | - | ||||||||||||
|
Accumulated deferred income taxes
|
2,359 | 32,746 | 41,754 | 76,859 | ||||||||||||
|
Other
|
141 | (29,644 | ) | 15,351 | (14,152 | ) | ||||||||||
|
TOTAL
|
(154,791 | ) | 3,102 | 57,105 | (94,584 | ) | ||||||||||
|
TOTAL ASSETS
|
$ | 145,826 | $ | 240,012 | $ | (264,102 | ) | $ | 121,736 | |||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Balance Sheet
|
||||||||||||||||
|
September 30, 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
|
$ | (512,206 | ) | $ | (50 | ) | $ | - | $ | (512,256 | ) | |||||
|
Notes payable and commercial paper:
|
||||||||||||||||
|
Associated companies
|
(28,000 | ) | 202,626 | (174,626 | ) | - | ||||||||||
|
Other
|
(40,436 | ) | - | 350,473 | 310,037 | |||||||||||
|
Account payable:
|
||||||||||||||||
|
Associated companies
|
(168 | ) | 9,507 | (9,339 | ) | - | ||||||||||
|
Other
|
(249,867 | ) | (66,942 | ) | (240 | ) | (317,049 | ) | ||||||||
|
Customer deposits
|
7,073 | - | - | 7,073 | ||||||||||||
|
Taxes accrued
|
(664,891 | ) | - | 658,741 | (6,150 | ) | ||||||||||
|
Accumulated deferred income taxes
|
16,545 | 6,119 | (10,946 | ) | 11,718 | |||||||||||
|
Interest accrued
|
(10,555 | ) | 1,932 | (16,963 | ) | (25,586 | ) | |||||||||
|
Deferred fuel costs
|
(74,444 | ) | - | - | (74,444 | ) | ||||||||||
|
Obligations under capital leases
|
(1,163 | ) | - | - | (1,163 | ) | ||||||||||
|
Pension and other postretirement liabilities
|
(43,235 | ) | 1,157 | - | (42,078 | ) | ||||||||||
|
System agreement cost equalization
|
(19,592 | ) | - | - | (19,592 | ) | ||||||||||
|
Other
|
31,589 | (38,008 | ) | (1,652 | ) | (8,071 | ) | |||||||||
|
TOTAL
|
(1,589,350 | ) | 116,341 | 795,448 | (677,561 | ) | ||||||||||
|
NON-CURRENT LIABILITIES
|
||||||||||||||||
|
Accumulated deferred income taxes and taxes accrued
|
259,354 | 51,641 | (281,704 | ) | 29,291 | |||||||||||
|
Accumulated deferred investment tax credits
|
(7,149 | ) | - | - | (7,149 | ) | ||||||||||
|
Obligations under capital leases
|
(1,727 | ) | - | - | (1,727 | ) | ||||||||||
|
Other regulatory liabilities
|
290,965 | - | - | 290,965 | ||||||||||||
|
Decommissioning and retirement cost liabilities
|
91,658 | 97,589 | - | 189,247 | ||||||||||||
|
Accumulated provisions
|
(247,436 | ) | 3,115 | (2,398 | ) | (246,719 | ) | |||||||||
|
Pension and other postretirement liabilities
|
(20,126 | ) | 13,390 | - | (6,736 | ) | ||||||||||
|
Long-term debt
|
997,989 | 2,030 | (644,845 | ) | 355,174 | |||||||||||
|
Other
|
25,221 | (33,654 | ) | (5,978 | ) | (14,411 | ) | |||||||||
|
TOTAL
|
1,388,749 | 134,111 | (934,925 | ) | 587,935 | |||||||||||
|
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 2013 and in 2012
|
- | (2 | ) | 2 | - | |||||||||||
|
Paid-in capital
|
- | 151,779 | (147,207 | ) | 4,572 | |||||||||||
|
Retained earnings
|
330,396 | (195,739 | ) | (13,595 | ) | 121,062 | ||||||||||
|
Accumulated other comprehensive income (loss)
|
16,031 | 33,522 | - | 49,553 | ||||||||||||
|
Less - treasury stock, at cost
|
- | - | (36,175 | ) | (36,175 | ) | ||||||||||
|
Total common shareholders' equity
|
346,427 | (10,440 | ) | (124,625 | ) | 211,362 | ||||||||||
|
Subsidiaries' preferred stock without sinking fund
|
- | - | - | - | ||||||||||||
|
TOTAL
|
346,427 | (10,440 | ) | (124,625 | ) | 211,362 | ||||||||||
|
TOTAL LIABILITIES AND EQUITY
|
$ | 145,826 | $ | 240,012 | $ | (264,102 | ) | $ | 121,736 | |||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Three Months Ended September 30, 2013
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 2,706,369 | $ | - | $ | (1,569 | ) | $ | 2,704,800 | |||||||
|
Natural gas
|
26,113 | - | - | 26,113 | ||||||||||||
|
Competitive businesses
|
- | 623,321 | (2,275 | ) | 621,046 | |||||||||||
|
Total
|
2,732,482 | 623,321 | (3,844 | ) | 3,351,959 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
712,929 | 105,753 | (428 | ) | 818,254 | |||||||||||
|
Purchased power
|
378,042 | 23,098 | (8,595 | ) | 392,545 | |||||||||||
|
Nuclear refueling outage expenses
|
31,557 | 33,201 | - | 64,758 | ||||||||||||
|
Asset impairment and related charges
|
- | 291,505 | - | 291,505 | ||||||||||||
|
Other operation and maintenance
|
569,829 | 264,138 | 5,381 | 839,348 | ||||||||||||
|
Decommissioning
|
29,426 | 31,422 | - | 60,848 | ||||||||||||
|
Taxes other than income taxes
|
122,862 | 33,626 | 462 | 156,950 | ||||||||||||
|
Depreciation and amortization
|
269,006 | 55,125 | 1,018 | 325,149 | ||||||||||||
|
Other regulatory charges (credits) - net
|
13,708 | - | - | 13,708 | ||||||||||||
|
Total
|
2,127,359 | 837,868 | (2,162 | ) | 2,963,065 | |||||||||||
|
OPERATING INCOME
|
605,123 | (214,547 | ) | (1,682 | ) | 388,894 | ||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
17,676 | - | - | 17,676 | ||||||||||||
|
Interest and investment income
|
33,821 | 20,946 | (31,337 | ) | 23,430 | |||||||||||
|
Miscellaneous - net
|
(5,873 | ) | (2,296 | ) | (2,045 | ) | (10,214 | ) | ||||||||
|
Total
|
45,624 | 18,650 | (33,382 | ) | 30,892 | |||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
134,081 | 4,268 | 19,155 | 157,504 | ||||||||||||
|
Allowance for borrowed funds used during construction
|
(6,453 | ) | - | - | (6,453 | ) | ||||||||||
|
Total
|
127,628 | 4,268 | 19,155 | 151,051 | ||||||||||||
|
INCOME BEFORE INCOME TAXES
|
523,119 | (200,165 | ) | (54,219 | ) | 268,735 | ||||||||||
|
Income taxes
|
170,816 | (107,337 | ) | (38,926 | ) | 24,553 | ||||||||||
|
CONSOLIDATED NET INCOME
|
352,303 | (92,828 | ) | (15,293 | ) | 244,182 | ||||||||||
|
Preferred dividend requirements of subsidiaries
|
4,332 | - | - | 4,332 | ||||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 347,971 | $ | (92,828 | ) | $ | (15,293 | ) | $ | 239,850 | ||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 1.95 | $ | (0.52 | ) | $ | (0.08 | ) | $ | 1.35 | ||||||
|
DILUTED
|
$ | 1.95 | $ | (0.52 | ) | $ | (0.09 | ) | $ | 1.34 | ||||||
|
AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
|
||||||||||||||||
|
BASIC
|
178,283,721 | |||||||||||||||
|
DILUTED
|
178,652,210 | |||||||||||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Three Months Ended September 30, 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 2,321,328 | $ | - | $ | (968 | ) | $ | 2,320,360 | |||||||
|
Natural gas
|
23,557 | - | - | 23,557 | ||||||||||||
|
Competitive businesses
|
- | 626,849 | (7,206 | ) | 619,643 | |||||||||||
|
Total
|
2,344,885 | 626,849 | (8,174 | ) | 2,963,560 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
500,218 | 96,479 | (427 | ) | 596,270 | |||||||||||
|
Purchased power
|
312,429 | 35,293 | (11,170 | ) | 336,552 | |||||||||||
|
Nuclear refueling outage expenses
|
29,714 | 32,868 | - | 62,582 | ||||||||||||
|
Asset impairment and related charges
|
- | - | - | - | ||||||||||||
|
Other operation and maintenance
|
518,830 | 244,981 | 1,431 | 765,242 | ||||||||||||
|
Decommissioning
|
27,657 | 29,139 | - | 56,796 | ||||||||||||
|
Taxes other than income taxes
|
119,676 | 29,097 | 276 | 149,049 | ||||||||||||
|
Depreciation and amortization
|
251,099 | 29,585 | 1,056 | 281,740 | ||||||||||||
|
Other regulatory charges (credits) - net
|
24,477 | - | - | 24,477 | ||||||||||||
|
Total
|
1,784,100 | 497,442 | (8,834 | ) | 2,272,708 | |||||||||||
|
OPERATING INCOME
|
560,785 | 129,407 | 660 | 690,852 | ||||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
18,396 | - | - | 18,396 | ||||||||||||
|
Interest and investment income
|
35,772 | 20,197 | (31,479 | ) | 24,490 | |||||||||||
|
Miscellaneous - net
|
(4,451 | ) | (3,038 | ) | (3,279 | ) | (10,768 | ) | ||||||||
|
Total
|
49,717 | 17,159 | (34,758 | ) | 32,118 | |||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
130,331 | 3,118 | 22,351 | 155,800 | ||||||||||||
|
Allowance for borrowed funds used during construction
|
(8,003 | ) | - | - | (8,003 | ) | ||||||||||
|
Total
|
122,328 | 3,118 | 22,351 | 147,797 | ||||||||||||
|
INCOME BEFORE INCOME TAXES
|
488,174 | 143,448 | (56,449 | ) | 575,173 | |||||||||||
|
Income taxes
|
187,668 | 56,676 | (11,841 | ) | 232,503 | |||||||||||
|
CONSOLIDATED NET INCOME
|
300,506 | 86,772 | (44,608 | ) | 342,670 | |||||||||||
|
Preferred dividend requirements of subsidiaries
|
4,332 | - | 1,250 | 5,582 | ||||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 296,174 | $ | 86,772 | $ | (45,858 | ) | $ | 337,088 | |||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 1.67 | $ | 0.49 | $ | (0.26 | ) | $ | 1.90 | |||||||
|
DILUTED
|
$ | 1.66 | $ | 0.49 | $ | (0.26 | ) | $ | 1.89 | |||||||
|
AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
|
||||||||||||||||
|
BASIC
|
177,517,846 | |||||||||||||||
|
DILUTED
|
177,975,075 | |||||||||||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Three Months Ended September 30, 2013 vs. 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 385,041 | $ | - | $ | (601 | ) | $ | 384,440 | |||||||
|
Natural gas
|
2,556 | - | - | 2,556 | ||||||||||||
|
Competitive businesses
|
- | (3,528 | ) | 4,931 | 1,403 | |||||||||||
|
Total
|
387,597 | (3,528 | ) | 4,330 | 388,399 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
212,711 | 9,274 | (1 | ) | 221,984 | |||||||||||
|
Purchased power
|
65,613 | (12,195 | ) | 2,575 | 55,993 | |||||||||||
|
Nuclear refueling outage expenses
|
1,843 | 333 | - | 2,176 | ||||||||||||
|
Asset impairment and related charges
|
- | 291,505 | - | 291,505 | ||||||||||||
|
Other operation and maintenance
|
50,999 | 19,157 | 3,950 | 74,106 | ||||||||||||
|
Decommissioning
|
1,769 | 2,283 | - | 4,052 | ||||||||||||
|
Taxes other than income taxes
|
3,186 | 4,529 | 186 | 7,901 | ||||||||||||
|
Depreciation and amortization
|
17,907 | 25,540 | (38 | ) | 43,409 | |||||||||||
|
Other regulatory charges (credits )- net
|
(10,769 | ) | - | - | (10,769 | ) | ||||||||||
|
Total
|
343,259 | 340,426 | 6,672 | 690,357 | ||||||||||||
|
OPERATING INCOME
|
44,338 | (343,954 | ) | (2,342 | ) | (301,958 | ) | |||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
(720 | ) | - | - | (720 | ) | ||||||||||
|
Interest and investment income
|
(1,951 | ) | 749 | 142 | (1,060 | ) | ||||||||||
|
Miscellaneous - net
|
(1,422 | ) | 742 | 1,234 | 554 | |||||||||||
|
Total
|
(4,093 | ) | 1,491 | 1,376 | (1,226 | ) | ||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
3,750 | 1,150 | (3,196 | ) | 1,704 | |||||||||||
|
Allowance for borrowed funds used during construction
|
1,550 | - | - | 1,550 | ||||||||||||
|
Total
|
5,300 | 1,150 | (3,196 | ) | 3,254 | |||||||||||
|
INCOME BEFORE INCOME TAXES
|
34,945 | (343,613 | ) | 2,230 | (306,438 | ) | ||||||||||
|
Income taxes
|
(16,852 | ) | (164,013 | ) | (27,085 | ) | (207,950 | ) | ||||||||
|
CONSOLIDATED NET INCOME
|
51,797 | (179,600 | ) | 29,315 | (98,488 | ) | ||||||||||
|
Preferred dividend requirements of subsidiaries
|
- | - | (1,250 | ) | (1,250 | ) | ||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 51,797 | $ | (179,600 | ) | $ | 30,565 | $ | (97,238 | ) | ||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 0.28 | $ | (1.01 | ) | $ | 0.18 | $ | (0.55 | ) | ||||||
|
DILUTED
|
$ | 0.29 | $ | (1.01 | ) | $ | 0.17 | $ | (0.55 | ) | ||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Nine Months Ended September 30, 2013
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 6,834,943 | $ | - | $ | (3,653 | ) | $ | 6,831,290 | |||||||
|
Natural gas
|
113,315 | - | - | 113,315 | ||||||||||||
|
Competitive businesses
|
- | 1,770,577 | (16,141 | ) | 1,754,436 | |||||||||||
|
Total
|
6,948,258 | 1,770,577 | (19,794 | ) | 8,699,041 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
1,509,264 | 310,561 | (1,631 | ) | 1,818,194 | |||||||||||
|
Purchased power
|
1,194,182 | 89,818 | (32,582 | ) | 1,251,418 | |||||||||||
|
Nuclear refueling outage expenses
|
91,367 | 100,573 | - | 191,940 | ||||||||||||
|
Asset impairment and related charges
|
- | 291,505 | - | 291,505 | ||||||||||||
|
Other operation and maintenance
|
1,676,655 | 747,598 | 13,548 | 2,437,801 | ||||||||||||
|
Decommissioning
|
86,926 | 92,416 | - | 179,342 | ||||||||||||
|
Taxes other than income taxes
|
355,162 | 96,714 | 1,058 | 452,934 | ||||||||||||
|
Depreciation and amortization
|
765,727 | 154,672 | 3,142 | 923,541 | ||||||||||||
|
Other regulatory charges (credits) - net
|
22,914 | - | - | 22,914 | ||||||||||||
|
Total
|
5,702,197 | 1,883,857 | (16,465 | ) | 7,569,589 | |||||||||||
|
OPERATING INCOME
|
1,246,061 | (113,280 | ) | (3,329 | ) | 1,129,452 | ||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
46,675 | - | - | 46,675 | ||||||||||||
|
Interest and investment income
|
124,622 | 71,554 | (93,899 | ) | 102,277 | |||||||||||
|
Miscellaneous - net
|
(18,685 | ) | (11,187 | ) | (7,120 | ) | (36,992 | ) | ||||||||
|
Total
|
152,612 | 60,367 | (101,019 | ) | 111,960 | |||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
395,594 | 11,237 | 59,591 | 466,422 | ||||||||||||
|
Allowance for borrowed funds used during construction
|
(18,432 | ) | - | - | (18,432 | ) | ||||||||||
|
Total
|
377,162 | 11,237 | 59,591 | 447,990 | ||||||||||||
|
INCOME BEFORE INCOME TAXES
|
1,021,511 | (64,150 | ) | (163,939 | ) | 793,422 | ||||||||||
|
Income taxes
|
340,817 | (64,968 | ) | (61,647 | ) | 214,202 | ||||||||||
|
CONSOLIDATED NET INCOME
|
680,694 | 818 | (102,292 | ) | 579,220 | |||||||||||
|
Preferred dividend requirements of subsidiaries
|
12,997 | - | 1,250 | 14,247 | ||||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 667,697 | $ | 818 | $ | (103,542 | ) | $ | 564,973 | |||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 3.75 | $ | 0.00 | $ | (0.58 | ) | $ | 3.17 | |||||||
|
DILUTED
|
$ | 3.74 | $ | 0.00 | $ | (0.58 | ) | $ | 3.16 | |||||||
|
AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
|
||||||||||||||||
|
BASIC
|
178,170,339 | |||||||||||||||
|
DILUTED
|
178,520,063 | |||||||||||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Nine Months Ended September 30, 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 6,042,658 | $ | - | $ | (2,906 | ) | $ | 6,039,752 | |||||||
|
Natural gas
|
93,444 | - | - | 93,444 | ||||||||||||
|
Competitive businesses
|
- | 1,754,774 | (22,150 | ) | 1,732,624 | |||||||||||
|
Total
|
6,136,102 | 1,754,774 | (25,056 | ) | 7,865,820 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
1,304,446 | 269,226 | (1,407 | ) | 1,572,265 | |||||||||||
|
Purchased power
|
903,977 | 94,978 | (32,140 | ) | 966,816 | |||||||||||
|
Nuclear refueling outage expenses
|
81,513 | 102,775 | - | 184,288 | ||||||||||||
|
Asset impairment and related charges
|
- | 355,524 | - | 355,524 | ||||||||||||
|
Other operation and maintenance
|
1,531,007 | 725,948 | 2,803 | 2,259,758 | ||||||||||||
|
Decommissioning
|
84,576 | 42,065 | - | 126,641 | ||||||||||||
|
Taxes other than income taxes
|
333,916 | 89,513 | 900 | 424,329 | ||||||||||||
|
Depreciation and amortization
|
704,741 | 128,728 | 3,242 | 836,711 | ||||||||||||
|
Other regulatory charges (credits) - net
|
162,509 | - | - | 162,509 | ||||||||||||
|
Total
|
5,106,685 | 1,808,757 | (26,602 | ) | 6,888,841 | |||||||||||
|
OPERATING INCOME
|
1,029,417 | (53,983 | ) | 1,546 | 976,979 | |||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
70,986 | - | - | 70,986 | ||||||||||||
|
Interest and investment income
|
113,063 | 77,477 | (95,773 | ) | 94,767 | |||||||||||
|
Miscellaneous - net
|
(19,224 | ) | (15,563 | ) | (7,008 | ) | (41,794 | ) | ||||||||
|
Total
|
164,825 | 61,914 | (102,781 | ) | 123,959 | |||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
382,961 | 14,924 | 54,277 | 452,162 | ||||||||||||
|
Allowance for borrowed funds used during construction
|
(27,877 | ) | - | - | (27,877 | ) | ||||||||||
|
Total
|
355,084 | 14,924 | 54,277 | 424,285 | ||||||||||||
|
INCOME BEFORE INCOME TAXES
|
839,158 | (6,993 | ) | (155,512 | ) | 676,653 | ||||||||||
|
Income taxes
|
162,914 | 11,427 | (64,201 | ) | 110,140 | |||||||||||
|
CONSOLIDATED NET INCOME
|
676,244 | (18,420 | ) | (91,311 | ) | 566,513 | ||||||||||
|
Preferred dividend requirements of subsidiaries
|
12,997 | - | 3,111 | 16,108 | ||||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 663,247 | $ | (18,420 | ) | $ | (94,422 | ) | $ | 550,405 | ||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 3.74 | $ | (0.10 | ) | $ | (0.53 | ) | $ | 3.11 | ||||||
|
DILUTED
|
$ | 3.73 | $ | (0.10 | ) | $ | (0.53 | ) | $ | 3.10 | ||||||
|
AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
|
||||||||||||||||
|
BASIC
|
177,184,464 | |||||||||||||||
|
DILUTED
|
177,636,549 | |||||||||||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Nine Months Ended September 30, 2013 vs. 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 792,285 | $ | - | $ | (747 | ) | $ | 791,538 | |||||||
|
Natural gas
|
19,871 | - | - | 19,871 | ||||||||||||
|
Competitive businesses
|
- | 15,803 | 6,009 | 21,812 | ||||||||||||
|
Total
|
812,156 | 15,803 | 5,262 | 833,221 | ||||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
204,818 | 41,335 | (224 | ) | 245,929 | |||||||||||
|
Purchased power
|
290,205 | (5,160 | ) | (442 | ) | 284,602 | ||||||||||
|
Nuclear refueling outage expenses
|
9,854 | (2,202 | ) | - | 7,652 | |||||||||||
|
Asset impairment and related charges
|
- | (64,019 | ) | - | (64,019 | ) | ||||||||||
|
Other operation and maintenance
|
145,648 | 21,650 | 10,745 | 178,043 | ||||||||||||
|
Decommissioning
|
2,350 | 50,351 | - | 52,701 | ||||||||||||
|
Taxes other than income taxes
|
21,246 | 7,201 | 158 | 28,605 | ||||||||||||
|
Depreciation and amortization
|
60,986 | 25,944 | (100 | ) | 86,830 | |||||||||||
|
Other regulatory charges (credits )- net
|
(139,595 | ) | - | - | (139,595 | ) | ||||||||||
|
Total
|
595,512 | 75,100 | 10,137 | 680,748 | ||||||||||||
|
OPERATING INCOME
|
216,644 | (59,297 | ) | (4,875 | ) | 152,473 | ||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
(24,311 | ) | - | - | (24,311 | ) | ||||||||||
|
Interest and investment income
|
11,559 | (5,923 | ) | 1,874 | 7,510 | |||||||||||
|
Miscellaneous - net
|
539 | 4,376 | (112 | ) | 4,802 | |||||||||||
|
Total
|
(12,213 | ) | (1,547 | ) | 1,762 | (11,999 | ) | |||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
12,633 | (3,687 | ) | 5,314 | 14,260 | |||||||||||
|
Allowance for borrowed funds used during construction
|
9,445 | - | - | 9,445 | ||||||||||||
|
Total
|
22,078 | (3,687 | ) | 5,314 | 23,705 | |||||||||||
|
INCOME BEFORE INCOME TAXES
|
182,353 | (57,157 | ) | (8,427 | ) | 116,769 | ||||||||||
|
Income taxes
|
177,903 | (76,395 | ) | 2,554 | 104,062 | |||||||||||
|
CONSOLIDATED NET INCOME
|
4,450 | 19,238 | (10,981 | ) | 12,707 | |||||||||||
|
Preferred dividend requirements of subsidiaries
|
- | - | (1,861 | ) | (1,861 | ) | ||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 4,450 | $ | 19,238 | $ | (9,120 | ) | $ | 14,568 | |||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 0.01 | $ | 0.10 | $ | (0.05 | ) | $ | 0.06 | |||||||
|
DILUTED
|
$ | 0.01 | $ | 0.10 | $ | (0.05 | ) | $ | 0.06 | |||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Twelve Months Ended September 30, 2013
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 8,666,541 | $ | - | $ | (4,354 | ) | $ | 8,662,187 | |||||||
|
Natural gas
|
150,707 | - | - | 150,707 | ||||||||||||
|
Competitive businesses
|
- | 2,342,112 | (19,707 | ) | 2,322,406 | |||||||||||
|
Total
|
8,817,248 | 2,342,112 | (24,061 | ) | 11,135,300 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
1,880,836 | 403,742 | (1,813 | ) | 2,282,765 | |||||||||||
|
Purchased power
|
1,475,609 | 105,167 | (40,375 | ) | 1,540,401 | |||||||||||
|
Nuclear refueling outage expenses
|
120,691 | 132,561 | - | 253,252 | ||||||||||||
|
Asset impairment and related charges
|
- | 291,505 | - | 291,505 | ||||||||||||
|
Other operation and maintenance
|
2,225,169 | 979,490 | 18,776 | 3,223,436 | ||||||||||||
|
Decommissioning
|
115,015 | 122,447 | - | 237,461 | ||||||||||||
|
Taxes other than income taxes
|
453,668 | 130,842 | 1,393 | 585,903 | ||||||||||||
|
Depreciation and amortization
|
1,025,166 | 201,990 | 4,258 | 1,231,413 | ||||||||||||
|
Other regulatory charges (credits) - net
|
35,509 | - | - | 35,509 | ||||||||||||
|
Total
|
7,331,663 | 2,367,744 | (17,761 | ) | 9,681,645 | |||||||||||
|
OPERATING INCOME
|
1,485,585 | (25,632 | ) | (6,300 | ) | 1,453,655 | ||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
68,449 | - | - | 68,449 | ||||||||||||
|
Interest and investment income
|
161,851 | 99,138 | (53,111 | ) | 207,877 | |||||||||||
|
Miscellaneous - net
|
(25,305 | ) | (14,697 | ) | (8,411 | ) | (48,414 | ) | ||||||||
|
Total
|
204,995 | 84,441 | (61,522 | ) | 227,912 | |||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
526,431 | 14,211 | 152,806 | 693,448 | ||||||||||||
|
Allowance for borrowed funds used during construction
|
(27,867 | ) | - | - | (27,867 | ) | ||||||||||
|
Total
|
498,564 | 14,211 | 152,806 | 665,581 | ||||||||||||
|
INCOME BEFORE INCOME TAXES
|
1,192,016 | 44,598 | (220,628 | ) | 1,015,986 | |||||||||||
|
Income taxes
|
227,244 | (15,067 | ) | (77,261 | ) | 134,916 | ||||||||||
|
CONSOLIDATED NET INCOME
|
964,772 | 59,665 | (143,367 | ) | 881,070 | |||||||||||
|
Preferred dividend requirements of subsidiaries
|
17,329 | - | 2,500 | 19,829 | ||||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 947,443 | $ | 59,665 | $ | (145,867 | ) | $ | 861,241 | |||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 5.32 | $ | 0.34 | $ | (0.82 | ) | $ | 4.84 | |||||||
|
DILUTED
|
$ | 5.31 | $ | 0.34 | $ | (0.82 | ) | $ | 4.83 | |||||||
|
AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
|
||||||||||||||||
|
BASIC
|
178,062,568 | |||||||||||||||
|
DILUTED
|
178,469,482 | |||||||||||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Twelve Months Ended September 30, 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 7,905,395 | $ | - | $ | (3,664 | ) | $ | 7,901,731 | |||||||
|
Natural gas
|
132,809 | - | - | 132,809 | ||||||||||||
|
Competitive businesses
|
- | 2,349,108 | (28,796 | ) | 2,320,312 | |||||||||||
|
Total
|
8,038,204 | 2,349,108 | (32,460 | ) | 10,354,852 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
1,793,612 | 352,070 | (1,711 | ) | 2,143,971 | |||||||||||
|
Purchased power
|
1,182,903 | 102,095 | (42,395 | ) | 1,242,603 | |||||||||||
|
Nuclear refueling outage expenses
|
108,081 | 140,308 | - | 248,389 | ||||||||||||
|
Asset impairment and related charges
|
- | 355,524 | - | 355,524 | ||||||||||||
|
Other operation and maintenance
|
2,070,878 | 962,090 | 17,484 | 3,050,452 | ||||||||||||
|
Decommissioning
|
112,352 | 37,654 | - | 150,006 | ||||||||||||
|
Taxes other than income taxes
|
435,303 | 117,262 | 1,297 | 553,862 | ||||||||||||
|
Depreciation and amortization
|
946,514 | 175,264 | 4,464 | 1,126,242 | ||||||||||||
|
Other regulatory charges (credits) - net
|
164,129 | - | - | 164,129 | ||||||||||||
|
Total
|
6,813,772 | 2,242,267 | (20,861 | ) | 9,035,178 | |||||||||||
|
OPERATING INCOME
|
1,224,432 | 106,841 | (11,599 | ) | 1,319,674 | |||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
95,733 | - | - | 95,733 | ||||||||||||
|
Interest and investment income
|
150,381 | 106,444 | (128,969 | ) | 127,856 | |||||||||||
|
Miscellaneous - net
|
(27,347 | ) | (25,084 | ) | (8,136 | ) | (60,567 | ) | ||||||||
|
Total
|
218,767 | 81,360 | (137,105 | ) | 163,022 | |||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
511,659 | 20,714 | 61,825 | 594,198 | ||||||||||||
|
Allowance for borrowed funds used during construction
|
(38,373 | ) | - | - | (38,373 | ) | ||||||||||
|
Total
|
473,286 | 20,714 | 61,825 | 555,825 | ||||||||||||
|
INCOME BEFORE INCOME TAXES
|
969,913 | 167,487 | (210,529 | ) | 926,871 | |||||||||||
|
Income taxes
|
119,657 | 29,666 | 51,008 | 200,331 | ||||||||||||
|
CONSOLIDATED NET INCOME
|
850,256 | 137,821 | (261,537 | ) | 726,540 | |||||||||||
|
Preferred dividend requirements of subsidiaries
|
17,329 | 1,196 | 3,470 | 21,995 | ||||||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 832,927 | $ | 136,625 | $ | (265,007 | ) | $ | 704,545 | |||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 4.71 | $ | 0.77 | $ | (1.50 | ) | $ | 3.98 | |||||||
|
DILUTED
|
$ | 4.69 | $ | 0.77 | $ | (1.49 | ) | $ | 3.97 | |||||||
|
AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
|
||||||||||||||||
|
BASIC
|
176,927,393 | |||||||||||||||
|
DILUTED
|
177,560,181 | |||||||||||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||||||
|
Consolidating Income Statement
|
||||||||||||||||
|
Twelve Months Ended September 30, 2013 vs. 2012
|
||||||||||||||||
|
(Dollars in thousands)
|
||||||||||||||||
|
(Unaudited)
|
||||||||||||||||
|
Utility
|
Entergy Wholesale Commodities
|
Parent & Other
|
Consolidated
|
|||||||||||||
|
OPERATING REVENUES
|
||||||||||||||||
|
Electric
|
$ | 761,146 | $ | - | $ | (690 | ) | $ | 760,456 | |||||||
|
Natural gas
|
17,898 | - | - | 17,898 | ||||||||||||
|
Competitive businesses
|
- | (6,996 | ) | 9,089 | 2,094 | |||||||||||
|
Total
|
779,044 | (6,996 | ) | 8,399 | 780,448 | |||||||||||
|
OPERATING EXPENSES
|
||||||||||||||||
|
Operating and Maintenance:
|
||||||||||||||||
|
Fuel, fuel related expenses, and gas purchased for resale
|
87,224 | 51,672 | (102 | ) | 138,794 | |||||||||||
|
Purchased power
|
292,706 | 3,072 | 2,020 | 297,798 | ||||||||||||
|
Nuclear refueling outage expenses
|
12,610 | (7,747 | ) | - | 4,863 | |||||||||||
|
Asset impairment and related charges
|
- | (64,019 | ) | - | (64,019 | ) | ||||||||||
|
Other operation and maintenance
|
154,291 | 17,400 | 1,292 | 172,984 | ||||||||||||
|
Decommissioning
|
2,663 | 84,793 | - | 87,455 | ||||||||||||
|
Taxes other than income taxes
|
18,365 | 13,580 | 96 | 32,041 | ||||||||||||
|
Depreciation and amortization
|
78,652 | 26,726 | (206 | ) | 105,171 | |||||||||||
|
Other regulatory charges (credits )- net
|
(128,620 | ) | - | - | (128,620 | ) | ||||||||||
|
Total
|
517,891 | 125,477 | 3,100 | 646,467 | ||||||||||||
|
OPERATING INCOME
|
261,153 | (132,473 | ) | 5,299 | 133,981 | |||||||||||
|
OTHER INCOME (DEDUCTIONS)
|
||||||||||||||||
|
Allowance for equity funds used during construction
|
(27,284 | ) | - | - | (27,284 | ) | ||||||||||
|
Interest and investment income
|
11,470 | (7,306 | ) | 75,858 | 80,021 | |||||||||||
|
Miscellaneous - net
|
2,042 | 10,387 | (275 | ) | 12,153 | |||||||||||
|
Total
|
(13,772 | ) | 3,081 | 75,583 | 64,890 | |||||||||||
|
INTEREST EXPENSE
|
||||||||||||||||
|
Interest expense
|
14,772 | (6,503 | ) | 90,981 | 99,250 | |||||||||||
|
Allowance for borrowed funds used during construction
|
10,506 | - | - | 10,506 | ||||||||||||
|
Total
|
25,278 | (6,503 | ) | 90,981 | 109,756 | |||||||||||
|
INCOME BEFORE INCOME TAXES
|
222,103 | (122,889 | ) | (10,099 | ) | 89,115 | ||||||||||
|
Income taxes
|
107,587 | (44,733 | ) | (128,269 | ) | (65,415 | ) | |||||||||
|
CONSOLIDATED NET INCOME
|
114,516 | (78,156 | ) | 118,170 | 154,530 | |||||||||||
|
Preferred dividend requirements of subsidiaries
|
- | (1,196 | ) | (970 | ) | (2,166 | ) | |||||||||
|
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
|
$ | 114,516 | $ | (76,960 | ) | $ | 119,140 | $ | 156,696 | |||||||
|
EARNINGS PER AVERAGE COMMON SHARE:
|
||||||||||||||||
|
BASIC
|
$ | 0.61 | $ | (0.43 | ) | $ | 0.68 | $ | 0.86 | |||||||
|
DILUTED
|
$ | 0.62 | $ | (0.43 | ) | $ | 0.67 | $ | 0.86 | |||||||
|
*Totals may not foot due to rounding.
|
||||||||||||||||
|
Entergy Corporation
|
||||||||||||
|
Consolidated Cash Flow Statement
|
||||||||||||
|
Three Months Ended September 30, 2013 vs. 2012
|
||||||||||||
|
(Dollars in thousands)
|
||||||||||||
|
(Unaudited)
|
||||||||||||
|
2013
|
2012
|
Variance
|
||||||||||
|
OPERATING ACTIVITIES
|
||||||||||||
|
Consolidated net income
|
$ | 244,182 | $ | 342,670 | $ | (98,488 | ) | |||||
|
Adjustments to reconcile consolidated net income to net cash
|
||||||||||||
|
flow provided by operating activities:
|
||||||||||||
|
Depreciation, amortization, and decommissioning, including nuclear fuel amortization
|
524,035 | 461,005 | 63,030 | |||||||||
|
Deferred income taxes, investment tax credits, and non-current taxes accrued
|
11,863 | 233,885 | (222,022 | ) | ||||||||
|
Asset impairment and related charges
|
291,505 | - | 291,505 | |||||||||
|
Changes in working capital:
|
||||||||||||
|
Receivables
|
(55,597 | ) | (109,830 | ) | 54,233 | |||||||
|
Fuel inventory
|
10,231 | 10,159 | 72 | |||||||||
|
Accounts payable
|
(232,619 | ) | 135,257 | (367,876 | ) | |||||||
|
Prepaid taxes and taxes accrued
|
52,026 | 57,071 | (5,045 | ) | ||||||||
|
Interest accrued
|
(22,414 | ) | (17,774 | ) | (4,640 | ) | ||||||
|
Deferred fuel
|
58,002 | (46,101 | ) | 104,103 | ||||||||
|
Other working capital accounts
|
52,260 | (22,933 | ) | 75,193 | ||||||||
|
Changes in provisions for estimated losses
|
2,783 | 1,788 | 995 | |||||||||
|
Changes in other regulatory assets
|
(43,495 | ) | (64,395 | ) | 20,900 | |||||||
|
Changes in pensions and other postretirement liabilities
|
(73,769 | ) | (40,563 | ) | (33,206 | ) | ||||||
|
Other
|
264,561 | 91,630 | 172,931 | |||||||||
|
Net cash flow provided by operating activities
|
1,083,554 | 1,031,869 | 51,685 | |||||||||
|
INVESTING ACTIVITIES
|
||||||||||||
|
Construction/capital expenditures
|
(536,349 | ) | (606,180 | ) | 69,831 | |||||||
|
Allowance for equity funds used during construction
|
18,434 | 19,080 | (646 | ) | ||||||||
|
Nuclear fuel purchases
|
(188,947 | ) | (172,108 | ) | (16,839 | ) | ||||||
|
Changes in transition charge account
|
(12,820 | ) | (14,912 | ) | 2,092 | |||||||
|
Payments to storm reserve escrow account
|
(2,027 | ) | (4,022 | ) | 1,995 | |||||||
|
Receipts from storm reserve escrow account
|
49 | - | 49 | |||||||||
|
Decrease (increase) in other investments
|
(14,761 | ) | (107,071 | ) | 92,310 | |||||||
|
Litigation proceeds for reimbursement of spent nuclear fuel storage costs
|
10,271 | 98,872 | (88,601 | ) | ||||||||
|
Proceeds from nuclear decommissioning trust fund sales
|
284,005 | 471,864 | (187,859 | ) | ||||||||
|
Investment in nuclear decommissioning trust funds
|
(310,457 | ) | (508,544 | ) | 198,087 | |||||||
|
Net cash flow used in investing activities
|
(752,602 | ) | (823,021 | ) | 70,419 | |||||||
|
FINANCING ACTIVITIES
|
||||||||||||
|
Proceeds from the issuance of:
|
||||||||||||
|
Long-term debt
|
952,131 | 964,332 | (12,201 | ) | ||||||||
|
Treasury stock
|
4,086 | 21,974 | (17,888 | ) | ||||||||
|
Retirement of long-term debt
|
(1,096,115 | ) | (829,090 | ) | (267,025 | ) | ||||||
|
Changes in credit borrowings and commercial paper - net
|
15,919 | 252,460 | (236,541 | ) | ||||||||
|
Dividends paid:
|
||||||||||||
|
Common stock
|
(147,977 | ) | (147,551 | ) | (426 | ) | ||||||
|
Preferred stock
|
(4,332 | ) | (4,332 | ) | - | |||||||
|
Net cash flow provided by (used in) financing activities
|
(276,288 | ) | 257,793 | (534,081 | ) | |||||||
|
Effect of exchange rates on cash and cash equivalents
|
(704 | ) | (315 | ) | (389 | ) | ||||||
|
Net increase (decrease) in cash and cash equivalents
|
53,960 | 466,326 | (412,366 | ) | ||||||||
|
Cash and cash equivalents at beginning of period
|
311,372 | 283,393 | 27,979 | |||||||||
|
Cash and cash equivalents at end of period
|
$ | 365,332 | $ | 749,719 | $ | (384,387 | ) | |||||
|
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
|
||||||||||||
|
Cash paid (received) during the period for:
|
||||||||||||
|
Interest - net of amount capitalized
|
$ | 173,884 | $ | 168,525 | $ | 5,359 | ||||||
|
Income taxes
|
$ | 18,895 | $ | 22 | $ | 18,873 | ||||||
|
Entergy Corporation
|
||||||||||||
|
Consolidated Cash Flow Statement
|
||||||||||||
|
Nine Months Ended September 30, 2013 vs. 2012
|
||||||||||||
|
(Dollars in thousands)
|
||||||||||||
|
(Unaudited)
|
||||||||||||
|
2013
|
2012
|
Variance
|
||||||||||
|
OPERATING ACTIVITIES
|
||||||||||||
|
Consolidated net income
|
$ | 579,220 | $ | 566,513 | $ | 12,707 | ||||||
|
Adjustments to reconcile consolidated net income to net cash
|
||||||||||||
|
flow provided by operating activities:
|
||||||||||||
|
Depreciation, amortization, and decommissioning, including nuclear fuel amortization
|
1,472,985 | 1,293,667 | 179,318 | |||||||||
|
Deferred income taxes, investment tax credits, and non-current taxes accrued
|
174,052 | 111,228 | 62,824 | |||||||||
|
Asset impairment and related charges
|
291,505 | 355,524 | (64,019 | ) | ||||||||
|
Changes in working capital:
|
||||||||||||
|
Receivables
|
(273,876 | ) | (162,015 | ) | (111,861 | ) | ||||||
|
Fuel inventory
|
16,421 | (9,063 | ) | 25,484 | ||||||||
|
Accounts payable
|
(80,626 | ) | 143,596 | (224,222 | ) | |||||||
|
Prepaid taxes and taxes accrued
|
(6,150 | ) | 44,625 | (50,775 | ) | |||||||
|
Interest accrued
|
(25,586 | ) | (24,752 | ) | (834 | ) | ||||||
|
Deferred fuel
|
(43,419 | ) | (40,192 | ) | (3,227 | ) | ||||||
|
Other working capital accounts
|
(81,315 | ) | (131,374 | ) | 50,059 | |||||||
|
Changes in provisions for estimated losses
|
(247,560 | ) | (17,479 | ) | (230,081 | ) | ||||||
|
Changes in other regulatory assets
|
173,164 | 49,250 | 123,914 | |||||||||
|
Changes in pensions and other postretirement liabilities
|
(48,814 | ) | (75,104 | ) | 26,290 | |||||||
|
Other
|
299,458 | 115,364 | 184,094 | |||||||||
|
Net cash flow provided by operating activities
|
2,199,459 | 2,219,788 | (20,329 | ) | ||||||||
|
INVESTING ACTIVITIES
|
||||||||||||
|
Construction/capital expenditures
|
(1,781,208 | ) | (1,868,690 | ) | 87,482 | |||||||
|
Allowance for equity funds used during construction
|
49,411 | 73,497 | (24,086 | ) | ||||||||
|
Nuclear fuel purchases
|
(398,456 | ) | (412,912 | ) | 14,456 | |||||||
|
Payment for purchase of plant
|
- | (645 | ) | 645 | ||||||||
|
Changes in transition charge account
|
(3,702 | ) | (2,036 | ) | (1,666 | ) | ||||||
|
NYPA value sharing payment
|
(71,736 | ) | (72,000 | ) | 264 | |||||||
|
Payments to storm reserve escrow account
|
(5,882 | ) | (7,009 | ) | 1,127 | |||||||
|
Receipts from storm reserve escrow account
|
260,279 | 17,884 | 242,395 | |||||||||
|
Decrease (increase) in other investments
|
(43,656 | ) | (69,995 | ) | 26,339 | |||||||
|
Litigation proceeds for reimbursement of spent nuclear fuel storage costs
|
21,034 | 109,105 | (88,071 | ) | ||||||||
|
Proceeds from nuclear decommissioning trust fund sales
|
1,063,711 | 1,416,697 | (352,986 | ) | ||||||||
|
Investment in nuclear decommissioning trust funds
|
(1,147,571 | ) | (1,507,123 | ) | 359,552 | |||||||
|
Net cash flow used in investing activities
|
(2,057,776 | ) | (2,323,227 | ) | 265,451 | |||||||
|
FINANCING ACTIVITIES
|
||||||||||||
|
Proceeds from the issuance of:
|
||||||||||||
|
Long-term debt
|
2,925,997 | 2,289,494 | 636,503 | |||||||||
|
Mandatorily redeemable preferred membership units of subsidiary
|
- | 51,000 | (51,000 | ) | ||||||||
|
Treasury stock
|
20,720 | 56,602 | (35,882 | ) | ||||||||
|
Retirement of long-term debt
|
(3,106,226 | ) | (2,029,016 | ) | (1,077,210 | ) | ||||||
|
Changes in credit borrowings and commercial paper - net
|
310,042 | 247,845 | 62,197 | |||||||||
|
Dividends paid:
|
||||||||||||
|
Common stock
|
(445,031 | ) | (441,292 | ) | (3,739 | ) | ||||||
|
Preferred stock
|
(14,469 | ) | (15,497 | ) | 1,028 | |||||||
|
Net cash flow provided by (used in) financing activities
|
(308,967 | ) | 159,136 | (468,103 | ) | |||||||
|
Effect of exchange rates on cash and cash equivalents
|
47 | (416 | ) | 463 | ||||||||
|
Net increase (decrease) in cash and cash equivalents
|
(167,237 | ) | 55,281 | (222,518 | ) | |||||||
|
Cash and cash equivalents at beginning of period
|
532,569 | 694,438 | (161,869 | ) | ||||||||
|
Cash and cash equivalents at end of period
|
$ | 365,332 | $ | 749,719 | $ | (384,387 | ) | |||||
|
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
|
||||||||||||
|
Cash paid (received) during the period for:
|
||||||||||||
|
Interest - net of amount capitalized
|
$ | 435,161 | $ | 422,142 | $ | 13,019 | ||||||
|
Income taxes
|
$ | 107,560 | $ | 42,472 | $ | 65,088 | ||||||
|
Entergy Corporation
|
||||||||||||
|
Consolidated Cash Flow Statement
|
||||||||||||
|
Twelve Months Ended September 30, 2013 vs. 2012
|
||||||||||||
|
(Dollars in thousands)
|
||||||||||||
|
(Unaudited)
|
||||||||||||
|
2013
|
2012
|
Variance
|
||||||||||
|
OPERATING ACTIVITIES
|
||||||||||||
|
Consolidated net income
|
$ | 881,070 | $ | 726,540 | $ | 154,530 | ||||||
|
Adjustments to reconcile consolidated net income to net cash flow
|
||||||||||||
|
provided by operating activities:
|
||||||||||||
|
Depreciation, amortization, and decommissioning, including nuclear fuel amortization
|
1,950,967 | 1,723,392 | 227,575 | |||||||||
|
Deferred income taxes, investment tax credits, and non-current taxes accrued
|
36,345 | (162,822 | ) | 199,167 | ||||||||
|
Asset impairment and related charges
|
291,505 | 355,524 | (64,019 | ) | ||||||||
|
Changes in working capital:
|
||||||||||||
|
Receivables
|
(126,063 | ) | 79,600 | (205,663 | ) | |||||||
|
Fuel inventory
|
13,880 | (16,347 | ) | 30,227 | ||||||||
|
Accounts payable
|
(231,001 | ) | 250,505 | (481,506 | ) | |||||||
|
Prepaid taxes and taxes accrued
|
4,709 | 379,425 | (374,716 | ) | ||||||||
|
Interest accrued
|
318 | (5,617 | ) | 5,935 | ||||||||
|
Deferred fuel
|
(103,214 | ) | 23,603 | (126,817 | ) | |||||||
|
Other working capital accounts
|
(101,930 | ) | (58,180 | ) | (43,750 | ) | ||||||
|
Changes in provisions for estimated losses
|
(254,889 | ) | (23,957 | ) | (230,932 | ) | ||||||
|
Changes in other regulatory assets
|
(274,514 | ) | (874,741 | ) | 600,227 | |||||||
|
Changes in pensions and other postretirement liabilities
|
670,389 | 1,163,047 | (492,658 | ) | ||||||||
|
Other
|
162,384 | (341,123 | ) | 503,507 | ||||||||
|
Net cash flow provided by operating activities
|
2,919,956 | 3,218,849 | (298,893 | ) | ||||||||
|
INVESTING ACTIVITIES
|
||||||||||||
|
Construction/capital expenditures
|
(2,587,168 | ) | (2,448,049 | ) | (139,119 | ) | ||||||
|
Allowance for equity funds used during construction
|
72,045 | 98,653 | (26,608 | ) | ||||||||
|
Nuclear fuel purchases
|
(543,504 | ) | (578,987 | ) | 35,483 | |||||||
|
Payment for purchase of plant
|
(455,711 | ) | (347,192 | ) | (108,519 | ) | ||||||
|
Changes in securitization account
|
2,599 | (8,853 | ) | 11,452 | ||||||||
|
NYPA value sharing payment
|
(71,736 | ) | (72,000 | ) | 264 | |||||||
|
Payments to storm reserve escrow account
|
(7,830 | ) | (8,391 | ) | 561 | |||||||
|
Receipts from storm reserve escrow account
|
270,279 | 17,884 | 252,395 | |||||||||
|
Decrease (increase) in other investments
|
41,514 | (20,925 | ) | 62,439 | ||||||||
|
Litigation proceeds for reimbursement of spent nuclear fuel storage costs
|
21,034 | 109,105 | (88,071 | ) | ||||||||
|
Proceeds from nuclear decommissioning trust fund sales
|
1,721,069 | 1,723,954 | (2,885 | ) | ||||||||
|
Investment in nuclear decommissioning trust funds
|
(1,836,937 | ) | (1,839,776 | ) | 2,839 | |||||||
|
Net cash flow used in investing activities
|
(3,374,346 | ) | (3,374,577 | ) | 231 | |||||||
|
FINANCING ACTIVITIES
|
||||||||||||
|
Proceeds from the issuance of:
|
||||||||||||
|
Long-term debt
|
4,114,864 | 3,744,741 | 370,123 | |||||||||
|
Mandatorily redeemable preferred membership units of subsidiary
|
- | 51,000 | (51,000 | ) | ||||||||
|
Common stock and treasury stock
|
27,004 | 69,898 | (42,894 | ) | ||||||||
|
Retirement of long-term debt
|
(4,207,443 | ) | (3,518,987 | ) | (688,456 | ) | ||||||
|
Redemption of subsidiary common and preferred stock
|
- | (30,308 | ) | 30,308 | ||||||||
|
Changes in credit borrowings and commercial paper - net
|
749,872 | 211,308 | 538,564 | |||||||||
|
Dividends paid:
|
||||||||||||
|
Common stock
|
(592,948 | ) | (587,607 | ) | (5,341 | ) | ||||||
|
Preferred stock
|
(21,301 | ) | (21,384 | ) | 83 | |||||||
|
Net cash flow provided by (used in) financing activities
|
70,048 | (81,339 | ) | 151,387 | ||||||||
|
Effect of exchange rates on cash and cash equivalents
|
(45 | ) | (354 | ) | 309 | |||||||
|
Net increase (decrease) in cash and cash equivalents
|
(384,387 | ) | (237,421 | ) | (146,966 | ) | ||||||
|
Cash and cash equivalents at beginning of period
|
749,719 | 987,140 | (237,421 | ) | ||||||||
|
Cash and cash equivalents at end of period
|
$ | 365,332 | $ | 749,719 | $ | (384,387 | ) | |||||
|
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
|
||||||||||||
|
Cash paid (received) during the period for:
|
||||||||||||
|
Interest - net of amount capitalized
|
$ | 559,144 | $ | 540,888 | $ | 18,256 | ||||||
|
Income taxes
|
$ | 114,302 | $ | 40,441 | $ | 73,861 | ||||||