Attached files
| file | filename |
|---|---|
| 8-K - 8-K - EP Energy LLC | a13-24174_18k.htm |
Exhibit 99.1
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|
Financial and Operational Reporting Package Third Quarter 2013 |
EP ENERGY LLC
Financial and Operational Reporting Package
Third Quarter 2013
Table of Contents
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Page |
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|
Notes to Investors |
1 |
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Operating Results |
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Financial Highlights |
2 |
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Statements of Income |
3 |
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Average Daily Volumes, Realized Prices and Adjusted Cash Operating Costs Per Unit |
4 |
|
Derivative Schedule |
5 |
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|
Non-GAAP Reconciliations |
|
|
Pro Forma Consolidated Financial Data |
6-7 |
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Adjusted EBITDAX |
8 |
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Cash Operating Costs and Adjusted Cash Operating Costs |
9 |
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Glossary |
10-11 |
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NOTES TO INVESTORS
Cautionary Statement
This Financial and Operational Reporting Package (“Package”) includes summarized financial and other information about EP Energy LLC (“EP Energy” or the “Company”). The information in this Package is intended to provide highlights and should not be used as a substitute for financial information in EP Energy’s filings with the Securities and Exchange Commission (“SEC”). Readers should refer to those filings. In addition, the glossary contains certain definitions of measures used in this Package and in other presentations we provide. These definitions may not be the same as definitions used by other companies. This Package may contain information that is based on estimates. The Company has made every reasonable effort to ensure that the information and assumptions on which these estimates are based are current, reasonable and complete. Factors that could cause actual results to differ materially from the estimates in this Package are changes in unaudited and/or unreviewed financial information and the effects of any changes in accounting rules and guidance, as well as other factors discussed in EP Energy’s filings with the SEC. The financial data and statistics in this Package for Third Quarter 2013 reflect the operating results of EP Energy through September 30, 2013. Independent auditors have not audited this Package. The Company assumes no obligation to publicly update or revise any information contained herein as a result of new information, future events, or otherwise.
Non-GAAP Financial Measures
The SEC’s Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In this package, these measures may include pro forma financial results, Reported EBITDAX, Adjusted EBITDAX, cash operating costs and adjusted cash operating costs. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP. The required presentations and reconciliations are included in the body of this Package.
EP Energy believes that the non-GAAP financial measures described in the glossary are useful to investors because these measurements are used by many companies in the industry as a measure of operating and financial performance and are commonly employed by financial analysts and others to evaluate the operating and financial performance of the Company and to compare it with the performance of other companies within the industry. These non-GAAP financial measures may not be comparable to similarly titled measures used by other companies and should not be used as a substitute for net income (loss), income (loss) from continuing operations, operating income, operating cash flows or other measures of financial performance presented in accordance with GAAP.
EP ENERGY LLC
FINANCIAL HIGHLIGHTS
(unaudited)
|
|
|
2013 |
|
2012 |
|
Year-to-Date |
| ||||||||||||
|
|
|
Q1 |
|
Q2 |
|
Q3 |
|
Q1 |
|
Q2 |
|
Q3 |
|
Q4 |
|
2013 |
|
2012 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) income from continuing operations ($ in millions) |
|
(132 |
) |
197 |
|
(110 |
) |
100 |
|
40 |
|
(205 |
) |
64 |
|
(45 |
) |
(65 |
) |
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|
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|
|
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Adjusted EBITDAX ($ in millions) |
|
270 |
|
274 |
|
315 |
|
272 |
|
284 |
|
315 |
|
312 |
|
859 |
|
871 |
|
|
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Average Cash Operating Costs ($/Boe) |
|
15.82 |
|
14.10 |
|
14.26 |
|
10.30 |
|
33.14 |
|
14.20 |
|
15.62 |
|
14.71 |
|
19.23 |
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Adjusted Cash Operating Costs ($/Boe) |
|
12.92 |
|
12.66 |
|
12.45 |
|
9.92 |
|
8.73 |
|
9.55 |
|
11.26 |
|
12.67 |
|
9.37 |
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Depreciation, depletion and amortization rate ($/Boe) |
|
16.60 |
|
18.84 |
|
21.15 |
|
14.83 |
|
11.73 |
|
9.71 |
|
12.83 |
|
18.92 |
|
12.03 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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Equivalent Consolidated Sales Volumes (MBoe/d) |
|
83.9 |
|
85.0 |
|
88.2 |
|
87.5 |
|
90.0 |
|
90.2 |
|
87.2 |
|
85.7 |
|
89.2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Consolidated Oil and Condensate Sales Volumes (MBbls/d) |
|
30.8 |
|
34.2 |
|
40.0 |
|
19.8 |
|
20.4 |
|
25.7 |
|
29.3 |
|
35.0 |
|
21.9 |
|
EP ENERGY LLC
STATEMENTS OF INCOME
($ in millions)
(unaudited)
|
|
|
2013 |
|
2012 |
|
Year-to-Date |
| |||||||||||||||||||||
|
|
|
Q1 |
|
Q2 |
|
Q3 |
|
Q1 |
|
Q2 |
|
Q3 |
|
Q4 |
|
2013 |
|
2012 |
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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| |||||||||
|
Operating revenues |
|
|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Oil and condensate |
|
$ |
266 |
|
$ |
292 |
|
$ |
371 |
|
$ |
180 |
|
$ |
165 |
|
$ |
216 |
|
$ |
242 |
|
$ |
929 |
|
$ |
561 |
|
|
Natural gas |
|
82 |
|
99 |
|
78 |
|
94 |
|
76 |
|
96 |
|
100 |
|
259 |
|
266 |
| |||||||||
|
NGL |
|
15 |
|
17 |
|
22 |
|
8 |
|
13 |
|
14 |
|
13 |
|
54 |
|
35 |
| |||||||||
|
Financial derivatives |
|
(131 |
) |
166 |
|
(142 |
) |
76 |
|
346 |
|
(181 |
) |
62 |
|
(107 |
) |
241 |
| |||||||||
|
Total operating revenues |
|
232 |
|
574 |
|
329 |
|
358 |
|
600 |
|
145 |
|
417 |
|
1,135 |
|
1,103 |
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| |||||||||
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Operating expenses |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Natural gas purchases |
|
2 |
|
8 |
|
6 |
|
— |
|
4 |
|
9 |
|
6 |
|
16 |
|
13 |
| |||||||||
|
Transportation costs |
|
22 |
|
24 |
|
24 |
|
13 |
|
22 |
|
21 |
|
21 |
|
70 |
|
56 |
| |||||||||
|
Lease operating expense |
|
38 |
|
40 |
|
41 |
|
27 |
|
25 |
|
28 |
|
33 |
|
119 |
|
80 |
| |||||||||
|
General and administrative expenses |
|
58 |
|
55 |
|
49 |
|
38 |
|
234 |
|
75 |
|
77 |
|
162 |
|
347 |
| |||||||||
|
Depreciation, depletion and amortization (1) |
|
125 |
|
146 |
|
172 |
|
118 |
|
96 |
|
81 |
|
103 |
|
443 |
|
295 |
| |||||||||
|
Impairment and ceiling test charges (1) |
|
— |
|
— |
|
2 |
|
— |
|
1 |
|
— |
|
— |
|
2 |
|
1 |
| |||||||||
|
Exploration expense (1) |
|
13 |
|
14 |
|
12 |
|
— |
|
5 |
|
20 |
|
18 |
|
39 |
|
25 |
| |||||||||
|
Taxes other than income |
|
23 |
|
15 |
|
25 |
|
17 |
|
12 |
|
16 |
|
16 |
|
63 |
|
45 |
| |||||||||
|
Total operating expenses |
|
281 |
|
302 |
|
331 |
|
213 |
|
399 |
|
250 |
|
274 |
|
914 |
|
862 |
| |||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Operating (loss) income |
|
(49 |
) |
272 |
|
(2 |
) |
145 |
|
201 |
|
(105 |
) |
143 |
|
221 |
|
241 |
| |||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Earnings (loss) from unconsolidated affiliates |
|
2 |
|
4 |
|
(19 |
) |
(3 |
) |
(3 |
) |
(2 |
) |
2 |
|
(13 |
) |
(8 |
) | |||||||||
|
Other income (expense) |
|
— |
|
1 |
|
— |
|
— |
|
1 |
|
— |
|
— |
|
1 |
|
1 |
| |||||||||
|
Loss on extinguishment of debt |
|
(1 |
) |
(2 |
) |
(6 |
) |
— |
|
— |
|
(14 |
) |
— |
|
(9 |
) |
(14 |
) | |||||||||
|
Interest expense |
|
(84 |
) |
(78 |
) |
(83 |
) |
(4 |
) |
(63 |
) |
(84 |
) |
(81 |
) |
(245 |
) |
(151 |
) | |||||||||
|
(Loss) income from continuing operations before income taxes |
|
(132 |
) |
197 |
|
(110 |
) |
138 |
|
136 |
|
(205 |
) |
64 |
|
(45 |
) |
69 |
| |||||||||
|
Income tax expense |
|
— |
|
— |
|
— |
|
38 |
|
96 |
|
— |
|
— |
|
— |
|
134 |
| |||||||||
|
(Loss) income from continuing operations |
|
$ |
(132 |
) |
$ |
197 |
|
$ |
(110 |
) |
$ |
100 |
|
$ |
40 |
|
$ |
(205 |
) |
$ |
64 |
|
$ |
(45 |
) |
$ |
(65 |
) |
(1) Reflects the use of the full cost method of accounting for oil and natural gas properties before the acquisition of EP Energy in May 2012 and the use of successful efforts method of accounting after the acquisition.
EP ENERGY LLC
AVERAGE DAILY VOLUMES, REALIZED PRICES AND ADJUSTED CASH OPERATING COSTS PER UNIT
|
|
|
2013 |
|
2012 |
|
Year-to-Date |
| |||||||||||||||||||||
|
|
|
Q1 |
|
Q2 |
|
Q3 |
|
Q1 |
|
Q2 |
|
Q3 |
|
Q4 |
|
2013 |
|
2012 |
| |||||||||
|
Oil and Condensate Sales Volumes (MBbls/d) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Eagle Ford |
|
20.4 |
|
22.2 |
|
26.1 |
|
9.8 |
|
10.9 |
|
15.7 |
|
18.5 |
|
22.9 |
|
12.1 |
| |||||||||
|
Wolfcamp |
|
1.5 |
|
2.9 |
|
4.3 |
|
1.1 |
|
1.2 |
|
1.4 |
|
1.6 |
|
2.9 |
|
1.2 |
| |||||||||
|
Altamont |
|
7.9 |
|
8.3 |
|
8.9 |
|
7.6 |
|
7.1 |
|
7.4 |
|
8.1 |
|
8.4 |
|
7.4 |
| |||||||||
|
Haynesville |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
| |||||||||
|
Other Domestic Consolidated |
|
1.0 |
|
0.8 |
|
0.7 |
|
1.3 |
|
1.2 |
|
1.2 |
|
1.1 |
|
0.8 |
|
1.2 |
| |||||||||
|
Total Domestic Consolidated |
|
30.8 |
|
34.2 |
|
40.0 |
|
19.8 |
|
20.4 |
|
25.7 |
|
29.3 |
|
35.0 |
|
21.9 |
| |||||||||
|
Natural Gas Sales Volumes (MMcf/d) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Eagle Ford |
|
37 |
|
42 |
|
44 |
|
16 |
|
19 |
|
25 |
|
32 |
|
41 |
|
20 |
| |||||||||
|
Wolfcamp |
|
3 |
|
5 |
|
9 |
|
2 |
|
2 |
|
1 |
|
3 |
|
5 |
|
2 |
| |||||||||
|
Altamont |
|
18 |
|
19 |
|
19 |
|
18 |
|
18 |
|
18 |
|
18 |
|
19 |
|
18 |
| |||||||||
|
Haynesville |
|
204 |
|
174 |
|
148 |
|
314 |
|
321 |
|
287 |
|
243 |
|
175 |
|
307 |
| |||||||||
|
Other Domestic Consolidated |
|
26 |
|
24 |
|
23 |
|
42 |
|
39 |
|
31 |
|
26 |
|
24 |
|
37 |
| |||||||||
|
Total Domestic Consolidated |
|
288 |
|
264 |
|
243 |
|
392 |
|
399 |
|
362 |
|
322 |
|
264 |
|
384 |
| |||||||||
|
NGL Sales Volumes (MBbls/d) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Eagle Ford |
|
4.4 |
|
5.8 |
|
6.8 |
|
1.5 |
|
2.2 |
|
3.2 |
|
3.3 |
|
5.7 |
|
2.3 |
| |||||||||
|
Wolfcamp |
|
0.4 |
|
0.7 |
|
0.6 |
|
— |
|
0.2 |
|
0.6 |
|
0.5 |
|
0.6 |
|
0.3 |
| |||||||||
|
Altamont |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
| |||||||||
|
Haynesville |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
|
— |
| |||||||||
|
Other Domestic |
|
0.4 |
|
0.3 |
|
0.3 |
|
0.9 |
|
0.8 |
|
0.5 |
|
0.4 |
|
0.3 |
|
0.7 |
| |||||||||
|
Total Domestic Consolidated |
|
5.2 |
|
6.8 |
|
7.7 |
|
2.4 |
|
3.2 |
|
4.3 |
|
4.2 |
|
6.6 |
|
3.3 |
| |||||||||
|
Equivalent Sales Volumes (MBoe/d) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Eagle Ford |
|
31.0 |
|
34.9 |
|
40.2 |
|
14.1 |
|
16.3 |
|
23.0 |
|
27.0 |
|
35.4 |
|
17.8 |
| |||||||||
|
Wolfcamp |
|
2.4 |
|
4.4 |
|
6.4 |
|
1.5 |
|
1.7 |
|
2.2 |
|
2.5 |
|
4.4 |
|
1.8 |
| |||||||||
|
Altamont |
|
11.0 |
|
11.4 |
|
12.1 |
|
10.7 |
|
10.0 |
|
10.4 |
|
11.2 |
|
11.5 |
|
10.4 |
| |||||||||
|
Haynesville |
|
34.0 |
|
29.0 |
|
24.7 |
|
52.2 |
|
53.4 |
|
47.8 |
|
40.5 |
|
29.2 |
|
51.1 |
| |||||||||
|
Other Domestic Consolidated |
|
5.5 |
|
5.3 |
|
4.8 |
|
9.0 |
|
8.6 |
|
6.8 |
|
6.0 |
|
5.2 |
|
8.1 |
| |||||||||
|
Total Domestic Consolidated |
|
83.9 |
|
85.0 |
|
88.2 |
|
87.5 |
|
90.0 |
|
90.2 |
|
87.2 |
|
85.7 |
|
89.2 |
| |||||||||
|
Average realized prices (1) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Oil and condensate price on physical sales ($/Bbl) |
|
$ |
96.02 |
|
$ |
93.72 |
|
$ |
100.84 |
|
$ |
99.97 |
|
$ |
89.78 |
|
$ |
90.44 |
|
$ |
89.72 |
|
$ |
97.13 |
|
$ |
93.05 |
|
|
Natural gas price on physical sales ($/Mcf) |
|
$ |
3.11 |
|
$ |
3.76 |
|
$ |
3.22 |
|
$ |
2.64 |
|
$ |
2.00 |
|
$ |
2.60 |
|
$ |
3.13 |
|
$ |
3.36 |
|
$ |
2.41 |
|
|
NGL price on physical sales ($/Bbl) |
|
$ |
31.57 |
|
$ |
26.46 |
|
$ |
31.39 |
|
$ |
36.99 |
|
$ |
42.28 |
|
$ |
34.78 |
|
$ |
34.73 |
|
$ |
29.74 |
|
$ |
37.87 |
|
|
Average transportation costs (1) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Oil and condensate ($/Bbl) |
|
$ |
2.03 |
|
$ |
2.11 |
|
$ |
1.97 |
|
$ |
1.26 |
|
$ |
1.50 |
|
$ |
2.78 |
|
$ |
2.13 |
|
$ |
2.03 |
|
$ |
1.93 |
|
|
Natural gas ($/Mcf) |
|
$ |
0.56 |
|
$ |
0.56 |
|
$ |
0.52 |
|
$ |
0.27 |
|
$ |
0.49 |
|
$ |
0.38 |
|
$ |
0.49 |
|
$ |
0.54 |
|
$ |
0.38 |
|
|
NGL ($/Bbl) |
|
$ |
3.81 |
|
$ |
6.14 |
|
$ |
7.64 |
|
$ |
4.02 |
|
$ |
7.28 |
|
$ |
2.48 |
|
$ |
3.47 |
|
$ |
6.11 |
|
$ |
4.41 |
|
|
Average cash operating costs and adjusted cash operating costs ($/Boe) (1) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Lease operating expenses |
|
$ |
5.07 |
|
$ |
5.15 |
|
$ |
5.12 |
|
$ |
3.47 |
|
$ |
3.07 |
|
$ |
3.30 |
|
$ |
4.03 |
|
$ |
5.11 |
|
$ |
3.27 |
|
|
Production taxes |
|
2.79 |
|
3.23 |
|
2.92 |
|
1.90 |
|
2.19 |
|
2.07 |
|
1.90 |
|
2.98 |
|
2.04 |
| |||||||||
|
General and administrative expenses |
|
7.67 |
|
7.10 |
|
6.04 |
|
4.78 |
|
28.57 |
|
8.89 |
|
9.53 |
|
6.92 |
|
14.15 |
| |||||||||
|
Taxes other than production and income taxes |
|
0.29 |
|
(1.38 |
) |
0.18 |
|
0.15 |
|
(0.69 |
) |
(0.06 |
) |
0.16 |
|
(0.30 |
) |
(0.23 |
) | |||||||||
|
Total cash operating costs |
|
$ |
15.82 |
|
$ |
14.10 |
|
$ |
14.26 |
|
$ |
10.30 |
|
$ |
33.14 |
|
$ |
14.20 |
|
$ |
15.62 |
|
$ |
14.71 |
|
$ |
19.23 |
|
|
Transition/restructuring costs and non-cash compensation expense (2) |
|
(2.90 |
) |
(1.44 |
) |
(1.81 |
) |
(0.38 |
) |
(24.41 |
) |
(4.65 |
) |
(4.36 |
) |
(2.04 |
) |
(9.86 |
) | |||||||||
|
Total adjusted cash operating costs |
|
$ |
12.92 |
|
$ |
12.66 |
|
$ |
12.45 |
|
$ |
9.92 |
|
$ |
8.73 |
|
$ |
9.55 |
|
$ |
11.26 |
|
$ |
12.67 |
|
$ |
9.37 |
|
|
Depreciation, depletion and amortization rate ($/Boe) (1) |
|
$ |
16.60 |
|
$ |
18.84 |
|
$ |
21.15 |
|
$ |
14.83 |
|
$ |
11.73 |
|
$ |
9.71 |
|
$ |
12.83 |
|
$ |
18.92 |
|
$ |
12.03 |
|
(1) Prices and costs per unit are calculated using consolidated volumes from continuing activities only and exclude divested assets.
(2) A detail of these expenses is included in the reconciliation of Adjusted EBITDAX on page 8.
EP ENERGY LLC
DERIVATIVE SCHEDULE AS OF SEPTEMBER 30, 2013
|
|
|
2013 |
|
2014 |
|
2015 |
|
2016 |
| ||||||||||||
|
Crude Oil |
|
Notional |
|
Average Hedge |
|
Notional |
|
Average |
|
Notional |
|
Average Hedge |
|
Notional Volume |
|
Average |
| ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Fixed Price Swaps (2) |
|
4.37 |
|
$ |
100.08 |
|
15.99 |
|
$ |
98.10 |
|
21.01 |
|
$ |
90.08 |
|
4.48 |
|
$ |
85.46 |
|
|
Collars - Ceiling |
|
0.64 |
|
$ |
97.86 |
|
1.13 |
|
$ |
100.00 |
|
1.10 |
|
$ |
100.00 |
|
— |
|
— |
| |
|
Three-Way Collars - Ceiling |
|
— |
|
— |
|
2.92 |
|
$ |
103.76 |
|
— |
|
— |
|
— |
|
— |
| |||
|
Three-Way Collars - Floor (3) |
|
— |
|
— |
|
2.92 |
|
$ |
95.00 |
|
— |
|
— |
|
— |
|
— |
| |||
|
|
|
2013 |
|
2014 |
|
2015 |
|
2016 |
| ||||||||
|
Basis Swaps - Crude Oil |
|
Notional |
|
Average Hedge |
|
Notional |
|
Average |
|
Notional |
|
Average Hedge |
|
Notional Volume |
|
Average |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basis Swaps (4) |
|
1.01 |
|
Various |
|
5.84 |
|
Various |
|
3.65 |
|
Various |
|
1.83 |
|
Various |
|
|
|
|
2013 |
|
2014 |
|
2015 |
|
2016 |
| |||||||||||
|
Natural Gas |
|
Notional |
|
Average Hedge |
|
Notional |
|
Average |
|
Notional |
|
Average Hedge |
|
Notional Volume |
|
Average |
| |||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||
|
Fixed Price Swaps |
|
20 |
|
$ |
3.25 |
|
63 |
|
$ |
4.02 |
|
44 |
|
$ |
4.28 |
|
— |
|
— |
|
|
Written Calls - Ceiling |
|
— |
|
— |
|
13 |
|
$ |
4.02 |
|
— |
|
— |
|
— |
|
— |
| ||
Note: US Domestic positions are as of September 30, 2013 (Contract Months: October 2013 - Forward).
(1) Volumes presented are TBtu for natural gas and MMBbl for oil. Prices presented are per MMBtu of natural gas and per Bbl of oil.
(2) On 1,564 MBbls, if market prices settle at or below $71.47 in 2013, we will receive a “locked in” cash settlement of the market price plus $24.27 per Bbl.
(3) If market prices settle at or below $75.00, we will receive a “locked-in” cash settlement of the market price plus $20.00 per Bbl.
(4) We use various types of oil basis swaps to lock-in certain crude oil differentials.
EP ENERGY LLC
RECONCILIATION OF PRO FORMA CONSOLIDATED FINANCIAL DATA
($ in millions)
(unaudited)
|
|
|
2012 |
| |||||||||||||||||||
|
|
|
Q1 (1) |
|
Adjustments |
|
Q1 |
|
April 1 to |
|
March 23 |
|
Adjustments |
|
Q2 |
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
Operating revenues |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
Oil and condensate |
|
$ |
198 |
|
$ |
(18 |
) |
$ |
180 |
|
$ |
112 |
|
$ |
66 |
|
$ |
(13 |
) |
$ |
165 |
|
|
Natural gas |
|
160 |
|
(66 |
) |
94 |
|
68 |
|
38 |
|
(30 |
) |
76 |
| |||||||
|
NGL |
|
17 |
|
(9 |
) |
8 |
|
12 |
|
4 |
|
(3 |
) |
13 |
| |||||||
|
Financial derivatives |
|
76 |
|
— |
|
76 |
|
289 |
|
57 |
|
— |
|
346 |
| |||||||
|
Total operating revenues |
|
451 |
|
(93 |
) |
358 |
|
481 |
|
165 |
|
(46 |
) |
600 |
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
Operating expenses |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
Natural gas purchases |
|
— |
|
— |
|
— |
|
— |
|
4 |
|
— |
|
4 |
| |||||||
|
Transportation costs |
|
25 |
|
(12 |
) |
13 |
|
20 |
|
9 |
|
(7 |
) |
22 |
| |||||||
|
Lease operating expense |
|
52 |
|
(25 |
) |
27 |
|
28 |
|
11 |
|
(14 |
) |
25 |
| |||||||
|
General and administrative expenses |
|
40 |
|
(2 |
) |
38 |
|
29 |
|
206 |
|
(1 |
) |
234 |
| |||||||
|
Depreciation, depletion and amortization (2) |
|
193 |
|
(75 |
) |
118 |
|
114 |
|
25 |
|
(43 |
) |
96 |
| |||||||
|
Impairments and ceiling test charges (2) |
|
62 |
|
(62 |
) |
— |
|
— |
|
1 |
|
— |
|
1 |
| |||||||
|
Exploration expense (2) |
|
— |
|
— |
|
— |
|
— |
|
5 |
|
— |
|
5 |
| |||||||
|
Taxes other than income |
|
23 |
|
(6 |
) |
17 |
|
7 |
|
8 |
|
(3 |
) |
12 |
| |||||||
|
Total operating expenses |
|
395 |
|
(182 |
) |
213 |
|
198 |
|
269 |
|
(68 |
) |
399 |
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
Operating (loss) income |
|
56 |
|
89 |
|
145 |
|
283 |
|
(104 |
) |
22 |
|
201 |
| |||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||
|
Loss from unconsolidated affiliates |
|
(3 |
) |
— |
|
(3 |
) |
(2 |
) |
(1 |
) |
— |
|
(3 |
) | |||||||
|
Other income (expense) |
|
— |
|
— |
|
— |
|
1 |
|
— |
|
— |
|
1 |
| |||||||
|
Interest expense |
|
(4 |
) |
— |
|
(4 |
) |
(10 |
) |
(53 |
) |
— |
|
(63 |
) | |||||||
|
Income (loss) from continuing operations before income taxes |
|
49 |
|
89 |
|
138 |
|
272 |
|
(158 |
) |
22 |
|
136 |
| |||||||
|
Income tax expense (3) |
|
38 |
|
— |
|
38 |
|
96 |
|
— |
|
— |
|
96 |
| |||||||
|
Income (loss) from continuing operations |
|
$ |
11 |
|
$ |
89 |
|
$ |
100 |
|
$ |
176 |
|
$ |
(158 |
) |
$ |
22 |
|
$ |
40 |
|
(1) Reflects our GAAP financial information.
(2) Reflects the use of the full cost method of accounting for oil and natural gas properties before the acquisition of EP Energy in May 2012 and the use of successful efforts method of accounting after the acquisition.
(3) Adjustments do not include income tax effects.
EP ENERGY LLC
RECONCILIATION OF PRO FORMA CONSOLIDATED FINANCIAL DATA
($ in millions)
(unaudited)
|
|
|
Year-to-Date 2012 |
| ||||||||||||||||
|
|
|
Q1 (1) |
|
April 1 to |
|
March 23 |
|
Q3 (1) |
|
Adjustments |
|
Pro Forma |
| ||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
|
Operating revenues |
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
|
Oil and condensate |
|
$ |
198 |
|
$ |
112 |
|
$ |
66 |
|
$ |
216 |
|
$ |
(31 |
) |
$ |
561 |
|
|
Natural gas |
|
160 |
|
68 |
|
38 |
|
96 |
|
(96 |
) |
266 |
| ||||||
|
NGL |
|
17 |
|
12 |
|
4 |
|
14 |
|
(12 |
) |
35 |
| ||||||
|
Financial derivatives |
|
76 |
|
289 |
|
57 |
|
(181 |
) |
— |
|
241 |
| ||||||
|
Total operating revenues |
|
451 |
|
481 |
|
165 |
|
145 |
|
(139 |
) |
1,103 |
| ||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
|
Operating expenses |
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
|
Natural gas purchases |
|
— |
|
— |
|
4 |
|
9 |
|
— |
|
13 |
| ||||||
|
Transportation costs |
|
25 |
|
20 |
|
9 |
|
21 |
|
(19 |
) |
56 |
| ||||||
|
Lease operating expense |
|
52 |
|
28 |
|
11 |
|
28 |
|
(39 |
) |
80 |
| ||||||
|
General and administrative expenses |
|
40 |
|
29 |
|
206 |
|
75 |
|
(3 |
) |
347 |
| ||||||
|
Depreciation, depletion and amortization (2) |
|
193 |
|
114 |
|
25 |
|
81 |
|
(118 |
) |
295 |
| ||||||
|
Impairments and ceiling test charges (2) |
|
62 |
|
— |
|
1 |
|
— |
|
(62 |
) |
1 |
| ||||||
|
Exploration expense (2) |
|
— |
|
— |
|
5 |
|
20 |
|
— |
|
25 |
| ||||||
|
Taxes other than income |
|
23 |
|
7 |
|
8 |
|
16 |
|
(9 |
) |
45 |
| ||||||
|
Total operating expenses |
|
395 |
|
198 |
|
269 |
|
250 |
|
(250 |
) |
862 |
| ||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
|
Operating (loss) income |
|
56 |
|
283 |
|
(104 |
) |
(105 |
) |
111 |
|
241 |
| ||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
|
Loss from unconsolidated affiliates |
|
(3 |
) |
(2 |
) |
(1 |
) |
(2 |
) |
— |
|
(8 |
) | ||||||
|
Other income (expense) |
|
— |
|
1 |
|
— |
|
— |
|
— |
|
1 |
| ||||||
|
Loss on extinguishment of debt |
|
— |
|
— |
|
— |
|
(14 |
) |
— |
|
(14 |
) | ||||||
|
Interest expense |
|
(4 |
) |
(10 |
) |
(53 |
) |
(84 |
) |
— |
|
(151 |
) | ||||||
|
Income (loss) from continuing operations before income taxes |
|
49 |
|
272 |
|
(158 |
) |
(205 |
) |
111 |
|
69 |
| ||||||
|
Income tax expense (3) |
|
38 |
|
96 |
|
— |
|
— |
|
— |
|
134 |
| ||||||
|
Income (loss) from continuing operations |
|
$ |
11 |
|
$ |
176 |
|
$ |
(158 |
) |
$ |
(205 |
) |
$ |
111 |
|
$ |
(65 |
) |
(1) Reflects our GAAP financial statements.
(2) Reflects the use of the full cost method of accounting for oil and natural gas properties before the acquisition of EP Energy in May 2012 and the use of successful efforts method of accounting after the acquisition.
(3) Adjustments do not include income tax effects.
EP ENERGY LLC
RECONCILIATION OF ADJUSTED EBITDAX
($ in millions)
(unaudited)
|
|
|
2013 |
|
2012 |
|
Year-to-Date |
| |||||||||||||||||||||
|
|
|
Q1 |
|
Q2 |
|
Q3 |
|
Q1 |
|
Q2 |
|
Q3 |
|
Q4 |
|
2013 |
|
2012 |
| |||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
(Loss) income from continuing operations |
|
$ |
(132 |
) |
$ |
197 |
|
$ |
(110 |
) |
$ |
100 |
|
$ |
40 |
|
$ |
(205 |
) |
$ |
64 |
|
$ |
(45 |
) |
$ |
(65 |
) |
|
Depreciation, depletion and amortization |
|
125 |
|
146 |
|
172 |
|
118 |
|
96 |
|
81 |
|
103 |
|
443 |
|
295 |
| |||||||||
|
Interest expense |
|
84 |
|
78 |
|
83 |
|
4 |
|
63 |
|
84 |
|
81 |
|
245 |
|
151 |
| |||||||||
|
Income tax expense |
|
— |
|
— |
|
— |
|
38 |
|
96 |
|
— |
|
— |
|
— |
|
134 |
| |||||||||
|
Exploration expense |
|
13 |
|
14 |
|
12 |
|
— |
|
5 |
|
20 |
|
18 |
|
39 |
|
25 |
| |||||||||
|
EBITDAX |
|
90 |
|
435 |
|
157 |
|
260 |
|
300 |
|
(20 |
) |
266 |
|
682 |
|
540 |
| |||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Mark to market on financial derivatives |
|
131 |
|
(166 |
) |
142 |
|
(76 |
) |
(346 |
) |
181 |
|
(62 |
) |
107 |
|
(241 |
) | |||||||||
|
Cash settlements and premiums on financial derivatives (1) |
|
28 |
|
(5 |
) |
(26 |
) |
82 |
|
126 |
|
98 |
|
76 |
|
(3 |
) |
306 |
| |||||||||
|
Impairments and ceiling test charges |
|
— |
|
— |
|
2 |
|
— |
|
1 |
|
— |
|
— |
|
2 |
|
1 |
| |||||||||
|
(Income) loss from unconsolidated affiliates |
|
(2 |
) |
(4 |
) |
19 |
|
3 |
|
3 |
|
2 |
|
(2 |
) |
13 |
|
8 |
| |||||||||
|
Non-cash compensation expense |
|
13 |
|
1 |
|
8 |
|
3 |
|
14 |
|
9 |
|
15 |
|
22 |
|
26 |
| |||||||||
|
Transition and restructuring costs |
|
3 |
|
4 |
|
1 |
|
— |
|
183 |
|
25 |
|
12 |
|
8 |
|
208 |
| |||||||||
|
Loss on extinguishment of debt |
|
1 |
|
2 |
|
6 |
|
— |
|
— |
|
14 |
|
— |
|
9 |
|
14 |
| |||||||||
|
Advisory fee |
|
6 |
|
7 |
|
6 |
|
— |
|
3 |
|
6 |
|
7 |
|
19 |
|
9 |
| |||||||||
|
Adjusted EBITDAX |
|
$ |
270 |
|
$ |
274 |
|
$ |
315 |
|
$ |
272 |
|
$ |
284 |
|
$ |
315 |
|
$ |
312 |
|
$ |
859 |
|
$ |
871 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||
|
Adjusted EBITDAX of divested assets |
|
$ |
— |
|
$ |
— |
|
$ |
— |
|
$ |
48 |
|
$ |
21 |
|
$ |
— |
|
$ |
— |
|
$ |
— |
|
$ |
69 |
|
(1) Includes $8 million and $1 million of premiums received in Q1 and Q2 2013, respectively. Includes $4 million of cash premiums paid and $1 million of cash premiums received in Q3 and Q4 2012, respectively.
EP ENERGY LLC
RECONCILIATION OF CASH OPERATING COSTS AND ADJUSTED CASH OPERATING COSTS (1)
(unaudited)
|
|
|
Q1 |
|
Q2 |
|
Q3 |
|
Q4 |
|
Year-to-Date |
| ||||||||||||||||
|
|
|
Total |
|
Per-Unit |
|
Total |
|
Per-Unit |
|
Total |
|
Per-Unit |
|
Total |
|
Per-Unit |
|
Total |
|
Per-Unit |
| ||||||
|
2013 |
|
($ MM) |
|
($/Boe)(2) |
|
($ MM) |
|
($/Boe)(2) |
|
($ MM) |
|
($/Boe)(2) |
|
($ MM) |
|
($/Boe)(2) |
|
($ MM) |
|
($/Boe)(2) |
| ||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
|
Total operating expenses |
|
$ |
281 |
|
$ |
37.23 |
|
$ |
302 |
|
38.95 |
|
$ |
331 |
|
40.93 |
|
|
|
|
|
$ |
914 |
|
$ |
39.08 |
|
|
Depreciation, depletion and amortization |
|
(125 |
) |
(16.60 |
) |
(146 |
) |
(18.84 |
) |
(172 |
) |
(21.15 |
) |
|
|
|
|
(443 |
) |
(18.92 |
) | ||||||
|
Transportation costs |
|
(22 |
) |
(2.87 |
) |
(24 |
) |
(3.09 |
) |
(24 |
) |
(2.97 |
) |
|
|
|
|
(70 |
) |
(2.98 |
) | ||||||
|
Exploration expense |
|
(13 |
) |
(1.74 |
) |
(14 |
) |
(1.81 |
) |
(12 |
) |
(1.51 |
) |
|
|
|
|
(39 |
) |
(1.68 |
) | ||||||
|
Natural gas purchases |
|
(2 |
) |
(0.20 |
) |
(8 |
) |
(1.11 |
) |
(6 |
) |
(0.80 |
) |
|
|
|
|
(16 |
) |
(0.71 |
) | ||||||
|
Impairments |
|
— |
|
— |
|
— |
|
— |
|
(2 |
) |
(0.24 |
) |
|
|
|
|
(2 |
) |
(0.08 |
) | ||||||
|
Total cash operating costs and per-unit cash costs (3) |
|
$ |
119 |
|
$ |
15.82 |
|
$ |
110 |
|
14.10 |
|
$ |
115 |
|
14.26 |
|
|
|
|
|
$ |
344 |
|
$ |
14.71 |
|
|
Transition/restructuring costs and non-cash compensation expense (4) |
|
(22 |
) |
(2.90 |
) |
(12 |
) |
(1.44 |
) |
(14 |
) |
(1.81 |
) |
|
|
|
|
(48 |
) |
(2.04 |
) | ||||||
|
Total adjusted cash operating costs and per-unit adjusted cash costs (3) |
|
$ |
97 |
|
$ |
12.92 |
|
$ |
98 |
|
12.66 |
|
$ |
101 |
|
12.45 |
|
|
|
|
|
$ |
296 |
|
$ |
12.67 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||
|
Total consolidated equivalent volumes (MBoe) |
|
|
|
7,555 |
|
|
|
7,733 |
|
|
|
8,110 |
|
|
|
|
|
|
|
23,398 |
| ||||||
|
|
|
Q1 Pro Forma |
|
Q2 Pro Forma |
|
Q3 |
|
Q4 |
|
Year-to-Date Pro Forma |
| ||||||||||||||||||||
|
|
|
Total |
|
Per-Unit |
|
Total |
|
Per-Unit |
|
Total |
|
Per-Unit |
|
Total |
|
Per-Unit |
|
Total |
|
Per-Unit |
| ||||||||||
|
2012 |
|
($ MM) |
|
($/Boe)(2) |
|
($ MM) |
|
($/Boe)(2) |
|
($ MM) |
|
($/Boe)(2) |
|
($ MM) |
|
($/Boe)(2) |
|
($ MM) |
|
($/Boe)(2) |
| ||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||||||
|
Total operating expenses |
|
$ |
213 |
|
$ |
26.76 |
|
$ |
399 |
|
48.69 |
|
$ |
250 |
|
$ |
29.84 |
|
$ |
274 |
|
$ |
34.12 |
|
$ |
862 |
|
$ |
35.11 |
| |
|
Depreciation, depletion and amortization |
|
(118 |
) |
(14.83 |
) |
(96 |
) |
(11.73 |
) |
(81 |
) |
(9.71 |
) |
(103 |
) |
(12.83 |
) |
(295 |
) |
$ |
(12.03 |
) | |||||||||
|
Transportation costs |
|
(13 |
) |
(1.63 |
) |
(22 |
) |
(2.70 |
) |
(21 |
) |
(2.46 |
) |
(21 |
) |
(2.65 |
) |
(56 |
) |
$ |
(2.29 |
) | |||||||||
|
Exploration expense |
|
— |
|
— |
|
(5 |
) |
(0.62 |
) |
(20 |
) |
(2.42 |
) |
(18 |
) |
(2.25 |
) |
(25 |
) |
$ |
(1.03 |
) | |||||||||
|
Natural gas purchases |
|
— |
|
— |
|
(4 |
) |
(0.50 |
) |
(9 |
) |
(1.05 |
) |
(6 |
) |
(0.77 |
) |
(13 |
) |
$ |
(0.53 |
) | |||||||||
|
Total cash operating costs and per-unit cash costs (3) |
|
$ |
82 |
|
$ |
10.30 |
|
$ |
272 |
|
$ |
33.14 |
|
$ |
119 |
|
$ |
14.20 |
|
$ |
126 |
|
$ |
15.62 |
|
$ |
473 |
|
$ |
19.23 |
|
|
Transition/restructuring costs and non-cash compensation expense (4) |
|
(3 |
) |
(0.38 |
) |
(200 |
) |
(24.41 |
) |
(39 |
) |
(4.65 |
) |
(35 |
) |
(4.36 |
) |
(242 |
) |
(9.86 |
) | ||||||||||
|
Total adjusted cash operating costs and per-unit adjusted cash costs (3) |
|
$ |
79 |
|
$ |
9.92 |
|
$ |
72 |
|
$ |
8.73 |
|
$ |
80 |
|
$ |
9.55 |
|
$ |
91 |
|
$ |
11.26 |
|
$ |
231 |
|
$ |
9.37 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||||||||
|
Total consolidated equivalent volumes (MBoe) |
|
|
|
7,959 |
|
|
|
8,193 |
|
|
|
8,391 |
|
|
|
8,030 |
|
|
|
24,543 |
| ||||||||||
(1) Per unit costs are based on continuing activities only and exclude divested assets.
(2) Per unit costs are based on actual total amounts rather than the rounded totals presented.
(3) Excludes volumes and costs associated with our equity investment in Four Star.
(4) Q3 2013 includes $6 million of advisory fees paid to Sponsors and $8 million of non-cash compensation expense. Q3 2012 included $25 million for transition and restructuring costs associated with the acquisition of EP Energy, $6 million of advisory fees paid to Sponsors and $8 million of non-cash compensation expense. The year-to-date Septemer 30, 2013 includes $7 million for transition and restructuring costs associated with the acquisition of EP Energy, $19 million of advisory fees paid to Sponsors and $22 million of non-cash compensation expense. The year-to-date Septemer 30, 2012 included $208 million for transition and restructuring costs associated with the acquisition of EP Energy, $9 million of advisory fees paid to Sponsors and $25 million of non-cash compensation expense.
GLOSSARY
This contains a glossary of terms used in this Package as well as those used in other investor presentations and press releases. They are for reference only and may not be comparable to similarly titled measures used at other companies.
NON-GAAP FINANCIAL MEASURES
EP Energy LLC (the successor and formerly known as Everest Acquisition LLC) was formed as a Delaware limited liability company on March 23, 2012 by Apollo Global Management LLC (Apollo) and other private equity investors (collectively, the Sponsors). On April 24, 2012, we issued approximately $2.75 billion in private placement notes. Proceeds from these notes, along with other sources, were used by the Sponsors to acquire EP Energy Global LLC (formerly known as EP Energy Corporation and EP Energy, L.L.C. after its conversion into a Delaware limited liability company) and subsidiaries. On May 24, 2012, the Sponsors acquired EP Energy Global LLC for approximately $7.2 billion in cash (the Acquisition).
Pro Forma Financial Results
In July 2013, we entered into a Quota Purchase Agreement to sell our Brazil operations which have been reclassified as discontinued operations in all periods presented. In addition, we previously reclassified our CBM, Arklatex, and south Texas natural gas assets (which were sold during the third quarter of 2013) as discontinued operations only in successor periods subsequent to the Acquisition (May 25, 2012). For periods prior to the Acquisition, the predecessor applied the full cost method of accounting for oil and natural gas properties. Accordingly these domestic assets sold did not qualify for, and have not been reflected as, discontinued operations in the predecessor financial statement periods. To aid in comparability, we are presenting information prior to the Acquisition, referred to as predecessor periods in our GAAP financial statements, on a pro forma basis to exclude the domestic natural gas asset sales, along with certain other sales completed in 2012, namely the sales of our Gulf of Mexico and Egyptian assets.
Reported EBITDAX and Adjusted EBITDAX
Reported EBITDAX is defined as income (loss) from continuing operations plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as Reported EBITDAX, adjusted as applicable in the relevant period, for the net change in the fair value of derivatives (mark to market effects, cash settlements and premiums paid or received related to these derivatives), impairment and/or ceiling test charges, equity earnings from our investment in Four Star (sold in September 2013), non-cash compensation expense, transition and restructuring costs, losses or gains on extinguishment of debt, and advisory fees paid to our sponsors.
We believe that the presentation of Reported EBITDAX and Adjusted EBITDAX is important to provide management and investors with (i) additional information to evaluate our ability to service debt, adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) an important supplemental indicator of the operational performance of our business, (iii) an additional criterion for evaluating our performance relative to our peers, (iv) additional information to measure our liquidity (before cash capital requirements and working capital needs) (v) and supplemental information to investors about certain material non-cash and/or other items that may not continue at the same level in the future.
Reported EBITDAX and Adjusted EBITDAX have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP or as an alternative to net income, income (loss) from continuing operations, operating income, net cash provided by operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. For example, our presentation of Reported EBITDAX and Adjusted EBITDAX may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Reported EBITDAX and Adjusted EBITDAX should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual or non-recurring items or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cash Operating Costs and Adjusted Cash Operating Costs
We monitor cash operating costs required to produce our oil and natural gas. Cash operating costs is a non-GAAP measure calculated on a per Boe produced basis and includes total operating expenses less depreciation, depletion and amortization expense, natural gas purchases, transportation costs, exploration expense, impairment and/or ceiling test charges and other non-cash operating costs. Adjusted cash operating costs is a non-GAAP measure and is defined as cash operating costs less transition and restructuring costs and non-cash compensation expense. We believe cash operating costs and adjusted cash operating costs per unit are valuable measures to provide management and investors and reflect operating performance and efficiency; however, these measures may not be comparable to similarly titled measures used by other companies and are subject to several of the same limitations as analytical tools as noted in the paragraphs above.