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Delaware
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46-3472728
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(State or Other Jurisdiction of
Incorporation or Organization)
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(I.R.S. Employer
Identification No.)
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1001 Louisiana Street
Houston, Texas
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77002
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(Address of Principal Executive Offices)
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(Zip Code)
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Large accelerated filer
x
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Accelerated filer
o
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Non-accelerated filer
o
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Smaller reporting company
o
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(Do not check if a smaller reporting company)
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Caption
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Page
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/d
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=
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per day
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Bbl
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=
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barrel
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Boe
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=
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barrel of oil equivalent
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CBM
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=
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coal bed methane
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Gal
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=
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gallons
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LLS
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=
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light Louisiana sweet crude oil
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MBoe
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=
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thousand barrels of oil equivalent
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MBbls
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=
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thousand barrels
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Mcf
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=
|
thousand cubic feet
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MMBtu
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=
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million British thermal units
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MMBbls
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=
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million barrels
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MMcf
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=
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million cubic feet
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MMcfe
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=
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million cubic feet of natural gas equivalents
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MMGal
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=
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million gallons
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NGLs
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=
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natural gas liquids
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NYMEX
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=
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New York Mercantile Exchange
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TBtu
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=
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trillion British thermal units
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WTI
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=
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West Texas intermediate
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Quarters ended
March 31, |
||||||
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2015
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2014
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||||
Operating revenues
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|
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Oil
|
$
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229
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|
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$
|
406
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Natural gas
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48
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|
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78
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NGLs
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13
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27
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Financial derivatives
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203
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(135
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)
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Total operating revenues
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493
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376
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||
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||||
Operating expenses
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|
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Natural gas purchases
|
7
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|
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3
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Transportation costs
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27
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|
|
23
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|
||
Lease operating expense
|
47
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|
|
44
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|
||
General and administrative
|
47
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|
|
133
|
|
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Depreciation, depletion and amortization
|
224
|
|
|
192
|
|
||
Exploration and other expense
|
6
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|
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8
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|
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Taxes, other than income taxes
|
22
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|
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33
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|
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Total operating expenses
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380
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436
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||
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||||
Operating income (loss)
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113
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|
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(60
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)
|
||
Loss on extinguishment of debt
|
—
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|
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(17
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)
|
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Interest expense
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(84
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)
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(79
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)
|
||
Income (loss) from continuing operations before income taxes
|
29
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|
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(156
|
)
|
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Income tax expense (benefit)
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10
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|
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(56
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)
|
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Income (loss) from continuing operations
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19
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|
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(100
|
)
|
||
Income from discontinued operations, net of tax
|
—
|
|
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10
|
|
||
Net income (loss)
|
$
|
19
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|
|
$
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(90
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)
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|
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|
|
||||
Basic and diluted net income (loss) per common share
|
|
|
|
|
|
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Income (loss) from continuing operations
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$
|
0.08
|
|
|
$
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(0.42
|
)
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Income from discontinued operations, net of tax
|
—
|
|
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0.04
|
|
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Net income (loss)
|
$
|
0.08
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|
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$
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(0.38
|
)
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Basic and diluted weighted average common shares outstanding
|
244
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|
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238
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|
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March 31, 2015
|
|
December 31, 2014
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ASSETS
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|
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Current assets
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|
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Cash and cash equivalents
|
$
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9
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|
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$
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22
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Accounts receivable
|
|
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Customer, net of allowance of less than $1 in 2015 and 2014
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206
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234
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Other, net of allowance of $1 in 2015 and 2014
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28
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|
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38
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|
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Income tax receivable
|
2
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24
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|
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Materials and supplies
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24
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25
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Derivative instruments
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746
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752
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|
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Prepaid assets
|
7
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7
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Total current assets
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1,022
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|
|
1,102
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Property, plant and equipment, at cost
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|
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Oil and natural gas properties
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10,645
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10,241
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Other property, plant and equipment
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79
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|
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76
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|
||
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10,724
|
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10,317
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Less accumulated depreciation, depletion and amortization
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1,809
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1,589
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|
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Total property, plant and equipment, net
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8,915
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|
8,728
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Other assets
|
|
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|
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Derivative instruments
|
289
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297
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|
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Unamortized debt issue costs
|
85
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|
|
90
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|
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Other
|
2
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2
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|
376
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|
|
389
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Total assets
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$
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10,313
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$
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10,219
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March 31, 2015
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|
December 31, 2014
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||||
LIABILITIES AND EQUITY
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|
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Current liabilities
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|
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|
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|
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Accounts payable
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|
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|
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Trade
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$
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106
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|
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$
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142
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Other
|
328
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|
|
403
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|
||
Deferred income taxes
|
250
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|
|
251
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|
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Derivative instruments
|
1
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1
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|
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Accrued interest
|
106
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|
|
53
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|
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Asset retirement obligations
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2
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|
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2
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Other accrued liabilities
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35
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47
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|
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Total current liabilities
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828
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899
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Long-term debt
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4,726
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4,598
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Other long-term liabilities
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|
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|
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|
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Deferred income taxes
|
339
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|
|
327
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|
||
Asset retirement obligations
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41
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|
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40
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|
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Other
|
7
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|
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7
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|
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Total non-current liabilities
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5,113
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|
|
4,972
|
|
||
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|
||||
Commitments and contingencies (Note 8)
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|
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|
||||
Stockholders’ equity
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|
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|
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|
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Class A shares, $0.01 par value; 550 million shares authorized; 248 million shares issued and outstanding at March 31, 2015; 245 million shares issued and outstanding at December 31, 2014
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2
|
|
|
2
|
|
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Class B shares, $0.01 par value; 0.8 million shares authorized, issued and outstanding at March 31, 2015 and December 31, 2014
|
—
|
|
|
—
|
|
||
Preferred stock, $0.01 par value; 50 million shares authorized; no shares issued or outstanding
|
—
|
|
|
—
|
|
||
Additional paid-in capital
|
3,515
|
|
|
3,510
|
|
||
Retained earnings
|
855
|
|
|
836
|
|
||
Total stockholders’ equity
|
4,372
|
|
|
4,348
|
|
||
Total liabilities and equity
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$
|
10,313
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|
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$
|
10,219
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|
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Quarters ended
March 31, |
||||||
|
2015
|
|
2014
|
||||
Cash flows from operating activities
|
|
|
|
|
|
||
Net income (loss)
|
$
|
19
|
|
|
$
|
(90
|
)
|
Adjustments to reconcile net income (loss) to net cash provided by operating activities
|
|
|
|
|
|
||
Depreciation, depletion and amortization
|
224
|
|
|
198
|
|
||
Gain on sale of assets
|
—
|
|
|
(13
|
)
|
||
Deferred income tax expense (benefit)
|
10
|
|
|
(51
|
)
|
||
Loss on extinguishment of debt
|
—
|
|
|
17
|
|
||
Share-based compensation expense
|
5
|
|
|
4
|
|
||
Non-cash portion of exploration expense
|
4
|
|
|
7
|
|
||
Amortization of debt issuance costs
|
5
|
|
|
5
|
|
||
Other
|
(1
|
)
|
|
3
|
|
||
Asset and liability changes
|
|
|
|
|
|
||
Accounts receivable
|
38
|
|
|
(16
|
)
|
||
Accounts payable
|
(90
|
)
|
|
6
|
|
||
Derivative instruments
|
14
|
|
|
111
|
|
||
Accrued interest
|
53
|
|
|
53
|
|
||
Other asset changes
|
23
|
|
|
4
|
|
||
Other liability changes
|
(13
|
)
|
|
(15
|
)
|
||
Net cash provided by operating activities
|
291
|
|
|
223
|
|
||
|
|
|
|
||||
Cash flows from investing activities
|
|
|
|
|
|
||
Capital expenditures
|
(432
|
)
|
|
(459
|
)
|
||
Proceeds from the sale of assets
|
—
|
|
|
17
|
|
||
Net cash used in investing activities
|
(432
|
)
|
|
(442
|
)
|
||
|
|
|
|
||||
Cash flows from financing activities
|
|
|
|
|
|
||
Proceeds from issuance of long-term debt
|
364
|
|
|
550
|
|
||
Repayments of long-term debt
|
(236
|
)
|
|
(964
|
)
|
||
Proceeds from issuance of stock
|
—
|
|
|
669
|
|
||
Net cash provided by financing activities
|
128
|
|
|
255
|
|
||
|
|
|
|
||||
Change in cash and cash equivalents
|
(13
|
)
|
|
36
|
|
||
Cash and cash equivalents
|
|
|
|
|
|
||
Beginning of period
|
22
|
|
|
51
|
|
||
End of period
|
$
|
9
|
|
|
$
|
87
|
|
|
Stockholders’ Equity
|
||||||||||||||||||||||||
|
Class A Stock
|
|
Class B Stock
|
|
Additional
Paid-in Capital
|
|
Retained Earnings
|
|
|
||||||||||||||||
|
Shares
|
|
Amount
|
|
Shares
|
|
Amount
|
|
|
|
Total
|
||||||||||||||
Balance at December 31, 2014
|
245
|
|
|
$
|
2
|
|
|
0.8
|
|
|
$
|
—
|
|
|
$
|
3,510
|
|
|
$
|
836
|
|
|
$
|
4,348
|
|
Share-based compensation
|
3
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
5
|
|
|
—
|
|
|
5
|
|
|||||
Net income
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
19
|
|
|
19
|
|
|||||
Balance at March 31, 2015
|
248
|
|
|
$
|
2
|
|
|
0.8
|
|
|
$
|
—
|
|
|
$
|
3,515
|
|
|
$
|
855
|
|
|
$
|
4,372
|
|
|
Quarter ended March 31, 2014
|
||
|
(in millions)
|
||
Operating revenues
|
$
|
31
|
|
|
|
||
Operating expenses
|
|
|
|
Transportation costs
|
3
|
|
|
Lease operating expense
|
13
|
|
|
Depreciation, depletion and amortization
|
6
|
|
|
Impairment charges
(1)
|
3
|
|
|
Other expense
|
5
|
|
|
Total operating expenses
|
30
|
|
|
|
|
||
Gain on sale of assets
|
13
|
|
|
Other income
|
3
|
|
|
Income from discontinued operations before income taxes
|
17
|
|
|
Income tax expense
|
7
|
|
|
Income from discontinued operations, net of tax
|
$
|
10
|
|
|
|
March 31, 2015
|
|
December 31, 2014
|
||||||||||||
|
Carrying
Amount
|
|
Fair
Value
|
|
Carrying
Amount
|
|
Fair
Value
|
||||||||
|
(in millions)
|
||||||||||||||
Long-term debt
|
$
|
4,726
|
|
|
$
|
4,809
|
|
|
$
|
4,598
|
|
|
$
|
4,582
|
|
|
|
|
|
|
|
|
|
||||||||
Derivative instruments
|
$
|
1,034
|
|
|
$
|
1,034
|
|
|
$
|
1,048
|
|
|
$
|
1,048
|
|
|
|
2015
Volumes
|
|
2016
Volumes
|
|
||
Oil (MBbls)
|
|
|
|
|
|
|
|
Fixed Price Swaps
|
|
|
|
|
|
|
|
LLS
(1)
|
|
—
|
|
|
4,392
|
|
|
Basis Swaps
|
|
|
|
|
|
||
WTI - CM vs. TM
(2)
|
|
—
|
|
|
3,660
|
|
|
NYMEX Roll
(3)
|
|
490
|
|
|
182
|
|
|
|
(1)
|
In April 2015, we unwound
1,464
MBbls of 2016 LLS three way collars in exchange for
4,392
MBbls of 2016 LLS fixed price swaps. No cash or other consideration was included as part of this exchange.
|
(2)
|
EP Energy receives WTI trade month (TM) and pays WTI calendar month (CM).
|
(3)
|
Hedges the timing risk associated with our physical sales. We generally sell oil for the delivery month at a sales price based on the average NYMEX WTI price during that month, plus an adjustment calculated as a spread between the weighted average prices of the delivery month, the next month and the following month during the period when the delivery month is prompt (the "trade month roll").
|
|
Level 2
|
||||||||||||||||||||||||||||||
|
Derivative Assets
|
|
Derivative Liabilities
|
||||||||||||||||||||||||||||
|
Gross
Fair Value
|
|
|
|
Balance Sheet Location
|
|
Gross
Fair Value
|
|
|
|
Balance Sheet Location
|
||||||||||||||||||||
|
|
Impact of
Netting
|
|
Current
|
|
Non-
current
|
|
|
Impact of
Netting
|
|
Current
|
|
Non-
current
|
||||||||||||||||||
|
(in millions)
|
|
(in millions)
|
||||||||||||||||||||||||||||
March 31, 2015
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||
Derivative instruments
|
$
|
1,069
|
|
|
$
|
(34
|
)
|
|
$
|
746
|
|
|
$
|
289
|
|
|
$
|
(35
|
)
|
|
$
|
34
|
|
|
$
|
(1
|
)
|
|
$
|
—
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||
December 31, 2014
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||
Derivative instruments
|
$
|
1,093
|
|
|
$
|
(44
|
)
|
|
$
|
752
|
|
|
$
|
297
|
|
|
$
|
(45
|
)
|
|
$
|
44
|
|
|
$
|
(1
|
)
|
|
$
|
—
|
|
|
2015
|
||
|
(in millions)
|
||
Net asset retirement liability at January 1
|
$
|
42
|
|
Liabilities incurred
|
1
|
|
|
Liabilities settled
|
(1
|
)
|
|
Accretion expense
|
1
|
|
|
Net asset retirement liability at March 31
|
$
|
43
|
|
|
Interest Rate
|
|
March 31, 2015
|
|
December 31, 2014
|
||||
|
|
|
(in millions)
|
||||||
$2.75 billion RBL credit facility - due May 24, 2019
|
Variable
|
|
$
|
980
|
|
|
$
|
852
|
|
$750 million senior secured term loan - due May 24, 2018
(1)(3)
|
Variable
|
|
496
|
|
|
496
|
|
||
$400 million senior secured term loan - due April 30, 2019
(2)(3)
|
Variable
|
|
150
|
|
|
150
|
|
||
$750 million senior secured notes - due May 1, 2019
(3)
|
6.875%
|
|
750
|
|
|
750
|
|
||
$2.0 billion senior unsecured notes - due May 1, 2020
|
9.375%
|
|
2,000
|
|
|
2,000
|
|
||
$350 million senior unsecured notes - due September 1, 2022
|
7.75%
|
|
350
|
|
|
350
|
|
||
Total
|
|
|
$
|
4,726
|
|
|
$
|
4,598
|
|
|
|
|
Number of Shares
|
|
Weighted Average
Grant Date Fair Value
per Share
|
|
|||
Non-vested at December 31, 2014
|
|
1,033,394
|
|
|
$
|
19.80
|
|
|
Granted
|
|
3,538,385
|
|
|
9.38
|
|
|
|
Vested
|
|
(2,564
|
)
|
|
19.82
|
|
|
|
Forfeited
|
|
(7,223
|
)
|
|
16.21
|
|
|
|
Non-vested at March 31, 2015
|
|
4,561,992
|
|
|
$
|
11.72
|
|
|
•
|
Eagle Ford Shale.
The Eagle Ford Shale continues to provide the highest economic returns in our portfolio. We are currently running three rigs in this program.
|
•
|
Wolfcamp Shale.
In our Wolfcamp Shale program, we are focused on optimizing our drilling, completion and artificial lift systems. We are currently running one rig in this program.
|
•
|
Altamont.
In Altamont, we are gaining operational efficiencies as we develop this oil field. Our acreage in this area is largely held-by-production. We are currently running two rigs in this program.
|
•
|
Haynesville Shale.
The Haynesville Shale generates positive cash flow, and our acreage in the Haynesville Shale is held-by-production. We are currently running one rig in this program.
|
|
2015
|
|
2016
|
|
2017
|
|||||||||||||||
|
Volumes
(1)
|
|
Average
Price
(1)
|
|
Volumes
(1)
|
|
Average
Price
(1)
|
|
Volumes
(1)
|
|
Average
Price
(1)
|
|||||||||
Oil
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||
Fixed Price Swaps
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||
WTI
|
13,361
|
|
|
$
|
89.34
|
|
|
8,510
|
|
|
$
|
80.03
|
|
|
4,015
|
|
|
$
|
66.11
|
|
Brent
|
1,925
|
|
|
$
|
100.01
|
|
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
LLS
|
—
|
|
|
$
|
—
|
|
|
5,124
|
|
|
$
|
91.88
|
|
|
—
|
|
|
$
|
—
|
|
Ceilings
|
825
|
|
|
$
|
100.00
|
|
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
Three Way Collars
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||
Ceiling - Brent
|
825
|
|
|
$
|
110.02
|
|
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
Floors - Brent
(2)
|
825
|
|
|
$
|
100.00
|
|
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
Ceiling - LLS
|
—
|
|
|
$
|
—
|
|
|
1,464
|
|
|
$
|
99.29
|
|
|
—
|
|
|
$
|
—
|
|
Floors - LLS
(3)
|
—
|
|
|
$
|
—
|
|
|
1,464
|
|
|
$
|
94.00
|
|
|
—
|
|
|
$
|
—
|
|
Basis Swaps
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||
LLS vs. WTI
(4)
|
5,163
|
|
|
$
|
4.11
|
|
|
2,013
|
|
|
$
|
3.91
|
|
|
—
|
|
|
$
|
—
|
|
LLS vs. Brent
(5)
|
2,750
|
|
|
$
|
(3.77
|
)
|
|
2,196
|
|
|
$
|
(4.99
|
)
|
|
—
|
|
|
$
|
—
|
|
Midland vs. Cushing
(6)
|
825
|
|
|
$
|
(0.65
|
)
|
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
WTI - CM vs. TM
(7)
|
2,750
|
|
|
$
|
1.28
|
|
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
NYMEX Roll
(8)
|
7,400
|
|
|
$
|
(0.96
|
)
|
|
7,316
|
|
|
$
|
(0.92
|
)
|
|
—
|
|
|
$
|
—
|
|
Natural Gas
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||
Fixed Price Swaps
|
47
|
|
|
$
|
4.26
|
|
|
7
|
|
|
$
|
4.20
|
|
|
—
|
|
|
$
|
—
|
|
Basis Swaps
(9)
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||
CIG
|
3
|
|
|
$
|
(0.25
|
)
|
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
Waha
|
3
|
|
|
$
|
(0.07
|
)
|
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
Propane
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||
Fixed Price Swaps
|
35
|
|
|
$
|
0.60
|
|
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
|
(1)
|
Volumes presented are MBbls for oil, TBtu for natural gas and MMGal for propane. Prices presented are per Bbl of oil, MMBtu of natural gas and Gal for propane.
|
(2)
|
If market prices settle at or below
$85.00
in 2015, we will receive a “locked-in” cash settlement of the market price plus
$15.00
per Bbl.
|
(3)
|
If market prices settle at or below
$80.00
in 2016, we will receive a “locked-in” cash settlement of the market price plus
$14.00
per Bbl.
|
(4)
|
EP Energy receives WTI plus basis spread listed and pays LLS.
|
(5)
|
EP Energy receives Brent plus basis spread listed and pays LLS.
|
(6)
|
EP Energy receives Cushing plus basis spread listed and pays Midland.
|
(7)
|
EP Energy receives WTI trade month (TM) plus the spread listed and pays WTI calendar month (CM).
|
(8)
|
Hedges the timing risk associated with our physical sales. We generally sell oil for the delivery month at a sales price based on the average NYMEX WTI price during that month, plus an adjustment calculated as a spread between the weighted average prices of the delivery month, the next month and the following month during the period when the delivery month is prompt (the "trade month roll").
|
(9)
|
EP Energy receives the basis spread listed and pays CIG and Waha basis.
|
|
|
2015
|
|
2016
|
|
||||||||||
|
|
Volumes
(1)
|
|
Average
Price
(1)
|
|
Volumes
(1)
|
|
Average
Price
(1)
|
|
||||||
Oil
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||
Fixed Price Swaps
|
|
|
|
|
|
|
|
|
|
|
|
|
|||
LLS
(2)
|
|
—
|
|
|
$
|
—
|
|
|
4,392
|
|
|
$
|
67.25
|
|
|
Basis Swaps
|
|
|
|
|
|
|
|
|
|
||||||
WTI - CM vs. TM
|
|
—
|
|
|
$
|
—
|
|
|
3,660
|
|
|
$
|
0.20
|
|
|
NYMEX Roll
|
|
490
|
|
|
$
|
(1.00
|
)
|
|
182
|
|
|
$
|
(1.00
|
)
|
|
|
(1)
|
Volumes presented are MBbls. Prices presented are per Bbl.
|
(2)
|
In April 2015, we unwound 1,464 MBbls of 2016 LLS three way collars in exchange for
4,392
MBbls of 2016 LLS fixed price swaps. No cash or other consideration was included as part of this exchange.
|
•
|
Capital expenditures of approximately $1.2 billion to $1.25 billion, allocated primarily to our oil programs: $825 million to Eagle Ford, $190 million to Wolfcamp, $140 million to Altamont and $100 million to Haynesville.
|
•
|
Well completions between 160 and 190.
|
•
|
Average daily production volumes for the year of approximately 97.0 MBoe/d to 107.0 MBoe/d, including average daily oil production volumes of approximately 57 MBbls/d to 63 MBbls/d.
|
•
|
Per unit adjusted cash operating costs for the year of approximately $10.50 to $12.00 per Boe, and transportation costs of $2.95 to $3.15 per Boe.
|
•
|
Per unit depreciation, depletion and amortization rate for the year of approximately $25.00 to $27.00 per Boe.
|
|
2015
|
|
2014
|
||
United States (MBoe/d)
|
|
|
|
|
|
Eagle Ford Shale
|
54.7
|
|
|
46.5
|
|
Wolfcamp Shale
|
17.9
|
|
|
11.9
|
|
Altamont
|
17.1
|
|
|
13.4
|
|
Haynesville Shale
|
12.6
|
|
|
18.7
|
|
Other
|
0.1
|
|
|
0.2
|
|
Total
|
102.4
|
|
|
90.7
|
|
|
|
|
|
||
Oil (MBbls/d)
|
60.0
|
|
|
48.6
|
|
Natural Gas (MMcf/d)
|
185
|
|
|
197
|
|
NGLs (MBbls/d)
|
11.6
|
|
|
9.3
|
|
•
|
Altamont
—Our Altamont equivalent volumes increased
3.7
MBoe/d (
28%
) for the quarter ended
March 31, 2015
compared to the same period in
2014
. Altamont produced an average of
12.5
MBbls/d of oil during the quarter ended
March 31, 2015
, and we completed
9
additional operated oil wells for a total of 368 net operated wells at
March 31, 2015
.
|
|
Quarters ended
March 31, |
||||||
|
2015
|
|
2014
|
||||
|
(in millions)
|
||||||
Operating revenues
|
|
|
|
|
|
||
Oil
|
$
|
229
|
|
|
$
|
406
|
|
Natural gas
|
48
|
|
|
78
|
|
||
NGLs
|
13
|
|
|
27
|
|
||
Total physical sales
|
290
|
|
|
511
|
|
||
Financial derivatives
|
203
|
|
|
(135
|
)
|
||
Total operating revenues
|
493
|
|
|
376
|
|
||
|
|
|
|
||||
Operating expenses
|
|
|
|
|
|
||
Natural gas purchases
|
7
|
|
|
3
|
|
||
Transportation costs
|
27
|
|
|
23
|
|
||
Lease operating expense
|
47
|
|
|
44
|
|
||
General and administrative
|
47
|
|
|
133
|
|
||
Depreciation, depletion and amortization
|
224
|
|
|
192
|
|
||
Exploration and other expense
|
6
|
|
|
8
|
|
||
Taxes, other than income taxes
|
22
|
|
|
33
|
|
||
Total operating expenses
|
380
|
|
|
436
|
|
||
|
|
|
|
||||
Operating income (loss)
|
113
|
|
|
(60
|
)
|
||
Loss on extinguishment of debt
|
—
|
|
|
(17
|
)
|
||
Interest expense
|
(84
|
)
|
|
(79
|
)
|
||
Income (loss) from continuing operations before income taxes
|
29
|
|
|
(156
|
)
|
||
Income tax expense (benefit)
|
10
|
|
|
(56
|
)
|
||
Income (loss) from continuing operations
|
19
|
|
|
(100
|
)
|
||
Income from discontinued operations, net of tax
|
—
|
|
|
10
|
|
||
Net income (loss)
|
$
|
19
|
|
|
$
|
(90
|
)
|
|
Quarters ended
March 31, |
||||||
|
2015
|
|
2014
|
||||
|
(in millions)
|
||||||
Operating revenues:
|
|
|
|
|
|
||
Oil
|
$
|
229
|
|
|
$
|
406
|
|
Natural gas
|
48
|
|
|
78
|
|
||
NGLs
|
13
|
|
|
27
|
|
||
Total physical sales
|
290
|
|
|
511
|
|
||
Financial derivatives
|
203
|
|
|
(135
|
)
|
||
Total operating revenues
|
$
|
493
|
|
|
$
|
376
|
|
|
|
|
|
||||
Volumes:
|
|
|
|
|
|
||
Oil (MBbls)
|
5,402
|
|
|
4,373
|
|
||
Natural gas (MMcf)
|
16,628
|
|
|
17,699
|
|
||
NGLs (MBbls)
|
1,044
|
|
|
843
|
|
||
Equivalent volumes (MBoe)
|
9,218
|
|
|
8,166
|
|
||
Total MBoe/d
|
102.4
|
|
|
90.7
|
|
||
|
|
|
|
||||
Consolidated prices per unit
(1)
:
|
|
|
|
|
|
||
Oil
|
|
|
|
|
|
||
Average realized price on physical sales ($/Bbl)
(2)
|
$
|
42.40
|
|
|
$
|
92.83
|
|
Average realized price, including financial derivatives ($/Bbl)
(2)(3)
|
$
|
78.39
|
|
|
$
|
91.20
|
|
Natural gas
|
|
|
|
|
|
||
Average realized price on physical sales ($/Mcf)
(2)
|
$
|
2.51
|
|
|
$
|
4.21
|
|
Average realized price, including financial derivatives ($/Mcf)
(3)
|
$
|
3.69
|
|
|
$
|
3.26
|
|
NGLs
|
|
|
|
|
|
||
Average realized price on physical sales ($/Bbl)
|
$
|
12.04
|
|
|
$
|
32.29
|
|
Average realized price, including financial derivatives ($/Bbl)
(3)
|
$
|
12.26
|
|
|
$
|
31.40
|
|
|
(1)
|
Natural gas prices for the
quarter
s ended
March 31, 2015
and
2014
are calculated including a reduction of
$7 million
and
$3 million
, respectively, for natural gas purchases associated with managing our physical sales.
|
(2)
|
Changes in realized oil and natural gas prices reflect the effects of unfavorable unhedged locational or basis differentials, unhedged volumes and contractual deductions between the commodity price index and the actual price at which we sold our oil and natural gas.
|
(3)
|
The quarters ended
March 31, 2015
and
2014
, include approximately $194 million of cash received and $7 million of cash paid, respectively, for the settlement of crude oil derivative contracts and approximately $20 million of cash received and $17 million of cash paid, respectively, for the settlement of natural gas financial derivatives. The quarters ended
March 31, 2015
and
2014
, include less than $1 million and approximately $1 million, respectively, of cash paid for the settlement of NGLs derivative contracts. No cash premiums were received for the quarter ended
March 31, 2015
. Cash premiums received for the quarter ended
March 31, 2014
were less than $1 million.
|
|
Oil
|
|
Natural gas
|
|
NGLs
|
|
Total
|
||||||||
|
(in millions)
|
||||||||||||||
March 31, 2014 sales
|
$
|
406
|
|
|
$
|
78
|
|
|
$
|
27
|
|
|
$
|
511
|
|
Change due to prices
|
(272
|
)
|
|
(25
|
)
|
|
(21
|
)
|
|
(318
|
)
|
||||
Change due to volumes
|
95
|
|
|
(5
|
)
|
|
7
|
|
|
97
|
|
||||
March 31, 2015 sales
|
$
|
229
|
|
|
$
|
48
|
|
|
$
|
13
|
|
|
$
|
290
|
|
|
Quarters ended March 31,
|
||||||||||||||
|
2015
|
|
2014
|
||||||||||||
|
Oil
(Bbl)
|
|
Natural gas
(MMBtu)
|
|
Oil
(Bbl)
|
|
Natural gas
(MMBtu)
|
||||||||
Differentials and deducts
|
$
|
(6.49
|
)
|
|
$
|
(0.50
|
)
|
|
$
|
(5.70
|
)
|
|
$
|
(0.58
|
)
|
NYMEX
|
$
|
48.63
|
|
|
$
|
2.98
|
|
|
$
|
98.69
|
|
|
$
|
4.94
|
|
|
Quarters ended
March 31, |
||||||
|
2015
|
|
2014
|
||||
Depreciation, depletion and amortization ($/Boe)
(1)
|
$
|
24.30
|
|
|
$
|
23.47
|
|
|
(1)
|
Includes $0.07 per Boe for both of the quarters ended
March 31, 2015
and
2014
related to accretion expense on asset retirement obligations.
|
|
Quarters ended
March 31, |
||||||||||||||
|
2015
|
|
2014
|
||||||||||||
|
Total
|
|
Per Unit
(1)
|
|
Total
|
|
Per Unit
(1)
|
||||||||
|
(in millions, except per unit costs)
|
||||||||||||||
Total continuing operating expenses
|
$
|
380
|
|
|
$
|
41.27
|
|
|
$
|
436
|
|
|
$
|
53.40
|
|
|
|
|
|
|
|
|
|
||||||||
Depreciation, depletion and amortization
|
(224
|
)
|
|
(24.30
|
)
|
|
(192
|
)
|
|
(23.47
|
)
|
||||
Transportation costs
|
(27
|
)
|
|
(2.90
|
)
|
|
(23
|
)
|
|
(2.85
|
)
|
||||
Exploration expense
(2)
|
(5
|
)
|
|
(0.51
|
)
|
|
(8
|
)
|
|
(0.99
|
)
|
||||
Natural gas purchases
|
(7
|
)
|
|
(0.74
|
)
|
|
(3
|
)
|
|
(0.43
|
)
|
||||
Total continuing cash operating costs
|
117
|
|
|
12.82
|
|
|
210
|
|
|
25.66
|
|
||||
Transition/restructuring costs, non-cash portion of compensation expense and other
(3)
|
(12
|
)
|
|
(1.38
|
)
|
|
(100
|
)
|
|
(12.20
|
)
|
||||
Total adjusted cash operating costs and adjusted per-unit cash operating costs
|
$
|
105
|
|
|
$
|
11.44
|
|
|
$
|
110
|
|
|
$
|
13.46
|
|
|
|
|
|
|
|
|
|
||||||||
Total equivalent volumes (MBoe)
|
9,218
|
|
|
|
|
|
8,166
|
|
|
|
|
|
(1)
|
Per unit costs are based on actual total amounts rather than the rounded totals presented.
|
(2)
|
Represents exploration expense only.
|
(3)
|
For the
quarter
ended
March 31, 2015
, amount includes approximately
$8 million
of transition and severance costs related to restructuring and
$5 million
of non-cash compensation expense. For the
quarter
ended
March 31, 2014
, amount includes $90 million of transaction, management and other fees paid to our Sponsors, $9 million of non-cash compensation expense and $1 million of transition and severance costs related to restructuring. The non-cash portion of compensation expense represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under our long-term incentive plans.
|
|
Quarters ended
March 31, |
||||||
|
2015
|
|
2014
|
||||
Average cash operating costs ($/Boe)
|
|
|
|
|
|
||
Lease operating expenses
|
$
|
5.12
|
|
|
$
|
5.42
|
|
Production taxes
(1)
|
2.13
|
|
|
3.72
|
|
||
General and administrative expenses
(2)
|
5.09
|
|
|
16.24
|
|
||
Taxes, other than production and income taxes
|
0.28
|
|
|
0.28
|
|
||
Other expenses
(3)
|
0.20
|
|
|
—
|
|
||
Total cash operating costs
|
12.82
|
|
|
25.66
|
|
||
Transition/restructuring costs, non-cash portion of compensation expense and other
(2)
|
(1.38
|
)
|
|
(12.20
|
)
|
||
Total adjusted cash operating costs
|
$
|
11.44
|
|
|
$
|
13.46
|
|
|
(1)
|
Production taxes include ad valorem and severance taxes which decreased during the
quarter
ended
March 31, 2015
due to lower commodity prices.
|
(2)
|
For additional detail of items included in general and administrative expenses, refer to the reconciliation of cash operating costs and adjusted cash operating costs above.
|
(3)
|
Includes early rig termination fees of $2 million.
|
|
Quarters ended
March 31, |
||||||
|
2015
|
|
2014
|
||||
|
(in millions)
|
||||||
Net income (loss)
|
$
|
19
|
|
|
$
|
(90
|
)
|
Income from discontinued operations, net of tax
|
—
|
|
|
(10
|
)
|
||
Income (loss) from continuing operations
|
19
|
|
|
(100
|
)
|
||
Income tax expense (benefit)
|
10
|
|
|
(56
|
)
|
||
Interest expense, net of capitalized interest
|
84
|
|
|
79
|
|
||
Depreciation, depletion and amortization
|
224
|
|
|
192
|
|
||
Exploration expense
(1)
|
5
|
|
|
8
|
|
||
EBITDAX
|
342
|
|
|
123
|
|
||
Mark-to-market on financial derivatives
(2)
|
(203
|
)
|
|
135
|
|
||
Cash settlements and premiums on financial derivatives
(3)
|
214
|
|
|
(25
|
)
|
||
Non-cash portion of compensation expense
(4)
|
5
|
|
|
9
|
|
||
Transition, restructuring and other costs
(5)
|
8
|
|
|
1
|
|
||
Fees paid to Sponsors
(6)
|
—
|
|
|
90
|
|
||
Loss on extinguishment of debt
(7)
|
—
|
|
|
17
|
|
||
Adjusted EBITDAX
|
$
|
366
|
|
|
$
|
350
|
|
|
(1)
|
Represents exploration expense only.
|
(2)
|
Represents the income statement impact of financial derivatives.
|
(3)
|
Represents actual cash settlements received/(paid) related to financial derivatives, including cash premiums. No cash premiums were received for the quarter ended
March 31, 2015
. For the quarter ended
March 31, 2014
, we received less than $1 million of cash premiums.
|
(4)
|
For the quarters ended
March 31, 2015
and 2014, cash payments were less than $1 million.
|
(5)
|
Reflects transition and severance costs related to restructuring activities.
|
(6)
|
Represents transaction, management and other fees paid to the Sponsors in 2014.
|
(7)
|
Represents the loss on extinguishment of debt recorded related to retirement of the PIK toggle note in 2014.
|
|
Capital
Expenditures
(in millions)
|
|
Average Drilling
Rigs
|
|||
Eagle Ford Shale
|
$
|
288
|
|
|
5.0
|
|
Wolfcamp Shale
|
74
|
|
|
2.0
|
|
|
Altamont
|
48
|
|
|
2.0
|
|
|
Haynesville Shale
|
5
|
|
|
0.1
|
|
|
Total capital expenditures
|
$
|
415
|
|
|
9.1
|
|
|
Quarters ended
March 31, |
||||||
|
2015
|
|
2014
|
||||
Cash Flow from Operations
|
|
|
|
|
|
||
Operating activities
|
|
|
|
|
|
||
Net income (loss)
|
$
|
19
|
|
|
$
|
(90
|
)
|
Gain on sale of assets
|
—
|
|
|
(13
|
)
|
||
Other income adjustments
|
247
|
|
|
183
|
|
||
Changes in assets and liabilities
|
25
|
|
|
143
|
|
||
Total cash flow from operations
|
$
|
291
|
|
|
$
|
223
|
|
|
|
|
|
||||
Other Cash Inflows
|
|
|
|
|
|
||
Investing activities
|
|
|
|
|
|
||
Proceeds from the sale of assets
|
$
|
—
|
|
|
$
|
17
|
|
|
|
|
|
||||
Financing activities
|
|
|
|
|
|
||
Proceeds from issuance of long-term debt
|
364
|
|
|
550
|
|
||
Proceeds from issuance of stock
|
—
|
|
|
669
|
|
||
|
364
|
|
|
1,219
|
|
||
Total cash inflows
|
$
|
364
|
|
|
$
|
1,236
|
|
|
|
|
|
||||
Cash Outflows
|
|
|
|
|
|
||
Investing activities
|
|
|
|
|
|
||
Capital expenditures
|
$
|
432
|
|
|
$
|
459
|
|
|
|
|
|
|
|
||
Financing activities
|
|
|
|
|
|
||
Repayments of long-term debt
|
236
|
|
|
964
|
|
||
|
236
|
|
|
964
|
|
||
Total cash outflows
|
$
|
668
|
|
|
$
|
1,423
|
|
|
|
|
|
||||
Net change in cash and cash equivalents
|
$
|
(13
|
)
|
|
$
|
36
|
|
|
|
|
Oil, Natural Gas and NGL Derivatives
|
||||||||||||||||
|
|
|
10 Percent Increase
|
|
10 Percent Decrease
|
||||||||||||||
|
Fair Value
|
|
Fair Value
|
|
Change
|
|
Fair Value
|
|
Change
|
||||||||||
|
(in millions)
|
||||||||||||||||||
Price impact
(1)
|
$
|
1,034
|
|
|
$
|
830
|
|
|
$
|
(204
|
)
|
|
$
|
1,237
|
|
|
$
|
203
|
|
|
|
|
Oil, Natural Gas and NGL Derivatives
|
||||||||||||||||
|
|
|
1 Percent Increase
|
|
1 Percent Decrease
|
||||||||||||||
|
Fair Value
|
|
Fair Value
|
|
Change
|
|
Fair
Value
|
|
Change
|
||||||||||
|
(in millions)
|
||||||||||||||||||
Discount rate
(2)
|
$
|
1,034
|
|
|
$
|
1,026
|
|
|
$
|
(8
|
)
|
|
$
|
1,042
|
|
|
$
|
8
|
|
Credit rate
(3)
|
$
|
1,034
|
|
|
$
|
1,024
|
|
|
$
|
(10
|
)
|
|
$
|
1,039
|
|
|
$
|
5
|
|
|
(1)
|
Presents the hypothetical sensitivity of our commodity-based derivatives to changes in fair values arising from changes in oil and natural gas prices.
|
(2)
|
Presents the hypothetical sensitivity of our commodity-based derivatives to changes in the discount rates we used to determine the fair value of our derivatives.
|
(3)
|
Presents the hypothetical sensitivity of our commodity-based derivatives to changes in credit risk of our counterparties.
|
•
|
should not in all instances be treated as categorical statements of fact, but rather as a way of allocating the risk to one of the parties if those statements prove to be inaccurate;
|
•
|
may have been qualified by disclosures that were made to the other party in connection with the negotiation of the applicable agreement, which disclosures are not necessarily reflected in the agreement;
|
•
|
may apply standards of materiality in a way that is different from what may be viewed as material to certain investors; and
|
•
|
were made only as of the date of the applicable agreement or such other date or dates as may be specified in the agreement and are subject to more recent developments.
|
|
EP ENERGY CORPORATION
|
|
|
|
|
Date: April 30, 2015
|
/s/ Dane E. Whitehead
|
|
Dane E. Whitehead
|
|
Executive Vice President and Chief Financial Officer
|
|
(Principal Financial Officer)
|
|
|
|
|
Date: April 30, 2015
|
/s/ Francis C. Olmsted III
|
|
Francis C. Olmsted III
|
|
Vice President and Controller
|
|
(Principal Accounting Officer)
|
Exhibit
Number
|
|
Description
|
|
|
|
*10.1
|
|
Third Amendment, dated as of October 27, 2014, to the Credit Agreement, dated as of May 24, 2012, among EPE Acquisition, LLC, EP Energy LLC, the lenders party thereto and JPMorgan Chase Bank, N.A., as administrative agent and collateral agent.
|
|
|
|
10.2
|
|
Fourth Amendment, dated as of April 6, 2015, to the Credit Agreement, dated as of May 24, 2012, among EPE Acquisition, LLC, EP Energy LLC, the lenders party thereto and JPMorgan Chase Bank, N.A., as administrative agent and collateral agent (Exhibit 10.1 to Company’s Current Report on Form 8‑K, filed with the SEC on April 6, 2015).
|
|
|
|
*31.1
|
|
Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
|
|
|
*31.2
|
|
Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
|
|
|
*32.1
|
|
Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
|
|
|
*32.2
|
|
Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
|
|
|
*101.INS
|
|
XBRL Instance Document.
|
|
|
|
*101.SCH
|
|
XBRL Schema Document.
|
|
|
|
*101.CAL
|
|
XBRL Calculation Linkbase Document.
|
|
|
|
*101.DEF
|
|
XBRL Definition Linkbase Document.
|
|
|
|
*101.LAB
|
|
XBRL Labels Linkbase Document.
|
|
|
|
*101.PRE
|
|
XBRL Presentation Linkbase Document.
|
By:
|
/s/ Lana Gifas
Name: Lana Gifas Title: Director |
By:
|
/s/ Jennifer Anderson
Name: Darlene Arias Title: Associate Director |
By:
|
/s/ Jonathan J. Kim
Name: Jonathan J. Kim Title: Authorized Signatory |
By:
|
/s/ Robert Robin
Name: Robert Robin Title: Authorized Signatory |
By:
|
/s/ Philip F. Kurpiewski
Name: Philip F. Kurpiewski Title: Senior Vice President |
By:
|
/s/ Barbara Gronquist
Name: Barbara Gronquist Title: Senior Vice President |
By:
|
/s/ Philip F. Kurpiewski
Name: Philip F. Kurpiewski Title: Senior Vice President |
By:
|
/s/ Barbara Gronquist
Name: Barbara Gronquist Title: Senior Vice President |
|
Commitment
|
%
|
|
||
JP Morgan Chase Bank, N.A.
|
|
$189,671,925.61
|
|
6.90
|
%
|
Citibank, N.A.
|
189,671,925.61
|
|
6.90
|
%
|
|
BMO Harris Financing, Inc.
|
173,272,545.55
|
|
6.30
|
%
|
|
Credit Suisse AG, Cayman Islands Branch
|
173,272,545.55
|
|
6.30
|
%
|
|
Royal Bank of Canada
|
173,272,545.55
|
|
6.30
|
%
|
|
Deutsche Bank AG New York Branch
|
173,272,545.52
|
|
6.30
|
%
|
|
UBS AG, Stamford Branch
|
157,520,495.95
|
|
5.73
|
%
|
|
Canadian Imperial Bank of Commerce, New York Branch
|
125,795,858.64
|
|
4.57
|
%
|
|
Capital One, National Association
|
125,211,842.11
|
|
4.55
|
%
|
|
Wells Fargo Bank, National Association
|
119,711,842.11
|
|
4.35
|
%
|
|
Compass Bank
|
101,067,569.16
|
|
3.68
|
%
|
|
Societe Generale
|
94,983,552.63
|
|
3.45
|
%
|
|
SunTrust Bank
|
94,983,552.63
|
|
3.45
|
%
|
|
Toronto Dominion (New York) LLC
|
94,983,552.63
|
|
3.45
|
%
|
|
Sumitomo Mitsui Banking Corporation
|
85,322,368.43
|
|
3.10
|
%
|
|
DNB Capital LLC
|
77,000,000.00
|
|
2.80
|
%
|
|
Bank of America, N.A.
|
63,322,368.43
|
|
2.30
|
%
|
|
ING Capital LLC
|
63,322,368.43
|
|
2.30
|
%
|
|
Mizuho Bank, Ltd.
|
63,322,368.43
|
|
2.30
|
%
|
|
The Royal Bank of Scotland PLC
|
63,322,368.43
|
|
2.30
|
%
|
|
The Bank of Nova Scotia
|
47,491,776.31
|
|
1.73
|
%
|
|
The Bank of Tokyo Mitsubishi UFJ Ltd.
|
47,491,776.31
|
|
1.73
|
%
|
|
Goldman Sachs Bank USA
|
47,491,776.31
|
|
1.73
|
%
|
|
Morgan Stanley Bank, N.A.
|
47,491,776.31
|
|
1.73
|
%
|
|
MUFG Union Bank, N.A.
|
47,491,776.31
|
|
1.73
|
%
|
|
Scotiabanc Inc.
|
47,491,776.31
|
|
1.73
|
%
|
|
Comerica Bank
|
37,745,200.74
|
|
1.37
|
%
|
|
Nomura Corporate Funding Americas, LLC
|
25,000,000.00
|
|
0.91
|
%
|
|
TOTAL
|
|
$2,750,000,000
|
|
100.00
|
%
|
|
/s/ Brent J. Smolik
|
|
Brent J. Smolik
|
|
Chairman, President and Chief Executive Officer
|
|
EP Energy Corporation
|
|
/s/ Dane E. Whitehead
|
|
Dane E. Whitehead
|
|
Executive Vice President and Chief Financial Officer
|
|
EP Energy Corporation
|
|
/s/ Brent J. Smolik
|
|
Brent J. Smolik
|
|
Chairman, President and
|
|
Chief Executive Officer
|
|
EP Energy Corporation
|
|
|
|
Date: April 30, 2015
|
|
/s/ Dane E. Whitehead
|
|
Dane E. Whitehead
|
|
Executive Vice President and
|
|
Chief Financial Officer
|
|
EP Energy Corporation
|
|
|
|
Date: April 30, 2015
|