8-K


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 8-K
CURRENT REPORT

Pursuant to Section 13 or 15(d) of
The Securities Exchange Act of 1934

Date of Report - February 24, 2016
(Date of earliest event reported)


QEP RESOURCES, INC.
(Exact name of registrant as specified in its charter)

 
 
 
STATE OF DELAWARE
001-34778
87-0287750
(State or other jurisdiction of
incorporation)
(Commission File No.)
(I.R.S. Employer
Identification No.)

1050 17th Street, Suite 800, Denver, Colorado 80265
(Address of principal executive offices)

Registrant's telephone number, including area code 303-672-6900

Not Applicable
(Former name or former address, if changed since last report)



Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):

[ ] Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

[ ] Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

[ ] Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act
(17 CFR 240.14d-2(b))

[ ] Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act
(17 CFR 240.13e-4(c))






Section 2 - Financial Information

Item 2.02    Results of Operations and Financial Condition

On February 24, 2016, QEP Resources, Inc. (the “Registrant”) issued a press release to report the results of operations for the year ended December 31, 2015, to provide an update on 2015 operations, and provide to 2016 guidance. A copy of the Registrant's release is attached as Exhibit 99.1, and the information contained therein is incorporated herein by reference.

The Registrant's press release announcing its financial results for the year ended December 31, 2015, includes non-GAAP financial measures. Generally, a non-GAAP financial measure is a numerical measure of a company's financial and operating performance that either excludes or includes amounts that are not normally excluded or included in the most directly comparable measure calculated and presented in accordance with United States generally accepted accounting principles, or GAAP. Pursuant to the requirements of Regulation G, the Registrant has provided quantitative reconciliations within the press release of the non-GAAP financial measures to the most directly comparable GAAP financial measures.

The information contained in Item 2.02 to this Form 8-K, including the exhibit, shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and the information shall not be deemed incorporated by reference into any filing under the Securities Act of 1933, as amended, except as shall be expressly set forth by specific reference in such filing.


Section 9 – Financial Statements and Exhibits

Item 9.01    Financial Statements and Exhibits.

(d)  Exhibits.

Exhibit No.
Exhibit
 
 
 
 
99.1
Press release issued February 24, 2016, by QEP Resources, Inc.
 





SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



 
 
QEP Resources, Inc.
 
 
(Registrant)
 
 
 
February 24, 2016
 
 
 
 
 
 
 
/s/ Richard J. Doleshek
 
 
Richard J. Doleshek
 
 
Executive Vice President and Chief Financial Officer
 
 
 
 
 
 



List of Exhibits:
 
 
 
 
 
Exhibit No.
Exhibit
 
 
 
 
99.1
Press release issued February 24, 2016, by QEP Resources, Inc.
 



Exhibit


QEP RESOURCES REPORTS FOURTH QUARTER AND FULL YEAR 2015 FINANCIAL AND OPERATIONAL RESULTS AND ANNOUNCES 2016 GUIDANCE

Full Year 2015 Highlights

Reduced year-over-year capital expenditures by 41%, excluding acquisitions, while delivering record total production
Increased year-over-year crude oil production by more than 14%
Maintained strong liquidity, including $376 million of cash at year-end and undrawn revolving credit facility
Achieved record estimated year-end proved crude oil reserves

2016 Capital Investment Plan

Investing capital of $450 to $500 million, matched to forecasted cash flow
Maintaining three to four QEP-operated rigs during 2016, with one each in Williston, Permian and Pinedale
Forecasting flat crude oil production and a slight reduction in natural gas production compared with 2015
Suspending dividend payments to preserve cash and provide additional financial flexibility

DENVER — February 24, 2016 — QEP Resources, Inc. (NYSE: QEP) (QEP or the Company) today reported fourth quarter and full year 2015 financial and operating results. The Company reported a net loss of $38.6 million for the fourth quarter 2015, or $0.22 per diluted share, compared with net income of $665.9 million, or $3.72 per diluted share, in the fourth quarter 2014. For the year ended December 31, 2015, QEP reported a net loss of $149.4 million, or $0.85 per diluted share, compared with net income of $784.4 million, or $4.36 per diluted share, for the comparable 2014 period.

Net income or loss includes non-cash gains and losses associated with the change in the fair value of derivative instruments, gains and losses from asset sales, costs associated with the early extinguishment of debt, asset impairments and certain other non-cash and/or non-recurring items. Excluding these items, the Company's fourth quarter 2015 Adjusted Net Loss (a non-GAAP measure) was $1.8 million, or $0.01 per diluted share, compared with Adjusted Net Income of $38.6 million, or $0.22 per diluted share, in the fourth quarter 2014. For the year ended December 31, 2015, the Company’s Adjusted Net Income was $1.9 million, or $0.01 per diluted share, compared with Adjusted Net Income of $239.1 million, or $1.33 per diluted share, for 2014.

Adjusted EBITDA (a non-GAAP measure) for the fourth quarter 2015 was $254.0 million, compared with $386.3 million in the fourth quarter 2014. For the year ended December 31, 2015, the Company reported Adjusted EBITDA of $1,029.3 million compared with $1,483.3 million from continuing operations for 2014. The definition and reconciliations of Adjusted EBITDA and Adjusted Net Income to net income are provided within the financial tables of this release.

“Our high-quality, diversified E&P asset portfolio, combined with a year-end 2015 cash position of $376 million and an undrawn revolving credit facility, places QEP in an enviable position in today's challenging commodity price environment,” commented Chuck Stanley, Chairman, President and CEO of QEP Resources. “In the fourth quarter we continued to optimize production, increase operating efficiencies, reduce costs and allocate capital to the highest return assets in our portfolio."

“As a testament to our asset quality, we reported estimated 2015 year-end proved reserves of 3.6 trillion cubic feet of gas equivalent, an 8% decline from year-end 2014, despite a 47% and 40% decline in SEC year-end 2015 prices of crude oil and natural gas, respectively, from year-end 2014. We also achieved record estimated year-end proved crude oil reserves, and replaced 236% of total 2015 production, excluding price-related revisions."


1


“As we enter 2016, capital discipline remains the cornerstone of our corporate strategy. In response to current commodity prices, we have set a capital investment budget of $450 to $500 million, designed to match forecasted 2016 cash flow. The capital investment budget anticipates ramping down from nine QEP-operated rigs at the end of 2015 to three to four operated rigs for the remainder of the year, with one each on our Williston, Permian and Pinedale acreage. The budget also anticipates funding the completion of a portion of our inventory of drilled but not completed wells carried over from last year and provides flexibility for the addition of a fourth rig later in 2016. While we are reducing our 2016 capital program by over 50% compared with 2015, the combined benefits of lower well costs, continued improvements in new well productivity, and the quality of our assets should allow us to keep year-over-year oil production essentially flat, with natural gas production down slightly. In addition, we are suspending our $0.02 per quarter dividend to further bolster our liquidity. While the impact on our cash position is relatively small, we believe this is a prudent decision in this commodity price environment."

“Moving forward, we remain keenly focused on creating shareholder value through operational excellence, solid execution, technical innovation, and financial discipline. We will continue to actively manage our capital program to preserve our balance sheet, so we are in position to capitalize on our portfolio of top-tier assets when the commodity market improves,” concluded Stanley.

The “4Q 2015 Operations Update” presentation, which includes slides containing maps and other supporting materials referred to in this release, is posted on the Company’s website www.qepres.com.


2


QEP Financial Results Summary


Adjusted EBITDA by Operating Segment (1) 
 
Three Months Ended
 
Year Ended
 
December 31,
 
December 31,
 
2015
 
2014
 
Change
 
2015
 
2014
 
Change
 
(in millions)
QEP Energy
$
254.1

 
$
373.0

 
(32
)%
 
$
1,027.1

 
$
1,437.0

 
(29
)%
QEP Marketing and Other
(0.1
)
 
(6.9
)
 
99
 %
 
2.2

 
1.3

 
69
 %
Adjusted EBITDA from continuing operations
254.0


366.1


(31
)%

1,029.3


1,438.3


(28
)%
Adjusted EBITDA from discontinued operations

 
20.2

 
(100
)%
 

 
144.4

 
(100
)%
Adjusted EBITDA
$
254.0

 
$
386.3

 
(34
)%
 
$
1,029.3

 
$
1,582.7

 
(35
)%
 
 
 
 
 
 
 
 
 
 
 
 
(1) See attached financial tables of this release for a reconciliation of Adjusted EBITDA to net income.

QEP Energy

Adjusted EBITDA for the fourth quarter 2015 was $254.1 million, a 32% decrease from the fourth quarter 2014, primarily due to decreased average realized prices for crude oil, natural gas and NGL, partially offset by an increase in natural gas production.
Capital investment (on an accrual basis) for the fourth quarter 2015, was $218.6 million, down $15.4 million from the third quarter 2015, excluding acquisitions. Capital investment (on an accrual basis) for the year ended December 31, 2015, was $1,007.4 million, down 41% compared with the full year 2014, excluding acquisitions.
Net equivalent production decreased by 2% to 84.0 Bcfe in the fourth quarter 2015 compared with 85.9 Bcfe in the fourth quarter 2014. This decrease was primarily due to decreased crude oil and NGL production in the Williston Basin, partially offset by increased crude oil, NGL and natural gas production in the Permian Basin and increased natural gas production at Pinedale.
Crude oil and NGL production decreased 2% and 27%, respectively, while natural gas production increased 4%, in the fourth quarter 2015 compared with the fourth quarter 2014. Fourth quarter 2015 crude oil volumes were impacted by completion related shut-ins in the Williston Basin, while NGL volumes were lower due to operating in ethane rejection.
Crude oil and NGL production accounted for 67% of field-level revenues in the fourth quarter 2015. Field-level revenues decreased 43% in the fourth quarter 2015 compared with the fourth quarter 2014 due to lower crude oil and NGL prices and lower NGL volumes.
During the full year 2015, the Company invested nearly $100 million to acquire various oil and gas properties, including additional interests in QEP-operated wells, in several of its core areas of operation. These acquisitions were partially offset by the sale of certain non-core assets.
The Company has entered into additional crude oil and natural gas derivative contracts for 2016, 2017 and 2018 to help mitigate commodity price risk.  See tables provided in this release for further details.

QEP Marketing & Other

QEP Resources ended the fourth quarter 2015 with cash and cash equivalents of $376.1 million and no borrowings under its unsecured revolving credit facility. The credit facility was amended in the fourth quarter 2015. QEP's credit facility is not subject to semi-annual borrowing base redeterminations.
General and administrative expense for the fourth quarter 2015 was $40.4 million, a decrease of 30% compared with the fourth quarter 2014. For the year ended December 31, 2015, general and administrative expense was $181.1 million, a decrease of over 11% compared with the prior year. Full year 2015 general and administrative expense reflects one time charges of $2.7 million related to workforce reductions, $5.0 million related to the closure of our Tulsa, Oklahoma office and $11.2 million related to a pension curtailment.

3


Effective January 1, 2016, QEP terminated its contracts for resale and marketing transactions between its wholly owned subsidiaries, QEP Marketing and QEP Energy. QEP Energy will market its own gas, oil and NGL production. In addition, substantially all of QEP Marketing's third-party purchase and sale agreements and gathering, processing and transportation contracts have been assigned to QEP Energy, except those contracts related to natural gas storage activities and the Haynesville gathering system in Northwest Louisiana. As a result, a majority of intercompany transactions will be eliminated, and the Company will have one reportable segment. The change in affiliate transactions will simplify our business processes and financial statements.
QEP Resources suspended its cash dividend indefinitely in response to significant declines in crude oil, NGL and natural gas prices. The suspension of the dividend will allow the Company to preserve cash in the current commodity environment.


4


QEP 2016 Guidance


In response to the current commodity price environment QEP intends to reduce its capital budget for drilling and completions by over 50% compared with 2015. Due to efficiency gains, strong well performance and ongoing cost reduction initiatives, the Company expects to see essentially flat year-over-year crude oil production in 2016. The Company's guidance anticipates that its working rig count will decline from nine at year-end 2015 to approximately three to four rigs, with one each in the Williston and Permian basins and Pinedale, respectively, by the beginning of the second quarter 2016.

QEP Resources initial full year 2016 guidance and related assumptions are shown below. The Company’s guidance assumes no asset acquisitions or divestitures, and that QEP will not recover ethane from its produced gas for the entire year.

Initial 2016 Guidance
 
2016
 
Current Forecast
Oil production (MMBbl)
18.5 - 20.5
NGL production (MMBbl)
4 - 5
Natural gas production (Bcf)
165 - 175
   Total equivalent production (Bcfe)
300 - 328
 
 
Lease operating and transportation expense (per Mcfe)
$1.60 - $1.70
Depletion, depreciation and amortization (per Mcfe)
$3.00 - $3.30
Production and property taxes, % of field-level revenue
8.5%
 
 
Figures below in millions
General and administrative expense (1)
$150 - $160
 
 
Capital investment (excluding acquisitions)
$450 - $500

(1) Forecasted general and administrative expense includes approximately $35.0 million of non-cash expenses primarily related to share based compensation.

Estimated Proved Reserves


QEP Energy's estimated proved reserves totaled 3.6 Tcfe at December 31, 2015, down 8% from year-end 2014, primarily due to the net impact of lower crude oil, natural gas and NGL prices. Approximately 42% of total proved reserves at year-end 2015 were crude oil and NGL compared with 41% at year-end 2014. Proved developed reserves were 2.1 Tcfe, or 58%, of total estimated proved reserves at year-end 2015. Extensions and discoveries were 1.1 Tcfe, driven primarily by the Company's development activities in the Williston, Permian and Uinta basins. A reconciliation of reported quantities of estimated proved reserves is summarized in the table below:


5


 
 
Natural Gas
 
Oil
 
NGL
 
Natural Gas Equivalents
 
 
(Bcf)
 
(MMbbl)
 
(MMbbl)
 
(Bcfe)(1)
Balance at December 31, 2014
 
2,317.2

 
172.5

 
96.6

 
3,931.9

    Revisions of previous estimates(2)
 
(463.8
)
 
(47.0
)
 
(55.3
)
 
(1,077.9
)
    Extensions and discoveries
 
467.7

 
85.6

 
21.8

 
1,111.9

    Purchase of reserves in place
 
3.2

 
2.0

 
0.6

 
18.7

    Sale of reserves in place
 
(34.3
)
 
(0.4
)
 
(0.2
)
 
(37.6
)
    Production
 
(181.1
)
 
(19.6
)
 
(4.7
)
 
(326.8
)
Balance at December 31, 2015
 
2,108.9

 
193.1

 
58.8

 
3,620.2


(1) Oil and NGL are converted to natural gas equivalents at the ratio of one barrel of crude oil, condensate or NGL to six Mcf of natural gas equivalent.
(2) Price-related negative revisions totaled 756.9 Bcfe

Details on the reported quantities of estimated year-end 2015 and 2014 proved reserves presented by operating area, proved reserve category and percentage of total estimated proved reserves comprised of crude oil and NGL (liquids) are as follows:

 
 
Total (in Bcfe)
 
% of total
 
PUD %
 
liquids %
For the year ended December 31, 2015
 
 
 
 
 
 
Northern Region
 
 
 
 
 
 
 
 
Pinedale
 
1,125.0

 
31
%
 
27
%
 
13
%
Williston Basin
 
1,085.7

 
30
%
 
39
%
 
86
%
Uinta Basin
 
558.9

 
16
%
 
55
%
 
18
%
Other Northern
 
74.4

 
2
%
 
%
 
8
%
Southern Region
 

 

 


 


Haynesville/Cotton Valley
 
396.5

 
11
%
 
57
%
 
%
Permian Basin
 
374.0

 
10
%
 
66
%
 
87
%
Midcontinent
 
5.7

 
%
 
%
 
32
%
Total QEP Energy
 
3,620.2

 
100
%
 
42
%
 
42
%
 
 
 
 
 
 
 
 
 
For the year ended December 31, 2014
 
 
 
 
 
 
Northern Region
 
 
 
 
 
 
 
 
Pinedale
 
1,450.1

 
37
%
 
41
%
 
24
%
Williston Basin
 
858.9

 
22
%
 
40
%
 
88
%
Uinta Basin
 
623.0

 
16
%
 
48
%
 
32
%
Other Northern
 
94.0

 
2
%
 
%
 
11
%
Southern Region
 
 
 
 
 


 


Haynesville/Cotton Valley
 
493.9

 
13
%
 
57
%
 
%
Permian Basin
 
375.7

 
10
%
 
58
%
 
78
%
Midcontinent
 
36.3

 
%
 
%
 
19
%
Total QEP Energy
 
3,931.9

 
100
%
 
44
%
 
41
%


6


Operations Summary

The table below presents a summary of QEP-operated and non-operated well completions for the year ended December 31, 2015:

 
Operated Completions
 
Non-operated Completions
 
Three Months Ended December 31, 2015
 
Year Ended December 31, 2015
 
Three Months Ended December 31, 2015
 
Year Ended December 31, 2015
 
Gross
 
Net
 
Gross
 
Net
 
Gross
 
Net
 
Gross
 
Net
Northern Region
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Pinedale
24

 
14.4

 
107

 
68.1

 

 

 

 

Williston Basin
10

 
7.8

 
70

 
55.0

 
16

 
0.5

 
84

 
4.7

Uinta Basin

 

 
11

 
11.0

 

 

 
19

 
0.2

Other Northern

 

 
4

 
4.0

 

 

 

 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Southern Region
 
 
 
 
 

 
 

 
 
 
 
 
 

 
 

Haynesville/Cotton Valley

 

 

 

 
4

 
0.3

 
24

 
3.2

Permian Basin
5

 
4.7

 
36

 
31.6

 
1

 
0.6

 
2

 
0.9

Midcontinent

 

 

 

 

 

 
4

 
0.1


7


Williston Basin

Williston Basin net production averaged approximately 51.6 Mboed (90% liquids) during the fourth quarter 2015, a decrease of 4% compared with both the third quarter 2015 and fourth quarter 2014. The Company completed and turned to sales 10 gross operated wells during the quarter (average working interest 78%), all in South Antelope. Williston Basin production was impacted during the quarter by offset completion activity, which resulted in shut-ins and curtailments of existing wells. The Company also participated in 16 gross outside-operated Bakken/Three Forks wells that were completed and turned to sales during the quarter (average working interest 3%). (See Slide 6)

The Company's five high-density infill pilot wells spaced at 400- and 600-foot intervals in the Middle Bakken and the Three Forks formations that were initially completed and turned to sales in the second quarter 2015 continue to perform strongly. During the fourth quarter, the Company turned to sales five additional high-density infill pilot wells spaced at 600 feet which brings the total wells turned to sales within the pilot area to 21.

QEP also continued to conduct tests on the second bench of the Three Forks Formation, with four wells completed in this zone recently turned to sales with an average 24-hour IP of 2,665 Boed. Finally, during the fourth quarter the Company turned to sales its first third bench Three Forks test with a 24-hour IP of 3,058 Boed. The well continues to show promising early-time performance, closely tracking cumulative production performance of first and second bench wells. (See Slides 7-10)

As the Company continues infill development, the anticipated well pod size (well pods are clusters of closely-spaced wellheads) is expected to increase from a current average of four wells per pod to as many as 12 wells per pod. Larger well pods will result in increased latency between drilling and completion operations as more wells are temporarily “trapped” under a drilling rig until all wells on a pod are finished, the rig is removed, and completion operations can begin, and greater downtime for offset fracture stimulations, resulting in more variability in production volumes from the Company's Williston Basin assets in the future.

At the end of the fourth quarter, QEP had 24 gross operated wells waiting on completion (comprised of 21 in South Antelope and three at Ft. Berthold, average working interest 95%) in the Williston Basin and three operated rigs running in South Antelope. In addition, the Company had interest in 19 gross non-operated wells waiting on completion (average working interest 5%) at the end of the fourth quarter.

Current average gross QEP-operated drilled and completed authorization for expenditure ("AFE") well costs are $6.0 million on South Antelope, with costs associated with facilities and artificial lift adding approximately $0.8 million per well on average. The Company expects the operated rig count in South Antelope to drop to one rig by the beginning of the second quarter 2016.

Slides 5-11 depict QEP Energy's acreage and activity in the Williston Basin.


8


Permian Basin

Permian Basin net production averaged 13.8 Mboed (84% liquids) during the fourth quarter 2015, a 5% increase over the third quarter 2015 and a 42% increase over the fourth quarter 2014. QEP completed and turned to sales five gross-operated horizontal wells in the fourth quarter 2015 (average working interest 94%). One well targeted the Spraberry Shale and four targeted the Middle Spraberry. Four of the five wells reached peak production during the quarter; the University 7-1302 H2 SS, completed in the Spraberry Shale, achieved a peak 24-hour IP rate of 1,753 Boed and the Mabee C H19 MS, Mabee C H20 MS, and University 7-1302 H1 MS wells, all targeting the Middle Spraberry achieving peak 24-hour rates of 863 Boed, 961 Boed, and 1,115 Boed, respectively.

At the end of the fourth quarter, QEP had four gross-operated horizontal wells (two Spraberry Shale and two Middle Spraberry) waiting on completion (average working interest 98%) and two operated rigs in the Permian Basin drilling horizontal targets.

Current average gross QEP-operated drilled and completed AFE well costs are $5.7 million for Spraberry wells, with costs associated with facilities and artificial lift adding approximately $0.7 million per well, on average. The Company expects the operated rig count in the Permian Basin to drop to one rig by the beginning of the second quarter 2016.

Slides 12-15 depict QEP Energy's acreage and activity in the Permian Basin.

Pinedale

Pinedale net production averaged 304 MMcfed (14% liquids), a new natural gas production record for QEP, during the fourth quarter 2015. This represented a 6% increase over the third quarter 2015 and a 7% increase over the fourth quarter 2014. The Company completed and turned to sales 24 gross-operated Pinedale wells in the quarter.

At the end of the fourth quarter, QEP had 20 gross-operated Pinedale wells waiting on completion (average working interest 63%) and three operated rigs running in Pinedale.

Current average gross QEP-operated drilled and completed AFE well costs are $2.9 million in Pinedale, with costs associated with facilities and plunger lift adding approximately $0.2 million per well, on average. The Company expects operated rig count in Pinedale to drop to one rig by the beginning of the second quarter 2016.

Slide 16 depicts QEP Energy's acreage and activity at Pinedale.

Uinta Basin

Uinta Basin net production averaged 71 MMcfed (21% liquids), during the fourth quarter 2015, of which 43 MMcfed (10% liquids) was from the Lower Mesaverde play.

QEP’s continued focus on drilling and completion optimization is yielding encouraging results in the Lower Mesaverde play. The Company's most recent horizontal well exhibited strong peak production early in the fourth quarter while drilling days and completed well costs continued to decrease. Production performance from the pad of eight directionally drilled vertical wells targeting the Lower Mesaverde (completed at the end of the second quarter 2015) continues to be solid. These wells have achieved over 3.5 Bcfe gross aggregate cumulative production after 224 days online (post refrigeration-processing). The Company believes it has an extensive inventory of vertical and horizontal well locations in the Lower Mesaverde play, and recent results continue to further de-risk this multi-Tcfe resource.

At the end of the fourth quarter, QEP had one rig active in the Uinta Basin drilling an eight well pad of directional vertical wells targeting the Lower Mesaverde play. The Company expects to operate no rigs in the Uinta Basin once QEP has completed drilling on the current eight well pad.

Slide 17 depicts QEP Energy's activity in the Red Wash Lower Mesaverde play in the Uinta Basin.

9



Fourth Quarter 2015 and Full Year Results Conference Call


QEP Resources' management will discuss fourth quarter and full year 2015 results in a conference call on Thursday, February 25, 2016, beginning at 9:00 a.m. EST. The conference call can be accessed at www.qepres.com. You may also participate in the conference call by dialing (877) 869-3847 in the U.S. or Canada and (201) 689-8261 for international calls. A replay of the teleconference will be available on the website at www.qepres.com immediately after the call through March 25, 2015, or by dialing (877) 660-6853 in the U.S. or Canada and (201) 612-7415 for international calls, and then entering the conference ID #13628460. In addition, QEP’s slides for the fourth quarter 2015, with updated maps showing QEP’s leasehold and current activity for key operating areas discussed in this release, can be found on the Company’s website at www.qepres.com.



About QEP Resources, Inc.



10


QEP Resources, Inc. (NYSE:QEP) is a leading independent natural gas and crude oil exploration and production company focused in two major regions: the Northern Region (primarily the Rockies and the Williston Basin) and the Southern Region (primarily Texas and Louisiana) of the United States. For more information, visit QEP Resources' website at: www.qepres.com.

11


Forward-Looking Statements


This release includes forward-looking statements within the meaning of Section 27(a) of the Securities Act of 1933, as amended, and Section 21(e) of the Securities Exchange Act of 1934, as amended. Forward-looking statements can be identified by words such as “anticipates,” “believes,” “forecasts,” “plans,” “estimates,” “expects,” “should,” “will” or other similar expressions. Such statements are based on management’s current expectations, estimates and projections, which are subject to a wide range of uncertainties and business risks. These forward-looking statements include statements regarding: our 2016 Capital Investment Plan, including amount of planned capital expenditures, the number and location of drilling rigs to be deployed, anticipated production levels and the suspension of dividend payments; our high quality, diversified E&P asset portfolio; our liquidity; our focus on capital discipline; plans to match spending with anticipated cash flows; funding the completion in 2016 of a portion of our wells drilled but not completed in 2015; adding a fourth rig during 2016; expected gross completed well costs and additional costs for facilities and artificial lift; variability in production volumes from the Williston Basin and factors contributing to such variability; forecasted production, lease operating and transportation expense, depletion, depreciation and amortization expense, general and administrative expense, production and property taxes and capital investment for 2015 and related assumptions for such guidance; plans to reject ethane in 2016; drilling and completion optimization; operational excellence; solid execution; technical innovation; preservation of our balance sheet; estimated reserves; our extensive inventory of drilling locations; simplification of our business processes and financial statements by eliminating certain intercompany transactions; preservation of cash; the pension curtailment loss; and the importance of non-GAAP financial measures. Actual results may differ materially from those included in the forward-looking statements due to a number of factors, including, but not limited to: changes in natural gas, NGL and oil prices; liquidity constraints, including those resulting from the cost or unavailability of financing due to debt and equity capital and credit market conditions, changes in our credit rating, our compliance with loan covenants, the increasing credit pressure on our industry or demands for cash collateral by counterparties to derivative and other contracts; global geopolitical and macroeconomic factors; the activities of the Organization of Petroleum Exporting Countries (OPEC), including the ability of members of OPEC to agree to and maintain oil price and production controls and the ability of Iran to market its oil following the lifting of trade sanctions; general economic conditions, including interest rates; changes in local, regional, national and global demand for natural gas, oil and NGL; impact of new laws and regulations, including regulations regarding the flaring of natural gas, the use of hydraulic fracture stimulation and the implementation of the Dodd-Frank Act; impact of U.S. dollar exchange rates on oil, NGL and natural gas prices; elimination of federal income tax deductions for oil and gas exploration and development; imposition of a federal tax on each barrel of oil produced in the United States; drilling results; shortages of oilfield equipment, services and personnel; the availability of storage and refining capacity; operating risks such as unexpected drilling conditions; transportation constraints; weather conditions; changes in maintenance, service and construction costs; permitting delays; outcome of contingencies such as legal proceedings; inadequate supplies of water and/or lack of water disposal sources; and the other risks discussed in the Company’s periodic filings with the Securities and Exchange Commission, including the Risk Factors section of the Company’s Annual Report on Form 10-K for the year ended December 31, 2015. QEP Resources undertakes no obligation to publicly correct or update the forward-looking statements in this news release, in other documents, or on the website to reflect future events or circumstances. All such statements are expressly qualified by this cautionary statement.

Disclosures regarding non-proved reserves


The Securities and Exchange Commission (SEC) requires oil and gas companies, in their filings with the SEC, to disclose proved reserves that a company has demonstrated by actual production or through reliable technology to be economically and legally producible at specific prices and existing economic and operating conditions. The SEC permits optional disclosure of probable and possible reserves; however, QEP has made no such disclosures in its filings with the SEC. Estimates of probable and possible reserves are by their nature more speculative than estimates of proved reserves and, accordingly, are subject to substantially more risks of actually being realized. Actual quantities that may be ultimately recovered from QEP’s interests may differ substantially from the reserve estimates contained in this release. Investors are urged to closely consider the disclosures and risk factors about the Company’s reserves in its Annual Report on Form 10-K for the year ended December 31, 2015, and in other reports on file with the SEC.


12


Contact

Investors:                    Media:
William I. Kent                    Brent Rockwood
Director, Investor Relations            Director, Communications
303-405-6665                    303-672-6999


13


QEP RESOURCES, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
 
Three Months Ended
 
Year Ended
 
December 31,
 
December 31,
 
2015
 
2014
 
2015
 
2014
REVENUES
(in millions, except per share amounts)
Gas sales
$
105.2

 
$
167.2

 
$
468.5

 
$
776.4

Oil sales
193.3

 
327.5

 
834.2

 
1,368.5

NGL sales
18.3

 
44.0

 
80.0

 
223.3

Other revenues
2.7

 
6.0

 
15.1

 
11.1

Purchased gas and oil sales (1)
148.8

 
212.4

 
620.8

 
913.9

Total Revenues
468.3

 
757.1

 
2,018.6

 
3,293.2

OPERATING EXPENSES
 

 
 

 
 

 
 

Purchased gas and oil expense (1)
151.7

 
213.2

 
626.8

 
910.1

Lease operating expense
63.2

 
63.1

 
238.8

 
240.1

Gas, oil and NGL transportation and other handling costs
75.1

 
79.1

 
291.3

 
277.6

Gathering and other expense
1.4

 
1.9

 
5.8

 
6.7

General and administrative
40.4

 
57.4

 
181.1

 
204.4

Production and property taxes
26.9

 
44.4

 
117.6

 
205.2

Depreciation, depletion and amortization
231.8

 
282.2

 
881.1

 
994.7

Exploration expenses

 
5.2

 
2.7

 
9.9

Impairment
20.1

 
1,139.6

 
55.6

 
1,143.2

Total Operating Expenses
610.6

 
1,886.1

 
2,400.8

 
3,991.9

Net gain (loss) from asset sales
(2.3
)
 
61.7

 
4.6

 
(148.6
)
OPERATING INCOME (LOSS)
(144.6
)
 
(1,067.3
)
 
(377.6
)
 
(847.3
)
Realized and unrealized gains (losses) on derivative contracts
108.7

 
376.5

 
277.2

 
363.3

Interest and other income
1.5

 
5.0

 
3.0

 
12.8

Income from unconsolidated affiliates

 
0.1

 

 
0.3

Loss from early extinguishment of debt

 
(2.0
)
 

 
(2.0
)
Interest expense
(36.2
)
 
(40.7
)
 
(145.6
)
 
(169.1
)
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
(70.6
)
 
(728.4
)
 
(243.0
)
 
(642.0
)
Income tax (provision) benefit
32.0

 
258.6

 
93.6

 
232.5

NET INCOME (LOSS) FROM CONTINUING OPERATIONS
(38.6
)
 
(469.8
)
 
(149.4
)
 
(409.5
)
Net income from discontinued operations, net of income tax

 
1,135.7

 

 
1,193.9

NET INCOME (LOSS)
$
(38.6
)
 
$
665.9

 
$
(149.4
)
 
$
784.4

 
 
 
 
 
 
 
 
Earnings (loss) per common share
 

 
 

 
 

 
 

Basic from continuing operations
$
(0.22
)
 
$
(2.62
)
 
$
(0.85
)
 
$
(2.28
)
Basic from discontinued operations

 
6.34

 

 
6.64

Basic total
$
(0.22
)
 
$
3.72

 
$
(0.85
)
 
$
4.36

Diluted from continuing operations
$
(0.22
)
 
$
(2.62
)
 
$
(0.85
)
 
$
(2.28
)
Diluted from discontinued operations

 
6.34

 

 
$
6.64

Diluted total
$
(0.22
)
 
$
3.72

 
$
(0.85
)
 
$
4.36

 
 
 
 
 
 
 
 
Weighted-average common shares outstanding
 
 
 
 
 
 
 
Used in basic calculation
176.7

 
179.0

 
176.6

 
179.8

Used in diluted calculation
176.7

 
179.0

 
176.6

 
179.8

Dividends per common share
$
0.02


$
0.02

 
$
0.08


$
0.08

 ____________________________
(1) 
In the fourth quarter of 2015, the Company determined that certain transactions that had been reported on a gross basis and included in "Purchased gas and oil sales" and "Purchased gas and oil expense" on the Consolidated Statement of Operations for certain periods in 2014 and the first three quarters of 2015 should have been reported net, as the transactions were with the same counterparty and were entered into in contemplation of one another. The Company revised its financial statements to reflect the net accounting treatment and assessed the cumulative impact of the revisions on each period affected. The revisions had no effect on the Company’s operating income, net income, earnings per share or cash flows. The Company determined that the impact of the change from gross to net accounting was not material, either individually or in the aggregate, to previously issued financial statements. The Company has, however, recast its Consolidated Statement of Operations for the year ended December 31, 2014, to report “Purchased gas and oil sales” and “Purchased gas and oil expense” on a net basis to conform to presentation for the year ended December 31, 2015.

14


QEP RESOURCES, INC.
CONSOLIDATED BALANCE SHEETS
 
December 31,
2015
 
December 31,
2014
ASSETS
(in millions)
Current Assets
 
 
 
Cash and cash equivalents
$
376.1

 
$
1,160.1

Accounts receivable, net
278.2

 
441.9

Income tax receivable
87.3

 

Fair value of derivative contracts
146.8

 
339.0

Gas, oil and NGL inventories, at lower of average cost or market
13.3

 
13.7

Prepaid expenses and other
30.1

 
46.8

Total Current Assets
931.8

 
2,001.5

Property, Plant and Equipment (successful efforts method for oil and gas properties)
 
 

Proved properties
13,314.9

 
12,278.7

Unproved properties
691.0

 
825.2

Marketing and other
297.9

 
293.8

Materials and supplies
38.5

 
54.3

Total Property, Plant and Equipment
14,342.3

 
13,452.0

Less Accumulated Depreciation, Depletion and Amortization
 

 
 

Exploration and production
6,870.2

 
6,153.0

Marketing and other
87.5

 
67.8

Total Accumulated Depreciation, Depletion and Amortization
6,957.7

 
6,220.8

Net Property, Plant and Equipment
7,384.6

 
7,231.2

Fair value of derivative contracts
23.2

 
9.9

Other noncurrent assets
85.9

 
44.2

TOTAL ASSETS
$
8,425.5

 
$
9,286.8

LIABILITIES AND EQUITY
 

 
 

Current Liabilities
 

 
 

Checks outstanding in excess of cash balances
$
29.8

 
$
54.7

Accounts payable and accrued expenses
351.7

 
575.4

Income taxes payable

 
532.1

Production and property taxes
46.1

 
61.7

Interest payable
36.4

 
36.4

Fair value of derivative contracts
0.8

 

Deferred income taxes

 
84.5

Current portion of long-term debt
176.8

 

Total Current Liabilities
641.6

 
1,344.8

Long-term debt
2,042.0

 
2,218.1

Deferred income taxes
1,479.8

 
1,362.7

Asset retirement obligations
204.9

 
193.8

Fair value of derivative contracts
4.0

 

Other long-term liabilities
105.3

 
92.1

Commitments and Contingencies


 


EQUITY
 

 
 

Common stock - par value $0.01 per share; 500.0 million shares authorized; 177.3 million and 176.2 million shares issued, respectively
1.8

 
1.8

Treasury stock - 0.5 million and 0.8 million shares, respectively
(14.6
)
 
(25.4
)
Additional paid-in capital
554.8

 
535.3

Retained earnings
3,418.3

 
3,587.9

Accumulated other comprehensive income (loss)
(12.4
)
 
(24.3
)
Total Common Shareholders' Equity
3,947.9

 
4,075.3

TOTAL LIABILITIES AND EQUITY
$
8,425.5


$
9,286.8


15


QEP RESOURCES, INC.
CONSOLIDATED CASH FLOWS
 
Year Ended
 
December 31,
 
2015
 
2014
 
(in millions)
OPERATING ACTIVITIES
 

 
 

Net income (loss)
$
(149.4
)
 
$
784.4

Net income attributable to noncontrolling interest

 
21.6

Adjustments to reconcile net income to net cash provided by operating activities:
 
 

Depreciation, depletion and amortization
881.1

 
1,040.6

Deferred income taxes
25.3

 
(84.1
)
Impairment
55.6

 
1,143.2

Share-based compensation
34.7

 
27.2

Pension curtailment
11.2

 

Amortization of debt issuance costs and discounts
6.2

 
6.7

Net loss (gain) from asset sales
(4.6
)
 
(1,644.8
)
Income from unconsolidated affiliates

 
(5.2
)
Distributions from unconsolidated affiliates and other

 
9.4

Non-cash loss on early extinguishment of debt

 
4.4

Unrealized (gains) losses on marketable securities
0.2

 

Unrealized (gains) losses on derivative contracts
183.7

 
(374.4
)
Changes in operating assets and liabilities
(562.7
)
 
613.5

Net Cash Provided by Operating Activities
481.3

 
1,542.5

INVESTING ACTIVITIES
 

 
 

Property acquisitions
(98.3
)
 
(960.5
)
Property, plant and equipment, including dry hole exploratory well expense
(1,141.1
)
 
(1,765.9
)
Proceeds from disposition of assets
21.8

 
3,296.6

Acquisition deposit held in escrow

 
50.0

Other investing activities

 
(42.0
)
Net Cash Provided by (Used in) Investing Activities
(1,217.6
)
 
578.2

FINANCING ACTIVITIES
 

 
 

Checks outstanding in excess of cash balances
(24.9
)
 
(54.4
)
Long-term debt issued

 
300.0

Long-term debt issuance costs paid
(2.6
)
 
(9.3
)
Long-term debt repaid

 
(600.0
)
Proceeds from credit facility

 
5,455.0

Repayments of credit facility

 
(5,935.0
)
Common stock repurchased and retired

 
(99.7
)
Treasury stock repurchases
(2.7
)
 
(6.2
)
Other capital contributions
(0.2
)
 
6.0

Dividends paid
(14.1
)
 
(14.6
)
Excess tax (provision) benefit on share-based compensation
(3.2
)
 
(0.5
)
Distribution to noncontrolling interest

 
(31.9
)
Net Cash Provided by (Used in) Financing Activities
(47.7
)
 
(990.6
)
Change in cash and cash equivalents
(784.0
)
 
1,130.1

Beginning cash and cash equivalents
1,160.1

 
30.0

Ending cash and cash equivalents
$
376.1

 
$
1,160.1


16


QEP Energy - Production by Region
 
Three Months Ended December 31,
 
Year Ended December 31,
 
2015

2014

Change

2015

2014

Change
 
(in Bcfe)
Northern Region
 
 
 
 
 
 
 
 
 
 
 
Pinedale
28.0

 
26.3

 
6
 %
 
101.0

 
98.9

 
2
 %
Williston Basin
28.5

 
29.8

 
(4
)%
 
112.3

 
91.4

 
23
 %
Uinta Basin
6.5

 
7.5

 
(13
)%
 
29.5

 
27.3

 
8
 %
Other Northern
2.8

 
2.7

 
4
 %
 
10.6

 
10.6

 
 %
Total Northern Region
65.8

 
66.3

 
(1
)%
 
253.4

 
228.2

 
11
 %
Southern Region
 
 
 
 
 
 
 
 
 
 
 
Haynesville/Cotton Valley
10.3

 
11.0

 
(6
)%
 
43.6

 
49.9

 
(13
)%
Permian
7.6

 
5.4

 
41
 %
 
26.0

 
15.8

 
65
 %
Midcontinent
0.3

 
3.2

 
(91
)%
 
3.8

 
28.8

 
(87
)%
Total Southern Region
18.2

 
19.6

 
(7
)%
 
73.4

 
94.5

 
(22
)%
Total production
84.0

 
85.9

 
(2
)%
 
326.8

 
322.7

 
1
 %


QEP Energy - Total Production
 
Three Months Ended December 31,
 
Year Ended December 31,
 
2015
 
2014
 
Change
 
2015
 
2014
 
Change
QEP Energy Production Volumes
 
 
 
 
 
 
 
 
 
 
 
Gas (Bcf)
46.0

 
44.4

 
4
 %
 
181.1

 
179.3

 
1
 %
Oil (Mbbl)
5,062.9

 
5,181.5

 
(2
)%
 
19,582.3

 
17,146.5

 
14
 %
NGL (Mbbl)
1,272.0

 
1,751.3

 
(27
)%
 
4,704.3

 
6,769.1

 
(31
)%
Total production (Bcfe)
84.0

 
85.9

 
(2
)%
 
326.8

 
322.7

 
1
 %
Average daily production (MMcfe)
913.0

 
933.2

 
(2
)%
 
895.3

 
884.0

 
1
 %


17


QEP Energy - Prices
 
Three Months Ended December 31,
 
Year Ended December 31,
 
2015

2014

Change

2015

2014

Change
Gas (per Mcf)
 
 
 
 
 
 
 
 
 
 
 
Average field-level price
$
2.29

 
$
3.78

 
 
 
$
2.59

 
$
4.33

 
 
Commodity derivative impact
0.75

 
0.15

 
 
 
0.57

 
(0.09
)
 
 
Net realized price
$
3.04

 
$
3.93

 
(23
)%
 
$
3.16

 
$
4.24

 
(25
)%
Oil (per bbl)
 
 
 
 
 
 
 
 
 
 
 
Average field-level price
$
38.16

 
$
63.21

 
 
 
$
42.59

 
$
79.79

 
 
Commodity derivative impact
21.41

 
12.71

 
 
 
18.06

 
0.92

 
 
Net realized price
$
59.57

 
$
75.92

 
(22
)%
 
$
60.65

 
$
80.71

 
(25
)%
NGL (per bbl)
 
 
 
 
 
 
 
 
 
 
 
Average field-level price
$
14.41

 
$
25.15

 
 
 
$
16.98

 
$
32.95

 
 
Commodity derivative impact

 

 
 
 

 

 
 
Net realized price
$
14.41

 
$
25.15

 
(43
)%
 
$
16.98

 
$
32.95

 
(48
)%
Average net equivalent price (per Mcfe)
 
 
 
 
 
 
 
 
 
 
 
Average field-level price
$
3.77

 
$
6.28

 
 
 
$
4.23

 
$
7.34

 
 
Commodity derivative impact
1.70

 
0.84

 
 
 
1.40

 
(0.01
)
 
 
Net realized price
$
5.47

 
$
7.12

 
(23
)%
 
$
5.63

 
$
7.33

 
(23
)%

 
Three Months Ended December 31,
 
Year Ended December 31,
 
(per Mcfe)
 
2015
 
2014
 
Change
 
2015
 
2014
 
Change
 
 
Depreciation, depletion and amortization
$
2.73

 
$
3.26

 
(16
)%
 
$
2.66

 
$
3.05

 
(13
)%
Lease operating expense
0.75

 
0.74

 
1
 %
 
0.73

 
0.74

 
(1
)%
Gas, oil and NGL transportation and other handling costs
0.92

 
0.93

 
(1
)%
 
0.92

 
0.90

 
2
 %
Production taxes
0.32

 
0.52

 
(38
)%
 
0.35

 
0.63

 
(44
)%
Total Operating Expenses
$
4.72

 
$
5.45

 
(13
)%
 
$
4.66

 
$
5.32

 
(12
)%


18


QEP RESOURCES, INC.
NON-GAAP MEASURES

Adjusted EBITDA

This release contains references to the non-GAAP measure of Adjusted EBITDA. Management believes Adjusted EBITDA is an important measure of the Company's financial and operating performance that allows investors to understand how management evaluates financial performance to make operating decisions and allocate resources. Management defines Adjusted EBITDA as earnings before interest, income taxes, depreciation, depletion and amortization (EBITDA) adjusted to exclude changes in fair value of derivative contracts, exploration expenses, gains and losses from asset sales, impairment, and certain other non-cash and/or non-recurring items. The following tables reconcile net income to Adjusted EBITDA:
 
QEP Energy
 
QEP Marketing & Other (1)
 
Continuing Operations
 
Discontinued Operations
 
QEP Consolidated
Three Months Ended December 31, 2015
(in millions)
Net income (loss)
$
(51.0
)
 
$
12.4

 
$
(38.6
)
 
$

 
$
(38.6
)
Unrealized gains on derivative contracts
35.4

 
0.3

 
35.7

 

 
35.7

Net (gain) loss from asset sales
2.2

 
0.1

 
2.3

 

 
2.3

Interest and other income
(1.4
)
 
(0.1
)
 
(1.5
)
 

 
(1.5
)
Income tax provision (benefit)
(32.7
)
 
0.7

 
(32.0
)
 

 
(32.0
)
Interest expense
52.3

 
(16.1
)
 
36.2

 

 
36.2

Depreciation, depletion and amortization
229.2

 
2.6

 
231.8

 

 
231.8

Impairment
20.1

 

 
20.1

 

 
20.1

Exploration expenses

 

 

 

 

Adjusted EBITDA
$
254.1

 
$
(0.1
)
 
$
254.0

 
$


$
254.0

 
 
 
 
 
 
 
 
 
 
Three Months Ended December 31, 2014
 
 
 
Net income (loss)
$
(472.9
)
 
$
3.1

 
$
(469.8
)
 
$
1,135.7

 
$
665.9

Unrealized losses on derivative contracts
(304.4
)
 
(4.1
)
 
(308.5
)
 

 
(308.5
)
Net (gain) loss from asset sales
(61.7
)
 

 
(61.7
)
 
(1,793.5
)
 
(1,855.2
)
Interest and other income
(4.4
)
 
(0.6
)
 
(5.0
)
 
(0.3
)
 
(5.3
)
Income tax provision (benefit)
(255.9
)
 
(2.7
)
 
(258.6
)
 
675.4

 
416.8

Interest expense (income) (2)
47.8

 
(7.1
)
 
40.7

 
0.6

 
41.3

Loss on early extinguishment of debt

 
2.0

 
2.0

 
2.4

 
4.4

Depreciation, depletion and amortization (3)
279.7

 
2.5

 
282.2

 
(0.1
)
 
282.1

Impairment
1,139.6

 

 
1,139.6

 

 
1,139.6

Exploration expenses
5.2

 

 
5.2

 

 
5.2

Adjusted EBITDA
$
373.0

 
$
(6.9
)
 
$
366.1

 
$
20.2

 
$
386.3

_________________________
(1) 
Includes intercompany eliminations.
(2) 
Excludes noncontrolling interest's share of $0.4 million of during the three months ended December 31, 2014, of interest expense attributable to QEP Midstream Partners, L.P. (QEP Midstream), divested by the Company in December 2014 as part of the sale of our midstream assets.
(3) 
Excludes noncontrolling interests' share of $2.7 million during the three months ended December 31, 2014, of depreciation, depletion and amortization attributable to QEP Midstream and Rendezvous Gas Services, L.L.C., also divested by the Company in December 2014 as part of the sale of our midstream assets.



19


 
QEP Energy
 
QEP Marketing & Other (1)
 
Continuing Operations
 
Discontinued Operations
 
QEP Consolidated
For the Year Ended December 31, 2015
(in millions)
Net income (loss)
$
(182.9
)
 
$
33.5

 
$
(149.4
)
 
$

 
$
(149.4
)
Unrealized gains on derivative contracts
182.9

 
0.8

 
183.7

 

 
183.7

Net (gain) loss from asset sales
(9.7
)
 
5.1

 
(4.6
)
 

 
(4.6
)
Interest and other income
(1.9
)
 
(1.1
)
 
(3.0
)
 

 
(3.0
)
Income tax provision (benefit)
(105.9
)
 
12.3

 
(93.6
)
 

 
(93.6
)
Interest expense (income)
204.5

 
(58.9
)
 
145.6

 

 
145.6

Pension curtailment loss (2)
11.0

 
0.2

 
11.2

 

 
11.2

Depreciation, depletion and amortization
870.8

 
10.3

 
881.1

 

 
881.1

Impairment
55.6

 

 
55.6

 

 
55.6

Exploration expenses
2.7

 

 
2.7

 

 
2.7

Adjusted EBITDA
$
1,027.1

 
$
2.2

 
$
1,029.3

 
$


$
1,029.3

 
 
 
 
 
 
 
 
 
 
For the Year Ended December 31, 2014
 
 
 
Net income (loss)
$
(432.5
)
 
$
23.0

 
$
(409.5
)
 
$
1,193.9

 
$
784.4

Unrealized (gains) losses on derivative contracts
(368.2
)
 
(6.2
)
 
(374.4
)
 

 
(374.4
)
Net (gain) loss from asset sales
148.6

 

 
148.6

 
(1,793.4
)
 
(1,644.8
)
Interest and other income
(11.8
)
 
(1.0
)
 
(12.8
)
 
(0.3
)
 
(13.1
)
Income tax provision (benefit)
(246.9
)
 
14.4

 
(232.5
)
 
708.2

 
475.7

Interest expense (income)(3)
210.3

 
(41.2
)
 
169.1

 
2.3

 
171.4

Loss on early extinguishment of debt

 
2.0

 
2.0

 
2.4

 
4.4

Depreciation, depletion and amortization(4)
984.4

 
10.3

 
994.7

 
31.3

 
1,026.0

Impairment
1,143.2

 

 
1,143.2

 

 
1,143.2

Exploration expenses
9.9

 

 
9.9

 

 
9.9

Adjusted EBITDA
$
1,437.0

 
$
1.3

 
$
1,438.3

 
$
144.4


$
1,582.7

_________________________
(1) 
Includes intercompany eliminations.
(2) 
The pension curtailment is a non-cash expense incurred during the year ended December 31, 2015, due to changes in the Company's pension plan. The Company believes that the pension curtailment loss does not reflect expected future operating performance or provide meaningful comparisons to past operating performance and therefore has excluded the loss from the calculation of QEP's Adjusted EBITDA.
(3) 
Excludes noncontrolling interest's share of $1.5 million during the year ended December 31, 2014, of interest expense attributable to QEP Midstream.
(4) 
Excludes noncontrolling interests' share of $14.6 million during the year ended December 31, 2014, of depreciation, depletion and amortization attributable to Rendezvous Gas Services, L.L.C. and QEP Midstream.





20


Adjusted Net Income

This release also contains references to the non-GAAP measure of Adjusted Net Income. Management defines Adjusted Net Income as earnings excluding gains and losses from asset sales, unrealized gains and losses on derivative contracts, costs from early extinguishment of debt, asset impairments and certain other non-cash and/or non-recurring items. Management believes Adjusted Net Income is an important measure of the Company’s operational performance relative to other gas and oil producing companies.

The following table reconciles net income to Adjusted Net Income:
 
Three Months Ended
Year Ended
 
December 31,
December 31,
 
2015
 
2014
 
2015
 
2014
 
(in millions, except earnings per share)
Net income (loss)
$
(38.6
)
 
$
665.9

 
$
(149.4
)
 
$
784.4

Adjustments to net income
 
 
 
 
 
 
 
Net (gain) loss from asset sales from continuing operations
2.3

 
(61.7
)
 
(4.6
)
 
148.6

Income taxes on net (gain) loss from asset sales from continuing operations
(0.8
)
 
21.9

 
1.8

 
(53.8
)
Net (gain) loss from asset sales from discontinued operations

 
(1,793.5
)
 

 
(1,793.4
)
Income taxes on net (gain) loss from asset sales from discontinued operations

 
667.2

 

 
660.0

Unrealized (gains) losses on derivative contracts from continuing operations
35.7

 
(308.5
)
 
183.7

 
(374.4
)
Income taxes on unrealized (gains) losses on derivative contracts from continuing operations
(13.1
)
 
109.5

 
(70.7
)
 
135.5

Pension curtailment loss

 

 
11.2

 

Income taxes on pension curtailment loss

 

 
(4.3
)
 

Loss on early extinguishment of debt from continuing operations

 
2.0

 

 
2.0

Income taxes on loss from early extinguishment of debt from continuing operations

 
(0.7
)
 

 
(0.7
)
Loss on early extinguishment of debt from discontinued operations

 
2.4

 

 
2.4

Income taxes on loss from early extinguishment of debt discontinued operations

 
(0.9
)
 

 
(0.9
)
Impairment charges from continuing operations
20.1

 
1,139.6

 
55.6

 
1,143.2

Income taxes impairment charges from continuing operations
(7.4
)
 
(404.6
)
 
(21.4
)
 
(413.8
)
Total after-tax adjustments to net income
36.8

 
(627.3
)
 
151.3

 
(545.3
)
Adjusted net income (loss)
$
(1.8
)
 
$
38.6

 
$
1.9

 
$
239.1


 
 
 
 
 
 
 
Earnings (Loss) per Common Share
 
 
 
 
 
 
 
Diluted earnings per share
$
(0.22
)
 
$
3.72

 
$
(0.85
)
 
$
4.36

Diluted after-tax adjustments to net income per share
0.21

 
(3.50
)
 
0.86

 
(3.03
)
Diluted Adjusted Net Income per share
$
(0.01
)
 
$
0.22

 
$
0.01

 
$
1.33

 
 
 
 
 
 
 
 
Weighted-average common shares outstanding

 
 
 
 
 
 
Diluted
176.7

 
179.0

 
176.6

 
179.8

     

21


The following table presents open derivative positions as of February 19, 2016:

QEP Energy Commodity Derivative Swap Positions
Year
 
Index
 
Total
Volumes
 
Average Swap Price per Unit
 
 
 
 
(in millions)
 
 
Gas sales
 
 
 
(MMBtu)

 
 
2016
 
NYMEX HH
 
46.5

 
$
2.80

2016
 
IFNPCR
 
61.2

 
$
2.53

2017
 
NYMEX HH
 
65.7

 
$
2.76

2017
 
IFNPCR
 
25.6

 
$
2.53

2018
 
NYMEX HH
 
7.3

 
$
2.80

Oil sales
 
 
 
(Bbls)

 
 

2016
 
NYMEX WTI
 
6.7

 
$
55.84

2017
 
NYMEX WTI
 
2.6

 
$
54.39


QEP Energy Gas Collars
 
 
 
 
Total Volume
 
Average Price
 
Average Price
Year
 
Index
 
 
Floor
 
Ceiling
 
 
 
 
(in millions)
 
 
 
 
 
 
 
 
(MMBtu)

 
($/MMBtu)

 
($/MMBtu)

2016
 
NYMEX HH
 
6.1

 
2.75

 
3.89


QEP Energy Gas Sales Basis Swaps
Year
 
Index Less Differential
 
Index
 
Total Volumes
MMBtu
 
Weighted-Average Differential
 
 
 
 
 
 
(in millions)
 
 
Gas basis swaps
 
 
 
 
 
(MMBtu)

 
($/MMBtu)

2016
 
NYMEX HH
 
IFNPCR
 
30.6

 
(0.16
)
2017
 
NYMEX HH
 
IFNPCR
 
32.9

 
(0.19
)

QEP Marketing Commodity Derivative Positions
Year
 
Type of Contract
 
Index
 
Total
Volumes
 
Average Swap Price
per MMBtu
 
 
 
 
 
 
(in millions)
 
 
Gas sales
 
 
 
 
 
(MMBtu)

 
 
2016
 
SWAP
 
IFNPCR
 
3.2

 
$
2.68

2017
 
SWAP
 
IFNPCR
 
0.1

 
$
2.71

Gas purchases
 
 
 
 
 
(MMBtu)

 
 

2016
 
SWAP
 
IFNPCR
 
0.2

 
$
1.83



22