QEP Resources Reports First Quarter 2014 Financial and Operating Results

  QEP Resources Reports First Quarter 2014 Financial and Operating Results    *Increased crude oil production by 55% over the first quarter 2013 to 37     Mbod driven by Williston Basin oil production growth of nearly 100%.   *Grew crude oil production to 27% of total production from 16% in the first     quarter 2013.   *Delivered significant year-over-year increases in Net Income, Adjusted Net     Income and Adjusted EBITDA.   *Acquired Permian Basin assets (the "Permian Basin Acquisition") for     approximately $945 million with early drilling and production results     surpassing initial expectations.   *Entered into definitive agreements to sell multiple non-core E&P assets     for an aggregate price of $807 million, subject to customary adjustments.   *Entered into a definitive agreement to sell a 40% equity interest in QEP's     affiliate Green River Processing, LLC to QEP Midstream Partners, LP     (“QEPM”) for an aggregate price of $230 million.  Business Wire  DENVER -- May 7, 2014  QEP Resources, Inc. (NYSE: QEP) ("QEP" or the "Company") today reported first quarter 2014 financial and operating results. The Company reported net income during the first quarter 2014 of $39.7 million, or $0.22 per diluted share, compared to a net loss of $4.3 million, or $0.02 per diluted share, in the first quarter 2013.  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, and impairment charges. Excluding these items, the Company’s Adjusted Net Income (a non-GAAP measure) was $68.1 million, or $0.38 per diluted share, for the first quarter 2014, compared to $49.4 million, or $0.28 per diluted share, for the comparable 2013 period. The higher Adjusted Net Income was due primarily to higher oil and NGL production and improved realized natural gas prices partially offset by higher lease operating expenses and production taxes and a realized loss on derivative instruments in the first quarter of 2014 compared to a realized gain in the comparable 2013 period.  Adjusted EBITDA (a non-GAAP measure) for the first quarter 2014 was $386.3 million, compared to $375.0 million in the first quarter 2013, a 3% increase. The definition of Adjusted EBITDA and reconciliations of Adjusted EBITDA and Adjusted Net Income to net income are provided within the financial tables of this release.  “During the first quarter we made substantial progress on positioning QEP to have a more focused asset portfolio with significant positions in high-return, high-margin crude oil and liquids-rich gas plays,” commented Chuck Stanley, Chairman, President and CEO of QEP Resources. “In addition, our asset managers delivered solid execution during the quarter as Williston Basin crude oil production nearly doubled from a year ago, and the Permian Basin contributed one month of production in the quarter with initial vertical well production results exceeding our estimates at the time of the acquisition. We have already ramped up our Permian Basin rig count from two rigs in early March to five today, and we are making substantial progress on data collection to better plan the horizontal development of this newly acquired asset."  "The announced sales of non-core E&P assets, totaling approximately $807 million, a 40% interest in our Green River processing business to QEPM for $230 million, and the anticipated divestiture of additional Midcontinent E&P assets, with aggregate net production of approximately 21 MMcfed, will further strengthen our financial position and focus our upstream portfolio."  "As we continue to make progress on the previously-announced separation of our midstream business, the underlying performance of the business remains strong. In the quarter, we initiated multiple expansion projects and delivered a processing margin that was at the highest level in two years."  "We continue to maintain our relentless focus on shareholder value creation through growing crude oil production from our Williston Basin assets, integrating and accelerating development of our newly-acquired Permian Basin crude oil properties, divesting non-core E&P assets, and completing the separation of our midstream business,” concluded Stanley.  Slides for the first quarter 2014 with maps and other supporting materials referred to in this release are posted on the Company’s website at www.qepres.com.  QEP Financial Results Summary   Adjusted EBITDA by Subsidiary^(1)                                 Three Months Ended                                     March 31,                                     2014          2013          Change                                     (in millions) QEP Energy                          $ 331.8           $ 323.7           3    % QEP Field Services                  53.2              53.2              —    % QEP Marketing and                   1.3              (1.9    )         168  % Resources Adjusted EBITDA                     $ 386.3          $ 375.0          3    %   ^(1)  See attached financial tables of this release for a reconciliation of        Adjusted EBITDA to net income attributable to QEP.          QEP Energy    *Net natural gas equivalent production decreased by 6% to 73.7 Bcfe in the     first quarter 2014 compared to 78.0 Bcfe in the first quarter 2013, due     primarily to decreased gas production in the Haynesville, Midcontinent and     Pinedale areas offset by increased crude oil and NGL production in the     Williston Basin and the addition of Permian Basin Acquisition production     during the month of March. Crude oil and NGL production increased 55% and     41%, respectively, while natural gas production decreased 24%, in the     first quarter 2014, compared to 2013.   *Adjusted EBITDA increased 3% compared to the first quarter 2013, driven by     increases in crude oil and NGL production volumes and a 10% increase in     the net realized price for natural gas. This increase was partially offset     by an 11% and 12% decrease in the net realized prices of crude oil and     NGLs, respectively.   *Crude oil and NGL revenues increased 44% compared to the first quarter     2013, and represented approximately 61% of field-level production     revenues.   *QEP Energy's capital investment (on an accrual basis) for the first three     months of 2014, excluding the $945.0 million related to the Permian Basin     Acquisition, was $318.2 million.  QEP Field Services    *QEP Field Services’ Adjusted EBITDA during the first quarter 2014 was     equal to the prior-year period. The first quarter 2014 Adjusted EBITDA was     driven primarily by an increase in processing margin of $16.5 million,     offset by a 13% decrease in natural gas gathering volumes as a result of     declining dry gas production volumes on the Haynesville gathering system.   *QEP Field Services' capital investment (on an accrual basis) for the first     quarter of 2014 totaled $21.5 million.  QEP 2014 Guidance  QEP Resources' full year 2014 guidance is shown below. The Company’s updated guidance assumes a June 30, 2014 closing of the announced E&P asset sales, ethane rejection for the remainder of 2014, operating impact of the Permian Basin Acquisition starting on March 1, 2014, and other assumptions summarized in the table below:  Guidance and Assumptions                        2014                                2014                          Previous       Asset       Forecast         Current                          Forecast     sale      Revision^(1)   Forecast                                         Impact QEP Energy oil           14.0 -       (0.3)     0.5            14.2 - production (MMBbl)       15.0                                        15.2 QEP Energy NGL           4.0 - 4.5      (0.7)       0.5              3.8 - 4.3 production (MMBbl) QEP Energy natural gas production        175 - 190    (9)       0              166 - 181 (Bcf) QEP Energy total equivalent               283 - 307                                   274 - 298 production (Bcfe)                                                                       Lease operating          $1.50 -                                     $1.50 - and transportation       $1.65                                       $1.65 expense (per Mcfe) QEP Energy Depletion,               $3.50 -                                     $3.30 - Depreciation and         $3.80                      ($0.20)          $3.60 Amortization (per Mcfe) Production and property taxes, %        9% - 10%                                    9% - 10% of field-level revenue                                                                                                (figures below in millions) QEP Resources General and              $190 -                                      $190 - Administrative           $210                                        $210 Expense                                                                       QEP Energy capital       $1,650 -       ($50)                        $1,600 - investment^(2)           $1,750                                      $1,700 QEP Field Services       $80                                         $80 capital investment Corporate and other capital         $25                                 $25 investment Total QEP                $1,755 -                                    $1,705 - Resources capital        $1,855                                      $1,805 investment  ^(1)  Revision of forecast for retained assets         ^(2)   Excludes acquisitions          Operations Summary  QEP Energy  Williston Basin:  Williston Basin net production averaged approximately 31.1 Mboed (96% liquids) during the first quarter 2014, a 12% improvement over the fourth quarter 2013, and an 87% improvement over the first quarter 2013. The Company completed and turned to sales 14 gross operated wells during the quarter, including eight wells in South Antelope, and six wells in the Fort Berthold Reservation. The Company also participated in 20 gross outside-operated Bakken/Three Forks wells that were completed and turned to sales during the quarter (average working interest 7%). QEP Energy continues to reduce costs with recent drill, complete, and equipment capital costs of less than $10.0 million per well.  At the end of the first quarter, QEP Energy had eight operated rigs running in the Williston Basin on the South Antelope acreage.QEP Energy had 24 gross operated wells waiting on completion (average working interest 80%). In addition, the Company had interests in 33 gross outside-operated wells being drilled (average working interest 7%) and ten gross outside-operated wells waiting on completion (average working interest 10%) at the end of the first quarter.  Slides 6-8 depict QEP Energy's acreage and activity in the Bakken/Three Forks play.  Permian Basin:  QEP Energy closed the previously-announced Permian Basin acquisition on Febuary 25, ^ 2014 and assumed all field-level operations on April 1, 2014. Daily production during the month of March averaged 6.6 Mboed (85% liquids). In the first quarter, QEP Energy, along with the previous owner of the asset, completed and turned ten gross vertical Atokaberry wells to sales.  At end of first quarter, QEP Energy had three operated rigs in the Permian Basin; two drilling vertical Atokaberry wells and one drilling a horizontal target in the Wolfcamp section. QEP Energy had three gross operated wells waiting on completion (average working interest of 95%) at end of the first quarter.  Slide 9 depicts QEP Energy's acreage and activity in the northern Midland Basin.  Pinedale Anticline:  During the first quarter 2014, QEP Energy's Pinedale net production averaged 232 MMcfed (24% liquids). QEP Energy began recovering ethane from Pinedale production on October 1, 2013, and partial ethane recovery continued throughout the first quarter 2014.  The Company completed and turned to sales 22 gross Pinedale wells during the first quarter 2014, including one well for which QEP Energy was the operator but owns only a small overriding royalty interest. In 2014, Pinedale completions will focus on those areas of the field where QEP Energy has a majority working interest. QEP Energy suspends Pinedale completion operations during the coldest months of the winter, generally from December to mid-February. At the end of the first quarter, the Company had 55 gross Pinedale wells with QEP working interests drilled, cased and waiting on completion (average working interest 83%).  Drilling and completion efficiencies have allowed QEP Energy to maintain industry-leading average well costs at Pinedale. In the first quarter, drill times from spud to total depth averaged 11.3 days, compared to an average of 12.0 days in 2013. At the end of the first quarter, QEP Energy had four rigs operating at Pinedale. The Company currently expects to complete a total of approximately 110 - 115 gross wells during 2014, including approximately ten wells for which QEP Energy is the designated operator but owns only a small overriding royalty interest.  Please refer to slides 10-11 for additional details on the Company's Pinedale operations.  Uinta Basin:  During the first quarter 2014, Uinta Basin net production averaged 68 MMcfed (33% liquids) of which 31 MMcfed (24% liquids) was from the Lower Mesaverde play. QEP Energy began recovering ethane from Uinta Basin gas production on October 1, 2013, and partial ethane recovery continued throughout the first quarter 2014.  At the end of the first quarter, the Company had one operated drilling rig working in the Lower Mesaverde play, 81 producing wells in the play, and one well waiting on completion (working interest 100%). QEP Energy has over 3,200 potential remaining locations in this liquids-rich gas resource play. At the end of the first quarter, the Company was drilling its third Lower Mesaverde well with a fundamentally different design that could considerably alter the well economics and lead to an accelerated development approach.  Slide 12 depicts QEP Energy's acreage and additional details of the Lower Mesaverde play.  QEP Field Services  During the first quarter 2014 QEP Field Services' processing margin (total processing plant revenues less shrink, transportation, fractionation, and operating expenses) was $42.8 million, a 63% increase compared to the $26.3 million generated in the first quarter 2013. This increase was driven by a 154% increase in the keep-whole margin (NGL sales revenue less shrink, transportation and fractionation expenses), which was $23.1 million in the first quarter of 2014 and $9.1 million a year earlier, offset by a 2% decrease in processing fee-based revenues.  Gathering margin declined 10% in the first quarter of 2014 compared to the first quarter of 2013, due to a 13% decrease in gathering system throughput. Gathering system throughput volumes decreased primarily as a result of a 42% decline at QEP Field Services' Northwest Louisiana Hub primarily due to lower QEP Energy production resulting from the ongoing suspension of drilling in the Haynesville, as well as lower gathering volumes on the Uinta gathering system and QEPM's Vermillion gathering system. Approximately 69% and 83% of QEP Field Services' total margin was derived from fee-based gathering and processing agreements in the first quarter 2014 and 2013, respectively.  As a result of the initial public offering of QEPM, QEP Field Services saw an increase in net income attributable to noncontrolling interest. For the first quarter 2014, this change resulted in negative impacts on QEP's net income and Adjusted EBITDA of $4.9 million and $8.2 million, respectively.  First Quarter 2014 Results Conference Call  QEP Resources’ management will discuss first quarter 2014 results in a conference call on Thursday, May 8, 2014, beginning at 9:00 a.m. EDT. 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 immediately after the call through June 8, 2014, 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 # 13580524. In addition, QEP’s slides for the first quarter 2014, 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.  About QEP Resources, Inc.  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 Oklahoma, Texas, and Louisiana) of the United States. QEP Resources also gathers, compresses, treats, processes and stores natural gas. QEP Resources is the majority owner of QEP Midstream Partners, LP (NYSE:QEPM) and owns 100% of the partnership’s general partner. For more information, visit QEP Resources' website at: www.qepres.com.  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: forecasted production, lease operating and transportation expense, DD&A expense, general and administrative expense, property taxes and capital investment for 2014 and related assumptions for such guidance; plans to drill and complete wells; cost reductions in the Williston Basin; well costs and completions in the Pinedale Anticline; potential locations and anticipated results from changes in drilling designs in the Uinta Basin; focus on shareholder value creation; integration and acceleration of development of the Permian Basin properties; separation of the midstream business; financial position; focus on upstream assets; and 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: the availability of capital; global geopolitical and macroeconomic factors; general economic conditions, including interest rates; changes in local, regional, national and global demand for natural gas, oil and NGL; natural gas, NGL and oil prices; impact of new laws and regulations, including regulations regarding the use of hydraulic fracture stimulation and the implementation of the Dodd-Frank Act; elimination of federal income tax deductions for oil and gas exploration and development; drilling results; shortages of oilfield equipment, services and personnel; operating risks such as unexpected drilling conditions; transportation constraints; weather conditions; changes in maintenance and construction costs and possible inflationary pressures; permitting delays; the availability and cost of credit; outcome of contingencies such as legal proceedings; inability to successfully integrate acquired assets; 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, 2013. 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 Estimated Ultimate Recovery (EUR)  The Securities and Exchange Commission 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. QEP uses certain terms in its periodic news releases and other presentation materials such as “estimated ultimate recovery” or “EUR”, “resource potential”, and “net resource potential”. These estimates are by their nature more speculative than estimates of proved, probable or possible reserves and accordingly are subject to substantially more risks of actually being realized. The SEC guidelines strictly prohibit QEP from including such estimates in filings with the SEC. Investors are urged to closely consider the disclosures about the Company’s reserves in its Annual Report on Form 10-K for the year ended December31, 2013, and in other reports on file with the SEC.  QEP RESOURCES, INC.  CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS  (Unaudited)                                        Three Months Ended                                            March 31,                                            2014                2013 REVENUES                                   (in millions except per share data) Gas sales                                  $   222.5           $  197.6 Oil sales                                  288.7                  194.2 NGL sales                                  101.1                  68.4 Gathering, processing and other            44.4                   45.6 Purchased gas, oil and NGL sales           227.2                 190.7      Total Revenues                             883.9                 696.5      OPERATING EXPENSES Purchased gas, oil and NGL expense         224.3                  196.8 Lease operating expense                    55.3                   40.1 Gas, oil and NGL transportation            43.4                   32.8 and other handling costs Gathering, processing and other            25.8                   20.6 General and administrative                 56.6                   46.0 Production and property taxes              49.3                   35.9 Depreciation, depletion and                240.2                  254.2 amortization Exploration expenses                       2.2                    5.1 Impairment                                 2.0                   —          Total Operating Expenses                   699.1                  631.5 Net gain (loss) from asset sales           2.4                   (0.2      ) OPERATING INCOME                           187.2                  64.8 Realized and unrealized losses on          (80.9      )           (34.6     ) derivative contracts Interest and other income                  2.9                    2.0 Income from unconsolidated                 2.2                    1.3 affiliates Interest expense                           (42.5      )           (39.4     ) INCOME (LOSS) BEFORE INCOME TAXES          68.9                   (5.9      ) Income tax (provision) benefit             (23.4      )           2.2        NET INCOME (LOSS)                          45.5                   (3.7      ) Net income attributable to                 (5.8       )           (0.6      ) noncontrolling interest NET INCOME (LOSS) ATTRIBUTABLE TO          $   39.7              $  (4.3   ) QEP                                                                    Earnings Per Common Share Attributable to QEP Basic total                                $   0.22               $  (0.02  ) Diluted total                              $   0.22               $  (0.02  )                                                                    Weighted-average common shares outstanding Used in basic calculation                  179.7                  177.0 Used in diluted calculation                180.0                  177.0 Dividends per common share                 $   0.02               $  0.02                                                                               QEP RESOURCES, INC.  CONDENSED CONSOLIDATED BALANCE SHEETS  (Unaudited)                                          March 31,        December 31,                                              2014                 2013 ASSETS                                       (in millions) Current Assets Cash and cash equivalents                    $ 3.9                $  11.9 Accounts receivable, net                     586.5                408.5 Fair value of derivative contracts           —                    0.2 Gas, oil and NGL inventories, at             7.8                  13.4 lower of average cost or market Deferred income taxes - current              50.4                 30.6 Prepaid expenses and other                   61.8                54.4        Total Current Assets                         710.4               519.0       Property, Plant and Equipment (successful efforts method for gas and oil properties) Proved properties                            12,401.4             11,571.4 Unproved properties                          1,102.5              665.1 Midstream field services                     1,719.2              1,698.1 Marketing and resources                      89.4                 85.5 Material and supplies                        64.8                59.0        Total Property, Plant and Equipment          15,377.3            14,079.1    Less Accumulated Depreciation, Depletion and Amortization Exploration and production                   5,146.5              4,930.9 Midstream field services                     425.0                409.7 Marketing and resources                      24.2                22.1        Total Accumulated Depreciation,              5,595.7             5,362.7     Depletion and Amortization Net Property, Plant and Equipment            9,781.6             8,716.4     Investment in unconsolidated                 38.5                 39.0 affiliates Fair value of derivative contracts           3.9                  1.0 Restricted Cash                              —                    50.0 Other noncurrent assets                      45.2                51.4        TOTAL ASSETS                                 $ 10,579.6          $  9,376.8                                                                     LIABILITIES AND EQUITY Current Liabilities Checks outstanding in excess of cash         $ 78.4               $  90.9 balances Accounts payable and accrued                 581.0                434.9 expenses Production and property taxes                62.3                 51.8 Interest payable                             34.2                 37.2 Fair value of derivative contracts           71.8                26.7        Total Current Liabilities                    827.7                641.5 Long-term debt                               3,919.2              2,997.5 Deferred income taxes                        1,601.7              1,560.6 Asset retirement obligations                 204.3                191.8 Fair value of derivative contracts           2.9                  — Other long-term liabilities                  108.1                108.6 Commitments and contingencies (see Note 11) EQUITY Common stock - par value $0.01 per share; 500.0 million shares authorized;                                  1.8                  1.8 180.7 million and 179.7 million shares issued, respectively Treasury stock - 0.6 million and 0.4         (20.9      )         (14.9      ) million shares, respectively Additional paid-in capital                   508.1                498.4 Retained earnings                            2,953.8              2,917.8 Accumulated other comprehensive loss         (25.5      )         (26.5      ) Total Common Shareholders' Equity            3,417.3              3,376.6 Noncontrolling interest                      498.4               500.2       Total Equity                                 3,915.7            3,876.8     TOTAL LIABILITIES AND EQUITY                 $ 10,579.6         $  9,376.8                                                                                 QEP RESOURCES, INC.  CONSOLIDATED CASH FLOWS  (Unaudited)                                               Three Months Ended                                                   March 31,                                                   2014           2013                                                   (in millions) OPERATING ACTIVITIES Net income (loss)                                 $  45.5            $  (3.7 ) Adjustments to reconcile net income to net cash provided by operating activities: Depreciation, depletion and amortization          240.2              254.2 Deferred income taxes                             20.7               (9.3    ) Impairment                                        2.0                — Equity-based compensation                         6.8                6.1 Amortization of debt issuance costs and           1.7                1.5 discounts Net (gain) loss from asset sales                  (2.4     )         0.2 Income from unconsolidated affiliates             (2.2     )         (1.3    ) Distributions from unconsolidated                 2.7                1.5 affiliates and other Unrealized loss on derivative contracts           45.5               85.3 Changes in operating assets and                   (38.1    )         (162.4  ) liabilities Net Cash Provided by Operating Activities         322.4             172.1    INVESTING ACTIVITIES Property acquisitions                             (946.6   )         (23.6   ) Property, plant and equipment, including          (330.2   )         (361.0  ) dry exploratory well expense Proceeds from disposition of assets               2.9                1.5 Acquisition deposit held in escrow                50.0              —        Net Cash Used in Investing Activities             (1,223.9 )         (383.1  ) FINANCING ACTIVITIES Checks outstanding in excess of cash              (12.5    )         60.0 balances Long-term debt issued                             300.0              — Long-term debt issuance costs paid                (1.1     )         — Proceeds from credit facility                     1,643.0            1,027.0 Repayments of credit facility                     (1,021.5 )         (866.5  ) Treasury stock repurchases                        (5.5     )         (7.5    ) Other capital contributions                       2.9                2.1 Dividends paid                                    (3.6     )         (3.6    ) Excess tax benefit on equity-based                (0.6     )         1.0 compensation Distribution to noncontrolling interest           (7.6     )         (1.5    ) Net Cash Provided by Financing Activities         893.5             211.0    Change in cash and cash equivalents               (8.0     )         — Beginning cash and cash equivalents               11.9              —        Ending cash and cash equivalents                  $  3.9            $  —                                                                                    QEP RESOURCES, INC.  OPERATIONS BY LINE OF BUSINESS  (Unaudited)  QEP Energy - Production by Region                           Three Months Ended                                March 31,                                (in Bcfe)                                2014          2013          Change Northern Region Pinedale                       20.9                 21.7                 (4  )% Williston Basin                16.8                 9.0                  87  % Uinta Basin                    6.2                  5.8                  7   % Other Northern                 2.5                 3.5                 (29 )% Total Northern                 46.4                40.0                16  % Region Southern Region Haynesville/Cotton             14.4                 22.3                 (35 )% Valley Permian Basin                  1.2                  —                    —   % Midcontinent                   11.7                15.7                (25 )% Total Southern                 27.3                38.0                (28 )% Region Total production               73.7                78.0                (6  )%                                                                                QEP Energy - Total Production                                  Three Months Ended                                     March 31,                                     2014          2013          Change QEP Energy Production Volumes Gas (Bcf)                           44.5              58.5              (24 )% Oil (Mbbl)                          3,312.0           2,138.9           55  % NGL (Mbbl)                          1,568.3          1,108.5          41  % Total production (Bcfe)             73.7              78.0              (6  )% Average daily production            819.3             866.4             (5  )% (MMcfe)                                                                               QEP Energy - Prices                        Three Months Ended                             March 31,                             2014            2013            Change Gas (per Mcf) Average field-level                 $ 5.00                $ 3.38 price Commodity derivative                  (0.46   )             0.76     impact Net realized                $ 4.54               $ 4.14               10  % price Oil (per bbl) Average field-level                 $ 87.16               $ 90.81 price Commodity derivative                  (3.91   )             2.43     impact Net realized                $ 83.25              $ 93.24              (11 )% price NGL (per bbl) Average field-level                 $ 40.26               $ 45.64 price Commodity derivative                  —                    —        impact Net realized                $ 40.26              $ 45.64              (12 )% price Average net equivalent price (per Mcfe) Average field-level                 $ 7.79                $ 5.67 price Commodity derivative                  (0.45   )             0.64     impact Net realized                $ 7.34               $ 6.31               16  % price                                                                               QEP Energy - Operating Expenses                             Three Months Ended                                   March 31,                                   2014          2013          Change                                   (per Mcfe) Depreciation, depletion and                     $ 3.03             $ 3.05             (1  )% amortization Lease operating                   0.76               0.53               43  % expense Gas, oil and NGL transport & other                 0.88               0.72               22  % handling costs Production taxes                  0.65              0.44              48  % Total Operating                   $ 5.32            $ 4.74            12  % Expenses                                                                                                                   Three Months Ended                                         March 31,                                         2014         2013         Change QEP Field Services Gathering Operating Statistics Gas gathering volumes (millions         97.3            111.3           (13 )% of MMBtu) Gathering revenue (per MMBtu)           $ 0.34          $ 0.34          —   %                                                                          QEP Field Services Gathering Margin (in millions) Gathering revenue                       $ 32.6          $ 37.6          (13 )% Other Gathering revenue                 11.1            10.2            9   % Gathering expense                       (10.0   )       (10.3   )       (3  )% Gathering margin                        $ 33.7         $ 37.5         (10 )%                                                                          QEP Field Services Processing Margin (in millions) NGL sales                               $ 38.0          $ 17.8          113 % Processing (fee-based) revenues         16.0            16.4            (2  )% Other processing revenues               8.1             4.9             65  % Processing expense                      (4.4    )       (4.1    )       7   % Processing plant fuel and               (11.3   )       (5.9    )       92  % shrink expense Gas, oil and NGL transport &            (3.6    )       (2.8    )       29  % other handling costs Processing margin                       $ 42.8         $ 26.3         63  % Keep-whole margin^(1)                   $ 23.1          $ 9.1           154 %                                                                          QEP Field Services Processing Operating Statistics NGL sales (MBbls)                       669.2           341.1           96  % Average net realized NGL sales          $ 56.78         $ 52.32         9   % price (per Bbl)^(2) Total fee-based processing              54.7            53.7            2   % volumes (in millions of MMBtu) Average fee-based processing            $ 0.29          $ 0.31          (6  )% revenue (per MMBtu)         Keep-whole margin is calculated as NGL sales less processing plant fuel ^(1)  and shrink, natural gas, oil and NGL transportation & other handling        costs.                Average net realized NGL sales price per barrel is calculated as NGL ^(2)   sales including realized gains from commodity derivative contracts        settlements divided by NGL sales volumes.          QEP RESOURCES, INC. NON-GAAP MEASURES (Unaudited)  This release contains references to the non-GAAP measure of Adjusted EBITDA. Management believes Adjusted EBITDA is an important measure of the Company’s cash flow, liquidity, and ability to incur and service debt, fund capital expenditures and make distributions to shareholders. The use of this measure allows investors to understand how management evaluates financial performance to make operating decisions and allocates resources. It is also an important measure for comparing the Company’s financial performance to other gas and oil producing companies. 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 QEP Resources’ and its subsidiaries’ net income attributable to QEP to Adjusted EBITDA:                                                       QEP                   QEP          QEP Field    Marketing    QEP                      Energy          Services        &               Resources                                                      Resources Three Months Ended March          (in millions) 31, 2014 Net income attributable         9.5             25.4            4.8             39.7 to QEP Unrealized losses on            45.2            —               0.3             45.5 derivative contracts Net gain from        (2.4   )        —               —               (2.4   ) asset sales Interest and         (2.9   )        —               —               (2.9   ) other income Income tax           5.9             14.6            2.9             23.4 provision Interest expense              48.9            0.4             (7.0   )        42.3 (income) ^(1) Depreciation, depletion and        223.4           12.8            0.3             236.5 amortization ^(2) Impairment           2.0             —               —               2.0 Exploration          2.2            —              —              2.2     expenses Adjusted             331.8          53.2           1.3            386.3   EBITDA                                                                       Three Months Ended March 31, 2013 Net (loss) income               (29.8  )        21.6            3.9             (4.3   ) attributable to QEP Unrealized losses on            84.0            —               1.3             85.3 derivative contracts Net (gain) loss from            (0.1   )        0.3             —               0.2 asset sales Interest and         (1.7   )        (0.3   )        —               (2.0   ) other income Income tax (benefit)            (17.2  )        12.5            2.5             (2.2   ) provision Interest             45.3            4.0             (9.9   )        39.4 expense Depreciation, depletion and        238.1           15.1            0.3             253.5 amortization ^(2) Exploration          5.1            —              —              5.1     expenses Adjusted             323.7          53.2           (1.9   )        375.0   EBITDA          Excludes noncontrolling interest's share, of $0.2 million during the ^(1)  three months ended March 31, 2014, of interest expense attributable to        QEP Midstream.         ^(2)   Excludes noncontrolling interests' share of $3.7 and $0.7 million        during the three months ended March 31, 2014 and 2013, respectively.          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, accrued litigation loss contingency, costs from early extinguishment of debt and asset impairments. 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 attributable to QEP Resources’ to Adjusted Net Income:                                Three Months Ended                                   March 31,                                   2014                       2013                                   (in millions, except per earnings per share) Net income (loss)                 $   39.7                   $   (4.3   ) attributable to QEP Adjustments to net income (loss) Net (gain) loss from              (2.4       )                   0.2 asset sales Income tax provision (benefit) from asset              0.9                            (0.1       ) sales Unrealized loss on                45.5                           85.3 derivative contracts Income tax (benefit) on unrealized loss on                (16.9      )                   (31.7      ) derivative contracts Impairment Charges                2.0                            — Income tax (benefit) on non-cash price-related            (0.7       )                   —           impairment charge Total after-tax                   28.4                          53.7        adjustments to net income Adjusted net income attributable to QEP               $   68.1                      $   49.4    Resources                                                                   Earnings per Common Share attributable to QEP Diluted earnings per              $   0.22                       $   (0.02  ) share Diluted after-tax adjustments to net income         0.16                          0.30        per share Diluted Adjusted Net              $   0.38                      $   0.28    Income per share                                                                   Weighted-average common shares outstanding Diluted^(1)                       180.0                          177.3                                                                   Weighted-average common shares outstanding diluted Non-GAAP reconciliation^(1) Weighted-average common shares outstanding used                                          177.0 in GAAP diluted calculation Potential number of shares issuable upon exercise of in-the-money                                         0.3         stock options under the long-term stock incentive plan Weighted-average common shares outstanding used                                          177.3       in Non- GAAP diluted calculation         The three months ended March 31, 2013, diluted common shares        outstanding for purposes of calculating Diluted Adjusted Net Income per        share include potential increases in shares that could result from the ^(1)  exercise of in-the-money stock options. These potential shares are        excluded for the three months ended March 31, 2013, in calculating        earnings-per-share for GAAP purposes, because the effect is        antidilutive due to the Company's net loss for GAAP purposes.          The following table presents open 2014 derivative positions as of April 30, 2014:                                                                        Average Year      Type of Contract    Index        Total         Swap                                                     Volumes          price                                                                      per unit                                                     (in                                                     millions) Gas                                                 (MMBtu) sales 2014         SWAP                   NYMEX           19.6             $  4.22 2014         SWAP                   IFNPCR          53.9             $  4.08 2015         SWAP                   NYMEX           25.6             $  4.14 2015         SWAP                   IFNPCR          7.3              $  3.97 Oil                                                 (Bbls) Sales 2014         SWAP                   NYMEX WTI       7.2              $  92.59 2015         SWAP                   NYMEX WTI       4.7              $  88.17                                                                           The following table sets forth QEP Energy's oil basis swaps as of April 30, 2014:                            Index Less             Total            Weighted Year      Index     Differential          Volumes       Average                                                                   Differential Oil                                              (in basis                                            millions) swaps                                                  (Bbls) 2014         NYMEX        ICE Brent              0.5              $    13.78              WTI 2014         NYMEX        LLS                    0.5              $    4.00              WTI 2015         NYMEX        LLS                    0.1              $    4.00              WTI                                                                          The following table sets forth QEP Marketing’s volumes and swap prices for its commodity derivative contracts as of April 30, 2014:                                                      Total            Average Year           Type of          Index                   Swap                    Contract                         Volumes          price                                                                      per MMBtu                                                     (in                                                     millions) Gas sales                                           (MMBtu) 2014               SWAP                IFNPCR       2.6              $   3.77 Gas                                                 (MMBtu) purchases 2014               SWAP                IFNPCR       0.8              $   3.82  Contact:  QEP Resources, Inc. Investors: Greg Bensen Director, Investor Relations 303-405-6665 or Media: Brent Rockwood Director, Communications 303-672-6999  
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