Pioneer Southwest Energy Partners L.P. Reports Third Quarter 2012 Financial and Operating Results Business Wire DALLAS -- October 31, 2012 Pioneer Southwest Energy Partners L.P. (“Pioneer Southwest” or “the Partnership”) (NYSE:PSE) today announced financial and operating results for the quarter ended September 30, 2012. Pioneer Southwest reported third quarter net income of $6 million, or $0.15 per common unit. Net income for the third quarter included unrealized mark-to-market derivative losses of $11 million, or $0.32 per common unit. Without the effect of this item, adjusted income for the third quarter was $17 million, or $0.47 per common unit. Cash flow from operations for the third quarter was $25 million. During October, the Partnership purchased a 94% working interest in approximately 3,000 gross acres in Midland County for $6.3 million. The acquisition includes all deep drilling rights on the acreage, with approximately 75 40-acre locations and 75 20-acre locations, which are expected to be completed in the Spraberry, Dean, Wolfcamp and Strawn intervals and potentially the Atoka interval. The acreage also has horizontal Wolfcamp Shale potential. There is no existing production on this acreage. The Partnership expects to move two of its three drilling rigs to this acreage during the fourth quarter. Oil and gas sales for the third quarter averaged 7,664 barrels oil equivalent per day (BOEPD). Production benefited by 215 barrels per day (BPD) from the drawdown of natural gas liquids (NGL) inventory at Mont Belvieu, Texas, associated with unplanned third-party fractionator downtime during the second quarter. This benefit was offset by a production loss of approximately 450 BOEPD during the third quarter due to continuing third-party fractionator capacity constraints at Mont Belvieu. The NGL fractionation constraints were resolved in early October. The Partnership’s three-rig drilling program continued during the third quarter, with six new wells being placed on production and the recompletion of four wells that were previously only producing from one interval. At the end of the quarter, the Partnership had six wells awaiting completion. The Partnership has a large inventory of remaining oil drilling locations in the Spraberry field, with approximately 155 40-acre locations and 1,275 20-acre locations. The 2012 capital program is expected to result in approximately 50 wells being drilled or recompleted during the year. Essentially all of the wells drilled will be deepened to the Strawn formation, and 35% of the planned wells will also be deepened to the Atoka formation. Production data from current Strawn completions supports the addition of an incremental 30 thousand barrels oil equivalent (MBOE) of estimated ultimate recovery (EUR) for wells completed in this interval. Completions in the Atoka interval are estimated to add an incremental 50 MBOE to 70 MBOE of EUR. Approximately 85% and 70% of the Partnership’s acreage position has Strawn and Atoka potential, respectively. The Partnership currently has four downspaced 20-acre wells on production. Results to date indicate that production from these wells is performing near the type curve for a 40-acre Wolfcamp well (EUR of 140 MBOE). Capital spending for 2012 is forecasted to range from $110 million to $120 million. The 2012 capital program is expected to generate full-year production growth of approximately 8% compared to 2011. Third quarter oil sales averaged 4,934 BPD, NGL sales averaged 1,665 BPD and gas sales averaged 6 million cubic feet per day. The third quarter average price for oil was $88.12 per barrel. The average price for NGLs was $31.60 per barrel, and the average price for gas was $2.62 per thousand cubic feet. Production costs (including production and ad valorem taxes) for the third quarter averaged $26.15 per barrel oil equivalent (BOE). These costs were higher than the second quarter of 2012 by $2.81 per BOE, primarily due to increases in salt water disposal costs (principally water hauling costs), higher electricity costs associated with the increase in gas prices, higher repair and maintenance costs and higher per BOE costs resulting from the approximately 450 BOEPD of lost sales volumes, as discussed above. Depreciation, depletion and amortization expense averaged $8.18 per BOE. The Partnership has additional borrowing capacity under its credit facility of $212 million as of September 30, 2012, which is expected to be adequate to fund future growth from drilling activities and acquisitions. Pioneer Southwest previously announced a cash distribution of $0.52 per outstanding common unit for the quarter ended September 30, 2012. The distribution is payable November 9, 2012 to unitholders of record at the close of business on November 2, 2012. On an annual basis, the cash distribution equates to $2.08 per common unit. Distribution sustainability is supported by the Partnership’s low-decline rate Spraberry properties, its large drilling inventory of 40-acre and 20-acre locations and its strong derivative position through 2014. Of the Partnership’s forecasted production, derivative contracts cover approximately 80% in the fourth quarter of 2012, 65% in 2013, 70% in 2014 and 10% in 2015. Fourth Quarter 2012 Financial Outlook The following paragraphs provide the Partnership’s fourth quarter of 2012 outlook for certain operating and financial items. Production is forecasted to average 7,400 BOEPD to 7,900 BOEPD. This assumes the remaining NGL inventory at Mont Belvieu of 8,400 barrels (approximately 90 BPD) will be drawn down during the fourth quarter, but will be offset by line fill requirements in the fourth quarter for the new Lone Star NGL pipeline in which Pioneer Southwest will be a shipper. The fourth quarter production estimate also assumes a negative impact ranging from 100 BOEPD to 200 BOEPD due to reduced ethane recoveries associated with gas processing facilities in the Spraberry field nearing capacity during the fourth quarter due to greater-than-anticipated industry production growth. New gas processing capacity of 100 million cubic feet per day is expected to be added in late March/early April 2013. Production costs (including production and ad valorem taxes) are expected to average $22.50 to $26.50 per BOE based on continuing higher salt water disposal and electricity costs, higher per BOE costs resulting from the gas processing capacity limitations negatively impacting sales volumes and current NYMEX strip prices for oil, NGLs and gas. Depreciation, depletion and amortization expense is expected to average $7.75 to $8.75 per BOE. General and administrative expense is expected to be $1.5 million to $2.5 million. Interest expense is expected to be $500 thousand to $800 thousand. Accretion of discount on asset retirement obligations is forecasted to be nominal. Pioneer Southwest’s effective income tax rate is expected to be approximately 1% of earnings before income taxes as a result of Pioneer Southwest being subject to the Texas Margin tax. Earnings Conference Call On Thursday, November 1, 2012, at 11:00 a.m. Central Time, Pioneer Southwest will discuss its financial and operating results for the third quarter with an accompanying presentation. Instructions for listening to the call and viewing the accompanying presentation are shown below. Internet: www.pioneersouthwest.com Select “Investors,” then “Earnings Calls & Webcasts” to listen to the discussion and view the presentation. Telephone: Dial (888) 455-2260 confirmation code: 2684624 five minutes before the call to listen to the discussion. View the presentation via Pioneer Southwest’s internet address above. A replay of the webcast will be archived on Pioneer Southwest’s website. A telephone replay will be available through November 20, 2012 by dialing (888) 203-1112 confirmation code: 2684624. Pioneer Southwest is a Delaware limited partnership, headquartered in Dallas, Texas, with current production and drilling operations in the Spraberry field in West Texas. For more information, visit www.pioneersouthwest.com. Except for historical information contained herein, the statements in this News Release are forward-looking statements that are made pursuant to the Safe Harbor Provisions of the Private Securities Litigation Reform Act of 1995. Forward-looking statements and the business prospects of Pioneer Southwest are subject to a number of risks and uncertainties that may cause Pioneer Southwest’s actual results in future periods to differ materially from the forward-looking statements. These risks and uncertainties include, among other things, volatility of commodity prices, the effectiveness of Pioneer Southwest’s commodity price derivative strategy, reliance on Pioneer Natural Resources Company and its subsidiaries to manage Pioneer Southwest’s business and identify and evaluate drilling opportunities and acquisitions, product supply and demand, competition, the ability to obtain environmental and other permits and the timing thereof, other government regulation or action, the ability to obtain approvals from third parties and negotiate agreements with third parties on mutually acceptable terms, litigation, the costs and results of drilling and operations, availability of equipment, services, resources and personnel required to complete Pioneer Southwest’s operating activities, access to and availability of transportation, processing and refining facilities, Pioneer Southwest’s ability to replace reserves, including through acquisitions, and implement its business plans or complete its development activities as scheduled, uncertainties associated with acquisitions, access to and cost of capital, the financial strength of counterparties to Pioneer Southwest’s credit facility and derivative contracts and the purchasers of Pioneer Southwest’s oil, NGL and gas production, uncertainties about estimates of reserves and the ability to add proved reserves in the future, the assumptions underlying production forecasts, quality of technical data and environmental and weather risks, including the possible impacts of climate change. These and other risks are described in Pioneer Southwest’s 10-K and 10-Q Reports and other filings with the Securities and Exchange Commission. In addition, Pioneer Southwest may be subject to currently unforeseen risks that may have a materially adverse impact on it. Pioneer Southwest undertakes no duty to publicly update these statements except as required by law. Cautionary Note to U.S. Investors --The U.S. Securities and Exchange Commission (“SEC”) prohibits oil and gas companies, in their filings with the SEC, from disclosing estimates of oil or gas resources other than “reserves,” as that term is defined by the SEC. In this news release, Pioneer Southwest includes estimates of quantities of oil and gas using certain terms, such as “estimated ultimate recovery,” “EUR” or other descriptions of volumes of reserves, which terms include quantities of oil and gas that may not meet the SEC’s definitions of proved, probable and possible reserves, and which the SEC's guidelines strictly prohibit Pioneer Southwest from including in filings with the SEC. These estimates are by their nature more speculative than estimates of proved reserves and accordingly are subject to substantially greater risk of being recovered by Pioneer Southwest. U.S. investors are urged to consider closely the disclosures in the Partnership’s periodic filings with the SEC. Such filings are available from the Partnership at 5205 N. O'Connor Blvd., Suite 200, Irving, Texas 75039, Attention: Investor Relations, and the Partnership’s website at www.pioneersouthwest.com. These filings also can be obtained from the SEC by calling 1-800-SEC-0330. PIONEER SOUTHWEST ENERGY PARTNERS L.P. UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (in thousands) September 30, December 31, 2012 2011 ASSETS Current assets: Cash $ 3,494 $ 1,176 Accounts receivable - trade 16,532 18,063 Inventories 1,273 920 Prepaid expenses 331 240 Deferred income taxes 122 207 Derivatives 4,354 5,619 Total current assets 26,106 26,225 Property, plant and equipment, at cost: Oil and gas properties, using the successful efforts method of accounting: Proved properties 514,727 437,085 Unproved properties 98 — Accumulated depletion, depreciation (157,086 ) (141,498 ) and amortization Total property, plant and 357,739 295,587 equipment Deferred income taxes 136 1,008 Derivatives 5,621 3,665 Other, net 1,162 242 $ 390,764 $ 326,727 LIABILITIES AND PARTNERS' EQUITY Current liabilities: Accounts payable: Trade $ 17,655 $ 10,756 Due to affiliates 1,012 830 Interest payable 143 16 Income taxes payable to affiliate 120 550 Derivatives 14,353 28,101 Asset retirement obligations 900 500 Other current liabilities 143 — Total current liabilities 34,326 40,753 Long-term debt 88,000 32,000 Derivatives 2,692 16,953 Asset retirement obligations 8,628 9,815 Other noncurrent liabilities 333 — Partners' equity 256,785 227,206 Commitments and contingencies $ 390,764 $ 326,727 PIONEER SOUTHWEST ENERGY PARTNERS L.P. UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (in thousands, except for per unit data) Three Months Ended Nine Months Ended September 30, September 30, 2012 2011 2012 2011 Revenues: Oil and gas $ 46,385 $ 55,200 $ 139,655 $ 159,486 Other income — — — 2 Derivative gains (13,592 ) 55,761 18,176 28,852 (losses), net 32,793 110,961 157,831 188,340 Costs and expenses: Oil and gas 14,468 10,002 36,487 28,378 production Production and ad 3,974 3,629 11,801 10,460 valorem taxes Depletion, depreciation and 5,771 4,372 15,589 11,272 amortization General and 1,888 1,873 5,548 5,287 administrative Accretion of discount on asset 189 229 567 684 retirement obligations Interest 638 413 1,456 1,206 Other 221 — 969 — 27,149 20,518 72,417 57,287 Income before income 5,644 90,443 85,414 131,053 taxes Income tax provision (111 ) (946 ) (1,062 ) (1,353 ) Net income $ 5,533 $ 89,497 $ 84,352 $ 129,700 Allocation of net income: General partner's $ 6 $ 90 $ 84 $ 130 interest Limited partners' 5,474 89,231 84,058 129,335 interest Unvested participating 53 176 210 235 securities' interest Net income $ 5,533 $ 89,497 $ 84,352 $ 129,700 Net income per common unit - basic $ 0.15 $ 2.69 $ 2.35 $ 3.91 and diluted Weighted average common units 35,714 33,114 35,714 33,114 outstanding - basic and diluted Distributions declared per common $ 0.52 $ 0.51 $ 1.55 $ 1.52 unit PIONEER SOUTHWEST ENERGY PARTNERS L.P. UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (in thousands) Three Months Ended Nine Months Ended September 30, September 30, 2012 2011 2012 2011 Cash flows from operating activities: Net income $ 5,533 $ 89,497 $ 84,352 $ 129,700 Adjustments to reconcile net income to net cash provided by operating activities: Depletion, depreciation and 5,771 4,372 15,589 11,272 amortization Deferred income 90 885 957 943 taxes Accretion of discount on 189 229 567 684 asset retirement obligations Amortization of debt related 64 45 174 136 costs Amortization of unit-based 228 141 639 372 compensation Commodity derivative 11,597 (62,330 ) (28,700 ) (52,702 ) related activity Other noncash 221 — 969 — expense Change in operating assets and liabilities: Accounts (3,014 ) (1,153 ) 1,531 (3,116 ) receivable Inventories 368 131 (353 ) (11 ) Prepaid expenses (220 ) (242 ) (91 ) (93 ) Accounts payable 4,798 657 6,241 3,037 Interest payable 143 3 127 116 Income taxes payable to (514 ) (420 ) (430 ) (69 ) affiliate Asset retirement (576 ) (182 ) (1,477 ) (468 ) obligations Other current (82 ) — (296 ) — liabilities Net cash provided by 24,596 31,633 79,799 89,801 operating activities Cash flows from investing activities: Additions to oil and gas (25,160 ) (20,774 ) (76,778 ) (50,170 ) properties Net cash used in investing (25,160 ) (20,774 ) (76,778 ) (50,170 ) activities Cash flows from financing activities: Borrowings under 21,000 17,500 107,000 50,404 credit facility Principal payments on (2,000 ) (7,500 ) (51,000 ) (34,604 ) credit facility Payment of — — (1,291 ) — financing fees Distributions to (18,590 ) (16,905 ) (55,412 ) (50,383 ) unitholders Net cash provided by (used in) 410 (6,905 ) (703 ) (34,583 ) financing activities Net increase (decrease) in (154 ) 3,954 2,318 5,048 cash Cash, beginning 3,648 1,201 1,176 107 of period Cash, end of $ 3,494 $ 5,155 $ 3,494 $ 5,155 period PIONEER SOUTHWEST ENERGY PARTNERS L.P. UNAUDITED SUMMARY PRODUCTION AND PRICE DATA Three Months Ended Nine Months Ended September 30, September 30, 2012 2011 2012 2011 Average Daily Sales Volumes: Oil (Bbls) - 4,934 4,598 4,900 4,263 Natural gas 1,665 1,707 1,449 1,578 liquids (Bbls) - Gas (Mcf) - 6,388 6,744 6,665 6,503 Total (BOE) - 7,664 7,429 7,459 6,925 Average Reported Prices: Oil (per Bbl) - $ 88.12 $ 108.46 $ 91.13 $ 115.95 Natural gas liquids (per $ 31.60 $ 45.27 $ 33.29 $ 42.94 Bbl) - Gas (per Mcf) - $ 2.62 $ 3.57 $ 2.24 $ 3.41 Total (per BOE) $ 65.79 $ 80.77 $ 68.33 $ 84.36 - PIONEER SOUTHWEST ENERGY PARTNERS L.P. UNAUDITED SUPPLEMENTAL EARNINGS PER UNIT INFORMATION (in thousands, except for per unit amounts) The Partnership follows the two-class method of calculating basic and diluted net income per unit. Under the two-class method, generally accepted accounting principles ("GAAP") provide that the net income applicable to the Partnership be allocated to all securities that participate in the Partnership's earnings. Accordingly, net income applicable to the Partnership is allocated to the General Partner, unvested participating securities and common unitholders. Net losses applicable to the Partnership are allocated to the General Partner and common unitholders but only to unvested participating securities to the extent that they receive distributions during loss periods because unvested participating securities are not contractually obligated to share in the Partnership's net losses. Unit- and unit-based awards with guaranteed dividend or distribution participation rights qualify as "participating securities" during their vesting periods. The Partnership's basic and diluted net income per unit attributable to common unitholders is computed as (i) net income applicable to the Partnership, (ii) less General Partner net income, (iii) less unvested participating securities' basic and diluted net income (iv) divided by weighted average basic and diluted units outstanding. The following table provides a reconciliation of the Partnership's net income applicable to the Partnership to basic and diluted net income attributable to common unitholders, and the calculation of net income per common unit - basic and diluted, for the three and nine months ended September30, 2012 and 2011: Three Months Ended Nine Months Ended September 30, September 30, 2012 2011 2012 2011 Net income applicable to the $ 5,533 $ 89,497 $ 84,352 $ 129,700 Partnership Less: General partner's (6 ) (90 ) (84 ) (130 ) interest Unvested participating (53 ) (176 ) (210 ) (235 ) securities' interest Basic and diluted net income $ 5,474 $ 89,231 $ 84,058 $ 129,335 applicable to common unitholders Weighted average basic and diluted 35,714 33,114 35,714 33,114 units outstanding Net income per common unit - $ 0.15 $ 2.69 $ 2.35 $ 3.91 basic and diluted PIONEER SOUTHWEST ENERGY PARTNERS L.P. UNAUDITED SUPPLEMENTAL NON-GAAP FINANCIAL MEASURES (in thousands) EBITDAX and distributable cash flow (as defined below) are presented herein and reconciled to the GAAP measures of net cash provided by operating activities and net income. Management of Pioneer Southwest Energy Partners L.P. believes these financial measures provide additional information to the investment community about the Partnership's ability to generate sufficient cash flow to sustain or increase distributions to its unitholders, among other items. In particular, EBITDAX is used in the Partnership's credit facility to determine the interest rate that the Partnership will pay on outstanding borrowings and to determine compliance with the leverage coverage test. EBITDAX and distributable cash flow should not be considered as alternatives to net cash provided by operating activities or net income, as defined by GAAP. Three Months Ended Nine Months Ended September 30, 2012 September 30, 2012 Net cash provided by $ 24,596 $ 79,799 operating activities Add/(Deduct): Depletion, depreciation (5,771 ) (15,589 ) and amortization Deferred income taxes (90 ) (957 ) Accretion of discount on asset retirement (189 ) (567 ) obligations Amortization of debt (64 ) (174 ) issuance costs Amortization of (228 ) (639 ) unit-based compensation Commodity derivative (11,597 ) 28,700 related activity Other noncash expense (221 ) (969 ) Changes in operating (903 ) (5,252 ) assets and liabilities Net income 5,533 84,352 Add/(Deduct): Depletion, depreciation 5,771 15,589 and amortization Accretion of discount on asset retirement 189 567 obligations Interest expense 638 1,456 Income tax provision 111 1,062 Amortization of 228 639 unit-based compensation Commodity derivative 11,597 (28,700 ) related activity Other noncash expense 221 969 EBITDAX (a) 24,288 75,934 Add/(Deduct): Cash reserves to maintain production and (6,149 ) (19,950 ) cash flow Cash interest expense (574 ) (1,282 ) Cash income taxes (21 ) (105 ) Distributable cash flow (b) $ 17,544 $ 54,597 _____________ (a) "EBITDAX" represents earnings before depletion, depreciation and amortization expense; accretion of discount on asset retirement obligations; interest expense; income taxes; amortization of unit-based compensation; noncash commodity derivative related activity and other noncash expenses. (b) Distributable cash flow equals EBITDAX adjusted for the Partnership's estimated cash reserves to maintain production and cash flow, cash interest expense and cash income taxes. PIONEER SOUTHWEST ENERGY PARTNERS L.P. SUPPLEMENTAL INFORMATION Open Commodity Derivative Positions as of October 30, 2012 Twelve Months Ending 2012 December 31, Fourth Quarter 2013 2014 2015 Oil Derivatives: Collar contracts with short puts: Volume (Bbls per day) 1,500 1,750 5,000 — Price per Bbl: Ceiling $ 109.00 $ 116.00 $ 124.00 $ — Floor $ 85.00 $ 88.14 $ 90.00 $ — Short put $ 70.00 $ 73.14 $ 72.00 $ — Swap contracts: Volume (Bbls per day) 3,000 3,000 — — Price per Bbl $ 79.32 $ 81.02 $ — $ — NGL Derivatives: Swap contracts: Volume (Bbls per day) 750 — — — Price per Bbl (a) $ 35.03 $ — $ — $ — Gas Derivatives: Collar contracts with short puts: Volume (MMBtus per day) — — — 5,000 Price per MMBtu: Ceiling $ — $ — $ — $ 5.00 Floor $ — $ — $ — $ 4.00 Short put $ — $ — $ — $ 3.00 Swap contracts: Volume (MMBtus per day) 5,000 2,500 5,000 — Price per MMBtu (b) $ 6.43 $ 6.89 $ 4.00 $ — Basis swap contracts: Permian Basin index swaps 2,500 2,500 — — (MMBtus per day) (c) Price differential $ (0.30 ) $ (0.31 ) $ — $ — ($/MMBtu) _____________ (a) Represents weighted average index price per Bbl of each NGL component. (b) Represents the NYMEX Henry Hub index price on the derivative trade date. (c) Represents swaps that fix the basis differentials between the Permian Basin index price and the NYMEX Henry Hub index price used in gas swap contracts. PIONEER SOUTHWEST ENERGY PARTNERS L.P. UNAUDITED SUPPLEMENTAL INFORMATION Derivative Gains (Losses), Net (in thousands) Three Months Ended Nine Months Ended September 30, 2012 September 30, 2012 Noncash changes in fair value: Oil derivative gains $ (9,000 ) $ 28,726 (losses) NGL derivative gains (267 ) 4,747 (losses) Gas derivative losses (2,330 ) (4,773 ) Total noncash derivative (11,597 ) 28,700 gains (losses), net Cash settled changes in fair value: Oil derivative losses (3,424 ) (13,831 ) NGL derivative losses (197 ) (1,815 ) Gas derivative gains 1,626 5,122 Total cash derivative (1,995 ) (10,524 ) losses, net Total derivative $ (13,592 ) $ 18,176 gains (losses), net PIONEER SOUTHWEST ENERGY PARTNERS L.P. UNAUDITED SUPPLEMENTAL NON-GAAP FINANCIAL MEASURES (in millions, except per unit data) Adjusted income excluding unrealized mark-to-market derivative losses, as presented in this press release, is presented and reconciled to the Partnership’s net income determined in accordance with GAAP because the Partnership believes that this non-GAAP financial measure reflects an additional way of viewing aspects of the Partnership’s business that, when viewed together with its financial results computed in accordance with GAAP, provides a more complete understanding of factors and trends affecting its historical financial performance and future operating results, greater transparency of underlying trends and greater comparability of results across periods. In addition, management believes that this non-GAAP measure may enhance investors’ ability to assess the Partnership’s historical and future financial performance. This non-GAAP financial measure is not intended to be a substitute for the comparable GAAP measure and should be read only in conjunction with the Partnership’s consolidated financial statements prepared in accordance with GAAP. Unrealized mark-to-market derivative gains and losses will recur in future periods; however, the amount can vary significantly from period to period. The table below reconciles the Partnership’s net income for the three months ended September30, 2012, as determined in accordance with GAAP, to adjusted income excluding unrealized mark-to-market derivative losses for that quarter. After-tax Per Common Amounts Unit Net income $ 6 $ 0.15 Unrealized mark-to-market derivative losses 11 0.32 Adjusted income excluding unrealized $ 17 $ 0.47 mark-to-market derivative losses Contact: Pioneer Southwest Energy Partners L.P. Investors Frank Hopkins, 972-969-4065 or Eric Pregler, 972-969-5756 or Media and Public Affairs Susan Spratlen, 972-969-4018 or Suzanne Hicks, 972-969-4020
Pioneer Southwest Energy Partners L.P. Reports Third Quarter 2012 Financial and Operating Results
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