News Column

DCP Midstream Partners Announces a Dropdown and Organic Growth Project Totaling $1.4 Billion and Reports Record Fourth Quarter and Year End 2013 Results

February 26, 2014

DCP MIDSTREAM PARTNERS ANNOUNCES A DROPDOWN AND ORGANIC GROWTH PROJECT TOTALING $1.4 BILLION AND REPORTS RECORD FOURTH QUARTER AND YEAR END 2013 RESULTS * $1.15 billion immediately accretive dropdown from DCP Midstream * 200 MMcf/d Lucerne 2 plant, an organic growth project, with a total estimated cost of $250 million * Record 2013 annual Distributable Cash Flow of $296 million, an increase of 64 percent over 2012 * Record fourth quarter 2013 Adjusted EBITDA of $104 million and Distributable Cash Flow of $79 million * Thirteenth consecutive quarterly distribution increase now at $2.93 per unit annualized DENVER - DCP Midstream Partners, LP (NYSE: DPM), or the Partnership, today reported financial results for the three and twelve months ended December 31, 2013. The table below reflects the results for the three and twelve months ended December 31, 2013 and 2012 on a consolidated basis and for the 2012 periods as originally reported. FOURTH QUARTER AND YEAR TO DATE 2013 SUMMARY RESULTS     Three Months Ended   Year Ended     December 31,   December 31, 2013 2012 As 2013 2012 As     ((3))   ((3)(4))   Reported   ((3))   ((3)(4))   Reported in 2012 in 2012 -----------------------------------------------------------     (Unaudited) -----------------------------------------------------------     (Millions, except per unit amounts) Net income attributable to 28 70 64 181 198 168 partners((1)(5)) $ $ $ $ $ $ Net income per limited partner 0.09 0.87 0.87 1.34 2.28 2.28 unit - basic and diluted((1)(5)) $ $ $ $ $ $ Adjusted 104 98 86 365 302 252 EBITDA((2)) $ $ $ $ $ $ Adjusted net income 63 68 62 217 177 147 attributable to partners((2)) $ $ $ $ $ $ Adjusted net income per limited partner 0.49 0.83 0.83 1.80 1.89 1.89 unit((2)) - basic and diluted $ $ $ $ $ $ Distributable 79  ** 68 296  ** 180 cash flow((2)) $ $ $ $ $ $ (1)   Includes non-cash commodity derivative mark-to-market losses of $35 million and gains of $2 million for the three months ended December 31, 2013 and 2012, respectively.  Includes non-cash commodity derivative mark-to-market losses of $37 million and gains of $21 million for the twelve months ended December 31, 2013 and 2012, respectively. (2)   Denotes a financial measure not presented in accordance with U.S. generally accepted accounting principles, or GAAP. Each such non-GAAP financial measure is defined below under "Non-GAAP Financial Information", and each is reconciled to its most directly comparable GAAP financial measures under "Reconciliation of Non-GAAP Financial Measures" below. (3)   Includes our 80 percent interest in the Eagle Ford system, retrospectively adjusted. We acquired a 33.33 percent interest in the Eagle Ford system in November 2012, and a 46.67 percent interest in March 2013. Transfers of net assets between entities under common control are accounted for as if the transactions had occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method. In addition, results are presented as originally reported in 2012 for comparative purposes. (4)   Includes our 100 percent interest in Southeast Texas, retrospectively adjusted. We acquired a 33.33 percent interest in Southeast Texas in January 2011, and a 66.67 percent interest in March 2012. Transfers of net assets between entities under common control are accounted for as if the transactions had occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method. In addition, results are presented as originally reported in 2012 for comparative purposes. (5)   The Partnership recognized no lower of cost or market adjustments during the three months ended December 31, 2013 and 2012, respectively, and $4 million and $19 million of lower of cost or market adjustments during the twelve months ended December 31, 2013 and 2012, respectively. **  Distributable cash flow has not been calculated under the pooling method. DROPDOWN TRANSACTION AND ORGANIC GROWTH PROJECT IN THE DJ BASIN The Partnership announced a $1.15 billion immediately accretive dropdown from DCP Midstream, the owner of the Partnership's general partner, the largest dropdown in DPM's history. Included in the dropdown are the following: * A one-third interest in the 720-mile, fee-based Sand Hills natural gas liquids (NGL) pipeline, transporting NGLs from both DCP and third party plants in the Permian Basin and Eagle Ford Shale to facilities along the Texas Gulf Coast and the Mont Belvieu market hub. With an initial capacity of 200,000 barrels per day (Bbls/d) the pipeline will have the ability to ramp up to capacity of 350,000 Bbls/d after the completion of planned pump stations. * A one-third interest in the 800-mile, fee-based Southern Hills NGL pipeline, which has an expected capacity of 175,000 Bbls/d after completion of planned pump stations. Southern Hills provides NGL takeaway service from the Midcontinent to the Mont Belvieu market hub. * The remaining 20 percent interest in the Eagle Ford system, bringing the Partnership's ownership interest to 100 percent. The Eagle Ford system includes seven integrated plants with total processing capacity of 1.2 billion cubic feet per day (Bcf/d), including the 100 percent owned Eagle plant and Goliad plant which was recently placed into service. * Lucerne 1, a 35 million cubic feet per day (MMcf/d) cryogenic natural gas processing plant located in the prolific DJ Basin. The plant includes a long-term fee-based processing agreement with DCP Midstream providing a fixed demand charge, along with a throughput fee on all volumes processed. The Partnership also announced an organic growth project, the Lucerne 2 plant, a 200 MMcf/d plant which is currently under construction.  Once in service, the plant includes a 10-year fee-based processing agreement with DCP Midstream providing a fixed demand charge, along with a throughput fee on all volumes processed. The Lucerne 2 plant will be a deep-cut cryogenic, natural gas processing plant in the rapidly expanding, liquids-rich DJ Basin that is part of the growing Niobrara shale formation. Once in service, the Partnership will own approximately 50 percent of the 800 million cubic feet per day of total capacity in the DJ basin owned and operated by the DCP enterprise. The Lucerne plants will be connected to the Front Range Pipeline for NGL takeaway to the Mont Belvieu market hub. The Lucerne 2 plant is expected to be placed into service in mid 2015.  The Partnership estimates additional expenditures of approximately $180 million after the transaction closes to complete this project. These transactions are subject to certain closing conditions and working capital and other customary closing adjustments. The transactions are expected to close in March 2014. CEO AND CHAIRMAN'S PERSPECTIVE "With this transaction, we have now firmly established the Partnership as a fully integrated midstream provider and with the two NGL pipelines, the Partnership now accesses the rapidly expanding Permian basin and Granite Wash and SCOOP areas of the Midcontinent," said Wouter van Kempen, CEO and chairman of the Partnership, and CEO and chairman of DCP Midstream. "Executing on our growth for growth strategy as a DCP enterprise, we have doubled the size of the Partnership in the past few years, and we continue to be focused on being a premier operator delivering value to our customers and unitholders." PRESIDENT'S PERSPECTIVE "We are hitting on all cylinders; not only did we just deliver record results for 2013, we are also excited to announce this transaction as it includes both solid fee-based assets that are accretive to unit holders as well as a great organic growth opportunity in the prolific DJ Basin," said Bill Waldheim, president of the Partnership. "With the addition of these primarily fee-based assets we are well positioned to deliver sustainable distribution growth and long-term value to our unitholders." 2013 AND RECENT HIGHLIGHTS In addition to delivering on our distributable cash flow and distribution growth forecasts, we successfully executed on our 2013 business plan. * We achieved our distribution growth forecast which represents a 6 percent increase over the 2012 declared distribution rate * 2013 distributable cash flow of $296 million is up 64 percent from 2012 * We continue executing on our growth strategy with both dropdowns and quality organic growth projects. In 2013, we completed over $1 billion of dropdowns, including * an additional 47 percent interest in the Eagle Ford system * the 110 MMcf/d O'Connor plant, with the 160 MMcf/d expansion nearing completion * a one-third interest in the 435-mile, 150,000 Bbl/d Front Range NGL pipeline * The 583-mile Texas Express NGL pipeline commenced operations October 31, 2013 with initial capacity of 280,000 Bbls/d, expandable to 400,000 Bbls/d. The Partnership owns a 10 percent interest, which is operated by Enterprise * In February 2014, the 435-mile Front Range NGL pipeline and 200 MMcf/d Goliad plant were placed into service * The Front Range Pipeline has 150,000 Bbls/d of capacity, is owned one- third by the Partnership and is operated by Enterprise * Our 200 MMcf/d Goliad plant is part of our Eagle Ford system and is our seventh plant in the Eagle Ford Shale, including the Eagle plant, where 400 MMcf/d of processing capacity has been added in just the last year. The Goliad plant is connected to Sand Hills pipeline for NGL takeaway to Mont Belvieu CONSOLIDATED FINANCIAL RESULTS Consolidated results are shown using the pooling method of accounting, which includes results associated with DCP Midstream's ownership interests in the Eagle Ford system and Southeast Texas during its periods of ownership. While the Partnership hedges the majority of its commodity risk, prior period results reflect DCP Midstream's unhedged portion of its ownership interest in the Eagle Ford system and Southeast Texas during those periods. Adjusted EBITDA for the three months ended December 31, 2013 increased to $104 million from $98 million for the three months ended December 31, 2012, reflecting increased volumes on our Eagle Ford and East Texas systems and growth from the operation of our fee-based O'Connor plant, partially offset by higher operating expenses primarily as a result of growth and asset reliability expenditures. Adjusted EBITDA for the three months ended December 31, 2012 included a significant recovery of the non-cash lower of cost or market price adjustment (LCM Adjustment) for our wholesale propane logistics segment that was recorded in the second quarter of 2012. Adjusted EBITDA for the year ended December 31, 2013 increased to $365 million from $302 million for the year ended December 31, 2012. These results reflect increased volumes on our Eagle Ford and East Texas systems and growth from the operation of our fee based O'Connor plant, partially offset by lower commodity prices on the unhedged portion of the Eagle Ford and Southeast Texas systems associated with DCP Midstream's ownership and hedge settlement timing on storage and higher operating expenses primarily as a result of growth and asset reliability expenditures. These results also reflect the dropdown of the Mont Belvieu fractionators and higher volumes and margins in NGL Logistics and Wholesale Propane. On January 28, 2014, the Partnership announced a quarterly distribution of $0.7325 per limited partner unit. This represents an increase of 1.7 percent over the last quarterly distribution and an increase of 6.2 percent over the distribution declared in the fourth quarter of 2012. Our distributable cash flow of $79 million for the three months ended December 31, 2013, provided a 0.96 times distribution coverage ratio adjusted for the timing of actual distributions paid during the quarter. The 2013 distribution coverage ratio  on a cash paid basis  was approximately 1.1 times. OPERATING RESULTS BY BUSINESS SEGMENT Natural Gas Services - Adjusted segment EBITDA increased to $90 million for the three months ended December 31, 2013, from $69 million for the three months ended December 31, 2012, reflecting increased volumes on our Eagle Ford and East Texas systems and growth from the operation of our fee-based O'Connor plant, partially offset by higher operating expenses primarily as a result of growth and asset reliability expenditures. Adjusted segment EBITDA increased to $308 million for the year ended December 31, 2013, from $291 million for the year ended December 31, 2012, reflecting increased volumes on our Eagle Ford and East Texas systems and growth from the operation of our fee-based O'Connor plant, partially offset by lower commodity prices on the unhedged portion of the Eagle Ford and Southeast Texas systems associated with DCP Midstream's ownership, hedge settlement timing on storage, lower volumes across certain of our assets and higher operating expenses primarily as a result of growth and asset reliability expenditures. Results are shown using the pooling method of accounting, which includes the additional 47 percent of the Eagle Ford system since the date of acquisition on November 1, 2012, and 80 percent of the Eagle Ford system for the ten months ended October 31, 2012. Results also include 67 percent of Southeast Texas for the three months ended March 31, 2012. These results reflect the unhedged portion of the Eagle Ford system and Southeast Texas associated with DCP Midstream's ownership interest during those periods. NGL Logistics - Adjusted segment EBITDA of $19 million for the three months ended December 31, 2013, was relatively flat compared to $20 million for the three months ended December 31, 2012, reflecting a non-cash write off of a discontinued construction project, partially offset by higher results from the Mont Belvieu fractionators. Adjusted segment EBITDA increased to $85 million for the year ended December 31, 2013, from $59 million for the year ended December 31, 2012. These results reflect the July 2012 dropdown of the Mont Belvieu fractionators, higher throughput on certain of our pipelines and higher margins at the Marysville storage facility. Wholesale Propane Logistics - Adjusted segment EBITDA decreased to $10 million for the three months ended December 31, 2013, from $27 million for the three months ended December 31, 2012.  Results for the three months ended December 31, 2012 included a significant recovery of the LCM Adjustment that was recorded in the second quarter of 2012 and higher unit margins associated with favorable hedging. Adjusted segment EBITDA increased to $34 million for the year ended December 31, 2013, from $26 million for the year ended December 31, 2012. The 2013 results reflect increased unit margins and the exporting of propane from the Chesapeake terminal in the first quarter of 2013, partially offset by a non-cash write off of a discontinued construction project. 2012 results reflect reduced demand due to the industry's excess inventory as a result of near record warm weather. CORPORATE AND OTHER Interest expense for the three and twelve months ended December 31, 2013 increased due to higher debt levels, partially offset by higher capitalized interest. CAPITALIZATION At December 31, 2013, the Partnership had $1,590 million of long-term debt outstanding comprised of senior notes and $335 million of short-term debt outstanding under our commercial paper program. Total available revolver capacity was $664 million. Our leverage ratio pursuant to our credit facility for the quarter ended December 31, 2013, was approximately 3.9 times. Our effective interest rate on our overall debt position, as of December 31, 2013, was 3.4 percent. COMMODITY DERIVATIVE ACTIVITY The objective of our commodity risk management program is to protect downside risk in our distributable cash flow. We utilize mark-to-market accounting treatment for our commodity derivative instruments. Mark-to-market accounting rules require companies to record currently in earnings the difference between their contracted future derivative settlement prices and the forward prices of the underlying commodities at the end of the accounting period. Revaluing our commodity derivative instruments based on futures pricing at the end of the period creates assets or liabilities and associated non-cash gains or losses. Realized gains or losses from cash settlement of the derivative contracts occur monthly as our physical commodity sales are realized or when we rebalance our portfolio. Non-cash gains or losses associated with the mark-to-market accounting treatment of our commodity derivative instruments do not affect our distributable cash flow. For the three months ended December 31, 2013, commodity derivative activity and total revenues included non-cash losses of $35 million. This compares to non- cash gains of $2 million for the three months ended December 31, 2012. Net hedge cash settlements for the three months ended December 31, 2013, were receipts of $13 million. Net hedge cash settlements for the three months ended December 31, 2012, were receipts of $18 million. For the year ended December 31, 2013, commodity derivative activity and total revenues included non-cash losses of $37 million. This compares to non-cash gains of $21 million for the year ended December 31, 2012. Net hedge cash settlements for the year ended December 31, 2013, were receipts of $54 million. Net hedge cash settlements for the year ended December 31, 2012, were receipts of $49 million. While our earnings will continue to fluctuate as a result of the volatility in the commodity markets, our commodity derivative contracts mitigate a substantial portion of the risk of weakening commodity prices thereby stabilizing distributable cash flows. EARNINGS CALL DCP Midstream Partners will hold a conference call to discuss fourth quarter results on Thursday, Februrary 27, 2014, at 9:00 a.m. ET. The dial-in number for the call is 1-800-708-4539  in the United States or 1-847-619-6396 outside the United States.  The conference confirmation number for login is 36550042. A live webcast of the call can be accessed on the Investor section of DCP Midstream Partners' website at www.dcppartners.com. The call will be available for replay one hour after the end of the conference until Midnight ET, on March 18, 2014, by dialing 1-888-843-7419 in the United States or 1-630-652-3042 outside the United States. The replay conference number is 36550042. A replay, transcript and presentation slides in PDF format will also be available by accessing the Investor section of the Partnership's website. NON-GAAP FINANCIAL INFORMATION This press release and the accompanying financial schedules include the following non-GAAP financial measures: distributable cash flow, adjusted EBITDA, adjusted segment EBITDA, adjusted net income attributable to partners, adjusted net income allocable to limited partners, and adjusted net income per limited partner unit. The accompanying schedules provide reconciliations of these non- GAAP financial measures to their most directly comparable GAAP financial measures. The Partnership's non-GAAP financial measures should not be considered in isolation or as an alternative to its financial measures presented in accordance with GAAP, including operating revenues, net income or loss attributable to partners, net cash provided by or used in operating activities or any other measure of liquidity or financial performance presented in accordance with GAAP as a measure of operating performance, liquidity or ability to service debt obligations and make cash distributions to unitholders. The non- GAAP financial measures presented by us may not be comparable to similarly titled measures of other companies because they may not calculate their measures in the same manner. We define distributable cash flow as net cash provided by or used in operating activities, less maintenance capital expenditures, net of reimbursable projects, plus or minus adjustments for non-cash mark-to-market of derivative instruments, proceeds from divestiture of assets, net income attributable to noncontrolling interests net of depreciation and income tax, net changes in operating assets and liabilities, and other adjustments to reconcile net cash provided by or used in operating activities. Historical distributable cash flow is calculated excluding the impact of retrospective adjustments related to any acquisitions presented under the pooling method. Maintenance capital expenditures are cash expenditures made to maintain our cash flows, operating or earnings capacity. These expenditures add on to or improve capital assets owned, including certain system integrity, compliance and safety improvements. Maintenance capital expenditures also include certain well connects, and may include the acquisition or construction of new capital assets. Non-cash mark-to-market of derivative instruments is considered to be non-cash for the purpose of computing distributable cash flow because settlement will not occur until future periods, and will be impacted by future changes in commodity prices and interest rates. Distributable cash flow is used as a supplemental liquidity and performance measure by the Partnership's management and by external users of its financial statements, such as investors, commercial banks, research analysts and others, to assess the Partnership's ability to make cash distributions to its unitholders and its general partner. We define adjusted EBITDA as net income or loss attributable to partners less interest income, noncontrolling interest in depreciation and income tax expense and non-cash commodity derivative gains, plus interest expense, income tax expense, depreciation and amortization expense and non-cash commodity derivative losses. The commodity derivative non-cash losses and gains result from the marking to market of certain financial derivatives used by us for risk management purposes that we do not account for under the hedge method of accounting. These non-cash losses or gains may or may not be realized in future periods when the derivative contracts are settled, due to fluctuating commodity prices. We define adjusted segment EBITDA for each segment as segment net income or loss attributable to partners less non-cash commodity derivative gains for that segment, plus depreciation and amortization expense and non-cash commodity derivative losses for that segment, adjusted for any noncontrolling interest on depreciation and amortization expense for that segment. The Partnership's adjusted EBITDA equals the sum of its adjusted segment EBITDAs, plus general and administrative expense. Adjusted EBITDA is used as a supplemental liquidity and performance measure and adjusted segment EBITDA is used as a supplemental performance measure by the Partnership's management and by external users of its financial statements, such as investors, commercial banks, research analysts and others to assess: * financial performance of the Partnership's assets without regard to financing methods, capital structure or historical cost basis; * the Partnership's operating performance and return on capital as compared to those of other companies in the midstream energy industry, without regard to financing methods or capital structure; * viability and performance of acquisitions and capital expenditure projects and the overall rates of return on investment opportunities; * performance of the Partnership's business excluding non-cash commodity derivative gains or losses; and * in the case of Adjusted EBITDA, the ability of the Partnership's assets to generate cash sufficient to pay interest costs, support its indebtedness, make cash distributions to its unitholders and general partner, and finance maintenance capital expenditures. We define adjusted net income attributable to partners as net income attributable to partners, plus non-cash derivative losses, less non-cash derivative gains. Adjusted net income per limited partner unit is then calculated from adjusted net income attributable to partners. These non-cash derivative losses and gains result from the marking to market of certain financial derivatives used by us for risk management purposes that we do not account for under the hedge method of accounting. Adjusted net income attributable to partners and adjusted net income per limited partner unit are provided to illustrate trends in income excluding these non-cash derivative losses or gains, which may or may not be realized in future periods when derivative contracts are settled, due to fluctuating commodity prices. ABOUT DCP MIDSTREAM PARTNERSDCP Midstream Partners, LP (NYSE: DPM) is a midstream master limited partnership engaged in the business of gathering, compressing, treating, processing, transporting, storing and selling natural gas; producing, fractionating, transporting, storing and selling NGLs and condensate; and transporting, storing and selling propane in wholesale markets. DCP Midstream Partners, LP is managed by its general partner, DCP Midstream GP, LP, which in turn is managed by its general partner, DCP Midstream GP, LLC which is 100 percent owned by DCP Midstream, LLC, a joint venture between Phillips 66 and Spectra Energy. For more information, visit the DCP Midstream Partners, LP website at www.dcppartners.com. CAUTIONARY STATEMENTS This press release may contain or incorporate by reference forward-looking statements as defined under the federal securities laws regarding DCP Midstream Partners, LP, including projections, estimates, forecasts, plans and objectives. Although management believes that expectations reflected in such forward-looking statements are reasonable, no assurance can be given that such expectations will prove to be correct. In addition, these statements are subject to certain risks, uncertainties and other assumptions that are difficult to predict and may be beyond the Partnership's control. If one or more of these risks or uncertainties materialize, or if underlying assumptions prove incorrect, the Partnership's actual results may vary materially from what management anticipated, estimated, projected or expected. The key risk factors that may have a direct bearing on the Partnership's results of operations and financial condition are described in detail in the Partnership's annual and quarterly reports most recently filed with the Securities and Exchange Commission and other such matters discussed in the "Risk Factors" section of the Partnership's most recent Annual Report on Form 10-K and subsequent Quarterly Reports on Form 10-Q filed with the Securities and Exchange Commission. Investors are encouraged to closely consider the disclosures and risk factors contained in the Partnership's annual and quarterly reports filed from time to time with the Securities and Exchange Commission. The forward looking statements contained herein speak as of the date of this announcement. The Partnership undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. Information contained in this press release is unaudited, and is subject to change. DCP MIDSTREAM PARTNERS, LP FINANCIAL RESULTS AND SUMMARY BALANCE SHEET DATA (Unaudited)       Three Months Ended   Year Ended       December 31,   December 31, As As       2013   2012   Reported   2013   2012   Reported in 2012 in 2012 ------------------------------------------------------------       (Millions, except per unit amounts) Sales of natural gas, propane, NGLs and condensate   $ 743$ 557$ 376$ 2,695$ 2,459$ 1,466 Transportation, processing and other   81 75   54   268   232   185 Losses from commodity derivative activity, net  (22) 20   20   17   70   70 -------- -------- ---------- ---------- ---------- --------- Total operating   revenues   802 652   450   2,980   2,761   1,721 Purchases of natural gas, propane and NGLs    (655)  (488)    (328)    (2,381)    (2,177)    (1,301) Operating and maintenance expense    (59)  (48)    (31)    (211)    (193)    (123) Depreciation and amortization expense    (25)  (22)    (14)    (93)    (89)    (64) General and administrative expense    (15)  (18)     (12)    (62)    (74)     (46)          - Other expense  (5)          -      (8)      -          - -------- -------- ---------- ---------- ---------- --------- Total operating costs and   expenses    (759)  (576)    (385)    (2,755)    (2,533)    (1,534) -------- -------- ---------- ---------- ---------- --------- Operating income   43 76   65   225   228   187 Interest expense    (12)  (10)     (10)    (52)    (42)     (42) Earnings from unconsolidated affiliates   10 9   12   33   26   29 Income tax          - expense  (6)          -      (8)    (1)    (1) Net income attributable to noncontrolling interests    (7)  (5)    (3)    (17)    (13)    (5) -------- -------- ---------- ---------- ---------- --------- Net income attributable   to partners   28 70   64   181   198   168 Net income attributable to predecessor      - operations      (6)        -      (6)    (33)    (3) General partner's interest in net income    (20)  (12)    (12)    (70)    (41)    (41) -------- -------- ---------- ---------- ---------- --------- Net income allocable to limited partners   $ 8$ 52$ 52$ 105$ 124$ 124 -------- -------- ---------- ---------- ---------- --------- Net income per limited partner $ unit-basic and diluted $ 0.09 0.87 $ 0.87$ 1.34$ 2.28$ 2.28 -------- -------- ---------- ---------- ---------- --------- Weighted-average limited partner units outstanding- basic and diluted   87.8   60.5   60.5   78.4   54.5   54.5 -------- -------- ---------- ---------- ---------- ---------       As Reported     December 31,   December 31,   December 31,   2013   2012   2012 -------------- ------------------- -------------     (Millions) Cash and cash equivalents   $ 12 $ 2 $ 1 Other current assets     491   366   308 Property, plant and equipment, net     3,005   2,550   1,727 Other long-term assets   1,018                 685   936 -------------- ------------------- ------------- Total assets   $ 4,526 $ 3,603 $ 2,972 -------------- ------------------- ------------- Current liabilities   $ 722 $ 345 $ 234 Long-term debt     1,590   1,620   1,620 Other long-term liabilities     41   44   35 Partners' equity     1,945   1,405   1,048 Noncontrolling interests     228   189   35 -------------- ------------------- ------------- Total liabilities and equity   $ 4,526 $ 3,603 $ 2,972 -------------- ------------------- ------------- DCP MIDSTREAM PARTNERS, LP RECONCILIATION OF NON-GAAP FINANCIAL MEASURES (Unaudited)     Three Months Ended   Year Ended     December 31,   December 31, As As     2013 2012 Reported 2013 2012 Reported       in 2012       in 2012 ----------------------------------------------------------       (Millions, except per unit amounts) Reconciliation of Non-GAAP Financial Measures: Net income attributable to partners $ 28$ 70$ 64$ 181$ 198$ 168   Interest expense   12   10   10   52   42   42 Depreciation, amortization and income tax expense, net of noncontrolling   interests   29   20   14   95   83   63 Non-cash commodity derivative mark-   to-market   35    (2)    (2)   37    (21)    (21) -------- -------- ----------- -------- -------- ---------- Adjusted EBITDA   104   98   86   365   302   252   Interest expense    (12)    (10)    (10)    (52)    (42)    (42) Depreciation, amortization and income tax expense, net of noncontrolling   interests    (29)    (20)    (14)    (95)    (83)    (63) Other        -        -       -      (1)      -       - -------- -------- ----------- -------- -------- ---------- Adjusted net income attributable to partners   63 $ 68   62   217 $ 177   147 -------- -------- Maintenance capital expenditures, net of reimbursable   projects    (7)        (6)    (23)        (18) Distributions from unconsolidated affiliates, net   of earnings    (3)       1   6         - Depreciation and amortization, net of noncontrolling   interests   23       14   87       62 Impact of minimum volume receipt for throughput   commitment    (6)        (6)      -           - Discontinued construction   projects   4         -     8         - Adjustment to remove impact of   pooling      -           -      (6)        (17)   Other   5       3   7       6 -------- ----------- -------- ---------- Distributable cash flow((1)) $ 79     $   68 $  296     $ 180 -------- ----------- -------- ---------- Adjusted net income attributable to partners $ 63$ 68$ 62$ 217$ 177$ 147 Adjusted net income attributable to predecessor   operations      -      (6)     -      (6)    (33)    (3) Adjusted general partner's interest in net   income    (20)    (12)    (12)    (70)    (41)    (41) -------- -------- ----------- -------- -------- ---------- Adjusted net income allocable to limited partners $ 43$ 50$ 50$ 141$ 103$ 103 -------- -------- ----------- -------- -------- ---------- Adjusted net income per limited partner unit - basic and diluted $ 0.49$ 0.83$ 0.83$ 1.80$ 1.89$ 1.89 -------- -------- ----------- -------- -------- ---------- Net cash provided (used) by operating activities $ 60 $  (70) $  (34) $ 324$ 82$ 125   Interest expense   12   10   10   52   42   42 Distributions from unconsolidated affiliates, net   of earnings   3      -      (1)    (6)      -       - Net changes in operating assets   and liabilities   8   168   117    (8)   219   115 Net income attributable to noncontrolling interests, net of depreciation   and income tax    (9)    (8)    (3)    (23)    (20)    (7) Discontinued construction   projects    (4)      -       -      (8)      -       - Non-cash commodity derivative mark-   to-market   35    (2)    (2)   37    (21)    (21) Other, net      (1)      -      (1)    (3)      -      (2) -------- -------- ----------- -------- -------- ---------- Adjusted EBITDA $ 104$ 98$ 86$ 365$ 302$ 252 -------- --------   Interest expense    (12)        (10)    (52)        (42) Maintenance capital expenditures, net of reimbursable   projects    (7)      (6)    (23)      (18) Distributions from unconsolidated affiliates, net   of earnings    (3)     1   6       - Adjustment to remove impact of   pooling      -         -      (6)      (17) Discontinued construction   projects   4       -     8       -   Other    (7)        (3)    (2)       5 -------- ----------- -------- ---------- Distributable cash flow((1)) $ 79   $ 68$ 296   $ 180 -------- ----------- -------- ---------- (1)  Distributable cash flow has not been calculated under the pooling method. DCP MIDSTREAM PARTNERS, LP RECONCILIATION OF NON-GAAP FINANCIAL MEASURES SEGMENT FINANCIAL RESULTS AND OPERATING DATA  (Unaudited)   Three Months Ended     Year Ended   December 31,     December 31,     2013     As Reported in     2013     As Reported in 2012 2012 --------------------------------------------------------     (Millions, except as indicated) Reconciliation of Non-GAAP Financial Measures: Distributable cash $   $   $   $ flow   79 68 296 180 Distributions $   $   $   $ declared   86 54 309 199 -------- ------------------- -------- ------------------ Distribution coverage ratio - declared   0.92 x 1.25 x 0.96 x 0.91 x -------- ------------------- -------- ------------------ Distributable cash $ $ $ $ flow   79   68   296   180 Distributions paid   $ 82   $ 53   $ 277   $ 181 -------- ------------------- -------- ------------------ Distribution coverage ratio - paid   0.96 x 1.29 x 1.07 x 0.99 x -------- ------------------- -------- ------------------     Three Months Ended   Year Ended     December 31,   December 31, As As       2013   2012   Reported   2013   2012   Reported in 2012 in 2012 ------------------------------------------------------------       (Millions, except per unit amounts) Natural Gas Services Segment: Financial results: Segment net income attributable to partners $ 32$ 66$ 54$ 193$ 237$ 180 Non-cash commodity derivative   mark-to-market   36    (15)    (15)   36    (20)    (20) Depreciation and amortization   expense   24   20   12   85   81   55 Noncontrolling interests on depreciation   and income tax    (2)    (2)       -      (6)    (7)    (2) --------- --------- ---------- --------- --------- --------- Adjusted segment EBITDA $ 90$ 69$ 51$ 308$ 291$ 213 --------- --------- ---------- --------- --------- --------- Operating and financial data: Natural gas throughput   (MMcf/d)   2,308   2,168   1,725   2,270   2,322   1,667 NGL gross production   (Bbls/d)   129,538   106,827   74,253   118,578   112,032   65,610 Operating and maintenance   expense $ 52$ 41$ 24$ 180$ 162$ 92 NGL Logistics Segment: Financial results: Segment net income attributable to partners $ 18$ 19$ 19$ 79$ 53$ 53 Depreciation and amortization   expense   1   1   1   6   6   6 --------- --------- ---------- --------- --------- --------- Adjusted segment EBITDA $ 19$ 20$ 20$ 85$ 59$ 59 --------- --------- ---------- --------- --------- --------- Operating and financial data: NGL pipelines throughput   (Bbls/d)   87,324   81,120   81,120   89,361   78,508   78,508 Operating and maintenance   expense $ 3$ 3$ 3$ 16$ 16$ 16 Wholesale Propane Logistics Segment: Financial results: Segment net income attributable to partners $ 11$ 14$ 14$ 31$ 25$ 25 Non-cash commodity derivative   mark-to-market    (1)   12   12   1    (1)    (1) Depreciation and amortization       -   expense       1   1   2   2   2 --------- --------- ---------- --------- --------- --------- Adjusted segment EBITDA $ 10$ 27$ 27$ 34$ 26$ 26 --------- --------- ---------- --------- --------- --------- Operating and financial data: Propane sales volume   (Bbls/d)   22,007   21,297   21,297   19,553   19,111   19,111 Operating and maintenance   expense $ 4$ 4$ 4$ 15$ 15$ 15 DCP MIDSTREAM PARTNERS, LP RECONCILIATION OF NON-GAAP FINANCIAL MEASURES (Unaudited) Twelve months               ended December  Q113  Q213  Q313  Q413 31, 2013 ------------------------------------------- ------------       (Millions, except as indicated) Net income attributable to $ $ $ $ $ partners 52 102  (1) 28 181 Maintenance capital expenditures, net of reimbursable   projects    (7)    (3)    (6)    (7)    (23) Depreciation and amortization expense, net of noncontrolling   interests     19   21   24   23   87 Non-cash commodity derivative mark-   to-market   10  (58) 50 35 37 Distributions from unconsolidated affiliates, net of   earnings     3   3   3    (3)   6 Impact of minimum volume receipt for throughput           -   commitment   2 2 2  (6) Discontinued construction   projects 4     -       -   4 8 Adjustment to remove impact of   pooling  (6)     -       -       -    (6) Other       -   1     -   5 6 ---------- ---------- ---------- ---------- ------------ Distributable cash $ $ $ $ $ flow   77 68 72 79 296 ---------- ---------- ---------- ---------- ------------ Distributions $ $ $ $ $ declared   69 72 82 86 309 ---------- ---------- ---------- ---------- ------------ Distribution coverage ratio - declared 1.12x 0.94x 0.88x 0.92x 0.96x Distributable cash $ $ $ $ $ flow   77 68 72 79 296 ---------- ---------- ---------- ---------- ------------ Distributions paid   $ 54$ 69$ 72$ 82 $ 277 ---------- ---------- ---------- ---------- ------------ Distribution coverage ratio - paid   1.43x 0.99x 1.00x 0.96x 1.07x This announcement is distributed by GlobeNewswire on behalf of GlobeNewswire clients. The owner of this announcement warrants that: (i) the releases contained herein are protected by copyright and other applicable laws; and (ii) they are solely responsible for the content, accuracy and originality of the information contained therein. Source: DCP Midstream Partners LP via GlobeNewswire [HUG#1764714]


For more stories on investments and markets, please see HispanicBusiness' Finance Channel



Source: Thomson Reuters ONE


Story Tools