ONEOK Announces Higher Fourth-Quarter 2011 and Higher Full-Year 2011 Financial Results; Increases 2012 Earnings Guidance (NYSE: OKE) today announced fourth-quarter 2011 earnings of $1.09 per diluted share, compared with 76 cents per diluted share for the same period last year. Fourth-quarter net income attributable to ONEOK was $115.0 million, a 38-percent increase compared with $83.1 million for the same period in 2010. Full-year 2011 net income attributable to ONEOK was $360.6 million, or $3.36 per diluted share, an 8-percent increase compared with $334.6 million, or $3.10 per diluted share, for 2010. ONEOK also increased its 2012 net income guidance to the range of $360 million to $410 million, compared with the previous guidance range of $355 million to $400 million that it released on Sept. The updated guidance reflects higher expected earnings in the ONEOK Partners segment offset partially by lower expected earnings in the energy services segment. Updated 2012 earnings guidance for ONEOK includes a projected dividend increase of 5 cents per share in July 2012, subject to ONEOK board approval, compared with a previous expectation of a 4-cent-per-share increase. "We had exceptionally strong performance in 2011, led by our ONEOK Partners segment, which increased its volumes and benefited from our integrated midstream natural gas and natural gas liquids assets," said John W. Gibson, ONEOK chairman and chief executive officer. We also posted strong fourth-quarter financial results as we continued to build on our solid third quarter. Our ONEOK Partners segment turned in another exceptional quarter, as continued strong natural gas liquids price differentials and higher natural gas liquids and natural gas volume growth resulted in increased fourth-quarter results. "Our natural gas distribution segment delivered solid results for the fourth quarter, while our energy services segment continues to face a challenging market," Gibson said. ONEOK's fourth-quarter 2011 operating income was $365.0 million, a 51-percent increase compared with $242.3 million for the fourth quarter 2010. Fourth-quarter 2011 results benefited from higher natural gas liquids (NGL) optimization, marketing, isomerization and exchange margins resulting from favorable NGL price differentials and increased NGL fractionation and transportation capacity available for optimization activities; higher net realized NGL and condensate prices, higher NGL volumes gathered and fractionated and higher natural gas volumes processed in the ONEOK Partners segment, offset partially by increased employee-related incentive and benefit costs in all segments, primarily higher share-based compensation costs. Fourth-quarter 2011 results for the natural gas distribution segment were lower due to higher employee-related costs, primarily higher share-based compensation costs, compared with the same period last year. The energy services segment had lower fourth-quarter results due primarily to lower storage and marketing margins, net of hedging activities, resulting from lower realized seasonal natural gas storage price differentials; and lower transportation margins, net of hedging activities, resulting from narrower realized natural gas price location differentials. Full-year 2011 operating income was $1.16 billion, compared with $942.7 million for the full year last year. The full-year 2011 increase was driven primarily by higher NGL optimization, marketing, isomerization and exchange margins resulting from favorable NGL price differentials and increased NGL fractionation and transportation capacity available for optimization activities; higher NGL volumes gathered and fractionated; higher net realized NGL and condensate prices; and higher natural gas volumes processed; offset partially by the deconsolidation of Overland Pass Pipeline in September 2010 in the natural gas liquids business in the ONEOK Partners segment. These increases were offset by lower earnings in the energy services segment due primarily to lower transportation margins, net of hedging activities, resulting from narrower realized natural gas price location differentials; lower storage and marketing margins, net of hedging activities; and lower premium-services margins. Full-year 2011 natural gas distribution segment results were lower as a result of higher operating costs, primarily higher share-based compensation costs. Operating costs for the fourth quarter 2011 were $255.8 million, compared with $226.6 million in the same period last year. Operating costs for the full-year 2011 period were $908.3 million, compared with $830.9 million for the full year last year. The increases for the three-month and full-year 2011 periods were due primarily to higher employee-related costs associated with incentive and benefit plans, which includes share-based compensation costs; and higher expenses for materials and outside services in the ONEOK Partners segment. Share-based compensation costs relate primarily to the company's employee stock award program that awards eligible employees with a share of company stock whenever the stock closes at a new one-dollar high. For the full year 2011, the company awarded 31 shares of company stock to each employee at a cost of $16.0 million, which included taxes paid on behalf of employees. In February 2012, ONEOK sold its retail natural gas marketing business, which was accounted for in the natural gas distribution segment, to Constellation Energy Group, Inc. for $22.5 million plus working capital. Prior-period results have been recast to account for this business as income from discontinued operations. View earnings tables Full-year 2011 operating income of $1.16 billion, compared with $942.7 million in 2010; ONEOK Partners segment operating income of $939.5 million, compared with $586.3 million in 2010; Natural gas distribution segment operating income of $197.6 million, compared with $225.1 million in 2010; Energy services segment operating income of $23.8 million, compared with $130.7 million in 2010; Distributions declared on the company's general partner interest in ONEOK Partners of $143.7 million for 2011, compared with $120.3 million for 2010; distributions declared on the company's limited partner interest in ONEOK Partners of $200.5 million for 2011, compared with $190.8 million for 2010; ONEOK Partners completing a two-for-one split of the partnership's common units and Class B units on July 12, 2011. As a result, ONEOK owns 11,800,000 common units, 72,988,252 Class B units and a 2-percent general partner interest, which together represent 42.8 percent; Completing in August a $300 million accelerated share repurchase agreement and receiving 4.3 million shares; ONEOK, on a stand-alone basis, ending the year with $842.0 million of commercial paper outstanding, $2.0 million in letters of credit, $30.9 million of cash and cash equivalents, $347.7 million of natural gas in storage and $356.0 million available under its $1.2 billion credit facility; ONEOK stand-alone cash flow from continuing operations, before changes in working capital, of $713.4 million for the full-year 2011 period, which exceeded capital expenditures and dividends of $499.7 million by $213.7 million; ONEOK in January 2012 completing a $700 million public offering of 4.25-percent senior notes due 2022; ONEOK in February 2012 announcing that its board of directors has authorized a two-for-one split of ONEOK common stock, subject to shareholder approval of a proposal to increase the number of authorized shares of ONEOK common stock to 600 million from 300 million. The proposal will be voted on at the company's 2012 annual meeting of shareholders on May 23, 2012; ONEOK in February 2012 completing the sale of ONEOK Energy Marketing Company to Constellation Energy Group, Inc. for $22.5 million plus working capital; and Declaring a quarterly dividend of 61 cents per share payable on Feb. 14, 2012, to shareholders of record at the close of business Jan. 31, 2012, a 9-percent increase from the previous quarter. ONEOK Partners ONEOK Partners' fourth-quarter 2011 operating income was $317.5 million, compared with $159.7 million in the same period last year. The increase in fourth-quarter 2011 operating income, compared with the same period in 2010, reflects: A $156.3 million increase in the natural gas liquids business due to favorable NGL price differentials and increased NGL fractionation and transportation capacity available for optimization activities between the Mid-Continent and Gulf-Coast markets and higher marketing margins; A $13.6 million increase from higher isomerization margins in the natural gas liquids business; A $10.1 million increase due to higher natural gas volumes processed in the natural gas gathering and processing business; A $6.0 million increase from higher net realized NGL and condensate prices in the natural gas gathering and processing business; A $3.2 million increase due to higher NGL storage margins as a result of favorable contract renegotiations in the natural gas liquids business; and A $2.9 million increase from higher NGL volumes gathered and fractionated, and favorable contract renegotiations associated with exchange services activities in the natural gas liquids business. For the full-year 2011 period, the ONEOK Partners segment posted operating income of $939.5 million, compared with $586.3 million in 2010. Full-year 2011 results reflect: A $363.6 million increase in the natural gas liquids business due to favorable NGL price differentials and increased NGL fractionation and transportation capacity available for optimization activities between the Mid-Continent and Gulf-Coast markets and higher marketing margins; A $44.9 million increase in the natural gas liquids business from higher NGL volumes gathered and fractionated, and favorable contract renegotiations associated with storage and exchange services activities; A $32.6 million increase in the natural gas gathering and processing business from higher net realized NGL and condensate prices; A $26.4 million increase from higher isomerization margins in the natural gas liquids business; A $19.4 million increase in natural gas volumes processed in the natural gas gathering and processing business; An $8.8 million increase due to favorable changes in contract terms in the natural gas gathering and processing business; A $42.8 million decrease resulting from the deconsolidation of Overland Pass Pipeline in September 2010 and a $16.3 million gain on the sale of a 49-percent ownership interest in Overland Pass Pipeline Company recorded in the third quarter 2010 in the natural gas liquids business; A $12.5 million decrease from lower natural gas transportation margins in the natural gas pipelines business; and An $8.2 million decrease from lower natural gas volumes gathered in the natural gas gathering and processing business. Fourth-quarter 2011 operating costs were $130.7 million, compared with $111.4 million in the fourth quarter 2010. Full-year 2011 operating costs were $459.4 million, compared with $403.5 million in 2010. The operating cost increases for both the three-month and full-year 2011 periods were due primarily to higher labor and employee-related costs associated with incentive and benefit plans, which includes share-based compensation costs; higher expenses for materials and outside services associated with scheduled maintenance at the partnership's NGL fractionation, pipeline and storage facilities; and higher property taxes. These increases were offset partially by the deconsolidation of Overland Pass Pipeline in September 2010, which is now accounted for under the equity method of accounting in ONEOK Partners' natural gas liquids business. Equity earnings from investments were $33.6 million in the fourth quarter 2011, compared with $30.7 million in the same period in 2010. Full-year 2011 equity earnings from investments were $127.2 million, compared with $101.9 million in 2010. The increase for the full-year 2011 period was due primarily to the partnership's 50-percent interest in Overland Pass Pipeline included in equity earnings from investments that became effective September 2010 and increased contracted capacity on Northern Border Pipeline, in which the partnership owns a 50-percent interest. Key Statistics: More detailed information is listed in the tables. Natural gas gathered totaled 1,057 billion British thermal units per day (BBtu/d) in the fourth quarter 2011, up 1 percent compared with the same period last year due to increased drilling activity in the Williston Basin, offset partially by continued production declines in the Powder River Basin in Wyoming and certain parts of Kansas; and up 1 percent compared with the third quarter 2011; Natural gas processed totaled 758 BBtu/d in the fourth quarter 2011, up 13 percent compared with the same period last year due to increased drilling activity in the Williston Basin and western Oklahoma, offset partially by natural production declines in Kansas; and up 5 percent compared with the third quarter 2011; The realized composite NGL net sales price was $1.06 per gallon in the fourth quarter 2011, up 5 percent compared with the same period last year; and down 3 percent compared with the third quarter 2011; The realized condensate net sales price was $85.39 per barrel in the fourth quarter 2011, up 33 percent compared with the same period last year; and down 3 percent compared with the third quarter 2011; The realized residue gas net sales price was $5.08 per million British thermal units (MMBtu) in the fourth quarter 2011, down 15 percent compared with the same period last year; and down 3 percent compared with the third quarter 2011; The realized gross processing spread was $7.79 per MMBtu in the fourth quarter 2011, up 1 percent compared with the same period last year; and down 5 percent compared with the third quarter 2011; Natural gas transportation capacity contracted totaled 5,433 thousand dekatherms per day in the fourth quarter 2011, down 3 percent compared with the same period last year due primarily to lower contracted capacity on Midwestern Gas Transmission resulting from narrower natural gas price location differentials; and up 6 percent compared with the third quarter 2011; Natural gas transportation capacity subscribed was 84 percent in the fourth quarter 2011 compared with 87 percent subscribed for the same period last year; and up from 79 percent in the third quarter 2011; The average natural gas price in the Mid-Continent region was $3.20 per MMBtu in the fourth quarter 2011, down 12 percent compared with the same period last year; and down 20 percent compared with the third quarter 2011; NGLs fractionated totaled 583 thousand barrels per day (MBbl/d) in the fourth quarter 2011, up 10 percent compared with the same period last year due primarily to increased throughput through existing supply connections in Texas and the Mid-Continent and Rocky Mountain regions, and new supply connections in the Mid-Continent and Rocky Mountain regions; and up 10 percent compared with the third quarter 2011; NGLs transported on gathering lines totaled 473 MBbl/d in the fourth quarter 2011, up 17 percent compared with the same period last year, due primarily to increased production through existing supply connections in Texas and the Mid-Continent and Rocky Mountain regions, and new supply connections in the Mid-Continent and Rocky Mountain regions; and up 7 percent compared with the third quarter 2011; NGLs transported on distribution lines totaled 512 MBbl/d in the fourth quarter 2011, up 10 percent compared with the same period last year; and up 12 percent compared with the third quarter 2011 due primarily to increased volumes transported to Midwest markets on the North System pipeline and the completion of the Sterling I pipeline expansion project in the fourth quarter of 2011; and The Conway-to-Mont Belvieu average price differential for ethane, based on Oil Price Information Service (OPIS) pricing, was 49 cents per gallon in the fourth quarter 2011, compared with 8 cents per gallon in the same period last year; and 27 cents per gallon in the third quarter 2011. Natural Gas Distribution Prior reporting periods for the natural gas distribution segment exclude retail marketing operations that were sold in February 2012, and those operations are now accounted for as income from discontinued operations. The natural gas distribution segment reported operating income of $54.5 million in the fourth quarter 2011, compared with $62.0 million in the fourth quarter 2010. Fourth-quarter 2011 operating costs were $117.5 million, compared with $108.4 million in the fourth quarter 2010. The fourth-quarter 2011 increases were due primarily to higher employee-related costs associated with incentive and benefit plans, which includes share-based compensation costs. For the full year 2011, operating income was $197.6 million, compared with $225.1 million in the same period in 2010. Full-year 2011 operating costs were $422.0 million, compared with $398.8 million in 2010. Higher operating costs included $14.7 million in higher share-based compensation costs, $8.1 million in higher employee-related incentive and benefit costs, and $3.2 million in increased pension costs. Residential natural gas sales totaled 39.9 billion cubic feet (Bcf) in the fourth quarter 2011, up 2 percent compared with the same period last year; Total natural gas volumes sold were 52.0 Bcf in the fourth quarter 2011, down 3 percent compared with the same period last year due to lower wholesale volumes available for sale, which had minimal impact on margins; and Total natural gas volumes delivered were 102.5 Bcf in the fourth quarter 2011, down 3 percent compared with the same period last year. Energy Services The energy services segment reported a fourth-quarter 2011 operating loss of $5.5 million, compared with operating income of $19.8 million in the same period in 2010. Fourth-quarter results reflect a $16.0 million decrease in storage and marketing margins due primarily to lower realized seasonal natural gas storage price differentials, net of hedging; and a $9.8 million decrease in natural gas transportation margins, net of hedging, due primarily to narrower realized natural gas price location differentials and lower hedge settlements in 2011. Operating income for the full-year 2011 period was $23.8 million, compared with $130.7 million in the same period in 2010. Full-year 2011 results, compared with 2010, reflect: A $65.3 million decrease in natural gas transportation margins, net of hedging, due primarily to narrower realized natural gas price location differentials and lower hedge settlements in 2011; A $34.3 million decrease in storage and marketing margins due primarily to lower realized seasonal natural gas storage price differentials, net of hedging; A $7.3 million decrease in premium-services margins associated with lower demand fees; and A $4.3 million decrease in financial trading margins. Millions of dollars Marketing, storage and transportation revenues, gross Storage and transportation costs Marketing, storage and transportation, net Financial trading, net Net margin Total natural gas in storage at Dec. 31, 2011, was 70.5 Bcf, compared with 63.0 Bcf a year earlier; Total natural gas storage capacity under lease at Dec. 31, 2011, was 75.6 Bcf, compared with 73.6 Bcf a year earlier; and Total natural gas transportation capacity under lease at Dec. 31, 2011, was 1.2 billion cubic feet per day (Bcf/d), of which 1.1 Bcf/d was contracted under long-term natural gas transportation contracts, compared with 1.4 Bcf/d of total capacity and 1.1 Bcf/d of long-term capacity a year earlier. ONEOK's 2012 net income is expected to be in the range of $360 million to $410 million, compared with its previously announced range of $355 million to $400 million that was provided on Sept. The increased guidance reflects higher expected earnings in the ONEOK Partners segment and lower anticipated earnings in the energy services segment. Additional information is available in the guidance tables on the ONEOK website. The midpoint for ONEOK's 2012 operating income guidance increased to $1.13 billion, compared with its previous guidance midpoint of $1.1 billion. The midpoint for ONEOK's 2012 net income guidance is $385 million, compared with its previous guidance of $378 million. The midpoint of the ONEOK Partners segment's 2012 operating income guidance increased to $910 million, compared with its previous guidance of $833 million. The updated 2012 guidance reflects higher expected earnings in the natural gas liquids business, offset partially by lower expected earnings in the natural gas gathering and processing business. The average unhedged prices assumed for 2012 at ONEOK Partners are $97.75 per barrel for New York Mercantile Exchange (NYMEX) crude oil, $3.30 per MMBtu for NYMEX natural gas and $1.20 per gallon for composite natural gas liquids. Previous guidance released on Sept. 26, 2011, assumed $99.30 per barrel for NYMEX crude oil, $4.71 per MMBtu for NYMEX natural gas and $1.42 per gallon for composite natural gas liquids. For 2012, ONEOK Partners estimates that in its natural gas gathering and processing business, a 1-cent-per-gallon change in the composite price of NGLs would change annual net margin by approximately $1.7 million. A $1.00-per-barrel change in the price of crude oil would change annual net margin by approximately $1.3 million. Also, a 10-cent-per-MMBtu change in the price of natural gas would change annual net margin by approximately $2.2 million. All of these sensitivities exclude the effects of hedging and assume normal operating conditions. Additionally, ONEOK Partners estimates that in the natural gas liquids business, the Conway-to-Mont Belvieu OPIS average ethane price differential is expected to be 32 cents in 2012, compared with 12 cents provided in its previous guidance on Sept. The midpoint of the natural gas distribution segment's 2012 operating income is $223 million, compared with its previous guidance of $226 million. The reduction primarily reflects the sale of the retail marketing business. The midpoint of the energy services segment's 2012 operating income was reduced to $0 million, compared with its previous guidance of $40 million. The reduction reflects expected narrower realized natural gas price location differentials and lower realized seasonal natural gas storage price differentials. 2012 capital expenditures are expected to be approximately $2.3 billion, comprised of approximately $2.0 billion at ONEOK Partners and $302 million at ONEOK on a stand-alone basis. On a stand-alone basis, the midpoint of ONEOK's 2012 guidance for cash flow before changes in working capital has been updated to $740 million, compared with its previous guidance of $746 million. Cash flow before changes in working capital is expected to exceed capital expenditures and dividends by $155 million to $195 million. 2012 earnings guidance for ONEOK includes a projected dividend increase of 5 cents per share in July 2012, subject to ONEOK board approval, compared with a previous expectation of 4 cents per share semiannually. ONEOK's 2012 earnings guidance also includes a projected 2.5-cent-per-quarter increase in unitholder distributions from ONEOK Partners, subject to ONEOK Partners board approval, compared with a previous expectation of a 2-cent-per-quarter increase. ONEOK and ONEOK Partners management will conduct a joint conference call on Tuesday, Feb. 21, 2012, at 11 a.m. Eastern Standard Time (10 a.m. Central Standard Time). The call will also be carried live on ONEOK's and ONEOK Partners' websites. To participate in the telephone conference call, dial 888-857-6931, pass code 7074825, or log on to www.oneok.com or www.oneokpartners.com. If you are unable to participate in the conference call or the webcast, the replay will be available on ONEOK's website, www.oneok.com, and ONEOK Partners' website, www.oneokpartners.com, for 30 days. A recording will be available by phone for seven days. The playback call may be accessed at 888-203-1112 pass code 7074825. ONEOK has disclosed in this news release stand-alone cash flow, before changes in working capital, which is a non-GAAP financial measure. Stand-alone cash flow, before changes in working capital, is used as a measure of the company's financial performance. Stand-alone cash flow, before changes in working capital, is defined as net income less the portion attributable to non-controlling interests, adjusted for equity in earnings and distributions received from ONEOK Partners, and ONEOK's stand-alone depreciation and amortization, deferred income taxes, net of the change in taxes receivable, and certain other items. The non-GAAP financial measure described above is useful to investors because the measurement is used as a measurement of financial performance of the company's fundamental business activities. ONEOK stand-alone cash flow, before changes in working capital, should not be considered in isolation or as a substitute for net income or any other measure of financial performance presented in accordance with GAAP. This non-GAAP financial measure excludes some, but not all, items that affect net income. Additionally, this calculation may not be comparable with similarly titled measures of other companies. A reconciliation of stand-alone cash flow, before changes in working capital, to net income is included in the financial tables. (NYSE: OKE) is a diversified energy company. We are the general partner and own 42.8 percent of ONEOK Partners, L.P. (NYSE: OKS), one of the largest publicly traded master limited partnerships, which is a leader in the gathering, processing, storage and transportation of natural gas in the U.S. and owns one of the nation's premier natural gas liquids (NGL) systems, connecting NGL supply in the Mid-Continent and Rocky Mountain regions with key market centers. ONEOK is among the largest natural gas distributors in the United States, serving more than two million customers in Oklahoma, Kansas and Texas. Our energy services operation focuses primarily on marketing natural gas and related services throughout the U.S. ONEOK is a FORTUNE 500 company and is included in Standard & Poor's (S&P) 500 Stock Index. For information about ONEOK, Inc., visit the website: www.oneok.com. For the latest news about ONEOK, follow us on Twitter @ONEOKNews. Some of the statements contained and incorporated in this news release are forward-looking statements within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act. The forward-looking statements relate to our anticipated financial performance, liquidity, management's plans and objectives for our future operations, our business prospects, the outcome of regulatory and legal proceedings, market conditions and other matters. We make these forward-looking statements in reliance on the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995. The following discussion is intended to identify important factors that could cause future outcomes to differ materially from those set forth in the forward-looking statements. Forward-looking statements include the items identified in the preceding paragraph, the information concerning possible or assumed future results of our operations and other statements contained or incorporated in this news release identified by words such as "anticipate," "estimate," "expect," "project," "intend," "plan," "believe," "should," "goal," "forecast," "guidance," "could," "may," "continue," "might," "potential," "scheduled," and other words and terms of similar meaning. One should not place undue reliance on forward-looking statements, which are applicable only as of the date of this news release. Known and unknown risks, uncertainties and other factors may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by forward-looking statements. Those factors may affect our operations, markets, products, services and prices. In addition to any assumptions and other factors referred to specifically in connection with the forward-looking statements, factors that could cause our actual results to differ materially from those contemplated in any forward-looking statement include, among others, the following: the effects of weather and other natural phenomena, including climate change, on our operations, including energy sales and demand for our services and energy prices; competition from other United States and foreign energy suppliers and transporters, as well as alternative forms of energy, including, but not limited to, solar power, wind power, geothermal energy and biofuels such as ethanol and biodiesel; the status of deregulation of retail natural gas distribution; the capital intensive nature of our businesses; the profitability of assets or businesses acquired or constructed by us; our ability to make cost-saving changes in operations; risks of marketing, trading and hedging activities, including the risks of changes in energy prices or the financial condition of our counterparties; the uncertainty of estimates, including accruals and costs of environmental remediation; the timing and extent of changes in energy commodity prices; the effects of changes in governmental policies and regulatory actions, including changes with respect to income and other taxes, pipeline safety, environmental compliance, climate change initiatives and authorized rates of recovery of natural gas and natural gas transportation costs; the impact on drilling and production by factors beyond our control, including the demand for natural gas and crude oil; producers' desire and ability to obtain necessary permits; reserve performance; and capacity constraints on the pipelines that transport crude oil, natural gas and NGLs from producing areas and our facilities; changes in demand for the use of natural gas because of market conditions caused by concerns about global warming; the impact of unforeseen changes in interest rates, equity markets, inflation rates, economic recession and other external factors over which we have no control, including the effect on pension and postretirement expense and funding resulting from changes in stock and bond market returns; our indebtedness could make us vulnerable to general adverse economic and industry conditions, limit our ability to borrow additional funds and/or place us at competitive disadvantages compared with our competitors that have less debt, or have other adverse consequences; actions by rating agencies concerning the credit ratings of ONEOK and ONEOK Partners; the results of administrative proceedings and litigation, regulatory actions, rule changes and receipt of expected clearances involving the Oklahoma Corporation Commission (OCC), Kansas Corporation Commission (KCC), Texas regulatory authorities or any other local, state or federal regulatory body, including the Federal Energy Regulatory Commission (FERC), the National Transportation Safety Board (NTSB), the Pipeline and Hazardous Materials Safety Administration (PHMSA), the Environmental Protection Agency (EPA) and the Commodity Futures Trading Commission (CFTC); our ability to access capital at competitive rates or on terms acceptable to us; risks associated with adequate supply to our gathering, processing, fractionation and pipeline facilities, including production declines that outpace new drilling; the risk that material weaknesses or significant deficiencies in our internal controls over financial reporting could emerge or that minor problems could become significant; the impact and outcome of pending and future litigation; the ability to market pipeline capacity on favorable terms, including the effects of: future demand for and prices of natural gas and NGLs; competitive conditions in the overall energy market; availability of supplies of Canadian and United States natural gas; and availability of additional storage capacity; performance of contractual obligations by our customers, service providers, contractors and shippers; the timely receipt of approval by applicable governmental entities for construction and operation of our pipeline and other projects and required regulatory clearances; our ability to acquire all necessary permits, consents or other approvals in a timely manner, to promptly obtain all necessary materials and supplies required for construction, and to construct gathering, processing, storage, fractionation and transportation facilities without labor or contractor problems; the mechanical integrity of facilities operated; demand for our services in the proximity of our facilities; our ability to control operating costs; adverse labor relations; acts of nature, sabotage, terrorism or other similar acts that cause damage to our facilities or our suppliers' or shippers' facilities; economic climate and growth in the geographic areas in which we do business; the risk of a prolonged slowdown in growth or decline in the United States or international economies, including liquidity risks in United States or foreign credit markets; the impact of recently issued and future accounting updates and other changes in accounting policies; the possibility of future terrorist attacks or the possibility or occurrence of an outbreak of, or changes in, hostilities or changes in the political conditions in the Middle East and elsewhere; the risk of increased costs for insurance premiums, security or other items as a consequence of terrorist attacks; risks associated with pending or possible acquisitions and dispositions, including our ability to finance or integrate any such acquisitions and any regulatory delay or conditions imposed by regulatory bodies in connection with any such acquisitions and dispositions; the possible loss of natural gas distribution franchises or other adverse effects caused by the actions of municipalities; the impact of uncontracted capacity in our assets being greater or less than expected; the ability to recover operating costs and amounts equivalent to income taxes, costs of property, plant and equipment and regulatory assets in our state and FERC-regulated rates; the composition and quality of the natural gas and NGLs we gather and process in our plants and transport on our pipelines; the efficiency of our plants in processing natural gas and extracting and fractionating NGLs; the impact of potential impairment charges; the risk inherent in the use of information systems in our respective businesses, implementation of new software and hardware, and the impact on the timeliness of information for financial reporting; our ability to control construction costs and completion schedules of our pipelines and other projects; and the risk factors listed in the reports we have filed and may file with the Securities and Exchange Commission (SEC), which are incorporated by reference. These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other factors could also have material adverse effects on our future results. These and other risks are described in greater detail in Item 1A, Risk Factors, in the Annual Report. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these factors. Other than as required under securities laws, we undertake no obligation to update publicly any forward-looking statement whether as a result of new information, subsequent events or change in circumstances, expectations or otherwise. Analyst Contact: Dan Harrison Megan Washbourne