----

|                  |
|------------------|
|                  |  |  |  |
| November 5, 2013 |   | Analyst Contact: | T.D. Eureste918-588-7167 |
|             |   | Media Contact: | Brad Borror918-588-7582 |

----

|         |                                                          |
|---------|----------------------------------------------------------|
| • | Significantly narrower NGL location price differentials; |

|         |                                                    |
|---------|----------------------------------------------------|
| • | Lower realized natural gas and NGL product prices; |

|         |                                                        |
|---------|--------------------------------------------------------|
| • | Lower NGL volumes as a result of ethane rejection; and |

|         |                                                                                     |
|---------|-------------------------------------------------------------------------------------|
| • | Increased depreciation and amortization expense from the completed growth projects. |

----

|         |                                                                                                                                        |
|---------|----------------------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas gathering and processing segment operating income of $58.5 million, compared with $57.0 million in the third quarter 2012; |

|         |                                                                                                                         |
|---------|-------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas liquids segment operating income of $146.2 million, compared with $158.8 million in the third quarter 2012; |

|         |                                                                                                                         |
|---------|-------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas pipelines segment operating income of $35.2 million, compared with $33.5 million in the third quarter 2012; |

|         |                                                                                                                                   |
|---------|-----------------------------------------------------------------------------------------------------------------------------------|
| • | Completing in August 2013 a public offering of 11.5 million common units generating net proceeds of approximately $553.4 million; |

|         |                                                                                                                                                                                                                                                                                                                          |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Completing in September 2013 a $1.25 billion public offering of senior notes, consisting of $425 million of five-year senior notes at 3.2 percent; $425 million of 10-year senior notes at 5.0 percent; and $400 million of 30-year senior notes at 6.2 percent, generating net proceeds of approximately $1.24 billion; |

|         |                                                                                                          |
|---------|----------------------------------------------------------------------------------------------------------|
| • | Increasing investments in its 2010 to 2015 growth program to a range of $5.3 billion to $5.6 billion by: |

|         |                                                                                                                                                                                                                                                                           |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Completing in September 2013 the acquisition of a 50-million cubic feet per day (MMcf/d) natural gas processing facility - the Sage Creek plant and related natural gas gathering and NGL infrastructure - in Converse and Campbell Counties, Wyo., for $305 million; and |

|         |                                                                                                                                                                                                                                                                                                           |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Announcing an investment of $135 million in the Sage Creek assets to upgrade and construct natural gas gathering and processing related infrastructure, construct new NGL pipeline infrastructure and connect the Sage Creek natural gas processing plant to the partnership’s Bakken NGL Pipeline; |

----

|         |                                                                                                                                                                                                                                   |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Having $723.0 million of cash and cash equivalents and $47.0 million in commercial paper outstanding and no borrowings outstanding under the partnership’s $1.2 billion revolving credit facility as of Sept. 30, 2013; and |

|         |                                                                                                                                                                                                                       |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Increasing in October 2013 its third-quarter distribution to 72.5 cents per unit, or $2.90 per unit on an annualized basis, payable on Nov. 14, 2013, to unitholders of record at the close of business Nov. 4, 2013. |

|         |                                                                                                                                                                                                                                                                                        |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $21.1 million increase due primarily to volume growth in the Williston Basin from the Stateline I and Stateline II natural gas processing plants and increased well connections, which resulted in higher natural gas volumes gathered, compressed, processed, transported and sold; |

|         |                                                                             |
|---------|-----------------------------------------------------------------------------|
| • | A $4.3 million decrease due primarily to lower realized NGL product prices; |

|         |                                                                                                     |
|---------|-----------------------------------------------------------------------------------------------------|
| • | A $1.8 million decrease due to changes in contract mix and terms associated with volume growth; and |

|         |                                                                                        |
|---------|----------------------------------------------------------------------------------------|
| • | A $13.5 million increase in operating costs and depreciation and amortization expense. |

|         |                                                                                                                                                                                                                                                                                        |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $66.0 million increase due primarily to volume growth in the Williston Basin from the Stateline I and Stateline II natural gas processing plants and increased well connections, which resulted in higher natural gas volumes gathered, compressed, processed, transported and sold; |

|         |                                                       |
|---------|-------------------------------------------------------|
| • | A $6.4 million increase due to a contract settlement; |

|         |                                                                              |
|---------|------------------------------------------------------------------------------|
| • | A $25.8 million decrease due primarily to lower realized NGL product prices; |

|         |                                                                                                  |
|---------|--------------------------------------------------------------------------------------------------|
| • | An $8.3 million decrease due to changes in contract mix and terms associated with volume growth; |

|         |                                                                                                                                                 |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $2.8 million decrease from lower dry natural gas volumes gathered in the Powder River Basin as a result of continued production declines; and |

|         |                                                                                        |
|---------|----------------------------------------------------------------------------------------|
| • | A $35.9 million increase in operating costs and depreciation and amortization expense. |

----

|         |                                                                                              |
|---------|----------------------------------------------------------------------------------------------|
| • | A $4.7 million increase due to higher materials, supplies and outside services expenses; and |

|         |                                                                                                                              |
|---------|------------------------------------------------------------------------------------------------------------------------------|
| • | A $1.0 million increase due to higher labor and employee benefit costs, offset partially by other employee-related expenses. |

|         |                                                                                           |
|---------|-------------------------------------------------------------------------------------------|
| • | A $10.4 million increase due to higher materials, supplies and outside services expenses; |

|         |                                                                                                                                  |
|---------|----------------------------------------------------------------------------------------------------------------------------------|
| • | A $6.6 million increase due to higher labor and employee benefit costs, offset partially by other employee-related expenses; and |

|         |                                                     |
|---------|-----------------------------------------------------|
| • | A $2.1 million increase from higher property taxes. |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                             |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas gathered was 1,389 billion British thermal units per day (BBtu/d) in the third quarter 2013, up 21 percent compared with the same period last year due to increased well connections in the Williston Basin and western Oklahoma, and the completion of additional natural gas gathering lines and compression; including its Divide County gathering system, to support the Stateline I and Stateline II natural gas processing plants in the Williston Basin, offset partially by continued dry natural gas production declines in the Powder River Basin in Wyoming; and up 5 percent compared with the second quarter 2013; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                           |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas processed was 1,135 BBtu/d in the third quarter 2013, up 25 percent compared with the same period last year due to increased well connections in the Williston Basin and western Oklahoma, and the completion of the Stateline I and Stateline II natural gas processing plants in the Williston Basin, including its Divide County gathering system; and up 8 percent compared with the second quarter 2013; |

|         |                                                                                                                                                                                                                                                                                                       |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | NGL sales were 83,000 barrels per day (bpd) in the third quarter 2013, up 34 percent compared with the same period last year due to the completion of the Stateline I and Stateline II natural gas processing plants in the Williston Basin; and up 11 percent compared with the second quarter 2013; |

----

|         |                                                                                                                                                                                                                |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | The realized composite NGL net sales price was 90 cents per gallon in the third quarter 2013, down 18 percent compared with the same period last year; and up 6 percent compared with the second quarter 2013; |

|         |                                                                                                                                                                                                            |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | The realized condensate net sales price was $90.68 per barrel in the third quarter 2013, up 5 percent compared with the same period last year; and up 8 percent compared with the second quarter 2013; and |

|         |                                                                                                                                                                                                                                                   |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | The realized residue natural gas net sales price was $3.36 per million British thermal units (MMBtu) in the third quarter 2013, down 9 percent compared with the same period last year; and down 6 percent compared with the second quarter 2013. |

----

|                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                         |
|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
|                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                         |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
|                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                    |   | Three Months Ended |   | Nine Months Ended |
|                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                    |   | September 30, |   | September 30, |
| Operating Information (a) (d)                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                           |   | 2013 |   | 2012 |   | 2013 |   | 2012 |
| Commodity                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                               |   |   |   |   |   |   |   |   |
| NGL sales (Bbl/d) (b)                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                   |   | 14,621 |  |   | 11,487 |  |   | 13,827 |  |   | 11,097 |  |
| Residue gas sales (MMBtu/d) (c)                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                         |   | 76,801 |  |   | 54,435 |  |   | 67,722 |  |   | 46,636 |  |
| Condensate sales (Bbl/d) (b)                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                            |   | 2,018 |  |   | 2,025 |  |   | 2,373 |  |   | 2,401 |  |
| Percentage of total net margin                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                          |   | 66 | % |   | 70 | % |   | 65 | % |   | 69 | % |
| Fee-based                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                               |   |   |  |   |   |  |   |   |  |   |   |  |
| Wellhead volumes (MMBtu/d)                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                              |   | 1,389,485 |  |   | 1,149,072 |  |   | 1,310,734 |  |   | 1,091,063 |  |
| Average rate ($/MMBtu)                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                  |   | $ | 0.35 |  |   | $ | 0.34 |  |   | $ | 0.35 |  |   | $ | 0.35 |  |
| Percentage of total net margin                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                          |   | 34 | % |   | 30 | % |   | 35 | % |   | 31 | % |
| (a) - Includes volumes for consolidated entities only.(b) - Represents equity volumes.(c) - Represents equity volumes net of fuel.(d) - Keep-whole quantities represent less than two percent of our contracts by volume.  The quantities of natural gas for fuel and shrink associated with our keep-whole contracts have been deducted from residue gas sales, and the NGLs and condensate retained from our keep-whole contracts are included in NGL sales and condensate sales.  Prior periods have been recast to conform to current presentation. |

|                       |
|-----------------------|
|                       |  |  |  |  |  |  |  |  |  |  |
|                  |   | Three Months Ending December 31, 2013 |
|                  |   | VolumesHedged |   | Average Price |   | PercentageHedged |
| NGLs (Bbl/d)          |   | 9,034 |  |   | $ | 1.11 |  | / gallon |   | 61% |
| Condensate (Bbl/d)    |   | 2,213 |  |   | $ | 2.41 |  | / gallon |   | 80% |
| Total (Bbl/d)         |   | 11,247 |  |   | $ | 1.37 |  | / gallon |   | 64% |
| Natural gas (MMBtu/d) |   | 68,315 |  |   | $ | 3.90 |  | / MMBtu |   | 75% |
|                  |   |   |   |   |   |   |   |
|                  |   |   |   |   |   |   |   |
|                  |   | Year Ending December 31, 2014 |
|                  |   | VolumesHedged |   | Average Price |   | PercentageHedged |
| NGLs (Bbl/d)          |   | 1,475 |  |   | $ | 1.37 |  | / gallon |   | 11% |
| Condensate (Bbl/d)    |   | 2,233 |  |   | $ | 2.24 |  | / gallon |   | 66% |
| Total (Bbl/d)         |   | 3,708 |  |   | $ | 1.89 |  | / gallon |   | 22% |
| Natural gas (MMBtu/d) |   | 69,274 |  |   | $ | 4.11 |  | / MMBtu |   | 63% |
|                  |   |   |   |   |   |   |   |
|                  |   |   |   |   |   |   |   |
|                  |   | Year Ending December 31, 2015 |
|                  |   | VolumesHedged |   | Average Price |   | PercentageHedged |
| Natural gas (MMBtu/d) |   | 48,877 |  |   | $ | 4.19 |  | / MMBtu |   | 41% |

----

|         |                                                                                                                         |
|---------|-------------------------------------------------------------------------------------------------------------------------|
| • | A 1-cent-per-gallon change in the composite price of NGLs would change annual net margin by approximately $2.0 million; |

|         |                                                                                                                       |
|---------|-----------------------------------------------------------------------------------------------------------------------|
| • | A $1.00-per-barrel change in the price of crude oil would change annual net margin by approximately $1.3 million; and |

|         |                                                                                                                      |
|---------|----------------------------------------------------------------------------------------------------------------------|
| • | A 10-cent-per-MMBtu change in the price of natural gas would change annual net margin by approximately $3.7 million. |

|         |                                                                                                                                                                                                                                               |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $35.0 million increase in exchange-services margins from higher NGL volumes gathered, higher fees from contract renegotiations for its NGL exchange-services activities and higher revenues from customers with minimum volume obligations; |

|         |                                                                                                                                                                                                    |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $9.8 million increase in operational measurement gains of approximately $2.8 million in the third quarter 2013, compared with losses of approximately $7.0 million in the same period last year; |

|         |                                                                                      |
|---------|--------------------------------------------------------------------------------------|
| • | A $4.1 million increase in storage margins due primarily to contract renegotiations; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                             |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $42.3 million decrease in optimization and marketing margins, primarily as a result of a $39.5 million decrease from significantly narrower NGL location price differentials, offset partially by higher transportation capacity available for optimization activities due to ethane rejection, and a $17.8 million decrease in marketing margins, offset partially by a $15.0 million increase due primarily to more favorable NGL product price differentials.  In the third quarter 2012, the segment realized higher marketing margins on the sale of NGL inventory held as a result of scheduled maintenance at its Mont Belvieu, Texas, NGL fractionation facility; |

|         |                                                                                                    |
|---------|----------------------------------------------------------------------------------------------------|
| • | An $8.0 million decrease from the impact of ethane rejection, which resulted in lower NGL volumes; |

|         |                                                                                                                                                 |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $6.9 million decrease from lower isomerization volumes, resulting from narrower price differentials between normal butane and iso-butane; and |

----

|         |                                                                                       |
|---------|---------------------------------------------------------------------------------------|
| • | A $4.6 million increase in operating costs and depreciation and amortization expense. |

|         |                                                                                                                                                                                                                                                |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $124.6 million increase in exchange-services margins from higher NGL volumes gathered, higher fees from contract renegotiations for its NGL exchange-services activities and higher revenues from customers with minimum volume obligations; |

|         |                                                                                                                                                                                                      |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $19.7 million increase due to the impact of operational measurement gains of approximately $11.5 million in 2013, compared with losses of approximately $8.2 million in the same period last year; |

|         |                                                                                      |
|---------|--------------------------------------------------------------------------------------|
| • | A $5.7 million increase in storage margins due primarily to contract renegotiations; |

|         |                                                                                                                                                    |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $173.8 million decrease in optimization and marketing margins, primarily as a result of significantly narrower NGL location price differentials; |

|         |                                                                                                    |
|---------|----------------------------------------------------------------------------------------------------|
| • | A $32.0 million decrease from the impact of ethane rejection, which resulted in lower NGL volumes; |

|         |                                                                                                                                                     |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $15.8 million decrease from lower isomerization volumes, resulting from the narrower price differential between normal butane and iso-butane; and |

|         |                                                                                        |
|---------|----------------------------------------------------------------------------------------|
| • | A $15.3 million increase in operating costs and depreciation and amortization expense. |

|         |                                                                                                 |
|---------|-------------------------------------------------------------------------------------------------|
| • | A $2.8 million increase due to higher property taxes related to completed capital projects; and |

|         |                                                                                                                                                                                                |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $1.7 million decrease due to other employee-related expenses, offset partially by higher labor and employee benefit costs due to growth in operations related to completed capital projects. |

|         |                                                                                                                                                                                                                       |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $2.0 million increase due to higher labor and employee benefit costs associated with the growth in operations related to completed capital projects, offset partially by other lower employee-related expenses; and |

|         |                                                       |
|---------|-------------------------------------------------------|
| • | A $3.6 million increase due to higher property taxes. |

----

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                            |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | NGLs transported on gathering lines were 574,000 bpd in the third quarter 2013, up 8 percent compared with the same period last year, due primarily to increased volumes from the Williston Basin made available by the completed Bakken NGL Pipeline; and NGLs gathered as a result of the capacity increase in the Mid-Continent and Texas made available through the partnership’s Cana-Woodford Shale and Granite Wash projects; offset partially by decreases in NGL volumes gathered as a result of ethane rejection; and up 4 percent compared with the second quarter 2013 ; |

|         |                                                                                                                                                                                                                                                                                                                                                                        |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | NGLs fractionated were 557,000 bpd in the third quarter 2013, down 4 percent compared with the same period last year, due to lower volumes from ethane rejection during 2013, offset partially by higher volumes from the Williston Basin made available by the segment’s completed Bakken NGL Pipeline; and up 4 percent compared with the second quarter 2013; |

|         |                                                                                                                                                                                                                                                                    |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | NGLs transported on distribution lines were 454,000 bpd in the third quarter 2013, down 10 percent compared with the same period last year, due primarily to decreased volumes  from ethane rejection; and up 5 percent compared with the second quarter 2013; and |

|         |                                                                                                                                                                                                                                                                                                                    |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | The average Conway-to-Mont Belvieu price differential of ethane in ethane/propane mix, based on Oil Price Information Service (OPIS) pricing, was 4 cents per gallon in the third quarter 2013, compared with 16 cents per gallon in the same period last year; and 6 cents per gallon in the second quarter 2013. |

----

|         |                                                                                                                                                                                                                               |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas transportation capacity contracted was 5,428 thousand dekatherms per day in the third quarter 2013, up 3 percent compared with the same period last year; and up 1 percent compared with the second quarter 2013; |

|         |                                                                                                                                                                                                            |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas transportation capacity subscribed was 89 percent in the third quarter 2013, up 2 percent compared with the same period last year; and up 1 percent compared with the second quarter 2013; and |

|         |                                                                                                                                                                                                                            |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | The average natural gas price in the Mid-Continent region was $3.42 per MMBtu in the third quarter 2013, up 24 percent compared with the same period last year; and down 11 percent compared with the second quarter 2013. |

|         |                                                                                                                                                                                                                                    |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Of the approximately $2.4 billion to $2.5 billion of announced growth projects and acquisitions in the natural gas gathering and processing segment, projects totaling approximately $1.3 billion have been completed, as follows: |

|         |                                                                                                                                                                                                                                                                                                                                                                                   |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $360 million for the Garden Creek plant, a 100 MMcf/d natural gas processing facility in the Bakken Shale and Three Forks formations in the Williston Basin in North Dakota that was placed in service in December 2011, and related expansions; and for new well connections, expansions and upgrades to the existing natural gas gathering system infrastructure; |

|         |                                                                                                                                                                                                                                                                                                                                  |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $600 million to construct the Stateline I and Stateline II plants, each with 100 MMcf/d of natural gas processing capacity, and related expansions and upgrades to the existing gathering and compression infrastructure, and new well connections in the Bakken Shale and Three Forks formations in the Williston |

----

|         |                                                                                                                                                                                                                         |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $305 million to acquire the Sage Creek plant, a 50 MMcf/d natural gas processing facility, and related natural gas gathering and natural gas liquids infrastructure in the Powder River Basin in Wyoming. |

|         |                                                                                                                                                                                |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $1.1 billion to $1.2 billion of announced growth projects in the natural gas gathering and processing segment are in various stages of construction, as follows: |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                              |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $150 million to construct a 270-mile natural gas gathering system and related infrastructure in Divide County, N.D., that was placed in service in 2013.  The remaining $20 million of additional expansion of the system is expected to be completed by year-end 2014.  The system gathers and transports natural gas from producers in the Bakken Shale and Three Forks formations in the Williston Basin to the partnership's Stateline I and Stateline II plants, each with 100 MMcf/d of natural gas processing capacity in western Williams County, N.D; |

|         |                                                                                                                                                                                                                                                                                                            |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $350 million to construct the Canadian Valley plant, a 200 MMcf/d natural gas processing facility in the Cana-Woodford Shale in Oklahoma, which is expected to be completed in the first quarter 2014; and expansions and upgrades to the existing gathering and compression infrastructure; |

|         |                                                                                                                                                                                                                                                                                                                                                                           |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $310 million to $345 million to construct the Garden Creek II plant, a 100 MMcf/d natural gas processing facility in the Bakken Shale and Three Forks formations in the Williston Basin in North Dakota, which is expected to be completed in the third quarter 2014; and expansions and upgrades to the existing gathering and compression infrastructure; |

|         |                                                                                                                                                                                         |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $50 million to upgrade the recently acquired Sage Creek natural gas processing plant, and construct natural gas gathering and processing infrastructure through 2016; and |

|         |                                                                                                                                                                                                                                                                                                                                                                            |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $325 million to $360 million to construct the Garden Creek III plant, a 100 MMcf/d natural gas processing facility in the Bakken Shale and Three Forks formations in the Williston Basin in North Dakota, which is expected to be completed in the first quarter 2015; and expansions and upgrades to the existing gathering and compression infrastructure. |

|         |                                                                                                                                                                                                                   |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Of the approximately $2.9 billion to $3.1 billion of announced growth projects and acquisitions in the natural gas liquids segment, projects totaling approximately $900 million have been completed, as follows: |

----

|         |                                                                                                                                                                                                                                                                             |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $30 million for the installation of seven additional pump stations along its existing Sterling I NGL distribution pipeline that was placed in service at the end of 2011; the additional pump stations increased the pipeline’s capacity by 15,000 bpd; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                              |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $220 million to construct more than 230 miles of 10- and 12-inch diameter NGL pipelines that expanded the partnership's existing Mid-Continent NGL gathering system in the Cana-Woodford and Granite Wash areas by adding an incremental 75,000 bpd to 80,000 bpd of unfractionated NGLs to the partnership's existing NGL gathering systems in the Mid-Continent and the Arbuckle Pipeline.  These NGL pipelines were placed in service in April 2012, and the partnership connected three new third-party natural gas processing facilities and three existing third-party natural gas processing facilities that were expanded to its NGL gathering system.  In addition, the installation of additional pump stations on the Arbuckle Pipeline was completed, increasing its capacity to 240,000 bpd; |

|         |                                                                                                                                                                                                                                                     |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $117 million for a 60,000 bpd expansion of the partnership’s NGL fractionation capacity at Bushton, Kan., which was placed in service in September 2012, to accommodate NGL volumes from the Mid-Continent and Williston Basin; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                             |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $490 million to $520 million for the construction of an approximately 600-mile NGL pipeline - the Bakken NGL Pipeline - to transport unfractionated NGLs produced from the Bakken Shale in the Williston Basin to the partnership’s 50 percent-owned Overland Pass Pipeline, a 760-mile NGL pipeline extending from southern Wyoming to Conway, Kan.  The Bakken NGL Pipeline was placed in service in April 2013, with current capacity of 60,000 bpd; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                 |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $23 million for the construction of a 12-inch diameter ethane header pipeline that creates a new point of interconnection between the Mont Belvieu, Texas, NGL fractionation and storage assets, and several petrochemical customers.  The ethane header pipeline has the capacity to transport 400,000 bpd of purity ethane from the partnership’s NGL storage facilities; its 80 percent-owned, 160,000 bpd MB-1 NGL fractionator; and its two wholly owned, 75,000-bpd MB-2 and MB-3 NGL fractionators that are under construction.  The ethane header pipeline was placed in service in April 2013; and |

|         |                                                                                                                                                                                                                                                                       |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $36 million on the partnership’s 50 percent-owned Overland Pass Pipeline for a 60,000-bpd capacity expansion to transport the additional unfractionated NGL volumes from the Bakken NGL Pipeline, which was completed in the second quarter 2013. |

----

|         |                                                                                                                                                               |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $2.0 billion to $2.2 billion of announced growth projects in the natural gas liquids segment are in various stages of construction, as follows: |

|         |                                                                                                                                                                                      |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $360 million to $390 million for the construction of a 75,000 bpd NGL fractionator, MB-2, at Mont Belvieu, Texas, which is expected to be in service in November 2013; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                            |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $700 million to $800 million for the construction of a 540-plus-mile, 16-inch NGL pipeline - the Sterling III Pipeline - expected to be completed in late 2013, to transport either unfractionated NGLs or NGL purity products from the Mid-Continent region to the Texas Gulf Coast, with an initial capacity of 193,000 bpd and the ability to expand to 250,000 bpd; and the reconfiguration of its existing Sterling I and II NGL distribution pipelines to transport either unfractionated NGLs or NGL purity products; |

|         |                                                                                                                                                                                                                            |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $45 million to install a 40,000 bpd ethane/propane (E/P) splitter at its Mont Belvieu NGL storage facility to split E/P mix into purity ethane, which is expected to be completed in the first quarter 2014; |

|         |                                                                                                                                                                                                                                                  |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $100 million to install additional pump stations on the Bakken NGL Pipeline to increase its capacity to 135,000 bpd from its current capacity of 60,000 bpd.  The expansion is expected to be completed in the third quarter 2014; |

|         |                                                                                                                                                                                                                         |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $525 million to $575 million for the construction of a 75,000 bpd NGL fractionator, MB-3, and related infrastructure at Mont Belvieu, Texas, that is expected to be completed in the fourth quarter 2014; |

|         |                                                                                                                                                                                                                                                            |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $85 for the construction of new NGL pipeline infrastructure to connect the recently acquired Sage Creek natural gas processing plant to the partnerships’ Bakken NGL Pipeline, which is expected to be completed by year-end 2014; and |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                 |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Approximately $140 million, announced in January 2013, for the construction of an approximately 95-mile NGL pipeline between existing NGL fractionation infrastructure at Hutchinson, Kan., and Medford, Okla., and the modification of the partnership’s NGL fractionation infrastructure at Hutchinson, Kan., to accommodate unfractionated NGLs produced in the Williston Basin; both projects are expected to be completed in the first quarter 2015. |

----

|         |                                                                                                                                                                     |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | EBITDA is defined as net income adjusted for interest expense, depreciation and amortization, income taxes and allowance for equity funds used during construction; |

|         |                                                                                                                                                                                                                        |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | DCF is defined as EBITDA, computed as described above, less interest expense, maintenance capital expenditures and equity earnings from investments, adjusted for cash distributions received and certain other items; |

|         |                                                                                                                                                                                     |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Coverage ratio is defined as distributable cash flow to limited partners per limited partner unit divided by the distribution declared per limited partner unit for the period; and |

|         |                                                                                                                                                                                                                                        |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Distributable cash flow to limited partners per limited partner unit is computed as DCF less distributions declared to the general partner for the period, divided by the weighted-average number of units outstanding for the period. |

----

----

|         |                                                                                                                                             |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------|
| • | the effects of weather and other natural phenomena, including climate change, on our operations, 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 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; |

|         |                                                                                                                         |
|---------|-------------------------------------------------------------------------------------------------------------------------|
| • | difficulties or delays experienced by trucks or pipelines in delivering products to or from our terminals or pipelines; |

|         |                                                                                                                                  |
|---------|----------------------------------------------------------------------------------------------------------------------------------|
| • | changes in demand for the use of natural gas and crude oil because of market conditions caused by concerns about global warming; |

|         |                                                                                                                     |
|---------|---------------------------------------------------------------------------------------------------------------------|
| • | conflicts of interest between us, our general partner, ONEOK Partners GP, and related parties of ONEOK Partners GP; |

|         |                                                                                                                                                                   |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | the impact of unforeseen changes in interest rates, equity markets, inflation rates, economic recession and other external factors over which we have no control; |

|         |                                                                                                                                                                                                                                                                                |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | 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 us or the parent of our general partner; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                       |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | 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 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 or extended periods of ethane rejection; |

|         |                                                                                                                                                                              |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | the risk that material weaknesses or significant deficiencies in our internal control 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: |

|         |                                                                                                       |
|---------|-------------------------------------------------------------------------------------------------------|
| • | 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 and 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; |

|         |                                                                                                                                                      |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | 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 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. |

----

|                                                                   |
|-------------------------------------------------------------------|
|                                                                   |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| ONEOK Partners, L.P. and Subsidiaries                             |   |   |   |   |   |   |   |
| CONSOLIDATED STATEMENTS OF INCOME                                 |   |   |   |   |   |   |   |
|                                                              | Three Months Ended |   | Nine Months Ended |
|                                                              | September 30, |   | September 30, |
| (Unaudited)                                                       | 2013 |   | 2012 |   | 2013 |   | 2012 |
|                                                              | (Thousands of dollars, except per unit amounts) |
| Revenues                                                          | $ | 3,134,733 |  |   | $ | 2,547,460 |  |   | $ | 8,420,359 |  |   | $ | 7,266,354 |  |
| Cost of sales and fuel                                            | 2,711,159 |  |   | 2,127,723 |  |   | 7,214,233 |  |   | 6,024,065 |  |
| Net margin                                                        | 423,574 |  |   | 419,737 |  |   | 1,206,126 |  |   | 1,242,289 |  |
| Operating expenses                                                |   |  |   |   |  |   |   |  |   |   |  |
| Operations and maintenance                                        | 108,978 |  |   | 110,268 |  |   | 338,353 |  |   | 319,905 |  |
| Depreciation and amortization                                     | 61,182 |  |   | 49,754 |  |   | 174,086 |  |   | 150,024 |  |
| General taxes                                                     | 13,384 |  |   | 10,908 |  |   | 46,249 |  |   | 40,505 |  |
| Total operating expenses                                          | 183,544 |  |   | 170,930 |  |   | 558,688 |  |   | 510,434 |  |
| Gain (loss) on sale of assets                                     | 22 |  |   | (420 | ) |   | 342 |  |   | 603 |  |
| Operating income                                                  | 240,052 |  |   | 248,387 |  |   | 647,780 |  |   | 732,458 |  |
| Equity earnings from investments                                  | 27,468 |  |   | 28,591 |  |   | 79,744 |  |   | 92,380 |  |
| Allowance for equity funds used during construction               | 6,429 |  |   | 3,302 |  |   | 21,172 |  |   | 6,126 |  |
| Other income                                                      | 3,753 |  |   | 2,971 |  |   | 8,229 |  |   | 6,567 |  |
| Other expense                                                     | (589 | ) |   | (472 | ) |   | (2,447 | ) |   | (2,104 | ) |
| Interest expense (net of capitalized interest of $14,320, $11,328 |   |   |   |   |   |   |   |
| $38,284 and $29,472, respectively)                                | (57,722 | ) |   | (47,776 | ) |   | (171,118 | ) |   | (148,110 | ) |
| Income before income taxes                                        | 219,391 |  |   | 235,003 |  |   | 583,360 |  |   | 687,317 |  |
| Income taxes                                                      | (2,991 | ) |   | (2,626 | ) |   | (7,821 | ) |   | (9,396 | ) |
| Net income                                                        | 216,400 |  |   | 232,377 |  |   | 575,539 |  |   | 677,921 |  |
| Less:  Net income attributable to noncontrolling interests        | 90 |  |   | 102 |  |   | 263 |  |   | 336 |  |
| Net income attributable to ONEOK Partners, L.P.                   | $ | 216,310 |  |   | $ | 232,275 |  |   | $ | 575,276 |  |   | $ | 677,585 |  |
|                                                              |   |   |   |   |   |   |   |
| Limited partners’ interest in net income:                   |   |   |   |   |   |   |   |
| Net income attributable to ONEOK Partners, L.P.                   | $ | 216,310 |  |   | $ | 232,275 |  |   | $ | 575,276 |  |   | $ | 677,585 |  |
| General partner’s interest in net income                    | (71,344 | ) |   | (59,807 | ) |   | (202,732 | ) |   | (163,210 | ) |
| Limited partners’ interest in net income                    | $ | 144,966 |  |   | $ | 172,468 |  |   | $ | 372,544 |  |   | $ | 514,375 |  |
|                                                              |   |   |   |   |   |   |   |
| Limited partners’ net income per unit, basic and diluted    | $ | 0.64 |  |   | $ | 0.78 |  |   | $ | 1.68 |  |   | $ | 2.38 |  |
|                                                              |   |   |   |   |   |   |   |
| Number of units used in computation (thousands)                   | 226,991 |  |   | 219,816 |  |   | 222,322 |  |   | 216,241 |  |

----

|                                                                           |
|---------------------------------------------------------------------------|
|                                                                           |  |  |  |  |  |  |  |  |
| ONEOK Partners, L.P. and Subsidiaries                                     |   |   |   |   |
| CONSOLIDATED BALANCE SHEETS                                               |   |   |   |   |
|                                                                      |   | September 30, |   | December 31, |
| (Unaudited)                                                               |   | 2013 |   | 2012 |
| Assets                                                                    |   | (Thousands of dollars) |
| Current assets                                                            |   |   |   |   |
| Cash and cash equivalents                                                 |   | $ | 723,030 |  |   | $ | 537,074 |  |
| Accounts receivable, net                                                  |   | 956,575 |  |   | 914,036 |  |
| Affiliate receivables                                                     |   | 13,227 |  |   | 16,092 |  |
| Gas and natural gas liquids in storage                                    |   | 390,629 |  |   | 235,836 |  |
| Commodity imbalances                                                      |   | 93,722 |  |   | 89,704 |  |
| Other current assets                                                      |   | 83,829 |  |   | 98,966 |  |
| Total current assets                                                      |   | 2,261,012 |  |   | 1,891,708 |  |
|                                                                      |   |   |   |   |
| Property, plant and equipment                                             |   |   |   |   |
| Property, plant and equipment                                             |   | 10,245,377 |  |   | 8,585,142 |  |
| Accumulated depreciation and amortization                                 |   | 1,595,814 |  |   | 1,440,871 |  |
| Net property, plant and equipment                                         |   | 8,649,563 |  |   | 7,144,271 |  |
|                                                                      |   |   |   |   |
| Investments and other assets                                              |   |   |   |   |
| Investments in unconsolidated affiliates                                  |   | 1,201,873 |  |   | 1,221,405 |  |
| Goodwill and intangible assets                                            |   | 640,122 |  |   | 645,871 |  |
| Other assets                                                              |   | 110,756 |  |   | 55,975 |  |
| Total investments and other assets                                        |   | 1,952,751 |  |   | 1,923,251 |  |
| Total assets                                                              |   | $ | 12,863,326 |  |   | $ | 10,959,230 |  |
|                                                                      |   |   |   |   |
| Liabilities and equity                                                    |   |   |   |   |
| Current liabilities                                                       |   |   |   |   |
| Current maturities of long-term debt                                      |   | $ | 7,650 |  |   | $ | 7,650 |  |
| Notes payable                                                             |   | 47,000 |  |   | — |  |
| Accounts payable                                                          |   | 1,202,049 |  |   | 1,058,007 |  |
| Affiliate payables                                                        |   | 43,934 |  |   | 75,710 |  |
| Commodity imbalances                                                      |   | 228,207 |  |   | 273,173 |  |
| Accrued interest                                                          |   | 88,545 |  |   | 76,734 |  |
| Other current liabilities                                                 |   | 99,465 |  |   | 79,158 |  |
| Total current liabilities                                                 |   | 1,716,850 |  |   | 1,570,432 |  |
|                                                                      |   |   |   |   |
| Long-term debt, excluding current maturities                              |   | 6,046,494 |  |   | 4,803,629 |  |
|                                                                      |   |   |   |   |
| Deferred credits and other liabilities                                    |   | 108,087 |  |   | 121,662 |  |
|                                                                      |   |   |   |   |
| Commitments and contingencies                                             |   |   |   |   |
|                                                                      |   |   |   |   |
| Equity                                                                    |   |   |   |   |
| ONEOK Partners, L.P. partners’ equity:                              |   |   |   |   |
| General partner                                                           |   | 169,166 |  |   | 152,513 |  |
| Common units: 158,627,354 and 146,827,354 units issued and outstanding at |   |   |   |   |
| September 30, 2013, and December 31, 2012, respectively                   |   | 3,448,986 |  |   | 2,945,051 |  |
| Class B units: 72,988,252 units issued and outstanding at                 |   |   |   |   |
| September 30, 2013, and December 31, 2012                                 |   | 1,426,418 |  |   | 1,460,498 |  |
| Accumulated other comprehensive loss                                      |   | (57,263 | ) |   | (99,322 | ) |
| Total ONEOK Partners, L.P. partners’ equity                         |   | 4,987,307 |  |   | 4,458,740 |  |
|                                                                      |   |   |   |   |
| Noncontrolling interests in consolidated subsidiaries                     |   | 4,588 |  |   | 4,767 |  |
|                                                                      |   |   |   |   |
| Total equity                                                              |   | 4,991,895 |  |   | 4,463,507 |  |
| Total liabilities and equity                                              |   | $ | 12,863,326 |  |   | $ | 10,959,230 |  |

----

|                                                                                   |
|-----------------------------------------------------------------------------------|
|                                                                                   |  |  |  |  |  |  |  |  |
| ONEOK Partners, L.P. and Subsidiaries                                             |   |   |   |   |
| CONSOLIDATED STATEMENTS OF CASH FLOWS                                             |   |   |
|                                                                              |   | Nine Months Ended |
|                                                                              |   | September 30, |
| (Unaudited)                                                                       |   | 2013 |   | 2012 |
|                                                                              |   | (Thousands of dollars) |
| Operating activities                                                              |   |   |   |   |
| Net income                                                                        |   | $ | 575,539 |  |   | $ | 677,921 |  |
| Adjustments to reconcile net income to net cash provided by operating activities: |   |   |   |   |
| Depreciation and amortization                                                     |   | 174,086 |  |   | 150,024 |  |
| Allowance for equity funds used during construction                               |   | (21,172 | ) |   | (6,126 | ) |
| Gain on sale of assets                                                            |   | (342 | ) |   | (603 | ) |
| Deferred income taxes                                                             |   | 5,673 |  |   | 5,863 |  |
| Equity earnings from investments                                                  |   | (79,744 | ) |   | (92,380 | ) |
| Distributions received from unconsolidated affiliates                             |   | 79,022 |  |   | 92,996 |  |
| Changes in assets and liabilities:                                                |   |   |  |   |   |  |
| Accounts receivable                                                               |   | (42,539 | ) |   | 106,834 |  |
| Affiliate receivables                                                             |   | 2,865 |  |   | (10,229 | ) |
| Gas and natural gas liquids in storage                                            |   | (154,793 | ) |   | (125,033 | ) |
| Accounts payable                                                                  |   | 171,770 |  |   | (76,592 | ) |
| Affiliate payables                                                                |   | (31,776 | ) |   | 3,132 |  |
| Commodity imbalances, net                                                         |   | (48,984 | ) |   | 17,252 |  |
| Accrued interest                                                                  |   | 11,811 |  |   | (2,091 | ) |
| Other assets and liabilities, net                                                 |   | 12,702 |  |   | (120,448 | ) |
| Cash provided by operating activities                                             |   | 654,118 |  |   | 620,520 |  |
|                                                                              |   |   |   |   |
| Investing activities                                                              |   |   |   |    |  |
| Capital expenditures (less allowance for equity funds used during construction)   |   | (1,373,904 | ) |   | (1,011,527 | ) |
| Acquisition                                                                       |   | (304,889 | ) |   | — |  |
| Contributions to unconsolidated affiliates                                        |   | (4,558 | ) |   | (21,284 | ) |
| Distributions received from unconsolidated affiliates                             |   | 24,891 |  |   | 25,756 |  |
| Proceeds from sale of assets                                                      |   | 641 |  |   | 1,663 |  |
| Cash used in investing activities                                                 |   | (1,657,819 | ) |   | (1,005,392 | ) |
|                                                                              |   |   |   |   |
| Financing activities                                                              |   |   |   |   |
| Cash distributions:                                                               |   |   |   |    |  |
| General and limited partners                                                      |   | (669,981 | ) |   | (550,978 | ) |
| Noncontrolling interests                                                          |   | (442 | ) |   | (636 | ) |
| Borrowing of notes payable, net                                                   |   | 47,000 |  |   | — |  |
| Issuance of long-term debt, net of discounts                                      |   | 1,247,822 |  |   | 1,295,036 |  |
| Long-term debt financing costs                                                    |   | (10,217 | ) |   | (9,635 | ) |
| Repayment of long-term debt                                                       |   | (5,738 | ) |   | (358,948 | ) |
| Issuance of common units, net of issuance costs                                   |   | 569,246 |  |   | 919,521 |  |
| Contribution from general partner                                                 |   | 11,967 |  |   | 19,069 |  |
| Cash provided by financing activities                                             |   | 1,189,657 |  |   | 1,313,429 |  |
| Change in cash and cash equivalents                                               |   | 185,956 |  |   | 928,557 |  |
| Cash and cash equivalents at beginning of period                                  |   | 537,074 |  |   | 35,091 |  |
| Cash and cash equivalents at end of period                                        |   | $ | 723,030 |  |   | $ | 963,648 |  |

----

|                                                                                |
|--------------------------------------------------------------------------------|
|                                                                                |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| ONEOK Partners, L.P. and Subsidiaries                                          |   |   |   |   |   |   |   |
| INFORMATION AT A GLANCE                                                        |   |   |   |   |   |   |   |
|                                                                           | Three Months Ended |   | Nine Months Ended |
|                                                                           | September 30, |   | September 30, |
| (Unaudited)                                                                    | 2013 |   | 2012 |   | 2013 |   | 2012 |
|                                                                           | (Millions of dollars, except as noted) |
| Natural Gas Gathering and Processing                                           |   |   |   |   |   |   |   |
| Net margin                                                                     | $ | 130.9 |  |   | $ | 115.9 |  |   | $ | 365.4 |  |   | $ | 332.3 |  |
| Operating costs                                                                | $ | 45.1 |  |   | $ | 39.4 |  |   | $ | 141.7 |  |   | $ | 120.9 |  |
| Depreciation and amortization                                                  | $ | 27.4 |  |   | $ | 19.6 |  |   | $ | 76.4 |  |   | $ | 61.3 |  |
| Operating income                                                               | $ | 58.5 |  |   | $ | 57.0 |  |   | $ | 147.7 |  |   | $ | 151.3 |  |
| Equity earnings from investments                                               | $ | 4.7 |  |   | $ | 5.5 |  |   | $ | 16.2 |  |   | $ | 21.0 |  |
| Natural gas gathered (BBtu/d) (a)                                              | 1,389 |  |   | 1,149 |  |   | 1,311 |  |   | 1,091 |  |
| Natural gas processed (BBtu/d) (a) (b)                                         | 1,135 |  |   | 906 |  |   | 1,060 |  |   | 833 |  |
| NGL sales (MBbl/d) (a)                                                         | 83 |  |   | 62 |  |   | 77 |  |   | 57 |  |
| Residue gas sales (BBtu/d) (a)                                                 | 521 |  |   | 416 |  |   | 475 |  |   | 386 |  |
| Realized composite NGL net sales price ($/gallon) (a) (c)                      | $ | 0.90 |  |   | $ | 1.10 |  |   | $ | 0.87 |  |   | $ | 1.07 |  |
| Realized condensate net sales price ($/Bbl) (a) (c)                            | $ | 90.68 |  |   | $ | 86.54 |  |   | $ | 87.40 |  |   | $ | 87.72 |  |
| Realized residue gas net sales price ($/MMBtu) (a) (c)                         | $ | 3.36 |  |   | $ | 3.69 |  |   | $ | 3.48 |  |   | $ | 3.74 |  |
| Capital expenditures - growth                                                  | $ | 197.0 |  |   | $ | 152.0 |  |   | $ | 556.9 |  |   | $ | 419.8 |  |
| Capital expenditures - maintenance                                             | $ | 7.5 |  |   | $ | 5.7 |  |   | $ | 17.6 |  |   | $ | 15.3 |  |
| (a) - Includes volumes for consolidated entities only.                         |   |   |   |   |   |   |   |
| (b) - Includes volumes at company-owned and third-party facilities.            |   |   |   |   |   |   |
| (c) - Presented net of the impact of hedging activities on our equity volumes. |   |   |   |   |
|                                                                           |   |   |   |   |   |   |   |
| Natural Gas Liquids                                                            |   |   |   |   |   |   |   |
| Net margin                                                                     | $ | 226.2 |  |   | $ | 234.6 |  |   | $ | 632.1 |  |   | $ | 703.7 |  |
| Operating costs                                                                | $ | 57.0 |  |   | $ | 56.8 |  |   | $ | 171.1 |  |   | $ | 166.6 |  |
| Depreciation and amortization                                                  | $ | 23.0 |  |   | $ | 18.6 |  |   | $ | 65.0 |  |   | $ | 54.2 |  |
| Operating income                                                               | $ | 146.2 |  |   | $ | 158.8 |  |   | $ | 396.0 |  |   | $ | 482.4 |  |
| Equity earnings from investments                                               | $ | 6.3 |  |   | $ | 4.7 |  |   | $ | 15.4 |  |   | $ | 16.4 |  |
| NGL sales (MBbl/d)                                                             | 686 |  |   | 615 |  |   | 647 |  |   | 544 |  |
| NGLs transported-gathering lines (MBbl/d) (b)                                  | 574 |  |   | 530 |  |   | 542 |  |   | 517 |  |
| NGLs fractionated (MBbl/d) (a)                                                 | 557 |  |   | 581 |  |   | 535 |  |   | 565 |  |
| NGLs transported-distribution lines (MBbl/d) (b)                               | 454 |  |   | 504 |  |   | 426 |  |   | 489 |  |
| Conway-to-Mont Belvieu OPIS average price differential -                       |   |   |   |   |   |   |   |
| ethane in ethane/propane mix ($/gallon)                                        | $ | 0.04 |  |   | $ | 0.16 |  |   | $ | 0.04 |  |   | $ | 0.21 |  |
| Capital expenditures - growth                                                  | $ | 222.6 |  |   | $ | 198.4 |  |   | $ | 753.3 |  |   | $ | 518.0 |  |
| Capital expenditures - maintenance                                             | $ | 8.2 |  |   | $ | 13.9 |  |   | $ | 21.0 |  |   | $ | 43.5 |  |
| (a) - Includes volumes at company-owned and third-party facilities.            |   |   |   |   |   |   |
| (b) - Includes volumes for consolidated entities only.                         |   |   |   |   |   |   |   |
|                                                                           |   |   |   |   |   |   |   |
| Natural Gas Pipelines                                                          |   |   |   |   |   |   |   |
| Net margin                                                                     | $ | 69.5 |  |   | $ | 71.4 |  |   | $ | 211.2 |  |   | $ | 212.0 |  |
| Operating costs                                                                | $ | 23.5 |  |   | $ | 26.3 |  |   | $ | 75.6 |  |   | $ | 78.3 |  |
| Depreciation and amortization                                                  | $ | 10.8 |  |   | $ | 11.6 |  |   | $ | 32.7 |  |   | $ | 34.5 |  |
| Operating income                                                               | $ | 35.2 |  |   | $ | 33.5 |  |   | $ | 102.9 |  |   | $ | 99.1 |  |
| Equity earnings from investments                                               | $ | 16.5 |  |   | $ | 18.3 |  |   | $ | 48.1 |  |   | $ | 55.0 |  |
| Natural gas transportation capacity contracted (MDth/d) (a)                    | 5,428 |  |   | 5,249 |  |   | 5,486 |  |   | 5,345 |  |
| Transportation capacity subscribed (a)                                         | 89 | % |   | 87 | % |   | 90 | % |   | 88 | % |
| Average natural gas price                                                      |   |   |   |   |   |   |   |
| Mid-Continent region ($/MMBtu) (a)                                             | $ | 3.42 |  |   | $ | 2.75 |  |   | $ | 3.56 |  |   | $ | 2.43 |  |
| Capital expenditures - growth                                                  | $ | 5.4 |  |   | $ | — |  |   | $ | 7.8 |  |   | $ | 1.7 |  |
| Capital expenditures - maintenance                                             | $ | 5.7 |  |   | $ | 5.1 |  |   | $ | 14.7 |  |   | $ | 12.9 |  |
| (a) - Includes volumes for consolidated entities only.                         |   |   |   |   |   |   |   |

----

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|--------------------------------------------------------------------|
|                                                                    |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| ONEOK Partners, L.P. and Subsidiaries                              |   |   |   |   |   |   |   |   |
| RECONCILIATION OF NON-GAAP FINANCIAL MEASURES                      |   |   |   |   |   |   |
|                                                               |   |   |   |   |   |   |   |   |
|                                                               |   | Three Months Ended |   | Nine Months Ended |
|                                                               |   | September 30, |   | September 30, |
| (Unaudited)                                                        |   | 2013 |   | 2012 |   | 2013 |   | 2012 |
|                                                               | (Thousands of dollars, except per unit amounts) |
| Reconciliation of Net Income to EBITDA and Distributable Cash Flow |   |   |   |   |   |   |
| Net income                                                         |   | $ | 216,400 |  |   | $ | 232,377 |  |   | $ | 575,539 |  |   | $ | 677,921 |  |
| Interest expense                                                   |   | 57,722 |  |   | 47,776 |  |   | 171,118 |  |   | 148,110 |  |
| Depreciation and amortization                                      |   | 61,182 |  |   | 49,754 |  |   | 174,086 |  |   | 150,024 |  |
| Income taxes                                                       |   | 2,991 |  |   | 2,626 |  |   | 7,821 |  |   | 9,396 |  |
| Allowance for equity funds used during construction                |   | (6,429 | ) |   | (3,302 | ) |   | (21,172 | ) |   | (6,126 | ) |
| EBITDA                                                             |   | 331,866 |  |   | 329,231 |  |   | 907,392 |  |   | 979,325 |  |
| Interest expense                                                   |   | (57,722 | ) |   | (47,776 | ) |   | (171,118 | ) |   | (148,110 | ) |
| Maintenance capital                                                |   | (21,427 | ) |   | (25,587 | ) |   | (53,289 | ) |   | (72,089 | ) |
| Equity earnings from investments                                   |   | (27,468 | ) |   | (28,591 | ) |   | (79,744 | ) |   | (92,380 | ) |
| Distributions received from unconsolidated affiliates              |   | 34,409 |  |   | 34,557 |  |   | 103,913 |  |   | 118,752 |  |
| Other                                                              |   | (510 | ) |   | (448 | ) |   | (2,932 | ) |   | (4,771 | ) |
| Distributable cash flow                                            |   | $ | 259,148 |  |   | $ | 261,386 |  |   | $ | 704,222 |  |   | $ | 780,727 |  |
|                                                               |   |   |   |   |   |   |   |   |
| Distributions to general partner                                   |   | (71,812 | ) |   | (59,361 | ) |   | (205,002 | ) |   | (161,595 | ) |
| Distributable cash flow to limited partners                        |   | $ | 187,336 |  |   | $ | 202,025 |  |   | $ | 499,220 |  |   | $ | 619,132 |  |
|                                                               |   |   |   |   |   |   |   |   |
| Distributions declared per limited partner unit                    |   | $ | 0.725 |  |   | $ | 0.685 |  |   | $ | 2.16 |  |   | $ | 1.98 |  |
| Coverage ratio                                                     |   | 1.14 |  |   | 1.34 |  |   | 1.04 |  |   | 1.45 |  |
|                                                               |   |   |   |   |   |   |   |   |
| Number of units used in computation (thousands)                    |   | 226,991 |  |   | 219,816 |  |   | 222,322 |  |   | 216,241 |  |