----

|                |
|----------------|
|                |  |  |  |
| August 5, 2014 |   | Analyst Contact: | T.D. Eureste918-588-7167 |
|           |   | Media Contact: | Brad Borror918-588-7582 |

----

----

|         |                                                                                                                                                                                                                                          |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Higher natural gas volumes gathered, processed and sold, and higher NGL volumes sold as a result of recently completed capital-growth projects; and higher net realized prices, all in the natural gas gathering and processing segment; |

|         |                                                                                                                                 |
|---------|---------------------------------------------------------------------------------------------------------------------------------|
| • | Higher margin NGL volumes delivered from the Bakken NGL Pipeline and from new plants connected in the Mid-Continent region; and |

|         |                                                                                                                                                                                                              |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Higher natural gas pipeline transportation revenues due to increased rates on intrastate pipelines, and higher contracted capacity and natural gas volumes transported in the natural gas pipelines segment. |

----

|         |                                                                                                                                         |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas gathering and processing segment operating income of $66.1 million, compared with $55.5 million in the second quarter 2013; |

|         |                                                                                                                          |
|---------|--------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas liquids segment operating income of $159.0 million, compared with $142.7 million in the second quarter 2013; |

|         |                                                                                                                           |
|---------|---------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas pipelines segment operating income of $37.3 million, compared with $31.9  million in the second quarter 2013; |

|         |                                                                                                                                                                       |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Increasing in July 2014 investments in its 2010-2016 capital-growth program by approximately $1.1 billion to a range of $7.0 billion to $7.5 billion, which includes: |

|         |                                                                                                                                                                                                                                                                                                                                                                 |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Announcing an investment of approximately $515 million to $670 million to construct the Demicks Lake plant, a 200-MMcf/d natural gas processing facility in the Williston Basin in North Dakota, which is expected to be completed in the third quarter 2016; and expansions and upgrades to the existing natural gas gathering and compression infrastructure; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                       |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Announcing an investment of approximately $80 million to $100 million to construct additional natural gas compression to take advantage of additional natural gas processing capacity as a result of better than expected plant performance at the  partnership’s  existing and planned Garden Creek and Stateline natural gas processing plants in the Williston Basin by a total of 100 MMcf/d, which is expected to be completed in the fourth quarter 2015; |

|         |                                                                                                                                                                                                                                                                                                                |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Announcing an investment of approximately $10 million to $15 million to construct approximately 12 miles of natural gas liquids (NGL) gathering pipeline from the Demicks Lake plant to the partnerships’ existing Bakken NGL Pipeline, which is expected to be completed in the third quarter 2016; and |

|         |                                                                                                                                                                                                                                          |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| – | Announcing an investment of approximately $365 million to $470 million to construct the Knox plant, a 200-MMcf/d natural gas processing facility in Oklahoma’s SCOOP play, which is expected to be completed in the fourth quarter |

----

|         |                                                                                                                                             |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------|
| • | Completing in May 2014 a public offering of approximately 13.9 million common units, generating net proceeds of approximately $730 million; |

|         |                                                                                                                                                                                                                                                                                                                                                           |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Completing the sale of approximately $107.2 million of common units through the partnership’s $300 million at-the-market equity program, which combined with the public offering in May, resulted in ONEOK’s aggregate ownership interest in ONEOK Partners decreasing to 38.5 percent at June 30, 2014, from 41.0 percent at March 31, 2014; |

|         |                                                                                                |
|---------|------------------------------------------------------------------------------------------------|
| • | Increasing the partnership’s commercial paper program to $1.7 billion from $1.2 billion; |

|         |                                                                                                                                                                                                                                                            |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Having $278.0 million of cash and cash equivalents, $14.0 million in letters of credit issued, no commercial paper outstanding and no borrowings outstanding under the partnership’s $1.7 billion revolving credit facility as of June 30, 2014; and |

|         |                                                                                                                                                                                                  |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Increasing in July 2014 the second-quarter 2014 distribution to 76 cents per unit, or $3.04 per unit on an annualized basis, payable on Aug. 14, 2014, to unitholders of record on Aug. 4, 2014. |

|         |                                                                                                                                                                                                                                                                                                                                       |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $24.6 million increase due primarily to natural gas volume growth in the Williston Basin and Cana-Woodford Shale and increased ownership in the Maysville, Oklahoma, natural gas processing plant, which resulted in higher natural gas volumes gathered, compressed, processed, transported and sold, and higher NGL volumes sold; |

|         |                                                                       |
|---------|-----------------------------------------------------------------------|
| • | An $8.1 million increase due primarily to higher net realized prices; |

|         |                                                                       |
|---------|-----------------------------------------------------------------------|
| • | A $3.4 million increase due primarily to changes in contract mix; and |

|         |                                                                          |
|---------|--------------------------------------------------------------------------|
| • | A $6.4 million decrease due to a condensate contract settlement in 2013. |

|         |                                                                                              |
|---------|----------------------------------------------------------------------------------------------|
| • | A $9.4 million increase due to higher materials and supplies, and outside services expenses; |

|         |                                                                             |
|---------|-----------------------------------------------------------------------------|
| • | A $7.6 million increase due to higher labor and employee benefit costs; and |

|         |                                                                              |
|---------|------------------------------------------------------------------------------|
| • | A $2.6 million decrease due to the timing of property tax estimates in 2014. |

----

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                     |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $61.4 million increase due primarily to natural gas volume growth in the Williston Basin and Cana-Woodford Shale and increased ownership in the Maysville, Oklahoma, natural gas processing plant, which resulted in higher natural gas volumes gathered, compressed, processed, transported and sold, higher NGL volumes sold, and higher fees, offset partially by wellhead freeze-offs due to severely cold weather in the first quarter 2014; |

|         |                                                                       |
|---------|-----------------------------------------------------------------------|
| • | A $13.9 million increase due primarily to higher net realized prices; |

|         |                                                                       |
|---------|-----------------------------------------------------------------------|
| • | A $5.1 million increase due primarily to changes in contract mix; and |

|         |                                                                          |
|---------|--------------------------------------------------------------------------|
| • | A $6.4 million decrease due to a condensate contract settlement in 2013. |

|         |                                                                                               |
|---------|-----------------------------------------------------------------------------------------------|
| • | A $21.4 million increase due to higher materials and supplies, and outside services expenses; |

|         |                                                                              |
|---------|------------------------------------------------------------------------------|
| • | An $8.8 million increase due to higher labor and employee benefit costs; and |

|         |                                                                              |
|---------|------------------------------------------------------------------------------|
| • | A $2.7 million decrease due to the timing of property tax estimates in 2014. |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                             |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas gathered was 1,646 billion British thermal units per day (BBtu/d) in the second quarter 2014, up 24 percent compared with the same period in 2013 due to volume growth from new natural gas processing plants placed in service and increased ownership in the Maysville, Oklahoma, natural gas processing plant, offset partially by continued dry natural gas production declines in the Powder River Basin in Wyoming and natural gas production declines in Kansas; and up 10 percent compared with the first quarter 2014; |

|         |                                                                                                                                                                                                                                                                                                                                                    |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas processed was 1,447 BBtu/d in the second quarter 2014, up 37 percent compared with the same period in 2013 due to volume growth from new natural gas processing plants placed in service and the increased ownership in the Maysville, Oklahoma, natural gas processing plant; and up 14 percent compared with the first quarter 2014; |

----

|         |                                                                                                                                                                                     |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | NGL sales were 98,000 barrels per day (bpd) in the second quarter 2014, up 31 percent compared with the same period in 2013; and up 9 percent compared with the first quarter 2014; |

|         |                                                                                                                                                                                                                                                                                                                                                                          |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | The realized composite NGL net sales price was 96 cents per gallon in the second quarter 2014, up 13 percent compared with the same period in 2013; and down 9 percent compared with the first quarter 2014, due primarily to higher prices from increased demand associated with colder than normal weather and lower propane storage levels in the first quarter 2014; |

|         |                                                                                                                                                                                                            |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | The realized condensate net sales price was $77.46 per barrel in the second quarter 2014, down 8 percent compared with the same period in 2013; and up 2 percent compared with the first quarter 2014; and |

|         |                                                                                                                                                                                                                                               |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | The realized residue natural gas net sales price was $4.07 per million British thermal units (MMBtu) in the second quarter 2014, up 14 percent compared with the same period in 2013; and up 13 percent compared with the first quarter 2014. |

----

|                                                        |
|--------------------------------------------------------|
|                                                        |  |  |  |  |  |  |  |  |  |  |  |
|                                                   | Three Months Ended |   | Six Months Ended |
|                                                   | June 30, |   | June 30, |
| Equity-Volume Information (a)                          | 2014 |   | 2013 |   | 2014 |   | 2013 |
|                                                   |   |   |   |   |   |   |   |
| NGL sales (MBbl/d)                                     | 15.9 |  |   | 13.9 |  |   | 16.8 |  |   | 13.4 |  |
| Condensate sales (MBbl/d)                              | 3.1 |  |   | 2.5 |  |   | 3.3 |  |   | 2.6 |  |
| Residue natural gas sales (BBtu/d)                     | 105.3 |  |   | 68.8 |  |   | 96.9 |  |   | 63.1 |  |
| (a) - Includes volumes for consolidated entities only. |   |   |   |   |   |   |   |

|                      |
|----------------------|
|                      |  |  |  |  |  |  |  |  |  |
|                 | Six Months Ending December 31, 2014 |
|                 | VolumesHedged |   | Average Price |   | PercentageHedged |
| NGLs (MBbl/d)        | 11.1 |  |   | $ | 1.17 |  | / gallon |   | 57% |
| Condensate (MBbl/d)  | 2.5 |  |   | $ | 2.22 |  | / gallon |   | 73% |
| Total (MBbl/d)       | 13.6 |  |   | $ | 1.36 |  | / gallon |   | 60% |
| Natural gas (BBtu/d) | 89.2 |  |   | $ | 4.06 |  | / MMBtu |   | 76% |

|                      |
|----------------------|
|                      |  |  |  |  |  |  |  |  |  |
|                 | Year Ending December 31, 2015 |
|                 | VolumesHedged |   | Average Price |   | PercentageHedged |
| NGLs (MBbl/d)        | 1.2 |  |   | $ | 1.07 |  | / gallon |   | 7% |
| Natural gas (BBtu/d) | 61.3 |  |   | $ | 4.34 |  | / MMBtu |   | 44% |

----

|         |                                                                                                                              |
|---------|------------------------------------------------------------------------------------------------------------------------------|
| • | A 10-cent-per-MMBtu change in the price of residue natural gas would change annual net margin by approximately $4.6 million; |

|         |                                                                                                                             |
|---------|-----------------------------------------------------------------------------------------------------------------------------|
| • | A 1-cent-per-gallon change in the composite price of NGLs would change annual net margin by approximately $2.7 million; and |

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

|         |                                                                                                                                                                                                                                                                                                                                                               |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $31.4 million increase in exchange-services margins, resulting primarily from higher volumes delivered from the Bakken NGL Pipeline, volumes from new plants connected in the Mid-Continent region and higher fees from contract renegotiations for NGL exchange-services activities, offset partially by lower volumes from the termination of a contract; |

|         |                                                                                                                                                        |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $17.3 million increase from higher isomerization volumes, resulting from wider NGL product price differentials between normal butane and iso-butane; |

|         |                                                                                          |
|---------|------------------------------------------------------------------------------------------|
| • | A $1.3 million increase in storage margins due primarily to contract renegotiations; and |

|         |                                                                                 |
|---------|---------------------------------------------------------------------------------|
| • | A $2.7 million decrease from the impact of lower operational measurement gains. |

|         |                                                                                                                                                                                             |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | An $8.7 million increase due to higher outside services expenses associated primarily with scheduled maintenance and the growth of operations related to completed capital-growth projects; |

|         |                                                                                                        |
|---------|--------------------------------------------------------------------------------------------------------|
| • | A $4.5 million increase due to higher property taxes related to completed capital-growth projects; and |

----

|         |                                                                                                                                                                     |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $4.0 million increase due to higher employee-related expenses due to recently completed capital-growth projects and growth of the partnership’s operations. |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                       |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $72.4 million increase in optimization and marketing margins, resulting from a $28.2 million increase due to significantly wider NGL location price differentials from the impact of severely cold weather during the first quarter 2014, related primarily to propane; a $26.2 million increase from more favorable NGL product price differentials; and an $18.0 million increase in marketing margins, related primarily to increased weather-related seasonal demand for propane during the first quarter 2014; |

|         |                                                                                                                                                                                                                                                                                                                                                     |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $39.4 million increase in exchange-services margins, resulting primarily from higher volumes from the Bakken NGL Pipeline, volumes from new plants connected in the Mid-Continent region and higher fees from contract renegotiations for NGL exchange-services activities, offset partially by lower volumes from the termination of a contract; |

|         |                                                                                                                                                        |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $20.6 million increase from higher isomerization volumes, resulting from wider NGL product price differentials between normal butane and iso-butane; |

|         |                                                                                      |
|---------|--------------------------------------------------------------------------------------|
| • | A $4.7 million increase in storage margins due primarily to contract renegotiations; |

|         |                                                                                     |
|---------|-------------------------------------------------------------------------------------|
| • | A $4.1 million decrease from the impact of lower operational measurement gains; and |

|         |                                                                                                   |
|---------|---------------------------------------------------------------------------------------------------|
| • | A $3.8 million decrease from the impact of ethane rejection, which resulted in lower NGL volumes. |

|         |                                                                                                                                                                                              |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | An $11.0 million increase due to higher outside services expenses associated primarily with scheduled maintenance and the growth of operations related to completed capital-growth projects; |

|         |                                                                                                    |
|---------|----------------------------------------------------------------------------------------------------|
| • | A $6.6 million increase due to higher property taxes related to completed capital-growth projects; |

----

|         |                                                                                                                                                                         |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $5.0 million increase due to higher employee-related expenses due to recently completed capital-growth projects and growth of the partnership’s operations; and |

|         |                                                                                    |
|---------|------------------------------------------------------------------------------------|
| • | A $1.4 million increase due to higher costs for chemicals, materials and supplies. |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                            |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | NGLs transported on gathering lines were 520,000 bpd in the second quarter 2014, down 6 percent compared with the same period in 2013, due primarily to the termination of a contract and increased ethane rejection in the Mid-Continent region, offset partially by increased volumes from the Williston Basin made available by the Bakken NGL Pipeline that was placed in service in April 2013 and volumes from new plants connected in the Mid-Continent; and up 9 percent compared with the first quarter 2014; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                              |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | NGLs fractionated were 520,000 bpd in the second quarter 2014, down 3 percent compared with the same period in 2013, due primarily to the termination of a contract and increased ethane rejection in the Mid-Continent region, offset partially by increased volumes from the Williston Basin made available by the Bakken NGL Pipeline and volumes from new plants connected in the Mid-Continent; and up 10 percent compared with the first quarter 2014; |

|         |                                                                                                                                                                                |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | NGLs transported on distribution lines were 431,000 bpd in the second quarter 2014, relatively unchanged compared with the same period in 2013 and the first quarter 2014; and |

|         |                                                                                                                                                                                                                                                                                                                  |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | The average Conway-to-Mont Belvieu price differential of ethane in ethane/propane mix, based on Oil Price Information Service (OPIS) pricing, was 3 cents per gallon in the second quarter 2014, compared with 6 cents per gallon in the same period in 2013; and 12 cents per gallon in the first quarter 2014. |

|         |                                                                                                                                                                                                                                                                                                                                 |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $9.4 million increase from higher firm transportation revenues resulting primarily from higher rates on its intrastate natural gas pipelines, increased contracted capacity and rates on Midwestern Gas Transmission Company and increased interruptible transportation revenues from higher natural gas volumes transported; |

|         |                                                                                                            |
|---------|------------------------------------------------------------------------------------------------------------|
| • | A $1.4 million increase from additional storage services to meet utility customers’ peak-day demand; |

----

|         |                                                                                                                     |
|---------|---------------------------------------------------------------------------------------------------------------------|
| • | A $1.3 million increase from higher net retained fuel due primarily to additional natural gas volumes retained; and |

|         |                                                                                       |
|---------|---------------------------------------------------------------------------------------|
| • | A $4.3 million decrease due to lower storage revenues from lower contracted capacity. |

|         |                                                                                                                                                                                                                                                                                                                                  |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $13.8 million increase from higher firm transportation revenues resulting primarily from higher rates on its intrastate natural gas pipelines, increased contracted capacity and rates on Midwestern Gas Transmission Company and increased interruptible transportation revenues from higher natural gas volumes transported; |

|         |                                                                                                                                                                                                          |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $6.1 million increase from higher short-term natural gas storage services due to increased park-and-loan services associated with weather-related seasonal demand primarily in the first quarter 2014; |

|         |                                                                                                                                     |
|---------|-------------------------------------------------------------------------------------------------------------------------------------|
| • | A $6.0 million increase from higher net retained fuel due to higher natural gas prices and additional natural gas volumes retained; |

|         |                                                                                                                                                                              |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | A $5.3 million increase from higher park-and-loan services as a result of weather-related seasonal demand on its interstate natural gas pipelines in the first quarter 2014; |

|         |                                                                                                                          |
|---------|--------------------------------------------------------------------------------------------------------------------------|
| • | A $1.6 million increase primarily from additional storage services to meet utility customers’ peak-day demand; and |

|         |                                                                                       |
|---------|---------------------------------------------------------------------------------------|
| • | A $5.7 million decrease due to lower storage revenues from lower contracted capacity. |

|         |                                                                                                                                                                                                                               |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas transportation capacity contracted was 5,691 thousand dekatherms per day in the second quarter 2014, up 6 percent compared with the same period in 2013; and down 3 percent compared with the first quarter 2014; |

|         |                                                                                                                                                                                                            |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Natural gas transportation capacity subscribed was 90 percent in the second quarter 2014, up 2 percent compared with the same period in 2013; and down 3 percent compared with the first quarter 2014; and |

|         |                                                                                                                                                                                                                                                                                                                                               |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | The average natural gas price in the Mid-Continent region was $4.36 per MMBtu in the second quarter 2014, up 13 percent compared with the same period in 2013; and down 22 percent compared with the first quarter 2014, due primarily to higher natural gas prices in the first quarter 2014 as a result of weather-related seasonal demand. |

----

|         |                                                                                                                                                                                                                                                                                               |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $300 million to construct the Canadian Valley plant, a 200-MMcf/d natural gas processing facility in the Cana-Woodford Shale area in Oklahoma, which was completed in March 2014; and expansions and upgrades to existing natural gas gathering and compression infrastructure; |

|         |                                                                                                                                                                                                                                                                                   |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $305 million in September 2013 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 Niobrara Shale, an NGL-rich area in the Powder River Basin in Wyoming; |

|         |                                                                                                                                                                                                       |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $90 million in the fourth quarter 2013 to acquire the remaining 30 percent interest in the Maysville, Oklahoma, natural gas processing facility in the Cana-Woodford Shale in Oklahoma; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                        |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $125 million to construct a 270-mile natural gas gathering system and related infrastructure in Divide County, North Dakota.  The system, which required less infrastructure than originally anticipated, gathers and transports natural gas from producers in the Williston Basin to the partnership's Stateline I and Stateline II natural gas processing plants, each with 100 MMcf/d of natural gas processing capacity in western Williams County, North Dakota. The majority of the system was placed in service in the second quarter 2013, with the remaining portion of the system expected to be completed by the end of 2014; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                              |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $565 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 existing gathering and compression infrastructure in the Bakken Shale and Three Forks formations in the Williston Basin in North Dakota. The Stateline I plant was placed in service in September 2012, and the Stateline II plant was placed in service in April 2013; and |

|         |                                                                                                                                                                              |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $360 million to construct the Garden Creek plant, a 100-MMcf/d natural gas processing facility in the Bakken Shale and Three Forks formations in the Williston |

----

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

|         |                                                                                                                                                                                                                                                                                                                                      |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $325 million to $360 million to construct the Garden Creek III plant, a 100-MMcf/d natural gas processing facility in the Williston Basin in North Dakota, which is expected to be completed in the fourth quarter 2014; and expansions and upgrades to existing natural gas gathering and compression infrastructure; |

|         |                                                                                                                                                                                                                                                                                                                                    |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $550 million to $680 million to construct the Lonesome Creek plant, a 200-MMcf/d natural gas processing facility in the Williston Basin in North Dakota, which is expected to be completed in the fourth quarter 2015; and expansions and upgrades to existing natural gas gathering and compression infrastructure; |

|         |                                                                                                                                                   |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $50 million to upgrade the Sage Creek natural gas processing plant and construct natural gas gathering infrastructure through 2015; |

|         |                                                                                                                                                                                                                                                                                                                         |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $515 million to $670 million to construct the Demicks Lake plant, a 200-MMcf/d natural gas processing facility in the Williston Basin in North Dakota, which is expected to be completed in the third quarter 2016; and expansions and upgrades to the existing gathering and compression infrastructure; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                               |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $80 million to $100 million to construct additional natural gas compression to take advantage of additional natural gas processing capacity as a result of better than expected plant performance at the  partnership’s  existing and planned Garden Creek and Stateline natural gas processing plants in the Williston Basin by a total of 100 MMcf/d, which is expected to be completed in the fourth quarter 2015; and |

|         |                                                                                                                                                                                                                                                                                                          |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $365 million to $470 million to construct the Knox plant, a 200-MMcf/d natural gas processing facility in Oklahoma’s SCOOP play, which is expected to be completed in the fourth quarter 2016; and expansions and upgrades to the existing gathering and compression infrastructure. |

----

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                    |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $767 million to construct a 550-plus-mile, 16-inch diameter NGL pipeline – the Sterling III Pipeline – which was completed in March 2014, 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 260,000 bpd; and the reconfiguration of its existing Sterling I and II NGL distribution pipelines to transport either unfractionated NGLs or NGL purity products, which was completed in July 2014; |

|         |                                                                                                                                                                                                          |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $46 million to install a 40,000-bpd ethane/propane (E/P) splitter at its Mont Belvieu, Texas, NGL storage facility to split E/P mix into purity ethane, which was completed in March 2014; |

|         |                                                                                                                                                    |
|---------|----------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $375 million to construct a 75,000-bpd NGL fractionator, MB-2, at Mont Belvieu, Texas, which was placed in service in December 2013; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                      |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $455 million to construct the 600-mile, 12-inch diameter 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, Kansas. The Bakken NGL Pipeline was placed in service in April 2013, with a 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; from its 80 percent-owned, 160,000-bpd MB-1 NGL fractionator; from its two wholly owned, 75,000-bpd NGL fractionators - MB-2, which was placed in service in December 2013, and MB-3, which currently is being constructed; and from its recently completed E/P splitter.  The ethane header pipeline was placed in service in April 2013; |

|         |                                                                                                                                                                                                                                                                                 |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $36 million to expand by 60,000 bpd the capacity of the partnership’s 50 percent-owned Overland Pass Pipeline, which was placed in service in the second quarter 2013, to transport the additional unfractionated NGL volumes from the Bakken NGL Pipeline; |

|         |                                                                                                                                                                                                                                                 |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $117 million to expand by 60,000 bpd the partnership’s NGL fractionation capacity at Bushton, Kansas, which was placed in service in September 2012, to accommodate NGL volumes from the Mid-Continent and Williston Basin; |

|         |                                                                                                                                                                                                                                                 |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | 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 |

----

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

|         |                                                                                                                                                                                                                                         |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | 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, which is expected to be completed in the third quarter 2014; |

|         |                                                                                                                                                                                                                                                                  |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $100 million, announced in November 2013, for a second expansion of the Bakken NGL Pipeline, which will increase the pipeline’s capacity to 160,000 bpd from 135,000.  The expansion is expected to be completed in the second quarter 2016; |

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

|         |                                                                                                                                                                                                                                                        |
|---------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $85 million to construct new NGL pipeline infrastructure and connect the Sage Creek natural gas processing plant to the partnership’s Bakken NGL Pipeline; these projects are expected to be completed in the fourth quarter 2015; |

|         |                                                                                                                                                                                                                                                                                                                                                                                                                                     |
|---------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $140 million to construct an approximately 95-mile NGL pipeline between existing NGL fractionation infrastructure at Hutchinson, Kansas, and Medford, Oklahoma, and the modification of the partnership’s NGL fractionation infrastructure at Hutchinson, Kansas, to accommodate unfractionated NGLs produced in the Williston Basin; both projects are expected to be completed in the first quarter 2015; and |

|         |                                                                                                                                                                                                                                                                             |
|---------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Approximately $10 million to $15 million to construct an approximately 12-mile NGL gathering pipeline connecting the Demicks Lake natural gas processing plant to the partnership’s Bakken NGL Pipeline, which is expected to be completed in the third quarter 2016. |

----

|         |                                                                                                                                                                              |
|---------|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| • | Adjusted 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 adjusted 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; |

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

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

----

----

|         |                                                                                                                                             |
|---------|---------------------------------------------------------------------------------------------------------------------------------------------|
| • | 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, NGLs 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 any 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 |   | Six Months Ended |
|                                                                                                  | June 30, |   | June 30, |
| (Unaudited)                                                                                           | 2014 |   | 2013 |   | 2014 |   | 2013 |
|                                                                                                  | (Thousands of dollars, except per unit amounts) |
| Revenues                                                                                              |   |   |   |   |   |   |   |
| Commodity sales                                                                                       | $ | 2,715,109 |  |   | $ | 2,447,411 |  |   | $ | 5,521,838 |  |   | $ | 4,646,205 |  |
| Services                                                                                              | 350,626 |  |   | 320,768 |  |   | 706,200 |  |   | 639,421 |  |
| Total revenues                                                                                        | 3,065,735 |  |   | 2,768,179 |  |   | 6,228,038 |  |   | 5,285,626 |  |
| Cost of sales and fuel                                                                                | 2,571,402 |  |   | 2,356,226 |  |   | 5,224,071 |  |   | 4,503,074 |  |
| Net margin                                                                                            | 494,333 |  |   | 411,953 |  |   | 1,003,967 |  |   | 782,552 |  |
| Operating expenses                                                                                    |   |   |   |   |   |   |   |
| Operations and maintenance                                                                            | 142,664 |  |   | 108,086 |  |   | 273,182 |  |   | 229,375 |  |
| Depreciation and amortization                                                                         | 71,447 |  |   | 58,226 |  |   | 138,182 |  |   | 112,904 |  |
| General taxes                                                                                         | 17,981 |  |   | 15,890 |  |   | 37,646 |  |   | 32,865 |  |
| Total operating expenses                                                                              | 232,092 |  |   | 182,202 |  |   | 449,010 |  |   | 375,144 |  |
| Gain (loss) on sale of assets                                                                         | (16 | ) |   | 279 |  |   | (1 | ) |   | 320 |  |
| Operating income                                                                                      | 262,225 |  |   | 230,030 |  |   | 554,956 |  |   | 407,728 |  |
| Equity earnings from investments                                                                      | 25,435 |  |   | 26,421 |  |   | 59,094 |  |   | 52,276 |  |
| Allowance for equity funds used during construction                                                   | 1,253 |  |   | 5,656 |  |   | 12,224 |  |   | 14,743 |  |
| Other income                                                                                          | 3,189 |  |   | 771 |  |   | 4,522 |  |   | 4,476 |  |
| Other expense                                                                                         | (1,389 | ) |   | (377 | ) |   | (2,158 | ) |   | (1,858 | ) |
| Interest expense (net of capitalized interest of $11,375, $11,359, $27,143 and $23,964, respectively) | (73,008 | ) |   | (57,524 | ) |   | (141,284 | ) |   | (113,396 | ) |
| Income before income taxes                                                                            | 217,705 |  |   | 204,977 |  |   | 487,354 |  |   | 363,969 |  |
| Income taxes                                                                                          | (3,194 | ) |   | (2,523 | ) |   | (7,375 | ) |   | (4,830 | ) |
| Net income                                                                                            | 214,511 |  |   | 202,454 |  |   | 479,979 |  |   | 359,139 |  |
| Less:  Net income attributable to noncontrolling interests                                            | 77 |  |   | 87 |  |   | 153 |  |   | 173 |  |
| Net income attributable to ONEOK Partners, L.P.                                                       | $ | 214,434 |  |   | $ | 202,367 |  |   | $ | 479,826 |  |   | $ | 358,966 |  |
|                                                                                                  |   |   |   |   |   |   |   |
| Limited partners’ interest in net income:                                                       |   |   |   |   |   |   |   |
| Net income attributable to ONEOK Partners, L.P.                                                       | $ | 214,434 |  |   | $ | 202,367 |  |   | $ | 479,826 |  |   | $ | 358,966 |  |
| General partner’s interest in net income                                                        | (84,669 | ) |   | (66,680 | ) |   | (161,901 | ) |   | (131,388 | ) |
| Limited partners’ interest in net income                                                        | $ | 129,765 |  |   | $ | 135,687 |  |   | $ | 317,925 |  |   | $ | 227,578 |  |
|                                                                                                  |   |   |   |   |   |   |   |
| Limited partners’ net income per unit, basic and diluted                                        | $ | 0.54 |  |   | $ | 0.62 |  |   | $ | 1.35 |  |   | $ | 1.03 |  |
|                                                                                                  |   |   |   |   |   |   |   |
| Number of units used in computation (thousands)                                                       | 240,503 |  |   | 220,116 |  |   | 236,361 |  |   | 219,988 |  |

----

|                                                                                                                             |
|-----------------------------------------------------------------------------------------------------------------------------|
|                                                                                                                             |  |  |  |  |  |  |  |  |
| ONEOK Partners, L.P. and Subsidiaries                                                                                       |   |   |   |   |
| CONSOLIDATED BALANCE SHEETS                                                                                                 |   |   |   |   |
|                                                                                                                        |   | June 30, |   | December 31, |
| (Unaudited)                                                                                                                 |   | 2014 |   | 2013 |
| Assets                                                                                                                      |   | (Thousands of dollars) |
| Current assets                                                                                                              |   |   |   |   |
| Cash and cash equivalents                                                                                                   |   | $ | 278,029 |  |   | $ | 134,530 |  |
| Accounts receivable, net                                                                                                    |   | 1,077,512 |  |   | 1,103,130 |  |
| Affiliate receivables                                                                                                       |   | 8,340 |  |   | 9,185 |  |
| Natural gas and natural gas liquids in storage                                                                              |   | 335,116 |  |   | 188,286 |  |
| Commodity imbalances                                                                                                        |   | 93,070 |  |   | 80,481 |  |
| Other current assets                                                                                                        |   | 92,339 |  |   | 67,491 |  |
| Total current assets                                                                                                        |   | 1,884,406 |  |   | 1,583,103 |  |
| Property, plant and equipment                                                                                               |   |   |   |   |
| Property, plant and equipment                                                                                               |   | 11,516,931 |  |   | 10,755,048 |  |
| Accumulated depreciation and amortization                                                                                   |   | 1,774,798 |  |   | 1,652,648 |  |
| Net property, plant and equipment                                                                                           |   | 9,742,133 |  |   | 9,102,400 |  |
| Investments and other assets                                                                                                |   |   |   |   |
| Investments in unconsolidated affiliates                                                                                    |   | 1,212,408 |  |   | 1,229,838 |  |
| Goodwill and intangible assets                                                                                              |   | 826,297 |  |   | 832,180 |  |
| Other assets                                                                                                                |   | 83,271 |  |   | 115,087 |  |
| Total investments and other assets                                                                                          |   | 2,121,976 |  |   | 2,177,105 |  |
| Total assets                                                                                                                |   | $ | 13,748,515 |  |   | $ | 12,862,608 |  |
| Liabilities and equity                                                                                                      |   |   |   |   |
| Current liabilities                                                                                                         |   |   |   |   |
| Current maturities of long-term debt                                                                                        |   | $ | 7,650 |  |   | $ | 7,650 |  |
| Notes payable                                                                                                               |   | — |  |   | — |  |
| Accounts payable                                                                                                            |   | 1,260,334 |  |   | 1,255,411 |  |
| Affiliate payables                                                                                                          |   | 39,780 |  |   | 47,458 |  |
| Commodity imbalances                                                                                                        |   | 207,456 |  |   | 213,577 |  |
| Accrued interest                                                                                                            |   | 92,214 |  |   | 92,711 |  |
| Other current liabilities                                                                                                   |   | 142,935 |  |   | 89,211 |  |
| Total current liabilities                                                                                                   |   | 1,750,369 |  |   | 1,706,018 |  |
| Long-term debt, excluding current maturities                                                                                |   | 6,041,618 |  |   | 6,044,867 |  |
| Deferred credits and other liabilities                                                                                      |   | 129,614 |  |   | 113,027 |  |
| Commitments and contingencies                                                                                               |   |   |   |   |
| Equity                                                                                                                      |   |   |   |   |
| ONEOK Partners, L.P. partners’ equity:                                                                                |   |   |   |   |
| General partner                                                                                                             |   | 200,757 |  |   | 170,561 |  |
| Common units: 175,910,629 and 159,007,854 units issued and outstanding atJune 30, 2014, and December 31, 2013, respectively |   | 4,318,705 |  |   | 3,459,920 |  |
| Class B units: 72,988,252 units issued and outstanding atJune 30, 2014, and December 31, 2013                               |   | 1,413,909 |  |   | 1,422,516 |  |
| Accumulated other comprehensive loss                                                                                        |   | (110,965 | ) |   | (58,837 | ) |
| Total ONEOK Partners, L.P. partners’ equity                                                                           |   | 5,822,406 |  |   | 4,994,160 |  |
| Noncontrolling interests in consolidated subsidiaries                                                                       |   | 4,508 |  |   | 4,536 |  |
| Total equity                                                                                                                |   | 5,826,914 |  |   | 4,998,696 |  |
| Total liabilities and equity                                                                                                |   | $ | 13,748,515 |  |   | $ | 12,862,608 |  |

----

|                                                                                   |
|-----------------------------------------------------------------------------------|
|                                                                                   |  |  |  |  |  |  |  |  |
| ONEOK Partners, L.P. and Subsidiaries                                             |   |   |   |   |
| CONSOLIDATED STATEMENTS OF CASH FLOWS                                             |   |   |   |   |
|                                                                              |   | Six Months Ended |
|                                                                              |   | June 30, |
| (Unaudited)                                                                       |   | 2014 |   | 2013 |
|                                                                              |   | (Thousands of dollars) |
| Operating activities                                                              |   |   |   |   |
| Net income                                                                        |   | $ | 479,979 |  |   | $ | 359,139 |  |
| Adjustments to reconcile net income to net cash provided by operating activities: |   |   |   |   |
| Depreciation and amortization                                                     |   | 138,182 |  |   | 112,904 |  |
| Allowance for equity funds used during construction                               |   | (12,224 | ) |   | (14,743 | ) |
| Loss (gain) on sale of assets                                                     |   | 1 |  |   | (320 | ) |
| Deferred income taxes                                                             |   | 3,402 |  |   | 3,022 |  |
| Equity earnings from investments                                                  |   | (59,094 | ) |   | (52,276 | ) |
| Distributions received from unconsolidated affiliates                             |   | 61,200 |  |   | 51,546 |  |
| Changes in assets and liabilities:                                                |   |   |   |   |
| Accounts receivable                                                               |   | 23,674 |  |   | 57,998 |  |
| Affiliate receivables                                                             |   | 845 |  |   | 2,953 |  |
| Natural gas and natural gas liquids in storage                                    |   | (146,830 | ) |   | (26,410 | ) |
| Accounts payable                                                                  |   | 68,045 |  |   | (23,484 | ) |
| Affiliate payables                                                                |   | (7,678 | ) |   | (35,988 | ) |
| Commodity imbalances, net                                                         |   | (18,710 | ) |   | (59,621 | ) |
| Accrued interest                                                                  |   | (497 | ) |   | (1,986 | ) |
| Other assets and liabilities, net                                                 |   | 3,783 |  |   | 10,727 |  |
| Cash provided by operating activities                                             |   | 534,078 |  |   | 383,461 |  |
| Investing activities                                                              |   |   |   |   |
| Capital expenditures (less allowance for equity funds used during construction)   |   | (792,414 | ) |   | (924,832 | ) |
| Acquisition                                                                       |   | (14,000 | ) |   | — |  |
| Contributions to unconsolidated affiliates                                        |   | (1,063 | ) |   | (4,558 | ) |
| Distributions received from unconsolidated affiliates                             |   | 16,449 |  |   | 17,958 |  |
| Proceeds from sale of assets                                                      |   | 319 |  |   | 324 |  |
| Cash used in investing activities                                                 |   | (790,709 | ) |   | (911,108 | ) |
| Financing activities                                                              |   |   |   |   |
| Cash distributions:                                                               |   |   |   |   |
| General and limited partners                                                      |   | (493,049 | ) |   | (444,352 | ) |
| Noncontrolling interests                                                          |   | (181 | ) |   | (294 | ) |
| Borrowing of notes payable, net                                                   |   | — |  |   | 429,000 |  |
| Repayment of long-term debt                                                       |   | (3,825 | ) |   | (3,825 | ) |
| Issuance of common units, net of issuance costs                                   |   | 878,765 |  |   | 15,942 |  |
| Contribution from general partner                                                 |   | 18,420 |  |   | 332 |  |
| Cash provided by (used in) financing activities                                   |   | 400,130 |  |   | (3,197 | ) |
| Change in cash and cash equivalents                                               |   | 143,499 |  |   | (530,844 | ) |
| Cash and cash equivalents at beginning of period                                  |   | 134,530 |  |   | 537,074 |  |
| Cash and cash equivalents at end of period                                        |   | $ | 278,029 |  |   | $ | 6,230 |  |

----

|                                                                                                  |
|--------------------------------------------------------------------------------------------------|
|                                                                                                  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| ONEOK Partners, L.P. and Subsidiaries                                                            |   |   |   |   |   |   |   |
| INFORMATION AT A GLANCE                                                                          |   |   |   |   |   |   |   |
|                                                                                             | Three Months Ended |   | Six Months Ended |
|                                                                                             | June 30, |   | June 30, |
| (Unaudited)                                                                                      | 2014 |   | 2013 |   | 2014 |   | 2013 |
|                                                                                             | (Millions of dollars, except as noted) |
| Natural Gas Gathering and Processing                                                             |   |   |   |   |   |   |   |
| Net margin                                                                                       | $ | 154.9 |  |   | $ | 125.3 |  |   | $ | 308.5 |  |   | $ | 234.6 |  |
| Operating costs                                                                                  | $ | 59.4 |  |   | $ | 45.0 |  |   | $ | 124.2 |  |   | $ | 96.7 |  |
| Depreciation and amortization                                                                    | $ | 29.4 |  |   | $ | 25.1 |  |   | $ | 58.3 |  |   | $ | 49.0 |  |
| Operating income                                                                                 | $ | 66.1 |  |   | $ | 55.5 |  |   | $ | 126.0 |  |   | $ | 89.2 |  |
| Equity earnings from investments                                                                 | $ | 5.1 |  |   | $ | 5.2 |  |   | $ | 10.6 |  |   | $ | 11.6 |  |
| Natural gas gathered (BBtu/d) (a)                                                                | 1,646 |  |   | 1,326 |  |   | 1,573 |  |   | 1,271 |  |
| Natural gas processed (BBtu/d) (a) (b)                                                           | 1,447 |  |   | 1,055 |  |   | 1,358 |  |   | 1,022 |  |
| NGL sales (MBbl/d) (a)                                                                           | 98 |  |   | 75 |  |   | 94 |  |   | 73 |  |
| Residue natural gas sales (BBtu/d) (a)                                                           | 683 |  |   | 467 |  |   | 626 |  |   | 451 |  |
| Realized composite NGL net sales price ($/gallon) (a) (c)                                        | $ | 0.96 |  |   | $ | 0.85 |  |   | $ | 1.00 |  |   | $ | 0.85 |  |
| Realized condensate net sales price ($/Bbl) (a) (c)                                         | $ | 77.46 |  |   | $ | 83.86 |  |   | $ | 76.80 |  |   | $ | 86.06 |  |
| Realized residue natural gas net sales price ($/MMBtu) (a) (c)                              | $ | 4.07 |  |   | $ | 3.57 |  |   | $ | 3.85 |  |   | $ | 3.55 |  |
| Average fee rate ($/MMBtu) (a)                                                                   | $ | 0.34 |  |   | $ | 0.34 |  |   | $ | 0.36 |  |   | $ | 0.35 |  |
| Capital expenditures - growth                                                                    | $ | 159.5 |  |   | $ | 200.9 |  |   | $ | 272.7 |  |   | $ | 359.9 |  |
| Capital expenditures - maintenance                                                               | $ | 8.7 |  |   | $ | 5.1 |  |   | $ | 18.4 |  |   | $ | 10.1 |  |
| (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 ONEOK Partners’ equity volumes. |   |   |   |   |
|                                                                                             |   |   |   |   |   |   |   |
| Natural Gas Liquids                                                                              |   |   |   |   |   |   |   |
| Net margin                                                                                       | $ | 266.1 |  |   | $ | 219.2 |  |   | $ | 535.1 |  |   | $ | 405.8 |  |
| Operating costs                                                                                  | $ | 76.1 |  |   | $ | 54.2 |  |   | $ | 141.2 |  |   | $ | 114.1 |  |
| Depreciation and amortization                                                                    | $ | 31.1 |  |   | $ | 22.3 |  |   | $ | 58.2 |  |   | $ | 42.0 |  |
| Operating income                                                                                 | $ | 159.0 |  |   | $ | 142.7 |  |   | $ | 335.7 |  |   | $ | 249.7 |  |
| Equity earnings from investments                                                                 | $ | 4.5 |  |   | $ | 5.9 |  |   | $ | 9.2 |  |   | $ | 9.0 |  |
| NGL sales (MBbl/d)                                                                               | 603 |  |   | 677 |  |   | 583 |  |   | 628 |  |
| NGLs transported-gathering lines (MBbl/d) (a)                                                    | 520 |  |   | 554 |  |   | 498 |  |   | 526 |  |
| NGLs fractionated (MBbl/d) (b)                                                                   | 520 |  |   | 537 |  |   | 496 |  |   | 525 |  |
| NGLs transported-distribution lines (MBbl/d) (a)                                                 | 431 |  |   | 432 |  |   | 430 |  |   | 413 |  |
| Average Conway-to-Mont Belvieu OPIS price differential -ethane in ethane/propane mix ($/gallon)  | $ | 0.03 |  |   | $ | 0.06 |  |   | $ | 0.08 |  |   | $ | 0.04 |  |
| Capital expenditures - growth                                                                    | $ | 196.9 |  |   | $ | 261.4 |  |   | $ | 457.8 |  |   | $ | 530.7 |  |
| Capital expenditures - maintenance                                                               | $ | 13.8 |  |   | $ | 7.9 |  |   | $ | 25.9 |  |   | $ | 12.8 |  |
| (a) - Includes volumes for consolidated entities only.                                           |   |   |   |   |   |   |
| (b) - Includes volumes at company-owned and third-party facilities.                              |   |   |   |   |   |   |   |
|                                                                                             |   |   |   |   |   |   |   |
| Natural Gas Pipelines                                                                            |   |   |   |   |   |   |   |
| Net margin                                                                                       | $ | 75.5 |  |   | $ | 67.7 |  |   | $ | 169.0 |  |   | $ | 141.8 |  |
| Operating costs                                                                                  | $ | 27.3 |  |   | $ | 25.0 |  |   | $ | 54.7 |  |   | $ | 52.1 |  |
| Depreciation and amortization                                                                    | $ | 10.9 |  |   | $ | 10.8 |  |   | $ | 21.7 |  |   | $ | 21.9 |  |
| Operating income                                                                                 | $ | 37.3 |  |   | $ | 31.9 |  |   | $ | 92.4 |  |   | $ | 67.8 |  |
| Equity earnings from investments                                                                 | $ | 15.9 |  |   | $ | 15.3 |  |   | $ | 39.3 |  |   | $ | 31.7 |  |
| Natural gas transportation capacity contracted (MDth/d) (a)                                      | 5,691 |  |   | 5,362 |  |   | 5,778 |  |   | 5,515 |  |
| Transportation capacity subscribed (a)                                                           | 90 | % |   | 88 | % |   | 91 | % |   | 90 | % |
| Average natural gas priceMid-Continent region ($/MMBtu) (a)                                      | $ | 4.36 |  |   | $ | 3.85 |  |   | $ | 4.98 |  |   | $ | 3.63 |  |
| Capital expenditures - growth                                                                    | $ | 2.2 |  |   | $ | 1.9 |  |   | $ | 4.4 |  |   | $ | 2.4 |  |
| Capital expenditures - maintenance                                                               | $ | 6.5 |  |   | $ | 4.1 |  |   | $ | 10.9 |  |   | $ | 8.9 |  |
| (a) - Includes volumes for consolidated entities only.                                           |   |   |   |   |   |   |   |

----

|                                                                             |
|-----------------------------------------------------------------------------|
|                                                                             |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| ONEOK Partners, L.P. and Subsidiaries                                       |   |   |   |   |   |   |   |   |
| RECONCILIATION OF NON-GAAP FINANCIAL MEASURES                               |   |   |   |   |   |   |
|                                                                        |   |   |   |   |   |   |   |   |
|                                                                        |   | Three Months Ended |   | Six Months Ended |
|                                                                        |   | June 30, |   | June 30, |
| (Unaudited)                                                                 |   | 2014 |   | 2013 |   | 2014 |   | 2013 |
|                                                                        | (Thousands of dollars, except per unit amounts) |
| Reconciliation of Net Income to Adjusted EBITDA and Distributable Cash Flow |   |   |   |   |
| Net income                                                                  |   | $ | 214,511 |  |   | $ | 202,454 |  |   | $ | 479,979 |  |   | $ | 359,139 |  |
| Interest expense                                                            |   | 73,008 |  |   | 57,524 |  |   | 141,284 |  |   | 113,396 |  |
| Depreciation and amortization                                               |   | 71,447 |  |   | 58,226 |  |   | 138,182 |  |   | 112,904 |  |
| Income taxes                                                                |   | 3,194 |  |   | 2,523 |  |   | 7,375 |  |   | 4,830 |  |
| Allowance for equity funds used during construction                         |   | (1,253 | ) |   | (5,656 | ) |   | (12,224 | ) |   | (14,743 | ) |
| Adjusted EBITDA                                                             |   | 360,907 |  |   | 315,071 |  |   | 754,596 |  |   | 575,526 |  |
| Interest expense                                                            |   | (73,008 | ) |   | (57,524 | ) |   | (141,284 | ) |   | (113,396 | ) |
| Maintenance capital                                                         |   | (30,710 | ) |   | (17,151 | ) |   | (57,562 | ) |   | (31,862 | ) |
| Equity earnings from investments                                            |   | (25,435 | ) |   | (26,421 | ) |   | (59,094 | ) |   | (52,276 | ) |
| Distributions received from unconsolidated affiliates                       |   | 42,579 |  |   | 39,311 |  |   | 77,649 |  |   | 69,504 |  |
| Other                                                                       |   | (2,334 | ) |   | (1,428 | ) |   | (4,154 | ) |   | (2,422 | ) |
| Distributable cash flow                                                     |   | $ | 271,999 |  |   | $ | 251,858 |  |   | $ | 570,151 |  |   | $ | 445,074 |  |
|                                                                        |   |   |   |   |   |   |   |   |
| Distributions to general partner                                            |   | (85,882 | ) |   | (67,145 | ) |   | (162,804 | ) |   | (133,190 | ) |
| Distributable cash flow to limited partners                                 |   | $ | 186,117 |  |   | $ | 184,713 |  |   | $ | 407,347 |  |   | $ | 311,884 |  |
|                                                                        |   |   |   |   |   |   |   |   |
| Distributions declared per limited partner unit                             |   | $ | 0.76 |  |   | $ | 0.72 |  |   | $ | 1.51 |  |   | $ | 1.44 |  |
| Coverage ratio                                                              |   | 1.02 |  |   | 1.17 |  |   | 1.14 |  |   | 0.99 |  |
|                                                                        |   |   |   |   |   |   |   |   |
| Number of units used in computation (thousands)                             |   | 240,503 |  |   | 220,116 |  |   | 236,361 |  |   | 219,988 |  |