The following table sets forth ONEOK Partners’ hedging information for the year ending December 31, 2008.
## Table 0 ##
(a) - Hedged with fixed-price swaps.
Year Ending December 31, 2008 Average Price Per Unit ONEOK Partners’ commodity price risk is estimated as a hypothetical change in the price of NGLs, crude oil and natural gas at December 31, 2007, excluding the effects of hedging and assuming normal operating conditions.
ONEOK Partners’ condensate sales are based on the price of crude oil.
ONEOK Partners estimates the following: ?
a $0.01 per gallon increase in the composite price of NGLs would increase annual net margin by approximately $1.7 million, ?
a $1.00 per barrel increase in the price of crude oil would increase annual net margin by approximately $0.5 million, and ?
a $0.10 per MMBtu increase in the price of natural gas would increase annual net margin by approximately $0.3 million.
The above estimates of commodity price risk do not include any effects on demand for its services that might be caused by, or arise in conjunction with, price changes.
For example, a change in the gross processing spread may cause ethane to be sold in the natural gas stream, impacting gathering and processing margins, NGL exchange margins, natural gas deliveries and NGL volumes shipped.
Distribution Our Distribution segment uses derivative instruments to hedge the cost of anticipated natural gas purchases during the winter heating months to protect their customers from upward volatility in the market price of natural gas.
Gains or losses associated with these derivative instruments are included in, and recoverable through, the monthly purchased gas cost mechanism.
Energy Services Our Energy Services segment is exposed to commodity price risk, including basis risk, arising from natural gas in storage and index-based purchases and sales of natural gas at various market locations.
We minimize the volatility of our exposure to commodity price risk through the use of derivative instruments, which, under certain circumstances, are designated as cash flow or fair value hedges.
We are also exposed to commodity price risk from fixed price purchases and sales of natural gas, which we hedge with derivative instruments.
Both the fixed price purchases and sales and related derivatives are recorded at fair value.
Fair Value Component of the Energy Marketing and Risk Management Assets and Liabilities - The following table sets forth the fair value component of the energy marketing and risk management assets and liabilities, excluding $3.5 million, net of derivative instruments that have been declared as either fair value or cash flow hedges, and $15.7 million, net of deferred option premiums.
## Table 1 ##
The net fair value of derivatives outstanding includes the effect of settled energy contracts and current period changes resulting primarily from newly originated transactions and the impact of market movements on the fair value of energy marketing and risk management assets and liabilities.
Fair value estimates consider the market in which the transactions are executed.
The market in which exchange traded and over-the-counter transactions are executed is a factor in determining fair
The table below shows the balance in accumulated other comprehensive income (loss) for the periods indicated.
## Table 2 ##
G.  CAPITAL STOCK Series A and B Convertible Preferred Stock - There are no shares of Series A or Series B currently outstanding.
Series C Preferred Stock - Series C Preferred Stock (Series C) is designed to protect our shareholders from coercive or unfair takeover tactics.
If issued, holders of shares of Series C are entitled to receive, in preference to the holders of ONEOK Common Stock, quarterly dividends in an amount per share equal to the greater of $0.50 or, subject to adjustment, 100 times the aggregate per share amount of all cash dividends, and 100 times the aggregate per share amount (payable in kind) of all non-cash dividends.
No shares of Series C have been issued.
Common Stock - At December 31, 2008, we had approximately 175 million shares of authorized and unreserved common stock available for issuance.
Stock Repurchase Plan - On May 17, 2007, our Board of Directors authorized a stock buy back program to repurchase up to 7.5 million shares of our currently issued and outstanding common stock.
On June 28, 2007, we repurchased 7.5 million shares of our outstanding common stock under an accelerated share repurchase agreement with Bank of America, N. A.
(Bank of America) at an initial price of $49.33 per share for a total of $370 million.
Bank of America borrowed 7.5 million of our shares from third parties and purchased shares in the open market to settle its short position.
Our repurchase was subject to a financial adjustment based on the volume-weighted average price, less a discount, of the shares subsequently repurchased by Bank of America over the course of the repurchase period.
The price adjustment could have been settled, at our option, in cash or in shares of our common stock.
In September 2007, the accelerated share repurchase agreement with Bank of America was settled, which resulted in Bank of America delivering an additional 186,402 shares of our common stock to us at no additional cost.
All shares under this accelerated repurchase agreement were recorded as treasury shares in our Consolidated Balance Sheets.
These transactions completed the plan approved by our Board of Directors and we have no remaining shares available for repurchase under our stock repurchase plan.
On August 7, 2006, under a previously authorized stock repurchase plan, we repurchased 7.5 million shares of our outstanding common stock under an accelerated share repurchase agreement with UBS Securities LLC (UBS) at an initial price of $37.52 per share for a total of $281.4 million.
These shares were recorded as treasury shares in our Consolidated Balance Sheets.
UBS borrowed 7.5 million of our shares from third parties and purchased shares in the open market to settle its short position.
Our repurchase was subject to a financial adjustment based on the volume-weighted average price, less a discount, of the shares subsequently repurchased by UBS over the course of the repurchase period.
The price adjustment could have been settled, at our option, in cash or in shares of our common stock.
In February 2007, the forward purchase contract with UBS was settled for a cash payment of $20.1 million, which was recorded in equity.
In accordance with EITF Issue No.99-7, “Accounting for an Accelerated Share Repurchase Program,” the repurchases were accounted for as two separate transactions: (i) as shares of common stock acquired in a treasury stock transaction recorded on the acquisition date; and (ii) as a forward contract indexed to our common stock.
Additionally, we classified the forward contracts as equity under EITF Issue No.00-19, “Accounting for Derivative Financial Instruments Indexed to, and Potentially Settled in, a Company’s Own Stock.
”
Selected Financial Results - The following table sets forth certain selected financial results for the continuing operations of our Distribution segment for the periods indicated:
## Table 3 ##
The following table sets forth our net margin, excluding other revenues, by type of customer, for the periods indicated:
## Table 4 ##
2012 vs.  2011 - Net margin increased due primarily to the following: .
an increase of $15.4 million from new rates in all three states; offset partially by .
a decrease of $8.5 million due to expiration of the Integrity Management Program (IMP) rider, which allowed Oklahoma Natural Gas to recover certain deferred pipeline-integrity costs in Oklahoma.
This decrease is offset by lower regulatory amortization in depreciation and amortization expense; and .
a decrease of $2.2 million from lower transportation volumes due to weather-sensitive customers in Kansas and Oklahoma.
Operating costs decreased due primarily to the following: .
a decrease of $16.7 million in share-based compensation costs from common stock awarded in the prior year to employees as part of ONEOK’s stock award program and the appreciation in ONEOK’s share price during 2011; .
a decrease of $8.9 million in employee-related incentive and health benefit costs due to reduced short-term incentives and medical claims expenses; offset partially by .
an increase of $5.4 million in pension costs as a result of the annual change in our estimated discount rate; .
an increase of $4.8 million due primarily to expenses associated with outside services and pipeline maintenance; and .
an increase of $4.0 million in litigation expense.
Depreciation and amortization expense decreased due primarily to a decrease of $8.5 million in regulatory amortization associated with the expiration of the IMP rider, offset partially by an increase of $6.1 million associated with additional capital expenditures.
2016, as well as significant sponsorship and other marketing agreements entered into during the period after December 31, 2016 through the date of this report:

<table><tr><td></td><td colspan="4"> Year Ending December 31, 2008</td></tr><tr><td></td><td> Volumes Hedged</td><td colspan="2">Average Price Per Unit</td><td>Volumes Hedged</td></tr><tr><td>Natural gas liquids<i>(Bbl/d)</i>(a)</td><td>8,085</td><td>$ 1.28</td><td>($/gallon)</td><td>70%</td></tr><tr><td>Condensate<i>(Bbl/d)</i>(a)</td><td>818</td><td>$ 2.15</td><td>($/gallon)</td><td>74%</td></tr><tr><td>Total liquid sales<i>(Bbl/d)</i></td><td>8,903</td><td>$ 1.36</td><td>($/gallon)</td><td>71%</td></tr><tr><td>(a) - Hedged with fixed-price swaps.</td><td></td><td></td><td></td><td></td></tr></table>
<table><tr><td></td><td>(Thousands of dollars)</td></tr><tr><td>Net fair value of derivatives outstanding at December 31, 2006</td><td>$-13,133</td></tr><tr><td>Derivatives realized or otherwise settled during the period</td><td>27,251</td></tr><tr><td>Fair value of new derivatives entered into during the period</td><td>8,287</td></tr><tr><td>Other changes in fair value</td><td>2,766</td></tr><tr><td>Net fair value of derivatives outstanding at December 31, 2007</td><td>$25,171</td></tr></table>
<table><tr><td></td><td>Unrealized Gains (Losses) on Energy Marketing and Risk Management Assets/Liabilities (Thousands of dollars)</td><td>UnrealizedHoldingGains (Losses) onInvestmentSecurities</td><td>Pension and Postretirement Benefit Plan Obligations</td><td>Accumulated Other Comprehensive Income (Loss)</td></tr><tr><td>December 31, 2006</td><td>$89,971</td><td>$12,614</td><td>$-63,053</td><td>$39,532</td></tr><tr><td>Other comprehensive income (loss)</td><td>-64,643</td><td>1,064</td><td>16,978</td><td>-46,601</td></tr><tr><td>December 31, 2007</td><td>$25,328</td><td>$13,678</td><td>$-46,075</td><td>$-7,069</td></tr><tr><td>Other comprehensive income (loss)</td><td>2,585</td><td>-12,864</td><td>-53,268</td><td>-63,547</td></tr><tr><td>December 31, 2008</td><td>$27,913</td><td>$814</td><td>$-99,343</td><td>$-70,616</td></tr></table>
<table><tr><td></td><td colspan="3">Years Ended December 31,</td><td colspan="2">Variances 2012 vs. 2011</td><td colspan="2">Variances 2011 vs. 2010</td></tr><tr><td>Financial Results</td><td>2012</td><td>2011</td><td>2010</td><td colspan="2">Increase (Decrease)</td><td colspan="2">Increase (Decrease)</td></tr><tr><td></td><td colspan="7">(Millions of dollars)</td></tr><tr><td>Gas sales</td><td>$1,252.0</td><td>$1,492.5</td><td>$1,687.4</td><td>$-240.5</td><td>-16%</td><td>$-194.9</td><td>-12%</td></tr><tr><td>Transportation revenues</td><td>88.8</td><td>90.9</td><td>91.5</td><td>-2.1</td><td>-2%</td><td>-0.6</td><td>-1%</td></tr><tr><td>Cost of gas</td><td>620.2</td><td>869.5</td><td>1,062.5</td><td>-249.3</td><td>-29%</td><td>-193.0</td><td>-18%</td></tr><tr><td>Net margin, excluding other revenues</td><td>720.6</td><td>713.9</td><td>716.4</td><td>6.7</td><td>1%</td><td>-2.5</td><td>—%</td></tr><tr><td>Other revenues</td><td>35.8</td><td>37.9</td><td>38.5</td><td>-2.1</td><td>-6%</td><td>-0.6</td><td>-2%</td></tr><tr><td>Net margin</td><td>756.4</td><td>751.8</td><td>754.9</td><td>4.6</td><td>1%</td><td>-3.1</td><td>—%</td></tr><tr><td>Operating costs</td><td>410.6</td><td>422.0</td><td>398.8</td><td>-11.4</td><td>-3%</td><td>23.2</td><td>6%</td></tr><tr><td>Depreciation and amortization</td><td>130.1</td><td>132.2</td><td>131.0</td><td>-2.1</td><td>-2%</td><td>1.2</td><td>1%</td></tr><tr><td>Operating income</td><td>$215.7</td><td>$197.6</td><td>$225.1</td><td>$18.1</td><td>9%</td><td>$-27.5</td><td>-12%</td></tr><tr><td>Capital expenditures</td><td>$280.3</td><td>$242.6</td><td>$215.6</td><td>$37.7</td><td>16%</td><td>$27.0</td><td>13%</td></tr></table>
<table><tr><td></td><td colspan="3">Years Ended December 31</td><td colspan="2">Variances 2012 vs. 2011</td><td colspan="2">Variances 2011 vs. 2010</td></tr><tr><td>Net Margin, Excluding Other Revenues</td><td>2012</td><td>2011</td><td>2010</td><td colspan="2">Increase (Decrease)</td><td colspan="2">Increase (Decrease)</td></tr><tr><td>Gas sales</td><td colspan="7">(Millions of dollars)</td></tr><tr><td>Residential</td><td>$523.4</td><td>$510.5</td><td>$509.1</td><td>$12.9</td><td>3%</td><td>$1.4</td><td>—%</td></tr><tr><td>Commercial</td><td>101.6</td><td>105.5</td><td>108.9</td><td>-3.9</td><td>-4%</td><td>-3.4</td><td>-3%</td></tr><tr><td>Industrial</td><td>2.2</td><td>2.4</td><td>2.2</td><td>-0.2</td><td>-8%</td><td>0.2</td><td>9%</td></tr><tr><td>Wholesale/public authority</td><td>4.6</td><td>4.6</td><td>4.7</td><td>—</td><td>—%</td><td>-0.1</td><td>-2%</td></tr><tr><td>Net margin on gas sales</td><td>631.8</td><td>623.0</td><td>624.9</td><td>8.8</td><td>1%</td><td>-1.9</td><td>—%</td></tr><tr><td>Transportation margin</td><td>88.8</td><td>90.9</td><td>91.5</td><td>-2.1</td><td>-2%</td><td>-0.6</td><td>-1%</td></tr><tr><td>Net margin, excluding other revenues</td><td>$720.6</td><td>$713.9</td><td>$716.4</td><td>$6.7</td><td>1%</td><td>$-2.5</td><td>—%</td></tr></table>

Question: What is the growing rate of Industrial in the years with the least Commercial? (in %)
Answer: -0.08333