Supplementary Information on Oil and Gas Producing Activities (Unaudited) 108 Results of Operations for Oil and Gas Producing Activities
## Table 0 ##
(a) Includes net gain (loss) on dispositions.
(b) Includes long-lived asset impairments.
(c) 2011 Canada production costs include $64 million accrued for Oil Sands water abatement.
## Table 1 ##
(a) Includes the following: ?2,273,594 stock options outstanding under the 2012 Plan; ?13,203,379 stock options outstanding under the 2007 Plan; ?2,465,332 stock options outstanding under the 2003 Plan and the net number of stock-settled SARs that could be issued from this Plan.
The number of stock-settled SARs is based on the closing price of Marathon Oil common stock on December 31, 2013 of $35.30 per share; ?324,672 common stock units that have been credited to non-employee directors pursuant to the non-employee director deferred compensation program and the annual director stock award program established under the 2012 Plan, 2007 Plan and 2003 Plan; common stock units credited under the 2012 Plan, 2007 Plan and 2003 Plan were 51,196, 222,215 and 51,261, respectively; ?977,853 restricted stock units granted to non-officers under the 2012 Plan and 2007 Plan and outstanding as of December 31, 2013.
In addition to the awards reported above 2,014,310 and 1,094,122 shares of restricted stock were issued and outstanding as of December 31, 2013, but subject to forfeiture restrictions under the 2012 Plan and 2007 Plan, respectively.
(b) Reflects awards of common stock units made to non-employee directors under the Deferred Compensation Plan for Non-Employee Directors prior to April 30, 2003.
When a non-employee director leaves the Board, he or she will be issued actual shares of Marathon Oil common stock in place of the common stock units.
(c) The weighted-average exercise prices do not take the restricted stock units or common stock units into account as these awards have no exercise price.
(d) Reflects the shares available for issuance under the 2012 Plan.
No more than 18,810,490 of these shares may be issued for awards other than stock options or stock appreciation rights.
In addition, shares related to grants that are forfeited, terminated, canceled or expire unexercised shall again immediately become available for issuance.
The Deferred Compensation Plan for Non-Employee Directors is our only equity compensation plan that has not been approved by our stockholders.
Our authority to make equity grants under this plan was terminated effective April 30, 2003.
Under the Deferred Compensation Plan for Non-Employee Directors, all non-employee directors were required to defer half of their annual retainers in the form of common stock units.
On the date the retainer would have otherwise been payable to the non-employee director, we credited an unfunded bookkeeping account for each non-employee director with a number of common stock units equal to half of his or her annual retainer divided by the fair market value of our common stock on that date.
The ongoing value of each common stock unit equals the market price of a share of our common stock.
When the non-employee director leaves the Board, he or she is issued actual shares of our common stock equal to the number of common stock units in his or her account at that time.
Item 13.
Certain Relationships and Related Transactions, and Director Independence Information required by this item is incorporated by reference to the material appearing under the heading "Certain Relationships and Related Person Transactions," and under the sub-heading "Board and Committee Independence" under the heading "The Board of Directors and Governance Matters" in our Proxy Statement for the 2014 Annual Meeting of Stockholders.
Item 14.
Principal Accounting Fees and Services Information required by this item is incorporated by reference to the material appearing under the heading "Information Regarding the Independent Registered Public Accounting Firm’s Fees, Services and Independence" in our Proxy Statement for the 2014 Annual Meeting of Stockholders.
Item 7.
Management’s Discussion and Analysis of Financial Condition and Results of Operations Each of our segments is organized and managed based upon both geographic location and the nature of the products and services it offers: ?
North America E&P – explores for, produces and markets liquid hydrocarbons and natural gas in North America; ?
International E&P – explores for, produces and markets liquid hydrocarbons and natural gas outside of North America and produces and markets products manufactured from natural gas, such as LNG and methanol, in E. G. ; and ?
Oil Sands Mining – mines, extracts and transports bitumen from oil sands deposits in Alberta, Canada, and upgrades the bitumen to produce and market synthetic crude oil and vacuum gas oil.
Certain sections of Management’s Discussion and Analysis of Financial Condition and Results of Operations include forwardlooking statements concerning trends or events potentially affecting our business.
These statements typically contain words such as "anticipates," "believes," "estimates," "expects," "targets," "plans," "projects," "could," "may," "should," "would" or similar words indicating that future outcomes are uncertain.
In accordance with "safe harbor" provisions of the Private Securities Litigation Reform Act of 1995, these statements are accompanied by cautionary language identifying important factors, though not necessarily all such factors, which could cause future outcomes to differ materially from those set forth in the forward-looking statements.
For additional risk factors affecting our business, see Item 1A.
Risk Factors in this Annual Report on Form 10-K.  Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the information under Item 1.  Business, Item 1A.
Risk Factors and Item 8.
Financial Statements and Supplementary Data found in this Annual Report on Form 10-K.  Spin-off Downstream Business On June 30, 2011, the spin-off of Marathon’s downstream business was completed, creating two independent energy companies: Marathon Oil and MPC.
Marathon stockholders at the close of business on the record date of June 27, 2011 received one share of MPC common stock for every two shares of Marathon common stock held.
A private letter tax ruling received in June 2011 from the IRS affirmed the tax-free nature of the spin-off.
Activities related to the downstream business have been treated as discontinued operations for all periods prior to the spin-off (see Item 8.
Financial Statements and Supplementary Data – Note 3 to the consolidated financial statements for additional information).
Overview – Market Conditions Prevailing prices for the various qualities of crude oil and natural gas that we produce significantly impact our revenues and cash flows.
The following table lists benchmark crude oil and natural gas price averages relative to our North America E&P and International E&P segments for the past three years.
## Table 2 ##
North America E&P Liquid hydrocarbons – The quality, location and composition of our liquid hydrocarbon production mix can cause our North America E&P price realizations to differ from the WTI benchmark.
Quality – Light sweet crude contains less sulfur and tends to be lighter than sour crude oil so that refining it is less costly and has historically produced higher value products; therefore, light sweet crude is considered of higher quality and has historically sold at a price that approximates WTI or at a premium to WTI.
The percentage of our North America E&P crude oil and condensate production that is light sweet crude has been increasing as onshore production from the Eagle Ford and Bakken increases and production from the Gulf of Mexico declines.
In 2013, the percentage of our U. S.  crude oil and condensate production that was sweet averaged 76 percent compared to 63 percent and 42 percent in 2012 and 2011.
Location – In recent years, crude oil sold along the U. S.  Gulf Coast, such as that from the Eagle Ford, has been priced based on the Louisiana Light Sweet ("LLS") benchmark which has historically priced at a premium to WTI and has historically tracked closely to Brent, while production from inland areas farther from large refineries has been priced lower.
The average annual WTI
The following table gives details of net sales volumes and average price realizations of our International E&P segment:
## Table 3 ##
(a) Corresponds with the basis for fiscal settlements with governments, representing equity tanker liftings and direct deliveries of liquid hydrocarbons.
(b) Includes natural gas acquired for injection and subsequent resale of 15 mmcfd and 16 mmcfd for 2012 and 2011.
(c) Primarily represents fixed prices under long-term contracts with Alba Plant LLC, AMPCO, and EGHoldings, equity method investees.
We include our share of Alba Plant LLC's, AMPCO's and EGHoldings' income in our International E&P segment.
Oil Sands Mining sales and other operating revenues decreased $14 million in 2012 from 2011.
This decrease was primarily the result of lower average price realizations which were partially offset by higher net sales volumes.
The following table gives details of net sales volumes and average price realizations of our Oil Sands Mining segment:

<table><tr><td colspan="2">(In millions)</td><td>U.S.</td><td>Canada</td><td>E.G.</td><td>OtherAfrica</td><td>Europe</td><td>OtherInt’l</td><td>Total</td></tr><tr><td>2013</td><td>Revenues and other income:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td></td><td>Sales</td><td>$5,059</td><td>$1,376</td><td>$33</td><td>$1,106</td><td>$924</td><td>$—</td><td>$8,498</td></tr><tr><td></td><td>Transfers</td><td>3</td><td>—</td><td>715</td><td>—</td><td>2,941</td><td>—</td><td>3,659</td></tr><tr><td></td><td>Other income<sup>(a)</sup></td><td>-9</td><td>—</td><td>—</td><td>—</td><td>—</td><td>-8</td><td>-17</td></tr><tr><td></td><td>Total revenues and other income</td><td>5,053</td><td>1,376</td><td>748</td><td>1,106</td><td>3,865</td><td>-8</td><td>12,140</td></tr><tr><td></td><td>Expenses:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td></td><td>Production costs</td><td>-1,318</td><td>-867</td><td>-113</td><td>-73</td><td>-498</td><td>—</td><td>-2,869</td></tr><tr><td></td><td>Exploration expenses</td><td>-717</td><td>-8</td><td>-3</td><td>-65</td><td>-123</td><td>-72</td><td>-988</td></tr><tr><td></td><td>Depreciation, depletion and amortization<sup>(b)</sup></td><td>-1,980</td><td>-218</td><td>-97</td><td>-28</td><td>-440</td><td>—</td><td>-2,763</td></tr><tr><td></td><td>Administrative expenses</td><td>-185</td><td>-21</td><td>-30</td><td>-19</td><td>-36</td><td>-14</td><td>-305</td></tr><tr><td></td><td>Total expenses</td><td>-4,200</td><td>-1,114</td><td>-243</td><td>-185</td><td>-1,097</td><td>-86</td><td>-6,925</td></tr><tr><td></td><td>Results before income taxes</td><td>853</td><td>262</td><td>505</td><td>921</td><td>2,768</td><td>-94</td><td>5,215</td></tr><tr><td></td><td>Income tax (provision) benefit</td><td>-323</td><td>-66</td><td>-182</td><td>-920</td><td>-2,004</td><td>26</td><td>-3,469</td></tr><tr><td></td><td>Results of continuing operations</td><td>$530</td><td>$196</td><td>$323</td><td>$1</td><td>$764</td><td>$-68</td><td>$1,746</td></tr><tr><td></td><td>Results of discontinued operations</td><td>$—</td><td>$—</td><td>$—</td><td>$160</td><td>$—</td><td>$—</td><td>$160</td></tr><tr><td>2012</td><td>Revenues and other income:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td></td><td>Sales</td><td>$3,879</td><td>$1,261</td><td>$29</td><td>$2,000</td><td>$835</td><td>$—</td><td>$8,004</td></tr><tr><td></td><td>Transfers</td><td>2</td><td>—</td><td>818</td><td>—</td><td>3,601</td><td>—</td><td>4,421</td></tr><tr><td></td><td>Other income<sup>(a)</sup></td><td>-8</td><td>—</td><td>—</td><td>—</td><td>—</td><td>-32</td><td>-40</td></tr><tr><td></td><td>Total revenues and other income</td><td>3,873</td><td>1,261</td><td>847</td><td>2,000</td><td>4,436</td><td>-32</td><td>12,385</td></tr><tr><td></td><td>Expenses:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td></td><td>Production costs</td><td>-1,054</td><td>-826</td><td>-141</td><td>-58</td><td>-398</td><td>—</td><td>-2,477</td></tr><tr><td></td><td>Exploration expenses</td><td>-558</td><td>-30</td><td>-5</td><td>-10</td><td>-34</td><td>-69</td><td>-706</td></tr><tr><td></td><td>Depreciation, depletion and amortization<sup>(b)</sup></td><td>-1,792</td><td>-217</td><td>-95</td><td>-43</td><td>-615</td><td>—</td><td>-2,762</td></tr><tr><td></td><td>Administrative expenses</td><td>-193</td><td>-8</td><td>-5</td><td>-4</td><td>-40</td><td>-12</td><td>-262</td></tr><tr><td></td><td>Total expenses</td><td>-3,597</td><td>-1,081</td><td>-246</td><td>-115</td><td>-1,087</td><td>-81</td><td>-6,207</td></tr><tr><td></td><td>Results before income taxes</td><td>276</td><td>180</td><td>601</td><td>1,885</td><td>3,349</td><td>-113</td><td>6,178</td></tr><tr><td></td><td>Income tax (provision) benefit</td><td>-100</td><td>-45</td><td>-210</td><td>-1,795</td><td>-2,486</td><td>51</td><td>-4,585</td></tr><tr><td></td><td>Results of continuing operations</td><td>$176</td><td>$135</td><td>$391</td><td>$90</td><td>$863</td><td>$-62</td><td>$1,593</td></tr><tr><td></td><td>Results of discontinued operations</td><td>$—</td><td>$—</td><td>$—</td><td>$-31</td><td>$—</td><td>$—</td><td>$-31</td></tr><tr><td>2011</td><td>Revenues and other income:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td></td><td>Sales</td><td>$3,058</td><td>$1,332</td><td>$29</td><td>$216</td><td>$1,000</td><td>$—</td><td>$5,635</td></tr><tr><td></td><td>Transfers</td><td>63</td><td>—</td><td>905</td><td>—</td><td>3,546</td><td>—</td><td>4,514</td></tr><tr><td></td><td>Other income<sup>(a)</sup></td><td>41</td><td>—</td><td>—</td><td>—</td><td>15</td><td>—</td><td>56</td></tr><tr><td></td><td>Total revenues and other income</td><td>3,162</td><td>1,332</td><td>934</td><td>216</td><td>4,561</td><td>—</td><td>10,205</td></tr><tr><td></td><td>Expenses:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td></td><td>Production costs<sup>(c)</sup></td><td>-961</td><td>-818</td><td>-118</td><td>-24</td><td>-376</td><td>—</td><td>-2,297</td></tr><tr><td></td><td>Exploration expenses</td><td>-377</td><td>-11</td><td>-1</td><td>1</td><td>-86</td><td>-167</td><td>-641</td></tr><tr><td></td><td>Depreciation, depletion and amortization<sup>(b)</sup></td><td>-1,472</td><td>-196</td><td>-104</td><td>-9</td><td>-684</td><td>—</td><td>-2,465</td></tr><tr><td></td><td>Administrative expenses</td><td>-182</td><td>-10</td><td>—</td><td>-1</td><td>-18</td><td>-10</td><td>-221</td></tr><tr><td></td><td>Total expenses</td><td>-2,992</td><td>-1,035</td><td>-223</td><td>-33</td><td>-1,164</td><td>-177</td><td>-5,624</td></tr><tr><td></td><td>Results before income taxes</td><td>170</td><td>297</td><td>711</td><td>183</td><td>3,397</td><td>-177</td><td>4,581</td></tr><tr><td></td><td>Income tax (provision) benefit</td><td>-59</td><td>-75</td><td>-254</td><td>-176</td><td>-2,176</td><td>65</td><td>-2,675</td></tr><tr><td></td><td>Results of continuing operations</td><td>$111</td><td>$222</td><td>$457</td><td>$7</td><td>$1,221</td><td>$-112</td><td>$1,906</td></tr><tr><td></td><td>Results of discontinued operations</td><td>$—</td><td>$—</td><td>$—</td><td>$-11</td><td>$—</td><td>$—</td><td>$-11</td></tr></table>
<table><tr><td>Plan category</td><td>Number ofsecurities tobe issueduponexercise ofoutstandingoptions,warrantsand rights</td><td></td><td>Weighted-averageexerciseprice ofoutstandingoptions,warrantsand rights<sup>(c)</sup></td><td>Number ofsecuritiesremainingavailable forfutureissuanceunder equitycompensationplans</td><td></td></tr><tr><td>Equity compensation plans approved by stockholders</td><td>19,244,830</td><td><sup>(a)</sup></td><td>$27.27</td><td>45,950,524</td><td><sup>(d)</sup></td></tr><tr><td>Equity compensation plans not approved by stockholders</td><td>20,984</td><td><sup>(b)</sup></td><td>N/A</td><td>—</td><td></td></tr><tr><td>Total</td><td>19,265,814</td><td></td><td>N/A</td><td>45,950,524</td><td></td></tr></table>
<table><tr><td>Benchmark</td><td>2013</td><td>2012</td><td>2011</td></tr><tr><td>WTI crude oil(Dollars per bbl)</td><td>$98.05</td><td>$94.15</td><td>$95.11</td></tr><tr><td>Brent (Europe) crude oil(Dollars per bbl)</td><td>$108.64</td><td>$111.65</td><td>$111.26</td></tr><tr><td>Henry Hub natural gas(Dollars per mmbtu)<sup>(a)</sup></td><td>$3.65</td><td>$2.79</td><td>$4.04</td></tr></table>
<table><tr><td></td><td>2012</td><td>2011</td></tr><tr><td>International E&P Operating Statistics</td><td></td><td></td></tr><tr><td>Net liquid hydrocarbon salesvolumes(mbbld)<sup>(a)</sup></td><td></td><td></td></tr><tr><td>Europe</td><td>97</td><td>101</td></tr><tr><td>Africa</td><td>78</td><td>43</td></tr><tr><td>Total International E&P</td><td>175</td><td>144</td></tr><tr><td>Liquid hydrocarbon average price realizations(per bbl)</td><td></td><td></td></tr><tr><td>Europe</td><td>$115.16</td><td>$115.55</td></tr><tr><td>Africa</td><td>$98.52</td><td>$73.21</td></tr><tr><td>Total International E&P</td><td>$107.78</td><td>$102.96</td></tr><tr><td>Net natural gas sales volumes(mmcfd)</td><td></td><td></td></tr><tr><td>Europe<sup>(b)</sup></td><td>101</td><td>97</td></tr><tr><td>Africa</td><td>443</td><td>443</td></tr><tr><td>Total International E&P</td><td>544</td><td>540</td></tr><tr><td>Natural gas average price realizations(per mcf)</td><td></td><td></td></tr><tr><td>Europe</td><td>$10.47</td><td>$9.84</td></tr><tr><td>Africa<sup>(c)</sup></td><td>$0.43</td><td>$0.24</td></tr><tr><td>Total International E&P</td><td>$2.29</td><td>$1.97</td></tr></table>

Question: by what percentage did the average price of wti crude oil increase from 2011 to 2013?
Answer: 0.03091