MARATHON OIL CORPORATION Notes to Consolidated Financial Statements 9.
Income per Common Share Basic income per share is based on the weighted average number of common shares outstanding, including securities exchangeable into common shares.
Diluted income per share assumes exercise of stock options, stock appreciation rights and restricted stock, provided the effect is not antidilutive.
## Table 0 ##
The per share calculations above exclude 5.4 million and 3.2 million stock options and stock appreciation rights in 2008 and 2007 that were antidilutive.
There were no antidilutive stock options or stock appreciation rights in 2006.
Restricted stock was not antidilutive in 2008, 2007 or 2006.10.
Segment Information We have four reportable operating segments: Exploration and Production; Oil Sands Mining; Refining, Marketing and Transportation; and Integrated Gas.
Each of these segments is organized and managed based upon the nature of the products and services they offer.  ?
Exploration and Production (“E&P”) – explores for, produces and markets liquid hydrocarbons and natural gas on a worldwide basis; ?
Oil Sands Mining (“OSM”) – mines, extracts and transports bitumen from oil sands deposits in Alberta, Canada, and upgrades the bitumen to produce and market synthetic crude oil and by-products; ?
Refining, Marketing and Transportation (“RM&T”) – refines, markets and transports crude oil and petroleum products, primarily in the Midwest, upper Great Plains, Gulf Coast and southeastern regions of the U. S. ; and ?
Integrated Gas (“IG”) – markets and transports products manufactured from natural gas, such as LNG and methanol, on a worldwide basis, and is developing other projects to link stranded natural gas resources with key demand areas.
Information regarding assets by segment is not presented because it is not reviewed by the chief operating decision maker (“CODM”).
Segment income represents income from continuing operations, net of minority interests and income taxes, attributable to the operating segments.
Our corporate general and administrative costs are not allocated to the operating segments.
These costs primarily consist of employment costs (including pension effects), professional services, facilities and other costs associated with corporate activities, net of associated income tax effects.
All foreign currency remeasurement and transaction gains or losses are not allocated to operating segments.
Non-cash gains and losses on two natural gas sales contracts in the United Kingdom that are accounted for as derivative instruments, impairments or infrequently occurring items (as determined by the CODM) also are not allocated to operating segments.
refining and wholesale marketing gross margin decline was consistent with the market indicators (crack spreads) in the Midwest and Gulf Coast regions.
In addition, manufacturing expenses were higher in 2008 due primarily to higher energy costs and maintenance activities.
Included in the refining and wholesale marketing gross margins were pretax derivative losses of $87 million in 2008 and $899 million in 2007.
The variance primarily reflects falling crude futures prices in the second half of 2008, as well as the fact that we reduced our use of derivatives to manage domestic crude oil acquisition price risk.
For a more complete explanation of our strategies to manage market risk related to commodity prices, see Quantitative and Qualitative Disclosures about Market Risk.
We averaged 944 mbpd of crude oil throughput in 2008 and 1,010 mbpd in 2007.
Total refinery throughputs averaged 1,151 mbpd in 2008 compared to 1,224 mbpd in 2007.
Crude and total throughputs were lower in 2008 than in 2007 in part due to the impact hurricanes and other weather related events had on our operations in 2008.
The following table includes certain key operating statistics for the RM&T segment for 2008 and 2007.
## Table 1 ##
(a) Sales revenue less cost of refinery inputs, purchased products and manufacturing expenses, including depreciation.
Management’s Discussion and Analysis of Financial Condition, Cash Flows and Liquidity Cash Flows Net cash provided from operating activities totaled $5,268 million in 2009 compared to $6,752 million in 2008 and $5,900 million in 2007.
The $1,484 million decrease in 2009 reflects the impact of lower average realized prices in 2009.
The $852 million increase in 2008 primarily reflects the impact of higher average realized prices in 2008.
Net cash used in investing activities totaled $5,238 million in 2009, compared with $5,405 million in 2008 and $7,481 million in 2007.
Significant investing activities include additions to property, plant and equipment, asset disposals and an acquisition of a business in 2007.
The most significant additions to property, plant and equipment relate to our long-term projects, which cross several years.
In our E&P segment, exploration and development projects in Angola impacted all three years.
Development and completion of the Alvheim/Vilje project affected 2007 and 2008, with other developments in the area in 2009.
Beginning in 2008, spending on U. S.  exploration and development projects in the Gulf of Mexico and unconventional resource plays became a more significant portion of our additions to property, plant and equipment.
In the OSM segment, the AOSP Expansion 1 began in 2008 and continued through 2009.
In our RM&T segment, the expansion of our Garyville, Louisiana, refinery affected all years.
Also in RM&T, the expansion and upgrading of our Detroit, Michigan refinery commenced with front-end engineering and design work in 2007 and construction in 2008 and 2009.
We have revised prior year amounts of capital expenditures in the consolidated statement of cash flows.
The consolidated statements of cash flows excludes changes to the consolidated balance sheets that did not affect cash.
A reconciliation of this amount to the reported capital expenditures follows for all years presented:
## Table 2 ##
Acquisitions in 2007 consist of the $3,907 million cash portion of the Western acquisition purchase price, net of the $44 million of cash acquired.
See Note 6 to the consolidated financial statements for more information about the Western acquisition.
MARATHON OIL CORPORATIONNotes to Consolidated Financial Statements93Expected long-term return on plan assets – The expected long-term return on plan assets assumption for our U. S.  funded plan is determined based on an asset rate-of-return modeling tool developed by a third-party investment group which utilizes underlying assumptions based on actual returns by asset category and inflation and takes into account our U. S.  pension plan’s asset allocation.
To determine the expected long-term return on plan assets assumption for our international plans, we consider the current level of expected returns on risk-free investments (primarily government bonds), the historical levels of the risk premiums associated with the other applicable asset categories and the expectations for future returns of each asset class.
The expected return for each asset category is then weighted based on the actual asset allocation to develop the overall expected long-term return on plan assets assumption.
Assumed weighted average health care cost trend rates

<table><tr><td></td><td colspan="2">2008</td><td colspan="2">2007</td><td colspan="2">2006</td></tr><tr><td><i>(In millions except per share data)</i></td><td>Basic</td><td>Diluted</td><td>Basic</td><td>Diluted</td><td>Basic</td><td>Diluted</td></tr><tr><td>Income from continuing operations</td><td>$3,528</td><td>$3,528</td><td>$3,948</td><td>$3,948</td><td>$4,957</td><td>$4,957</td></tr><tr><td>Discontinued operations</td><td>–</td><td>–</td><td>8</td><td>8</td><td>277</td><td>277</td></tr><tr><td>Net income</td><td>$3,528</td><td>$3,528</td><td>$3,956</td><td>$3,956</td><td>$5,234</td><td>$5,234</td></tr><tr><td>Weighted average common shares outstanding</td><td>709</td><td>709</td><td>690</td><td>690</td><td>716</td><td>716</td></tr><tr><td>Effect of dilutive securities</td><td>–</td><td>4</td><td>–</td><td>5</td><td>–</td><td>6</td></tr><tr><td>Weighted average common shares, including dilutive effect</td><td>709</td><td>713</td><td>690</td><td>695</td><td>716</td><td>722</td></tr><tr><td>Per share:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Income from continuing operations</td><td>$4.97</td><td>$4.95</td><td>$5.72</td><td>$5.68</td><td>$6.92</td><td>$6.87</td></tr><tr><td>Discontinued operations</td><td>$–</td><td>$–</td><td>$0.01</td><td>$0.01</td><td>$0.39</td><td>$0.38</td></tr><tr><td>Net income</td><td>$4.97</td><td>$4.95</td><td>$5.73</td><td>$5.69</td><td>$7.31</td><td>$7.25</td></tr></table>
<table><tr><td> RM&T Operating Statistics</td><td>2008</td><td>2007</td></tr><tr><td>Refining and wholesale marketing gross margin<i>(Dollars per gallon)</i><sup>(a)</sup></td><td>$0.1166</td><td>$0.1848</td></tr><tr><td>Refined products sales volumes<i>(Thousands of barrels per day)</i></td><td>1,352</td><td>1,410</td></tr></table>
<table><tr><td><i>(in millions)</i></td><td>2009</td><td>2008</td><td>2007</td></tr><tr><td>Additions to property, plant and equipment</td><td>$6,231</td><td>$6,989</td><td>$3,757</td></tr><tr><td>Change in capital accruals</td><td>-343</td><td>30</td><td>621</td></tr><tr><td>Discontinued operations</td><td>84</td><td>127</td><td>88</td></tr><tr><td>Capital expenditures</td><td>$5,972</td><td>$7,146</td><td>$4,466</td></tr></table>

Question: What's the average of the Refined products sales volumes(Thousands of barrels per day) in the years where Discontinued operations is greater than 85?
Answer: 1381.0