The following unaudited pro forma data is as if the acquisition of Western had been consummated at the beginning of each period presented.
The pro forma data is based on historical information and does not reflect the actual results that would have occurred nor is it indicative of future results of operations.
## Table 0 ##
Minority interest in MPC – On June 30, 2005, Marathon acquired the 38 percent ownership interest in Marathon Ashland Petroleum LLC (“MAP”) previously held by Ashland.
In addition, Marathon acquired a portion of Ashland’s Valvoline Instant Oil Change business, its maleic anhydride business, its interest in LOOP LLC, which owns and operates the only U. S.  deepwater oil port, and its interest in LOCAP LLC, which owns a crude oil pipeline.
As a result of the transactions, MAP is wholly owned by Marathon and its name was changed to Marathon Petroleum Company LLC effective September 1, 2005.
The acquisition was accounted for under the purchase method of accounting and, as such, Marathon’s results of operations include the results of the acquired businesses from June 30, 2005.
The purchase price is as follows:
## Table 1 ##
(a) The MAP Limited Liability Company Agreement was amended to eliminate the requirement for MPC to make quarterly cash distributions to Marathon and Ashland between the date the principal transaction agreements were signed and the closing of the acquisition.
Cash and MPC accounts receivable above include $506 million representing Ashland’s 38 percent of MPC’s distributable cash as of June 30, 2005.
(b) Ashland shareholders received 35 million shares valued at $27.23 per share, which was Marathon’s average common stock price over the trading days between June 23 and June 29, 2005.
The exchange ratio was designed to provide an aggregate number of Marathon shares worth $915 million based on Marathon’s average common stock price for each of the 20 consecutive trading days ending with the third complete trading day prior to June 30, 2005.
(c) Assumed debt was repaid on July 1, 2005.
(d) Marathon is entitled to certain tax deductions related to businesses previously owned by Ashland.
However, pursuant to the terms of the tax matters agreement, Marathon has agreed to reimburse Ashland for a portion of the tax benefits associated with these deductions.
This additional consideration will be included in the purchase price as amounts owed to Ashland are identified.
Additions to the purchase price for such amounts were $13 million and $17 million in 2007 and 2006.
The primary reasons for the acquisition and the principal factors that contributed to a purchase price that resulted in the recognition of goodwill were: ?
Marathon believed the outlook for the refining and marketing business was attractive in MPC’s core areas of operation.
Complete ownership of MPC provided Marathon the opportunity to leverage MPC’s access to premium U. S.  markets where Marathon expected the levels of demand to remain high for the foreseeable future; ?
The acquisition increased Marathon’s participation in the RM&T business without the risks commonly associated with integrating a newly acquired business; ?
MPC provided Marathon with an increased source of cash flow which Marathon believed enhanced the geographical balance in its overall risk portfolio; ?
Marathon anticipated the transaction would be accretive to income per share;
## Table 2 ##
(a) Management believes intersegment transactions were conducted under terms comparable to those with unrelated parties.
(b) Differences between segment totals and Marathon totals represent amounts related to corporate administrative activities and other unallocated items and are included in “Items not allocated to segments, net of income taxes” in the reconciliation below.
(c) Differences between segment totals and Marathon totals represent amounts related to corporate administrative activities.
(d) Through April 2007, Integrated Gas segment capital expenditures include EGHoldings at 100 percent.
As discussed in Note 4, effective May 1, 2007, Marathon no longer consolidates EGHoldings and its investment in EGHoldings is accounted for under the equity method of accounting; therefore EGHoldings’ capital expenditures subsequent to April 2007 are not included in Marathon’s capital expenditures
Supplementary Information on Oil and Gas Producing Activities (Unaudited) CONTINUED Summary of Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves
## Table 3 ##

<table><tr><td><i>(In millions, except per share amounts)</i></td><td><i></i> 2007</td><td> 2006</td></tr><tr><td>Revenues and other income</td><td>$66,089</td><td>$66,283</td></tr><tr><td>Income from continuing operations</td><td>3,495</td><td>4,765</td></tr><tr><td>Net income</td><td>3,503</td><td>5,042</td></tr><tr><td>Per share data:</td><td></td><td></td></tr><tr><td>Income from continuing operations – basic</td><td>$5.07</td><td>$6.35</td></tr><tr><td>Income from continuing operations – diluted</td><td>$5.03</td><td>$6.30</td></tr><tr><td>Net income – basic</td><td>$5.08</td><td>$6.72</td></tr><tr><td>Net income – diluted</td><td>$5.04</td><td>$6.67</td></tr></table>
<table><tr><td>Cash<sup>(a)</sup></td><td>$487</td></tr><tr><td>MPC accounts receivable<sup>(a)</sup></td><td>911</td></tr><tr><td>Marathon common stock<sup>(b)</sup></td><td>955</td></tr><tr><td>Estimated additional consideration related to tax matters<sup></sup></td><td>88</td></tr><tr><td>Transaction-related costs</td><td>10</td></tr><tr><td>Purchase price</td><td>2,451</td></tr><tr><td>Assumption of debt<sup>(c)</sup></td><td>1,920</td></tr><tr><td>Total consideration including debt assumption<sup>(d)</sup></td><td>$4,371</td></tr></table>
<table><tr><td></td><td>E&P</td><td>OSM</td><td>RM&T</td><td>IG</td><td>Total</td></tr><tr><td> 2007</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Revenues:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Customer</td><td>$8,623</td><td>$181</td><td>$54,137</td><td>$218</td><td>$63,159</td></tr><tr><td>Intersegment<sup>(a)</sup></td><td>497</td><td>40</td><td>348</td><td>–</td><td>885</td></tr><tr><td>Related parties</td><td>35</td><td>–</td><td>1,590</td><td>–</td><td>1,625</td></tr><tr><td>Segment revenues</td><td>9,155</td><td>221</td><td>56,075</td><td>218</td><td>65,669</td></tr><tr><td>Elimination of intersegment revenues</td><td>-497</td><td>-40</td><td>-348</td><td>–</td><td>-885</td></tr><tr><td>Loss on long-term U.K. natural gas contracts</td><td>-232</td><td>–</td><td>–</td><td>–</td><td>-232</td></tr><tr><td>Total revenues</td><td>$8,426</td><td>$181</td><td>$55,727</td><td>$218</td><td>$64,552</td></tr><tr><td>Segment income (loss)</td><td>$1,729</td><td>$-63</td><td>$2,077</td><td>$132</td><td>$3,875</td></tr><tr><td>Income from equity method investments</td><td>238</td><td>–</td><td>139</td><td>168</td><td>545</td></tr><tr><td>Depreciation, depletion and amortization<sup>(b)</sup></td><td>963</td><td>22</td><td>587</td><td>6</td><td>1,578</td></tr><tr><td>Minority interests in loss of subsidiary</td><td>–</td><td>–</td><td>–</td><td>3</td><td>3</td></tr><tr><td>Income tax provision (benefit)<sup>(b)</sup></td><td>2,172</td><td>-21</td><td>1,183</td><td>24</td><td>3,358</td></tr><tr><td>Capital expenditures<sup>(c)(d)</sup></td><td>2,511</td><td>165</td><td>1,640</td><td>93</td><td>4,409</td></tr><tr><td> 2006</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Revenues:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Customer</td><td>$8,326</td><td>$–</td><td>$54,471</td><td>$179</td><td>$62,976</td></tr><tr><td>Intersegment<sup>(a)</sup></td><td>672</td><td>–</td><td>16</td><td>–</td><td>688</td></tr><tr><td>Related parties</td><td>12</td><td>–</td><td>1,454</td><td>–</td><td>1,466</td></tr><tr><td>Segment revenues</td><td>9,010</td><td>–</td><td>55,941</td><td>179</td><td>65,130</td></tr><tr><td>Elimination of intersegment revenues</td><td>-672</td><td>–</td><td>-16</td><td>–</td><td>-688</td></tr><tr><td>Gain on long-term U.K. natural gas contracts</td><td>454</td><td>–</td><td>–</td><td>–</td><td>454</td></tr><tr><td>Total revenues</td><td>$8,792</td><td>$–</td><td>$55,925</td><td>$179</td><td>$64,896</td></tr><tr><td>Segment income</td><td>$2,003</td><td>$–</td><td>$2,795</td><td>$16</td><td>$4,814</td></tr><tr><td>Income from equity method investments</td><td>206</td><td>–</td><td>145</td><td>40</td><td>391</td></tr><tr><td>Depreciation, depletion and amortization<sup>(b)</sup></td><td>919</td><td>–</td><td>558</td><td>9</td><td>1,486</td></tr><tr><td>Minority interests in loss of subsidiary</td><td>–</td><td>–</td><td>–</td><td>10</td><td>10</td></tr><tr><td>Income tax provision<sup>(b)</sup></td><td>2,371</td><td>–</td><td>1,642</td><td>8</td><td>4,021</td></tr><tr><td>Capital expenditures<sup>(c)(d)</sup></td><td>2,169</td><td>–</td><td>916</td><td>307</td><td>3,392</td></tr><tr><td> 2005</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Revenues:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Customer</td><td>$7,320</td><td>$–</td><td>$54,414</td><td>$236</td><td>$61,970</td></tr><tr><td>Intersegment<sup>(a)</sup></td><td>678</td><td>–</td><td>198</td><td>–</td><td>876</td></tr><tr><td>Related parties</td><td>11</td><td>–</td><td>1,391</td><td>–</td><td>1,402</td></tr><tr><td>Segment revenues</td><td>8,009</td><td>–</td><td>56,003</td><td>236</td><td>64,248</td></tr><tr><td>Elimination of intersegment revenues</td><td>-678</td><td>–</td><td>-198</td><td>–</td><td>-876</td></tr><tr><td>Loss on long-term U.K. natural gas contracts</td><td>-386</td><td>–</td><td>–</td><td>–</td><td>-386</td></tr><tr><td>Total revenues</td><td>$6,945</td><td>$–</td><td>$55,805</td><td>$236</td><td>$62,986</td></tr><tr><td>Segment income</td><td>$1,887</td><td>$–</td><td>$1,628</td><td>$55</td><td>$3,570</td></tr><tr><td>Income from equity method investments</td><td>69</td><td>–</td><td>137</td><td>59</td><td>265</td></tr><tr><td>Depreciation, depletion and amortization<sup>(b)</sup></td><td>794</td><td>–</td><td>468</td><td>8</td><td>1,270</td></tr><tr><td>Minority interests in (income) loss of subsidiaries<sup>(b)</sup></td><td>–</td><td>–</td><td>-376</td><td>8</td><td>-368</td></tr><tr><td>Income tax provision (benefit)<sup>(b)</sup></td><td>1,030</td><td>–</td><td>1,007</td><td>-7</td><td>2,030</td></tr><tr><td>Capital expenditures<sup>(c)(d)</sup></td><td>1,366</td><td>–</td><td>841</td><td>571</td><td>2,778</td></tr></table>
<table><tr><td><i>(In millions)</i></td><td>2007</td><td>2006</td><td>2005</td></tr><tr><td>Sales and transfers of oil and gas produced, net of production, transportation and administrative costs</td><td>$-4,887</td><td>$-5,312</td><td>$-3,754</td></tr><tr><td>Net changes in prices and production, transportation and administrative costs related to future production</td><td>12,845</td><td>-1,342</td><td>6,648</td></tr><tr><td>Extensions, discoveries and improved recovery, less related costs</td><td>1,816</td><td>1,290</td><td>700</td></tr><tr><td>Development costs incurred during the period</td><td>1,654</td><td>1,251</td><td>1,030</td></tr><tr><td>Changes in estimated future development costs</td><td>-1,727</td><td>-527</td><td>-552</td></tr><tr><td>Revisions of previous quantity estimates</td><td>290</td><td>1,319</td><td>820</td></tr><tr><td>Net changes in purchases and sales of minerals in place</td><td>23</td><td>30</td><td>4,557</td></tr><tr><td>Accretion of discount</td><td>1,726</td><td>1,882</td><td>1,124</td></tr><tr><td>Net change in income taxes</td><td>-6,751</td><td>-660</td><td>-6,694</td></tr><tr><td>Timing and other</td><td>-12</td><td>-14</td><td>307</td></tr><tr><td>Net change for the year</td><td>4,977</td><td>-2,083</td><td>4,186</td></tr><tr><td>Beginning of year</td><td>8,518</td><td>10,601</td><td>6,415</td></tr><tr><td>End of year</td><td>$13,495</td><td>$8,518</td><td>$10,601</td></tr><tr><td>Net change for the year from discontinued operations</td><td>$–</td><td>$-216</td><td>$162</td></tr></table>

Question: if current development costs increased in 2008 as much as in 2007 , what would the 2008 total be , in millions?
Answer: 2057.0