Supplementary Information on Oil and Gas Producing Activities (Unaudited) C O N T I N U E D Estimated Quantities of Proved Oil and Gas Reserves (continued)
## Table 0 ##
(a) Consists of estimated reserves from properties governed by production sharing contracts.
(b) The net positive or negative balance of proved reserves acquired or relinquished in property trades within the same geographic area is reported within purchases of reserves in place or sales of reserves in place, respectively.
(c) Excludes the resale of purchased gas utilized in reservoir management.
Standardized Measure of Discounted Future Net Cash Flows and Changes Therein Relating to Proved Oil and Gas Reserves Estimated discounted future net cash flows and changes therein were determined in accordance with Statement of Financial Accounting Standards No.69.
Certain information concerning the assumptions used in computing the valuation of proved reserves and their inherent limitations are discussed below.
Marathon believes such information is essential for a proper understanding and assessment of the data presented.
Future cash inflows are computed by applying year-end prices of oil and gas relating to Marathon’s proved reserves to the year-end quantities of those reserves.
Future price changes are considered only to the extent provided by contractual arrangements in existence at year-end.
The assumptions used to compute the proved reserve valuation do not necessarily reflect Marathon’s expectations of actual revenues to be derived from those reserves or their present worth.
Assigning monetary values to the estimated quantities of reserves, described on the preceding page, does not reduce the subjective and ever-changing nature of such reserve estimates.
Additional subjectivity occurs when determining present values because the rate of producing the reserves must be estimated.
In addition to uncertainties inherent in predicting the future, variations from the expected production rate also could result directly or indirectly from factors outside of Marathon’s control, such as unintentional delays in development, environmental concerns, changes in prices or regulatory controls.
The reserve valuation assumes that all reserves will be disposed of by production.
However, if reserves are sold in place or subjected to participation by foreign governments, additional economic considerations also could affect the amount of cash eventually realized.
Future development and production, transportation and administrative costs are computed by estimating the expenditures to be incurred in developing and producing the proved oil and gas reserves at the end of the year, based on year-end costs and assuming continuation of existing economic conditions.
Future income tax expenses are computed by applying the appropriate year-end statutory tax rates, with consideration of future tax rates already legislated, to the future pretax net cash flows relating to Marathon’s proved oil and gas reserves.
Permanent differences in oil and gas related tax credits and allowances are recognized.
Discount was derived by using a discount rate of 10 percent a year to reflect the timing of the future net cash flows relating to proved oil and gas reserves.
At its Catlettsburg, Kentucky refinery, MAP has completed the approximately $440 million multi-year integrated investment program to upgrade product yield realizations and reduce fixed and variable manufacturing expenses.
This program involves the expansion, conversion and retirement of certain refinery processing units that, in addition to improving profitability, will allow the refinery to begin producing low-sulfur (TIER 2) gasoline.
Project startup was in the first quarter of 2004.
In the fourth quarter of 2003, MAP commenced approximately $300 million in new capital projects for its 74,000 bpd Detroit, Michigan refinery.
One of the projects, a $110 million expansion project, is expected to raise the crude oil capacity at the refinery by 35 percent to 100,000 bpd.
Other projects are expected to enable the refinery to produce new clean fuels and further control regulated air emissions.
Completion of the projects is scheduled for the fourth quarter of 2005.
Marathon will loan MAP the funds necessary for these upgrade and expansion projects.
Marketing In 2003, MAP’s refined product sales volumes (excluding matching buy/sell transactions) totaled 19.8 billion gallons (1,293,000 bpd).
Excluding sales related to matching buy/sell transactions, the wholesale distribution of petroleum products to private brand marketers and to large commercial and industrial consumers, primarily located in the Midwest, the upper Great Plains and the Southeast, and sales in the spot market, accounted for approximately 70 percent of MAP’s refined product sales volumes in 2003.
Approximately 50 percent of MAP’s gasoline volumes and 91 percent of its distillate volumes were sold on a wholesale or spot market basis to independent unbranded customers or other wholesalers in 2003.
Approximately half of MAP’s propane is sold into the home heating markets and industrial consumers purchase the balance.
Propylene, cumene, aromatics, aliphatics, and sulfur are marketed to customers in the chemical industry.
Base lube oils and slack wax are sold throughout the United States.
Pitch is also sold domestically, but approximately 13 percent of pitch products are exported into growing markets in Canada, Mexico, India, and South America.
MAP markets asphalt through owned and leased terminals throughout the Midwest and Southeast.
The MAP customer base includes approximately 900 asphalt-paving contractors, government entities (states, counties, cities and townships) and asphalt roofing shingle manufacturers.
The following table sets forth the volume of MAP’s consolidated refined product sales by product group for each of the last three years: Refined Product Sales
## Table 1 ##
MAP sells reformulated gasoline in parts of its marketing territory, primarily Chicago, Illinois; Louisville, Kentucky; northern Kentucky; and Milwaukee, Wisconsin.
MAP also sells low-vapor-pressure gasoline in nine states.
As of December 31, 2003, MAP supplied petroleum products to approximately 3,900 Marathon and Ashland branded retail outlets located primarily in Michigan, Ohio, Indiana, Kentucky and Illinois.
Branded retail outlets are also located in Florida, Georgia, Wisconsin, West Virginia, Minnesota, Tennessee, Virginia, Pennsylvania, North Carolina, South Carolina and Alabama.
Management’s Discussion and Analysis of Environmental Matters, Litigation and Contingencies Marathon has incurred and will continue to incur substantial capital, operating and maintenance, and remediation expenditures as a result of environmental laws and regulations.
To the extent these expenditures, as with all costs, are not ultimately reflected in the prices of Marathon’s products and services, operating results will be adversely affected.
Marathon believes that substantially all of its competitors are subject to similar environmental laws and regulations.
However, the specific impact on each competitor may vary depending on a number of factors, including the age and location of its operating facilities, marketing areas, production processes and whether or not it is engaged in the petrochemical business or the marine transportation of crude oil and refined products.
Marathon’s environmental expenditures for each of the last three years were(a):
## Table 2 ##
(a) Amounts are determined based on American Petroleum Institute survey guidelines and include 100 percent of MAP.
(b) These amounts include spending charged against remediation reserves, where permissible, but exclude noncash provisions recorded for environmental remediation.
Marathon’s environmental capital expenditures accounted for 17 percent of total capital expenditures in 2003, eight percent in 2002, and six percent in 2001.
Marathon accrues for environmental remediation activities when the responsibility to remediate is probable and the amount of associated costs can be reasonably estimated.
As environmental remediation matters proceed toward ultimate resolution or as additional remediation obligations arise, charges in excess of those previously accrued may be required.
Marathon has been notified that it is a potentially responsible party (“PRP”) at nine waste sites under the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) as of December 31, 2003.
In addition, there are 4 sites where Marathon has received information requests or other indications that Marathon may be a PRP under CERCLA but where sufficient information is not presently available to confirm the existence of liability.
At many of these sites, Marathon is one of a number of parties involved and the total cost of remediation, as well as Marathon’s share thereof, is frequently dependent upon the outcome of investigations and remedial studies.
There are also 125 additional sites, excluding retail marketing outlets, related to Marathon where remediation is being sought under other environmental statutes, both federal and state, or where private parties are seeking remediation through discussions or litigation.
Of these sites, 16 were associated with properties conveyed to MAP by Ashland for which Ashland has retained liability for all costs associated with remediation.
New or expanded environmental requirements, which could increase Marathon’s environmental costs, may arise in the future.
Marathon intends to comply with all legal requirements regarding the environment, but since not all of them are fixed or presently determinable (even under existing legislation) and may be affected by future legislation, it is not possible to predict all of the ultimate costs of compliance, including remediation costs that may be incurred and penalties that may be imposed.
Marathon’s environmental capital expenditures are expected to be approximately $415 million or 20% of capital expenditures in 2004.
Predictions beyond 2004 can only be broad-based estimates, which have varied, and will continue to vary, due to the ongoing evolution of specific regulatory requirements, the possible imposition of more stringent requirements and the availability of new technologies, among other matters.
Based upon currently identified projects, Marathon anticipates that environmental capital expenditures will be approximately $425 million in 2005; however, actual expenditures may vary as the number and scope of environmental projects are revised as a result of improved technology or changes in regulatory requirements and could increase if additional projects are identified or additional requirements are imposed.
FEDERAL REALTY INVESTMENT TRUST SCHEDULE III SUMMARY OF REAL ESTATE AND ACCUMULATED DEPRECIATION—CONTINUED Three Years Ended December 31, 2009 Reconciliation of Accumulated Depreciation and Amortization (In thousands)
## Table 3 ##
(5) Includes a charge of $16.4 million in 2009 for increasing the accrual for litigation regarding a parcel of land located adjacent to Santana Row as well as other costs related to the litigation and appeal process.
The matter is further discussed in Note 8 to the consolidated financial statements.
(6) Includes a charge of $1.6 million in 2008 related to the settlement of a litigation matter relating to a shopping center in New Jersey.
The matter is further discussed in Note 8 to the consolidated financial statements.
(7) The SEC has stated that EBITDA is a non-GAAP measure as calculated in the table below.
Adjusted EBITDA is a non-GAAP measure that means net income or loss attributable to the Trust plus net interest expense, income taxes, depreciation and amortization, gain or loss on sale of real estate and impairments of real estate if any.
Adjusted EBITDA is presented because it approximates a key performance measure in our debt covenants, but it should not be considered an alternative measure of operating results or cash flow from operations as determined in accordance with GAAP.
Adjusted EBITDA as presented may not be comparable to other similarly titled measures used by other REITs.

Tables referenced above, in order (Table 0 first):
<table><tr><td> <i>(Billions of cubic feet)</i> </td><td>United States</td><td>Europe</td><td>West (a) Africa</td><td>Consolidated</td><td>Equity Investees</td><td>Continuing Operations</td><td>Discontinued Operations</td></tr><tr><td><i>Natural Gas</i></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Proved developed and undeveloped reserves:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Beginning of year – 2001</td><td>1,914</td><td>614</td><td>–</td><td>2,528</td><td>89</td><td>2,617</td><td>477</td></tr><tr><td>Purchase of reserves in place<sup>(b)</sup></td><td>223</td><td>–</td><td>–</td><td>223</td><td>–</td><td>223</td><td>–</td></tr><tr><td>Revisions of previous estimates</td><td>-267</td><td>-12</td><td>–</td><td>-279</td><td>-27</td><td>-306</td><td>3</td></tr><tr><td>Improved recovery</td><td>10</td><td>–</td><td>–</td><td>10</td><td>–</td><td>10</td><td>–</td></tr><tr><td>Extensions, discoveries and other additions</td><td>210</td><td>126</td><td>–</td><td>336</td><td>–</td><td>336</td><td>48</td></tr><tr><td>Production<sup>(c)</sup></td><td>-289</td><td>-113</td><td>–</td><td>-402</td><td>-11</td><td>-413</td><td>-45</td></tr><tr><td>Sales of reserves in place<sup>(b)</sup></td><td>-8</td><td>–</td><td>–</td><td>-8</td><td>–</td><td>-8</td><td>-84</td></tr><tr><td>End of year – 2001</td><td>1,793</td><td>615</td><td>–</td><td>2,408</td><td>51</td><td>2,459</td><td>399</td></tr><tr><td>Purchase of reserves in place<sup>(b)</sup></td><td>–</td><td>–</td><td>571</td><td>571</td><td>–</td><td>571</td><td>9</td></tr><tr><td>Revisions of previous estimates</td><td>48</td><td>4</td><td>–</td><td>52</td><td>3</td><td>55</td><td>-20</td></tr><tr><td>Improved recovery</td><td>–</td><td>–</td><td>–</td><td>–</td><td>–</td><td>–</td><td>–</td></tr><tr><td>Extensions, discoveries and other additions</td><td>156</td><td>46</td><td>101</td><td>303</td><td>14</td><td>317</td><td>32</td></tr><tr><td>Production<sup>(c)</sup></td><td>-272</td><td>-103</td><td>-19</td><td>-394</td><td>-9</td><td>-403</td><td>-38</td></tr><tr><td>Sales of reserves in place<sup>(b)</sup></td><td>-1</td><td>–</td><td>–</td><td>-1</td><td>–</td><td>-1</td><td>-3</td></tr><tr><td>End of year – 2002</td><td>1,724</td><td>562</td><td>653</td><td>2,939</td><td>59</td><td>2,998</td><td>379</td></tr><tr><td>Purchase of reserves in place<sup>(b)</sup></td><td>7</td><td>–</td><td>–</td><td>7</td><td>–</td><td>7</td><td>–</td></tr><tr><td>Revisions of previous estimates</td><td>20</td><td>-7</td><td>36</td><td>49</td><td>1</td><td>50</td><td>–</td></tr><tr><td>Improved recovery</td><td>–</td><td>–</td><td>–</td><td>–</td><td>–</td><td>–</td><td>–</td></tr><tr><td>Extensions, discoveries and other additions</td><td>161</td><td>24</td><td>–</td><td>185</td><td>–</td><td>185</td><td>8</td></tr><tr><td>Production<sup>(c)</sup></td><td>-267</td><td>-95</td><td>-24</td><td>-386</td><td>-5</td><td>-391</td><td>-27</td></tr><tr><td>Sales of reserves in place<sup>(b)</sup></td><td>-10</td><td>–</td><td>–</td><td>-10</td><td>-55</td><td>-65</td><td>-360</td></tr><tr><td> End of year – 2003</td><td>1,635</td><td>484</td><td>665</td><td>2,784</td><td>–</td><td>2,784</td><td>–</td></tr><tr><td>Proved developed reserves:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Beginning of year – 2001</td><td>1,421</td><td>563</td><td>–</td><td>1,984</td><td>52</td><td>2,036</td><td>381</td></tr><tr><td>End of year – 2001</td><td>1,308</td><td>473</td><td>–</td><td>1,781</td><td>32</td><td>1,813</td><td>308</td></tr><tr><td>End of year – 2002</td><td>1,206</td><td>408</td><td>552</td><td>2,166</td><td>36</td><td>2,202</td><td>290</td></tr><tr><td> End of year – 2003</td><td>1,067</td><td>421</td><td>528</td><td>2,016</td><td>–</td><td>2,016</td><td>–</td></tr></table>
<table><tr><td><i>(Thousands of Barrels per Day)</i></td><td>2003</td><td>2002</td><td>2001</td></tr><tr><td>Gasoline</td><td>776</td><td>773</td><td>748</td></tr><tr><td>Distillates</td><td>365</td><td>346</td><td>345</td></tr><tr><td>Propane</td><td>21</td><td>22</td><td>21</td></tr><tr><td>Feedstocks and Special Products</td><td>97</td><td>82</td><td>71</td></tr><tr><td>Heavy Fuel Oil</td><td>24</td><td>20</td><td>41</td></tr><tr><td>Asphalt</td><td>74</td><td>75</td><td>78</td></tr><tr><td>TOTAL</td><td>1,357</td><td>1,318</td><td>1,304</td></tr><tr><td>Matching Buy/Sell Volumes included in above</td><td>64</td><td>71</td><td>45</td></tr></table>
<table><tr><td> <i>(In millions)</i> </td><td> 2003</td><td>2002</td><td>2001</td></tr><tr><td>Capital</td><td>$331</td><td>$128</td><td>$90</td></tr><tr><td>Compliance</td><td></td><td></td><td></td></tr><tr><td>Operating & maintenance</td><td>243</td><td>205</td><td>213</td></tr><tr><td>Remediation<sup>(b)</sup></td><td>44</td><td>45</td><td>22</td></tr><tr><td>Total</td><td>$618</td><td>$378</td><td>$325</td></tr></table>
<table><tr><td>Balance, December 31, 2006</td><td>$740,507</td></tr><tr><td>Additions during period—depreciation and amortization expense</td><td>96,454</td></tr><tr><td>Deductions during period—disposition and retirements of property</td><td>-80,258</td></tr><tr><td>Balance, December 31, 2007</td><td>756,703</td></tr><tr><td>Additions during period—depreciation and amortization expense</td><td>101,321</td></tr><tr><td>Deductions during period—disposition and retirements of property</td><td>-11,766</td></tr><tr><td>Balance, December 31, 2008</td><td>846,258</td></tr><tr><td>Additions during period—depreciation and amortization expense</td><td>103.698</td></tr><tr><td>Deductions during period—disposition and retirements of property</td><td>-11,869</td></tr><tr><td>Balance, December 31, 2009</td><td>$938,087</td></tr></table>

Question: What's the average of End of year – 2001 of Continuing Operations, and Balance, December 31, 2009 ?
Answer: 470273
Reasoning program: add(2459.0,938087.0), divide(#0,const_2)