Financing The Company’s total long-term debt, net of unamortized discount, at December 31, 2002, was $977 million compared to $837 million at December 31, 2001.
If the $125 million AMCCO debt had been included, the total long-term debt would have been $962 million at December 31, 2001.
The ratio of debt-to-book capital (defined as the Company’s total debt plus its equity) was 50 percent at December 31, 2002, compared with 47 percent at December 31, 2001.
## Table 0 ##
The Company’s long-term debt, net of current portion, is comprised of: ?
$250 million of 8% Senior Notes Due 2027 ?
$100 million of 7 1/4% Notes Due 2097 ?
$100 million of 7 1/4% Notes Due 2023 ?
$380 million on the $400 million credit facility based upon a Eurodollar rate plus a range of 60 to 145 basis points depending upon the percentage of utilization and credit rating, maturing in 2006.
The interest rate at December 31, 2002 was 2.47 percent.
The interest rate at December 31, 2001 was 3.0 percent.  ?
$125 million of 8.95% Series A-2 Notes on the AMCCO debt, payable in 2004.
There was no AMCCO debt on the Company’s balance sheet at December 31, 2001.  ?
$20.4 million on the Israel debt based upon the London Interbank Offering Rate (“LIBOR”) plus 75 basis points, payable in 2004.
The interest rate at December 31, 2002 was 2.18 percent.
There was no outstanding Israel debt at December 31, 2001.  ?
$7.9 million of the 6.25% Aspect acquisition note, payable in 2004 ?
($6.2) million unamortized discount The Company entered into a new $400 million five-year credit agreement on November 30, 2001 with certain commercial lending institutions which exposes the Company to the risk of earnings or cash flow loss due to changes in market interest rates.
The interest rate is based upon a Eurodollar rate plus a range of 60 to 145 basis points depending upon the percentage of utilization and credit rating.
At December 31, 2002, there was $380 million borrowed against this credit agreement, which has a maturity date of November 30, 2006.
For more information, see “Item 8.
Financial Statements and Supplementary Data--Note 3 - Debt” of this Form 10-K.
The Company also entered into a new $200 million 364-day credit agreement on November 27, 2002 with certain commercial lending institutions which exposes the Company to the risk of earnings or cash flow loss due to changes in market interest rates.
The interest rate is based upon a Eurodollar rate plus a range of 62.5 to 150 basis points depending upon the percentage of utilization and credit rating.
At December 31, 2002, there were no amounts outstanding under this credit agreement.
The agreement has a maturity date of November 26, 2003 for the revolving commitment and a maturity date of November 25, 2004 for the term commitment that includes any balance remaining after the revolving commitment matures.
For more information, see “Item 8.
Financial Statements and Supplementary Data--Note 3 - Debt” of this Form 10-K.  Financial covenants on both the $400 million and $200 million credit facilities include the following: (a) the ratio of Earnings Before Interest, Taxes, Depreciation and Exploration Expense (“EBITDAX”) to total interest expense for any consecutive period of four fiscal quarters ending on the last day of a fiscal quarter may not be less than 4.0 to 1.0; (b) the total debt to capitalization ratio, expressed as a percentage, may not exceed 60 percent at any time; and (c) the total asset value of the Company’s restricted subsidiaries may not be less than $800 million at any time.
Gathering, Marketing and Processing NEMI markets the majority of the Company’s domestic natural gas, as well as certain third-party natural gas.
NEMI sells natural gas directly to end-users, natural gas marketers, industrial users, interstate and intrastate pipelines, power generators and local distribution companies.
NEMI markets a portion of the Company’s domestic crude oil, as well as certain third-party crude oil.
The Company records all of NEMI’s sales and expenses as gathering, marketing and processing revenues and expenses.
All intercompany sales and expenses have been eliminated in the Company’s consolidated financial statements.
The gathering, marketing and processing revenues less expenses for NEMI are reflected in the table below.
## Table 1 ##
The margins for natural gas on a per MMBTU basis were $.035 for 2002 and 2001 and $.027 for 2000.
The increase in natural gas margin on a per MMBTU basis for 2001 compared to 2000 was due to the improvement in natural gas prices.
The margins for crude oil on a per Bbl basis were $.84 for 2002, $.95 for 2001 and $1.28 for 2000.
The decrease in crude oil margin for 2002 compared to 2001 was due to increased general and administrative expenses coupled with higher transportation expense.
The decrease in crude oil margin for 2001 compared to 2000 was due to lower crude oil prices.
Income Taxes Income tax expense decreased to $25 million in 2002 from $91 million in 2001, primarily from the decrease in income.
However, the effective income tax rate increased to 59 percent in 2002 from 41 percent in 2001.
During 2002, more of the Company’s income was from international operations.
Some of the countries in which the international operations were conducted have a higher statutory income tax rate than the United States.
To a lesser extent, also impacting the effective rate in 2002 was the lower income level.
FUTURE TRENDS The Company expects crude oil and natural gas production to increase in 2003 and 2004 compared to 2002.
The increased production in 2003 is expected primarily from the phase 2A expansion of the Alba field in Equatorial Guinea, the startup of production from the Mari-B field, offshore Israel, production from the CDX block in China and a full year of production in Ecuador.
The increase in 2004 is expected primarily from the continued expansion of markets in Israel and the phase 2B expansion of the LPG plant in Equatorial Guinea.
The Company recently set its 2003 capital expenditures budget at approximately $510 million.
Such expenditures are planned to be funded principally through internally generated cash flows.
The Company believes that it has the capital structure to take advantage of strategic acquisitions, as they become available, through internally generated cash flows or available lines of credit and other borrowing opportunities.
Ecuador.
Noble Energy has been actively engaged in exploration, exploitation and development of crude oil and natural gas properties in Ecuador since 1996.
The Company is currently utilizing the gas in the Amistad gas field (offshore Ecuador), which was discovered in the 1970s, to generate electricity through its 100 percent owned natural gas-fired power plant, located near the city of Machala.
Currently generating 130 MW, with additional capital investment, the power plant will ultimately be capable of generating 220 MW of electricity into the Ecuadorian power grid.
The concession covers 12,355 gross developed acres and 851,771 gross undeveloped acres encompassing the Amistad field.
For more information, see “Item 2.
Properties--Crude Oil and Natural Gas” of this Form 10-K.  Equatorial Guinea.
Noble Energy has been actively engaged in exploration, exploitation and development of crude oil and natural gas properties offshore Equatorial Guinea (West Africa) since 1990.
The offshore Equatorial Guinea production is from the Alba field, which produces natural gas and condensate.
The majority of the natural gas production is sold to a methanol plant, which began production in the second quarter of 2001.
The methanol plant has a 25-year contract to purchase natural gas from the Alba field.
The plant is owned by Atlantic Methanol Production Company LLC (“AMPCO”), in which the Company indirectly owns a 45 percent interest through its ownership of Atlantic Methanol Capital Company (“AMCCO”).
For more information on the methanol plant, see “Item 1.  Business--Unconsolidated Subsidiary” of this Form 10-K.  At December 31, 2002, the Company held 45,203 gross developed acres and 266,754 gross undeveloped acres offshore Equatorial Guinea on which the Company may conduct future exploration activities.
For more information, see “Item 2.
Properties--Crude Oil and Natural Gas” of this Form 10-K.  Israel.
Noble Energy has been actively engaged in exploration, exploitation and development of crude oil and natural gas properties in the Mediterranean Sea, offshore Israel, since 1998.
The Company owns a 47 percent interest in 11 licenses and two leases.
At December 31, 2002, the Company held 123,552 gross developed acres and 1,028,796 gross undeveloped acres located about 20 miles offshore Israel in water depths ranging from 700 feet to 5,000 feet.
Noble Energy and its partners announced on June 25, 2002 they had executed a definitive agreement for the sale of natural gas to Israel Electric Corporation (“IEC”).
For more information, see “Item 2.
Properties--Crude Oil and Natural Gas” of this Form 10-K.  North Sea.
Noble Energy has been actively engaged in exploration, exploitation and development of crude oil and natural gas properties in the North Sea (Denmark, Netherlands and United Kingdom) since 1996.
At December 31, 2002, the Company held 81,675 gross developed acres and 677,029 gross undeveloped acres on which the Company may conduct future exploration activities.
For more information, see “Item 2.
Properties-- Crude Oil and Natural Gas” of this Form 10-K.  Vietnam.
Noble Energy owns a 77 percent interest in two offshore blocks totaling 1,701,812 gross undeveloped acres in the Nam Con Son Basin.
For more information, see “Item 2.
Properties--Crude Oil and Natural Gas” of this Form 10-K.  Production Activities Operated Property Statistics.
The percentage of crude oil and natural gas wells operated and the percentage of sales volume from operated properties are shown in the following table as of December 31:
## Table 2 ##
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS Union Pacific Corporation and Subsidiary Companies For purposes of this report, unless the context otherwise requires, all references herein to the “Corporation”, “UPC”, “we”, “us”, and “our” mean Union Pacific Corporation and its subsidiaries, including Union Pacific Railroad Company, which will be separately referred to herein as “UPRR” or the “Railroad”.1.
Nature of Operations and Significant Accounting Policies Operations and Segmentation – We are a Class I railroad that operates in the United States.
We have 32,012 route miles, linking Pacific Coast and Gulf Coast ports with the Midwest and eastern United States gateways and providing several corridors to key Mexican gateways.
We serve the western twothirds of the country and maintain coordinated schedules with other rail carriers for the handling of freight to and from the Atlantic Coast, the Pacific Coast, the Southeast, the Southwest, Canada, and Mexico.
Export and import traffic is moved through Gulf Coast and Pacific Coast ports and across the Mexican and Canadian borders.
The Railroad, along with its subsidiaries and rail affiliates, is our one reportable operating segment.
Although revenues are analyzed by commodity group, we analyze the net financial results of the Railroad as one segment due to the integrated nature of our rail network.
The following table provides revenue by commodity group:
## Table 3 ##
Basis of Presentation – Certain prior year amounts have been reclassified to conform to the current period financial statement presentation.
The reclassifications include reporting freight revenues instead of commodity revenues.
The amounts reclassified from freight revenues to other revenues totaled $30 million and $71 million for the years ended December 31, 2007, and December 31, 2006, respectively.
In addition, we modified our operating expense categories to report fuel used in railroad operations as a stand-alone category, to combine purchased services and materials into one line, and to reclassify certain other expenses among operating expense categories.
These reclassifications had no impact on previously reported operating revenues, total operating expenses, operating income or net income.
Significant Accounting Policies Principles of Consolidation – The Consolidated Financial Statements include the accounts of Union Pacific Corporation and all of its subsidiaries.
Investments in affiliated companies (20% to 50% owned) are accounted for using the equity method of accounting.
All significant intercompany transactions are eliminated.
The Corporation evaluates its less than majority-owned investments for consolidation

Tables referenced above, in order (Table 0 first):
<table><tr><td> (in thousands)</td><td colspan="5"> Payments Due by Period</td></tr><tr><td> Contractual Obligations</td><td> Total</td><td> Less Than 1 Year</td><td> 1 to 3 Years</td><td> 4 to 5 Years</td><td> After 5 Years</td></tr><tr><td>Long-term debt</td><td>$1,025,246</td><td>$41,919</td><td>$153,327</td><td>$380,000</td><td>$450,000</td></tr><tr><td>Drilling obligations</td><td>118,211</td><td>116,411</td><td>1,800</td><td></td><td></td></tr><tr><td>Total contractual cash obligations</td><td>$1,143,457</td><td>$158,330</td><td>$155,127</td><td>$380,000</td><td>$450,000</td></tr></table>
<table><tr><td> (in thousands)</td><td colspan="2"> 2002</td><td colspan="2"> 2001</td><td colspan="2"> 2000</td></tr><tr><td> (amounts include inter- company eliminations)</td><td> Crude  Oil</td><td> Natural  Gas</td><td> Crude  Oil</td><td> Natural  Gas</td><td> Crude  Oil</td><td> Natural  Gas</td></tr><tr><td>Revenues</td><td>$88,377</td><td>$625,714</td><td>$75,550</td><td>$645,400</td><td>$91,204</td><td>$498,729</td></tr><tr><td>Expenses</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Cost of goods sold</td><td>61,553</td><td>588,022</td><td>49,191</td><td>607,170</td><td>63,005</td><td>464,600</td></tr><tr><td>Transportation</td><td>20,323</td><td>28,284</td><td>19,739</td><td>27,779</td><td>19,455</td><td>24,014</td></tr><tr><td>General and administrative</td><td>802</td><td>3,857</td><td>199</td><td>3,176</td><td>190</td><td>3,002</td></tr><tr><td>Total Expenses</td><td>$82,678</td><td>$620,163</td><td>$69,129</td><td>$638,125</td><td>$82,650</td><td>$491,616</td></tr><tr><td>Gross Margin</td><td>$5,699</td><td>$5,551</td><td>$6,421</td><td>$7,275</td><td>$8,554</td><td>$7,113</td></tr></table>
<table><tr><td></td><td colspan="2"> 2002</td><td colspan="2"> 2001</td><td colspan="2"> 2000</td></tr><tr><td> (in percentages)</td><td> Oil</td><td> Gas</td><td> Oil</td><td> Gas</td><td> Oil</td><td> Gas</td></tr><tr><td>Operated well count basis</td><td>23.3</td><td>62.8</td><td>24.8</td><td>60.6</td><td>23.1</td><td>66.0</td></tr><tr><td>Operated sales volume basis</td><td>29.3</td><td>45.1</td><td>37.2</td><td>52.3</td><td>48.3</td><td>64.5</td></tr></table>
<table><tr><td><i>Millions of Dollars</i></td><td><i>2008</i></td><td><i>2007</i></td><td><i>2006</i></td></tr><tr><td>Agricultural</td><td>$3,174</td><td>$2,605</td><td>$2,385</td></tr><tr><td>Automotive</td><td>1,344</td><td>1,458</td><td>1,427</td></tr><tr><td>Chemicals</td><td>2,494</td><td>2,287</td><td>2,084</td></tr><tr><td>Energy</td><td>3,810</td><td>3,134</td><td>2,949</td></tr><tr><td>Industrial Products</td><td>3,273</td><td>3,077</td><td>3,135</td></tr><tr><td>Intermodal</td><td>3,023</td><td>2,925</td><td>2,811</td></tr><tr><td>Total freight revenues</td><td>$17,118</td><td>$15,486</td><td>$14,791</td></tr><tr><td>Other revenues</td><td>852</td><td>797</td><td>787</td></tr><tr><td>Total operating revenues</td><td>$17,970</td><td>$16,283</td><td>$15,578</td></tr></table>

Question: Which year is the amounts include inter- company eliminations in terms of Revenues for Natural Gas the highest?
Answer: 2001