respect to the mainline American and the mainline US Airways dispatchers, flight simulator engineers and flight crew training instructors, all of whom are now represented by the TWU, a rival organization, the National Association of Airline Professionals (NAAP), filed single carrier applications seeking to represent those employees.
The NMB will have to determine that a single transportation system exists and will certify a post-merger representative of the combined employee groups before the process for negotiating new JCBAs can begin.
The Merger had no impact on the CBAs that cover the employees of our wholly-owned subsidiary airlines which are not being merged (Envoy, Piedmont and PSA).
For those employees, the RLA provides that CBAs do not expire, but instead become amendable as of a stated date.
In 2014, Envoy pilots ratified a new 10 year collective bargaining agreement, Piedmont pilots ratified a new 10 year collective bargaining agreement and Piedmont flight attendants ratified a new five-year collective bargaining agreement.
With the exception of the passenger service employees who are now engaged in traditional RLA negotiations that are expected to result in a JCBA and the US Airways flight simulator engineers and flight crew training instructors, other union-represented American mainline employees are covered by agreements that are not currently amendable.
Until those agreements become amendable, negotiations for JCBAs will be conducted outside the traditional RLA bargaining process described above, and, in the meantime, no self-help will be permissible.
The Piedmont mechanics and stock clerks and the PSA and Piedmont dispatchers also have agreements that are now amendable and are engaged in traditional RLA negotiations.
None of the unions representing our employees presently may lawfully engage in concerted refusals to work, such as strikes, slow-downs, sick-outs or other similar activity, against us.
Nonetheless, there is a risk that disgruntled employees, either with or without union involvement, could engage in one or more concerted refusals to work that could individually or collectively harm the operation of our airline and impair our financial performance.
For more discussion, see Part I, Item 1A.
Risk Factors – “Union disputes, employee strikes and other labor-related disruptions may adversely affect our operations.
” Aircraft Fuel Our operations and financial results are significantly affected by the availability and price of jet fuel.
Based on our 2015 forecasted mainline and regional fuel consumption, we estimate that, as of December 31, 2014, a one cent per gallon increase in aviation fuel price would increase our 2015 annual fuel expense by $43 million.
The following table shows annual aircraft fuel consumption and costs, including taxes, for our mainline operations for 2012 through 2014 (gallons and aircraft fuel expense in millions).
## Table 0 ##
(a) Represents “combined” financial data, which includes the financial results of American and US Airways Group each on a standalone basis.
Total combined fuel expenses for our wholly-owned and third-party regional carriers operating under capacity purchase agreements of American and US Airways Group, each on a standalone basis, were $2.0 billion, $2.1 billion and $2.1 billion for the years ended December 31, 2014, 2013 and 2012, respectively
allocation, historical returns on these types of assets, the current economic environment and the expected returns likely to be earned over the life of the plan.
We assume the long-term asset mix will be consistent with a target asset allocation of 70% equity and 30% fixed income, with a range of plus or minus 10% acceptable degree of variation in the plan’s asset allocation.
Based on these factors we assumed an average of 8.25% per annum over the life of the plan for the calculation of 2008 net periodic benefit cost.
The assumption will be reduced to 8.00% for the calculation of 2009 net periodic benefit cost.
No plan assets are expected to be returned to us during 2009.
In order to determine an appropriate discount rate at December 31, 2008, we performed an analysis of the Citigroup Pension Discount Curve (the CPDC) as of that date for each of our plans.
The CPDC uses spot rates that represent the equivalent yield on high quality, zero coupon bonds for specific maturities.
We used these rates to develop an equivalent single discount rate based on our plans’ expected future benefit payment streams and duration of plan liabilities.
A 1% increase in the discount rate would have resulted in a decrease in net periodic benefit cost of approximately $2 million in 2008.
A 1% decrease in the discount rate would have resulted in an increase in net periodic benefit cost of approximately $2 million in 2008.
Assumed health care cost trend rates were as follows at December 31:
## Table 1 ##
Weighted-average asset allocations for the tax-qualified defined benefit pension plan are as follows:
## Table 2 ##
## Table 3 ##
The investment policy for the tax-qualified defined benefit pension plan is determined by an employee benefits committee (the committee) with input from a third-party investment consultant.
Based on a review of historical rates of return achieved by equity and fixed income investments in various combinations over multi-year holding periods and an evaluation of the probabilities of achieving acceptable real rates of return, the committee has determined the target asset allocation deemed most appropriate to meet the immediate and future benefit payment requirements for the plan and to provide a diversification strategy which reduces market and interest rate risk.
A 1% increase (decrease) in the expected return on plan assets would have resulted in a (decrease) increase, respectively, in net periodic benefit cost of approximately $2 million in 2008.
We base our determination of the asset return component of pension expense on a market-related valuation of assets, which reduces year-to-year volatility.
This market-related valuation recognizes investment gains or losses over a five-year period from the year in which they occur.
Investment gains or losses for this purpose are the difference between the expected return calculated using the market-related value of assets and the actual return based on the fair value of assets.
Since the market-related value of assets recognizes gains or losses over a fiveyear period, the future value of assets will be impacted as previously deferred gains or losses are recorded.
As of January 1, 2008, we had cumulative asset gains of approximately $3 million, which remain to be recognized in the calculation of the market-related value of assets.
Contributions—As a result of previous contributions made to the pension plan, there are no required contributions expected during 2009.
During January 2009, we made a voluntary contribution of $1 million to the pension plan.
We may make additional contributions to our pension plan during the year.
We expect to make cash contributions of approximately $2 million to the unfunded restoration plan and $1 million to the medical and life plans during 2009.
(4) Average crude oil sales prices reflect reductions of $1.32 per Bbl (2010), and $2.13 per Bbl (2009) from hedging activities.
Average natural gas sales prices reflect a decrease of $0.01 per Mcf (2010) from hedging activities.
The effect of hedging activities on the average realized natural gas price for 2009 was de minimis.
This price reduction resulted from losses that were previously deferred in AOCL.
All hedge losses relating to US production had been reclassified to revenues by December 31, 2010.
(5) Includes sales volumes through November 24, 2010.
Our Block 3 PSC was terminated by the Ecuadorian government on November 25, 2010.
Intercompany natural gas sales were eliminated for accounting purposes.
Electricity sales are included in other revenues.
See Exit from Ecuador above.
Revenues from sales of crude oil, natural gas and NGLs have accounted for 90% or more of consolidated revenues for each of the last three fiscal years.
At December 31, 2011, our operated properties accounted for approximately 67% of our total production.
Being the operator of a property improves our ability to directly influence production levels and the timing of projects, while also enhancing our control over operating expenses and capital expenditures.
Productive Wells The number of productive crude oil and natural gas wells in which we held an interest at December 31, 2011 was as follows:
## Table 4 ##
Productive wells are producing wells and wells mechanically capable of production.
A gross well is a well in which a working interest is owned.
The number of gross wells is the total number of wells in which a working interest is owned.
The number of net wells is the sum of the fractional working interests owned in gross wells expressed as whole numbers and fractions thereof.
Wells with multiple completions are counted as one well in the table above.
Developed and Undeveloped Acreage Developed and undeveloped acreage (including both leases and concessions) held at December 31, 2011 was as follows:
## Table 5 ##
(1) Includes approximately 464,000 gross (214,000 net) developed acres in the Marcellus Shale that are held by the production of others.
(2) A portion of the acreage has been assigned to a partner and the agreement is awaiting government approval.
(3) The North Sea includes acreage in the UK and the Netherlands.
(4) We funded a 2-D seismic survey over the acreage in return for a working interest in the concession.
Table of Contents Noble Energy, Inc.  Index to Financial Statements Notes to Consolidated Financial Statements 108 (3) Represents amount held in escrow at December 31, 2016 for the purchase of certain Permian Basin properties.
See Note 3.
Acquisitions, Divestitures and Merger.
Supplemental statements of cash flow information is as follows:

Tables referenced above, in order (Table 0 first):
<table><tr><td>Year</td><td>Gallons</td><td>Average Price per Gallon</td><td>Aircraft Fuel Expense</td><td>Percent of Total Mainline Operating Expenses</td></tr><tr><td>2014</td><td>3,644</td><td>$2.91</td><td>$10,592</td><td>33.2%</td></tr><tr><td>2013 (a)</td><td>3,608</td><td>3.08</td><td>11,109</td><td>35.4</td></tr><tr><td>2012 (a)</td><td>3,512</td><td>3.19</td><td>11,194</td><td>35.8</td></tr></table>
<table><tr><td></td><td>2008</td><td>2007</td></tr><tr><td>Health care cost trend rate assumed for next year</td><td>8%</td><td>9%</td></tr><tr><td>Rate to which the cost trend rate is assumed to decline (ultimate trend rate)</td><td>5%</td><td>5%</td></tr><tr><td>Year rate reaches ultimate trend rate</td><td>2012</td><td>2012</td></tr></table>
<table><tr><td></td><td>1% Increase</td><td>1% Decrease</td></tr><tr><td></td><td colspan="2">(in millions)</td></tr><tr><td>Effect on total service and interest cost components for 2008</td><td>$-</td><td>$-</td></tr><tr><td>Effect on year-end 2008 postretirement benefit obligation</td><td>2</td><td>-2</td></tr></table>
<table><tr><td></td><td>Target Allocation</td><td colspan="2">Plan Assets</td></tr><tr><td></td><td>2009</td><td>2008</td><td>2007</td></tr><tr><td>Asset Category</td><td></td><td></td><td></td></tr><tr><td>Equity securities</td><td>70%</td><td>65%</td><td>70%</td></tr><tr><td>Fixed income</td><td>30%</td><td>35%</td><td>30%</td></tr><tr><td>Total</td><td>100%</td><td>100%</td><td>100%</td></tr></table>
<table><tr><td></td><td colspan="2">Crude Oil Wells</td><td colspan="2">Natural Gas Wells</td><td colspan="2">Total</td></tr><tr><td></td><td>Gross</td><td>Net</td><td>Gross</td><td>Net</td><td>Gross</td><td>Net</td></tr><tr><td>United States</td><td>6,953</td><td>6,163.0</td><td>7,181</td><td>5,327.7</td><td>14,134</td><td>11,490.7</td></tr><tr><td>Equatorial Guinea</td><td>4</td><td>1.6</td><td>14</td><td>5.0</td><td>18</td><td>6.6</td></tr><tr><td>Israel</td><td>-</td><td>-</td><td>3</td><td>1.4</td><td>3</td><td>1.4</td></tr><tr><td>North Sea</td><td>18</td><td>4.0</td><td>9</td><td>1.0</td><td>27</td><td>5.0</td></tr><tr><td>China</td><td>24</td><td>13.7</td><td>1</td><td>0.6</td><td>25</td><td>14.3</td></tr><tr><td>Total</td><td>6,999</td><td>6,182.3</td><td>7,208</td><td>5,335.7</td><td>14,207</td><td>11,518.0</td></tr></table>
<table><tr><td></td><td colspan="2">Developed Acreage</td><td colspan="2">Undeveloped Acreage</td></tr><tr><td></td><td>Gross</td><td>Net</td><td>Gross</td><td>Net</td></tr><tr><td>(thousands of acres)</td><td></td><td></td><td></td><td></td></tr><tr><td>United States</td><td></td><td></td><td></td><td></td></tr><tr><td>Onshore-1</td><td>2,065</td><td>1,305</td><td>1,890</td><td>1,351</td></tr><tr><td>Offshore</td><td>119</td><td>57</td><td>481</td><td>363</td></tr><tr><td>Total United States</td><td>2,184</td><td>1,362</td><td>2,371</td><td>1,714</td></tr><tr><td>International</td><td></td><td></td><td></td><td></td></tr><tr><td>Equatorial Guinea</td><td>285</td><td>119</td><td>307</td><td>137</td></tr><tr><td>Senegal/Guinea-Bissau</td><td>-</td><td>-</td><td>2,431</td><td>729</td></tr><tr><td>Cameroon</td><td>-</td><td>-</td><td>1,125</td><td>563</td></tr><tr><td>Israel</td><td>185</td><td>80</td><td>1,469</td><td>652</td></tr><tr><td>Cyprus-2</td><td>-</td><td>-</td><td>852</td><td>596</td></tr><tr><td>North Sea-3</td><td>36</td><td>6</td><td>147</td><td>29</td></tr><tr><td>China</td><td>7</td><td>4</td><td>-</td><td>-</td></tr><tr><td>France-4</td><td>-</td><td>-</td><td>2,808</td><td>2,036</td></tr><tr><td>Nicaragua</td><td>-</td><td>-</td><td>1,977</td><td>1,977</td></tr><tr><td>India</td><td>-</td><td>-</td><td>694</td><td>347</td></tr><tr><td>Total International</td><td>513</td><td>209</td><td>11,810</td><td>7,066</td></tr><tr><td>Total</td><td>2,697</td><td>1,571</td><td>14,181</td><td>8,780</td></tr></table>

Question: In which section is United States greater than 7000？
Answer: Natural Gas Wells in Gross