6 5 - RR DONNELLEY FINANCIAL - External Home Login
6 5 - RR DONNELLEY FINANCIAL - External Home Login
6 5 - RR DONNELLEY FINANCIAL - External Home Login
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and oil business activities: the successful efforts method and the full-cost method. Chesapeake follows the fullcost<br />
method of accounting under which all costs associated with property acquisition, exploration and<br />
development activities are capitalized. We also capitalize internal costs that can be directly identified with our<br />
acquisition, exploration and development activities and do not include any costs related to production, general<br />
corporate overhead or similar activities.<br />
Under the successful efforts method, geological and geophysical costs and costs of carrying and retaining<br />
undeveloped properties are charged to expense as incurred. Costs of drilling exploratory wells that do not<br />
result in proved reserves are charged to expense. Depreciation, depletion, amortization and impairment of<br />
natural gas and oil properties are generally calculated on a well by well or lease or field basis versus the<br />
aggregated “full-cost” pool basis. Additionally, gain or loss is generally recognized on all sales of natural gas<br />
and oil properties under the successful efforts method. As a result, our financial statements will differ from<br />
companies that apply the successful efforts method since we will generally reflect a higher level of capitalized<br />
costs as well as a higher natural gas and oil depreciation, depletion and amortization rate, and we will not have<br />
exploration expenses that successful efforts companies frequently have.<br />
Under the full-cost method, capitalized costs are amortized on a composite unit-of-production method<br />
based on proved natural gas and oil reserves. If we maintain the same level of production year over year, the<br />
depreciation, depletion and amortization expense may be significantly different if our estimate of remaining<br />
reserves or future development costs changes significantly. Proceeds from the sale of properties are<br />
accounted for as reductions of capitalized costs unless such sales involve a significant change in proved<br />
reserves and significantly alter the relationship between costs and proved reserves, in which case a gain or<br />
loss is recognized. The costs of unproved properties are excluded from amortization until the properties are<br />
evaluated. We review all of our unevaluated properties quarterly to determine whether or not and to what<br />
extent proved reserves have been assigned to the properties, and otherwise if impairment has occurred.<br />
Unevaluated properties are grouped by major producing area where individual property costs are not significant<br />
and are assessed individually when individual costs are significant.<br />
We review the carrying value of our natural gas and oil properties under the full-cost accounting rules of<br />
the Securities and Exchange Commission on a quarterly basis. This quarterly review is referred to as a ceiling<br />
test. Under the ceiling test, capitalized costs, less accumulated amortization and related deferred income taxes,<br />
may not exceed an amount equal to the sum of the present value of estimated future net revenues (adjusted<br />
for cash flow hedges) less estimated future expenditures to be incurred in developing and producing the proved<br />
reserves, less any related income tax effects. For 2010 and 2009, in calculating estimated future net revenues,<br />
current prices are calculated as the unweighted arithmetic average of natural gas and oil prices on the first day<br />
of each month within the 12-month period ended. Costs used are those as of the end of the appropriate<br />
quarterly period. For 2008, current prices and costs used are those as of the end of the appropriate quarterly<br />
period. Such prices are utilized except where different prices are fixed and determinable from applicable<br />
contracts for the remaining term of those contracts, including the effects of derivatives qualifying as cash flow<br />
hedges.<br />
Two primary factors impacting this test are reserve levels and natural gas and oil prices, and their<br />
associated impact on the present value of estimated future net revenues. Revisions to estimates of natural gas<br />
and oil reserves and/or an increase or decrease in prices can have a material impact on the present value of<br />
estimated future net revenues. Any excess of the net book value, less deferred income taxes, is generally<br />
written off as an expense.<br />
Income Taxes. As part of the process of preparing the consolidated financial statements, we are required<br />
to estimate the federal and state income taxes in each of the jurisdictions in which Chesapeake operates. This<br />
process involves estimating the actual current tax exposure together with assessing temporary differences<br />
resulting from differing treatment of items, such as derivative instruments, depreciation, depletion and<br />
amortization, and certain accrued liabilities for tax and accounting purposes. These differences and our net<br />
operating loss carryforwards result in deferred tax assets and liabilities, which are included in our consolidated<br />
balance sheet. We must then assess, using all available positive and negative evidence, the likelihood that the<br />
deferred tax assets will be recovered from future taxable income. If we believe that recovery is not likely, we<br />
must establish a valuation allowance. Generally, to the extent Chesapeake establishes a valuation allowance<br />
or increases or decreases this allowance in a period, we must include an expense or reduction of expense<br />
within the tax provision in the consolidated statement of operations.<br />
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