88 <strong>Denbury</strong> <strong>Resources</strong> Inc. <strong>2009</strong> <strong>Annual</strong> <strong>Report</strong>Unevaluated Oil and Natural Gas Properties Excluded From DepletionUnder full cost accounting, we may exclude certain unevaluated costs from the amortization base pendingdetermination of whether proved reserves can be assigned to such properties. We assign the purchase price of oil andnatural gas properties we acquire to proved and unevaluated properties based on the estimated fair values as definedin the FASC “Fair Value Measurements and Disclosures” topic. The costs classified as unevaluated are transferred tothe full cost amortization base as the properties are developed, tested and evaluated. A summary of the unevaluatedproperties excluded from oil and natural gas properties being amortized at December 31, <strong>2009</strong>, and the year in whichthey were incurred follows:December 31, <strong>2009</strong>Costs Incurred During:In thousands <strong>2009</strong> 2008 2007 2006 and prior TotalProperty acquisition costs $ 95,477 $ 2,573 $ 31,042 $ 70,350 $ 199,442Exploration and development 68,530 21,898 2,645 — 93,073Capitalized interest 12,477 7,442 5,341 2,581 27,841Total $ 176,484 $ 31,913 $ 39,028 $ 72,931 $ 320,356Property acquisition costs for <strong>2009</strong> are primarily for CO 2 tertiary potential at Conroe Field. Property acquisition costsfor 2007 are primarily for CO 2 tertiary oil field candidates acquired in the Seabreeze Complex. Property acquisitioncosts for 2006 and prior are primarily for Delhi Field, South Cypress Creek Field, and Citronelle Field. We commencedCO 2 injection at Delhi Field in November <strong>2009</strong> and we plan to commence CO 2 injection at Seabreeze in mid-2010. SeeNote 2, “Acquisitions and Divestitures.” Exploration and development costs are primarily associated with our CO 2tertiary oil fields that are under development and did not have proved reserves at December 31, <strong>2009</strong>. During <strong>2009</strong>, weestablished proved reserves at Cranfield Field and as a result we transferred $82.4 million of costs incurred on thisproject into the amortization base. Costs are transferred into the amortization base on an ongoing basis as the projectsare evaluated and proved reserves established or impairment determined. We review the excluded properties forimpairment at least annually. We currently estimate that evaluation of most of these properties and the inclusion of theircosts in the amortization base is expected to be completed within five years. Until we are able to determine whetherthere are any proved reserves attributable to the above costs, we are not able to assess the future impact on theamortization rate of the full cost pool.Full Cost Ceiling TestIn 2008 the Company recognized a write-down of its oil and natural gas properties of $226 million under the full costceiling test at December 31, 2008. In accordance with the full cost ceiling rules at December 31, 2008, the ceiling limitwas calculated utilizing the unescalated period-end prices, which were a NYMEX WTI oil price per Bbl of $44.60 anda Henry Hub cash price per M<strong>MB</strong>tu of $5.71. We included the portion of net capitalized cost of CO 2 assets and CO 2pipelines that were required for our proved tertiary reserves in the net capitalized costs subject to this ceiling test. Thefair value of our oil derivative contracts at December 31, 2008 of $249.7 million, which contracts had a floor price of$75.00 per barrel on 30,000 barrels per day for calendar year <strong>2009</strong>, was not included in the ceiling test as we did notdesignate these contracts as hedge instruments for accounting purposes.Because oil prices have recovered during <strong>2009</strong> from their year-end 2008 levels, we did not have a ceiling testwrite-down during <strong>2009</strong>. However, if oil prices were to decrease significantly in subsequent periods, we may berequired to record additional write-downs under the full cost pool ceiling test in the future. The possibility and amountof any future write-down is difficult to predict, and will depend upon oil and natural gas prices, the incremental provedreserves that may be added each period, revisions to previous reserve estimates and future capital expenditures,and additional capital spent. The SEC adopted major revisions to its rules governing oil and gas company reportingrequirements which are effective for us beginning with this December 31, <strong>2009</strong>, Form 10-K. Under these new rules,the full cost ceiling value is calculated using an average price based on the first day of every month during the period.Form 10-K Part IINotes to Consolidated Financial Statements
<strong>Denbury</strong> <strong>Resources</strong> Inc. <strong>2009</strong> <strong>Annual</strong> <strong>Report</strong> 89Note 6. Long-Term DebtDecember 31,In thousands <strong>2009</strong> 20089.75% Senior Subordinated Notes due 2016 $ 426,350 $ —Discount on Senior Subordinated Notes due 2016 (26,424) —7.5% Senior Subordinated Notes due 2015 300,000 300,000Premium on Senior Subordinated Notes due 2015 513 5997.5% Senior Subordinated Notes due 2013 225,000 225,000Discount on Senior Subordinated Notes due 2013 (631) (826)NEJD financing – Genesis 170,633 173,618Free State financing – Genesis 79,987 76,634Senior bank loan 125,000 75,000Capital lease obligations – Genesis 3,780 4,544Capital lease obligations 2,168 2,705Total 1,306,376 857,274Less current obligations 5,308 4,507Long-term debt and capital lease obligations $ 1,301,068 $ 852,7679.75% Senior Subordinated Notes due 2016On February 13, <strong>2009</strong>, we issued $420 million of 9.75% Senior Subordinated Notes due 2016 (“2016 Notes”). The2016 Notes, which carry a coupon rate of 9.75%, were sold at a discount (92.816% of par), which equates to aneffective yield to maturity of approximately 11.25%. The net proceeds of $381.4 million were used to repay most of ourthen-outstanding borrowings under our bank credit facility, which increased from the December 31, 2008 balance,primarily associated with the funding of the Hastings Field acquisition (see Note 2, “Acquisitions and Divestitures”). Inconjunction with this debt offering we amended our bank credit facility in early February <strong>2009</strong>, which, among otherthings, allowed us to issue these senior subordinated notes.In June <strong>2009</strong>, we issued an additional $6.35 million of 2016 Notes to our founder, Gareth Roberts, as part of aFounder’s Retirement Agreement. In connection with this issuance, we recorded compensation expense of$6.35 million in “General and administrative” expense in our Consolidated Statement of Operations during the yearended December 31, <strong>2009</strong>.The 2016 Notes mature on March 1, 2016, and interest on the 2016 Notes is payable March 1 and September 1 ofeach year. We may redeem the 2016 Notes in whole or in part at our option beginning March 1, 2013, at the followingredemption prices: 104.875% after March 1, 2013, 102.4375% after March 1, 2014, and 100% after March 1, 2015. Inaddition, we may at our option, redeem up to an aggregate of 35% of the 2016 Notes before March 1, 2012, at a priceof 109.75%. The indenture contains certain restrictions on our ability to incur additional debt, pay dividends on ourcommon stock, make investments, create liens on our assets, engage in transactions with our affiliates, transfer or sellassets, consolidate or merge, or sell substantially all of our assets. The 2016 Notes are not subject to any sinking fundrequirements. All of our significant subsidiaries fully and unconditionally guarantee this debt.NEJD Financing and Free State FinancingOn May 30, 2008, we closed on two transactions with Genesis involving two of our pipelines. The two transactionshave been recorded as financing leases. See Note 3, “Related Party Transactions – Genesis – NEJD Pipeline and FreeState Pipeline Transactions.”7.5% Senior Subordinated Notes due 2015On April 3, 2007, we issued $150 million of Senior Subordinated Notes due 2015 as an additional issuance under ourexisting indenture governing our December 2005 sale of $150 million of 7.5% Senior Subordinated Notes due 2015(collectively, the “2015 Notes”) discussed below. These notes, which carry a coupon rate of 7.5%, were sold at 100.5%of par, which equates to an effective yield to maturity of approximately 7.4%. Net proceeds from the sale wereapproximately $149.2 million. The net proceeds were used to repay a portion of the outstanding borrowings under ourbank credit facility.Notes to Consolidated Financial StatementsForm 10-K Part II