OREANDA-NEWS. Denbury Resources Inc. (NYSE:DNR) (“Denbury” or the “Company”) today announced a net loss of $381 million, or $1.03 per diluted share, for the second quarter of 2016.  The Company also reported adjusted net income(1) (a non-GAAP measure) for the quarter of $29 million, or $0.08(1)(2) per diluted share.  Adjusted net income(1) for the second quarter of 2016 differs from the quarter’s GAAP net loss primarily due to the exclusion of (1) a $479 million ($299 million after tax) full cost pool ceiling test write-down, (2) a $150 million ($93 million after tax) loss due to noncash fair value adjustments on commodity derivatives(1) (a non-GAAP measure) and (3) a $28 million ($17 million after tax) payment related to a previously announced legal settlement, with the GAAP and non-GAAP measures reconciled in tables beginning on page 8.

Sequential and year-over-year comparisons of selected quarterly financial items are shown in the following table:

    Quarter Ended
($ in millions, except per-share and unit data)   June 30, 2016   March 31, 2016   June 30, 2015
Net loss   $ (381 )   $ (185 )   $ (1,148 )
Adjusted net income (loss)(1) (non-GAAP measure)   29     (9 )   47  
Net loss per diluted share   (1.03 )   (0.53 )   (3.28 )
Adjusted net income (loss) per diluted share(1)(2) (non-GAAP measure)   0.08     (0.03 )   0.13  
Cash flows from operations   61     2     289  
Adjusted cash flows from operations(1)(3)(4) (non-GAAP measure)   93     57     252  
             
Revenues   $ 253     $ 194     $ 374  
Receipt on settlements of commodity derivatives   52     72     124  
Total   $ 305     $ 266     $ 498  
             
Average realized oil price per barrel (excluding derivative settlements)   $ 43.38     $ 30.71     $ 56.92  
Average realized oil price per barrel (including derivative settlements)   52.61     42.71     76.30  
Lease operating expenses per BOE   17.04     16.23     19.70  
             
Total production (BOE/d)   64,506     69,351     73,716  

(1)  A non-GAAP measure.  See accompanying schedules that reconcile GAAP to non-GAAP measures along with a statement indicating why the Company believes the non-GAAP measures provide useful information for investors.
(2)  Calculated using average diluted shares outstanding of 372.4 million and 351.1 million for the three months ended June 30, 2016 and 2015, respectively.
(3)  Adjusted cash flow from operations for the three-month period ended June 30, 2016 includes a $28 million payment to Evolution in connection with our settlement agreement to resolve all outstanding disputes and claims, and the three-month period ended March 31, 2016 includes severance-related payments associated with the 2016 workforce reduction of approximately $9 million.  Excluding these payments, adjusted cash flows from operations would have totaled $121 million and $66 million for the three months ended June 30, 2016 and March 31, 2016, respectively.
(4)  Adjusted cash flows from operations reflects cash flows from operations before working capital changes.

MANAGEMENT COMMENT

Phil Rykhoek, Denbury’s President and CEO, commented, “During the second quarter of 2016, we continued to make significant strides in our core objectives for 2016, which include lowering costs, preserving cash and liquidity, and reducing leverage.  We have continued to steadily improve our business, working towards maximizing our efficiency and shaping the path for the future of the Company.  Our overall cash costs per barrel of oil equivalent (“BOE”) were reduced by another $0.60 this quarter to approximately $32 per BOE, as reductions in general and administrative costs more than offset a slight increase in unit operating expenses.  Lease operating expenses totaled $100 million during the second quarter of 2016, a 24% decrease from the prior-year quarter, and general and administrative expenses totaled $23 million, a decrease of 41% from the prior-year quarter, further evidencing the success of our cost reduction efforts.

“Our 2016 production remains on track to meet the mid-point of our 2016 guidance when adjusted for extraordinary weather-related downtime and our pending asset sale.  During the second quarter, we experienced two separate 100-year flood events at Thompson Field, resulting in minimal production there this quarter which, coupled with weather-related production downtime at Conroe Field, negatively impacted our second quarter production by approximately 1,450 BOE/d.  Also, in the third quarter, we expect to close on the sale of our non-core Williston assets, which produced approximately 1,300 BOE/d in the first half of the year.  After adjusting for these two items, the mid-point of our full-year guidance is now approximately 1,000 BOE/d lower than our previous guidance.

“During the first half of 2016, we entered into debt exchange and purchase transactions, resulting in a net reduction of our debt principal balance of approximately $540 million, and have recently reduced debt by another $5 million through open-market debt purchases.  We remain focused on preserving our liquidity in this low oil price environment and continue to look for opportunities to reduce debt and enhance our balance sheet.”

DEBT REDUCTION

As previously disclosed, during May 2016, the Company entered into privately negotiated exchange agreements to exchange $1,058 million in aggregate principal amount of its outstanding senior subordinated notes for $615 million in aggregate principal amount of the Company’s new 9% Senior Secured Second Lien Notes due 2021 (“Senior Secured Notes”) plus 40.7 million shares of the Company’s common stock, resulting in a $12 million pre-tax gain on debt extinguishment.  For financial reporting purposes, $255 million of future interest on the Senior Secured Notes has been recorded as debt, and will be reduced as semi-annual interest payments are made, with the remaining $23 million of future interest to be recognized as interest expense over the term of the Senior Secured Notes.  Therefore, future interest expense on the Senior Secured Notes reflected in the Company’s financial statements will be significantly lower than the actual cash interest payments to be made, and management currently anticipates that for the remainder of 2016 approximately $13 million of interest per quarter on the Senior Secured Notes will not be reflected as interest expense.

In July 2016, the Company spent $14 million (excluding accrued interest) to repurchase an additional $3 million principal amount of senior subordinated notes due 2021 and $16 million principal amount of senior subordinated notes due 2022.  These transactions resulted in a net reduction of approximately $5 million in the Company’s debt principal balance.

PRODUCTION

Denbury’s total production for the second quarter of 2016 averaged 64,506 BOE per day (“BOE/d”), including 39,212 barrels per day (“Bbls/d”) from tertiary properties and 25,294 BOE/d from non-tertiary properties.  Production in the second quarter of 2016 decreased 7% sequentially and 12% compared to the second quarter of 2015.  The higher than anticipated decline was primarily due to weather-related shut-in production.

In April 2016, a series of strong thunderstorms in the Houston area damaged a primary tank battery in Conroe Field and flooded Thompson Field.  While most of the Conroe production was brought back online in June, additional record rainfall in May 2016 flooded Thompson Field a second time, forcing most of that field to remain shut in through the end of the quarter.  The Company is currently working to restore full production, most of which is expected to be back online during the third quarter.  Together, these storms and flooding impacted quarterly production by approximately 1,450 BOE/d.

During the second quarter, the Company’s quarterly production was further impacted by production shut-in due to economics, resulting in a decrease to quarterly production of approximately 2,750 BOE/d, representing an incremental decrease of approximately 300 BOE/d compared to the first quarter of 2016 and approximately 2,100 BOE/d compared to the second quarter of 2015.  As of June 30, 2016, approximately 2,600 BOE/d remained shut in due to economics.  Second quarter of 2016 production was 96% oil, similar to the prior-year period.

Tertiary oil production during the second quarter of 2016 decreased 3%, or 1,252 Bbls/d, on a sequential-quarter basis and 8%, or 3,372 Bbls/d, from the second quarter of 2015.  The decreases during both periods were largely driven by Tinsley Field facility seasonal processing constraints and Oyster Bayou Field maintenance and workovers, partially offset by increased production at Delhi and Bell Creek fields.

Non-tertiary oil-equivalent production was down 12%, or 3,593 BOE/d, on a sequential-quarter basis and 19%, or 5,838 BOE/d, from second quarter of 2015.  These decreases were greater than anticipated primarily due to the previously discussed weather-related shut-in production at Conroe and Thompson fields.

REVIEW OF FINANCIAL RESULTS

Oil and natural gas revenues, excluding the impact of derivative contracts, decreased 33% when comparing the second quarters of 2016 and 2015, due to a 21% decline in realized commodity prices and a 12% decrease in production.  Denbury’s average realized oil price per Bbl, excluding derivative settlements, was $43.38 in the second quarter of 2016, compared to $30.71 in the first quarter of 2016 and $56.92 in the prior-year second quarter.  Including derivative settlements, Denbury’s average realized oil price per Bbl was $52.61 in the second quarter of 2016, compared to $42.71 in the first quarter of 2016 and $76.30 in the prior-year second quarter.  The oil price realized relative to NYMEX oil prices (the Company’s NYMEX oil price differential) in the second quarter of 2016 was $2.18 per Bbl below NYMEX prices, compared to a differential of $3.02 per Bbl below NYMEX in the first quarter of 2016 and $0.89 per Bbl below NYMEX in the second quarter of 2015, largely due to volatility in oil sold at the Light Louisiana Sweet index.

The Company’s lease operating expenses over the past two years have decreased across all expense categories, and total lease operating expenses decreased 24% from the second quarter of 2015, significantly impacted by the reduction in CO2 injection volumes over the past year.  During the second quarter of 2016, the Company’s CO2 use further declined to 459 million cubic feet per day, a decrease of 40% when compared to the second quarter of 2015.  On a per-BOE basis, lease operating expenses in the second quarter of 2016 averaged $17.04 per BOE, an increase of 5% from the $16.23 per-BOE average in the first quarter of 2016, primarily due to a higher workover activity level and lower production volumes, and decreased 14% from the $19.70 per-BOE average in the second quarter of 2015 due to cost decreases in most lease operating expense categories, partially offset by the reduction in production volumes.

Taxes other than income, which includes ad valorem, production, and franchise taxes, were relatively unchanged on a sequential-quarter basis and decreased $14 million from the prior-year second quarter level due primarily to lower ad valorem taxes in the 2016 period due to lower assessed tax values and a decrease in severance taxes due to lower oil and natural gas revenues.

General and administrative expenses were $23 million in the second quarter of 2016, decreasing $15 million, or 41%, from the prior-year second quarter level.  This reduction was largely due to an approximate 28% reduction in headcount since March 31, 2015, which has resulted in lower employee compensation and related costs.

Interest expense, net of capitalized interest, decreased to $36 million in the second quarter of 2016, compared to $40 million in the second quarter of 2015.  As a result of the Company’s notes exchange discussed above, interest expense in the second quarter of 2016 excludes approximately $7 million of interest on the Company’s new Senior Secured Notes because it is recorded as debt for financial reporting purposes and is therefore not reflected as interest expense.  Cash interest expense decreased approximately $3 million between the respective quarters.

As a result of the continued decrease in average commodity pricing compared to 2015 levels, the Company recognized a full cost pool ceiling test write-down of $479 million during the second quarter of 2016, compared to $256 million during the first quarter of 2016 and $1.7 billion during the second quarter of 2015.  In determining these write-downs, the Company is required to use the average rolling first-day-of-the-month NYMEX oil and natural gas prices for the preceding 12 months, adjusted for market differentials by field.  The preceding 12-month NYMEX prices averaged $43.12 per Bbl for crude oil for the period ended June 30, 2016, down from $46.26 per Bbl for the period ended March 31, 2016 and $71.68 per Bbl for the period ended June 30, 2015.

Denbury’s overall depletion, depreciation, and amortization (“DD&A”) rate was $11.34 per BOE in the second quarter of 2016, compared to $22.05 per BOE in the prior-year second quarter and $12.26 per BOE in the first quarter of 2016, with the decreases primarily driven by a reduction in depletable costs resulting from the full cost pool ceiling test write-downs recognized during 2015 and the first quarter of 2016, as well as lower production and reductions in future development costs.

Receipts on settlements of oil and natural gas derivative contracts were $52 million in the second quarter of 2016, compared to receipts of $72 million in the first quarter of 2016 and receipts of $124 million in the prior-year second quarter.  These settlements resulted in increases in average net realized prices of $8.86 per BOE in the second quarter of 2016, $11.44 per BOE in the first quarter of 2016, and $18.51 per BOE in the second quarter of 2015.

Denbury’s effective tax rate for the second quarter of 2016 was 36.9%, up from 35.6% in the prior-year second quarter.  The effective tax rate for the second quarter of 2016 was lower than the Company’s statutory rate of 38% primarily due to the Company’s full cost pool ceiling test write-down recorded during the quarter.

2016 CAPITAL BUDGET AND ESTIMATED PRODUCTION

The Company’s 2016 capital budget, excluding acquisitions and capitalized interest, remains unchanged from the previously estimated amount of approximately $200 million; however, the Company could potentially adjust this budget higher or lower based on changes in estimated levels of cash flow.  The capital budget consists of approximately $145 million of tertiary, non-tertiary, and CO2 supply and pipeline projects, plus approximately $55 million of estimated capitalized costs (including capitalized internal acquisition, exploration and development costs and pre-production tertiary startup costs).  Of this combined capital expenditure amount, approximately $101 million (50%) has been incurred through the second quarter of 2016.

The Company expects to close the sale of its interests in non-core Williston assets in the third quarter for $58 million (before final closing adjustments) with an effective date of April 1, 2016.  Production from the Williston assets averaged approximately 1,300 BOE/d during the first half of 2016.  As a result of this pending sale and the impacts of extraordinary weather-related downtime in the Gulf Coast region, Denbury now expects full-year 2016 production to range between 64,000 BOE/d and 66,000 BOE/d, as compared to the Company’s previous guidance of between 64,000 BOE/d and 68,000 BOE/d, with production for the remainder of the year anticipated to be relatively flat after adjusting for the Williston asset sale.

DENBURY RESOURCES INC.
CONSOLIDATED STATEMENTS OF OPERATIONS (UNAUDITED)

The following information is based on GAAP reported earnings (along with additional required disclosures) included or to be included in the Company’s periodic reports:

    Three Months Ended   Six Months Ended
    June 30,   March 31,   June 30,
In thousands, except per-share data   2016   2015   2016   2016   2015
Revenues and other income                    
Oil sales   $ 244,572     $ 361,732     $ 184,816     $ 429,388     $ 654,002  
Natural gas sales   2,096     5,159     2,987     5,083     10,359  
CO2 sales and transportation fees   6,622     7,152     6,272     12,894     14,124  
Interest income and other income   1,858     2,651     769     2,627     5,858  
Total revenues and other income   255,148     376,694     194,844     449,992     684,343  
Expenses                    
Lease operating expenses   100,019     132,170     102,447     202,466     273,254  
Marketing and plant operating expenses   12,999     14,215     13,194     26,193     25,900  
CO2 discovery and operating expenses   1,071     945     607     1,678     1,892  
Taxes other than income   19,504     33,555     20,092     39,596     60,234  
General and administrative expenses   22,545     37,947     33,901     56,446     84,227  
Interest, net of amounts capitalized of $6,289, $8,738, $5,780, $12,069 and $17,147, respectively   36,058     39,863     42,171     78,229     79,962  
Depletion, depreciation, and amortization   66,541     147,940     77,366     143,907     297,898  
Commodity derivatives expense (income)   98,209     48,926     22,826     121,035     (34,150 )
Gain on debt extinguishment   (12,278 )   —     (94,991 )   (107,269 )   —  
Write-down of oil and natural gas properties   479,400     1,705,800     256,000     735,400     1,852,000  
Other expenses   34,688     —     1,544     36,232     —  
Total expenses   858,756     2,161,361     475,157     1,333,913     2,641,217  
Loss before income taxes   (603,608 )   (1,784,667 )   (280,313 )   (883,921 )   (1,956,874 )
Income tax benefit                    
Current income taxes   —     (1,696 )   (5 )   (5 )   (121 )
Deferred income taxes   (222,940 )   (634,472 )   (95,115 )   (318,055 )   (700,508 )
Net loss   $ (380,668 )   $ (1,148,499 )   $ (185,193 )   $ (565,861 )   $ (1,256,245 )
                     
Net loss per common share                    
Basic   $ (1.03 )   $ (3.28 )   $ (0.53 )   $ (1.58 )   $ (3.59 )
Diluted   $ (1.03 )   $ (3.28 )   $ (0.53 )   $ (1.58 )   $ (3.59 )
                     
Dividends declared per common share   $ —     $ 0.0625     $ —     $ —     $ 0.1250  
                     
Weighted average common shares outstanding                    
Basic   370,566     350,039     347,235     358,901     349,653  
Diluted   370,566     350,039     347,235     358,901     349,653  
 

DENBURY RESOURCES INC.
SUPPLEMENTAL NON-GAAP FINANCIAL MEASURES (UNAUDITED)

Reconciliation of net loss (GAAP measure) to adjusted net income (loss) (non-GAAP measure)

Adjusted net income (loss) is a non-GAAP measure provided as a supplement to present an alternative net income (loss) measure which excludes expense and income items (and their related tax effects) not directly related to the Company’s ongoing operations.  Management believes that adjusted net income (loss) may be helpful to investors by eliminating the impact of noncash and/or nonrecurring items not indicative of our performance from period to period, and is widely used by the investment community, while also being used by management, in evaluating the comparability of the Company’s ongoing operational results and trends.  Adjusted net income (loss) should not be considered in isolation, as a substitute for, or more meaningful than, net income or any other measure reported in accordance with GAAP, but rather to provide additional information useful in evaluating the Company’s operational trends and performance.

    Three Months Ended   Six Months Ended
    June 30,   March 31,   June 30,
In thousands, except per-share data   2016   2015   2016   2016   2015
Net loss (GAAP measure)   $ (380,668 )   $ (1,148,499 )   $ (185,193 )   $ (565,861 )   $ (1,256,245 )
Adjustments to reconcile to adjusted net income (loss) (non-GAAP measure)                    
Noncash fair value adjustments on commodity derivatives (1)   150,235     173,077     95,053     245,288     238,466  
Write-down of oil and natural gas properties (2)   479,400     1,705,800     256,000     735,400     1,852,000  
Gain on debt extinguishment (3)   (12,278 )   —     (94,991 )   (107,269 )   —  
Legal settlements included in other expenses (4)   30,250     —     —     30,250     —  
Write-off of debt issuance costs included in interest expense (5)   4,509     —     1,044     5,553     —  
Severance-related payments included in general and administrative expenses (6)   —     —     9,315     9,315     —  
Transaction costs and other (7)   4,531     —     1,107     5,638     —  
Estimated income taxes on above adjustments to net loss and other discrete tax items (8)   (247,178 )   (683,473 )   (91,432 )   (338,610 )   (763,877 )
Adjusted net income (loss) (non-GAAP measure)   $ 28,801     $ 46,905     $ (9,097 )   $ 19,704     $ 70,344  
                     
Adjusted net income (loss) per common share                    
Basic   $ 0.08     $ 0.13     $ (0.03 )   $ 0.05     $ 0.20  
Diluted   $ 0.08     $ 0.13     $ (0.03 )   $ 0.05     $ 0.20  

(1)  The net change between periods of the fair market values of open commodity derivative positions, excluding the impact of settlements on commodity derivatives during the period.
(2)  Full cost pool ceiling test write-downs related to the Company’s oil and natural gas properties.
(3)  Gain on extinguishment related to the Company’s debt exchange.
(4)  Settlements related to previously outstanding litigation, the most significant of which pertaining to a $28 million payment to Evolution in connection with the settlement resolving all outstanding disputes and claims.
(5)  Write-off of debt issuance costs associated with the Company’s senior secured bank credit facility, related to reductions in the Company’s lender commitments resulting from (1) the May 2016 redetermination and (2) the February 2016 amendment.
(6)  Severance-related payments associated with the Company’s February-2016 workforce reduction.
(7)  Transaction costs related to the Company’s debt exchange during the three months ended June 30, 2016 and a loss on sublease during the three months ended March 31, 2016.
(8)  The estimated income tax impacts on adjustments to net loss are generally computed based upon a statutory rate of 38%, applicable to all periods presented, with the exception of the write-down on oil and natural gas properties, which are computed individually based upon the Company’s effective tax rate.  In addition, recorded valuation allowances of $30.5 million have been adjusted for the three and six months ended June 30, 2015.

DENBURY RESOURCES INC.
SUPPLEMENTAL NON-GAAP FINANCIAL MEASURES (UNAUDITED)

Reconciliation of cash flows from operations (GAAP measure) to adjusted cash flows from operations (non-GAAP measure)

Adjusted cash flows from operations is a non-GAAP measure that represents cash flows provided by operations before changes in assets and liabilities, as summarized from the Company’s Unaudited Condensed Consolidated Statements of Cash Flows.  Adjusted cash flows from operations measures the cash flows earned or incurred from operating activities without regard to the collection or payment of associated receivables or payables.  Management believes that it is important to consider this additional measure, along with cash flows from operations, as it believes the non-GAAP measure can often be a better way to discuss changes in operating trends in its business caused by changes in production, prices, operating costs and related factors, without regard to whether the earned or incurred item was collected or paid during that period.

    Three Months Ended   Six Months Ended
In thousands   June 30,   March 31,   June 30,
  2016   2015   2016   2016   2015
Net loss (GAAP measure)   $ (380,668 )   $ (1,148,499 )   $ (185,193 )   $ (565,861 )   $ (1,256,245 )
Adjustments to reconcile to adjusted cash flows from operations                    
Depletion, depreciation, and amortization   66,541     147,940     77,366     143,907     297,898  
Deferred income taxes   (222,940 )   (634,472 )   (95,115 )   (318,055 )   (700,508 )
Stock-based compensation   3,263     7,118     859     4,122     14,967  
Noncash fair value adjustments on commodity derivatives   150,235     173,077     95,053     245,288     238,466  
Gain on debt extinguishment   (12,278 )   —     (94,991 )   (107,269 )   —  
Write-down of oil and natural gas properties   479,400     1,705,800     256,000     735,400     1,852,000  
Other   9,439     620     2,890     12,329     482  
Adjusted cash flows from operations (non-GAAP measure) (1)   92,992     251,584     56,869     149,861     447,060  
Net change in assets and liabilities relating to operations   (32,077 )   37,373     (54,840 )   (86,917 )   (20,339 )
Cash flows from operations (GAAP measure)   $ 60,915     $ 288,957     $ 2,029     $ 62,944     $ 426,721  

(1)  The three and six-month periods ended June 30, 2016 include a $28 million payment to Evolution in connection with our settlement agreement to resolve all outstanding disputes and claims, and the three-month period ended March 31, 2016 includes severance-related payments associated with the 2016 workforce reduction of approximately $9 million.  Excluding these payments, adjusted cash flows from operations would have totaled $121 million and $66 million for the three months ended June 30, 2016 and March 31, 2016, respectively, and $187 million for the six months ended June 30, 2016.

DENBURY RESOURCES INC.
SUPPLEMENTAL NON-GAAP FINANCIAL MEASURES (UNAUDITED)

Reconciliation of commodity derivatives income (expense) (GAAP measure) to noncash fair value adjustments on commodity derivatives (non-GAAP measure)

Noncash fair value adjustments on commodity derivatives is a non-GAAP measure and is different from “Commodity derivatives expense (income)” in the Unaudited Condensed Consolidated Statements of Operations in that the noncash fair value adjustments on commodity derivatives represents only the net change between periods of the fair market values of open commodity derivative positions, and excludes the impact of settlements on commodity derivatives during the period.  Management believes that noncash fair value adjustments on commodity derivatives is a useful supplemental disclosure to “Commodity derivatives expense (income)” because the GAAP measure also includes settlements on commodity derivatives during the period; the non-GAAP measure is widely used within the industry and by securities analysts, banks and credit rating agencies in calculating EBITDA and in adjusting net income to present those measures on a comparative basis across companies, as well as to assess compliance with certain debt covenants.

    Three Months Ended   Six Months Ended
    June 30,   March 31,   June 30,
In thousands   2016   2015   2016   2016   2015
Receipt on settlements of commodity derivatives   $ 52,026     $ 124,151     $ 72,227     $ 124,253     $ 272,616  
Noncash fair value adjustments on commodity derivatives (non-GAAP measure)   (150,235 )   (173,077 )   (95,053 )   (245,288 )   (238,466 )
Commodity derivatives income (expense) (GAAP measure)   $ (98,209 )   $ (48,926 )   $ (22,826 )   $ (121,035 )   $ 34,150  
 

DENBURY RESOURCES INC.
OPERATING HIGHLIGHTS (UNAUDITED)

    Three Months Ended   Six Months Ended
    June 30,   March 31,   June 30,
    2016   2015   2016   2016   2015
Production (daily – net of royalties)                    
Oil (barrels)   61,952     69,837     66,139     64,045     70,199  
Gas (mcf)   15,328     23,273     19,270     17,299     23,014  
BOE (6:1)   64,506     73,716     69,351     66,929     74,034  
Unit sales price (excluding derivative settlements)                    
Oil (per barrel)   $ 43.38     $ 56.92     $ 30.71     $ 36.84     $ 51.47  
Gas (per mcf)   1.50     2.44     1.70     1.61     2.49  
BOE (6:1)   42.02     54.69     29.76     35.67     49.58  
Unit sales price (including derivative settlements)                    
Oil (per barrel)   $ 52.61     $ 76.30     $ 42.71     $ 47.50     $ 72.79  
Gas (per mcf)   1.50     2.89     1.70     1.61     2.90  
BOE (6:1)   50.88     73.20     41.20     45.87     69.92  
NYMEX differentials                    
Gulf Coast region                    
Oil (per barrel)   $ (1.22 )   $ 1.86     $ (1.95 )   $ (1.78 )   $ 0.79  
Gas (per mcf)   (0.69 )   (0.10 )   (0.26 )   (0.46 )   (0.17 )
Rocky Mountain region                    
Oil (per barrel)   $ (3.98 )   $ (6.48 )   $ (5.04 )   $ (4.73 )   $ (7.19 )
Gas (per mcf)   (0.80 )   (0.68 )   (0.34 )   (0.56 )   (0.51 )
Total company                    
Oil (per barrel)   $ (2.18 )   $ (0.89 )   $ (3.02 )   $ (2.81 )   $ (1.87 )
Gas (per mcf)   (0.73 )   (0.30 )   (0.29 )   (0.50 )   (0.29 )
 

DENBURY RESOURCES INC.
OPERATING HIGHLIGHTS (UNAUDITED)

    Three Months Ended   Six Months Ended
    June 30,   March 31,   June 30,
Average Daily Volumes (BOE/d) (6:1)   2016   2015   2016   2016   2015
Tertiary oil production                    
Gulf Coast region                    
Mature properties (1)   9,415     11,170     9,666     9,540     10,987  
Delhi   3,996     3,623     3,971     3,984     3,587  
Hastings   4,972     5,350     5,068     5,020     5,024  
Heidelberg   5,246     5,885     5,346     5,296     5,955  
Oyster Bayou   5,088     5,936     5,494     5,291     5,899  
Tinsley   7,335     8,740     7,899     7,617     8,833  
Total Gulf Coast region   36,052     40,704     37,444     36,748     40,285  
Rocky Mountain region                    
Bell Creek   3,160     1,880     3,020     3,090     1,922  
Total Rocky Mountain region   3,160     1,880     3,020     3,090     1,922  
Total tertiary oil production   39,212     42,584     40,464     39,838     42,207  
Non-tertiary oil and gas production                    
Gulf Coast region                    
Mississippi   1,280     1,400     978     1,129     1,580  
Texas   4,104     6,304     6,148     5,126     6,396  
Other   456     906     549     503     956  
Total Gulf Coast region   5,840     8,610     7,675     6,758     8,932  
Rocky Mountain region                    
Cedar Creek Anticline   16,325     18,089     17,778     17,052     18,304  
Other   3,129     4,433     3,434     3,281     4,591  
Total Rocky Mountain region   19,454     22,522     21,212     20,333     22,895  
Total non-tertiary production   25,294     31,132     28,887     27,091     31,827  
Total production   64,506     73,716     69,351     66,929     74,034  
Pending property sales                    
Williston Assets (2)   (1,267 )   (1,561 )   (1,364 )   (1,315 )   (1,602 )
Continuing production   63,239     72,155     67,987     65,614     72,432  

(1)  Total mature properties include Brookhaven, Cranfield, Eucutta, Little Creek, Lockhart Crossing, Mallalieu, Martinville, McComb and Soso fields.
(2)  Includes non-tertiary production in the Rocky Mountain region related to the sale of remaining non-core assets in the Williston Basin of North Dakota and Montana, expected to close in the third quarter of 2016.

DENBURY RESOURCES INC.
PER-BOE DATA (UNAUDITED)

    Three Months Ended   Six Months Ended
    June 30,   March 31,   June 30,
    2016   2015   2016   2016   2015
Oil and natural gas revenues   $ 42.02     $ 54.69     $ 29.76     $ 35.67     $ 49.58  
Receipt on settlements of commodity derivatives   8.86     18.51     11.44     10.20     20.34  
Lease operating expenses   (17.04 )   (19.70 )   (16.23 )   (16.62 )   (20.39 )
Production and ad valorem taxes   (2.90 )   (4.43 )   (2.72 )   (2.81 )   (3.93 )
Marketing expenses, net of third-party purchases, and plant operating expenses   (1.85 )   (1.86 )   (1.84 )   (1.84 )   (1.66 )
Production netback   29.09     47.21     20.41     24.60     43.94  
CO2 sales, net of operating and exploration expenses   0.95     0.93     0.89     0.92     0.91  
General and administrative expenses   (3.84 )   (5.66 )   (5.37 )   (4.63 )   (6.29 )
Interest expense, net   (6.14 )   (5.94 )   (6.68 )   (6.42 )   (5.97 )
Other   (4.22 )   0.97     (0.24 )   (2.16 )   0.77  
Changes in assets and liabilities relating to operations   (5.46 )   5.57     (8.69 )   (7.14 )   (1.52 )
Cash flows from operations   10.38     43.08     0.32     5.17     31.84  
DD&A   (11.34 )   (22.05 )   (12.26 )   (11.81 )   (22.23 )
Write-down of oil and natural gas properties   (81.67 )   (254.29 )   (40.56 )   (60.37 )   (138.21 )
Deferred income taxes   37.98     94.58     15.07     26.11     52.28  
Gain on debt extinguishment   2.09     —     15.05     8.81     —  
Noncash fair value adjustments on commodity derivatives   (25.59 )   (25.80 )   (15.06 )   (20.14 )   (17.79 )
Other noncash items   3.30     (6.73 )   8.10     5.78     0.36  
Net loss   $ (64.85 )   $ (171.21 )   $ (29.34 )   $ (46.45 )   $ (93.75 )
 

CAPITAL EXPENDITURE SUMMARY (UNAUDITED) (1)

    Three Months Ended   Six Months Ended
    June 30,   March 31,   June 30,
In thousands   2016   2015   2016   2016   2015
Capital expenditures by project                    
Tertiary oil fields   $ 31,934     $ 53,694     $ 31,964     $ 63,898     $ 96,594  
Non-tertiary fields   4,903     21,595     5,873     10,776     52,579  
Capitalized internal costs (2)   11,314     15,499     14,473     25,787     33,911  
Oil and natural gas capital expenditures   48,151     90,788     52,310     100,461     183,084  
CO2 pipelines   135     5,517     —     135     6,296  
CO2 sources   —     630     —     —     10,482  
Other   9     282     8     17     44  
Capital expenditures, before acquisitions and capitalized interest   48,295     97,217     52,318     100,613     199,906  
Acquisitions of oil and natural gas properties   680     21,698     224     904     21,959  
Capital expenditures, before capitalized interest   48,975     118,915     52,542     101,517     221,865  
Capitalized interest   6,289     8,738     5,780     12,069     17,147  
Capital expenditures, total   $ 55,264     $ 127,653     $ 58,322     $ 113,586     $ 239,012  

(1)  Capital expenditure amounts include accrued capital.
(2)  Includes capitalized internal acquisition, exploration and development costs and pre-production tertiary startup costs.

DENBURY RESOURCES INC.
SELECTED BALANCE SHEET AND CASH FLOW DATA (UNAUDITED) (1)

    June 30,   December 31,
In thousands   2016   2015
Cash and cash equivalents   $ 2,545     $ 2,812  
Total assets   4,989,973     5,885,533  
         
Borrowings under senior secured bank credit facility   $ 320,000     $ 175,000  
Borrowings under senior secured second lien notes (principal only) (2)   614,919     —  
Borrowings under senior subordinated notes (principal only)   1,642,198     2,852,250  
Financing and capital leases   267,572     283,090  
Total debt (principal only)   $ 2,844,689     $ 3,310,340  
         
Total stockholders’ equity   $ 865,304     $ 1,248,912  

(1)  Certain amounts as of December 31, 2015 have been reclassified to conform to the current year presentation.  On the Company’s Unaudited Condensed Consolidated Balance Sheets, (1) debt issuance costs associated with the Company’s senior subordinated notes have been reclassified from “Other assets” to “Long-term debt, net of current portion” and (2) deferred tax assets have been reclassified from “Deferred tax assets, net” to “Deferred tax liabilities, net.”  Such reclassifications were made as a result of the adoption of new accounting pronouncements and had no impact on previously reported net income or cash flows.
(2)  Excludes $255 million of future interest payable on the notes as of June 30, 2016, accounted for as debt for financial reporting purposes.  See Debt Reduction above for further discussion.

    Six Months Ended
    June 30,
In thousands   2016   2015
Cash provided by (used in)        
Operating activities   $ 62,944     $ 426,721  
Investing activities   (127,520 )   (336,512 )
Financing activities   64,309     (108,949 )
         
Cash dividends paid   $ 413     $ 43,528