Quantcast

Vanguard Natural Resources, LLC Reports Record Third Quarter 2008 Financial Results

November 14, 2008

Vanguard Natural Resources, LLC (NYSEArca:VNR) (“Vanguard” or “Company”) today reported financial and operational results for the third quarter of 2008. The Company reported the following highlights for the third quarter:

— Achieved Adjusted EBITDA (a non-GAAP financial measure defined below) of $13.8 million, up 65% over $8.4 million in the third quarter of 2007 and up 16% over second quarter 2008.

— Generated distributable cash flow (a non-GAAP financial measure defined below) of $5.6 million for the three months ended September 30, 2008 representing a 118% increase over the $2.6 million generated in the third quarter of 2007. In addition, we generated $19.0 million of distributable cash flow for the nine months ended September 30, 2008 as compared to $7.0 million in the same period in 2007, a 172% increase.

— Reported daily production of 16,932 Mcfe, up 46% over 11,632 Mcfe/day in the third quarter of 2007 and up 7% over second quarter 2008 volumes.

— Production rate of approximately 19,200 Mcfe for the month of September 2008, a 13% increase over average daily production volumes for the third quarter.

— Recorded net income of $71.8 million for the quarter ended September 30, 2008. Excluding the impact of non-cash unrealized gains and losses in our commodity and interest rate derivative contracts, Adjusted Net Income (a non-GAAP financial measure defined below) was $5.9 million, up 459% over $1.1 million in the third quarter of 2007 and up 14% over second quarter 2008.

— Increased quarterly distribution to $0.50 representing a 12% increase over the distribution in the second quarter of 2008 and an 18% increase over the initial distribution set at the time of our IPO in October 2007.

— Announced that the Company will restate first and second quarter 2008 financial results due to a change in the accounting treatment for derivative contracts. The restatement does not impact the economics of the hedge transactions nor does it affect the Company’s liquidity, adjusted EBITDA, distributable cash flow, total assets, total liabilities, members’ capital, or the amount of available cash to pay distributions in any historical or future period.

Mr. Scott W. Smith, President and CEO, commented, “Our results this quarter were in line with our expectations with the addition of the South Texas properties and the amount of capital expenditures we incurred in the drilling of over 14 net wells in our three operating areas. As we had stated previously, this increased level of investment was a direct result of lack of rig availability earlier in the year and is not reflective of our expected level of capital expenditures each quarter going forward. During the fourth quarter, we expect to see the full benefits of our drilling program and property acquisitions as illustrated by our enhanced production rate exiting the third quarter, and we will focus our capital expenditures on select re-completions and well-connects of previously drilled wells in Appalachia, the drilling of two additional wells in south Texas and well completion work on the newly drilled wells in the Permian Basin. In the current commodity environment, we and our operating partners have elected to defer the drilling of additional development wells until such time as drilling, completion and service costs decline to levels commensurate with the decline in the commodity prices. We are fortunate that our extensive inventory of proved undeveloped locations in Appalachia and South Texas is associated with acreage that is held by production.”

Mr. Richard Robert, Executive Vice President and CFO, added, “As was expected, distributable cash flow this quarter was impacted by an unusually large amount of drilling, recompletions, and other capital expenditures. We anticipate that the results of the fourth quarter of 2008 will normalize our distribution coverage ratio for the year and bring it in line with our current expectation of approximately 1.15 to 1.20 times for 2008. Looking forward, our unitholders will benefit from the long-term hedging strategy that we have implemented. As outlined in detail in our press release on October 28, 2008, the price we receive for a significant percentage of our natural gas and oil is set at attractive levels for several years to come. We will continue to monitor our production and cash flows and will adjust our capital expenditures accordingly in order to maintain financial flexibility and liquidity in order to take advantage of opportunities which may arise in these volatile markets.”

Third Quarter 2008 Results

During the third quarter of 2008, the Company produced 1,558 MMcfe, resulting in Adjusted EBITDA of $13.8 million and net income of $71.8 million. Excluding the impact of non-cash changes in the fair value of our commodity and interest rate derivative contracts, Adjusted Net Income was $5.9 million. Adjusted EBITDA is the primary measure used by Company management to evaluate cash flow and the Company’s ability to sustain or increase distributions. Our definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to its most comparable GAAP financial measure, net income, are provided in this release. Our definition of Adjusted Net Income and a reconciliation of Adjusted Net Income to its most comparable GAAP financial measure, net income, are provided in this release.

In the third quarter of 2008, the Company participated in the drilling of 29 gross (12.2 net) wells in Appalachia. In the Permian Basin, the Company participated in 1 gross (1 net) well and in South Texas, the Company participated in 2 gross (0.9 net) wells. All of the wells drilled in the third quarter were successfully completed.

Cash Distributions

On October 15, 2008, the Company declared a cash distribution attributable to the third quarter of 2008 of $0.50 per unit, payable on November 14, 2008 to unitholders of record on October 31, 2008. This quarterly distribution of $0.50 per unit represents an increase of $0.055 per unit, or 12%, over the second quarter 2008 distribution of $0.445 and an increase of $0.075 per unit, or 18%, over the $0.425 distribution initially set forth in the prospectus for our initial public offering which was completed on October 29, 2007.

Restatement of Previously Issued Unaudited Quarterly Financial Statements in 2008

On November 10, 2008, in connection with preparing its quarterly report for third quarter 2008 and discussion with BDO Seidman, LLP, the Company’s new independent registered public accounting firm, management of the Company and the Audit Committee of its Board of Directors concluded that the contemporaneous formal documentation it had prepared to support its initial hedge designations and subsequent assessments for ineffectiveness in connection with the Company’s natural gas and oil hedging program in 2008 did not meet the technical requirements to qualify for cash flow hedge accounting treatment in accordance with Statement of Financial Accounting Standard No. 133, “Accounting for Derivative Instruments and Hedging Activities” (“SFAS No. 133″). The primary reasons for this determination were that the formal hedge documentation lacked specificity of the hedged cash flow and the quantitative subsequent assessments for ineffectiveness were insufficient. Therefore, the cash flow designations failed to meet hedge documentation requirements for cash flow hedge accounting treatment. In addition, the natural gas derivative swap contracts entered into in 2007 were de-designated as cash flow hedges in the first quarter of 2008 due to an overhedged position in natural gas which made them ineffective.

Under SFAS No. 133, the fair value of hedge contracts is recognized in the Consolidated Balance Sheet as an asset or liability, and the amounts received or paid under the hedge contracts are reflected in earnings during the period in which the underlying production occurs. If the hedge contracts qualify for hedge accounting treatment, the fair value of the hedge contract is recorded in “accumulated other comprehensive income”, and changes in the fair value do not affect net income in the period. If the hedge contract does not qualify for hedge accounting treatement, the change in the fair value of the hedge contract is reflected in earnings during the period as unrealized gain or loss on commodity derivatives. Under the cash flow accounting treatment used by the Company, the fair values of the hedge contracts were recognized in the consolidated balance sheets with the resulting unrealized gain or loss recorded initially in accumulated other comprehensive income and later reclassified through earnings when the hedged production affected earnings. As a result of the determination that the documentation failed to meet cash flow hedge accounting treatment, the unrealized gain or loss should have been recorded in the consolidated statements of operations as a component of earnings. In addition, the net derivative loss at December 31, 2007 related to the de-designated natural gas derivative swap contracts entered into in 2007 will continue to be reported in accumulated other comprehensive income until the month in which the transactions settle.

The Company will restate its consolidated unaudited quarterly financial statements for March 31, 2008 and June 30, 2008. The restatement does not impact the economics of the hedge transactions nor does it affect the Company’s liquidity, adjusted EBITDA, distributable cash flow, total assets, total liabilities, members’ capital, or the amount of available cash to pay distributions in any historical or future period. The restatement did not have any impact on any of the Company’s financial covenants under its reserve-based credit facility.

The Company expects the restatement will have the following effects on unrealized loss on commodity derivative contracts, net income (loss), and diluted income (loss) per unit for the three months ended March 31, 2008 and June 30, 2008 the impact of which has been reflected in the operating results for the nine months ended September 30, 2008:

 Vanguard Natural Resources, LLC Restatement of Historical Financial Results (Unaudited)  Quarter Ended ----------------------------- June 30, 2008  March 31, 2008 -------------- --------------  Unrealized loss on commodity derivative contracts: As previously reported                 $          --  $          -- As restated                            $ (52,186,386) $ (20,209,757)  Net income (loss): As previously reported                 $   5,164,168  $   4,276,020 As restated                            $ (47,019,744) $ (15,932,236)  Basic and diluted net income (loss) per unit: As previously reported                 $        0.46  $        0.38 As restated                            $       (4.19) $       (1.42)  

The Company plans to file its Quarterly Report on Form 10-Q for the three months ended September 30, 2008 with the Securities and Exchange Commission today. The Company expects to file amended Quarterly Reports on Form 10-Q for the periods ended March 31, 2008 and June 30, 2008 as soon as practicable.

Mr. Robert stated, “It is unfortunate that our earnings will now include the volatility related to non-cash mark to market fair value changes on our derivative contracts as it will now require the readers to analyze our Consolidated Statement of Operations in greater detail to ascertain the operating results that generate the cash that we distribute to our unitholders. However, on a positive note, this change in accounting treatment provides the Company with the flexibility to make investment and hedging decisions absent concerns about maintaining cash flow hedge accounting treatment.”

Presentations

On November 21, 2008 at 10:10 am Central Time, the Company will be part of a panel at RBC Capital Markets 2008 MLP Conference at the Four Seasons Hotel at Las Colinas in Dallas, Texas. In addition, the Company will be available for one-on-one meetings during the day.

On December 10, 2008 at 10:35 am Eastern Time, the Company will be presenting at the 7th Annual Wachovia Pipeline and Energy MLP Conference at the Jumeirah Essex House in New York, NY. In addition, the Company will be available for one-on-one meetings in the afternoon of December 9, 2008 and on December 10 when not presenting.

Conference Call Information

The Company will host a conference call today at 10:00 a.m. CST to review its financial results.

To participate, analysts, investors, media and the public in the U.S. may pre-register by using the following URL: https://www.theconferencingservice.com/prereg/key.process?key= P6PMVJYTA. Alternatively, you may dial 888-713-4213 shortly before 10:00 a.m. (CST). The international phone number is 617-213-4865. The conference passcode is 44711769.

A replay will be available for a seven-day period approximately one hour after the end of the call by dialing 888-286-8010 or 617-801-6888 (international). The replay passcode is 94392427.

A live audio webcast of the conference call and the earnings press release will be available on the Investor Relations page of Vanguard’s web site (http://www.vnrllc.com).

About Vanguard Natural Resources, LLC

Vanguard Natural Resources, LLC is a publicly-traded limited liability company, focused on the acquisition and development of natural gas and oil properties in the United States. Vanguard’s assets consist primarily of producing and non-producing natural gas and oil reserves located in the southern portion of the Appalachian Basin, the Permian Basin, and South Texas. More information on Vanguard can be found on its website at www.vnrllc.com.

Forward-Looking Statements

We make statements in this news release that are considered forward-looking statements within the meaning of the Securities Exchange Act of 1934. These forward-looking statements are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions and other factors. Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control. In addition, management’s assumptions about future events may prove to be inaccurate. Management cautions all readers that the forward-looking statements contained in this news release are not guarantees of future performance, and we cannot assure you that such statements will be realized or the forward-looking events and circumstances will occur. Actual results may differ materially from those anticipated or implied in the forward-looking statements due to factors listed in the “Risk Factors” section in our SEC filings and elsewhere in those filings. All forward-looking statements speak only as of the date of this news release. We do not intend to publicly update or revise any forward-looking statements as a result of new information, future events or otherwise.

 Vanguard Natural Resources, LLC Operating Statistics (Unaudited)  Three Months Ended      Nine Months Ended September 30,          September 30, -------------------    ------------------- 2008       2007        2008       2007 --------    -------    --------    ------- Net Natural Gas Production: Appalachian gas (MMcf)      923      1,002       2,693      3,102 Permian gas (MMcf)            -          -         150 (a)      - South Texas gas (MMcf)      239 (b)      -         240 (b) --------    -------    --------    ------- Total natural gas production (MMcf)          1,162      1,002       3,083      3,102 --------    -------    --------    -------  Average Appalachian daily gas production (Mcf/day)               10,031     10,892       9,827     11,363 Average Permian daily gas production (Mcf/day)                    -          -         618 (a)      - Average South Texas daily gas production (Mcf/day)                3,684 (b)      -       3,684 (b)      - --------    -------    --------    ------- Average Vanguard daily gas production (Mcf/day)                 13,715     10,892      14,129     11,363 --------    -------    --------    -------  Average Natural Gas Sales Price per Mcf: Net realized gas price, including realized gains (losses) on commodity derivative contracts   $ 11.35 (c)$  9.44 (c)$  10.78 (c)$  8.73(c) Net realized gas price, excluding realized gains (losses) on commodity derivative contracts   $ 11.46    $  6.69    $  11.56    $  8.14  Net Oil Production: Appalachian oil (Bbls)   11,122     11,348      32,543     19,861 Permian oil (Bbls)       54,924          -     157,463 (a)      - --------    -------    --------    ------- Total oil (Bbls)           66,046     11,348     190,006     19,861 --------    -------    --------    -------  Average Appalachian daily oil production (Bbls/day)                 121        123         119         73 Average Permian daily oil production (Bbls/day)                 597          -         648 (a)      - --------    -------    --------    ------- Average Vanguard daily oil production (Bbls/day)                   718        123         767         73 --------    -------    --------    -------  Average Oil Sales Price per Bbls: Net realized oil price, including realized gains (losses) on commodity derivative contracts   $ 93.26    $ 82.46    $  87.62    $ 73.03 Net realized oil price, excluding realized gains (losses) on commodity derivative contracts   $114.01    $ 82.46    $ 105.56    $ 73.03  

 (a) The Permian Basin acquisition closed on January 31, 2008 and as such only eight months of operations are included in the nine month period ended September 30, 2008.  (b) The South Texas acquisition closed on July 28, 2008 and as such only two months of operations are included in the three month and nine month period ended September 30, 2008.  (c) Excludes amortization of premiums paid and non-cash settlements on derivative contracts.  

 VANGUARD NATURAL RESOURCES, LLC AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)  Three Months Ended        Nine Months Ended September 30,             September 30, ------------------------ -------------------------- 2008 (a)      2007     2008 (a) (b)      2007 Revenues: Natural gas and oil sales       $20,838,797  $ 7,641,064 $ 55,692,781  $26,709,417 Realized gain (loss) on commodity cash flow hedges              --      940,566           --     (725,286) ------------ ----------- ------------- ------------ Total revenues      20,838,797    8,581,630   55,692,781   25,984,131 ------------ ----------- ------------- ------------  Costs and expenses: Lease operating expenses          3,483,968    1,347,565    7,799,721    3,807,985 Depreciation, depletion, amortization and accretion     4,187,241    2,267,050   10,341,243    6,587,339 Selling, general and administrative expenses          1,561,031    1,084,995    4,843,497    2,300,484 Bad debt expense          --           --           --    1,007,458 Taxes other than income            1,263,223      326,175    3,658,301    1,217,167 ------------ ----------- ------------- ------------ Total costs and expenses           10,495,463    5,025,785   26,642,762   14,920,433 ------------ ----------- ------------- ------------  ------------ ----------- ------------- ------------ Income from operations         10,343,334    3,555,845   29,050,019   11,063,698 ------------ ----------- ------------- ------------  Other income and (expense): Interest income        4,265       19,793       16,272       47,439 Interest expense  (1,488,745)  (2,524,427)  (3,862,855)  (6,944,241) Realized gain (loss) on commodity derivative contracts        (2,943,833)          --   (9,792,946)          -- Unrealized gain (loss) on commodity derivative contracts        66,353,176           --   (6,042,967)          -- Realized loss on interest rate derivative contracts           (39,058)          --      (90,364)          -- Unrealized loss on interest rate derivative contracts          (419,769)          --     (419,769)          -- Loss on extinguishment of debt                  --           --           --   (2,501,528) ------------ ----------- ------------- ------------ Total other expense, net       61,466,036   (2,504,634) (20,192,629)  (9,398,330) ------------ ----------- ------------- ------------  ------------ ----------- ------------- ------------ Net income         $71,809,370  $ 1,051,211 $  8,857,390  $ 1,665,368 ============ =========== ============= ============  Net income per unit: Common & Class B units - basic   $      5.90  $      0.18 $       0.77  $      0.29 ============ =========== ============= ============  Common & Class B units - diluted $      5.90  $      0.18 $       0.77  $      0.29 ============ =========== ============= ============  Weighted average units outstanding: Common units - basic & diluted  11,749,421    5,540,000   11,115,463    5,540,000 ============ =========== ============= ============ Class B units - basic & diluted     420,000      393,098      420,000      231,410 ============ =========== ============= ============  

 (a) The South Texas acquisition closed on July 28, 2008 and as such only two months of operations are included in the three month and nine month period ended September 30, 2008.  (b) The Permian Basin acquisition closed on January 31, 2008 and as such only eight months of operations are included in the nine month period ended September 30, 2008.  

 VANGUARD NATURAL RESOURCES, LLC AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS  September 30, December 31, 2008          2007 ------------- ------------- Assets                                      (Unaudited) Current assets Cash and cash equivalents             $    340,850  $  3,109,563 Trade accounts receivable, net          11,103,113     4,372,731 Derivative assets                        3,723,104     4,017,085 Other current assets                       940,824       453,198 ------------- ------------- Total current assets                       16,107,891    11,952,577 ------------- -------------  Property and equipment, net of accumulated depreciation                                   195,682       166,455  Natural gas and oil properties, at cost                                  278,974,900   135,435,240 Accumulated depletion                  (38,746,260)  (28,451,891) ------------- ------------- Natural gas and oil properties, net - full cost method                                240,228,640   106,983,349 ------------- -------------  Other assets Derivative assets                          486,311     1,329,511 Deferred financing costs                   897,521       941,833 Non-current deposits                        45,963     8,285,883 Other assets                             1,909,537     1,519,577 ------------- ------------- Total assets                               $259,871,545  $131,179,185 ============= =============  Liabilities and members' equity  Current liabilities Accounts payable - trade              $    184,726  $  1,056,627 Accounts payable - natural gas and oil                                     1,801,613       257,073 Payables to affiliates                   5,066,485     3,838,328 Accrued expenses                         2,503,386       203,159 ------------- ------------- Total current liabilities                     9,556,210     5,355,187  Long-term debt                         134,500,000    37,400,000 Derivative liabilities                  10,108,110     5,903,384 Asset retirement obligations             2,404,429       189,711 ------------- ------------- Total liabilities                           156,568,749    48,848,282 ------------- -------------  Commitments and contingencies  Members' equity Members' capital, 12,145,873 common units issued and outstanding at September 30, 2008 and 10,795,000 at December 31, 2007                     107,163,017    90,257,856 Class B units, 420,000 issued and outstanding at September 30, 2008 and December 31, 2007 4,016,122     2,131,995 Accumulated other comprehensive loss    (7,876,343)  (10,058,948) ------------- ------------- Total members' equity                       103,302,796    82,330,903 ------------- -------------  Total liabilities and members' equity      $259,871,545  $131,179,185 ============= =============  

Use of Non-GAAP Measures

Adjusted EBITDA

We present Adjusted EBITDA in addition to our reported net income in accordance with GAAP. Adjusted EBITDA is a non-GAAP financial measure that is defined as net income (loss) plus:

— Net interest expense (including write-off of deferred financing fees);

— Loss on extinguishment of debt;

— Depreciation, depletion and amortization (including accretion of asset retirement obligations);

— Bad debt expenses;

— Amortization of premiums paid and non-cash settlements on derivative contracts;

— Unrealized gains and losses on commodity and interest rate derivative contracts;

— Unit-based compensation expense; and

— Realized gains and losses on cancelled derivatives.

Adjusted EBITDA is used by management as a tool to measure (prior to the establishment of any cash reserves by our board of directors, debt service and capital expenditures) the cash distributions we could pay our unitholders. Specifically, this financial measure indicates to investors whether or not we are generating cash flow at a level that can sustain or support an increase in our quarterly distribution rates. Adjusted EBITDA is also used as a quantitative standard by our management and by external users of our financial statements such as investors, research analysts and others to assess the financial performance of our assets without regard to financing methods, capital structure or historical cost basis; the ability of our assets to generate cash sufficient to pay interest costs and support our indebtedness; and our operating performance and return on capital as compared to those of other companies in our industry. Adjusted EBITDA is not intended to represent cash flows for the period, nor is it presented as a substitute for net income, operating income, cash flows from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP.

Distributable Cash Flow

We present distributable cash flow in addition to our reported net income in accordance with GAAP. Distributable cash flow is a non-GAAP financial measure that is defined as net income (loss) plus:

— Loss on extinguishment of debt;

— Depreciation, depletion and amortization (including accretion of asset retirement obligations);

— Bad debt expenses;

— Amortization of premiums paid and non-cash settlements on derivative contracts;

— Unrealized gains and losses on commodity and interest rate derivative contracts;

— Unit-based compensation expense; and

— Realized gains and losses on cancelled derivatives;

Less:

— Drilling, captial workover and recompletion expenditures

Distributable cash flow is used by management as a tool to measure (prior to the establishment of any cash reserves by our board of directors) the cash distributions we could pay our unitholders. Specifically, this financial measure indicates to investors whether or not we are generating cash flow at a level that can sustain or support an increase in our quarterly distribution rates. While distributable cash flow is measured on a quarterly basis for reporting purposes, management must consider the timing and size of its planned capital expenditures in determining the sustainability of its quarterly distribution. Capital expenditures are typically not spent evenly throughout the year due to a variety of factors including weather, rig availability, and the commodity price environment. As a result, there will be some volatility in distributable cash flow measured on a quarterly basis. Distributable cash flow is not intended to be a substitute for net income, operating income, cash flows from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP.

 Vanguard Natural Resources, LLC Reconciliation of Net Income to Adjusted EBITDA (1) and Distributable Cash Flow (Unaudited)  Three Months Ended       Nine Months Ended September 30,            September 30, ------------------------ ------------------------ 2008 (2)       2007    2008 (2)(3)     2007 ------------- ---------- ------------ -----------  Net income           $ 71,809,370  $1,051,211 $ 8,857,390  $ 1,665,368 Plus: Interest expense     1,488,745   2,524,427   3,862,855    6,944,241 Loss on extinguishment of debt                     -           -           -    2,501,528 Depreciation, depletion, amortization and accretion           4,187,241   2,267,050  10,341,243    6,587,339 Bad debt expense             -           -           -    1,007,458 Amortization of premiums paid and non-cash settlements on derivative contracts           1,450,582   1,813,495   3,981,775    2,546,999 Unrealized (gains) and losses on commodity and interest rate derivative contracts         (65,933,407)          -   6,462,736            - Unit-based compensation expense               812,034     751,635   2,708,381    1,314,778 Realized loss on cancelled derivatives                 -           -           -      776,634 Less: Interest income          4,265      19,793      16,272       47,439 ------------- ---------- ------------------------ Adjusted EBITDA      $ 13,810,300  $8,388,025 $36,198,108  $23,296,906 Less: Interest expense, net    1,484,480   2,504,634   3,846,583    6,896,802 Drilling, captial workover and recompletion expenditures    6,681,845   3,293,876  13,359,807    9,426,483 ------------- ---------- ------------ ----------- Distributable Cash Flow                $  5,643,975  $2,589,515 $18,991,718  $ 6,973,621 ============= ========== ============ ===========  

 (1) Our Adjusted EBITDA should not be considered as an alternative to net income, operating income, cash flows from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Our Adjusted EBITDA excludes some, but not all, items that affect net income and operating income and these measures may vary among other companies. Therefore, our Adjusted EBITDA may not be comparable to similarly titled measures of other companies.  (2) The South Texas acquisition closed on July 28, 2008 and as such only two months of operations are included in the three month and nine month period ended September 30, 2008.  (3) The Permian Basin acquisition closed on January 31, 2008 and as such only eight months of operations are included in the nine month period ended September 30, 2008.  

Adjusted Net Income

We present Adjusted Net Income in addition to our reported net income in accordance with GAAP. Adjusted Net Income is a non-GAAP financial measure that is defined as net income (loss) plus:

— Unrealized gains and losses on commodity derivative contracts;

— Unrealized gains and losses on interest rate derivative contracts;

This information is provided because management believes exclusion of the impact of our unrealized derivatives not accounted for as cash flow hedges will help investors compare results between periods and identify operating trends that could otherwise be masked by these items and to highlight the impact that commodity price volatility has on our results. Adjusted Net Income is not intended to represent cash flows for the period, nor is it presented as a substitute for net income, operating income, cash flows from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP.

 Vanguard Natural Resources, LLC Reconciliation of Net Income to Adjusted Net Income (Unaudited)  Three Months Ended      Nine Months Ended September 30,           September 30, ------------------------ ---------------------- 2008         2007       2008        2007 ------------- ---------- ----------- ----------  Net income             $ 71,809,370  $1,051,211 $ 8,857,390 $1,665,368 Plus: Unrealized (gain) loss on commodity derivative contracts          (66,353,176)          -   6,042,967          - Unrealized loss on interest rate derivative contracts              419,769           -     419,769          - ------------- ---------- ----------- ---------- Total adjustments       (65,933,407)          -   6,462,736          - ------------- ---------- ----------- ----------  Adjusted Net Income    $  5,875,963  $1,051,211 $15,320,126 $1,665,368 ============= ========== =========== ==========   Basic and diluted net income per unit:      $       5.90  $     0.18 $      0.77 $     0.29 Plus: Unrealized (gain) and loss on commodity and interest rate derivative contracts                (5.42)          -        0.56          - ------------- ---------- ----------- ---------- Basic and diluted adjusted net income per unit:             $       0.48  $     0.18 $      1.33 $     0.29 ============= ========== =========== ==========  




comments powered by Disqus