~ Adjusted Net Income, after consideration of specific non-cash
items, was $5.4 Million, or $0.43 per unit ~ HOUSTON May 8
/PRNewswire-FirstCall/ -- Vanguard Natural Resources, LLC (NYSE
Arca: VNR) ("Vanguard" or "the Company") today reported financial
and operational results for the quarter ended March 31, 2009. Mr.
Scott W. Smith, President and CEO, commented, "We are pleased to
have generated $10.0 million of Distributable Cash Flow during the
first quarter of 2009, a record level for our company. The hedging
program we put in place over the past year insured the stability of
our cash flows and allowed us to make our planned distributions to
our unitholders. This quarter's cash flow, in combination with a
conservative capital expenditure program, generated a distribution
coverage ratio of approximately 1.6 times. For the year, we are on
track to meet our 2009 earnings guidance announced in conjunction
with our fourth quarter earnings press release. " Mr. Richard
Robert, Executive Vice President and CFO, added, "Due to our
proactive hedging initiatives, strong cash flow generation, and
prudent management of capital, we are well positioned to weather
this downturn in the economy and commodity markets. Since the end
of the March quarter, our cash position has risen to $5.4 million
and our debt now stands at $134 million. Given that approximately
100% of our natural gas production and 82% of our oil production
expected for the remainder of 2009 is hedged at commodity prices
well-above current levels, we feel confident in our ability to
continue to produce strong Distributable Cash Flow and coverage
ratios for the balance of the year." First Quarter 2009 Highlights:
-- Generated Adjusted EBITDA (a non-GAAP financial measure defined
below) of $12.7 million, up 21% over $10.4 million in the first
quarter of 2008 and slightly higher than fourth quarter 2008. --
Produced Distributable Cash Flow (a non-GAAP financial measure
defined below) of $10.0 million for the first quarter of 2009, a
43% increase over the $7.0 million generated in the first quarter
of 2008 and a 67% rise over the $6.0 million generated in the
fourth quarter of 2008. -- Recorded a net loss of $50.0 million for
the quarter ended March 31, 2009, compared to a net loss of $15.9
million in the 2008 first quarter. The recent quarter included $9.8
million of non-cash unrealized net gains in our commodity and
interest rate derivative contracts offset by a non-cash natural gas
and oil property impairment charge of $63.8 million under our
full-cost accounting method and a $1.3 million non-cash
compensation charge for the unrealized fair value of phantom units
granted to management. Excluding the net impact of these specific
non-cash items, Adjusted Net Income (a non-GAAP financial measure
defined below) was $5.4 million in the first quarter of 2009, or
$0.43 per unit, as compared to Adjusted Net Income of $4.3 million,
or $0.38 per unit, in the first quarter of 2008. -- Reported
average production of 17,815 Mcfe per day, up 19% over 15,016 Mcfe
per day produced in the first quarter of 2008, but down 4% over
fourth quarter 2008 average volumes of 18,576 Mcfe per day. During
the quarter we produced 1,140 MMcf of natural gas and 77,191 Bbls
of oil, which represented an increase of 25% and 49% over the 909
MMcf and 51,713 Bbls produced, respectively, in 2008 first quarter.
Sequentially, oil production was 8% higher than the 71,570 Bbls
produced in the 2008 fourth quarter but gas production was 11%
lower. Including the positive impact of our hedges in the first
quarter of this year, we realized a net price of $10.65 per Mcf of
natural gas and $70.53 per Bbl of crude oil. Impairment Charge The
first quarter 2009 results included a $63.8 million impairment
charge related to the write-down of our capitalized costs under
full-cost accounting. Under full-cost accounting, our dry hole and
geological costs are capitalized into the full cost pool, and are
subject to amortization and ceiling test limitations. The ceiling
is based on the net present value of the estimated future revenues,
as determined by the commodity spot prices at the end of each
quarter, discounted at 10%. Capitalized costs must be equal to or
less than this ceiling. Because of the precipitous drop in gas
prices at the end of the first quarter 2009, the net present value
of future revenues declined significantly. As a result, as of March
31, 2009, Vanguard was required to write-down its full-cost pool
down to the revenue ceiling. This impairment was calculated based
on prices of $3.65 per MMBtu for natural gas and $49.64 per barrel
of oil. The impairment calculation did not consider the positive
impact of the company's commodity derivative positions as generally
accepted accounting principles only allows the inclusion of
derivatives designated as cash flow hedges. Hedging Activities We
enter into derivative transactions in the form of hedging
arrangements to reduce the impact of natural gas and oil price
volatility on our cash flow from operations. As required by our
reserve-based credit facility, we have mitigated this volatility
through 2011 by implementing a hedging program on a portion of our
total anticipated production. At the end of the 2009 first quarter,
the fair value of commodity derivative contracts was approximately
$47.2 million, of which $28.1 million will settle during the next
twelve months. Currently, we use fixed-price swaps and NYMEX
collars and put options to hedge natural gas and oil prices. The
following table summarizes commodity derivative contracts in place
at March 31, 2009: April 1- December 31, 2009 2010 2011 Gas
Positions: Fixed Price Swaps: Notional Volume (MMBtu) 2,672,864
3,782,040 3,328,312 Fixed Price ($/MMBtu) $9.30 $8.95 $7.83 Puts:
Notional Volume (MMBtu) 613,041 - - Floor Price ($/MMBtu) $7.50 $-
$- Collars: Notional Volume (MMBtu) 749,997 914,000 364,000 Floor
Price ($/MMBtu) $7.50 $7.90 $7.50 Ceiling Price ($/MMBtu) $9.00
$9.24 $9.00 Total: Notional Volume (MMBtu) 4,035,902 4,696,040
3,962,312 Oil Positions: Fixed Price Swaps: Notional Volume (Bbls)
135,000 164,250 151,250 Fixed Price ($/Bbl) $87.23 $85.65 $85.50
Collars: Notional Volume (Bbls) 27,500 - - Floor Price ($/Bbl)
$100.00 $- $- Ceiling Price ($/Bbl) $127.00 $- $- Total: Notional
Volume (Bbls) 162,500 164,250 151,250 Selling, General and
Administrative Expense Our selling, general and administrative
expense rose $1.5 million to $3.2 million in the 2009 first quarter
from the same period in 2008, primarily reflecting the recognition
of non-cash expenses associated with our unit-based compensation
program. The 2009 first quarter results included a $2.2 million
non-cash compensation expense, compared to $0.9 million a year ago,
of which $1.3 million was related to the grant of phantom units on
January 1, 2009 and $0.9 million was related to the amortization of
common and Class B units. On January 1, 2009, in accordance with
their previously negotiated employment agreements, phantom units
were granted to two officers in amounts equal to 1% of our units
outstanding at January 1, 2009 and the amount paid in either cash
or units will equal the appreciation in value of the units, if any,
from the date of the grant until the determination date (December
31, 2009), plus cash distributions paid on the units, less an 8%
hurdle rate. The fair value of the phantom units at March 31, 2009
of $1.3 million was determined using a Black Scholes model and will
be recalculated at each quarter end until the final value is known
at December 31, 2009. Cash Distributions On May 15, 2009, the
Company will pay a first-quarter cash distribution of $0.50 per
unit to its unitholders of record on April 30, 2009. This quarterly
distribution payment was unchanged from the amount distributed for
the third and fourth quarters of 2008 and represents an increase of
$0.055 per unit, or 12%, over the $0.445 distribution set in the
first quarter of 2008. Capital Expenditures Capital expenditures
for the drilling, capital workover and recompletion of natural gas
and oil properties were $1.3 million in the first quarter of 2009
compared to $2.3 million for the comparable quarter of 2008. In
this low commodity price environment, Vanguard is allocating its
capital judiciously and has instituted a capital budget of between
$6.0 million and $6.5 million in 2009. These expenditures, which
predominantly consist of recompletions and workovers of existing
wells and a limited number of new wells in South Texas in the
second half of the 2009, are expected to be funded through cash
from operations. Reserve-based Credit Facility At the end of the
first quarter, we had indebtedness under the reserve-based credit
facility totaling $136.5 million, had $38.5 million available for
borrowing under its reserve-based credit facility and had $2.9
million in cash on our balance sheet. As of May 5, 2009, we have
$134 million outstanding on our reserve-based credit facility and
have $5.4 million in cash. The Company's borrowing base is
redetermined semi-annually, per the terms of our credit agreement.
We expect that the semi-annual borrowing base review process will
be completed during May 2009. We anticipate a reduction in our
borrowing base but based upon current expectations, we believe our
liquidity and capital resources will be sufficient for the conduct
of our business and operations for the foreseeable future. If
commodity prices continue to decline and banks continue to lower
their internal projections of natural gas and oil prices, it is
possible that we will be subject to additional decreases in our
borrowing base availability in the future. If our outstanding
borrowings under the reserve-based credit facility exceed 90% of
the borrowing base, we would be required to suspend distributions
to our unitholders until we have reduced our borrowings to below
the 90% threshold. As a result, absent accretive acquisitions, to
the extent available after unitholder distributions, debt service,
and capital expenditures, it is our current intention to utilize
our excess cash flow during 2009 to reduce our borrowings under our
reserve-based credit facility. Conference Call Information Vanguard
will host a conference call today to discuss its 2009 first quarter
results on Friday, May 8, 2009 at 11:00 a.m. Eastern Time (10:00
a.m. Central). To access the call, please dial (800) 762-8779 or
(480) 629-9031, for international callers and ask for the "Vanguard
Natural Resources" call a few minutes prior to the start time. The
conference call will also be broadcast live via the Internet and
can be accessed through the investor relations section of
Vanguard's website, http://www.vnrllc.com/. A telephonic replay of
the conference call will be available until May 22, 2009 and may be
accessed by calling (303) 590-3030 and using the pass code
4058441#. A webcast archive will be available on the Investor
Relations page at http://www.vnrllc.com/ shortly after the call and
will be accessible for approximately 30 days. For more information,
please contact Donna Washburn at DRG&E at (713) 529-6000 or
email at . About Vanguard Natural Resources, LLC Vanguard Natural
Resources, LLC is a publicly traded limited liability company
focused on the acquisition, production and development of natural
gas and oil properties. The Company'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 the Company can be found at
http://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 March 31, 2009 2008 Net Natural Gas Production:
Appalachian gas (MMcf) 805 867 Permian gas (MMcf) 59 42 ( a ) South
Texas gas (MMcf) 276 - ( b ) Total natural gas production (MMcf)
1,140 909 Average Appalachian daily gas production (Mcf/day) 8,949
9,527 Average Permian daily gas production (Mcf/day) 658 693 ( a )
Average South Texas daily gas ( b ) production (Mcf/day) 3,062 -
Average Vanguard daily gas production (Mcf/day) 12,669 10,220
Average Natural Gas Sales Price per Mcf: Net realized gas price,
including hedges $10.65 ( c ) $10.47 ( c ) Net realized gas price,
excluding hedges $5.55 $9.93 Net Oil Production: Appalachian oil
(Bbls) 16,511 10,991 Permian oil (Bbls) 60,680 40,722 ( a ) Total
oil (Bbls) 77,191 51,713 Average Appalachian daily oil production
(Bbls/day) 183 121 Average Permian daily oil production (Bbls/day)
674 679 ( a ) Average Vanguard daily oil production (Bbls/day) 857
800 Average Oil Sales Price per Bbl: Net realized oil price,
including hedges $70.53 $89.65 Net realized oil price, excluding
hedges $37.31 $96.33 ( a ) The Permian Basin acquisition closed on
January 31, 2008 and, as such, only two months of operations are
included in the three month period ended March 31, 2008. ( b ) The
South Texas acquisition closed on July 28, 2008 and, as such, no
operations are included in the three month period ended March 31,
2008. ( c ) Excludes amortization of premiums paid and non-cash
settlements on derivative contracts. VANGUARD NATURAL RESOURCES,
LLC AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF OPERATIONS (in
thousands, except per unit data) (Unaudited) Three Months Ended
March 31, 2009 2008 (a) (b) Revenues: Natural gas and oil sales
$9,202 $14,002 Gain (loss) on commodity cash flow hedges (896) 416
Gain (loss) on other commodity derivative contracts 17,649 (21,772)
Total revenues 25,955 (7,354) Costs and expenses: Lease operating
expenses 3,133 2,015 Depreciation, depletion, amortization and
accretion 3,783 2,824 Impairment of natural gas and oil properties
63,818 - Selling, general and administrative expenses 3,152 1,646
Production and other taxes 642 966 Total costs and expenses 74,528
7,451 Loss from operations (48,573) (14,805) Other income and
(expense): Interest income - 8 Interest expense (1,013) (1,130)
Loss on interest rate derivative contracts (379) (5) Total other
expense, net (1,392) (1,127) Net loss $(49,965) $(15,932) Net loss
per unit: Common & Class B units - basic $(3.98) $(1.42) Common
& Class B units - diluted $(3.98) $(1.42) Weighted average
units outstanding: Common units - basic & diluted 12,145,873
10,795,000 Class B units - basic & diluted 420,000 420,000 (a)
The South Texas acquisition closed on July 28, 2008 and as such no
operations are included in the three month period ended March 31,
2008. (b) The Permian Basin acquisition closed on January 31, 2008
and as such only two months of operations are included in the three
month period ended March 31, 2008. VANGUARD NATURAL RESOURCES, LLC
AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS (in thousands) March
31, December 31, 2009 2008 (Unaudited) Assets Current assets Cash
and cash equivalents $2,924 $3 Trade accounts receivable, net 4,204
6,083 Derivative assets 28,106 22,184 Other receivables 3,797 2,763
Other current assets 637 845 Total current assets 39,668 31,878
Natural gas and oil properties, at cost 286,632 284,447 Accumulated
depletion (169,739) (102,178) Natural gas and oil properties
evaluated, net - full cost method 116,893 182,269 Other assets
Derivative assets 19,087 15,749 Deferred financing costs 805 882
Other assets 1,053 1,784 Total assets $ 177,506 $ 232,562
Liabilities and members' equity Current liabilities Accounts
payable - trade $883 $2,148 Accounts payable - natural gas and oil
871 1,327 Payables to affiliates 1,263 2,555 Derivative liabilities
244 486 Accrued expenses 2,311 1,248 Total current liabilities
5,572 7,764 Long-term debt 136,500 135,000 Derivative liabilities
2,599 2,313 Asset retirement obligations 2,159 2,134 Total
liabilities 146,830 147,211 Commitments and contingencies Members'
equity Members' capital, 12,145,873 common units issued and
outstanding at March 31, 2009 and December 31, 2008 32,399 88,550
Class B units, 420,000 issued and outstanding at March 31, 2009 and
December 31, 2008 5,195 4,606 Accumulated other comprehensive loss
(6,918) (7,805) Total members' equity 30,676 85,351 Total
liabilities and members' equity $177,506 $232,562 Use of Non-GAAP
Measures Adjusted EBITDA We present Adjusted EBITDA in addition to
our reported net income (loss) 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 and realized gains and losses on interest
rate derivative contracts; -- Depreciation, depletion and
amortization (including accretion of asset retirement obligations);
-- Impairment of natural gas and oil properties; -- Amortization of
premiums paid and non-cash settlements on derivative contracts; --
Unrealized gains and losses on other commodity and interest rate
derivative contracts; -- Deferred taxes, and -- Unit-based
compensation expense 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 (loss) in accordance with GAAP.
Distributable Cash Flow is a non-GAAP financial measure that is
defined as net income (loss) plus: -- Depreciation, depletion and
amortization (including accretion of asset retirement obligations);
-- Impairment of natural gas and oil properties; -- Amortization of
premiums paid and non-cash settlements on derivative contracts; --
Unrealized gains and losses on other commodity and interest rate
derivative contracts; -- Deferred taxes, and -- Unit-based
compensation expense. Less: -- Drilling, capital 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 Loss to Adjusted EBITDA (1)
and Distributable Cash Flow (Unaudited) (in thousands) Three Months
Ended March 31, 2009 2008 (2) (3) Net Loss $(49,965) $(15,932)
Plus: Interest expense, including realized losses on interest rate
derivative contracts 1,349 1,130 Depreciation, depletion,
amortization and accretion 3,783 2,824 Impairment of natural gas
and oil properties 63,818 - Amortization of premiums paid and
non-cash settlements on derivative contracts 1,465 1,301 Unrealized
(gains) losses on other commodity and interest rate derivative
contracts (9,786) 20,210 Deferred taxes (197) - Unit-based
compensation expense 2,188 915 Less: Interest income - 8 Adjusted
EBITDA $12,655 $10,440 Less: Interest expense, net 1,349 1,122
Drilling, capital workover and recompletion expenditures 1,260
2,316 Distributable Cash Flow $10,046 $7,002 (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 no operations are included in the three month period
ended March 31, 2008. (3) The Permian Basin acquisition closed on
January 31, 2008 and as such only two months of operations are
included in the three month period ended March 31, 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 other commodity derivative
contracts; -- Unrealized gains and losses on interest rate
derivative contracts; -- Unrealized fair value of phantom units
granted to management; and -- Impairment of natural gas and oil
properties. This information is provided because management
believes exclusion of the impact of our unrealized derivatives not
accounted for as cash flow hedges and non-cash natural gas and oil
property impairment charge 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 Loss to
Adjusted Net Income (Unaudited) Three Months Ended March 31, 2009
2008 Net Loss $(49,965) $(15,932) Plus: Unrealized loss on interest
rate derivative contracts 43 - Unrealized loss on other commodity
derivative contracts - 20,210 Unrealized fair value of phantom
units granted to management 1,301 - Impairment of natural gas and
oil properties 63,818 - Less: Unrealized gain on other commodity
derivative contracts (9,829) - Total adjustments 55,333 20,210
Adjusted Net Income $5,368 $4,278 Basic and diluted net loss per
unit: $(3.98) $(1.42) Plus: Impairment of natural gas and oil
properties 5.08 - Unrealized fair value of phantom units granted to
management 0.10 - Less: Unrealized gain on commodity and interest
rate derivative contracts, net (0.77) 1.80 Basic and diluted
adjusted net income per unit: $0.43 $0.38 INVESTOR RELATIONS
CONTACT: Vanguard Natural Resources, LLC Richard Robert, EVP and
CFO, 832-327-2258 DRG&E Jack Lascar/Carol Coale, 713-529-6600
or DATASOURCE: Vanguard Natural Resources, LLC CONTACT: Richard
Robert, EVP and CFO of Vanguard Natural Resources, LLC,
+1-832-327-2258, , or Jack Lascar, , or Carol Coale, , both of
DRG&E, +1-713-529-6600 Web Site: http://www.vnrllc.com/
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