Pioneer Southwest Energy Partners L.P. (“Pioneer
Southwest” or “the Partnership”) (NYSE:PSE) today
announced financial and operating results for the quarter ended
December 31, 2009.
Net loss for the fourth quarter was $11 million, or $.35 per
common unit. The loss included noncash mark-to-market derivative
losses of $36 million, or $1.14 per common unit. Without the effect
of this item, adjusted income for the fourth quarter would have
been $25 million, or $.79 per common unit. Cash flow from
operations for the period was $18 million.
Oil and gas sales for the fourth quarter averaged 6,032 barrels
oil equivalent per day (BOEPD). Fourth quarter oil sales averaged
3,636 barrels per day (BPD), natural gas liquid (NGL) sales
averaged 1,388 BPD, and gas sales averaged 6 million cubic feet per
day (MMCFPD).
The fourth quarter average price for oil was $116.65 per barrel.
The average price for NGLs was $48.32 per barrel, and the average
price for gas was $6.03 per thousand cubic feet. The average prices
reported for the fourth quarter benefitted from the Partnership’s
attractive commodity derivative position.
The Partnership commenced a two-rig drilling program in early
November and through the end of December had drilled six wells, of
which five are producing and one is awaiting completion. During
2010, the Partnership expects to drill approximately 50 wells. The
drilling program is expected to provide production growth and,
based on current NYMEX strip prices and drilling and production
costs, generate internal rates of return of approximately 50%.
The Partnership has credit facility availability of $225
million, which is expected to be adequate to fund future growth
through drilling and acquisitions.
Pioneer Southwest previously announced a cash distribution of
$.50 per outstanding common unit for the quarter ended December 31,
2009, or $2.00 per outstanding common unit on an annual basis. The
distribution is payable February 11, 2010 to holders of record at
the close of business on February 4, 2010. Distribution
sustainability is supported by the Partnership’s low-decline rate
Spraberry properties, its drilling inventory of 40-acre and 20-acre
locations and its strong derivative position through 2013 (of the
Partnership’s forecasted production, derivative contracts cover
approximately 85% in 2010, 75% in 2011 and 2012 and 60% in
2013).
Proved Reserves
The Partnership’s total proved oil and gas reserves as of
December 31, 2009 were 44 million barrels oil equivalent (MMBOE).
The year-end 2009 proved reserves include the Spraberry reserves
acquired from a subsidiary of Pioneer Natural Resources Company in
August 2009. Since this transaction represented a transaction
between entities under common control under generally accepted
accounting standards, the proved reserves acquired by the
Partnership are reflected as if the Partnership had acquired the
assets at the beginning of the period.
The new Securities and Exchange Commission (SEC) reporting rules
applicable for year-end 2009 reporting require that year-end proved
reserve volumes be calculated using an average of the NYMEX spot
prices for sales of oil and gas on the first calendar day of each
month during 2009. On this basis, the price of oil and gas for 2009
proved reserves reporting purposes was $61.14 per barrel and $3.87
per million British thermal units (MMBtu), respectively. The prices
used to calculate proved reserves for year-end 2008, when Pioneer
Southwest’s proved reserves were last reported, were $44.60 per
barrel of oil and $5.71 per MMBtu of gas, representing the NYMEX
spot prices on December 31, 2008 as required by the previous SEC
reporting rules. Since the Partnership’s production is primarily
oil and NGLs, year-end proved reserves increased by 4 MMBOE,
including the acquired properties, as a result of positive price
revisions based on the higher oil price used for 2009.
Additional reserves totaling approximately 5 MMBOE would be
added if SEC NYMEX pricing returned to $80 per barrel of oil and $6
per MMBtu of gas.
Netherland, Sewell & Associates, Inc., an independent
reserve engineering firm, audited 100% of Pioneer Southwest’s
proved reserves at year-end 2009.
Financial
Outlook
First quarter 2010 production is forecasted to average 5,800
BOEPD to 6,200 BOEPD. First quarter production costs (including
production and ad valorem taxes) are expected to average $20.00 to
$23.00 per BOE based on current NYMEX strip prices for oil, NGLs
and gas. Depreciation, depletion and amortization expense is
expected to average $5.00 to $6.00 per BOE.
General and administrative expense is expected to be $1 million
to $2 million. Interest expense is expected to be $400,000 to
$600,000. Accretion of discount on asset retirement obligations is
forecasted to be nominal.
Pioneer Southwest’s cash taxes and effective income tax rate are
expected to be approximately 1% as a result of Pioneer Southwest
being subject to the Texas margin tax.
Earnings Conference
Call
On Wednesday, February 3, 2010 at 11:00 a.m. Central Time,
Pioneer Southwest will discuss its financial and operating results
with an accompanying presentation. Instructions for listening to
the call and viewing the accompanying presentation are shown
below.
Internet: www.pioneersouthwest.comSelect
“Investors,” then “Earnings Calls & Webcasts” to listen to the
discussion and view the presentation.
Telephone: Dial (888) 452-4024
(confirmation code: 3410205) five minutes before the call to listen
to the discussion. View the presentation via Pioneer Southwest’s
internet address above.
A replay of the webcast will be archived on Pioneer Southwest’s
website. A telephone replay will be available through March 3 by
dialing (888) 203-1112 (confirmation code: 3410205).
Pioneer Southwest is a Delaware limited partnership
headquartered in Dallas, Texas. Pioneer Natural Resources formed
Pioneer Southwest to own and acquire oil and gas assets in its area
of operations. This area includes onshore Texas and eight counties
in the southeast region of New Mexico. For more information, visit
Pioneer Southwest’s website at www.pioneersouthwest.com.
Except for historical information contained herein, the
statements in this News Release are forward-looking statements that
are made pursuant to the Safe Harbor Provisions of the Private
Securities Litigation Reform Act of 1995. Forward-looking
statements and the business prospects of Pioneer Southwest are
subject to a number of risks and uncertainties that may cause
Pioneer Southwest’s actual results in future periods to differ
materially from the forward-looking statements. These risks and
uncertainties include, among other things, volatility of commodity
prices, the effectiveness of Pioneer Southwest's commodity price
derivative strategy, reliance on Pioneer Natural Resources Company
and its subsidiaries to manage Pioneer Southwest's business and
identify and evaluate drilling opportunities and acquisitions,
product supply and demand, competition, the ability to obtain
environmental and other permits and the timing thereof, other
government regulation or action, the ability to obtain approvals
from third parties and negotiate agreements with third parties on
mutually acceptable terms, litigation, the costs and results of
drilling and operations, access to and availability of drilling
equipment and transportation, processing and refining facilities,
Pioneer Southwest's ability to replace reserves, including through
acquisitions, and implement its business plans or complete its
development activities as scheduled, uncertainties associated with
acquisitions, access to and cost of capital, the financial strength
of counterparties to Pioneer Southwest’s credit facility and
derivative contracts and the purchasers of Pioneer Southwest’s oil,
NGL and gas production, uncertainties about estimates of reserves
and the ability to add proved reserves in the future, the
assumptions underlying production forecasts, quality of technical
data and environmental and weather risks. Sensitivity price cases
for proved reserves mentioned in this release may not be attained
or sustained. These and other risks are described in Pioneer
Southwest's 10-K and 10-Q Reports and other filings with the
Securities and Exchange Commission. In addition, Pioneer Southwest
may be subject to currently unforeseen risks that may have a
materially adverse impact on it. Pioneer Southwest undertakes no
duty to publicly update these statements except as required by
law.
An audit of proved reserves follows the general principles set
forth in the standards pertaining to the estimating and auditing of
oil and gas reserve information promulgated by the Society of
Petroleum Engineers (“SPE”). A reserve audit as defined by the SPE
is not the same as a financial audit. Please see Pioneer
Southwest’s Annual Report on Form 10-K for a general description of
the concepts included in the SPE’s definition of a reserve
audit.
PIONEER SOUTHWEST ENERGY PARTNERS L.P. CONDENSED
UNAUDITED CONSOLIDATED BALANCE SHEETS (in thousands)
December 31, December 31, 2009
2008
ASSETS
Current assets: Cash and cash equivalents $ 625 $ 29,936
Accounts receivable 14,162 12,606 Inventories 851 1,941 Prepaid
expenses 260 105 Derivatives 16,042 51,261
Total current assets 31,940
95,849 Property, plant and equipment, at cost: Oil
and gas properties, using the successful efforts method of
accounting 311,730 305,075 Accumulated depletion, depreciation and
amortization (113,386 ) (100,370 ) Total
property, plant and equipment 198,344 204,705
Deferred income taxes 1,964 - Other assets:
Derivatives 23,784 65,804 Other, net 606 806
$ 256,638 $ 367,164
LIABILITIES AND PARTNERS' EQUITY Current liabilities:
Accounts payable: Trade $ 6,139 $ 5,824 Due to affiliates 697 5,968
Interest payable 26 - Income taxes payable to affiliate 460 492
Deferred income taxes 127 521 Derivatives 3,606 - Asset retirement
obligations 500 99 Total current
liabilities 11,555 12,904
Long-term debt 67,000 - Derivatives 30,205 -
Deferred income taxes
- 101 Asset retirement obligations 6,605 6,328 Partners' equity
141,273 347,831 $ 256,638
$ 367,164
PIONEER SOUTHWEST ENERGY PARTNERS
L.P. UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF
OPERATIONS (in thousands, except for per unit data)
Three Months Ended Twelve
Months Ended December 31, December 31,
2009 2008 2009 2008 Revenues: Oil $
39,015 $ 35,156 $ 134,902 $ 155,333 Natural gas liquids 6,169 3,089
21,568 22,993 Gas 3,356 2,923 12,247 15,068 Interest and other
1 159 210 192
48,541 41,327 168,927
193,586 Costs and expenses: Oil and gas
production 9,487 9,677 34,749 38,807 Production and ad valorem
taxes 2,220 2,883 9,547 14,213 Depletion, depreciation and
amortization 2,950 3,474 13,016 11,582 General and administrative
1,004 1,405 4,790 6,227 Accretion of discount on asset retirement
obligations 121 36 484 144 Interest 432 192 1,160 621 Derivative
loss, net 43,344 - 78,265 - Other, net 297 599
549 890 59,855
18,266 142,560 72,484
Income (loss) before taxes (11,314 ) 23,061 26,367 121,102
Income tax benefit (provision) 183 (248 )
(46 ) (1,326 ) Net income (loss) $ (11,131 ) $ 22,813
$ 26,321 $ 119,776 Allocation of net
income (loss): (a) Net income (loss) applicable to the Partnership
Predecessor $ - $ 2,348 $ (1,598 ) $ 59,038 Net income (loss)
applicable to the Partnership (11,131 ) 20,465
27,919 60,738 $ (11,131 ) $ 22,813
$ 26,321 $ 119,776 Allocation of net
income (loss) applicable to the Partnership: Applicable to the
general partner's interest $ (11 ) $ 21 $ 28 $ 61 Applicable to the
limited partners' interest (11,120 ) 20,444
27,891 60,677 $ (11,131 ) $ 20,465
$ 27,919 $ 60,738 Net income (loss) per
common unit - basic and diluted $ (0.35 ) $ 0.68 $ 0.92
$ 2.02 Weighted average common units
outstanding - basic and diluted 31,557 30,009
30,399 30,009
_____________ (a) The following table provides the composition of
the historic accounting attributes of the Partnership, as combined
with the Partnership Predecessor:
Prior to May 6,
2008 through Subsequent to May 6,
2008 August 31, 2009 August
31, 2009 2008 IPO Acquisitions Partnership
Predecessor Partnership Partnership
2009 Acquisition
Partnership Predecessor Partnership Predecessor Partnership
PIONEER SOUTHWEST ENERGY PARTNERS L.P.
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands) Three Months
Ended Twelve Months Ended
December 31,
December 31,
2009 2008 2009 2008 Cash flows
from operating activities: Net income (loss) $ (11,131 ) $ 22,813 $
26,321 $ 119,776 Adjustments to reconcile net income to net cash
provided by operating activities: Depletion, depreciation and
amortization 2,950 3,474 13,016 11,582 Deferred income taxes (272 )
153 (470 ) 278 Accretion of discount on asset retirement
obligations 121 36 484 144 Inventory valuation adjustment - 159 -
159 Amortization of debt issuance costs 47 58 200 155 Derivative
related activity 32,373 (4,266 ) 51,254 (11,349 ) Change in
operating assets and liabilities, net of effects from acquisition
and disposition: Accounts receivable (1,820 ) 4,710 (1,556 ) 5,786
Inventories 167 (914 ) 1,090 (1,152 ) Prepaid expenses 121 79 (155
) (105 ) Accounts payable (4,548 ) (4,860 ) (6,853 ) 7,550 Interest
payable (84 ) - 26 - Income taxes payable to affiliate 89 56 (32 )
(196 ) Asset retirement obligations (65 ) (2 )
(803 ) (173 ) Net cash provided by operating activities
17,948 21,496 82,522
132,455 Cash flows from investing activities:
Payments for acquisition of carrying value (42 ) (1,438 ) (54,716 )
(142,274 ) Additions to oil and gas properties (2,821 )
(1,497 ) (3,760 ) (15,625 ) Net cash used in
investing activities (2,863 ) (2,935 ) (58,476
) (157,899 ) Cash flows from financing activities:
Borrowings under credit facility 12,000 - 150,000 - Principal
payments on credit facility (80,000 ) - (83,000 ) - Proceeds from
issuance of common units, net 60,983 - 60,983 163,045 Partner
contributions 64 - 64 24 Payments for acquisition in excess of
carrying value 1,438 1,438 (113,512 ) (20,795 ) Payment of
financing fees - - - (960 ) Distributions to general partner and
common unitholders (15,019 ) (15,019 ) (60,078 ) (24,331 ) Net
contributions from (distributions to) owner 42
(3,809 ) (7,814 ) (61,604 ) Net cash provided by
(used in) financing activities (20,492 ) (17,390 )
(53,357 ) 55,379 Net increase (decrease) in
cash and cash equivalents (5,407 ) 1,171 (29,311 ) 29,935 Cash and
cash equivalents, beginning of period 6,032
28,765 29,936 1 Cash and cash
equivalents, end of period $ 625 $ 29,936 $ 625
$ 29,936
PIONEER
SOUTHWEST ENERGY PARTNERS L.P. UNAUDITED SUMMARY PRODUCTION
AND PRICE DATA
Three Months Ended
Twelve Months Ended
December 31,
December 31,
2009 2008 2009 2008
Average Daily Sales Volumes:
Oil (Bbls) -
3,636 3,880 3,683 3,937
Natural gas liquids (Bbls) -
1,388 884 1,420 1,298 Gas (Mcf)
- 6,050 5,005 6,248 5,828 Total
(BOE) - 6,032 5,598 6,145 6,206
Average Reported Prices: Oil (per Bbl) - $ 116.65 $ 98.48 $ 100.35
$ 107.79 Natural gas liquids (per Bbl) - $ 48.32 $ 37.98 $
41.61 $ 48.41 Gas (per Mcf) - $ 6.03 $ 6.35 $ 5.37 $ 7.06
Total (BOE) - $ 87.47 $ 79.93 $ 75.23 $ 85.14
PIONEER SOUTHWEST ENERGY PARTNERS
L.P.UNAUDITED SUPPLEMENTAL NON-GAAP FINANCIAL MEASURES
(a)(in thousands)
EBITDAX and distributable cash flow (as defined below) are
presented herein and reconciled to the generally accepted
accounting principle ("GAAP") measures of net cash provided by
operating activities and net income (loss). Management of Pioneer
Southwest Energy Partners L.P. believes these financial measures
provide additional information to the investment community about
the Partnership's ability to generate sufficient cash flow to
sustain or increase distributions to its unitholders, among other
items. In particular, EBITDAX is used in the Partnership's credit
facility to determine the interest rate that we will pay on
outstanding borrowings and to determine compliance with the
leverage and interest coverage tests. EBITDAX and distributable
cash flow should not be considered as alternatives to net cash
provided by operating activities or net income (loss), as defined
by GAAP.
Three Months Ended Twelve
Months Ended December 31, 2009 (a) December 31, 2009
(a) Net cash provided by operating activities $ 17,948 $
82,522 Deduct: Depletion, depreciation and amortization (2,950 )
(13,016 ) Deferred income taxes 272 470 Accretion of discount on
asset retirement obligations (121 ) (484 ) Amortization of debt
issuance costs (47 ) (200 ) Derivative related activity (32,373 )
(51,254 ) Changes in operating assets and liabilities 6,140
8,283 Net income (loss) (11,131 )
26,321 Add: Depletion, depreciation and amortization 2,950 13,016
Accretion of discount on asset retirement obligations 121 484
Interest expense 432 1,160 Income tax provision (benefit) (183 ) 46
Derivative related activity 32,373 51,254
EBITDAX (b) 24,562 92,281 Deduct: Cash reserves to
maintain production and cash flow (4,487 ) (20,631 ) Cash interest
expense (385 ) (960 ) Cash income taxes (89 ) (516 )
Distributable cash flow (c) $ 19,601 $ 70,174
_____________ (a) The information shown represents
the activity of the Partnership, including the Partnership
Predecessor data. (b) "EBITDAX" represents earnings before
depletion, depreciation and amortization expense; accretion of
discount on asset retirement obligations; interest expense; income
taxes and noncash commodity derivative related activity. (c)
Distributable cash flow equals EBITDAX less the Partnership's
estimated cash reserves to maintain production and cash flow, cash
interest expense and cash income taxes.
PIONEER SOUTHWEST
ENERGY PARTNERS L.P. SUPPLEMENTAL INFORMATION Open
Commodity Derivative Positions as of January 18, 2010
2010 Twelve Months Ending December
31, First Second Third
Fourth Quarter Quarter
Quarter Quarter 2011 2012 2013
Average Daily Oil Production Associated with
Derivatives: Swap Contracts: Volume (Bbl) 2,500 2,500
2,500 2,500 750 3,000 3,000 NYMEX price (Bbl) $ 93.34 $ 93.34 $
93.34 $ 93.34 $ 77.25 $ 79.32 $ 81.02
Collar Contracts:
Volume (Bbl) - - - - 2,000 - - NYMEX price (Bbl): Ceiling $ - $ - $
- $ - $ 170.00 $ - $ - Floor $ - $ - $ - $ - $ 115.00 $ - $ -
Collar Contracts with Short Puts: Volume (Bbl) 750 1,000
1,000 1,250 1,000 1,000 1,000 NYMEX price (Bbl): Ceiling $ 87.10 $
87.18 $ 87.18 $ 89.06 $ 99.60 $ 103.50 $ 111.50 Floor $ 70.00 $
70.00 $ 70.00 $ 70.00 $ 70.00 $ 80.00 $ 83.00 Short Put $ 55.00 $
55.00 $ 55.00 $ 55.00 $ 55.00 $ 65.00 $ 68.00
Percent of total
oil production (a) ~90% ~90% ~90% ~90% ~90% ~90% ~85%
Average Daily NGL Production Associated with
Derivatives: Swap Contracts: Volume (Bbl) 750 750 750
750 750 750 - Blended index price (Bbl) (b) $ 52.52 $ 52.52 $ 52.52
$ 52.52 $ 34.65 $ 35.03 $ -
Percent of total NGL production
(a) ~55% ~55% ~55% ~55% ~55% ~50% N/A
Average Daily Gas
Production Associated with Derivatives: Swap
Contracts: Volume (MMBtu) 5,000 5,000 5,000 5,000 2,500 2,500
2,500 NYMEX price (MMBtu) (c) $ 7.44 $ 7.44 $ 7.44 $ 7.44 $ 6.65 $
6.77 $ 6.89
Percent of total gas production (a) ~90% ~90%
~90% ~90% ~45% ~40% ~40%
Basis Swap Contracts: Spraberry
index swaps (MMBtu) (d) 2,500 2,500 2,500 2,500 - - - Price
differential ($/MMBtu) $ (0.87 ) $ (0.87 ) $ (0.87 ) $ (0.87 ) $ -
$ - $ - _____________ (a) Represents approximate percentage of
forecasted production that is covered by derivative contracts. (b)
Represents the blended Mont Belvieu index prices per Bbl. (c) NYMEX
Henry Hub index price or approximate NYMEX Henry Hub index price
based on the differential to the index price on the derivative
trade date. (d) Represents swaps that fix the basis differentials
between the index at which the Partnership sells its Spraberry gas
and NYMEX Henry Hub index prices used in gas swap contracts.
PIONEER SOUTHWEST ENERGY PARTNERS L.P. UNAUDITED
SUPPLEMENTAL INFORMATION Derivative
Loss, Net (in thousands) Three Months
Ended Twelve Months Ended December 31, 2009
December 31, 2009 Noncash fair value changes: Oil
derivative loss $ 32,065 $ 57,229 NGL derivative loss 6,149 10,651
Gas derivative gain (1,873 ) (880 ) Total noncash
derivative loss, net 36,341 67,000 Cash settlements: Oil
derivative loss 6,117 10,630 NGL derivative loss 1,062 1,452 Gas
derivative gain (176 ) (817 ) Total cash derivative
loss, net 7,003 11,265 Total derivative
loss, net $ 43,344 $ 78,265
Deferred
Gains on Discontinued Commodity Hedges as of December 31, 2009
(in thousands) 2010 2011
Commodity hedge gains (a): Oil $ 37,100 $ 36,489 NGL 6,688 -
Gas 2,893 - Total $ 46,681 $
36,489 ______________ (a) Deferred commodity hedge
gains will be amortized as increases to oil and gas revenues during
the indicated future periods.
PIONEER SOUTHWEST ENERGY PARTNERS
L.P.UNAUDITED SUPPLEMENTAL NON-GAAP FINANCIAL
MEASURES(in millions, except per unit data)
Income adjusted for unrealized fair value derivative losses, as
presented in this press release, is presented and reconciled to the
Partnership’s net loss determined in accordance with GAAP because
the Partnership believes that this non-GAAP financial measure
reflects an additional way of viewing aspects of the Partnership’s
business that, when viewed together with its financial results
computed in accordance with GAAP, provides a more complete
understanding of factors and trends affecting its historical
financial performance and future operating results, greater
transparency of underlying trends and greater comparability of
results across periods. In addition, management believes that this
non-GAAP measure may enhance investors’ ability to assess the
Partnership’s historical and future financial performance. This
non-GAAP financial measure is not intended to be a substitute for
the comparable GAAP measure and should be read only in conjunction
with the Partnership’s consolidated financial statements prepared
in accordance with GAAP. Unrealized fair value derivative gains and
losses are of a type that will recur in future periods; however,
the amount can vary significantly from period to period. The table
below reconciles the Partnership’s net loss for the three months
ended December 31, 2009, as determined in accordance with GAAP, to
adjusted income excluding unrealized fair value losses for that
quarter.
After-tax Per Common Amounts
Unit Net loss applicable to the Partnership $ (11 ) $
(0.35 ) Unrealized fair value derivative losses 36
1.14 Adjusted income excluding
unrealized fair value losses $ 25 $ 0.79
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