Pioneer Southwest Energy Partners L.P. (“Pioneer
Southwest” or “the Partnership”) (NYSE:PSE) today
announced financial and operating results for the quarter ended
June 30, 2011.
Pioneer Southwest reported second quarter net income of $53
million, or $1.59 per common unit. Net income included unrealized
mark-to-market derivative gains of $28 million, or $0.84 per common
unit. Without the effect of this item, adjusted income for the
second quarter was $25 million, or $0.75 per common unit. Cash flow
from operations for the second quarter was $31 million.
Oil and gas sales for the second quarter averaged 6,689 barrels
oil equivalent per day (BOEPD), an increase of 4% compared to the
second quarter of 2010, reflecting the success of the Partnership’s
two-rig drilling program. Second quarter oil sales averaged 4,051
barrels per day (BPD), natural gas liquid (NGL) sales averaged
1,577 BPD and gas sales averaged 6 million cubic feet per day.
Second quarter oil sales were impacted by a shortage of oil
transport trucks in West Texas, reducing oil production by an
estimated 140 BPD. The Partnership is adding incremental oil
transport trucks in the third quarter to cover the second quarter
shortfall and forecasted production growth.
The second quarter average reported price for oil was $125.02
per barrel. The average reported price for NGLs was $44.92 per
barrel and the average reported price for gas was $3.39 per
thousand cubic feet.
The Partnership has a large inventory of oil drilling locations
in the Spraberry field, with approximately 110 40-acre locations
and 1,200 20-acre locations. For 2011, the Partnership’s capital
budget totals $67 million, consisting of $62 million for a two-rig
drilling program and $5 million for facilities. The 2011 drilling
program includes drilling 40 to 45 wells and is expected to
generate full-year production growth of approximately 5% compared
to 2010. Nine wells were placed on production during the second
quarter of 2011 and 12 additional wells were awaiting completion at
June 30, 2011. All wells are being completed in the Lower Wolfcamp
and organic rich shale/silt intervals. In addition, the Partnership
is completing wells in the deeper Strawn interval and evaluating
Atoka interval drilling opportunities in certain areas of the
field. Year-to-date well costs have averaged $1.5 million per
well.
The Partnership has additional borrowing capacity under its
credit facility of $213 million as of June 30, 2011, which is
expected to be adequate to fund future growth from the two-rig
drilling program and acquisitions.
Pioneer Southwest previously announced a cash distribution of
$0.51 per outstanding common unit for the quarter ended June 30,
2011, or $2.04 per outstanding common unit on an annual basis. The
distribution is payable August 11, 2011, to unitholders of record
at the close of business on August 1, 2011.
Distribution sustainability is supported by the Partnership’s
low-decline rate Spraberry properties, its large drilling inventory
of 40-acre and 20-acre locations and its strong derivative position
through 2014. Of the Partnership’s forecasted production,
derivative contracts cover approximately 70% in 2011, 80% in 2012,
60% in 2013 and 25% in 2014.
Third Quarter 2011 Financial
Outlook
The following paragraphs provide the Partnership’s third quarter
of 2011 outlook for certain operating and financial items.
Production is forecasted to average 6,700 BOEPD to 7,200 BOEPD.
Production costs (including production and ad valorem taxes) are
expected to average $20.00 to $23.00 per barrel oil equivalent
(BOE) based on current NYMEX strip prices for oil, NGLs and gas.
Depreciation, depletion and amortization expense is expected to
average $5.50 to $6.50 per BOE.
General and administrative expense is expected to be $1.25
million to $2.25 million. Interest expense is expected to be $400
thousand to $600 thousand. 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% of earnings before income taxes as
a result of Pioneer Southwest being subject to the Texas Margin
tax.
Earnings Conference Call
On Thursday, August 4, 2011, at 11:30 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 (877) 852-6581 confirmation
code: 6526556 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 August 25 by
dialing (888) 203-1112 confirmation code: 6526556.
Pioneer Southwest is a Delaware limited partnership,
headquartered in Dallas, Texas, with current production and
drilling operations in the Spraberry field in West Texas. For more
information, visit 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, availability of equipment, services and
personnel required to complete Pioneer Southwest’s operating
activities, access to and availability of 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, including the possible impacts of climate
change. 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.
PIONEER SOUTHWEST ENERGY PARTNERS
L.P.
UNAUDITED CONDENSED CONSOLIDATED
BALANCE SHEETS
(in thousands)
June 30, December 31, 2011
2010 ASSETS Current assets: Cash and
cash equivalents $ 1,201 $ 107 Accounts receivable 17,787 15,824
Inventories 1,025 883 Prepaid expenses 111 260 Deferred income
taxes 163 - Derivatives 9,619 18,753
Total current assets 29,906 35,827
Property, plant and equipment, at cost: Oil and gas
properties, using the successful efforts method of accounting:
Proved properties 401,346 364,237 Accumulated depletion,
depreciation and amortization (132,863 ) (125,963 )
Total property, plant and equipment 268,483
238,274 Deferred income taxes 1,634 1,751 Derivatives
2,884 3,783 Other, net 334 425 $
303,241 $ 280,060
LIABILITIES AND
PARTNERS' EQUITY Current liabilities: Accounts payable: Trade $
18,105 $ 8,422 Due to affiliates 1,509 1,164 Interest payable 143
30 Income taxes payable to affiliate 842 492 Deferred income taxes
- 63 Derivatives 20,936 9,673 Asset retirement obligations
500 1,000 Total current liabilities
42,035 20,844 Long-term debt 87,000
81,200 Derivatives 38,139 31,713 Asset retirement obligations
12,293 11,558 Partners' equity 123,774 134,745
$ 303,241 $ 280,060
PIONEER SOUTHWEST ENERGY PARTNERS
L.P.
UNAUDITED CONDENSED CONSOLIDATED
STATEMENTS OF CASH FLOWS
(in thousands)
Three Months Ended Six Months Ended June
30, June 30, 2011 2010
2011 2010 Revenues: Oil and gas $
54,504 $ 44,319 $ 104,286 $ 89,827 Interest and other -
- 2 -
54,504 44,319 104,288
89,827 Costs and expenses: Oil and gas production
9,127 9,130 18,376 18,257 Production and ad valorem taxes 3,508
2,917 6,831 5,999 Depletion, depreciation and amortization 3,572
3,100 6,900 6,068 General and administrative 1,834 1,628 3,414
3,152 Accretion of discount on asset retirement obligations 228 137
455 273 Interest 398 408 793 771 Derivative (gains) losses, net
(17,700 ) (28,781 ) 26,909
(40,305 ) 967 (11,461 ) 63,678
(5,785 ) Income before taxes 53,537 55,780 40,610
95,612 Income tax provision (607 ) (547 ) (407
) (933 ) Net income $ 52,930 $ 55,233 $ 40,203
$ 94,679 Allocation of net income: General
partner's interest $ 53 $ 55 $ 40 $ 95 Limited partners' interest
52,773 55,119 40,093 94,530 Unvested participating securities'
interest 104 59 70
54 Net income $ 52,930 $ 55,233 $ 40,203
$ 94,679 Net income per common unit - basic
and diluted $ 1.59 $ 1.66 $ 1.21 $ 2.85
Weighted average common units outstanding - basic and
diluted 33,114 33,114 33,114
33,114 Distributions declared per
common unit $ 0.51 $ 0.50 $ 1.01 $ 1.00
PIONEER SOUTHWEST ENERGY PARTNERS
L.P.
UNAUDITED CONDENSED CONSOLIDATED
STATEMENTS OF CASH FLOWS
(in thousands)
Three Months Ended Six Months Ended June
30, June 30, 2011 2010 2011
2010 Cash flows from operating activities: Net income
$ 52,930 $ 55,233 $ 40,203 $ 94,679
Adjustments to reconcile net income to net
cash provided by operating activities:
Depletion, depreciation and amortization 3,572 3,100 6,900 6,068
Deferred income taxes 402 366 58 583 Accretion of discount on asset
retirement obligations 228 137 455 273 Amortization of debt
issuance costs 46 46 91 91 Amortization of unit-based compensation
141 64 231 83 Commodity derivative related activity (27,755 )
(34,906 ) 9,628 (53,642 )
Change in operating assets and
liabilities, net of effects from acquisitions:
Accounts receivable (326 ) 1,504 (1,963 ) 549 Inventories 8 18 (142
) (3 ) Prepaid expenses 64 67 149 140 Accounts payable 1,356 1,360
2,381 1,849 Interest payable 10 (10 ) 113 (7 ) Income taxes payable
to affiliate 205 181 350 350 Asset retirement obligations
(103 ) (117 ) (286 ) (164 )
Net cash provided by operating
activities
30,778 27,043 58,168
50,849 Cash flows from investing activities:
Additions to oil and gas properties (14,955 ) (12,164
) (29,396 ) (21,879 ) Net cash used in investing
activities (14,955 ) (12,164 ) (29,396 )
(21,879 ) Cash flows from financing activities: Borrowings
under credit facility 16,904 14,000 32,904 31,000 Principal
payments on credit facility (14,904 ) (11,000 ) (27,104 ) (26,000 )
Distributions to unitholders (16,904 ) (16,574 )
(33,478 ) (33,148 ) Net cash used in financing
activities (14,904 ) (13,574 ) (27,678 )
(28,148 ) Net increase in cash and cash equivalents 919
1,305 1,094 822 Cash and cash equivalents, beginning of period
282 142 107 625
Cash and cash equivalents, end of period $ 1,201 $
1,447 $ 1,201 $ 1,447
PIONEER SOUTHWEST ENERGY PARTNERS
L.P.
UNAUDITED SUMMARY PRODUCTION AND PRICE
DATA
Three Months Ended Six Months Ended June
30, June 30, 2011 2010 2011
2010 Average Daily Sales Volumes: Oil (Bbls) -
4,051 3,897 4,093 3,865 Natural
gas liquids (Bbls) - 1,577 1,588 1,512
1,580 Gas (Mcf) - 6,366 5,832 6,381
5,934 Total (BOE) - 6,689 6,457
6,669 6,434 Average Reported Prices: Oil (per Bbl) -
$ 125.02 $ 101.85 $ 120.23 $ 102.70 Natural gas liquids (per
Bbl) - $ 44.92 $ 40.52 $ 41.60 $ 44.33 Gas (per Mcf) - $
3.39 $ 4.42 $ 3.32 $ 4.95 Total (per BOE) - $ 89.50 $ 75.42
$ 86.40 $ 77.14
PIONEER SOUTHWEST ENERGY PARTNERS
L.P.UNAUDITED SUPPLEMENTAL EARNINGS PER UNIT
INFORMATION(in thousands, except for per unit
amounts)
The Partnership follows the two-class method of calculating
basic and diluted net income per unit. Under the two-class method,
generally accepted accounting principle ("GAAP") provides that the
net income applicable to the Partnership be allocated to all
securities that participate in the Partnership's earnings.
Accordingly, net income applicable to the Partnership is allocated
to the General Partner, unvested participating securities and
common unitholders. Net losses applicable to the Partnership are
allocated to the General Partner and common unitholders but only to
unvested participating securities to the extent that they receive
distributions during loss periods because unvested participating
securities are not contractually obligated to share in the
Partnership's net losses. Unit- and unit-based awards with
guaranteed dividend or distribution participation rights qualify as
"participating securities" during their vesting periods. The
Partnership's basic and diluted net income per unit attributable to
common unitholders is computed as (i) net income applicable to the
Partnership, (ii) less General Partner net income, (iii) less
unvested participating securities' basic and diluted net income
(iv) divided by weighted average basic and diluted units
outstanding.
The following table provides a reconciliation of the
Partnership's net income applicable to the Partnership to basic and
diluted net income attributable to common unitholders, and the
calculation of net income per common unit - basic and diluted, for
the three and six months ended June 30, 2011 and 2010:
Three Months Ended Six Months
Ended June 30, June 30, 2011
2010 2011 2010 Net
income applicable to the Partnership $ 52,930 $ 55,233 $ 40,203 $
94,679 Less: General partner's interest (53 ) (55 ) (40 ) (95 )
Unvested participating securities' interest (104 )
(59 ) (70 ) (54 ) Basic and diluted net income
applicable to common unitholders $ 52,773 $ 55,119 $
40,093 $ 94,530 Weighted average basic and
diluted units outstanding 33,114 33,114
33,114 33,114 Net income per
common unit - basic and diluted $ 1.59 $ 1.66 $ 1.21
$ 2.85
PIONEER SOUTHWEST ENERGY PARTNERS
L.P.UNAUDITED SUPPLEMENTAL NON-GAAP FINANCIAL
MEASURES(in thousands)
EBITDAX and distributable cash flow (as defined below) are
presented herein and reconciled to the GAAP measures of net cash
provided by operating activities and net income. 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 the Partnership 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, as defined by
GAAP.
Three Months Ended
Six Months Ended June 30, 2011 June 30, 2011
Net cash provided by operating activities $ 30,778 $ 58,168
Add/(Deduct): Depletion, depreciation and amortization (3,572 )
(6,900 ) Deferred income taxes (402 ) (58 )
Accretion of discount on asset retirement
obligations
(228 ) (455 ) Amortization of debt issuance costs (46 ) (91 )
Amortization of unit-based compensation (141 ) (231 ) Commodity
derivative related activity 27,755 (9,628 ) Changes in operating
assets and liabilities (1,214 ) (602 ) Net
income 52,930 40,203 Add/(Deduct): Depletion, depreciation and
amortization 3,572 6,900 Accretion of discount on asset retirement
obligations 228 455 Interest expense 398 793 Income tax provision
607 407 Amortization of unit-based compensation 141 231 Commodity
derivative related activity (27,755 ) 9,628
EBITDAX (a) 30,121 58,617 Deduct: Cash reserves to maintain
production and cash flow (7,694 ) (14,542 ) Cash interest expense
(352 ) (702 ) Cash income taxes (205 ) (349 )
Distributable cash flow (b) $ 21,870 $ 43,024
(a)
"EBITDAX" represents earnings before
depletion, depreciation and amortization expense; accretion of
discount on asset retirement obligations; interest expense; income
taxes; amortization of unit-based compensation and noncash
commodity derivative related activity.
(b)
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 August 2, 2011
2011 Twelve Months Ending December 31,
Third Fourth
Quarter Quarter 2012 2013
2014 Oil Derivatives: Swap
contracts: Volume (Bbls per day) 750 750 3,000 3,000 - Price
per Bbl $ 77.25 $ 77.25 $ 79.32 $ 81.02 $ -
Collar
contracts: Volume (Bbl) 2,000 2,000 - - - Price per Bbl:
Ceiling $ 170.00 $ 170.00 $ - $ - $ - Floor $ 115.00 $ 115.00 $ - $
- $ -
Collar contracts with short puts: Volume (Bbl) 1,000
1,000 1,000 1,000 2,000 Price per Bbl: Ceiling $ 99.60 $ 99.60 $
103.50 $ 111.50 $ 133.00 Floor $ 70.00 $ 70.00 $ 80.00 $ 83.00 $
90.00 Short put $ 55.00 $ 55.00 $ 65.00 $ 68.00 $ 75.00
Percent
of total oil production (a) ~90% ~90% ~90% ~85% ~40%
NGL
Derivatives: Swap contracts: Volume (Bbls per day) 750
750 750 - - Price per Bbl (b) $ 34.65 $ 34.65 $ 35.03 $ - $ -
Percent of total NGL production (a) ~50% ~50% ~50% N/A N/A
Gas Derivatives: Swap contracts: Volume (MMBtus per
day) 2,500 2,500 5,000 2,500 - Price per MMBtu (c) $ 6.65 $ 6.65 $
6.43 $ 6.89 $ -
Percent of total gas production (a) ~40%
~40% ~80% ~40% N/A
Basis swap contracts: Permian Basin index
swaps (MMBtus per day) (d) - - 2,500 2,500 - Price differential
($/MMBtu) $ - $ - $ (0.30 ) $ (0.31 ) $ -
(a)
Represents an estimated
percentage of forecasted production, which may differ from the
percentage of actual production.
(b)
Represents blended Mont Belvieu index prices per Bbl.
(c)
Represents the NYMEX Henry Hub index price or approximate NYMEX
Henry Hub index price based on historical differentials to the
index price on the derivative trade date.
(d)
Represents swaps that fix the basis differentials between the index
price at which the Partnership sells its gas and NYMEX Henry Hub
index price used in gas swap contracts.
PIONEER SOUTHWEST ENERGY PARTNERS
L.P.
UNAUDITED SUPPLEMENTAL
INFORMATION
Derivative Gains (Losses), Net (in thousands)
Three Months Ended Six Months
Ended June 30, 2011 June 30, 2011 Noncash
changes in fair value: Oil derivative gains (losses) $ 26,864 $
(7,728 ) NGL derivative gains (losses) 569 (1,597 ) Gas derivative
gains (losses) 322 (303 ) Total noncash
derivative gains (losses), net 27,755 (9,628 )
Cash settled changes in fair value: Oil derivative losses
(8,925 ) (15,439 ) NGL derivative losses (1,662 ) (2,947 ) Gas
derivative gains 532 1,105 Total cash
derivative losses, net (10,055 ) (17,281 ) Total
derivative gains (losses), net $ 17,700 $ (26,909 )
Deferred Gains on Discontinued Commodity Hedges as of June 30,
2011 (in thousands)
Third Fourth Quarter Quarter
Commodity hedge gains (a): Oil $ 9,197 $ 9,197
(a)
Deferred commodity hedge gains will be
amortized as increases to oil revenues during the indicated future
periods.
PIONEER SOUTHWEST ENERGY PARTNERS
L.P.UNAUDITED SUPPLEMENTAL NON-GAAP FINANCIAL
MEASURES(in millions, except per unit data)
Net income adjusted for unrealized mark-to-market derivative
gains, as presented in this press release, is presented and
reconciled to the Partnership’s net income 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 mark-to-market 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 income for the
three months ended June 30, 2011, as determined in accordance with
GAAP, to adjusted income excluding unrealized mark-to-market
derivative gains for that quarter.
After-tax Per Common
Amounts Unit Net income $ 53 $ 1.59
Unrealized mark-to-market derivative gains (28 )
(0.84 ) Adjusted income excluding unrealized mark-to-market
derivative gains $ 25 $ 0.75
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