McMoRan Exploration Co. (NYSE: MMR):
HIGHLIGHTS
- Exploration & Development
Activities:
- Davy Jones
- Installation of production facilities
for field commenced in September 2011.
- Completion activities for the
development of Wilcox sands in Davy Jones No.1 well being advanced
with flow testing expected by year-end 2011.
- Completion and flow testing of Davy
Jones No. 2 well expected in the second half of 2012.
- Blackbeard East
- By-pass well drilling below 32,000 feet
to evaluate targets in the Eocene.
- Exploration results to date indicate
updip potential in the Miocene (178 net feet of hydrocarbons) above
25,000 feet and downdip potential in the Oligocene (Frio) below
30,000 feet.
- Lafitte
- Interim logging operations in September
2011 and recent logging operations in October 2011 indicated
several Lower Miocene sands that appear to be hydrocarbon bearing
and measure approximately 250 gross feet (115 feet net) in
aggregate.
- Drilled to 28,400 feet. Plan to deepen
to proposed total depth of 29,950 feet to evaluate deeper Miocene
and Oligocene objectives.
- Boudin
- Exploratory well commenced drilling on
February 27, 2011 and is drilling below 23,800 feet towards a
proposed total depth of 24,800 feet.
- Third-quarter 2011 production
averaged 187 MMcfe/d net to McMoRan, compared with 146 MMcfe/d in
the third quarter of 2010.
- Average daily production for
2011 is expected to approximate 187 MMcfe/d net to McMoRan,
including 170 MMcfe/d in fourth quarter 2011.
- Operating cash flows totaled
$42.4 million for the third quarter of 2011, including working
capital sources of $21.8 million and $51.2 million in abandonment
expenditures.
- Capital expenditures totaled
$145.0 million in the third quarter of 2011 and $403.9 million for
the nine months ended September 30, 2011.
- Cash at September 30, 2011
totaled $642.3 million.
McMoRan Exploration Co. (NYSE: MMR) today reported a net loss
applicable to common stock of $9.4 million, $0.06 per share, for
the third quarter of 2011 compared with a net loss applicable to
common stock of $25.3 million, $0.26 per share, for the third
quarter of 2010.
James R. Moffett and Richard Adkerson, McMoRan’s Co-Chairmen,
said, “Our ultra-deep drilling program continues to confirm our
geologic model which targets large structures in the shallow waters
of the Gulf of Mexico that are analogous to the hydrocarbon bearing
geologic formations seen onshore and in the deepwater. To
date, each of the five exploratory wells drilled below the salt
weld have confirmed the presence of hydrocarbon bearing sands.
The results to date highlight the potential for multi-Tcfe
reservoirs spanning a 200 square mile area on the Shelf of the Gulf
of Mexico. We look forward to results from our ongoing
drilling operations and the important flow test at Davy Jones,
which would be the first production from this significant and
emerging new geologic trend.”
SUMMARY FINANCIAL TABLE*
Third Quarter Nine Months 2011
2010 2011 2010 (In
thousands, except per share amounts) Revenues $ 138,183 $ 94,840 $
433,495 $ 335,369 Operating income (loss) 2,836 (10,927 ) (41,821 )
(57,397 ) Income (loss) from continuing operations 2,411 (19,545 )
(49,989 ) (86,316 ) Loss from discontinued operations (1,489 )
(1,184 ) (4,722 ) (4,260 )
Net loss applicable to common
stock(a,b,c,d)
(9,420 ) (25,253 ) (87,168 ) (113,159 ) Diluted net loss per share:
Continuing operations $ (0.05 ) $ (0.25 ) $ (0.52 ) $ (1.17 )
Discontinued operations
(0.01 )
(0.01 ) (0.03 )
(0.05 ) Applicable to common stock $
(0.06 ) $ (0.26 ) $ (0.55 ) $ (1.22 ) Diluted average shares
outstanding 159,195 95,469 158,505 92,789
Operating cash flows(e)
$ 42,373 $ 28,172 $ 178,513 $ 119,705
EBITDAX(f)
$ 66,668 $ 40,352 $ 242,258 $ 184,092 Capital expenditures $
144,995 $ 58,823 $ 403,889
$ 160,259
*
If any in-progress well or unproved
property is determined to be non-productive or no longer meets the
capitalization requirements under applicable accounting rules after
the date of this release but prior to the filing of McMoRan’s
September 30, 2011 Form 10-Q, the related costs incurred through
September 30, 2011 would be charged to expense in McMoRan’s
third-quarter 2011 financial statements. McMoRan’s total drilling
costs for its seven in-progress or unproven wells totaled $1,246.1
million, including $708.8 million in allocated costs associated
with property acquisitions.
a.
After preferred dividends.
b.
Includes impairment charges totaling $11.3
million in third-quarter 2011, $11.3 million in third-quarter 2010,
$62.0 million in the first nine months of 2011 and $82.0 million in
the first nine months of 2010 to reduce certain fields’ net
carrying value to fair value. Also includes adjustments for asset
retirement obligations associated with certain of McMoRan’s oil and
gas properties totaling approximately $10.4 million in the
third-quarter 2011 and $46.0 million in the first nine months of
2011.
c.
Includes charges to exploration expense
totaling $42.0 million in the first nine months of 2011 for
non-commercial well costs primarily associated with the Blueberry
Hill #9 STK1 well.
d.
Includes McMoRan’s share of insurance
reimbursements related to losses incurred from the September 2008
hurricanes totaling $22.6 million in third-quarter 2011, $5.6
million in the third-quarter 2010, $52.0 million in the first nine
months of 2011 and $14.8 million in the first nine months of
2010.
e.
Includes reclamation spending of $51.2
million in third-quarter 2011, $29.2 million in third-quarter 2010,
$93.4 million in the first nine months of 2011 and $70.8 million in
the first nine months of 2010. Also includes working capital
sources of $21.8 million in third-quarter 2011, $26.5 million in
third quarter 2010, $27.5 million in the first nine months of 2011
and $46.8 million in the first nine months of 2010.
f.
See reconciliation of EBITDAX to net loss
applicable to common stock on page II.
PRODUCTION AND DEVELOPMENT ACTIVITIES
Third-quarter 2011 production averaged 187 MMcfe/d net to
McMoRan, compared with 146 MMcfe/d in the third quarter of 2010.
Production in the third quarter of 2011 was higher than McMoRan’s
previously reported estimates of 180 MMcfe/d in July 2011 because
of favorable production performance. Production is expected to
average approximately 170 MMcfe/d in the fourth quarter of 2011 and
187 MMcfe/d for the year. McMoRan’s estimated production rates are
dependent on the timing of planned recompletions, production
performance, weather and other factors.
Production from the Flatrock field averaged a gross rate of
approximately 164 MMcfe/d (67 MMcfe/d net to McMoRan) in the third
quarter of 2011, compared with 182 MMcfe/d (34 MMcfe/d net to
McMoRan) in the third quarter of 2010. McMoRan owns a 55.0 percent
working interest and a 41.3 percent net revenue interest in the
Flatrock field.
EXPLORATION ACTIVITIES
McMoRan’s exploration strategy is focused in the shallow waters
of the Gulf of Mexico (GOM) and Gulf Coast area on the “ultra-deep
gas play” and on the “deep gas play.”
Shallow Water, Ultra-Deep Exploration Update
Since 2008, McMoRan has actively pursued large ultra-deep
targets located in the shallow waters of the GOM below the salt
weld (i.e. listric fault) at depths generally below 25,000 feet.
The data gained to date from five wells confirm McMoRan’s geologic
model and the highly prospective nature of this emerging geologic
trend. Prior to McMoRan’s involvement in the ultra-deep, there had
been only two wells drilled on the Shelf targeting these
objectives; one did not reach its targeted depth and the other was
outside McMoRan’s focus area. McMoRan’s results to date have
indicated the potential for large accumulations of hydrocarbons at
these deeper depths in the shallow waters of the GOM.
McMoRan’s activities to date have confirmed that drilling below
the salt weld on the Shelf of the GOM can be achieved safely. In
addition, the data indicate the presence below the salt weld of
geologic formations including Middle/Lower Miocene, Wilcox, Frio,
Tuscaloosa and Cretaceous carbonate. These formations have been
prolific onshore, in the deepwater GOM and in international
locations. McMoRan is encouraged by the results which indicate the
potential for prospects with high quality reservoirs on large
structures with multi-Tcfe of gross unrisked potential. McMoRan
intends to conduct further drilling and flow testing to determine
the ultimate potential of this emerging geologic trend.
In September 2011, McMoRan commenced installation of production
facilities on South Marsh Island Block 230 for the Davy
Jones field. McMoRan is in the process of mobilizing a drilling
rig to commence completion activities for the development of Wilcox
sands in the Davy Jones discovery well (Davy Jones No.1) with flow
testing expected by year-end 2011.
As previously reported, McMoRan has drilled two successful
sub-salt wells in the Davy Jones field. The Davy Jones No.1 well
logged 200 net feet of pay in multiple Wilcox sands, which were all
full to base. The Davy Jones offset appraisal well (Davy Jones No.
2), which is located two and a half miles southwest of Davy Jones
No. 1, confirmed 120 net feet of pay in multiple Wilcox sands,
indicating continuity across the major structural features of the
Davy Jones prospect, and also encountered 192 net feet of potential
hydrocarbons in the Tuscaloosa and Lower Cretaceous carbonate
sections. McMoRan has advanced the technology, equipment and
processes needed to develop this field and expects to complete and
flow test Davy Jones No. 1 by year-end 2011 and Davy Jones No. 2 in
the second half of 2012. Following successful flow tests, McMoRan
expects production from both wells to utilize new production
facilities currently being installed.
Davy Jones involves a large ultra-deep structure encompassing
four OCS lease blocks (20,000 acres). McMoRan holds a 63.4 percent
working interest and a 50.2 percent net revenue interest in Davy
Jones. Other working interest owners in Davy Jones include: Energy
XXI (NASDAQ: EXXI) (15.8%), JX Nippon Oil Exploration (U.S.A.)
Limited (12%) and Moncrief Offshore LLC (8.8%). McMoRan’s total
investment in Davy Jones, which includes $483.3 million in
allocated property acquisition costs, totaled $699.6 million at
September 30, 2011.
McMoRan commenced drilling the Blackbeard East ultra-deep
exploration by-pass well on August 25, 2011 at 30,630 feet. The
by-pass well is currently drilling below 32,000 feet to evaluate
Eocene objectives encountered in the original well prior to a
mechanical issue. The original well was drilled to 32,559 feet. The
by-pass well is permitted to 34,000 feet.
As reported in January 2011, wireline logs indicated that
Blackbeard East encountered hydrocarbon bearing sands in the
Oligocene (Frio) with good porosity below 30,000 feet. The well
previously encountered 178 net feet of hydrocarbons in the Miocene
sands above 25,000 feet. Pressure and temperature data below the
salt weld between 19,500 feet and 24,600 feet at Blackbeard East
indicate that a completion at these depths could utilize
conventional equipment and technologies.
Blackbeard East is located in 80 feet of water on South
Timbalier Block 144. McMoRan holds a 72.0 percent working interest
and a 57.4 percent net revenue interest in the well. Other working
interest owners in Blackbeard East include EXXI (18.0%) and
Moncrief Offshore LLC (10.0%). McMoRan’s total investment in
Blackbeard East, which includes $130.4 million in allocated
property acquisition costs, totaled $252.4 million at September 30,
2011.
The Lafitte ultra-deep exploration well, which is located
on Eugene Island Block 223 in 140 feet of water, commenced drilling
on October 3, 2010. Wireline logs from interim logging operations
in September 2011 and recent logging operations in October 2011
indicate several Lower Miocene sands that appear to be hydrocarbon
bearing. The sands have various thicknesses that aggregate
approximately 250 gross feet (115 feet net), some of which are
contained within a thin-bedded, sand-shale formation. These Lower
Miocene aged sands are correlative to Lower Miocene sands seen
onshore and in the deepwater of the GOM and provide additional
confirmation of McMoRan’s ultra-deep geologic model. Lafitte is
McMoRan’s third ultra-deep prospect to encounter Miocene age sands
below the salt weld on the GOM Shelf.
The Lafitte well has been drilled to 28,400 feet and will be
deepened to a proposed total depth of 29,950 feet to evaluate
deeper Miocene objectives and possibly the Oligocene section.
McMoRan holds a 72.0 percent working interest and a 58.3 percent
net revenue interest in Lafitte. Other working interest owners in
Lafitte include EXXI (18.0%) and Moncrief Offshore LLC (10.0%).
McMoRan’s total investment in Lafitte, which includes $35.9 million
in allocated property acquisition costs, totaled $130.5 million at
September 30, 2011.
McMoRan plans to commence drilling an ultra-deep well within the
Blackbeard West unit on Ship Shoal Block 188 in the fourth quarter
of 2011. The well has a proposed total depth of 26,000 feet and is
located approximately 4 miles west of the Blackbeard West #1 well
on South Timbalier Block 168. McMoRan holds a 67.3 percent working
interest and a 51.5 percent net revenue interest in the Blackbeard
West well on Ship Shoal Block 188.
Shallow Water, Deep Gas Exploration Update
In addition to the ultra-deep play on the Shelf of the GOM,
McMoRan’s exploration strategy is also focused on the “deep gas
play.” Deep gas prospects target large Miocene age deposits above
the salt weld (i.e. listric fault) at depths typically between
15,000 to 25,000 feet.
The Boudin deep gas exploration well, which is located in
20 feet of water on Eugene Island Block 26, commenced drilling on
February 27, 2011. The well is currently drilling below 23,800 feet
towards a proposed total depth of 24,800 feet to evaluate Miocene
objectives. McMoRan holds a 53.5 percent working interest and a
42.4 percent net revenue interest in Boudin. EXXI holds a 20.6
percent working interest. McMoRan’s total investment in Boudin,
which includes $14.8 million in allocated property acquisition
costs, totaled $51.3 million at September 30, 2011.
REVENUES
McMoRan’s third-quarter 2011 oil and gas revenues totaled $134.5
million, compared to $90.8 million during the third quarter of
2010. During the third quarter of 2011, McMoRan’s sales volumes
totaled 11.4 Bcf of gas, 674,700 barrels of oil and condensate and
1.8 Bcfe of plant products, compared to 8.8 Bcf of gas, 534,000
barrels of oil and condensate and 1.5 Bcfe of plant products in the
third quarter of 2010. McMoRan’s third-quarter comparable average
realizations for gas were $4.38 per thousand cubic feet (Mcf) in
2011 and $4.61 per Mcf in 2010; for oil and condensate McMoRan
received an average of $100.94 per barrel in third-quarter 2011
compared to $75.78 per barrel in third-quarter 2010.
CASH, LIQUIDITY AND CAPITAL EXPENDITURES
At September 30, 2011, McMoRan had $642.3 million in cash. Total
debt was $561.6 million at September 30, 2011, including $261.6
million in convertible securities. McMoRan had no borrowings and
$100 million of letters of credit issued under its revolving credit
facility resulting in total availability of $50 million at
September 30, 2011.
On October 6, 2011 McMoRan completed an exchange offer for its
$74.7 million 5¼% Convertible Senior Notes due 2011 (“existing
notes”). A total of $68.2 million of the existing notes were
accepted for exchange for an equal principal amount of newly issued
5¼% Convertible Senior Notes due 2012 (“new notes”). McMoRan repaid
the remaining $6.5 million of the existing notes, which matured on
October 6, 2011. The terms of the new notes are substantially
identical to the terms of the existing notes, except that the new
notes have a maturity date of October 6, 2012.
In September 8, 2011, McMoRan acquired Whitney Exploration LLC’s
(Whitney) 2.97% working interest in Davy Jones and 2% working
interest in Blackbeard East. Under the terms of the transaction,
McMoRan issued approximately 2.8 million shares of McMoRan common
stock and paid $10 million in cash to Whitney for these interests.
McMoRan’s common stock price on the closing date was $12.36 per
share. Total consideration, including the assumption of certain
drilling cost obligations, approximated $49 million.
McMoRan has approximately 161 million shares of common stock
outstanding. Assuming conversion of McMoRan’s remaining outstanding
8% Convertible Perpetual Preferred Stock, 4% Convertible Senior
Notes, 5¾% Convertible Perpetual Preferred Stock and the new notes,
McMoRan would have approximately 224 million common shares
outstanding on a fully converted basis.
Capital expenditures totaled $145.0 million for the third
quarter of 2011 and $403.9 million for the nine-months ended
September 30, 2011. McMoRan expects 2011 capital expenditures to
approximate $500-550 million, including $300-350 million for
exploration and $200 million for development. Capital spending will
continue to be driven by opportunities, drilling results and
follow-on development activities.
Net abandonment expenditures, which include scheduled
conventional and hurricane-related work, totaled $51.2 million for
the third quarter of 2011 and $93.4 million for the nine-months
ended September 30, 2011. Abandonment expenditures are expected to
approximate $140 million in 2011.
In the third quarter of 2011, McMoRan recorded $22.6 million in
gains for reimbursable costs associated with its insurance
programs. Since 2009, McMoRan has recorded $115.6 million in gains
associated with the 2008 hurricane events in the GOM and continues
to pursue reimbursement of certain hurricane-related abandonment
costs under its insurance programs.
WEBCAST INFORMATION
A conference call with securities analysts to discuss McMoRan’s
third-quarter 2011 results is scheduled for today at 10:00 a.m.
Eastern Time. The conference call will be broadcast on the internet
along with slides. Interested parties may listen to the conference
call live and view the slides by accessing “www.mcmoran.com”. A
replay of the webcast will be available through Friday, November
11, 2011.
McMoRan Exploration Co. is an independent public company engaged
in the exploration, development and production of natural gas and
oil in the shallow waters of the GOM Shelf and onshore in the Gulf
Coast area. Additional information about McMoRan is available on
its internet website “www.mcmoran.com”.
CAUTIONARY STATEMENT: This press release contains
forward-looking statements that involve a number of assumptions,
risks and uncertainties that could cause actual results to differ
materially from those contained in the forward-looking statements.
We caution readers that forward-looking statements are not
guarantees of future performance or exploration and development
success, and our actual exploration experience and future financial
results may differ materially from those anticipated, projected or
assumed in the forward-looking statements. Such forward-looking
statements include, but are not limited to, statements regarding
various oil and gas discoveries, oil and gas exploration,
development and production activities, capital expenditures,
reclamation costs, anticipated and potential production and flow
rates, and other statements that are not historical facts. No
assurance can be given that any of the events anticipated by the
forward-looking statements will transpire or occur, or if any of
them do so, what impact they may have on our results of operations
or financial condition. Important factors that may cause actual
results to differ materially from those anticipated by
forward-looking statements include, but are not limited to, those
associated with general economic and business conditions, failure
to realize expected value creation from acquired properties,
variations in the market demand for, and prices of, oil and natural
gas, drilling results, unanticipated fluctuations in flow rates of
producing wells due to mechanical or operational issues (including
those experienced at wells operated by third parties where we are a
participant), changes in oil and natural gas reserve expectations,
the potential adoption of new governmental regulations,
unanticipated hazards for which we have limited or no insurance
coverage, failure of third party partners to fulfill their capital
and other commitments, the ability to satisfy future cash
obligations and environmental costs, adverse conditions, such as
high temperatures and pressure that could lead to mechanical
failures or increased costs, the ability to retain current or
future lease acreage rights, the ability to satisfy future cash
obligations and environmental costs, access to capital to fund
drilling activities, as well as other general exploration and
development risks and hazards, and other factors described in more
detail in Part I, Item 1A. "Risk Factors" included in our Annual
Report on Form 10-K for the year ended December 31, 2010 filed with
the SEC as updated by our subsequent filings with the SEC.
Investors are cautioned that many of the assumptions upon which
our forward-looking statements are based are likely to change after
our forward-looking statements are made, including for example the
market prices of oil and natural gas, which we cannot control, and
production volumes and costs, some aspects of which we may or may
not be able to control. Further, we may make changes to our
business plans that could or will affect our results. We caution
investors that we do not intend to update our forward-looking
statements, notwithstanding any changes in our assumptions, changes
in our business plans, our actual experience, or other changes, and
we undertake no obligation to update any forward-looking statements
more frequently than quarterly.
This press release contains a financial measure, earnings before
interest, taxes, depreciation, amortization and exploration
expenses (EBITDAX), commonly used in the oil and natural gas
industry but not recognized under GAAP. As required by SEC
Regulation G, reconciliations of this measure to amounts reported
in McMoRan’s consolidated financial statements are included in the
supplemental schedules of this press release.
The SEC requires oil and gas companies, in their filings with
the SEC, to disclose proved reserves that a company has
demonstrated by actual production or conclusive formation tests to
be economically and legally producible under existing economic and
operating conditions. Beginning with year-end reserves for 2009,
the SEC permits oil and gas companies, in their filings with the
SEC, to disclose probable and possible reserves, as such terms are
defined by the SEC. We use certain phrases and terms in this press
release, such as "gross unrisked potential” and “resource
potential" which the SEC's guidelines prohibit us from including in
filings with the SEC “Gross unrisked potential” and “resource
potential” do not take into account the certainty of resource
recovery, which is contingent on exploration success, technical
improvements in drilling access, commerciality and other factors,
and are therefore not indicative of expected future resource
recovery and should not be relied upon. We urge you to consider
closely the disclosure of proved reserves included in our Annual
Report on Form 10-K for the year ended December 31, 2010 filed with
the SEC.
McMoRan EXPLORATION CO.
STATEMENTS OF OPERATIONS
(Unaudited)
Three Months Ended Nine Months Ended September 30, September
30, 2011 2010 2011 2010 (In Thousands, Except Per
Share Amounts)
Revenues: Oil and natural gas $ 134,548 $
90,778 $ 423,729 $ 323,727 Service 3,635 4,062
9,766 11,642 Total revenues 138,183 94,840 433,495 335,369
Costs and expenses: Production and delivery costs 61,182
a
47,071 161,050
a
136,295 Depletion, depreciation and amortization expense b 66,730
48,588 248,738 214,720 Exploration expenses c 18,158 5,256 78,832
28,099 Gain on oil and gas derivative contracts - (942 ) - (4,210 )
General and administrative expenses 11,877 11,148 39,052 35,267
Main Pass Energy Hub™ costs 49 230 562 805 Insurance recoveries d
(22,649 ) (5,584 ) (52,018 ) (14,755 ) Gain on sale of oil and gas
property - - (900 ) (3,455 ) Total
costs and expenses 135,347 105,767 475,316
392,766 Operating income (loss) 2,836 (10,927 ) (41,821 )
(57,397 ) Interest expense, net (629 ) (8,690 ) (8,782 ) (29,096 )
Other income, net 204 72 614 177 Income
(loss) from continuing operations before income taxes 2,411 (19,545
) (49,989 ) (86,316 ) Income tax expense - - -
- Income (loss) from continuing operations 2,411 (19,545 )
(49,989 ) (86,316 ) Loss from discontinued operations (1,489
) (1,184 ) (4,722 ) (4,260 ) Net income (loss)
922 (20,729 ) (54,711 ) (90,576 ) Preferred dividends and
inducement payments for early conversion of convertible preferred
stock (10,342 ) (4,524 )e (32,457 )e
(22,583 )e Net loss applicable to common stock $ (9,420 ) $ (25,253
) $ (87,168 ) $ (113,159 )
Basic and diluted net loss per
share of common stock: Continuing operations $(0.05 ) $(0.25 )
$(0.52 ) $(1.17 ) Discontinued operations (0.01 ) (0.01 ) (0.03 )
(0.05 ) Net loss per share of common stock $(0.06 ) $(0.26 ) $(0.55
) $(1.22 )
Average common shares outstanding: Basic and
diluted 159,195 95,469 158,505 92,789
a.
Includes approximately $15.3 million in
the third quarter and nine months ended September 30, 2011 for an
unproductive workover drilling project.
b.
Includes impairment charges totaling $11.3
million and $62.0 million in the third quarter and nine months
ended September 30, 2011, respectively, and $11.3 million and $82.0
million in the third quarter and nine months ended September 30,
2010, respectively. Also includes reclamation accrual adjustments
totaling approximately $10.4 million and $46.0 million for asset
retirement obligations associated with certain oil and gas
properties in the third quarter and nine months ended September 30,
2011, respectively. Approximately $18.7 million of these losses
were covered for reimbursement under McMoRan’s insurance
policies.
c.
Includes charges for non-productive well
costs and unproven leasehold cost reductions of $3.1 million and
$42 million in the third quarter and nine months ended September
30, 2011, respectively, and $0.1 million and $7.5 million in the
third quarter and nine months ended September 30, 2010,
respectively.
d.
Represents McMoRan’s share of insurance
reimbursements related to losses incurred from the September 2008
hurricanes.
e.
Includes payments of $1.5 million to
induce the conversion of approximately 8,100 shares of McMoRan’s 8%
convertible perpetual preferred stock (8% preferred stock) into
approximately 1.2 million shares of its common stock in the nine
months ended September 30, 2011. Includes payments of $1.4 million
to induce the conversion of approximately 7,000 shares of McMoRan’s
8% preferred stock into approximately 1.0 million shares of common
stock in the third quarter ended September 30, 2010 and $12.2
million of payments to induce conversion of approximately 64,200
shares of 8% preferred stock into approximately 9.4 million shares
of common stock in the nine months ended September 30, 2010.
McMoRan EXPLORATION CO.
RECONCILIATION OF REPORTED AMOUNTS TO
NON-GAAP ITEMS (Unaudited)
EBITDAX is a financial measure commonly used in the oil and
natural gas industry but is not a recognized accounting term under
accounting principles generally accepted in the United States of
America (GAAP). As defined by McMoRan, EBITDAX reflects the
company’s adjusted oil and gas operating income (loss). EBITDAX is
derived from net income (loss) from continuing operations before
other income, net; interest expense, net; income tax expense; Main
Pass Energy HubTM costs; exploration expenses; depletion,
depreciation and amortization expense; hurricane repair charges
included in production and delivery costs; stock-based compensation
charged to general and administrative expenses; insurance
recoveries; gain on sale of oil and gas property; and change in
fair value of oil and gas derivative contracts. EBITDAX should not
be considered by itself or as a substitute for net income (loss),
operating income (loss), cash flows from operating activities or
any other measure of financial performance presented in accordance
with GAAP, or as a measure of McMoRan’s profitability or liquidity.
Because EBITDAX excludes some, but not all, items that affect net
income (loss), the computation of this non-GAAP financial measure
may be different from similar presentations of other companies,
including oil and gas companies in our industry. As a result, the
EBITDAX data presented below may not be comparable to similarly
titled measures of other companies.
McMoRan’s management utilizes both the GAAP and non-GAAP results
presented in this news release to evaluate McMoRan’s performance
and believes that comparative analysis of results are useful to
investors and other internal and external users of our financial
statements in evaluating our operating performance, and such
analysis can be enhanced by excluding the impact of these items to
help investors meaningfully compare our results from period to
period. The following is a reconciliation of reported amounts from
net loss applicable to common stock to EBITDAX (in thousands):
Third Quarter Nine Months
2011 2010 2011
2010 Net loss applicable to common stock, as reported $ (9,420 ) $
(25,253 ) $ (87,168 ) $ (113,159 ) Preferred dividends and
inducement payments for early conversion of convertible preferred
stock 10,342 4,524 32,457 22,583 Loss from discontinued operations
1,489 1,184 4,722 4,260 Income (loss)
from continuing operations, as reported 2,411 (19,545 ) (49,989 )
(86,316 ) Other income, net (204 ) (72 ) (614 ) (177 )
Interest expense, net 629 8,690 8,782 29,096 Income tax expense - -
- - Main Pass Energy HubTM costs 49 230 562 805 Exploration
expenses 18,158 5,256 78,832 28,099 Depletion, depreciation and
amortization expense 66,730 48,588 248,738 214,720 Hurricane repair
charges included in production and delivery costs (44 ) 1,205 26
3,857 Stock-based compensation charged to general and
administrative expenses 1,588 1,629 8,460 8,153 Insurance
recoveries (22,649 ) (5,584 ) (52,018 ) (14,755 ) Gain on sale of
oil and gas property - - (900 ) (3,455 ) Change in fair value of
oil and gas derivative contracts - (45 ) - 4,065 Other -
- 379 - EBITDAX $ 66,668 $ 40,352 $ 242,258 $
184,092
McMoRan EXPLORATION CO.
OPERATING DATA (Unaudited)
Third Quarter Nine Months 2011 2010 2011 2010
Sales volumes: Gas (thousand cubic feet, or Mcf) 11,367,900
8,754,300 34,638,200 29,795,900 Oil (barrels) 674,700 534,000
2,139,800 1,851,900 Plant products (per Mcf equivalent) a 1,756,400
1,484,700 5,137,700 4,681,300 Average realizations: Gas (per Mcf) $
4.38 $ 4.61 $ 4.54 $ 4.97 Oil (per barrel) 100.94 75.78 102.56
76.13 a. Results include approximately $16.5 million
and $46.3 million of revenues associated with plant products
(ethane, propane, butane, etc.) during the third quarter and nine
months ended September 30, 2011, respectively. Plant product
revenues for the comparable prior year periods totaled $9.8 million
and $34.3 million. One Mcf equivalent is determined using an
estimated energy content differential ratio of six Mcf of natural
gas to one barrel of crude oil, condensate or natural gas liquids.
McMoRan EXPLORATION CO.
CONDENSED BALANCE SHEETS
(Unaudited)
September 30, December 31, 2011 2010 (In Thousands)
ASSETS Cash and cash equivalents $ 642,273 $ 905,684
Accounts receivable 109,428 86,516 Inventories 33,067 38,461
Prepaid expenses 12,835 15,478 Current assets from discontinued
operations, including restricted cash of $473 473 702
Total current assets 798,076 1,046,841 Property, plant and
equipment, net 2,021,198 1,785,607 Restricted cash 60,252 53,975
Deferred financing costs and other assets 8,863 9,952 Long-term
assets from discontinued operations 2,989 2,989 Total
assets $ 2,891,378 $ 2,899,364
LIABILITIES AND
STOCKHOLDERS’ EQUITY Accounts payable $ 116,397 $ 102,658
Accrued liabilities 162,897 99,363 Accrued interest and dividends
payable 22,448 6,768 Current portion of accrued oil and gas
reclamation costs 103,949 120,970
5 ¼% convertible senior notes
74,720
a
74,720 Current portion of accrued sulphur reclamation costs
(discontinued operations) 5,577 11,772 Current liabilities from
discontinued operations 1,545 1,993 Total current liabilities
487,533 418,244 11.875% senior notes 300,000 300,000 4% convertible
senior notes 186,836 185,256 Accrued oil and gas reclamation costs
193,384 237,654 Other long-term liabilities 16,060 16,596 Accrued
sulphur reclamation costs (discontinued operations) 14,282 13,494
Other long-term liabilities from discontinued operations
4,325 3,783 Total liabilities 1,202,420
1,175,027 Stockholders' equity 1,688,958 1,724,337
Total liabilities and stockholders' equity $ 2,891,378 $ 2,899,364
a. Approximately $68.2 million principal amount of
the 5¼% convertible senior notes was exchanged in early October
2011 for new convertible senior notes with similar terms and a new
maturity date of October 6, 2012.
McMoRan EXPLORATION CO.
STATEMENTS OF CASH FLOW
(Unaudited)
Nine Months Ended September 30, 2011 2010 (In
Thousands)
Cash flow from operating activities: Net loss $
(54,711 ) $ (90,576 ) Adjustments to reconcile net loss to net cash
provided by operating activities: Loss from discontinued operations
4,722 4,260 Depletion, depreciation and amortization expense
248,738 214,720 Exploration drilling and related expenditures
42,046 7,522 Compensation expense associated with stock-based
awards 15,618 15,701 Amortization of deferred financing costs 4,212
2,796 Change in fair value of oil and gas derivative contracts -
4,065 Reclamation expenditures, net of prepayments by third parties
(93,411 ) (70,786 ) Increase in restricted cash (3,760 ) (11,041 )
Gain on sale of oil and gas property (900 ) (3,455 ) Other (50 )
295 (Increase) decrease in working capital: Accounts receivable
(47,648 ) 16,340 Accounts payable and accrued liabilities 68,058
30,929 Prepaid expenses, inventories and other 7,056
(459 ) Net cash provided by continuing operations 189,970 120,311
Net cash used in discontinued operations (11,457 )
(606 ) Net cash provided by operating activities 178,513
119,705
Cash flow from investing activities:
Exploration, development and other capital expenditures (403,889 )
(160,259 ) Acquisition of oil and gas properties (10,000 ) -
Proceeds from sale of oil and gas property 900 2,920
Net cash used in continuing operations (412,989 ) (157,339 ) Net
cash activity from discontinued operations - - Net
cash used in investing activities (412,989 ) (157,339
)
Cash flow from financing activities: Dividends paid
and inducement payments on early conversion of convertible
preferred stock (27,609 ) (23,136 ) Credit facility refinancing
fees (1,712 ) - Debt and equity issuance costs (543 ) - Proceeds
from exercise of stock options and other 929 (455 )
Net cash used in continuing operations (28,935 ) (23,591 ) Net cash
activity from discontinued operations - - Net cash
used in financing activities (28,935 ) (23,591 ) Net
decrease in cash and cash equivalents (263,411 ) (61,225 ) Cash and
cash equivalents at beginning of year 905,684 241,418
Cash and cash equivalents at end of period $ 642,273 $ 180,193
Supplemental non-cash investing & financing
activities:
Issuance of 2.8 million shares of common
stock and other non-
cash purchase price consideration
related to property
acquisition
$ 39,198 $ -
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