NOBLE ENERGY, INC. HOUSTON, July 24, 2014 /PRNewswire/ -- Noble Energy, Inc. (NYSE: NBL) announced today second quarter 2014 net income of $192 million, or $0.52 per diluted share on total revenues of $1.4 billion. Excluding the impact of certain items, which would typically not be considered by analysts in published earnings estimates, second quarter 2014 adjusted income((1)) was $318 million, or $0.87 per diluted share. Discretionary cash flow((1)) was $887 million and net cash provided by operating activities was $827 million. Capital expenditures for the second quarter of 2014 totaled $1.3 billion.
Key highlights for the second quarter of 2014 include:
-- Delivered record horizontal production of 112 thousand barrels of oil
equivalent per day (MBoe/d) from the DJ Basin and Marcellus Shale plays,
56 percent higher than second quarter of last year
-- Increased wet gas type curves 10 percent for wells in the Majorsville
area of the Marcellus Shale play
-- Announced plans to form Marcellus midstream MLP
-- Exploration discovery made at the Katmai prospect located in the Gulf of
Mexico
-- Acquired interest in 17 exploration lease blocks in the Atwater Valley
area of the Gulf of Mexico and spud initial prospect
-- Leviathan resource estimate increased 16 percent to 22 trillion cubic
feet equivalent (Tcfe) of natural gas
-- Signed two regional export letters of intent for natural gas sales to
LNG facilities in Egypt.
-- Closed China asset sale, receiving $186 million in proceeds
Charles D. Davidson, Noble Energy's Chairman and CEO, commented, "We continued to make great progress on numerous fronts during the second quarter and find ourselves well-positioned to accelerate our growth profile in the second half of 2014 and into 2015. Our U.S. onshore horizontal programs have set yet another quarterly volume record and new completion techniques are enhancing well performance in both the DJ Basin and Marcellus programs. Our Gulf of Mexico program has built significant momentum with a commercial oil discovery at Katmai, as well as by adding a significant new lease position with attractive and sizeable prospects. In the meantime, development work is rapidly proceeding on prior Gulf discoveries, which will begin to deliver new production in 2015. In West Africa, both Aseng and Alen reached production milestones in the quarter. Finally in the Eastern Mediterranean, we have announced letters of intent with two new customers for over 1.1 Bcf/d that support the expansion at Tamar and first phase of Leviathan development. I am excited about the progress we are making and our outlook for the coming months and years."
VOLUMES AND PRICES
Second quarter 2014 sales volumes averaged 290 MBoe/d, an increase of 14 percent compared to the second quarter of 2013, after adjusting for divested assets. Total liquid sales were up 18 percent. U.S. sales volumes comprised 57 percent of the total and the remaining 43 percent came from International operations. U.S. volumes increased 25 percent, after adjusting for divested assets, driven by the continued horizontal development of the Marcellus Shale and DJ Basin plays. Internationally, volumes were up slightly as Alen volumes in Equatorial Guinea, which started up in the third quarter of last year, more than offset natural declines at Aseng.
Global crude oil and condensate prices averaged $102.53 per barrel for the second quarter of 2014. Natural gas realizations averaged $4.24 per thousand cubic feet (Mcf) in the U.S. and $5.57 per Mcf in Israel. Natural gas liquid pricing in the U.S. averaged 34 percent of the average West Texas Intermediate crude oil price for the quarter.
EXPENSES
Second quarter 2014 total production costs, including lease operating expense (LOE), production and ad valorem taxes, and transportation and gathering averaged $9.40 per barrel of oil equivalent (Boe). LOE and depreciation, depletion and amortization (DD&A) per Boe were $5.84 and $15.65, respectively. Exploration expense for the quarter was $59 million, which had no substantial dry hole costs or seismic expenditures. General and administrative expenses reflected an increase in staffing for major development and exploration activities.
Included in the adjustments to net income for the second quarter of 2014 were gains associated with non-core property sales, impairments to reflect the updated estimate of abandonment cost on non-producing properties and a non-cash commodity derivative loss. The effective tax rate on adjusted earnings for the quarter was 22 percent and the deferred portion of taxes on adjusted earnings was 63 percent.
OPERATIONS UPDATE
In the DJ Basin, sales volumes averaged 98 MBoe/d for the second quarter of 2014. Horizontal production averaged 70 MBoe/d, a quarterly record and up 33 percent compared to the same quarter last year. Production volumes for the quarter were lower than expected due to the Company's decision to upgrade facilities for over 60 wells, third-party processing plant downtime and related higher line pressures in certain areas of the field, as well as longer drilling lead times associated with extended reach lateral wells and larger pads. Drilling activity in the quarter included 80 operated wells of which 53 wells had standard length laterals and 27 wells were extended reach. Well completions totaled 66, while 85 wells were brought online.
Underlying well performance of the base program remains strong for both standard and extended length laterals, consistent with associated type curves. Downspacing and new completion techniques were also evaluated in the quarter. The Loeffler pad, the Company's initial downspacing test, continued to track above the type curve for the area. On the recently finished Peppler/Peaks pad, located in the Core IDP, a plug-n-perf completion design was employed in place of the traditional sliding sleeves design on two of the three wells. Initial 60-day results from the plug-n-pref design are showing more than 50 percent improvement versus the sliding sleeves completion. Additional testing is planned in the second half of the year. At the AA21 econode, including 12 wells in the Wells Ranch IDP, the Company tested multiple completions techniques and is using downhole measurement equipment to capture specific stage level recovery data. The pad has been on line for 30 days and all of the wells are exceeding expectations. The Company is operating 10 drilling rigs across the basin, primarily focused in the Wells Ranch and East Pony IDPs.
In the Marcellus Shale, volumes averaged a record 249 million cubic feet of natural gas equivalent per day (MMcfe/d) for the second quarter, a 120 percent increase versus the same quarter of last year. Gross production from the Joint Venture surpassed 650 MMcfe/d, up from the 70 MMcfe/d when it was formed three years ago. In the quarter, 24 operated wells were drilled averaging over 7,200 lateral feet and 12 operated wells initiated production.
Based on encouraging production performance in Majorsville, type curves for wells with standard completion designs were raised by 10 percent to a projected recovery of 10 Bcfe for a 7,000 foot lateral length well. The WFN6 pad in the Majorsville area came online in the quarter and had a 30-day rate of over 65 MMcfe/d from eight wells averaging over 6,100 lateral feet. Over the last 60 days of production the pad has tracked 50 percent above type curves for that area. Two of the wells were completed using enhanced completion techniques and experienced production rates 15 to 30 percent above standard completions on the same pad.
Joint Venture partner, CONSOL Energy, drilled 24 wells and brought online 23 wells from a number of pads. In addition, 6 recompletions were performed in the Greenhill area of Greene County PA. Two of the wells were turned to production at initial rates over 4 MMcf/d each, a substantial increase from the 200 to 400 Mcf/d the wells were producing prior to the recompletion. Combined, the Joint Venture partners are operating 10 horizontal rigs split between the wet and dry gas portions of the acreage.
In the Gulf of Mexico, production for the second quarter averaged 19 MBoe/d, which was comprised of nearly 88 percent liquids. Galapagos and Swordfish reported another quarter of strong field performance. The Katmai prospect has already encountered over 115 feet of net oil pay in the secondary targets and continues to drill towards the main objective. An extension well at Dantzler is underway and expected to be at total depth in the third quarter. This well is designed to test an adjacent fault block and better define the scope of the field's development. Seventeen exploration lease blocks located in the Atwater Valley area were added to the Company's inventory through a farm-in. The initial well exploration prospect on these blocks, Bright, is drilling, targeting multiple Miocene reservoirs. It is anticipated to be at total depth during the third quarter.
In West Africa, product sales averaged 82 MBoe/d in the quarter. Aseng reached a milestone of 50 million gross barrels of oil produced and continues to perform above expectations at rates of 40 MBbl/d. Alen has been online for a full year now and production has grown to a record 30 MBbl/d gross following recent facility enhancements. Additional workover activities are underway, including a sidetrack of one well, which is expected to further increase production by the end of the year.
In the Eastern Mediterranean, Israel sales volumes for the second quarter of 2014 averaged 220 MMcfe/d. Natural gas demand was generally within seasonal norms, but impacted by a late start to the summer cooling period. Tamar continued to have exceptional uptime performance reporting less than 30 minutes of downtime in the quarter. The onshore compression project at Ashdod, which will expand the deliverability of Tamar by 200 MMcf/d gross, is over 60 percent complete with all major equipment installed. Two letters of intent to sell natural gas to regional customers were signed during the quarter, one involving Tamar for 440 MMcf/d gross and another related to Leviathan for 700 MMcf/d gross. Total gross resources for Leviathan were increased to 22 Tcfe from 19 Tcfe, as a result of continued evaluation work by the Company and a third-party engineering firm. Progress continues to be made on the first phase of Leviathan with the receipt of approval by the National Planning Committee of a site permit for a northern gas delivery point.
UPDATED GUIDANCE
Volumes for third quarter 2014 are anticipated to be between 290 and 305 MBoe/d and the fourth quarter volumes to range from 310 to 330 MBoe/d. These second half estimates are lower than earlier expectations primarily due to more conservative assumptions in the DJ Basin for infrastructure capacity and timing of well tie-ins. Infrastructure capacity constraints are related to higher than expected third-party midstream downtime, high field line pressures and the carryover impacts from facility enhancements. Included in the third quarter estimate is a 12 MBbl/d oil reduction versus the second quarter attributable to a significant underlifting in Equatorial Guinea, as well as the China asset sale. The third quarter estimate also included a reduced assumption for natural gas sales in Israel as a result of the ongoing conflict.
Detailed guidance is available in the supplemental information for the conference call.
(1) A Non-GAAP measure, see attached Reconciliation Schedules
WEBCAST AND CONFERENCE CALL INFORMATION
Noble Energy, Inc. will host a webcast and conference call at 9:00 a.m. Central time today. The webcast is accessible on the 'Investors' page at www.nobleenergyinc.com. Conference call numbers for participation are 888-339-3482 and 719-325-2282.The pass code number is 3281759. A replay will be available on the website.
Noble Energy is a leading independent energy company engaged in worldwide oil and gas exploration and production. The Company has core operations onshore in the U.S., primarily in the DJ Basin and Marcellus Shale, in the deepwater Gulf of Mexico, offshore Eastern Mediterranean, and offshore West Africa. Noble Energy is listed on the New York Stock Exchange and is traded under the ticker symbol NBL. Further information is available at www.nobleenergyinc.com.
This news release contains certain "forward-looking statements" within the meaning of federal securities law. Words such as "anticipates", "believes," "expects", "intends", "will", "should", "may", and similar expressions may be used to identify forward-looking statements. Forward-looking statements are not statements of historical fact and reflect Noble Energy's current views about future events. They include estimates of oil and natural gas reserves and resources, estimates of future production, assumptions regarding future oil and natural gas pricing, planned drilling activity, future results of operations, projected cash flow and liquidity, business strategy and other plans and objectives for future operations. No assurances can be given that the forward-looking statements contained in this news release will occur as projected and actual results may differ materially from those projected. Forward-looking statements are based on current expectations, estimates and assumptions that involve a number of risks and uncertainties that could cause actual results to differ materially from those projected. These risks include, without limitation, the volatility in commodity prices for crude oil and natural gas, the presence or recoverability of estimated reserves, the ability to replace reserves, environmental risks, drilling and operating risks, exploration and development risks, competition, government regulation or other actions, the ability of management to execute its plans to meet its goals and other risks inherent in Noble Energy's business that are discussed in its most recent annual report on Form 10-K and in other reports on file with the Securities and Exchange Commission. These reports are also available from Noble Energy's offices or website, http://www.nobleenergyinc.com. Forward-looking statements are based on the estimates and opinions of management at the time the statements are made. Noble Energy does not assume any obligation to update forward-looking statements should circumstances, management's estimates, or opinions change.
This news release also contains certain historical non-GAAP measures of financial performance that management believes are good tools for internal use and the investment community in evaluating Noble Energy's overall financial performance. These non-GAAP measures are broadly used to value and compare companies in the crude oil and natural gas industry. Please see the attached schedules for reconciliations of the differences between any historical non-GAAP measures used in this news release and the most directly comparable GAAP financial measures.
The Securities and Exchange Commission 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. The SEC permits the optional disclosure of probable and possible reserves; however, we have not disclosed the Company's probable and possible reserves in our filings with the SEC. We use certain terms in this news release, such as "resource estimates", "10 Bcfe for 7,000 foot lateral length" and "total gross resources". These estimates are by their nature more speculative than estimates of proved, probable and possible reserves and accordingly are subject to substantially greater risk of being actually realized. The SEC guidelines strictly prohibit us from including these estimates in filings with the SEC. Investors are urged to consider closely the disclosures and ris factors in our most recent annual report on Form 10-K and in other reports on file with the SEC, available from Noble Energy's offices or website, http://www.nobleenergyinc.com.
Schedule 1
Noble Energy, Inc.
Reconciliation of Net Income to Adjusted Income
(in millions, except per share amounts, unaudited)
Three Months Ended June 30, Six Months Ended June 30,
--------------------------- -------------------------
2014 Per 2013 Per 2014 Per 2013 Per
Diluted Diluted Diluted Diluted
Share Share Share Share
--- ----- ----- ----- -----
Net Income $192 $0.52 $377 $1.04 $392 $1.07 $639 $1.76
(Gain) loss on commodity derivatives, net of cash
settlements [1] 187 0.52 (159) (0.44) 228 0.62 (80) (0.21)
Asset impairments [2] 34 0.09 - - 131 0.36
(Gain) on divestitures [3] (44) (0.12) (17) (0.05) (42) (0.12) (67) (0.19)
Other adjustments (1) (3) (0.01)
--- --- -----
Total adjustments before tax 176 0.49 (166) (0.46) 317 0.86 (150) (0.41)
Income tax effect of (50) (0.14) 39 0.11 (93) (0.24) 22 0.06
adjustments [4]
Adjusted Income $318 $0.87 $250 $0.69 $616 $1.69 $511 $1.41
---- ----- ---- ----- ---- ----- ---- -----
Weighted average number of shares outstanding
Diluted 366 363 365 362
NOTE: Adjusted
income should
not be
considered a
substitute
for net
income as
reported in
accordance
with GAAP.
Adjusted
income is
provided for
comparison to
earnings
forecasts
prepared by
analysts and
other third
parties. Our
management
believes, and
certain
investors may
find, that
adjusted
income is
beneficial in
evaluating
our financial
performance.
We believe
such measures
can
facilitate
comparisons
of operating
performance
between
periods and
with our
peers. See
Schedule 2:
Summary
Statement of
Operations
All per share
and shares
outstanding
amounts have
been
retroactively
adjusted for
the two-for-
one stock
split, which
was
distributed
on May 28,
2013 to
shareholders
of record as
of May 14,
2013.
[1] Many factors
impact our
gain or loss
on commodity
derivatives,
net of cash
settlements,
including:
increases and
decreases in
the commodity
forward price
curves
compared to
our executed
hedging
arrangements;
increases in
hedged future
volumes; and
the mix of
hedge
arrangements
between NYMEX
WTI, Dated
Brent and
NYMEX HH
commodities.
These gains
or losses on
commodity
derivatives,
net of cash
settlements
recognized in
the current
period will
be realized
in the future
when cash
settlement
occurs.
[2] Amount for
2014
primarily
represents
impairment
related to
the North Sea
recorded in
the first
quarter and
non-
producing
properties in
the second
quarter.
[3] During 2014
and 2013 we
sold certain
non-core
onshore U.S.
properties
and our China
assets.
[4] The income tax
effect of
adjustments
are
determined
for each
major tax
jurisdiction
for each
adjusting
item.
Schedule 2
Noble Energy, Inc.
Summary Statement of Operations
(in millions, except per share amounts, unaudited)
Revenues Three Months Ended Six Months Ended
June 30, June 30,
-------- --------
2014 2013 2014 2013
---- ---- ---- ----
Crude oil and condensate $971 $817 $1,899 $1,667
Natural gas 297 253 622 432
Natural gas liquids 70 42 144 97
Income from equity method investees 45 37 97 96
--- --- --- ---
Total revenues 1,383 1,149 2,762 2,292
----- ----- ----- -----
Operating Expenses
Lease operating expense 154 140 299 257
Production and ad valorem taxes 53 43 102 86
Transportation and gathering expense 41 27 80 55
Exploration expense 59 90 133 151
Depreciation, depletion and
amortization 413 368 837 734
General and administrative 127 104 266 216
(Gain) loss on divestitures (44) 4 (42) (12)
Asset impairments 34 - 131
Other operating expense, net 17 12 23 20
--- --- --- ---
Total operating expenses 854 788 1,829 1,507
--- --- ----- -----
Operating Income 529 361 933 785
Other (Income) Expense
(Gain) loss on commodity derivative
instruments 236 (161) 311 (89)
Interest, net of amount capitalized 52 33 99 58
Other non-operating (income) expense,
net 8 3 13 12
--- --- --- ---
Total other (income) expense 296 (125) 423 (19)
--- ---- --- ---
Income from Continuing Operations
Before Income Taxes 233 486 510 804
Income Tax Provision 41 128 118 214
--- --- --- ---
Income from Continuing Operations 192 358 392 590
Discontinued Operations, Net of Tax - 19 - 49
--- --- --- ---
Net Income $192 $377 $392 $639
---- ---- ---- ----
Earnings Per Share [1]
Basic
Income from continuing operations $0.53 $1.00 $1.09 $1.64
Discontinued operations, net of tax - 0.05 - 0.14
--- ---- --- ----
Net Income $0.53 $1.05 $1.09 $1.78
----- ----- ----- -----
Diluted
Income from continuing operations $0.52 $0.99 $1.07 $1.63
Discontinued operations, net of tax - 0.05 - 0.13
--- ---- --- ----
Net Income $0.52 $1.04 $1.07 $1.76
----- ----- ----- -----
Weighted average number of shares outstanding [1]
Basic 361 359 361 358
Diluted 366 363 365 362
[1] All per share and shares
outstanding amounts have been
retroactively adjusted for the
two-for-one stock split, which
was distributed on May 28, 2013
to shareholders of record as of
May 14, 2013.
Schedule 3
Noble Energy, Inc.
Volume and Price Statistics
(unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
-------- --------
2014 2013 2014 2013
---- ---- ---- ----
Crude Oil and Condensate Sales Volumes (MBbl/d)
United States 65 58 65 60
Equatorial Guinea 34 31 34 29
Other International 5 4 5 4
--- --- --- ---
Total consolidated operations 104 93 104 93
Equity method investee 2 1 2 2
--- --- --- ---
Total sales volumes 106 94 106 95
--- --- --- ---
Crude Oil and Condensate Realized Prices ($/Bbl)
United States $99.39 $94.29 $98.22 $95.02
Equatorial Guinea 108.08 101.44 106.92 106.20
Other International 104.70 97.92 104.48 103.66
------ ----- ------ ------
Consolidated average realized prices $102.53 $96.84 $101.39 $98.87
------- ------ ------- ------
Natural Gas Sales Volumes (MMcf/d)
United States 469 404 476 406
Equatorial Guinea 248 252 245 249
Israel 218 220 218 166
--- --- --- ---
Total sales volumes 935 876 939 821
--- --- --- ---
Natural Gas Realized Prices ($/Mcf)
United States $4.24 $4.04 $4.52 $3.68
Equatorial Guinea 0.27 0.27 0.27 0.27
Israel 5.57 4.92 5.59 5.00
---- ---- ---- ----
Consolidated average realized prices $3.50 $3.18 $3.66 $2.91
----- ----- ----- -----
Natural Gas Liquids Sales Volumes (MBbl/d)
United States 22 15 20 15
Equity method investee 6 5 6 6
--- --- --- ---
Total sales volumes 28 20 26 21
--- --- --- ---
Natural Gas Liquids Realized Prices ($/Bbl)
United States $34.66 $30.05 $39.10 $34.63
Barrels of Oil Equivalent Volumes (MBoe/d)
United States 166 140 165 143
Equatorial Guinea 75 73 74 70
Israel 37 37 37 28
Other International 5 4 5 4
--- --- --- ---
Total consolidated operations 283 254 281 245
Equity method investee 7 6 7 8
--- --- --- ---
Total barrels of oil equivalent from
continuing operations 290 260 288 253
Total barrels of oil equivalent from
discontinued operations - 2 - 1
--- --- --- ---
Total barrels of oil equivalent 290 262 288 254
--- --- --- ---
Schedule 4
Noble Energy, Inc.
Condensed Balance Sheets
(in millions, unaudited)
ASSETS June 30, December 31,
2014 2013
---- ----
Current Assets
Cash and cash equivalents $958 $1,117
Accounts receivable, net 1,004 947
Other current assets 312 547
--- ---
Total current assets 2,274 2,611
Net property, plant and equipment 16,976 15,725
Goodwill 621 627
Other noncurrent assets 704 679
--- ---
Total Assets $20,575 $19,642
------- -------
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities
Accounts payable - trade $1,369 $1,354
Other current liabilities 866 988
--- ---
Total current liabilities 2,235 2,342
Long-term debt 5,160 4,566
Deferred income taxes 2,483 2,441
Other noncurrent liabilities 1,143 1,109
----- -----
Total Liabilities 11,021 10,458
Total Shareholders' Equity 9,554 9,184
----- -----
Total Liabilities and Shareholders' Equity $20,575 $19,642
------- -------
Schedule 5
Noble Energy, Inc.
Discretionary Cash Flow and Reconciliation to Net Cash Provided by Operating Activities
(in millions, unaudited)
Three Months Ended Six Months Ended
June 30,
June 30,
--------
2014 2013 2014 2013
---- ---- ---- ----
Adjusted Income [1] $318 $250 $616 $511
Adjustments to reconcile adjusted income to discretionary cash flow:
Depreciation, depletion and amortization 412 368 837 736
Exploration expense 59 90 133 151
(Income)/Dividends from equity method
investments, net 10 17 (3) (18)
Deferred compensation expense 8 3 12 14
Deferred income taxes 58 17 117 88
Stock-based compensation expense 22 20 45 38
Other - - - 3
--- --- --- ---
Discretionary Cash Flow $887 $765 $1,757 $1,523
---- ---- ------ ------
Reconciliation to Operating Cash Flows
Net changes in working capital (13) (159) 105 (168)
Cash exploration costs (47) (60) (107) (114)
Current tax benefit of earnings adjustments (5)
Other adjustments (7) 2 8
--- --- ---
Net Cash Provided by Operating Activities $827 $539 $1,757 $1,244
---- ---- ------ ------
Capital expenditures (accrual based) $1,272 $1,135 $2,223 $2,040
Increase in capital lease obligations [2] 16 31 21 36
--- --- --- ---
Total Capital Expenditures (Accrual
Based) $1,288 $1,166 $2,244 $2,076
------ ------ ------ ------
NOTE: The table
above
reconciles
discretionary
cash flow to
net cash
provided by
operating
activities.
While
discretionary
cash flow is
not a GAAP
measure of
financial
performance,
our
management
believes it
is a useful
tool for
evaluating
our overall
financial
performance.
Among our
management,
research
analysts,
portfolio
managers and
investors,
discretionary
cash flow is
broadly used
as an
indicator of
a company's
ability to
fund
exploration
and
production
activities
and meet
financial
obligations.
Discretionary
cash flow is
also
commonly
used as a
basis to
value and
compare
companies in
the oil and
gas
industry.
See Schedule
1:
Reconciliation
of Net
Income to
Adjusted
[1] Income.
[2] Increase in
capital
lease
obligations
represents
estimated
construction
in progress
to date on
US operating
assets and
corporate
buildings.
SOURCE Noble Energy
