- Quarterly capital expenditures totaled $527 million, below the low end of guidance, and less than discretionary cash
flow(1) and cash flow from operations.
- Exited the fourth quarter of 2015 with $5 billion in liquidity, including cash on hand and undrawn credit facility.
- Continued strong performance in all core areas drove record quarterly sales volumes of 422 MBoe/d, above the increased
guidance range. Set a new quarterly record for DJ Basin volumes of 121 MBoe/d.
- Reduced unit lease operating expense 36 percent year over year to $3.76 per BOE.
- Continued drilling and completion efficiencies across the entire U.S. Onshore region, highlighted by normalized well
costs under $3 million in Wells Ranch for extended reach laterals.
- Commenced production on five Lower Eagle Ford wells, averaging a 30-day IP of approximately 5 MBoe/d per well.
- Big Bend and Dantzler projects, in the deepwater Gulf of Mexico, reached combined peak production of over 20 MBoe/d,
net.
- Israel regulatory framework was implemented and the first export permit was granted for future gas sales to Egypt.
- Organic reserve additions replaced 2015 production 1.5 times (excluding acquisitions and price-related revisions).
HOUSTON, Feb. 17, 2016 (GLOBE NEWSWIRE) -- Noble Energy, Inc. (NYSE:NBL) (“Noble Energy” or “the Company”) announced today
results for the fourth quarter of 2015, including adjusted net income(1) of $191 million, or $0.44 per diluted
share. A reported net loss for the quarter of $2.0 billion was negatively impacted by $2.2 billion of primarily non-cash
items, which are not considered by analysts in published estimates. Net cash provided by operating activities of $576 million
and discretionary cash flow(1) of $609 million were in excess of capital expenditures of $527 million.
Total Company volumes for the fourth quarter of 2015 increased to 422 thousand barrels of oil equivalent per day (MBoe/d), up
more than eight percent versus the third quarter of 2015 and the fourth quarter of 2014 (pro-forma for the Rosetta Resources Inc.
merger). Liquids comprised 47 percent (33 percent crude oil and condensate and 14 percent natural gas liquids) of fourth
quarter 2015 volumes, with natural gas the remaining 53 percent. U.S. sales volumes for the quarter totaled 295 MBoe/d, while
International sales volumes were 127 MBoe/d. Total sales volumes were higher than produced volumes by more than five thousand
barrels per day (MBbl/d) due to the timing of liquids lifting in Equatorial Guinea.
Excluding the Company’s Texas properties, which were acquired in July of 2015, sales volumes were 362 MBoe/d for the fourth
quarter of 2015, up 15 percent compared to the fourth quarter of the previous year. This increase was primarily a result of
the Company’s continued horizontal completions and production optimization within the U.S. unconventional assets, the startup of
Big Bend and Dantzler in the deepwater Gulf of Mexico, and higher Israel natural gas demand.
David L. Stover, Noble Energy’s Chairman, President and CEO, commented, “Noble Energy ended 2015 by delivering another
outstanding operational quarter. We have substantially improved capital efficiency across our business, evidenced by a
continued reduction in well costs as well as completion enhancements in each of our core onshore assets. At the same time,
our unit operating costs have been reduced to the lowest level in the last eight years. We also successfully integrated our
new Texas assets and have quickly delivered a step-change in performance. Our offshore major project proficiency was
demonstrated once again with new project startups in the Gulf of Mexico, and we have established strong forward momentum for our
projects in the Eastern Mediterranean. With a high-quality, low-cost, and diverse portfolio, bolstered by strong liquidity
and a sound balance sheet, we enter 2016 well positioned to manage within cash flow and sustain our strong operating
performance.”
Fourth quarter 2015 total operating costs, including lease operating expense, production taxes and transportation, averaged
$6.93 per barrel of oil equivalent (BOE), down 22 percent from the fourth quarter of 2014. Depreciation, depletion, and
amortization totaled $17.67 per BOE during the fourth quarter of 2015, which reflects the impact of commodity price-driven reserve
revisions recorded at year-end. General and administrative costs were lower than anticipated due primarily to a reduction of
personnel costs.
Fourth quarter adjustments to net loss included approximately $1.3 billion of non-cash impairments, including $490 million
related to assets in the Gulf of Mexico and Equatorial Guinea and $779 million related to goodwill. The Company had unrealized
commodity derivative losses of $156 million, resulting from the value change of existing crude oil and natural gas hedge positions
as of the end of the year. Noble Energy also adjusted $95 million from exploration expense, following the Company’s decision
to exit its Nevada exploration program.
During the quarter, Noble Energy implemented a change in tax policy and outlook regarding the indefinite reinvestment of
international earnings. This item, which was also adjusted from earnings, enhances the Company’s financial flexibility with regards
to global cash management. For the fourth quarter, the remaining adjusted tax benefit reflects the balance of U.S. versus
international earnings, as well as the transition from interim reporting to full-year tax position.
OPERATIONS UPDATE
DJ BASIN
Sales volumes averaged 121 MBoe/d in the fourth quarter of 2015, up four percent from the third quarter of 2015 and 12 percent over
the fourth quarter of last year. Essentially all of the increase in volumes for the respective periods is liquids, driven
mostly by crude volumes. Liquids increased to 68 percent of fourth quarter 2015 DJ Basin volumes (51 percent crude oil and
condensate and 17 percent natural gas liquids) and 32 percent was natural gas. Horizontal production in the DJ Basin
increased to 97 MBoe/d. In the Company’s primary areas of activity, Wells Ranch and East Pony, combined sales volumes
averaged 62 MBoe/d during the quarter, up 35 percent compared to the fourth quarter of 2014.
Highlights include:
- Reduced normalized extended reach lateral length well costs, including allocated facilities, to below $3 million in Wells
Ranch.
- Average drilling time for a standard lateral length well (4,500 lateral feet) remained under six days, while medium (6,000
lateral feet) and long (9,000 lateral feet) wells are being drilled in seven and eight days, respectively.
- Drilled 31 wells at an average lateral length of over 6,900 feet. The Company reduced its full year 2015 average
drilling cost per lateral foot by 40 percent from 2014.
- Commenced production on 30 wells (equivalent to 50 standard lateral length wells). Included in the wells was the
Company’s first East Pony Codell well. Production results from the well are encouraging and consistent with equivalent
Niobrara wells nearby.
- Completion design optimization continues to positively impact well productivity. Over 70 percent of the wells completed
during the quarter utilized slickwater fluid design, and these wells continue to outperform similar hybrid gel wells.
- DCP Grand Parkway, a low-pressure gathering system in the northern part of Greater Wattenberg, commenced service in late
December, further lowering line pressures and enhancing gas transport system reliability.
- The Company exited 2015 with 45 wells drilled but uncompleted.
TEXAS (EAGLE FORD AND PERMIAN)
Production volumes for the Eagle Ford and Permian assets averaged 60 MBoe/d in the fourth quarter of 2015, up 11 percent versus the
volumes these assets produced in the third quarter of 2015. Liquids increased to 62 percent of the total (crude oil and
condensate represented 27 percent and NGLs were 35 percent), while natural gas accounted for 38 percent. 87 percent of the
volumes were from the Eagle Ford assets and 13 percent from the Permian.
Highlights include:
- Drilled four operated wells to total depth, including three Lower Eagle Ford wells and one Wolfcamp A well in the Permian’s
Delaware Basin. Drilling times have been reduced significantly versus prior performance on these assets.
- Commenced production on five Lower Eagle Ford wells. Included in the wells brought online were the Gates 05D 10-20,
14-20 and 18-20. The average 90-day production rate for each of the wells, with an average lateral length of approximately
7,000 feet and completed on 1,000 foot lateral spacing, was 4,210 Boe/d (10-20), 5,160 Boe/d (14-20) and 5,285 Boe/d
(18-20).
- The two most recent wells brought on production were designed to test enhanced completions on tighter lateral spacing (500
equivalent feet). The wells, Gates 05D 22-20 and 24-20 with an average lateral length of 6,500 feet, were completed with 40
foot cluster spacing and approximately 2,000 pounds of proppant per lateral foot. The 30-day IP for the wells was 4,200 and 3,870
Boe/d, respectively. Production from both wells, when normalized to a 5,000 foot lateral, is higher than the three million
barrel type curve, which is based on wider lateral spacing.
- There were 55 wells drilled but uncompleted (including 40 wells in the Eagle Ford and 15 wells in the Delaware) at the end of
2015.
MARCELLUS SHALE
Production volumes in the Marcellus Shale averaged 530 million cubic feet of natural gas equivalent per day (MMcfe/d) in the fourth
quarter of 2015, an eight percent increase over the third quarter of 2015 and 40 percent more than the same quarter of last
year. Natural gas represented 87 percent of fourth quarter 2015 volumes, with the remaining 13 percent primarily composed of
natural gas liquids (NGLs).
Highlights include:
- Commenced production on the Company’s first Utica well, the 9,345 foot lateral MND-6H located in Marshall County, West
Virginia. Production from the well reached 61 MMcf/d during flowback and is currently producing 20 MMcf/d on a reduced
choke to manage pressure draw down.
- Joint Venture partner CONSOL Energy completed 11 dry gas wells during the quarter.
- Exited the year with 85 wells drilled but uncompleted (54 wells in the wet gas and 31 in the dry gas area) in the Joint
Venture.
- CONE Midstream Partners gathered record average gross throughput volume of 1.3 billion cubic feet equivalent per day during
the fourth quarter, an increase of 46 percent from the same quarter last year. Additionally, CONE completed a
de-bottlenecking project that added approximately 30 MMcfe/d of throughput during the quarter.
GULF OF MEXICO
In the Gulf of Mexico, sales volumes averaged 23 MBoe/d, a 91 percent increase versus the third quarter of 2015 and 33 percent
versus the same quarter of last year. This increase was driven by the startup of production at Big Bend and Dantzler. Crude
oil and condensate represented 84 percent of fourth quarter 2015 volumes, while five percent was NGLs and 11 percent was natural
gas.
Highlights include:
- Combined production from the Big Bend and Dantzler development achieved a peak rate of over 20 MBoe/d, net.
- Finished subsea installation and construction on the Gunflint development. During the quarter, the Company completed
the Gunflint #2 and #4 wells. The project remains within budget and on schedule for a mid-2016 startup.
- Commenced drilling operations on the Silvergate prospect late in the fourth quarter. Noble Energy operates the prospect
with a 50 percent working interest. Silvergate, located in Mississippi Canyon 339, is a Miocene-aged target with subsea
tieback potential.
WEST AFRICA
Sales volumes in West Africa averaged 85 MBoe/d, which was 46 percent crude oil and condensate, seven percent NGLs, and 47 percent
natural gas. Sales volumes for the quarter exceeded production volumes by approximately five MBbl/d as a result of the timing
of liquids lifting from the Alen field and Alba.
Highlights include:
- The Alba compression project installation progressed and remains on schedule.
- Interpretation of the latest 3D seismic data is underway over Blocks O and I offshore Equatorial Guinea.
EASTERN MEDITERRANEAN
In the Eastern Mediterranean, Israel natural gas sales volumes averaged 252 MMcfe/d, an increase of approximately 10 percent versus
the fourth quarter of last year, driven by higher power generation needs.
Highlights include:
- Israel natural gas regulatory framework was implemented and enabled the Company to begin marketing Leviathan gas to Israeli
customers.
- Progress on finalizing gas sales agreements continues with multiple regional customers. Signed a Letter of Intent to
supply Dolphinus Holdings Ltd. with approximately 400 MMcf/d, gross, from Leviathan over 10 years for Egyptian industrial
use.
- Received the first export permit for future gas sales to Egypt.
- Initiated marketing to regional customers for gas from the Cyprus Aphrodite field.
- Signed an agreement to divest the Tanin and Karish fields for a total deal value of $73 million. Cash consideration was
received in January 2016.
- Executed a farm-out agreement in Block 12, offshore Cyprus, with BG International. Noble Energy maintains operatorship with a
working interest of 35 percent. The transaction closed and cash consideration of $125 million was received in January 2016. The
remaining $40 million will be collected in early 2017.
PROVED RESERVES
Estimated reserves at year-end 2015 were 1.4 billion barrels of oil equivalent, up one percent from 2014 year-end. Excluding
acquisitions and commodity price revisions, the Company had total additions of 191 million barrels of oil equivalent (MMBoe) versus
production of 130 MMBoe during the year. Organic reserve replacement, excluding price-related revisions, was 147 percent.
Reserves in the U.S., including Gulf of Mexico, were 62 percent of the Company’s total, with assets in Equatorial Guinea and Israel
making up the remaining 38 percent. The composition of reserves at the end of 2015 is 35 percent liquids, 33 percent
international natural gas and 32 percent U.S. natural gas.
Unconventional U.S. reserve replacement, excluding acquisition and commodity price revisions, was 2.3 times production,
reflecting development activity and improved well performance in the DJ Basin and Marcellus Shale. During 2015, the Company
added 269 MMBoe of proved reserves through the Rosetta merger. The impact of lower SEC commodity prices, utilized in the
preparation of proved reserve reporting, resulted in a reserve reduction of 307 MMBoe versus 2014. Approximately 50 percent
of the price-related reserves impact was related to the Company’s Marcellus estimations.
Proved developed reserves represent approximately 66 percent of total proved reserves at the end of the year, up three percent
from year-end 2014.
(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 888-437-9362 and 719-325-2396. The pass code number is 7718745. A replay will be available on
the website.
Noble Energy (NYSE:NBL) is an independent oil and natural gas exploration and production company with a
diversified high-quality portfolio of both U.S. unconventional and global offshore conventional assets spanning three
continents. Founded more than 80 years ago, the company is committed to safely and responsibly delivering our purpose:
Energizing the World, Bettering People’s Lives®. For more information, visit 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”, “estimates”, 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, 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 (“SEC”). 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.
| Schedule 1 |
| Noble Energy, Inc. |
| Summary Statement of Operations |
| (in millions, except per share amounts,
unaudited) |
| |
| |
|
Three Months Ended |
|
Twelve Months Ended |
| |
|
December 31, |
|
December 31, |
| |
|
2015 |
|
2014 |
|
2015 |
|
2014 |
| Revenues |
|
|
|
|
|
|
|
|
| Crude oil and condensate |
|
$ |
488 |
|
|
$ |
690 |
|
|
$ |
1,840 |
|
|
$ |
3,438 |
|
| Natural gas |
|
272 |
|
|
291 |
|
|
1,056 |
|
|
1,223 |
|
| Natural gas liquids |
|
56 |
|
|
56 |
|
|
147 |
|
|
270 |
|
| Income from equity method investees |
|
30 |
|
|
33 |
|
|
90 |
|
|
170 |
|
| Total revenues |
|
846 |
|
|
1,070 |
|
|
3,133 |
|
|
5,101 |
|
| Operating Expenses |
|
|
|
|
|
|
|
|
| Lease operating expense |
|
146 |
|
|
170 |
|
|
563 |
|
|
593 |
|
| Production and ad valorem taxes |
|
38 |
|
|
38 |
|
|
127 |
|
|
184 |
|
| Transportation and gathering expense |
|
85 |
|
|
50 |
|
|
272 |
|
|
170 |
|
| Exploration expense |
|
180 |
|
|
147 |
|
|
488 |
|
|
498 |
|
| Depreciation, depletion and amortization |
|
686 |
|
|
462 |
|
|
2,131 |
|
|
1,759 |
|
| General and administrative |
|
89 |
|
|
104 |
|
|
396 |
|
|
503 |
|
| Asset impairments |
|
490 |
|
|
336 |
|
|
533 |
|
|
500 |
|
| Goodwill Impairment |
|
779 |
|
|
— |
|
|
779 |
|
|
— |
|
| Other operating (income) expense, net |
|
65 |
|
|
8 |
|
|
316 |
|
|
(24 |
) |
| Total operating expenses |
|
2,558 |
|
|
1,315 |
|
|
5,605 |
|
|
4,183 |
|
| Operating Income (Loss) |
|
(1,712 |
) |
|
(245 |
) |
|
(2,472 |
) |
|
918 |
|
| Other (Income) Expense |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| (Gain) on commodity derivative instruments |
|
(170 |
) |
|
(903 |
) |
|
(501 |
) |
|
(976 |
) |
| Interest, net of amount capitalized |
|
80 |
|
|
59 |
|
|
263 |
|
|
210 |
|
| Other non-operating (income) expense, net |
|
5 |
|
|
(25 |
) |
|
(15 |
) |
|
(26 |
) |
| Total other (income) expense |
|
(85 |
) |
|
(869 |
) |
|
(253 |
) |
|
(792 |
) |
| Income (Loss) Before Income Taxes |
|
(1,627 |
) |
|
624 |
|
|
(2,219 |
) |
|
1,710 |
|
| Income Tax (Benefit) Provision |
|
401 |
|
|
222 |
|
|
222 |
|
|
496 |
|
| Net Income (Loss) |
|
$ |
(2,028 |
) |
|
$ |
402 |
|
|
$ |
(2,441 |
) |
|
$ |
1,214 |
|
| Earnings (Loss) Per Share |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Earnings (Loss) Per Share, Basic |
|
$ |
(4.73 |
) |
|
$ |
1.11 |
|
|
$ |
(6.07 |
) |
|
$ |
3.36 |
|
| Earnings (Loss) Per Share, Diluted |
|
$ |
(4.73 |
) |
|
$ |
1.05 |
|
|
$ |
(6.07 |
) |
|
$ |
3.27 |
|
| |
|
|
|
|
|
|
|
|
| Weighted average number of shares outstanding |
|
|
|
|
|
|
|
|
| Basic |
|
429 |
|
|
362 |
|
|
402 |
|
|
361 |
|
| Diluted |
|
429 |
|
|
367 |
|
|
402 |
|
|
367 |
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
| These financial statements should be read in conjunction with the financial statements
and the accompanying notes and other information included in Noble Energy's Annual Report on Form 10-K to be filed with the
Securities and Exchange Commission on February 17, 2016. |
| |
|
|
|
|
|
|
|
|
|
|
|
|
| On July 20, 2015, we completed the merger with Rosetta Resources Inc. (Rosetta or
Rosetta Merger) and the results of operations attributable to Rosetta are included in our consolidated statement of operations
beginning on July 21, 2015. The results of these operations attributable to Rosetta will affect the comparability of our
financial results to prior periods. |
| Schedule 2 |
| Noble Energy, Inc. |
| Condensed Balance Sheets |
| (in millions, unaudited) |
| |
|
|
|
|
| |
|
December 31, |
|
December 31, |
| |
|
2015 |
|
2014 |
| ASSETS |
|
|
|
|
| Current Assets |
|
|
|
|
| Cash and cash equivalents |
|
$ |
1,028 |
|
|
$ |
1,183 |
|
| Accounts receivable, net |
|
450 |
|
|
857 |
|
| Commodity derivative assets, current |
|
582 |
|
|
710 |
|
| Other current assets |
|
216 |
|
|
325 |
|
| Total current assets |
|
2,276 |
|
|
3,075 |
|
| Net property, plant and equipment |
|
21,300 |
|
|
18,143 |
|
| Goodwill |
|
— |
|
|
620 |
|
| Other noncurrent assets |
|
620 |
|
|
680 |
|
| Total Assets |
|
$ |
24,196 |
|
|
$ |
22,518 |
|
| LIABILITIES AND SHAREHOLDERS' EQUITY |
|
|
|
|
| Current Liabilities |
|
|
|
|
| Accounts payable - trade |
|
$ |
1,128 |
|
|
$ |
1,578 |
|
| Other current liabilities |
|
677 |
|
|
944 |
|
| Total current liabilities |
|
1,805 |
|
|
2,522 |
|
| Long-term debt |
|
7,976 |
|
|
6,068 |
|
| Deferred income taxes, noncurrent |
|
2,826 |
|
|
2,516 |
|
| Other noncurrent liabilities |
|
1,219 |
|
|
1,087 |
|
| Total Liabilities |
|
13,826 |
|
|
12,193 |
|
| Total Shareholders’ Equity |
|
10,370 |
|
|
10,325 |
|
| Total Liabilities and Shareholders’ Equity |
|
$ |
24,196 |
|
|
$ |
22,518 |
|
| |
|
|
|
|
|
|
|
|
| These financial statements should be read in conjunction with the financial statements
and the accompanying notes and other information included in Noble Energy's Annual Report on Form 10-K to be filed with the
Securities and Exchange Commission on February 17, 2016. |
| Schedule 3 |
| Noble Energy, Inc. |
| Volume and Price Statistics |
| (unaudited) |
| |
| |
|
Three Months Ended |
|
Twelve Months Ended |
| |
|
December 31, |
|
December 31, |
| |
|
2015 |
|
2014 |
|
2015 |
|
2014 |
| Crude Oil and Condensate Sales Volumes (MBbl/d) |
|
|
|
|
|
|
|
|
| United States |
|
99 |
|
|
70 |
|
|
81 |
|
|
68 |
|
| Equatorial Guinea |
|
37 |
|
|
37 |
|
|
31 |
|
|
33 |
|
| Other International |
|
— |
|
|
— |
|
|
— |
|
|
2 |
|
| Total consolidated operations |
|
137 |
|
|
107 |
|
|
112 |
|
|
103 |
|
| Equity method investee - Equatorial Guinea |
|
1 |
|
|
2 |
|
|
2 |
|
|
2 |
|
| Total sales volumes |
|
138 |
|
|
109 |
|
|
114 |
|
|
105 |
|
| Crude Oil and Condensate Realized Prices ($/Bbl)(1) |
|
|
|
|
|
|
|
|
| United States |
|
$ |
37.82 |
|
|
$ |
69.43 |
|
|
$ |
43.46 |
|
|
$ |
89.60 |
|
| Equatorial Guinea |
|
41.18 |
|
|
69.61 |
|
|
48.85 |
|
|
94.61 |
|
| Other International |
|
— |
|
|
— |
|
|
— |
|
|
103.74 |
|
| Consolidated average realized prices |
|
$ |
38.75 |
|
|
$ |
69.54 |
|
|
$ |
45.00 |
|
|
$ |
91.58 |
|
| Natural Gas Sales Volumes (MMcf/d) |
|
|
|
|
|
|
|
|
| United States |
|
859 |
|
|
578 |
|
|
708 |
|
|
518 |
|
| Equatorial Guinea |
|
243 |
|
|
251 |
|
|
227 |
|
|
243 |
|
| Israel |
|
247 |
|
|
226 |
|
|
252 |
|
|
231 |
|
| Total sales volumes |
|
1,349 |
|
|
1,055 |
|
|
1,187 |
|
|
992 |
|
| Natural Gas Realized Prices ($/Mcf)(1) |
|
|
|
|
|
|
|
|
| United States |
|
$ |
1.88 |
|
|
$ |
3.21 |
|
|
$ |
2.10 |
|
|
$ |
3.86 |
|
| Equatorial Guinea |
|
0.27 |
|
|
0.27 |
|
|
0.27 |
|
|
0.27 |
|
| Israel |
|
5.17 |
|
|
5.50 |
|
|
5.34 |
|
|
5.57 |
|
| Consolidated average realized prices |
|
$ |
2.19 |
|
|
$ |
3.00 |
|
|
$ |
2.44 |
|
|
$ |
3.38 |
|
| Natural Gas Liquids Sales Volumes (MBbl/d) |
|
|
|
|
|
|
|
|
| United States |
|
53 |
|
|
26 |
|
|
39 |
|
|
23 |
|
| Equity method investee - Equatorial Guinea |
|
6 |
|
|
4 |
|
|
5 |
|
|
5 |
|
| Total sales volumes |
|
59 |
|
|
30 |
|
|
44 |
|
|
28 |
|
| Natural Gas Liquids Realized Prices ($/Bbl)(1) |
|
|
|
|
|
|
|
|
| United States |
|
$ |
11.55 |
|
|
$ |
23.56 |
|
|
$ |
10.39 |
|
|
$ |
32.04 |
|
| Barrels of Oil Equivalent Volumes (MBoe/d) |
|
|
|
|
|
|
|
|
| United States |
|
295 |
|
|
192 |
|
|
237 |
|
|
176 |
|
| Equatorial Guinea |
|
78 |
|
|
79 |
|
|
69 |
|
|
74 |
|
| Israel |
|
42 |
|
|
38 |
|
|
42 |
|
|
39 |
|
| Other International |
|
— |
|
|
— |
|
|
— |
|
|
2 |
|
| Total consolidated operations |
|
415 |
|
|
309 |
|
|
348 |
|
|
291 |
|
| Equity method investee - Equatorial Guinea |
|
7 |
|
|
6 |
|
|
7 |
|
|
7 |
|
| Total sales volumes |
|
422 |
|
|
315 |
|
|
355 |
|
|
298 |
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
| (1) Average realized prices do not include gains or losses on
commodity derivative instruments. |
| |
| On July 20, 2015, we completed the merger with Rosetta and the associated
volumes and price statistics are included in our operations beginning on July 21, 2015. The results of these volumes and
prices attributable to Rosetta will affect the comparability of our results to prior periods. |
| Schedule 4 |
| Noble Energy, Inc. |
| Reconciliation of Net Income (Loss) to
Adjusted Income |
| (in millions, except per share amounts,
unaudited) |
| |
| |
|
Three Months Ended December
31, |
|
Twelve Months Ended December
31, |
| |
|
|
|
Per |
|
|
|
Per |
|
|
|
Per |
|
|
|
Per |
| |
|
|
|
Diluted |
|
|
|
Diluted |
|
|
|
Diluted |
|
|
|
Diluted |
| |
|
2015 |
|
Share |
|
2014 |
|
Share |
|
2015 |
|
Share |
|
2014 |
|
Share |
| Net Income (Loss) |
|
$ |
(2,028 |
) |
|
$ |
(4.73 |
) |
|
$ |
402 |
|
|
$ |
1.10 |
|
|
$ |
(2,441 |
) |
|
$ |
(6.07 |
) |
|
$ |
1,214 |
|
|
$ |
3.27 |
|
| (Gain) loss on commodity derivative instruments, net of cash settlements
[1] |
|
156 |
|
|
0.36 |
|
|
(778 |
) |
|
(2.12 |
) |
|
508 |
|
|
1.26 |
|
|
(947 |
) |
|
(2.58 |
) |
| Asset impairments [2] |
|
490 |
|
|
1.14 |
|
|
336 |
|
|
0.92 |
|
|
533 |
|
|
1.33 |
|
|
500 |
|
|
1.36 |
|
| Goodwill impairment [3] |
|
779 |
|
|
1.82 |
|
|
— |
|
|
— |
|
|
779 |
|
|
1.93 |
|
|
— |
|
|
— |
|
| Deferred compensation [4] |
|
3 |
|
|
0.01 |
|
|
(26 |
) |
|
(0.07 |
) |
|
(16 |
) |
|
(0.04 |
) |
|
(25 |
) |
|
(0.07 |
) |
| Corporate restructuring |
|
12 |
|
|
0.03 |
|
|
— |
|
|
— |
|
|
51 |
|
|
0.13 |
|
|
— |
|
|
— |
|
| Stacked drilling rig |
|
11 |
|
|
0.03 |
|
|
— |
|
|
— |
|
|
30 |
|
|
0.07 |
|
|
— |
|
|
— |
|
| Pension plan expense |
|
— |
|
|
— |
|
|
— |
|
|
— |
|
|
88 |
|
|
0.22 |
|
|
— |
|
|
— |
|
| Rosetta merger expenses |
|
8 |
|
|
0.02 |
|
|
— |
|
|
— |
|
|
81 |
|
|
0.21 |
|
|
— |
|
|
— |
|
| Nevada exploration expense [5] |
|
95 |
|
|
0.22 |
|
|
— |
|
|
— |
|
|
95 |
|
|
0.23 |
|
|
— |
|
|
— |
|
| Other adjustments |
|
19 |
|
|
0.04 |
|
|
2 |
|
|
0.01 |
|
|
27 |
|
|
0.07 |
|
|
(73 |
) |
|
(0.20 |
) |
| Total adjustments before tax |
|
1,573 |
|
|
3.67 |
|
|
(466 |
) |
|
(1.26 |
) |
|
2,176 |
|
|
5.41 |
|
|
(545 |
) |
|
(1.49 |
) |
| Income tax effect of adjustments [6] |
|
646 |
|
|
1.50 |
|
|
203 |
|
|
0.54 |
|
|
477 |
|
|
1.18 |
|
|
196 |
|
|
0.54 |
|
| Adjusted Income |
|
$ |
191 |
|
|
$ |
0.44 |
|
|
$ |
139 |
|
|
$ |
0.38 |
|
|
$ |
212 |
|
|
$ |
0.52 |
|
|
$ |
865 |
|
|
$ |
2.36 |
|
| Weighted average number of shares outstanding |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Diluted |
|
431 |
|
|
|
|
367 |
|
|
|
|
405 |
|
|
|
|
367 |
|
|
|
| NOTE: |
Adjusted income should not be considered an alternative to, or more meaningful than,
net income (loss) 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. However, Noble Energy's method of computing this measure may not be the same
method used to compute similar measures reported by other entities. See Schedule 1: Summary Statement of Operations.
|
| |
|
| |
On July 20, 2015, we completed the merger with Rosetta and the results of operations
attributable to Rosetta are included in our consolidated statement of operations beginning on July 21, 2015. The results of
these operations attributable to Rosetta will affect the comparability of our financial results to prior periods. |
| [1] |
Many factors impact our gain or loss on commodity derivative instruments, net of cash
settlements, including: increases and decreases in the commodity forward price curves compared to our executed hedging
arrangements; increases in hedged future revenues; and the mix of hedge arrangements between NYMEX WTI, Dated Brent and NYMEX
HH commodities. These gains or losses on commodity derivative instruments, net of cash settlements, recognized in the current
period, will be realized in the future when cash settlement occurs. |
| [2] |
Amount for 2015 relates to Equatorial Guinea, Gulf of Mexico and Eastern Mediterranean
properties. Amount for 2014 primarily relates to US Onshore, Gulf of Mexico and North Sea properties. |
| [3] |
Due to continuing declines in commodity prices and the market value of our common
stock, we determined that our goodwill, associated with the US reporting unit, was impaired. |
| [4] |
Amount represents (increases) decreases in the fair value of shares of our common
stock held in a rabbi trust. |
| [5] |
Amount represents our Northeast Nevada exploration efforts which we elected to
discontinue after assessing commercial viability in the current commodity price environment. |
| [6] |
Amount represents the income tax effect of adjustments, determined for each major tax
jurisdiction for each adjusting item, as well as the change in the indefinite reinvestment assertion related to accumulated
undistributed earnings of foreign subsidiaries. |
| Schedule 5 |
| Noble Energy, Inc. |
| Discretionary Cash Flow and Reconciliation to
Net Cash Provided by Operating Activities |
| (in millions, unaudited) |
| |
| |
|
Three Months Ended |
|
Twelve Months Ended |
| |
|
December 31, |
|
December 31, |
| |
|
2015 |
|
2014 |
|
2015 |
|
2014 |
| Adjusted Income [1] |
|
$ |
191 |
|
|
$ |
139 |
|
|
$ |
212 |
|
|
$ |
865 |
|
| Adjustments to reconcile adjusted income to discretionary cash flow |
|
|
|
|
|
|
|
|
| Depreciation, depletion and amortization |
|
686 |
|
|
462 |
|
|
2,131 |
|
|
1,759 |
|
| Exploration expense |
|
85 |
|
|
147 |
|
|
393 |
|
|
498 |
|
| (Income)/Dividends from equity method investments, net |
|
(10 |
) |
|
(20 |
) |
|
(14 |
) |
|
33 |
|
| Deferred income taxes |
|
(362 |
) |
|
4 |
|
|
(457 |
) |
|
72 |
|
| Stock-based compensation expense |
|
17 |
|
|
21 |
|
|
71 |
|
|
87 |
|
| Other |
|
2 |
|
|
1 |
|
|
(2 |
) |
|
10 |
|
| Discretionary Cash Flow |
|
$ |
609 |
|
|
$ |
754 |
|
|
$ |
2,334 |
|
|
$ |
3,324 |
|
| Reconciliation to Operating Cash Flows |
|
|
|
|
|
|
|
|
| Net changes in working capital |
|
(55 |
) |
|
127 |
|
|
(129 |
) |
|
412 |
|
| Cash exploration costs |
|
(33 |
) |
|
(79 |
) |
|
(106 |
) |
|
(229 |
) |
| Current tax benefit of earnings adjustments |
|
77 |
|
|
— |
|
|
97 |
|
|
— |
|
| Corporate restructuring |
|
(12 |
) |
|
— |
|
|
(51 |
) |
|
— |
|
| Stacked drilling rig |
|
(11 |
) |
|
— |
|
|
(30 |
) |
|
— |
|
| Rosetta merger expenses |
|
(8 |
) |
|
— |
|
|
(66 |
) |
|
— |
|
| Other adjustments |
|
9 |
|
|
1 |
|
|
13 |
|
|
(1 |
) |
| Net Cash Provided by Operating Activities |
|
$ |
576 |
|
|
$ |
803 |
|
|
$ |
2,062 |
|
|
$ |
3,506 |
|
| |
|
|
|
|
|
|
|
|
| Capital expenditures (accrual based) |
|
$ |
527 |
|
|
$ |
1,353 |
|
|
$ |
2,852 |
|
|
$ |
4,883 |
|
| Rosetta merger capital expenditures |
|
— |
|
|
— |
|
|
3,175 |
|
|
— |
|
| Increase in capital lease obligations [2] |
|
(5 |
) |
|
29 |
|
|
55 |
|
|
110 |
|
| Total Capital Expenditures (Accrual Based) |
|
$ |
522 |
|
|
$ |
1,382 |
|
|
$ |
6,082 |
|
|
$ |
4,993 |
|
| NOTE: |
Discretionary cash flow should not be considered an alternative to, or more meaningful
than, net income (loss), net cash provided by operating activities, or any other measure as reported in accordance with GAAP.
The table above reconciles discretionary cash flow to net cash provided by operating activities. Our management believes, and
certain investors may find that discretionary cash flow is useful as an indicator of the company's ability to fund exploration
and production activities and meet financial obligations. Discretionary cash flow is also useful as a basis for valuing
companies in the oil and gas industry. However, Noble Energy's method of computing this measure may not be the same
method used to compute similar measures reported by other entities.
|
| |
|
| |
On July 20, 2015, we completed the merger with Rosetta and the results of operations
attributable to Rosetta are included in our consolidated statement of operations beginning on July 21, 2015. The results
of these operations attributable to Rosetta will affect the comparability of our financial results to prior periods. |
| [1] |
See Schedule 4: Reconciliation of Net Income (Loss) to Adjusted Income. |
| [2] |
Represents estimated construction in progress to date on US operating assets and
corporate buildings. |
| Schedule 6 |
| Noble Energy, Inc. |
| Supplemental Data |
| (in millions, unaudited) |
| |
|
|
|
|
|
|
| |
|
United |
|
|
|
|
| 2015 Costs Incurred in Oil and Gas Activities |
|
States |
|
Int’l
[1] |
|
Total |
| |
|
|
|
|
|
|
| Proved property acquisition costs |
|
$ |
1,613 |
|
|
$ |
— |
|
|
$ |
1,613 |
|
| Unproved property acquisition costs |
|
1,478 |
|
|
2 |
|
|
1,480 |
|
| Exploration costs |
|
206 |
|
|
278 |
|
|
484 |
|
| Development costs [2] |
|
2,455 |
|
|
189 |
|
|
2,644 |
|
| Total costs incurred |
|
$ |
5,752 |
|
|
$ |
469 |
|
|
$ |
6,221 |
|
| |
|
|
|
|
|
|
| Reconciliation to Capital Spending (accrual basis) |
|
|
|
|
|
|
| Total costs incurred |
|
|
|
|
|
$ |
6,221 |
|
| Exploration overhead |
|
|
|
|
|
(154 |
) |
| Lease rentals |
|
|
|
|
|
(8 |
) |
| Asset retirement obligations |
|
|
|
|
|
(233 |
) |
| Total oil and gas spending |
|
|
|
|
|
5,826 |
|
| Investment in equity method investee |
|
|
|
|
|
104 |
|
| Other corporate capital and capital leases |
|
|
|
|
|
152 |
|
| Total capital spending (accrual basis) |
|
|
|
|
|
$ |
6,082 |
|
| |
|
|
|
|
|
|
| |
|
United |
|
|
|
|
| Proved Reserves [3] |
|
States |
|
Int’l
[4] |
|
Total |
| Total Barrel Oil Equivalents (MMBoe) |
|
|
|
|
|
|
| Beginning reserves - December 31, 2014 |
|
816 |
|
|
588 |
|
|
1,404 |
|
| Price-related revisions |
|
(293 |
) |
|
(14 |
) |
|
(307 |
) |
| Other non-price-related revisions |
|
84 |
|
|
7 |
|
|
91 |
|
| Extensions, discoveries and other additions |
|
100 |
|
|
— |
|
|
100 |
|
| Purchase of minerals in place |
|
269 |
|
|
— |
|
|
269 |
|
| Sale of minerals in place |
|
(6 |
) |
|
— |
|
|
(6 |
) |
| Production |
|
(86 |
) |
|
(44 |
) |
|
(130 |
) |
| Ending reserves - December 31, 2015 |
|
884 |
|
|
537 |
|
|
1,421 |
|
| Proved Developed Reserves (MMBoe) |
|
|
|
|
|
|
| December 31, 2014 |
|
426 |
|
|
455 |
|
|
881 |
|
| December 31, 2015 |
|
540 |
|
|
396 |
|
|
936 |
|
| [1] |
International primarily includes Cameroon, Cyprus, Equatorial Guinea, Falkland Islands
and Israel. |
| [2] |
Includes ARO costs of $194 million for United States and $39 million for
International. |
| [3] |
Netherland, Sewell & Associates, Inc. performed a reserves audit for 2015 and
concluded that the Company's estimates of proved reserves were, in the aggregate, reasonable and have been prepared in
accordance with Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the
Society of Petroleum Engineers. |
| [4] |
International primarily includes Equatorial Guinea and Israel. |
| |
|
Investor Contacts Brad Whitmarsh (281) 943-1670 Brad.Whitmarsh@nblenergy.com Megan Repine (832) 639-7380 Megan.Repine@nblenergy.com Media Contacts: Reba Reid (713) 412-8441 media@nblenergy.com Paula Beasley (281) 876-6133 media@nblenergy.com
