Noble Energy Announces Fourth Quarter and Full Year 2011 Results, Including Record Sales Volumes and Proved Reserves
HOUSTON, Feb. 9, 2012 /PRNewswire/ — Noble Energy, Inc. (NYSE: NBL) reported today a fourth quarter 2011 net loss of $296 million, or $1.67 per share diluted, on revenues of $985 million. Results for the quarter included an asset impairment charge and an unrealized commodity derivatives loss. Excluding these items, fourth quarter adjusted net income(1) was $211 million, or $1.18 per share diluted. The Company reported net income of $52 million during the final quarter of 2010, or $0.29 per share diluted, on revenues of $783 million. Adjusted net income(1) for the fourth quarter of 2010 was $185 million, or $1.04 per share diluted.
Discretionary cash flow(1) for the fourth quarter 2011 was $677 million compared to $538 million for the similar quarter in 2010. Net cash provided by operating activities was $385 million, compared to $494 million, and capital expenditures(2) were $1.0 billion.
Key highlights for the fourth quarter of 2011 include:
- Record sales volume of 233 thousand barrels of oil equivalent per day (MBoe/d) and 222 MBoe/d for the year
- Increased DJ Basin volumes to 66 MBoe/d with horizontal production exiting the quarter at 17 MBoe/d, a 48 percent increase over the prior quarter exit rate
- Produced 74 million cubic feet per day (MMcf/d) net in the Marcellus Joint Venture (JV)
- Started up the Aseng oil project offshore Equatorial Guinea, and exited the year producing 19 thousand barrels of oil per day (MBbl/d) net
- Announced a world-class discovery offshore Cyprus with a gross mean resource estimate of seven trillion cubic feet (Tcf)
- Successfully appraised the Leviathan discovery offshore Israel resulting in an increase in the gross mean resource estimate to 17 Tcf or 6 Tcf net
- Recorded year-end proved reserves of 1.2 billion barrels of oil equivalent (BBoe), up 11 percent from 2010
- Further strengthened the balance sheet through an upsized $3 billion credit facility and issuance of $1 billion 10-year bonds resulting in year-end liquidity of approximately $4.5 billion
Noble Energy reported full year 2011 net income of $453 million, or $2.54 per share diluted, compared to net income of $725 million, or $4.10 per share diluted, in 2010. Adjusted net income(1) for 2011 was $947 million, or $5.31 per share diluted, up from $746 million, or $4.22 per share diluted, in 2010. Discretionary cash flow(1) was $2.5 billion for the year, up 26 percent from 2010, and net cash provided by operating activities for the year was $2.2 billion, up 12 percent from 2010. Total year capital expenditures(2) were $3.0 billion.
Charles D. Davidson, Noble Energy’s Chairman and CEO, commented, “Noble Energy closed out 2011 with record production for the fourth quarter while significantly progressing our inventory of major projects. First production was reached at Aseng offshore Equatorial Guinea seven months ahead of schedule and 13 percent below budget. We are positioned to deliver production from Galapagos and South Raton in the Gulf of Mexico in the first half of 2012. We continue to mature our Eastern Mediterranean portfolio, where the development at Tamar is progressing on schedule and on budget and the recent appraisal drilling at Leviathan has increased the estimated resources of the field. The discovery at Cyprus, along with the Tanin discovery announced this week, increased gross estimated mean resources discovered in the Levant Basin to approximately 35 Tcf. Balancing our growing international portfolio are two lower-risk onshore U.S. developments. Production out of the DJ Basin continues to grow led by the horizontal program which completed 25 wells in the fourth quarter. The Marcellus JV is growing production, and we began to operate our first rig in early 2012 in the wet gas portion of the acreage. Financially, we have increased our liquidity position to support our major project developments. We are exceptionally well positioned for continued growth and delivery of value to our shareholders.”
Fourth quarter 2011 sales volumes averaged 233 MBoe/d, up eight percent from the fourth quarter 2010 excluding volumes from Ecuador, which we exited in 2011. The sales volume split for the fourth quarter 2011 was 40 percent liquids, 29 percent international natural gas, and 31 percent U.S. natural gas.
Noble Energy’s U.S. volumes totaled 127 MBoe/d for the fourth quarter 2011, up seven percent from the same quarter last year. The increase was attributed to the addition of the Marcellus JV and continued growth in the horizontal Niobrara play in the DJ Basin. Natural production declines were experienced in the deepwater Gulf of Mexico and various onshore natural gas properties.
Sales volume from the Company’s international assets was 106 MBoe/d for the final quarter of 2011, an increase of eight percent from the fourth quarter of 2010 excluding volumes from Ecuador. The increase was due to the early startup of the Aseng oil project offshore Equatorial Guinea and higher sales from the Mari-B field which continued to produce at high levels to satisfy Israeli natural gas demand.
Crude oil and condensate prices were up significantly from the fourth quarter of 2010. Noble Energy’s global crude oil price averaged $101.12 per barrel, up 22 percent versus the fourth quarter 2010. Natural gas realizations in the U.S. averaged $3.42 per thousand cubic feet (Mcf) and in Israel averaged $5.10 per Mcf. Natural gas liquid pricing in the U.S. averaged $46.11 per barrel for the quarter, representing 48 percent of the Company’s average U.S. crude oil realization.
Total production costs per barrel of oil equivalent (Boe), including lease operating expense (LOE), production and ad valorem taxes, and transportation were $7.88 per Boe, up 13 percent from the last quarter of 2010. LOE and depreciation, depletion, and amortization (DD&A) per Boe were $5.08 and $13.20, respectively. The unit rates were impacted by the Company’s mix of sales volumes, particularly with the startup of Aseng offshore Equatorial Guinea and the increased production from the DJ Basin. Production and ad valorem taxes reflected stronger liquid commodity prices and higher volumes. Exploration expense for the fourth quarter 2011 was $85 million, which included costs associated with the Bwabe dry hole offshore Cameroon. The Company’s adjusted effective tax rate for the fourth quarter 2011 was 33 percent, with 43 percent deferred.
The Company recorded a $620 million asset impairment related to onshore U.S. dry natural gas properties, primarily in the Piceance Basin, as a result of declining natural gas prices. Other operating expenses of $41 million were mostly due to costs associated with disposition of surplus inventory and expected legal settlements. Non-operating expenses included a $22 million deferred compensation charge associated with the quarterly value change of Noble Energy stock held in a benefit program.
PROVED RESERVES
Estimated reserves at the end of 2011 were approximately 1.2 BBoe, up 11 percent from 2010. Reserves in the U.S. accounted for 47 percent of the total, with International the remaining 53 percent. Reserves are split 31 percent global liquids, 42 percent international natural gas, and 27 percent U.S. natural gas.
Noble Energy added total proved reserves of 198 million barrels of oil equivalent (MMBoe) in 2011, including revisions. These additions replaced 244 percent of 2011 production.
U.S. net additions of 120 MMBoe resulted in 279 percent replacement of U.S. production and were driven by the acquisition of the Company’s Marcellus JV and the horizontal drilling program in the DJ Basin. These net additions included negative revisions of 45 MMBoe primarily associated with the reduction of undeveloped vertical locations in the DJ Basin as the Company continues to transition rigs to horizontal drilling and reduced activity levels in dry gas fields due to lower natural gas prices.
The international portfolio added net 78 MMBoe of reserves, or 205 percent replacement of international production, with 80 MMBoe of additions from the successful appraisal drilling results at Tamar offset slightly by revisions in non-core areas.
A Non-GAAP measure, see attached Reconciliation
(1) Schedules
Capital expenditures for the fourth quarter and full
year 2011 exclude a non-cash accrual related to
construction progress to date on the Aseng FPSO and
(2) the Marcellus acquisition.
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 888-299-7208 and 719-325-2149. 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 non-GAAP measures of financial performance that management believes are good tools for internal use and the investment community in evaluating the company’s overall financial performance. These non-GAAP measures help facilitate comparison of company operating performance across periods and with peer companies.
This news release contains certain “forward-looking statements” within the meaning of the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995. 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 or management’s estimates or opinions change.
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 “estimated resources”, “gross estimated resource,” and “gross mean resource estimate.” 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 risk 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 (Loss) to Adjusted Earnings
(in millions, except per share amounts, unaudited)
Three Months Ended Year Ended
December 31, December 31,
------------ ------------
Per
Diluted Per Per Per
Share Diluted Diluted Diluted
2011 [6] 2010 Share 2011 Share 2010 Share
---- -------- ---- -------- ---- -------- ---- --------
Net Income (Loss) $(296) $(1.67) $52 $0.29 $453 $2.54 $725 $4.10
Unrealized (gains)
losses on commodity
derivative instruments 162 0.91 145 0.81 22 0.13 (70) (0.39)
Asset impairments [1] 620 3.46 44 0.25 759 4.25 144 0.81
(Gain) loss on
divestitures [2] 1 0.01 1 0.01 (25) (0.14) (113) (0.63)
Drilling rig expense [3] - - - - 18 0.10 27 0.15
Other adjustments - - 2 0.01 4 0.02 4 0.02
--- --- --- ---- --- ---- --- ----
Total Adjustments before
tax 783 4.38 192 1.08 778 4.36 (8) (0.04)
Income Tax Effect of
Adjustments [4] (276) (1.54) (59) (0.33) (284) (1.59) 29 0.16
---- ----- --- ----- ---- ----- --- ----
Adjusted Earnings [5] $211 $1.18 $185 $1.04 $947 $5.31 $746 $4.22
---- ----- ---- ----- ---- ----- ---- -----
Weighted average number
of shares outstanding
Diluted [6] 177 178 179 177
[1] Impairments for 2011 related to our Piceance, Tri-State, East Texas, and Iron
Horse developments, all onshore US assets, due to a significant decline in the
natural gas prices, specifically during fourth quarter of 2011. Impairments for 2010
related to our Iron Horse development, an onshore US area, our non-core New Albany
Shale assets, our investment in the Noa/Noa South development, offshore Israel and
certain other Gulf of Mexico assets.
[2] Gain on divestitures in 2011 relates to the transfer of assets and exit from
Ecuador and in 2010 relates to the sale of non-core US onshore assets.
[3] Amount for 2011 represents stand-by rig expense incurred prior to receiving
permit to resume drilling activities in the deepwater Gulf of Mexico. Amount for
2010 represents costs to terminate a deepwater Gulf of Mexico drilling rig contract
due to the Federal Deepwater Moratorium.
[4] The net tax effects are determined by calculating the tax provision for GAAP Net
Income, which includes the adjusting items, and comparing the results to the tax
provision for Adjusted Earnings, which excludes the adjusting items. The difference
in the tax provision calculations represents the tax impact of the adjusting items
listed here. The calculation is performed at the end of each quarter and, as a
result, the tax rates for each discrete period may be different.
[5] Adjusted earnings should not be considered a substitute for net income (loss) as
reported in accordance with GAAP. Adjusted earnings is provided for comparison to
earnings forecasts prepared by analysts and other third parties. Our management
believes, and certain investors may find, that adjusted earnings is beneficial in
evaluating our financial performance as it excludes the impact of significant non-
cash items. We believe such measures can facilitate comparisons of operating
performance between periods and with our peers.
[6] The diluted weighted average number of shares outstanding used to calculate
"Adjusted Earnings Per Diluted Share" for the three months ended December 31, 2011
was 179 million shares.
Schedule 2
Noble Energy, Inc.
Summary Statement of Operations
(in millions, except per share amounts, unaudited)
Three Months
Ended Year Ended
December 31, December 31,
------------ ------------
2011 2010 2011 2010
---- ---- ---- ----
Revenues
Crude oil and condensate $653 $482 $2,373 $1,795
Natural gas 216 187 899 834
NGLs 68 61 264 203
Income from equity
method investees 48 33 195 118
Other revenues - 20 32 72
Total revenues 985 783 3,763 3,022
--- --- ----- -----
Operating Expenses
Lease operating expense 109 93 397 376
Production and Ad
Valorem taxes 38 29 146 125
Transportation expense 22 18 75 69
Exploration expense 85 78 279 245
Depreciation, depletion
and amortization 283 221 965 883
General and
administrative 87 83 341 277
(Gain) loss on
divestitures 1 1 (25) (113)
Asset impairments 620 44 759 144
Other operating expense,
net 41 14 86 64
--- --- ---
Total operating expenses 1,286 581 3,023 2,070
----- --- ----- -----
Operating Income (Loss) (301) 202 740 952
Other (Income) Expense
(Gain) loss on commodity
derivative instruments 137 123 (42) (157)
Interest, net of amount
capitalized 14 11 65 72
Other expense (income),
net 18 (1) 2 6
--- --- ---
Total other (income)
expense 169 133 25 (79)
--- --- --- ---
Income (Loss) Before
Taxes (470) 69 715 1,031
Income Tax Provision
(Benefit) (174) 17 262 306
Net Income (Loss) $(296) $52 $453 $725
----- --- ---- ----
Earnings (Loss) Per
Share, Basic $(1.67) $0.29 $2.57 $4.15
Earnings (Loss) Per
Share, Diluted (1.67) 0.29 2.54 4.10
Weighted Average Number
of Shares Outstanding,
Basic 177 175 176 175
Weighted Average Number
of Shares Outstanding,
Diluted 177 178 179 177
Schedule 3
Noble Energy, Inc.
Volume and Price Statistics
(unaudited)
Three Months
Ended Year Ended
December 31, December 31,
------------ ------------
2011 2010 2011 2010
---- ---- ---- ----
Crude Oil and
Condensate Sales
Volumes (MBbl/d)
United States 39 37 38 39
Equatorial Guinea 19 13 14 11
North Sea 8 10 8 10
China 4 4 4 4
--- --- --- ---
Total consolidated
operations 70 64 64 64
Equity method investee 2 1 2 2
---
Total sales volumes 72 65 66 66
--- --- --- ---
Crude Oil and
Condensate Realized
Prices ($/Bbl)
United States $95.45 $80.52 $95.19 $75.03
Equatorial Guinea 105.90 86.11 107.57 78.44
North Sea 112.90 89.28 112.97 80.24
China 109.37 80.77 106.19 75.15
------ -----
Consolidated average
realized prices $101.12 $83.02 $100.93 $76.46
------- ------ ------- ------
Natural Gas Sales
Volumes (MMcf/d)
United States 432 402 388 400
Equatorial Guinea 250 243 245 226
Israel 150 131 173 130
North Sea 4 4 5 6
Ecuador - 17 - 25
Total sales volumes 836 797 811 787
--- --- --- ---
Natural Gas Realized
Prices ($/Mcf)
United States $3.42 $3.57 $3.90 $4.17
Equatorial Guinea 0.27 0.27 0.27 0.27
Israel 5.10 3.87 4.86 4.03
North Sea 9.09 5.83 8.11 5.35
Average realized
prices $2.81 $2.61 $3.04 $3.00
----- ----- ----- -----
Natural Gas Liquids
(NGL) Sales Volumes
(MBbl/d)
United States 16 15 15 14
Equity method investee 6 7 5 5
---
Total sales volumes 22 22 20 19
--- --- --- ---
Natural Gas Liquids
Realized Prices
($/Bbl)
United States $46.11 $43.88 $48.35 $41.21
Barrels of Oil
Equivalent Volumes
(MBoe/d)
United States 127 119 117 119
Equatorial Guinea 61 53 56 49
Israel 25 22 29 22
North Sea 9 10 9 11
Ecuador - 3 - 4
China 4 4 4 4
--- --- --- ---
Total consolidated
operations 226 211 215 209
Equity method investee 7 8 7 7
Total barrels of oil
equivalent (Mboe/d) 233 219 222 216
--- --- --- ---
Barrels of oil
equivalent volumes
(MMBoe) 21 20 81 79
--- --- --- ---
Schedule 4
Noble Energy, Inc.
Condensed Balance Sheets
(in millions)
December 31,
------------
2011 2010
---- ----
Assets
Current Assets
Cash and cash equivalents $1,455 $1,081
Accounts receivable, net 783 556
Other current assets 180 201
--- ---
Total current assets 2,418 1,838
Net property, plant and equipment 12,782 10,264
Goodwill 696 696
Other noncurrent assets 548 484
Total Assets $16,444 $13,282
------- -------
Liabilities and Shareholders' Equity
Current Liabilities
Accounts payable - trade $1,343 $927
Other current liabilities 925 495
--- ---
Total current liabilities 2,268 1,422
Long-term debt 4,100 2,272
Deferred income taxes 2,059 2,110
Other noncurrent liabilities 752 630
--- ---
Total Liabilities 9,179 6,434
Total Shareholders' Equity 7,265 6,848
Total Liabilities and Shareholders' Equity $16,444 $13,282
------- -------
Schedule 5
Noble Energy, Inc.
Discretionary Cash Flow and Reconciliation to Operating
Cash Flow
(in millions, unaudited)
Three Months
Ended Year Ended
December 31, December 31,
------------ ------------
2011 2010 2011 2010
---- ---- ---- ----
Adjusted Earnings [1] $211 $185 $947 $746
Adjustments to reconcile
adjusted earnings to
discretionary cash flow:
Depreciation, depletion
and amortization 283 221 965 883
Exploration expense 85 78 279 245
(Income)/distributions
from equity method
investments, net 7 15 30 21
Deferred compensation
(income) expense 23 11 8 15
Deferred income taxes 44 17 204 31
Stock-based compensation
expense 15 14 58 54
Other 9 (3) 9 (14)
Discretionary Cash Flow
[2] $677 $538 $2,500 $1,981
---- ---- ------ ------
Reconciliation to
Operating Cash Flows
Net changes in working
capital (259) 24 (156) 158
Cash exploration costs (37) (77) (175) (187)
Current tax expense of
earnings adjustments 5 4 - 12
Stand-by rig expense [3] - - (18) (27)
Other adjustments (1) 5 19 9
--- ---
Net Cash Provided by
Operating Activities $385 $494 $2,170 $1,946
---- ---- ------ ------
Capital expenditures
(accrual based) $1,039 $596 $3,024 $2,143
Increase in FPSO lease
obligation 10 78 66 266
Marcellus Shale Asset
Acquisition [4] 75 - 1,308 -
DJ Basin Asset
Acquisition - - - 498
Total Capital
Expenditures (Accrual
Based) $1,124 $674 $4,398 $2,907
------ ---- ------ ------
Proceeds from
Divestitures $- $12 $77 $564
--- --- --- ----
[1] See Schedule 1, Reconciliation of Net Income to
Adjusted Earnings.
[2] The table above reconciles discretionary cash flow
to net cash provided by operating activities.
Adjustments for capitalized interest were
retrospectively removed from our discretionary cash flow
calculation as of March 31, 2011. 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.
[3] Amount for 2011 represents stand-by rig expense
incurred prior to receiving permit to resume drilling
activities in the deepwater Gulf of Mexico. Amount for
2010 represents costs to terminate a deepwater Gulf of
Mexico drilling rig contract due to the Federal
Deepwater Moratorium
[4] Year ended December 31, 2011, includes $69 million
representing our initial investment in CONE Gathering
LLC.
Schedule 6
Noble Energy, Inc.
Effect of Commodity Derivative Instruments
(in millions, unaudited)
Three Months
Ended Year Ended
December 31, December 31,
------------ ------------
2011 2010 2011 2010
---- ---- ---- ----
Reclassification from Accumulated Other
Comprehensive Loss (AOCL) to Revenue [1]
Crude Oil $- $5 $- $19
Natural Gas - - - 1
Total Revenue Decrease $- $5 $- $20
--- --- --- ---
(Gain) Loss on Commodity Derivative Instruments
Crude oil
Realized $8 $19 $44 $23
Unrealized 173 94 5 35
Total crude oil $181 $113 $49 $58
---- ---- --- ---
Natural gas
Realized $(33) $(41) $(108) $(110)
Unrealized (11) 51 17 (105)
Total natural gas (44) 10 (91) (215)
--- --- --- ----
Total (Gain) Loss on Commodity Derivative
Instruments $137 $123 $(42) $(157)
---- ---- ---- -----
Summary of Cash Settlements
Realized (gain) on commodity derivative instruments $(25) $(22) $(64) $(87)
Amounts reclassified from AOCL - 5 - 20
--- --- ---
Cash settlements (received) paid $(25) $(17) $(64) $(67)
---- ---- ---- ----
[1] The amounts reclassified from AOCL represented deferred unrealized hedge gains
and losses. All hedge gains or losses had been reclassified to revenues by
December 31, 2010.
Schedule 7
Noble Energy, Inc.
Supplemental Data
(in millions)
(Unaudited)
2011
Costs
Incurred
in Oil
and Gas
Activities United States Int'l [1] Total
------------- --------- -----
Property
acquisition
costs
Proved $392 $- $392
Unproved 942 40 982
Total
acquisition
costs 1,334 40 1,374
Exploration
costs 241 352 593
Development
costs
[2] 1,511 955 2,466
----- --- -----
Subtotal
costs
incurred 3,086 1,347 4,433
Increase
in FPSO
Lease
Obligation - 66 66
Total
costs
incurred $3,086 $1,413 $4,499
------ ------ ------
Reconciliation to Capital
Spending (accrual basis)
Total
costs
incurred $4,499
Exploration
overhead (95)
Lease
rentals (4)
Asset
retirement
obligations (128)
----
Total
oil and
gas
spending 4,272
CONE LLC
Investment 69
Other
capital 57
---
Total
capital
spending
(accrual
basis) $4,398
------
Proved
Reserves
[4] United States Int'l [3] Total
------------- --------- -----
Total
Barrel
Oil
Equivalents
(MMBoe)
Beginning
reserves
-
December
31,
2010 496 596 1,092
Revisions
of
previous
estimates (45) (5) (50)
Extensions,
discoveries
and
other
additions 97 83 180
Purchase
of
minerals
in place 68 - 68
Sale of
minerals
in
place - - -
Production (43) (38) (81)
---
Ending
reserves
-
December
31,
2011 573 636 1,209
--- --- -----
Proved
Developed
Reserves
(MMBoe)
December
31, 2010 312 190 502
December
31, 2011 333 171 504
[1] International includes Equatorial Guinea, Israel,
Cameroon, Cyprus, Senegal, Guinea-Bissau, North Sea, China,
France and Nicaragua.
[2] Includes ARO costs of $115 million for United States and
$13 million for Int'l.
[3] International includes Equatorial Guinea, Israel, North
Sea and China.
[4] Netherland, Sewell & Associates, Inc. performed an audit
of approximately 90% of Noble Energy's year-end 2011 total
proved reserves and concluded the Company's estimates of
proved reserves, in the aggregate, are reasonable and have
been prepared in accordance with generally accepted petroleum
engineering and evaluation principles.
SOURCE Noble Energy
