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Noble Energy Announces Highlights of 2012 Analyst Conference



         Noble Energy Announces Highlights of 2012 Analyst Conference

PR Newswire

HOUSTON, Dec. 6, 2012

HOUSTON, Dec. 6, 2012 /PRNewswire/ -- Noble Energy, Inc.'s (NYSE: NBL) senior
management is hosting a conference today in Houston, Texas with analysts and
investors to discuss the Company's current operations, future plans and
operational outlook.  Today's presentation includes the following key
highlights:

  o The Company's production is projected to increase at a compound annual
    growth rate (CAGR) of 17 percent over the next five years, resulting in
    average daily production of 540 thousand barrels of oil equivalent per day
    (MBoe/d) in 2017
  o Net risked resources have increased to 9.9 billion barrels of oil
    equivalent (BBoe), up 34 percent since 2011
  o The Company's total proven reserves are expected to be 2.6 BBoe by the end
    of 2016, representing a CAGR of 16 percent from year-end  2011
  o Discretionary cash flow is expected to exceed $7 billion by 2017, a CAGR
    of 21 percent
  o The horizontal Niobrara program in the DJ Basin has evolved into a
    top-tier U.S. oil play resulting in the acceleration of the drilling
    program to over 500 horizontal wells per year and net horizontal
    production of 175 MBoe/d by 2017
  o The development of the giant Leviathan field offshore Israel has been
    significantly advanced with the announced agreement in principle with a
    strategic partner

The Company announced a $3.9 billion capital program for 2013 and volume
guidance of 270 to 282 MBoe/d, representing a growth rate of 20 percent
adjusting for 2012 divestments

Charles D. Davidson, Noble Energy's Chairman and CEO said, "I am very excited
about the future plans we are presenting today.  Noble Energy continues on a
path of accelerating high value opportunities such as the horizontal Niobrara,
which we believe is now one of the top oil resource plays in the United
States.  As a result, we are accelerating the drilling program in this area
with a 50% increase in wells drilled next year.  However, Noble Energy's
bright future is not just about one area or one play.  Today, we are
highlighting the extraordinary growth opportunities we are pursuing throughout
our diversified global portfolio.  This portfolio continues to expand rapidly
with net risked resources now totaling 9.9 BBoe, a 34 percent increase over
just one year.  As we execute our growth agenda, the results now project
five-year debt adjusted growth rates in reserves, production and cash flow
that are all higher than those announced a year ago.  We believe these growth
rates, all solidly in double-digit territory, position Noble Energy to be a
top performer among our peers."

DJ Basin

Noble Energy continues to grow the resource size and accelerate the
development of its top-tier Niobrara oil play in the DJ Basin.  Net
recoverable resources are now estimated to be 2.1 BBoe, a 60 percent increase
over last year's estimate.  As a result, the drilling program has identified
9,500 horizontal well locations and is accelerating its drilling to over 500
wells per year by 2017.  The Company's accelerated development program is now
expected to grow DJ Basin production at a five-year CAGR of 20 percent,
tripling oil production. 

By adopting a fully integrated approach utilizing leading edge exploration and
reservoir technologies with its operational expertise, Noble Energy has
continued to advance its reservoir understanding resulting in increased
projected recoveries.  Tighter well spacing, multiple target zones, longer
laterals and improved completions have increased estimated ultimate recoveries
(EURs) and resulted in higher returns.    

Horizontal drilling has shifted the development focus to the oil rich window
(approximately 520,000 net acres) away from the legacy Wattenberg gas window
(approximately 120,000 net acres).  The oil rich window extends outside of the
Greater Wattenberg Area (GWA) and into Northern Colorado where oil content is
approximately 80 percent. 

Utilizing an average of nine rigs, the Company intends to drill approximately
300 horizontal wells in the DJ Basin in 2013, of which 20 percent will be
extended reach laterals.  Current production is nearly 90 MBoe/d with 60
percent liquids and is expected to exit 2013 at over 110 MBoe/d. 

Marcellus

Since the establishment of the innovative Marcellus joint venture (JV) in
September 2011, production has more than doubled to approximately 140 million
cubic feet equivalent per day (MMcfe/d).  In the current environment, Noble
Energy and its partner are focused on accelerating the development of the wet
gas areas while maintaining a lower level of activity in the dry gas areas. 
Better than forecasted well performance has resulted in normalized type curves
increasing by an average of 28 percent over the acquisition type curves.  This
higher EUR forecast, combined with optimized field development, has increased
the total resource estimate by 41 percent to 10 trillion cubic feet equivalent
(Tcfe) net.  Net production is expected to grow at a five-year CAGR of 55
percent, exceeding 800 MMcfe/d in 2017.

To further improve performance, the JV is integrating sub-surface analysis
with production results to optimize well placement and stimulation design. 
Operational tests such as tighter control of lateral well steering within the
best Marcellus reservoir interval and shorter staging for hydraulic fractures
are underway.  Noble Energy is sharing best practices across the JV operations
with a focus on continuous improvement.  The JV is targeting increased
reserves per well and a 20 percent reduction in well costs through these
efforts. 

In the wet gas area, the Company is focused on a 270 well development program
in the Majorsville area where the initial results indicate higher liquids
content and initial production rates than expected.  The contribution of
condensate and NGLs results in a realized price of over $7 per wellhead Mcf. 
A second development area called Normantown is being delineated with over 200
planned well locations. 

In 2013, the JV expects to drill 140 wells with 60 percent in the wet gas area
and to increase lateral lengths to an average of 5,500 feet.  The increased
lateral lengths will contribute to higher well EURs and a reduction in cost
per lateral foot completed.  The rig count for 2013 is expected to build up to
six in the wet gas area while remaining at two in the dry gas area where the
focus is on the extremely productive and high net revenue interest (NRI)
acreage in Southwestern Pennsylvania. 

Deepwater Gulf of Mexico

The Deepwater Gulf of Mexico continues to be a strong contributor to the
Company's performance.  With the recent discovery at Big Bend and successful
appraisal at Gunflint, Noble Energy now has two new major projects, both
expected to be sanctioned for development in 2013. 

The Galapagos project continues to outperform expectations.  The three well
project was brought online in June at rates 40 percent above initial estimates
and has a before tax net present value of $1.4 billion.  The recent discovery
at Big Bend in the Rio Grande area discovered oil in excellent reservoir
comparable to Galapagos and has a P75-P25 gross resource range of 30 to 65
million barrels of oil equivalent (MMBoe).  Troubadour, an adjacent Rio Grande
prospect that has been de-risked by the success at Big Bend, has a pre-drill
P75-P25 gross resource range of 20 to 60 MMBoe.  Noble Energy has an average
working interest of 70 percent between Big Bend and Troubadour and development
will likely be via a high rate multi-well subsea tieback similar to
Galapagos. 

After the recent appraisal well at Gunflint, the estimated P75-P25 gross
resource range is 90 to 325 MMBoe, which includes an untested Lower Miocene
objective.  A second appraisal well is planned to spud in January 2013 and
development pre-FEED work is underway.  Initial production is expected by late
2015 as a subsea tieback or by 2017 as a standalone facility. 

Looking forward, the Company will mature its significant prospect inventory
and execute an exploration program balanced between low-risk amplitude
prospects and high-impact subsalt prospects.  By the end of 2013, the first of
three subsalt prospects in the Aleutians area is scheduled to be tested.  The
combined gross mean resource of these prospects is 339 MMBoe.  A second focus
area in Mississippi Canyon is scheduled for drilling to begin in 2014 and
contains five significant prospects with a combined gross mean resource of 673
MMBoe.

Eastern Mediterranean

In the world-class Levant Basin, Noble Energy has been providing reliable gas
to Israel since 2004 resulting in significantly lower energy costs and reduced
CO[2 ]emissions.  Natural gas demand in Israel continues to rise due to
growing electricity demand and the emergence of new industrial customers. 

To satisfy this strong demand, Noble Energy is developing the largest offshore
project in Company history.  The Tamar project is on schedule for first
production in April 2013.  Sales for the remainder of 2013 following first
production are expected to average approximately 700 MMcf/d with a peak
capacity of nearly 1 billion cubic feet per day (Bcf/d).  The jacket and
topsides installations will be completed by the end of the year and the
world's longest subsea tieback will begin commissioning shortly thereafter. 
The realized price will be a blended price that will rise as Tamar volumes
continue to grow.  Future expansion phases will increase deliverability using
compression at the onshore terminal along with a combination of system
optimization and storage at Mari-B, allowing sales to grow to an average of
approximately 1 Bcf/d. 

The 17 Tcf Leviathan development will increase the deliverability and
reliability of domestic supply to Israeli customers.  Development plans have
been significantly advanced with the announced agreement in principle with
Woodside Energy as a strategic partner in the project.  Noble Energy will
continue as upstream operator and will retain 30 percent working interest. 
The first phase of development includes domestic capacity to deliver up to 750
MMcf/d via a northern entry point in 2016.  The project plans additional
capacity for exports via pipeline, onshore LNG, or floating LNG as early as
2018.  The Mesozoic oil prospect below the Leviathan gas discovery is planned
to be spud late next year. 

The Company is progressing its evaluation of development concepts at its
Cyprus discovery and continues to work with the Government of Cyprus on
monetization options.

West Africa

Production from the Aseng field in Block I and the Alba field, both offshore
Equatorial Guinea, continues to provide very strong cash flows supporting
Noble Energy's major developments in West Africa.  Strong operational
execution at Aseng has resulted in an average production rate of 60 MBbl/d
gross with over 99 percent uptime since start-up in November of 2011.  The
floating production, storage and offloading (FPSO) vessel at Aseng and the
processing platform at Alen will provide regional infrastructure for future
developments which are expected to benefit from lower overall operating costs.

Noble Energy has applied learnings from the major project development at Aseng
to the Alen project, which is now ahead of schedule.  The well operations are
complete and the platform is preparing for loadout.  The platform installation
is planned for the second quarter of 2013 and first production is now expected
in the third quarter.  Alen is among the most sophisticated projects that the
Company has undertaken and includes processing, liquids offtake to the Aseng
FPSO, and gas reinjection to the reservoir.  Integral to the project
achievements has been strong relationships with contractors demonstrated
through an attitude of shared success and the early installation of the
wellhead platform allowing drilling work to be completed off the project
critical path.  The Company expects first production at 40 MBbl/d gross, 18
MBbl/d net.

Recent successful appraisal drilling at Carla, an oil discovery located
beneath the Alen field, is moving field development ahead with project
sanction now expected in 2013.  The plan of development entails utilizing the
Aseng FPSO as a regional oil hub with first production in early 2016 and an
initial production rate of 11 MBbl/d net.  The Carla discovery has a P75-P25
gross resource range of 36 to 136 MMBoe.  Diega, another nearby oil discovery
with a P75-P25 gross resource range of 65 to 116 MMBoe, is targeted for
appraisal drilling in 2014.

Exploration and New Ventures

Noble Energy has a legacy of exploration success demonstrated by the three
core areas created through exploration efforts and 2.7 BBoe of net resources
discovered since 2007.  New Ventures teams actively evaluate frontier plays
with sufficient size and running room to mature into additional core areas. 
Successful plays would further enhance the Company's significant growth
profile.  The Company utilizes a stage-gate decision process that analyzes,
tests, and exits unsuccessful opportunities with limited capital investment
while ensuring the ability to competitively monetize successful discoveries at
industry leading cycle times.    

In Nevada, the Company is testing a tight oil play on a 350,000 net acre
position.  Two 3D seismic surveys have been completed and their analysis will
drive a phased vertical drilling program in 2013.  The play has a P75-P25
gross unrisked resource range of 190 – 1,400 MMBoe with a 55 percent chance of
geologic success.  With positive drilling results, development drilling and
oil production would commence in 2014.

Noble Energy has a 1.8 million acre gross position offshore Nicaragua with
multiple oil prospects and leads.  The Paraiso prospect is scheduled to be
drilled in 2013 and has a P75-P25 gross unrisked resource range of 210 to
1,220 MMBoe with a 25 percent chance of geologic success.  Development would
likely be via FPSO with initial production targeted for 2018.

The Company's largest new venture play is its 35 percent interest in a 10
million gross acre position offshore Falkland Islands that represents a gross
unrisked resource potential of 13 BBoe.  Acquisition of 3D seismic has begun
and will last approximately five months.  Results from the recent Scotia
exploration well will be integrated with the 3D seismic to determine future
locations for a 2014 drill plan. 

The New Venture program, when combined with the ongoing exploration program,
creates both near and long-term value for the Company.  By 2014, 25% of the
Company's net production is expected to be from discoveries made in the last
five years.  The current exploration prospect inventory is at the highest
level in Company history.  During the next two years, exploration wells will
test 7 BBoe gross unrisked resources plays.

Analyst Meeting Webcast

Noble Energy's 2012 analyst conference will be available via webcast at 8 a.m.
Central Time, December 6, 2012, on the 'Investors' page of the Company's
website at www.nobleenergyinc.com.  A replay of the webcast will be available
on the website until February 15, 2013. 

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 or
management's estimates or opinions change.

This news release also contains certain historical and forward-looking
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 also see Noble Energy's website at http://www.nobleenergyinc.com under
"Investors" 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 GAAP measures most comparable to the
forward-looking non-GAAP financial measures are not accessible on a
forward-looking basis and reconciling information is not available without
unreasonable effort.

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 "net risked resources", "estimated ultimate recovery" or
"EUR", "gross resources" and "gross mean 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 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.  

SOURCE Noble Energy

Website: http://www.nobleenergyinc.com
Contact: David Larson, +1-281-872-3125, dlarson@nobleenergyinc.com, or Eric
Schneider, CFA, +1-281-872-2640, eschneider@nobleenergyinc.com
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