ex99_4-20130730.htm

Second Quarter 2013 Earnings - Highlights

• Total Production (Boe/d)

• Operating costs

• Capital program

• Core earnings

• Core diluted EPS

• YTD CFFO before WC

• Cash balance @ 6/30/2013

See Significant Items Affecting Earnings in the Investor Relations Supplemental Schedules.

Results

772,000

On track

$1.3 billion

$1.58

$6.4 billion

$3.1 billion

Second Quarter 2013 Earnings - Highlights

Quarter-over-Quarter Impacts

• Improved oil and gas results.

+ Increased oil volumes, primarily in
MENA.

+ Increased domestic realized oil and
gas prices.

– Lower international realized oil prices.

• Lower marketing and trading
income.

• Higher equity compensation
expense.

See Significant Items Affecting Earnings in the Investor Relations Supplemental Schedules

Core Diluted EPS

$1.58

$1.69

$1.64

Second Quarter 2013 Earnings - Oil and Gas Total
Production

772

(2)

(3)

(7)

766

Company-wide Oil & Gas Production (Mboe/d)

763

2Q13 Impacts (Mboe/d)

• Permian weather &

gas plant turnarounds

• Colombia activity

(1)

Second Quarter 2013 Earnings - Oil and Gas
Domestic Production

462

(5)

478

(2)

470

Domestic Oil & Gas Production (Mboe/d)

2Q13 Impacts (Mboe/d)

• Permian weather -

oil impact

• Plant turnaround -

gas impact

Second Quarter 2013 Earnings - Oil & Gas
Realized Prices

Worldwide

Oil ($/bbl)

Worldwide

NGLs ($/bbl)

Domestic Nat.

Gas ($/mmbtu)

2Q13	$97.91	$38.78	$3.82
Benchmark %	104% *	41% *	95%
1Q13	$98.07	$40.27	$3.08
Benchmark %	104% *	43% *	91%
2Q12	$99.34	$42.06	$2.09
Benchmark %	106% *	45% *	91%

$94.22	$103.35	$4.00

$94.37	$112.64	$3.37

$93.49	$108.90	$2.28

WTI

NYMEX

Price Sensitivity	Pre-tax Income Impact
Oil +/- $1/bbl	=	+/- $38 mm
NGL +/- $1/bbl	=	+/- $8 mm
U.S. Nat Gas +/- $0.50/mmbtu	=	+/- $30 mm

Brent

Realized Prices

Benchmark Prices

* Note: As a % of WTI Oil.

Second Quarter 2013 Earnings - Oil & Gas
Production Costs

FY12 1Q13 2Q13 YTD13

Domestic $17.43 $14.06 $14.28 $14.17

Total $14.99 $13.93 $13.40 $13.66

Production Costs ($/boe)

• ~$500 million annualized domestic cost savings versus
full year 2012.

* Higher energy and feedstock costs.

2Q13 vs. 1Q13

($ in millions)

Guidance

3Q13 expected
to be ~$170 mm

Second Quarter 2013 Earnings - Chemical Segment
Core Earnings

Core Results

• 2Q13 $144 mm

• 1Q13 159 mm

• 2Q12 194 mm

Second Quarter 2013 Earnings - YTD 2013 Cash Flow

YE2012 vs. YTD2013

($ in millions)

Cash Flow
From
Operations
before
Working
Capital
changes

$6,000

$150

Beginning
Cash $1,600
12/31/12

$3,100

YTD’13
Debt / Capital 15%

Return on Equity 13%

Return on Capital Employed* 11%

* Note: Annualized; See attached GAAP reconciliation.

Second Quarter 2013 Earnings -
Key Performance Metrics - Domestic Production

• Occidental’s domestic oil and gas segment continued to execute on our
liquids production growth strategy.

− 2Q13 domestic production of 470 mboe/d, consisting of 338 mboe/d of liquids and 792 mmcf/d of gas.

− Planned plant maintenance and storms in the Permian negatively impacted production during 2Q13.

− 2Q13 domestic production generally in line with our expectations, except for the impact of storms.

Total Domestic Oil Production

+16 mboe/d
production
growth

Total Domestic Production

+16 mboe/d
production
growth

Second Quarter 2013 Earnings - Capital Efficiency
& Operating Cost Reduction Program

• Focused drilling program in our core areas

− Reduced our domestic well costs by 21% and operating costs by ~19% relative to
2012, ahead of previously stated targets of 15% well cost improvement and total oil
and gas operating costs below $14/boe for 2013.

• Believe we can sustain the benefits realized to date, achieve additional savings
in our drilling costs and reach our 2011 operating cost levels without a loss in
production or sacrificing safety.

• The purpose of these initiatives is to improve our return on capital.

Production Costs ($/boe)

Second Quarter 2013 Earnings - California
Operations Highlights

• Largest producer of natural gas and
oil and gas on a gross operated BOE
basis.

• Largest oil & gas mineral acreage
holder, with more than 2.1 mm net
acres.

• Diverse geologic characteristics and
numerous reservoir targets, range
from conventional to steam and water
floods and unconventional.

Second Quarter 2013 Earnings - California
Operations - 2013 Strategic Objectives

2013 Objectives

• Deliver predictable outcome given constraints of working in California.

• Advance projects with solid returns, low execution risk and long term
growth.

• Reducing drilling and completion costs to improve finding and
development costs and our project economics.

• Reduce operating costs without affecting production to improve current
earnings and free cash flow.

• Build a growing, highly predictable and lower decline base of production.

• Test various exploration and development concepts from a cost
improvement and execution predictability perspective.

Second Quarter 2013 Earnings - California
Operations - New Organizational Structure

• Restructured business units to create teams organized around
the unique characteristics of each asset group, resulting in a
5th business unit dedicated to managing heavy oil properties.

• Created 3 technical teams to enhance recovery from the complex
reservoirs in California.

– Allows us to grow California operations more efficiently and maximize the
benefits of our improved cost structure.

Elk Hills

Vintage

LA Basin

Long Beach

Heavy Oil

Business Units

Water Flood

EOR/Steam

Flood

Unconventional

New Technical Teams

California Operations

New Unit

Second Quarter 2013 Earnings - California
Operations - Operating Efficiency

• Significantly reduced operating costs as well as drilling costs
in California, exceeding our targets.

– Expect to save at least $175 million this year in operating costs.

Second Quarter 2013 Earnings - California
Operations - Capital Efficiency

• Improved capital efficiency by ~15% compared to 2012

– Locked in drilling programs

– Revised well designs

– Optimized drilling equipment and fluids to reduce drill time

– Improved contracting strategies

Second Quarter 2013 Earnings - California
Operations - Capital Program

Sufficient inventory to sustain this
strategy for at least 5 years, likely
10+ years, with flexibility to adjust
liquids vs. gas production based
on market conditions.

California 2013 Capital - $1.5 bn

Second Quarter 2013 Earnings - California
Operations - Water Floods

• Water floods are a core
competency of Oxy.

• Several new projects in
progress and a number of
floods where we are engaged
in redevelopment, expansion
or optimization activities.

• Wilmington Field

• Huntington Beach

• Expect 20%+ returns from
2013 water flood capital.

Los Angeles Basin

Second Quarter 2013 Earnings - California
Operations - Water Floods

• Most water flood capital directed to
optimize our most developed project,
the giant Wilmington Field.

– 135 new wells including 35 horizontal
wells.

– Horizontal wells can have average IP
rates over 3x higher than a similar
vertical well at a cost of just 20% more.

• Since acquiring the asset in 2000,
proven reserves have steadily grown
despite 12 years of production.

• 1,000+ future well locations.

• Up to 100 MMBOE of reserve
potential over next 7 years.

Wilmington Field Water Flood

Second Quarter 2013 Earnings - California
Operations - Water Floods

• Huntington Beach Field Redevelopment

– Adding two new fit-for-purpose rigs, one designed for drilling in urban areas.

– Expect to begin drilling towards year end 2013.

– 128 well locations identified, providing 4-5 years of inventory using the 2 rigs.

– Expect to add more well locations applying reservoir modeling and surveillance
as we’ve done in the analog Wilmington Field.

– We believe that we can increase our production from this field by 10,000 boe/d
and develop reserves of at least 50 MMBOE.

• Buena Vista Field

– Drill 150+ wells over next 5 years.

– Increase production by 4,000 boe/d and add 28 MMBOE of reserves.

• Have several other water floods in the pilot phase this year, several
under evaluation for redevelopment and a long list of potential
projects in the water flood screening process.

Second Quarter 2013 Earnings - California
Operations - Steam Floods

• Steam flood activities have been a focus in 2013

– Highly profitable, taking advantage of the gas versus oil price spread
where cheap gas is used to generate steam, which is then injected to
produce oil.

• These projects can deliver attractive returns at a combination
of gas prices as high as $6 per MMCF and oil prices as low as
$80 per barrel.

– Typical rates of return expected to be 25% or better.

Second Quarter 2013 Earnings - California
Operations - Steam Floods

• Kern Front and Lost Hills

− 2 largest steam floods

− > 1 billion barrels of original oil in
place; ~ 870 million barrels oil
remaining in place

− Added 2 rigs and expect to drill
~200 wells in 2H13 and grow
production by 3,000 BOEPD vs. 2013
entry rate and with full development
increasing by 15,000 BOEPD over
time.

− Believe this could develop
120 MMBOE of reserves.

• Oxnard and Midway Sunset Area

− With these pilot steam floods, we
expect to develop an additional 45
MMBOE of reserves.

Ventura (Oxnard)

Bakersfield

Lost Hills

Kern Front

Second Quarter 2013 Earnings - California
Operations - Steam Floods

• Total steam flood spending will constitute ~25% of total
California capital in 2013.

– Expect to drill >1,500 steam flood wells over the next 5 years.

• With shift of capital to water and steam flood opportunities,
we expect a lag of about 6 to 9 months before seeing
sustained production growth as the flow of new projects
reaches a steady level.

• Currently in a transition period but are now beginning to see
the initial phases of growth from these projects.

Second Quarter 2013 Earnings - California
Operations - Unconventional

• In addition to shale plays, our
“unconventional” opportunities
include reservoirs that have low
permeability, which require special
recovery processes to flow.

• ~1/3rd of our California production
is from unconventional reservoirs.

• Plan to drill >70 unconventional
wells in 2013.

• >1,000,000 prospective acres.

• Up to 7 Billion BOE of recoverable
reserves.

“Unconventional”
Production

Sacramento

San
Francisco

Los Angeles

Bakersfield

Oxy Acreage

Second Quarter 2013 Earnings - California
Operations - Unconventional

• Drilled ~1,300 unconventional wells
in California since 1998.

• >1,000 of these are in and around
Elk Hills, including the Monterey
and other key shale plays.

• 2013 plan includes 53
unconventional wells from multiple
shale plays around Elk Hills with
varying costs and performance.

– Program delivers 20%+ ROR

• Ongoing program around Elk Hills
is expected to increase ultimate
recovery by ~150 MMBOE.

Second Quarter 2013 Earnings - California
Operations - Unconventional

• Pursuit of Unconventional
Opportunities outside Elk Hills
includes the Rose Field.

• Acquired in late 2009, drilled 1
appraisal well in 2011, 8 development
wells in 2012 and 6 horizontal wells
in 2013.

• Very good results with average IP
rates exceeding expectations.

– Believe returns from this field will
be ~25% over the course of the
development program.

• Plan to drill unconventional wells in
South Belridge and Buena Vista this
year.

– Could provide >100 well locations
and 35 MMBOE of net reserves.

Second Quarter 2013 Earnings - California
Operations - Elk Hills

Elk Hills Field

• Have almost doubled proved
reserves since acquisition in
1998.

• Goal is to reduce the underlying
25% base decline rate by as much
as half.

− EOR projects (steam, water, polymer,
CO2 floods) could be implemented
over the next 3-10 years.

− OPEX/CAPEX reductions will improve
profitability of these water flood and
EOR opportunities.

• New cryogenic gas plant up time
>98% with record NGL yields.

• Elk Hills has 900+ MMBOE of
remaining reserves and resources
recoverable through water floods
and proven EOR technologies.

Second Quarter 2013 Earnings - California
Operations - Exploration

• >100 exploration wells drilled over past 5 years.

• Two thirds have found hydrocarbons and a large portion of these
resulted in commercial production.

• 3D seismic has been acquired over a significant portion of our acreage
contributing to our high rate of success.

• Made significant unconventional discovery in San Joaquin basin last year

– Continued appraisal drilling and testing this year established reserves and resources of
~50 MMBOE.

– Full development of this discovery is expected to require drilling 100 wells.

– In addition to the 50MMBOE we’ve established, we are testing and/or planning wells
in late 2013 and 2014 that, if successful, will double this volume.

– Further, this concept has repeatability and we plan to extend this play through much of our
California acreage.

• 2013 exploration program, which includes 15 wells, is on track to deliver
results consistent with prior years, and we continue to build inventory to
ensure we have a robust exploration program going forward into 2014
and beyond.

Second Quarter 2013 Earnings - California
Operations - Conventional Gas Properties

• Established sizeable conventional
natural gas position in the
Sacramento Basin.

– >318,000 net acres.

– ~66 MMcf/d of dry gas production.

– Largest operator in region (80%+).

• Optimize production with workovers
and modest drilling program of 8 new
wells in 2013 and 14 in 2014.

• Ability to ramp development with gas
prices at ~$5.00 per mcf.

• Identified total reserves and
contingent resources of ~300 Bcf.

– ~10 Tcf of original gas-in-place.

– ~2 Tcf remaining.

Oxy Properties operated by Vintage
business unit

Sacramento Basin

Second Quarter 2013 Earnings - California
Operations - Summary

• Large inventory of diverse projects.

– Water floods

– Steam floods

– Additional EOR (CO2, polymer floods, etc.)

– Unconventional

• Similar mix of projects in near-term with larger portion of
capital allocated to lower decline projects while achieving
healthy production growth.

Second Quarter 2013 Earnings - California
Operations - Summary

Progress toward 2013 Goals:

• $1.5 billion capital program and expect to generate free cash flow of over
$1 billion.

– With continued improvements in permitting, should be able to grow capital
budget to $2.0 billion in 2014, with further increases beyond that to ~$2.5 billion
on a sustainable basis.

• Expect production growth of at least 5-8% annually with > 20% ROR.

• Improved capital efficiency by 15% and reduced operating expenses by
~$3.50/boe, saving at least $175 million in 2013.

• Have identified 5,500+ well locations across large and diverse portfolio
and will add more through future projects.

• Exploration program delivered high rate of success, including significant
unconventional discovery in San Joaquin basin.

Second Quarter 2013 Earnings -
2013 Production Outlook

• Domestically, we continue to expect solid growth in our oil
production for the year.

− Based the nature and timing of our drilling program, such as steam
flood drilling in California, and the timing of gas plant maintenance
turnarounds in the Permian, we expected production growth to occur
in the 2nd half of the year.

− We have achieved the drilling targets we set in 1H13.

− As a result, we expect that 2H13 average domestic oil production
will be ~ 6,000 to 8,000 barrels a day higher than the 1H13 average,
the increases coming mainly from the Permian and California.

− We expect the modest declines in our domestic gas and NGLs
production that we have seen in 2Q13 to continue as a result of our
reduced drilling on gas properties and natural decline as well as
additional gas plant turnarounds scheduled in our Permian business
the rest of the year.

Second Quarter 2013 Earnings -
2013 Production Outlook

• Internationally, we expect more cost pool depletions in our
contracts in Qatar and Yemen, which will result in less cost
recovery barrels from those locations.

• However, we expect total international production to be
about flat in 2H13 compared to 2Q13 volumes, assuming
no renewed pick-up in insurgent activity in Colombia and
stable spending levels in Iraq.

• We expect international sales volumes to increase in 2H13
and recoup well over half of the underlift we have experienced
in 1H13.

• The first six months' capital spending was $4.2 billion, with
$2.2 billion spent in the second quarter.

• We expect the second half of the year spending rate to be
higher. Our annual spending level is expected to be generally
in line with the $9.6 billion program.

• The positive effect of our capital efficiency efforts is starting
to become noticeable in our spending patterns.

• As a result, we believe there is a reasonable possibility our
total spending may be somewhat lower than the program
amount just mentioned while still drilling the number of wells
we set out as a goal at the beginning of the year.

Second Quarter 2013 Earnings -

2013 Capital Outlook

• With regard to our strategic business review, we presented various
options to our Board of Directors.

• Our review of these options is not yet complete, so the Board will
continue to evaluate the alternatives. We expect to have additional
information regarding our plans towards the end of the year.

• Plains All American (PAA) filed a registration statement with the SEC
for a public offering of part of its interests in Plain’s general partner
(GP). We own 35 percent of the GP interests, and we expect to
monetize a portion as part of the proposed offering.

Second Quarter 2013 Earnings

Note: For additional information, see the registration statement, a copy of which is available on the SEC's
website. No sales of securities will take place until the registration statement becomes effective.

Second Quarter 2013 Earnings -
2H13 Guidance Summary

Oil & Gas Segment

• Domestic Production

– Oil - 6,000 to 8,000 bopd growth

– NGLs - modest decline

– Natural gas - modest decline

• International

– Production volumes - similar to 2Q13

– Sales volumes - increase in 2H13 to recoup over half the underlift vs. 1H13

• Exploration expense: $90 mm in 3Q13

Chemical Segment

• ~$170 mm operating income in 3Q13

Corporate

• Capital spending: $9.6 billion for FY 2013

• Income tax rate: ~41%