Occidental Petroleum Corporation February 13, 2019...> Aventine maintenance and logistics hub...
Transcript of Occidental Petroleum Corporation February 13, 2019...> Aventine maintenance and logistics hub...
February 13, 2019
Occidental Petroleum Corporation
Fourth Quarter 2018Earnings Conference Call
2
Cautionary Statements
Forward-Looking StatementsThis presentation contains forward-looking statements based on management’s current expectations relating to Occidental’s operations, liquidity, cash
flows, results of operations and business prospects. Words such as “estimate,” “project,” “predict,” “will,” “would,” “should,” “could,” “may,” “might,”
“anticipate,” “plan,” “intend,” “believe,” “expect,” “aim,” “goal,” “target,” “objective,” “likely” or similar expressions that convey the prospective nature of
events or outcomes generally indicate forward-looking statements. You should not place undue reliance on these forward-looking statements, which speak
only as of the date of this presentation. Actual results may differ from anticipated results, sometimes materially, and reported results should not be
considered an indication of future performance. Factors that could cause actual results to differ include, but are not limited to: global commodity pricing
fluctuations; changes in supply and demand for Occidental’s products; higher-than-expected costs; the regulatory approval environment; not successfully
completing, or any material delay of, field developments, expansion projects, capital expenditures, efficiency projects, acquisitions or dispositions;
technological developments; uncertainties about the estimated quantities of oil and natural gas reserves; lower-than-expected production from operations,
development projects or acquisitions; exploration risks; general economic slowdowns domestically or internationally; political conditions and events; liability
under environmental regulations including remedial actions; litigation; disruption or interruption of production or manufacturing or facility damage due to
accidents, chemical releases, labor unrest, weather, natural disasters, cyber-attacks or insurgent activity; failures in risk management; and the factors set
forth in Part I, Item 1A “Risk Factors” of the 2017 Form 10-K. Unless legally required, Occidental does not undertake any obligation to update any forward-
looking statements, as a result of new information, future events or otherwise.
Use of non-GAAP Financial InformationThis presentation includes non-GAAP financial measures. You can find the reconciliations to comparable GAAP financial measures on the “Investors”
section of our website.
Cautionary Note to U.S. InvestorsThe Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible
reserves. Any reserve estimates provided in this presentation that are not specifically designated as being estimates of proved reserves may include
"potential" reserves and/or other estimated reserves not necessarily calculated in accordance with, or contemplated by, the SEC’s latest reserve reporting
guidelines. U.S. investors are urged to consider closely the oil and gas disclosures in our 2017 Form 10-K and other reports and filings with the SEC. Copies
are available from the SEC and through our website, www.oxy.com
3
Occidental Petroleum
• 2018 & Fourth Quarter Highlights
• Financial Summary and Guidance
• Permian Update
• International Update
• Closing Remarks
4
2018 Highlights – Delivering on Our Value Proposition
Focused on Returns Operational ExcellenceCash Flow Generation Integrated Business
Sector leading returns,
achieved 14% ROCE and
27% CROCE
45% of CFFO returned to
shareholders
Returned $3.6 B to
shareholders including
$1.3 B of share
repurchases in 2018
Sector leading dividend,
with consecutive growth
since 2002 – 12% CAGR
Sold domestic pipeline and
export terminal while
maintaining takeaway &
export capacity
164% all-in reserve
replacement ratio, with
149% from organic
sources
New blocks in Abu Dhabi,
Oman and Colombia
OxyChem generated over
20 consecutive years of
free cash flow
Expansion of global market
access through Midstream
Low Carbon Ventures
established to leverage
carbon capture business
CFFO before working cap.
exceeded capex and
dividends by ~$800 MM
$3.8 B of Core income,
Core EPS of $5.01
International business
generated $1.4 B of free
cash flow
OxyChem and Midstream
generated highest
earnings in over 20 years
$3.0 B cash balance
Permian achieved lowest
operating costs per barrel
in this decade
Drilled <5% of Hz wells in
the Permian, but have 40%
of the top 50 wells
Improved average six-
month cumulative
production by 25% for
Permian Resources
Increased Al Hosn capacity
by 11%
Note: ROCE and CROCE are non-GAAP; see the reconciliations to comparable GAAP financial measures on our website
5
Value Based Cash Flow Growth
1Cash flow from operations before working capital2Production from ongoing operations
Note: See the reconciliations to comparable GAAP financial measures on our website
ROCE
Generation
Cash Flow
Growth
Return of
Capital
Sustainable
Returns
Value Based Returns2002 - 2016 2017 2018
ROCE: 11% Avg 5% 14%
CROCE: 21% Avg 18% 27%
2017 to 2018 Growth
CFFO1: 74%
EPS: 463%
Production2: 11%
Credit Ratings
A/A3/A Stable
Cash Distributions $2.4 B Dividends in 2018
$1.3 B Shares Repurchased
in 2018
Consecutive Dividend Growth
Since 2002 - 12% CAGR
$33 B of Total Capital
Returned Since 2002
48% of the $33 B Returned in
the Last 5 Years
6
2019 Capital Flexibility with Short-cycle Investments
<2 Years 2-3 Years >3 Years
D&C
61%
Facilities
24%
Base
Maintenance
12%
Exploration
3%
25%20%
55%
2019 Capital Program by Type
1Sustaining capital based on a 2019E production base decline rate of 20%2Payback based on $50 WTI
Sustaining1
55%
Growth
42%
Exploration
3%
Total
CompanyOil & Gas
$2.6
$0.5
$0.8
$0.2 $0.1 $0.3
2019 Captial Program
Chemicals
Midstream
Exploration & Other
International
Permian EOR
Permian Resources
$4.5 B Capital Program
9 - 11% Production Growth
2019 Capital Program
Payback for 2019 Development Capital2
7
Permian
Harvest Existing High-Return Unconventional Inventory and Lower Full-Cycle Costs
• Unconventional EOR
Commercial Success
• Scalable Unconventional
EOR Implementation
• New Anthropogenic
CCUS Project Online
• Expand Unconventional
& Anthropogenic EOR
Footprint
Replenish High-Return Unconventional Inventory and Delineate Additional Acreage
Oman
• Seismic New Blocks
• Exploration Wells
• Appraisal Drilling
• Block 62 Hub Expansion
• Development Plan
Execution
• New Blocks First
Production
• Production Ramp-Up
Abu Dhabi
• Seismic ON-3
• Exploration Well
• Al Hosn Debottlenecking
Pre-FEED
• Exploration Wells
• Al Hosn Debottlenecking
FEED
• ON-3 Development
• Exploration and
Appraisal Wells
• Al Hosn Debottlenecking
Execution
• ON-3 Production
• 1st Production from
Debottlenecking
Colombia
• Seismic New Blocks
• Initiate TECA Steam
Flood Development
• Seismic Processing
• Exploration Wells
• TECA Execution
• New Blocks
Development
• TECA Ramp-Up
• New Blocks
Production Ramp-Up
Road Map to 2022 Cash Flow Growth
1Cash flow from operations before working capital, Production Growth CAGR from 2018 to 2022: Permian Resources 24%, International 6% excluding Qatar
Note: 2020 - 2022 assumes $60 WTI/$70 Brent, $3.00 MID-MEH differential, Capital of $5.0 - $5.3 B
$9.0 B
2019 2020 2021 2022
20
22
Ca
sh
Flo
w F
rom
Op
era
tion
s1
Permian$6.0 B
OxyChem
Midstream$1.7 B
International
$2.1 B
Corporate,
Interest & Other
($0.8 B)
8
$0.00
$0.50
$1.00
$1.50
$2.00
$2.50
$3.00
$3.50
-
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
4,500
5,000
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018
Dividends $ MM Share Repurchases $ MM Dividends per Share $
Oxy Consistently Returns Capital to Shareholders
Note: 2013 dividend total adjusted to reflect that 1Q13 dividend was paid in 4Q12
$ M
M R
etu
rne
d t
o S
ha
reh
old
ers
Dividend Sustainable at $40 WTI
Consecutive Dividend Growth Since 2002 - 12% CAGR
$33 B of Total Capital Returned Since 2002
Over 70% of Market Capitalization Returned to Shareholders
Strong Balance Sheet - A/A3/A Credit Ratings
13% Annualized TSR since 2002
Div
ide
nd
s p
er S
ha
re
9
Occidental Petroleum
• 2018 & Fourth Quarter Highlights
• Financial Summary and Guidance
• Permian Update
• International Update
• Closing Remarks
10
4Q18 Results
Note: See the reconciliations to comparable GAAP financial measures on our website
Reported diluted EPS $0.93
Core diluted EPS $1.22
4Q18 CFFO before working capital & other $1.9 B
4Q18 capital expenditures $1.3 B
Dividend payments $0.6 B
Share repurchases $0.3 B
Cash balance as of 12/31/18 $3.0 B
Total reported production (Boed) 700,000
Total Permian Resources production (Boed) 250,000
4Q18 Actual versus Guidance
Midpoint ReconciliationBoed
• Permian Resources execution
and well productivity+5,000
• PSC impact of higher prices
• Weather and accelerated
maintenance
(5,000)
4Q18 Earnings Notes After-tax
Income
• Impairment charge ($220 MM)
• Lower effective tax rate $224 MM
11
2019 Guidance
Oil & Gas Segment
• FY 2019E Production
> Total production of 715 - 730 Mboed
> Permian Resources production of 278 - 288 Mboed
> International production of 278 - 283 Mboed
• 1Q19E Production
> Total production of 706 - 713 Mboed
> Permian Resources production of 256 - 261 Mboed
> International production of 293 - 295 Mboed
• International production is estimated at Brent 2019
calendar strip as of 2/1/2019
Production Costs – FY 2019E
• Domestic Oil & Gas: ~$11.00 / boe
Exploration Expense
• ~$40 MM in 1Q19E
• ~$130 MM in FY 2019E
DD&A – FY 2019E
• Oil & Gas: ~$13.50 / boe
• OxyChem and Midstream: $700 MM
Midstream
• $150 - $200 MM pre-tax income in 1Q19E
> Midland - MEH spread of $8.50 - $9.50 / Bbl
OxyChem
• ~$235 MM pre-tax income in 1Q19E
• $925 - $975 MM pre-tax income in FY 2019E
Corporate
• FY 2019E Domestic tax rate: 21%
• FY 2019E International tax rate: 45%
• Interest expense of $95 MM in 1Q19E
12
Occidental Petroleum
• 2018 & Fourth Quarter Highlights
• Financial Summary and Guidance
• Permian Update
• International Update
• Closing Remarks
13
2018 Permian Highlights
1See the reconciliations to comparable GAAP financial measures on our website
216%
+77
9%
Permian Reserves
Replacement Ratio1
Permian Production
Growth (Mboed)
Permian Opex/boe
Reduction
Permian Resources
Permian EOR
> Progressing anthropogenic CO2 sourcing strategy with
800,000 metric tons of anthropogenic CO2 sequestered
> 1 new CO2 flood and 10 expansions
> $8 reduction in Seminole San Andres Unit opex/boe
> 100% reserves replacement ratio1
> 52% annual average production growth
> 25% improvement in 6 month cumulative well productivity
> 10% reduction in opex/boe
> 300% reserves replacement ratio1
> Operator with the most top 50 wells in the Permian
> Aventine maintenance and logistics hub complete
> 19% improvement in feet drilled per day
> Completed 37,000 net acre trades
14
0%
25%
50%
75%
100%
Capital
Type
Growth
Capex
Rigs Wells
Permian Resources 2019 Disciplined Investment Plan
2019 Capital Program
Drilling
and
Completion
Facilities
OBO
Base Maint.
New
Mexico
TX
Delaware
OBO
Development
Appraisal
$2.6 B
Capex
~$1.2 B
Sustaining
180 - 190
Wells Online
High-margin
Growth
30-35% 2019 annual production
growth expected
Progressing
Technology
Deep Inventory17 years of inventory with less
than $50 WTI breakeven
Flexible
Ability to ramp-down to sustaining
capex of ~$1.2 B in less than 6
months
High ReturnsFocused development in
proven, high-return areas
EOR unconventional, data analytics,
and subsurface characterization
Max Price
RealizationsTakeaway capacity with access to
world markets
13 – 14
Rigs
Sustaining
Capex
Growth
Capex
15
Occidental Petroleum
• 2018 & Fourth Quarter Highlights
• Financial Summary and Guidance
• Permian Update
• International Update
• Closing Remarks
1616
• 1.5 million gross acres
• 35-year concession
with 30-year development rights
• High potential location> Prolific fields nearby
> Adjacent to Oxy’s Al Hosn Field
> Key targets already identified
> Leverage Oxy’s regional technical knowledge and
operational excellence
• Low initial exploration expenditures> Seismic acquisition and interpretation
> First exploration drilling starts late in 2019
Abu Dhabi
Block ON-3
17
Occidental Petroleum
• 2018 & Fourth Quarter Highlights
• Financial Summary and Guidance
• Permian Update
• International Update
• Closing Remarks
18
Growth within Cash Flow
Oxy’s Sustainable Value Proposition
CROCE
Leadership
Returns Focused Growth
Environmental, Social and Governance
Integrated Business Model
Robust, Low-Cost Inventory
Long-Term Production Growth of 5 - 8+% while Targeting a Return
of Over $3.1 B in Cash to Shareholders in 2019
Permian Resources is Driving High-Return Growth with the Best Wells in the
Permian Basin and Benefits from an Advantaged Cost Position
Industry Leading Base Decline Rate in Oil and Gas, Sustainable Cash Generation
from OxyChem, Expanded Global Market Access Through Midstream Business
Decades of Global Inventory: Conventional, Unconventional,
EOR (CO2, Water, Steam, & Gas Injection)Diverse Inventory and Recovery Techniques
Enhance Sustainable Cash Flow
Executive Compensation Aligned with Shareholder Value CreationUniquely Positioned to Advance CCUS
Proactive Social Responsibility Programs WorldwideIndustry Leading Human Capital
19
Appendix Contents
• Financial Information
• Social Responsibility, Environment and Governance
• Oil and Gas Updates
• 2018 Reserves
• OxyChem Update
20
Cash Flow Sensitivities in 1Q19
Oil & Gas
• Annualized cash flow changes ~$130 MM per ~$1.00 / bbl change in oil prices
> ~$100 MM per ~$1.00 / bbl change in WTI prices
> ~$30 MM per ~$1.00 / bbl change in Brent prices
• Annualized cash flow changes ~$35 MM per ~$0.50 / Mmbtu change in natural gas prices
• Annualized production changes 800 – 1,000 Boed per ~$1.00 / bbl change in Brent prices
OxyChem
• Annualized cash flow changes ~$30 MM per ~$10 / ton change in realized caustic soda prices
Midstream
• Annualized cash flow changes ~$45 MM per ~$0.25 / bbl change in Midland to MEH spread
> ~35 day lag due to trade month
21
• ~$1.3 B repurchased in 2018
• Completion expected in 2019
Cash Flow Priorities
Annual Operating Cash
Inflows
Sustaining Capital
at $40 WTI
A Growing
Dividend
5% - 8% Production
Growth
Share Buybacks &
Cash on Balance
Sheet
Estimated Cash Flows ($)1
CFFO$50 WTI
CFFO $60+ WTI
1Estimated cash flows assuming mid-cycle earnings in OxyChem and Midstream and exclude working capital
Annual Operating
Cash Inflows
Cash Flow Breakeven at LowOil Prices
$2 B+ Share Repurchase Program
Free Cash Flow Generation
• $40 WTI – maintain dividend and
production
• $50 WTI – grow dividend and grow long-term production by 5 - 8+%
Share Repurchases
& Cash on Balance
Sheet
Sustaining Capital
At $40 WTI
Dividend 5 - 8+% Long-term
Production Growth
CFFO$40 WTI
• At higher commodity prices,
Oxy is positioned to generate
excess free cash flow (after dividend payment) to increase
cash returns to shareholders
22
2018 Cash Flow and Cash Balance Reconciliation
Beginning Cash
Balance 1/1/18
CFFO Before
Working Capital
Asset Sales Dividends & Share
Repurchases
Capital Expenditures Other Ending Cash
Balance 12/31/18
$3.0
($3.6)
$8.1
$1.7
($5.0)
$2.8
$ B
($1.0)
23
Appendix Contents
• Financial Information
• Social Responsibility, Environment and Governance
• Oil and Gas Updates
• 2018 Reserves
• OxyChem Update
24
Commitment to Safety and the Environment
Safety commitment extends to
contractor workforce
Nearly nine times better than the
U.S. private industry average
Safety first culture embraced from
top to bottom of organization
CO2 EOR leader permanently
sequestering over 800,000 metric
tons of anthropogenic CO2 per year
Advance carbon offsets through CCUS
investment
Collaborative solutions through Oil &
Gas Climate Initiative
Focused on optimizing the use of
low-quality produced water
History of water management
through Permian EOR water floods
Less than 10% of water used in
Permian Resources is fresh water
Safety remains top priority Advantaged in Low
Carbon Scenarios
Water Conservation and
Recycle Leadership
0.322018 Employee and
Contractor IIR1
Safety Remains our
Top Priority
25.82017 GHG Emissions
Intensity2
0.0172017 Total Water
Usage Intensity3(Tonne CO2e/Mboe) (BBL/BOE)
1Global Injury and Illness Incidence Rate – incidents per 100 workers2GHG emissions intensity calculated as direct equity global oil and gas emissions (scope 1) as reported to CDP divided by total net production3Water usage intensity calculated as total equity global oil and gas water withdrawn, independent of salinity, divided by total net production
25
0
40
80
120
160
2017 2018 2019E
Ne
w M
exi
co
Wa
ter
Re
cyc
le
Ca
pa
cit
y (
MB
WP
D)
$3.50
$2.10
$0.75 $0.45
$-
$1
$2
$3
$4
Original Improved 2017 CurrentC
ost
/ b
bl o
f w
ate
rTruck Produced
Water
+ Truck Frac Water
Pipe Produced
Water
+ Truck Frac Water
2017 Recycle
Produced Water
for Frac Water
2018 Recycle
Produced Water
for Frac Water
Investment in New Mexico Water Infrastructure
New Mexico Water Recycle Cost Savings Per Barrel
4X Increase
Water Infrastructure Drives Value & Environmental Benefits
• New water recycling technology
implemented in New Mexico
> Greater than 80% of water used in
2019 will be recycled
> Targeting to use less than 1% fresh
water in 2019
• Expanding recycled water
technology to TX Delaware in
2019
Improve Water
Handling
Implement
Recycling
Improve Water
Recycling Technology
26
1Emissions for the production and the gathering and boosting segments, as reported to EPA under the Greenhouse Gas Mandatory Reporting Rule - Subpart W, which covers the petroleum and natural gas industry2Wells reported to EPA under Subpart W of the Greenhouse Gas Mandatory Reporting which covers onshore wells, excluding divested and out of production
Note: Selected Peers: APA, APC, COP, CVX, CXO, DVN, EOG, FANG, PXD, XOM
Note: Sources: IHS Enerdeq for 2017 Basin Production, EPA Flight tool for 2017 publically reported emissions
Pe
rmia
n G
ree
nh
ou
se
Ga
s In
ten
sit
y1(m
tC
O2e
pe
r M
bo
e)
Pe
rmia
n G
ree
nh
ou
se
Ga
s In
ten
sit
y1(m
tC
O2e
pe
r M
bo
e)
Permian Reported Well Count2
Gro
ss 2
01
7 P
erm
ian
Pro
du
cti
on
(M
bo
ed
)
0
5
10
15
20
25
30
35
40
45
50
0 5,000 10,000 15,000 20,000 25,000
Size of bubble reflects relative gross 2017 Permian production
Low Emission Intensity with Leading Basin Production Low Emission Intensity with More Operated Wells
Permian Emissions
0
100
200
300
400
500
0
10
20
30
40
50
OX
Y
Pe
er
1
Pe
er
2
Pe
er
3
Pe
er
4
Pe
er
5
Pe
er
6
Pe
er
7
Pe
er
8
Pe
er
9
Pe
er
10
OXY
27
Appendix Contents
• Financial Information
• Social Responsibility, Environment and Governance
• Oil and Gas Updates
• 2018 Reserves
• OxyChem Update
28
-50
0
50
100
150
200
250
0 90 180
Permian Resources Hz Unconventional Well Performance
Continuous Improvement in Permian Resources Well Performance
• Subsurface
Characterization
• Data Analytics
• Innovative Well
Designs
• Oxy Drilling
Dynamics
• Focused
Development
2015
2016
2017
2018
147% Improvement since 2015
25% Improvement from 2017 to 2018
Note: Data includes all horizontal Permian unconventional wells online in each year.
Cu
mu
lati
ve M
bo
e
Days
29
3,403
3,188
3,923
2017
1H18
2H18
Peak 30 Day Production (Boed)1
-
50
100
150
200
250
300
350
400
1 31 61 91 121 151 181
Core Development Areas Delivering Impressive Results – Greater Sand Dunes
Subsurface Characterization is Driving Basin
Leading Results
• Integrated workflows with seismic integration
• Customized development to maximize section value> Landing and spacing optimization
> Value-based well designs
> Life of field development plans
• Lost Tank Wolfcamp Appraisal Well: Lost Tank 30-19 Fed Com 31H> 5,207 Boed Peak 24hr
> 4,546 Boed Peak 30 Day
• Continued basin leading Bone Spring results in 4Q:> 19 Wells Online ~7,985 ft
> Avg IP 24 = 4,327 Boed1
> Avg IP 30 = 2,993 Boed1
• 92% of wells online in 2018 have an offset producing well
Days Online
2018
52 Wells ~9,950’
25% Better Than the Average
New Mexico Operator2
~9,900’
1Three stream production results2Peer data sourced from IHS Performance Evaluator and represents an average of Peers with greater than two wells online in 2018 for New Mexico Bone Spring wells with a lateral length greater than 9,500 ft
Greater Sand Dunes Bone Spring - 10K wells
Greater Sand Dunes Bone Spring - 10K wells
Cumulative Production (Mboe)
30 wells
8 wells
22 wells
30
2,572
2,856
2,897
2017
1H18
2H18
0
50
100
150
200
250
0 30 60 90 120 150 180
Scalable Performance Improvements Increasing
Asset Value
• New well design and subsurface characterization improving well
results> Landing optimization based on seismic
> Increased completion effectiveness through higher pump rates and
improved sand placement
• Large contiguous acreage position with large inventory
• Multi-bench development utilizes existing infrastructure
• 33% improvement in drill days from 2017 to 2018
• Improvements generating peer-leading 4Q results in Southern
Delaware> 9 Wells Online ~8,375 ft
> Avg IP 24 = 3,186 Boed1
> Avg IP 30 = 2,418 Boed1
• 90% of wells online YTD have an offset producing well
Core Development Areas Delivering Impressive Results – Barilla Draw
Days Online
2018
7 Wells ~10,000’
45% Better Than the
Average TX Delaware
Operator2
~10,000’
1Three stream production results2Peer data sourced from IHS Performance Evaluator and represents an average of Peers with greater than two wells online in 2018 for Wolfcamp oil wells in Texas Delaware with a lateral length greater than 9,500 ft
2018 New Well Design
14 Wells ~10,100’
Barilla Draw Wolfcamp A & Hoban - 10K wells
Peak 30 Day Production (Boed)1
Barilla Draw Wolfcamp A & Hoban - 10K wells
Cumulative Production (Mboe)
13 wells
3 wells
8 wells
31
1,250
2,250
3,250
4,250
December-17 March-18 May-18 August-18 November-18
2,000
4,000
6,000
8,000
10,000
December-17 March-18 May-18 August-18 November-18
Note: Data sourced from IHS Enerdeq as of 1/22/2018 for the period 12/2017 – 12/2018. Data for three Oxy wells were sourced from internal data as records were not yet available in IHS Enerdeq.
Oxy has 20 of the top 50 Wells in the Permian Basin Leading Wells with Less Proppant
Oxy Wells Competitor Wells Oxy Wells Competitor Wells
IP 2
4 H
ou
rB
OP
D
Pro
pp
an
t#
/ft
Oxy Average
Proppant #/ft
Competitor Average
Proppant #/ft
+29%
Permian Resources Delivers Basin Leading Wells
Oxy has the most top 50 wells of any operator in the Permian
32
Well NameLateral
Length (ft)
Peak 24 Hr
(boed)
Peak 30
Day (boed)
Oil
(%)
Brushy Canyon Federal 23 13H 4,376 899 833 90%
Mesa Verde BS Unit 1H 9,799 2,872 2,709 74%
Mesa Verde BS Unit 3H 9,753 3,002 2,680 72%
1st
BSS Cedar Canyon 16 State 1H 3,475 1,267 968 67%
Corral Fly 35-26 Fed Com 21H 9,880 7,970 5,959 77%
Corral Canyon 36-25 Fed Com 21H 11,194 5,245 4,673 78%
Corral Fly 35-26 Fed Com 22H 9,876 5,016 4,053 78%
Cedar Canyon 23 Fed Co 6H 7,241 4,518 3,963 75%
Sunrise MDP1 8 5 Fed Com 2H 9,857 5,364 3,911 83%
Corral Canyon 36 25 Fed Com 22H 11,191 4,928 3,901 77%
Oxy Total 2018 Average 7,862 3,135 2,423 79%
Cedar Canyon 21-22 FED Com 32H 9,851 5,834 3,916 68%
Cedar Canyon 23 24 Fed 32H 7,235 6,497 3,693 69%
Cedar Canyon 23 24 Fed Com 34H 7,172 4,876 3,338 73%
Cedar Canyon 21 22 Fed Com 34H 9,820 3,751 3,286 75%
Oxy Total 2018 Average 6,429 2,789 1,749 67%
Cedar Canyon 27 28 Fed 44H 9,800 7,439 5,398 76%
Cedar Canyon 27 28 Fed 43H 9,648 6,007 4,351 77%
CORRAL FLY 02-01 STATE 032H 9,876 6,003 4,021 72%
CORRAL FLY 02-01 STATE 033H 9,913 6,709 3,976 73%
LOST TANK 30-19 FED COM 31H 10,004 4,671 4,038 74%
CORRAL FLY 02-01 STATE 031H 9,851 5,728 3,609 70%
Oxy Total 2018 Average 9,840 5,476 3,868 73%
Cedar Canyon 27 10H 4,215 1,645 1,486 73%
Janie Conner 204H 4,500 1,980 1,221 78%
B Banker 226H 4,400 1,874 1,030 76%
Janie Conner 221H 4,522 2,282 1,809 39%
Tiger 14 24S 28E 224H 4,376 1,719 1,417 47%
Target Formation
Recent Well Results
2nd
BSS
3rd
BSS
Wolfcamp XY
Wolfcamp A
Wolfcamp D
Avalon
Wells included in table include non-operated wells. Production data is from internal system for operated wells and from operator data and IHS Enerdeq for non-op wells where available.
Wells in blue font were turned to production in 4Q18. All boe data is based on two-stream well tests.
Average shown for all benches with multiple wells in 2018.
Barilla Draw Type LogGreater Sand Dunes
Proven Economic Delineating
Results in Greater Sand Dunes Area Multi-Bench Development
Brushy Canyon
Avalon
1st Bone Spring
2nd Bone Spring
3rd Bone Spring
Wolfcamp X-Y
Wolfcamp A
Wolfcamp D
6,0
00
ft
33
Well NameLateral
Length (ft)
Peak 24 Hr
(boed)
Peak 30
Day (boed)
Oil
(%)
Avalon Evaluating
1st
BS Evaluating
Collie A East N63H 9,725 1,370 1,155 81%
Aardvark State 6 2H 4,947 1,254 821 87%
A Herring 94-93-7N 74H 9,751 1,647 1,360 78%
Morrison, HB 73H 4,927 854 864 75%
SARAH LINK 3-2-1W STATE 81H 9,930 3,503 2,793 79%
TOYAH 4-9-6N 83H 10,302 3,280 2,490 78%
TOYAH 4-9-6N 84H 10,402 2,684 2,133 79%
TOYAH WEST 4-9 82NH 10,193 2,407 2,062 78%
Oxy Total 2018 Average 7,555 2,282 1,727 73%
Peck 258-257-1N State 11H 9,767 5,652 4,299 76%
Chapman State 32-41-4S 15H 10,147 4,485 3,544 81%
Lyda 33-40-3S State 13H 10,105 5,042 3,373 81%
Lyda 33-40-1S State 16H 10,164 3,724 3,202 84%
SARAH LINK 3-2-2W STATE 12H 9,952 3,662 2,941 79%
Lyda 33-40-2S State 12H 10,158 3,839 2,813 81%
Janey State 24-25-2N 15H 10,147 2,948 2,736 79%
Janey State 24-25-1N 16H 10,147 2,996 2,594 83%
Oxy Total 2018 Average 8,950 2,505 1,892 80%
Agate 179-142-3S 25H 7,439 2,088 1,731 73%
Daytona Unit 1B 2H 6,947 1,897 1,544 79%
Agate 179 142 2S 21H 7,197 1,941 1,469 80%
Oxy Total 2018 Average 8,119 1,666 1,089 77%
A Herring 94-93-6N 33H 10,199 2,521 1,758 81%
Lemur 24 1H 4,251 1,125 937 81%
Target Formation
Recent Well Results
2nd
BS
3rd
BS
Hoban
Wolfcamp B
Wolfcamp C
Wolfcamp A
Wells included in table include non-operated wells. Production data is from internal system for operated wells and from operator data and IHS Enerdeq for non-op wells where available.
Wells in blue font were turned to production in 4Q18. All BOE Data is based on two-stream well tests.
Average shown for all benches with at least three wells in 2018. Wolfcamp DF wells now combined with Wolfcamp A wells.
Barilla Draw Type LogGreater Barilla Draw
Proven Economic Delineating
Results in Greater Barilla Draw Area Multi-Bench Development
Avalon
1st Bone Spring
2nd Bone Spring
3rd Bone Spring
Wolfcamp A/DF
Wolfcamp C
4,5
00
ft
Wolfcamp B
Hoban
34
Permian Scale and Operating Capability Reduces Costs• Full life-cycle wellbore
planning
• Data analytics integration
• Operational excellence
> Lower costs
> Water recycling
> Maximize recovery
• Downhole maintenance
and cost reduction
> Root cause failure analysis
> Organizational structure
and focus
> Chemical program
> Variable speed drives
2019 Not even at
4Q18 goal
Total Opex incl. OBO
$12.93
$11.17
$8.43$8.00
$7.23
$6.51
$-
$4.00
$8.00
$12.00
2014 2015 2016 2017 2018 4Q18
Permian Resources Total Opex/boe
Surface Downhole Supports Energy Other
Oxy Operated Opex/boe
December 2018 = $6.04
35
0
2,000
4,000
6,000
8,000
10,000
12,000
Breakeven
<$50
Breakeven
<$60
Breakeven
<$70
Additional
Inventory
Permian Resources High Value Inventory
3,059
3,992
5,048
10,453
Midland
Basin
Texas
Delaware
Basin
New Mexico
Delaware
Basin
Note: Breakeven defined as positive NPV 101As of 12/31/2018
Un
de
velo
pe
d D
rillin
g L
oca
tio
ns
1
Permian Resources
Inventory 4Q18
• Increased average length of
total inventory from
~7,750 ft to ~7,850 ft
• Continue to lower
breakevens within the <$50
breakeven category
> 17 years of inventory
with less than $50
WTI breakeven at a 10
rig per year pace
36
Permian Resources
• Significant growth potential in
all development areas
• ~640,000 net
unconventional acres within
the Delaware and Midland
Basin boundaries
• ~340,000 net acres
associated with 10,453
wells in unconventional
development inventory
• Resources – Unconventional Areas 1.35
• Enhanced Oil Recovery Areas 1.35
Oxy Permian Total ~2.7 MM
Net
Acres1Business Area Acreage
Permian Resources Acreage Permian EOR Acreage
NM Delaware Basin
TX Delaware Basin
Midland Basin
Central Basin
Platform
New Mexico NW Shelf
1Includes surface and minerals.
Note: Acreage as of 12/31/2018
37
Growth Opportunities
Colombia
Acquired 6 New Prospective Blocks:
• LLA-39 & LLA-52 in Llanos Basin
• Put-9, Mecaya, Terecay & Tacacho in Putumayo
Basin
> Increases Colombia acreage from 0.3 to ~2
million gross acres
> More than 700 Mmboe of resources
> Contiguous to existing infrastructure
> Analog to successful areas where Oxy has
Geology & Geoscience knowledge and
operational experience
> Plan to start exploration activities in 2019
Barranquilla
Medellin
Bogota D.C.
Mocoa
Venezuela
TACACHO
TERECAYPUT-9
MECAYA
City
Occidental
Occidental New
Blocks
Blk 15 – Former
Oxy Operations
Ecuador
protected Areas
38
Appendix Contents
• Financial Information
• Social Responsibility, Environment and Governance
• Oil and Gas Updates
• 2018 Reserves
• OxyChem Update
39
Total Company
Reserve
Replacement
2018
164%
All-In
149% Organic
YE 2017 Reserves Production Additions Acquisitions &
Sales
YE 2018 Reserves
2,598 (240)
357 2,75237
73% Proved
Developed
75% Liquids
Note: All reserves are in Mmboe
2018 Reserve Additions Through Program Execution
96% or 379 MMBOE Reserve Additions prior to price revision
Organic
Reserve
Replacements
40
Successful Drilling and A&D Programs
Positive total-company performance
revisions
~300% Permian Resources reserve
replacement in 2018
Improved productivity and lower well
costs in Permian Resources
Purchased ~37 Mmboe more barrels
than sold in Permian transactions in
2018
$17.14
$12.80
5 Year Average 2018
F&
D C
osts
(O
rga
nic
)1
1See the reconciliations to comparable GAAP financial measures on our website
$17.04
$12.29
5 Year Average 2018
F&
D C
osts
(A
ll S
ou
rce
s)1
Program Execution Highlights
41
Appendix Contents
• Financial Information
• Social Responsibility, Environment and Governance
• Oil and Gas Updates
• 2018 Reserves
• OxyChem Update
42
OxyChem: Market Leading Position
1 OxyChem pre-tax earnings excluding special items
0
500
1000
1500
2010 2011 2012 2013 2014 2015 2016 2017 2018
$ M
M
OxyChem Pre-Tax Earnings (EBIT)1
4C
Pe
Pla
nt
Market Overview
• Caustic soda supply-demand balance is favorable
• No major global capacity expansions
• Core caustic demand driven by Aluminum and Pulp and Paper
• PVC demand continues to improve as global population expands
• Major global exporter of all core products
• Top tier global producer in every product produced
> Largest merchant caustic soda seller in the world
> Largest VCM exporter in the world
> 2nd largest chlor-alkali producer in the world
> Largest caustic potash producer in the world
• Recent growth projects delivered on time and on budget, increasing earnings base
• Only 4 time winner of the American Chemistry Councils Sustained Excellence Award
• Positive cash flow generation throughout cycle
• Integrated assets capture benefits of favorable market conditions
• Global export portfolio leverages low domestic natural gas prices
Earnings HighlightsOxyChem at a Glance