PHILLIPS 66 BARCLAYS CONFERENCE
Greg Garland, Chairman and CEO
September 12, 2013
2
This presentation contains certain forward-looking statements within the meaning of Section 27A of the Securities Act of
1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, which are intended to be
covered by the safe harbors created thereby. Words and phrases such as “is anticipated,” “is estimated,” “is expected,” “is
planned,” “is scheduled,” “is targeted,” “believes,” “intends,” “objectives,” “projects,” “strategies” and similar expressions
are used to identify such forward-looking statements. However, the absence of these words does not mean that a
statement is not forward-looking. Forward-looking statements relating to Phillips 66’s operations (including joint venture
operations) are based on management’s expectations, estimates and projections about the company, its interests and the
energy industry in general on the date this presentation was prepared. These statements are not guarantees of future
performance and involve certain risks, uncertainties and assumptions that are difficult to predict. Therefore, actual
outcomes and results may differ materially from what is expressed or forecast in such forward-looking statements.
Factors that could cause actual results or events to differ materially from those described in the forward-looking
statements include fluctuations in crude oil, NGL, and natural gas prices, and refining and petrochemical margins;
unexpected changes in costs for constructing, modifying or operating our facilities; unexpected difficulties in
manufacturing, refining or transporting our products; lack of, or disruptions in, adequate and reliable transportation for
our crude oil, natural gas, NGL, and refined products; potential liability from litigation or for remedial actions, including
removal and reclamation obligations under environmental regulations; limited access to capital or significantly higher cost
of capital related to illiquidity or uncertainty in the domestic or international financial markets; and other economic,
business, competitive and/or regulatory factors affecting Phillips 66’s businesses generally as set forth in our filings with
the Securities and Exchange Commission. Phillips 66 is under no obligation (and expressly disclaims any such obligation)
to update or alter its forward-looking statements, whether as a result of new information, future events or otherwise.
CAUTIONARY STATEMENT
3
Operating excellence
Growth
Returns
Distributions
High-performing organization
STRATEGY
0
50
100
150
200
250
2002 2004 2006 2008 2010 20120
0.5
1
1.5
2
2.5
Total Recordable Rates
OPERATING EXCELLENCE
4
(Incidents per 200,000 Hours Worked)
20
09
20
10
20
11
20
12
20
13
1H
U.S. Refining Emissions (Lb/MBbl)
(SOx, NOx, and Particulate Matter)
Industry Average
Phillips 66 CPChem DCP
See appendix for footnotes.
Midstream: Growth
Build on integrated Transportation system
Utilize Phillips 66 Partners LP as a growth vehicle
Expand DCP
Grow NGL Operations
Chemicals: Growth
Grow CPChem organically
Advance olefins and polyolefins projects
Capitalize on domestic feedstock advantage
Marketing & Specialties: Selective growth
Expand European Retail Marketing
Grow Lubricants
Ensure refinery pull-through
5
Refining: Enhance returns
Process more advantaged crudes
Expand export capability
Increase yields
Decrease costs
Optimize portfolio
SEGMENT STRATEGY
Gulf Coast Fractionator, Mont Belvieu, Texas.
Refining
Marketing
& Specialties
Midstream
Chemicals
Refining
Marketing
& Specialties
Midstream
Chemicals
GROWING HIGHER VALUED BUSINESSES
6
Long-Term Adjusted Earnings 2009 – 2013 1H
See appendix for footnotes.
2013 1H ROCE shown
See appendix for footnotes.
11%
8%
7%
6%
PSX
OKE
EPD
KMP
ROCE
HIGH-PERFORMING BUSINESSES
7
25%
24%
20%
18%
10%
PSX
LYB
WLK
XOM Chem
DOW
ROCE
Chemicals Midstream
21%
18%
11%
9%
6%
PSX
MPC
CVX
VLO
TSO
ROCE
Refining and M&S
0
8
16
24
32
2000 2005 2010 2015 2020
U.S. Growth (MMBD)
8
MIDSTREAM
MACRO ENVIRONMENT
Mont Belvieu NGL Price (% WTI)
Natural Gas
Crude Oil
NGL
2 % CAGR
6 % CAGR
6 % CAGR
See appendix for footnotes.
0.35
0.45
0.55
0.65
0.75
0.85
2000 2005 2010 2015 2020
Consulant Range History
9
2013 Ethylene Production Cost Curve ($/ton)
U.S.
Average
U.S.
Ethane
ME Ethane
NE Asia SE Asia
0
500
1,000
1,500
0 40 80 120 160
Cumulative Ethylene Capacity (MM tons)
0
1,000
2,000
3,000
2012 2017 2022
Supply Range
Ethane Exports
Petchem Demand
U.S. Ethane Supply/Demand Balance (MBD)
CHEMICALS
MACRO ENVIRONMENT
See appendix for footnotes.
Western
Europe
-25
-20
-15
-10
-5
0
5
1Q09 1Q10 1Q11 1Q12 1Q13
-25
-20
-15
-10
-5
0
5
1Q09 1Q10 1Q11 1Q12 1Q13
10
-25
-20
-15
-10
-5
0
5
1Q09 1Q10 1Q11 1Q12 1Q13
LLS - Brent (Nominal $/bbl)
WTI - LLS (Nominal $/bbl)
2009 – 2013 avg:
$-10.43/bbl
Maya - LLS (Nominal $/bbl)
2009 – 2013 avg:
$-11.26/bbl
REFINING
MACRO ENVIRONMENT
2009 – 2013 avg:
$1.76/bbl
-$10
-$8
-$6
-$4
-$2
$0
$2
$4
0.00.51.01.52.02.53.03.54.04.55.05.56.06.57.07.58.0
20
15
20
20
Light Sour
Heavy
Medium
N.A. sweet crude production
displaces sweet imports
Additional sweet crude
production displaces light sour
imports
Gulf Coast light sweet crude will
price to compete with imports
REFINING
MACRO ENVIRONMENT
Import Volume, MMBD 11
See appendix for footnotes.
Light Sweet
North America Crude Import Supply Curve (Vs. Dated Brent $/bbl)
12
Build on integrated Transportation system
Utilize Phillips 66 Partners LP as a growth vehicle
Expand DCP
Grow NGL Operations
MIDSTREAM
GROWTH
MLP. Pecan Grove Crude Terminal, Carlyss, LA.
Crude rail cars
Jones Act ships
Unit train crude unloading facility projects
Clean products export facility projects
Terminal butane blending
Re-commission idle pipelines
New refinery storage
TRANSPORTATION
13 Jones Act tanker delivering Eagle Ford crude.
PHILLIPS 66 PARTNERS LP
14
Strategic relationship with PSX
Stable and predictable cash flows
Significant growth potential
Low cost capital source
Financial flexibility
Figures shown are 100% DCP.
15
2015+
DCP MIDSTREAM
Goliad Gas Plant
200 MMCFD
Granite Wash Gathering System
Expansion
140 MMCFD
National Helium Gas Plant
600 MMCFD
Rawhide Gas Plant
75 MMCFD
LaSalle Gas Plant
100 -- 160 MMCFD
Sand Hills
720 miles, 200 -- 350 MBD
Southern Hills
800 miles, 175 MBD
Front Range
435 miles, 150 -- 230 MBD
Texas Express
580 miles, 280 -- 400 MBD
Gathering and Processing NGL Pipelines
G&P Plant
Under construction/development
Expansion/Restart
DCP Legacy
New/Growth
Sand Hills and Southern Hills startup
Butane and butylene storage hub
Sweeny fractionator and pipelines
Freeport export terminal and de-ethanizer
Clemens salt dome storage
16
NGL OPERATIONS
Sand Hills Pipeline. Metering station. Mont Belvieu, Texas.
0.0
0.5
1.0
1.5
2.0
2010 2011 2012 2013E
MIDSTREAM
GROWTH
17
Capital Program ($B)
NGL Operations
DCP Midstream
Transportation
See appendix for footnotes.
DC
P
NG
L O
ps a
nd
Tra
nsp
ort
ati
on
G&P in Execution
2013 2015 2017+ 2014 2016
Sand Hills and Southern Hills pipelines
Rail Offloading Facilities
Rail Cars
Butane and Butylene
Storage Hub
Sweeny fractionator, storage,
and pipelines
G&P Expansions
Freeport export terminal and de-ethanizer
New pipelines
2012
CHEMICALS
GROWTH
18
Grow CPChem organically
Advance olefins and polyolefins projects
Capitalize on domestic feedstock advantage
CPChem. Mesaieed, Qatar
-
5
10
15
20
25
CPC CPC '17 DOW XOM LYB WLK
Other
M.E. region
N.A. light feedstock
19
Portfolio concentrated in
advantaged feedstock regions
U.S. 100% light feedstock based
Leading Middle East position
First mover on U.S. expansions
See appendix for footnotes.
Other category is predominantly heavy feedstock capacity.
N.A. light feedstock is predominantly ethane, propane, and butane.
CHEMICALS
FEEDSTOCK ADVANTAGE
Worldwide Ethylene Capacity (Billion Lbs)
Estimated capex and EBITDA figures are 100% CPChem.
Estimated EBITDA based on 2012 IHS industry margins. 20
CHEMICALS
ADVANCING OLEFINS AND POLYOLEFINS PROJECTS
1-Hexene Unit
Sweeny Ethylene Furnace
NAO Expansion
US Gulf Coast
Petrochemicals Project
Capacity increase
30% from 2012 – 2017
Estimated project spending
$6.5 -- 7.0 B
Additional EBITDA
$1.3 -- 1.6 B per year 2017+
CPChem. Mesaieed, Qatar
21
0.0
0.2
0.4
0.6
2010 2011 2012 2013E
CHEMICALS
EXECUTING GROWTH
Capital Program ($B)
2013 2015 2017+ 2014 2016
Sweeny Frac
Expansion
22 MBD
1-Hexene Unit
250 kMTA
Sweeny Ethylene
Furnace
90 kMTA
USGC Petrochemicals
1,500 kMTA (ethylene), 1,000 kMTA (polyethylene)
NAO Expansion
~130 kMTA
See appendix for footnotes.
2012
22
Process more advantaged crudes
Expand export capability
Increase yields
Decrease costs
Optimize portfolio
REFINING
ENHANCE RETURNS
San Francisco Refinery, Rodeo Facility. San Francisco, California.
REFINING
DIVERSIFIED PORTFOLIO
23
MI
Germany
HU WG
Ireland
United Kingdom
ME
Malaysia
Western / Pacific 440 MBD Central Region 475 MBD Gulf Coast 733 MBD Atlantic Basin / Europe 588 MBD
LA
SF
FD
BI
BG PC
BW
AL SW
WR
LC
Refinery system runs ~50% Sweet - 50% Sour crudes; ~65% Light/Medium - 35% Heavy crudes See appendix for footnotes.
REFINING
ADVANTAGED CRUDE
24
U.S. Refining (MBD)
LLS/ANS
Brent
Heavy
Canadian
WTI/WTS
See appendix for footnotes.
Current 3+ Years
Gasoline Gasoline
Distillate
Distillate
East East East
Gulf Gulf
Gulf West West
West
REFINING
ENHANCE RETURNS
25
Increase product placement optionality
Capture global demand growth
Maintain high utilization rates
2012 2Q13 3+ Years
Actual Actual Capacity Capacity Capacity
Domestic Exports (MBD)
100
285
180
320
500
See appendix for footnotes.
0%
10%
20%
30%
2010 2011 2012 2013 1H
ROCE (%)
REFINING
ENHANCE RETURNS
26
0.0
1.0
2.0
2010 2011 2012 2013E
Refining WRB
Capital Program ($B)
27
Expand European Retail Marketing
Grow Lubricants
Ensure refinery pull-through
MARKETING AND SPECIALTIES
SELECTIVE GROWTH
Berlin, Germany
28
1.7
3.5
6.5
9.1
4.1 2%
7%
14%
22%
17%
2009 2010 2011 2012 2013 1H
Midstream
Chemicals
Marketing & Specialties
Refining
Corporate
ROCE
Adjusted EBITDA and ROCE ($B)
FINANCIAL SUMMARY
Disciplined capital allocation
Enhanced financial flexibility
Growing shareholder distributions
19.0 20.6 20.8 21.4 21.7
8.0 8.0 7.0 7.0 6.5
30% 28%
25% 25% 23%
2Q 2012 3Q 2012 4Q 2012 1Q 2013 2Q 2013
Equity $B Debt $B Debt to Capital
CAPITAL STRUCTURE
29
20% - 30%
2013 TOTAL CAPITAL PROGRAM
30
WRB
DCP
DCP
CPChem
CPChem
PSX
0
1
2
3
4
PSX Maintenance JV Maintenance Growth Total
$B
See appendix for footnotes.
SHAREHOLDER DISTRIBUTIONS
31
0.0
1.0
2.0
3Q 12 4Q 12 1Q 13 2Q 13 Total
Dividends
Share
Repurchases
Regular dividends
Secure
Growing
Competitive
Share repurchase
Immediate EPS growth
Below intrinsic value
Accretive to ROCE
Distributions ($B)
$2 B capital returned to shareholders
A PROMISING FUTURE
32
Operating excellence
Growth
Returns
Distributions
High-performing organization
INSTITUTIONAL INVESTORS CONTACT Rosy Zuklic
Manager, Investor Relations
[email protected] 832-765-2297
Humber Refinery. North Lincolnshire, United Kingdom.
FOOTNOTES
34
Slide 4
Injury statistics do not include major projects.
Industry Averages are from: Phillips 66 –American Fuels and Petrochemical Manufacturers (AFPM) refining data, CPChem – American Chemistry Council (ACC), DCP – Gas Processors Association (GPA).
U.S. Refining emissions exclude Trainer. Values are calculated as pounds of SOx, NOx, and particulate matter per thousand barrels of clean product produced. WRB is included at 50%.
Slide 6
Corporate excluded from percentages.
Slide 7
To facilitate peer comparison, PSX’s Refining and Marketing & Specialties segments were combined for the Downstream ROCE calculation
Downstream ROCE for MPC, VLO and TSO are total company.
Downstream ROCE for CVX estimated based on excluding Chemicals.
XOM Chem refers to Exxon Mobil’s Chemicals segment.
Slide 8
Historical data from U.S. Energy Information Administration (EIA) dry gas, crude oil, and natural gas liquids field production.
Forecast from internal Phillips 66 analysis. CAGR based on 2012 to 2020 growth.
Slide 9
US Ethane Supply/Demand Imbalance -- Source for supply/demand: Internal Phillips 66 Analysis. Source for U.S. Expansions: Hodson Report October 2012 and Phillips 66 internal data
2013 Ethylene Production Cost Curve – Source: IHS
FOOTNOTES
35
Slide 11
Source: P66 internal analysis.
Includes total US & EC Canada.
Years refer to approximate year-end volumes displaced (based on Q1 ‘13 Imports, Production expectations and CDU utilization).
Slide 17
DCP Midstream capital program includes equity share of DCP Midstream capital.
2012 NGL Ops includes acquisition costs for one-third interest of Sand Hills and Southern Hills Pipelines totaling approximately $0.5 B. This amount was also included in DCP Midstream's capital spending, primarily in 2012.
Slide 19
Source: ICIS , 10-K filings, and external press releases
Slide 21
Project capacities are gross capacity.
Chemicals capital program denotes equity share of CPChem capital.
Slide 23 Sour is defined as sulfur > 0.54wt% Heavy is defined as API < 24
Slide 24
U.S. advantaged crude percentages are on an equity basis. Light and medium Canadian crude are in the WTI/WTS category.
Slide 26
Capital program denotes equity share of WRB capital as well as non-cash capital leases.
Slide 30
PSX Maintenance includes corporate.
Capital program includes our net share of certain equity affiliate investments Includes non-cash capital leases.
36
FOOTNOTES
2013 SENSITIVITIES
37
Sensitivities shown above are independent and are only valid within a limited price range
*Assumes LLS is less expensive than Brent
Net Income $MM
Midstream
1¢/Gal Increase in NGL price 4
10¢/MMBtu Increase in Natural Gas price 2
$1/BBL Increase in WTI price 2
Chemicals
1¢/Lb Increase in Olefins Chain Margin (Ethylene, Polyethylene, NAO) 35
Worldwide Refining (assuming 95% refining utilization)
$1/BBL Increase in Refining Margin 440
$1/BBL Increase in Crude Price Impact on Secondary Products (20)
$1/BBL Widening LLS / Maya Differential (LLS less Maya) 55
$1/BBL Widening WTI / WCS Differential (WTI less WCS) 40
$1/BBL Widening WTI / WTS Differential (WTI less WTS) 20
$1/BBL Widening LLS / Brent Differential (LLS less Brent)* (20)
$0.10/MMBtu Increase in Natural Gas price (10)
Corporate and Other
1% Increase in Interest Rate (3)
Impacts due to Actual Crude Feedstock Differing from Feedstock Assumed in Market Indicators:
NON-GAAP RECONCILIATIONS
ADJUSTED EARNINGS SLIDE 6
38
2013 2012 2011 2010 2009
1H Year Year Year Year
Midstream
Earnings (loss) 200$ 53$ 2,149$ 386$ 386$
Adjustments:
Net (gain) loss on asset sales - - (1,618) - (19)
Impairments - 330 4 - 79
Pending claims and settlements - (23) - - -
Gain on share issuance by equity affiliate (27) - - - (88)
Hurricane-related costs - 2 - - -
Adjusted earnings 173$ 362$ 535$ 386$ 358$
Chemicals
Earnings (loss) 463$ 823$ 716$ 486$ 228$
Adjustments:
Impairments - 27 - - -
Premium on early debt retirement - 89 - - -
Repositioning tax impacts - 41 - - -
Adjusted earnings 463$ 980$ 716$ 486$ 228$
Millions of Dollars
NON-GAAP RECONCILIATIONS
ADJUSTED EARNINGS SLIDE 6
39
2013 2012 2011 2010 2009
1H Year Year Year Year
Refining
Earnings (loss) 1,403$ 3,217$ 1,529$ (545)$ (536)$
Adjustments:
Net (gain) loss on asset sales - (104) 96 - -
Impairments - 606 314 1,110 -
Canceled projects - - 28 29 -
Severance accruals - - 15 28 -
Tax law impacts (13) - - - -
Pending claims and settlements - 19 - - 25
Repositioning tax impacts - 73 - - -
Hurricane-related costs - 33 - - -
Adjusted earnings 1,390$ 3,844$ 1,982$ 622$ (511)$
Marketing & Specialties
Earnings (loss) 520$ 465$ 573$ 567$ 538$
Adjustments:
Net (gain) loss on asset sales (23) (2) (23) (116) (13)
Impairments - - - 8 37
Pending claims and settlements (16) 38 - (35) -
Exit of business line 34 - - - -
Tax law impacts (4) - - - -
Repositioning tax impacts - 63 - - -
Adjusted earnings 511$ 564$ 550$ 424$ 562$
Millions of Dollars
NON-GAAP RECONCILIATIONS
ROCE 2013 1H SLIDE 7
40 * Total equity plus total debt
2013 1H Midstream Chemicals Refining and
M&S
Numerator ($MM)
Net Income 205 463 1,923
After-tax interest expense - - -
GAAP ROCE earnings 205 463 1,923
Special Items (27) - (22)
Adjusted ROCE earnings 178 463 1,901
Denominator ($MM)
GAAP average capital employed* 3,135 3,649 17,890
Annualized Adjusted ROCE 11% 25% 21%
Annualized GAAP ROCE 13% 25% 21%
NON-GAAP RECONCILIATIONS
CPCHEM EBITDA SLIDE 20
41
Incremental Project Earnings Projections
EBITDA Reconciliation to Net Income - $MM
Estimated incremental net income (CPChem View) Low High
Estimated incremental net income 1,000$ 1,313$
Estimated depreciation 280 260
Estimated interest - -
Estimated taxes 20 27
Estimated incremental EBITDA 1,300$ 1,600$
NON-GAAP RECONCILIATIONS
REFINING ROCE SLIDE 26
42
2013 2012 2011 2010
1H Year Year Year
Refining - ROCE
Numerator
Net Income 1,403$ 3,217$ 1,529$ (545)$
After-tax interest expense - - - -
GAAP ROCE earnings 1,403 3,217 1,529 (545)
Special Items (13) 627 453 1,167
Adjusted ROCE earnings 1,390$ 3,844$ 1,982$ 622$
Denominator
GAAP average capital employed* 14,312$ 14,331$ 15,160$ 16,829$
Annualized Adjusted ROCE 19% 27% 13% 4%
Annualized GAAP ROCE 20% 22% 10% -3%
Millions of Dollars
Except as Indicated
* Total equity plus total debt
NON-GAAP RECONCILIATIONS
ROCE SLIDE 28
43
2013 2012 2011 2010 2009
1H Year Year Year Year
Phillips 66 - ROCE
Numerator
Net Income 2,370$ 4,131$ 4,780$ 740$ 479$
After-tax interest expense 90 160 11 1 1
GAAP ROCE earnings 2,460 4,291 4,791 741 480
Special Items (49) 1,263 (1,184) 1,024 21
Adjusted ROCE earnings 2,411$ 5,554$ 3,607$ 1,765$ 501$
Denominator
GAAP average capital employed* 27,970$ 25,732$ 25,064$ 26,906$ 26,417$
Annualized Adjusted ROCE 17% 22% 14% 7% 2%
Annualized GAAP ROCE 18% 17% 19% 3% 2%
Millions of Dollars
Except as Indicated
* Total equity plus total debt
2013 2012 2011 2010 2009
1H Year Year Year Year
Phillips 66
Net Income 2,370$ 4,131$ 4,780$ 740$ 479$
Income taxes 1,185 2,500 1,844 579 368
Net interest expense 131 231 (16) (41) (46)
Depreciation and amortization 476 913 908 880 879
EBITDA 4,162$ 7,775$ 7,516$ 2,158$ 1,680$
Adjustments (pre-tax):
Net (gain) loss on asset sales (40) (189) (1,636) (234) (37)
Gain on share issuance by equity affiliate (43) - - - (135)
Impairments - 1,197 506 1,512 129
Canceled projects - - 44 106 -
Severance accruals - - 24 28 -
Exit of business line 54 - - - -
Tax law impacts (28) - - - -
Pending claims and settlements (25) 56 - (56) 39
Premium on early debt retirement - 144 - - -
Repositioning costs - 85 - - -
Hurricane-related costs - 56 - - -
Adjusted EBITDA 4,080$ 9,124$ 6,454$ 3,514$ 1,676$
Millions of Dollars
NON-GAAP RECONCILIATIONS
ADJUSTED EBITDA SLIDE 28
44
2013 2012 2011 2010 2009
1H Year Year Year Year
Midstream
Net Income 205$ 60$ 2,154$ 391$ 389$
Income taxes 112 29 454 186 205
Net interest expense - - - - -
Depreciation and amortization 38 83 82 74 99
EBITDA 355$ 172$ 2,690$ 651$ 693$
Adjustments (pre-tax):
Net (gain) loss on asset sales - - (1,830) - (15)
Impairments - 523 6 - 70
Pending claims and settlements - (37) - - -
Gain on share issuance by equity affiliate (43) - - - (135)
Hurricane-related costs - 2 - - -
Adjusted EBITDA 312$ 660$ 866$ 651$ 613$
Millions of Dollars
NON-GAAP RECONCILIATIONS
ADJUSTED EBITDA SLIDE 28
45
2013 2012 2011 2010 2009
1H Year Year Year Year
Chemicals
Net Income 463$ 823$ 716$ 486$ 228$
Income taxes 172 366 252 194 67
Net interest expense - - - - -
Depreciation and amortization - - - - -
EBITDA 635$ 1,189$ 968$ 680$ 295$
Adjustments (pre-tax):
Impairments - 43 - - -
Premium on early debt retirement - 144 - - -
Adjusted EBITDA 635$ 1,376$ 968$ 680$ 295$
Millions of Dollars
NON-GAAP RECONCILIATIONS
ADJUSTED EBITDA SLIDE 28
46
2013 2012 2011 2010 2009
1H Year Year Year Year
Refining
Net Income 1,403$ 3,217$ 1,529$ (545)$ (536)$
Income taxes 771 2,067 902 (56) (286)
Net interest expense - - (1) (2) (1)
Depreciation and amortization 345 655 664 659 641
EBITDA 2,519$ 5,939$ 3,094$ 56$ (182)$
Adjustments (pre-tax):
Net (gain) loss on asset sales - (185) 234 - -
Impairments - 606 500 1,500 -
Canceled projects - - 44 106 -
Severance accruals - - 24 28 -
Tax law impacts (22) - - - -
Pending claims and settlements - 31 - - 39
Hurricane-related costs - 54 - - -
Adjusted EBITDA 2,497$ 6,445$ 3,896$ 1,690$ (143)$
Millions of Dollars
NON-GAAP RECONCILIATIONS
ADJUSTED EBITDA SLIDE 28
47
2013 2012 2011 2010 2009
1H Year Year Year Year
Marketing & Specialities
Net Income 520$ 465$ 573$ 567$ 538$
Income taxes 270 277 333 348 457
Net interest expense - - (32) (40) (46)
Depreciation and amortization 63 153 159 147 138
EBITDA 853$ 895$ 1,033$ 1,022$ 1,087$
Adjustments (pre-tax):
Net (gain) loss on asset sales (40) (4) (40) (234) (22)
Impairments - - - 12 59
Pending claims and settlements (25) 62 - (56) -
Exit of business line 54 - - - -
Tax law impacts (6) - - - -
Adjusted EBITDA 836$ 953$ 993$ 744$ 1,124$
Millions of Dollars
NON-GAAP RECONCILIATIONS
ADJUSTED EBITDA SLIDE 28
48
2013 2012 2011 2010 2009
1H Year Year Year Year
Corporate
Net Income (221)$ (434)$ (192)$ (159)$ (140)$
Income taxes (140) (239) (97) (93) (75)
Net interest expense 131 231 17 1 1
Depreciation and amortization 30 22 3 - 1
EBITDA (200)$ (420)$ (269)$ (251)$ (213)$
Adjustments (pre-tax):
Impairments - 25 - - -
Repositioning costs - 85 - - -
Adjusted EBITDA (200)$ (310)$ (269)$ (251)$ (213)$
Millions of Dollars
NON-GAAP RECONCILIATIONS
ADJUSTED EBITDA SLIDE 28
49
NON-GAAP RECONCILIATIONS
SWEENY FRAC AND EXPORT EBITDA (TRANSCRIPT)
50
Millions of Dollars
First Year
Sweeny Fractionator & Export Facility
Estimated net income 190$
Estimated income taxes 118
Estimated net interest expense 5
Estimated depreciation and amortization 118
Estimated EBITDA 430$
NON-GAAP RECONCILIATIONS
CPCHEM EBITDA (TRANSCRIPT)
51 * Primarily related to premium on early debt retirement
Millions of Dollars
2012
Year
CPChem
Net Income 2,403$
Income taxes 67
Net interest expense 9
Depreciation and amortization 356
CPChem EBITDA 2,835$
Adjustments* 252
Adjusted CPChem EBITDA 3,087$