Sunoco Logistics Partners L.P.

NYSE

SXL Analyst DayNovember 2014

Forward-Looking StatementsStatements we make that are not historical facts are forward-looking statements.These forward-looking statements are not guarantees of future performance.Although we believe the assumptions underlying these statements are reasonable,investors are cautioned that such forward-looking statements involve risks anduncertainties that may affect our business and cause actual results to differ materiallyfrom those discussed in this presentation. Such risks and uncertainties includeeconomic, business, competitive and/or regulatory factors affecting our business, aswell as uncertainties related to the outcomes of any pending or future litigation.Sunoco Logistics Partners L.P. has included in its Annual Report on Form 10-K for theyear ended December 31, 2013 cautionary language identifying important risk factors(though not necessarily all such factors) that could cause future outcomes to differmaterially from those set forth in the forward-looking statements. For moreinformation about these risk factors, see our SEC filings, available on our website atwww.sunocologistics.com. We expressly disclaim any obligation to update or alterthese forward-looking statements, whether as a result of new information, futureevents or otherwise.

This presentation includes certain non-GAAP financial measures intended tosupplement, not substitute for, comparable GAAP measures. Reconciliations of non-GAAP financial measures to GAAP financial measures are provided in the appendixto this presentation. You should consider carefully the comparable GAAP measuresand the reconciliations to those measures provided in this presentation. 2

Agenda

Sunoco Logistics Overview p. 4

Crude Market Summary p. 15

Crude Projects p. 22

Refined Products Projects p. 25

NGL Market Summary p. 27

NGL Projects p. 30Mariner East 2PDH Overview

Summary p. 48

Appendix p. 52

Sunoco Logistics Overview

Sunoco Logistics Assets

5

Sunoco Logistics and Energy Transfer Assets

6

LP Interest, GP Interest, IDRsLP Interest, GP Interest, IDRs, Class H Units(1)

LP Interest, GP Interest, IDRs

Gathering and Processing

Contract Compression

& Treating

Lone Star NGL

70% ETP Interest 30% RGP Interest

(1) Class H Units track 50% of the SXL GP and IDR economics(2) Previously called Susser Petroleum Partners ("Susser") and traded under the ticker symbol SUSP on NYSE

Energy Transfer Family of Companies

7

SUNOCO LP(2)

(NYSE: SUN)

Crude Oil Pipelines

Crude Oil Acquisition &

Marketing

Terminal Facilities

NGL / Refined Product

Pipelines

ENERGY TRANSFER EQUITY, L.P.(NYSE: ETE)

ENERGY TRANSFER PARTNERS, L.P.

(NYSE: ETP)

REGENCY ENERGY PARTNERS LP(NYSE: RGP)SUNOCO LOGISTICS

PARTNERS L.P. (NYSE: SXL)Intrastate

Transportationand Storage

Interstate Transportation

and Storage

Midstream

Sunoco, Inc.Retail

Marketing

NGL Transportation and Services

Retail Operations

Joint Ventures

LP Interest, GP Interest, IDRs

Recent Highlights

3Q14 Results:

– EBITDA $246MM… 2nd biggest quarter ever– 10th consecutive 5% quarter-over-quarter distribution increase

2 Additional Successful Open Seasons:

– Mariner East 2– Permian Longview & Louisiana Extension

September 2014 YTD Organic Growth Capital of $1.8B:

– Updated guidance for 2014 at ~$2.5B– New guidance for 2015 at ~$2B… on committed projects only

8

EBITDA by Segment($MM)

9

2010 2011 2012 2013 LTM*Crude Oil Pipeline 156 207 275 349 394 Crude Oil Acq. & Mktg. 39 148 239 233 164 Terminal Facilities 127 149 225 233 306 Products Pipeline 77 69 71 56 80 Total EBITDA 399 573 810 871 944

*LTM = last twelve months ended September 30, 2014

Adjusted EBITDA: Ratable and Market Related

Maximize asset base by taking advantage of market opportunities

Distributions based on ratable cash

Market related cash flow increases coverage ratio

10

-

200

400

600

800

1,000

1,200

2010 2011 2012 2013 LTM*

Adj

uste

d EB

ITD

A ($

MM

)

Ratable Market Related

399

573

810871

944

*LTM = last twelve months ended September 30, 2014

10 Consecutive Quarters of 5% Distribution Growth

Guidance ~5% quarter over quarter increases in 2014

Note: Values adjusted for the two-for-one unit split completed on June 12, 2014 11

Major Organic Projects 13 Successful Open Seasons:3 West Texas Crude expansion projects (crude oil)Permian Express 1 (crude oil)Permian Express 2 (crude oil)Eaglebine Express (crude oil)Granite Wash Extension (crude oil)Permian Longview & Louisiana Extension (crude oil)Allegheny Access (refined products)Mariner West (natural gas liquids)Mariner East 1 (natural gas liquids)Mariner East 2 (natural gas liquids)Mariner South (natural gas liquids)

Actively developing:Delaware Basin Extension (crude oil)

12

Organic Capital

13

0

500

1,000

1,500

2,000

2,500

2010 2011 2012 2013 2014P 2015P

Inve

stm

ent (

$MM

)

Organic Expansion Capital

Acquisitions

0

100

200

300

400

500

600

2010 2011 2012 2013 2014*

Inve

stm

ent (

$MM

)

Acquisition Capital

*SXL does not comment on future acquisitions*Includes the acquisition of an additional 3.9% interest in Explorer Pipeline for $42MM 14

Crude Market Summary

$20

$40

$60

$80

$100

$120

$140

$160

$/bbl

Dated Brent Daily Price 2008 - Present

16

World Non-OPEC Liquids Supply Growth

Change Year-Over-Year

17

Source: PIRA

OPECNon-OPEC

Top 20 Crude Producers – November 2014 (MMBPD)

18

Source: PIRA

Source: PIRA

19

Approximate $/BBL Breakeven Price

$40

$60

$80

$100

Oil Sands Offshore Deepwater Shale

2010 2015

Shale is the Lowest Cost Barrel Today

$32

$46$53

$62 $66$72 $73

$0

$25

$50

$75

$100

WTI Oil Breakeven by Basin

$/BBL

Source: Credit Suisse

20

*** About 200 MBPD growth projected in 2014*** Actual Growth now estimated at over 300 MBPD

Permian Basin Output

21Source: PIRA

Crude Projects

Committed Fee-based Income

Permian Express 1Permian Crude to Nederland

2Q 2013

Delaware Basin ExtensionDelaware Basin Crude to Midland

1H 2016*

3 West Texas Crude ExpansionsPermian Crude to multiple markets

2012 - 2014

Permian LV & LA ExtensionPermian Crude to multiple markets

Mid-2016*

Eaglebine ExpressEaglebine / Woodbine Crude to Nederland

4Q 2014

Granite Wash ExtensionGranite Wash Crude to multiple markets

4Q 2014

Permian Express 2Permian Crude to multiple markets

Mid-2015*

*Expected Start-up 23

Crude Projects: 8 Successful Open Seasons (1 in progress)

Nederland Terminal

24

Refined Products Projects

Allegheny Access – Refined Products

Allegheny AccessOhio Products to Pittsburgh

4Q 2014*

26Committed Fee-based Income

*Expected Start-up

NGL Market Summary

Top 20 NGL Producers – 2014 (MMBPD)

OPECNon-OPEC

Source: PIRA

28

BPD

Marcellus / Utica NGL Forecast

Source: Dominion, SXL

-

200,000

400,000

600,000

800,000

1,000,000

1,200,000

1,400,000

2012 2013 2014 2015 2016 2017 2018 2019 2020Propane Normal Butane IsobutaneNat Gasoline Must-Recover Ethane Discretionary Ethane

Over 800 MBPD liquids by 2016

29

NGL Projects

Mariner Franchise

Mariner WestEthane from Houston to Sarnia

4Q 2013

Mariner SouthPropane / Butane from Mont Belvieu to Nederland

End of 2014*

Committed Fee-based Income

Mariner East 1Ethane / Propane from Houston to Marcus Hook

4Q 2014*

Mariner East 2NGLs from Shales to Marcus Hook

4Q 2016*

*Expected Start-up 31

Mariner South – Natural Gas Liquids

32Committed Fee-based Income

Lone StarFractionators

SXLTerminal

Mariner SouthPropane / Butane from Mont Belvieu to Nederland

End of 2014*

*Expected Start-up

Mariner South at Nederland Terminal

33

Nederland Terminal

34

Mariner West and East – Natural Gas Liquids

Mariner WestEthane from Houston to Sarnia

4Q 2013

Mariner East 1E/P from Houston to Marcus Hook

End of year 2014*

35Committed Fee-based Income

Mariner East 2NGLs to Marcus Hook

4Q 2016*

*Expected Start-up

Mariner East 2

Mariner East

37

Connecting to 4 Fractionator Origin Locations in the Basin

275,000 B/D Initial Capacity345,000 B/D including ME 1

World-Class NGL Facility at Marcus Hook Industrial Complex

37

Marcus Hook Industrial Complex

MarinerInfrastructure

38

Marcus Hook Terminal Build-Out

39

Marcus Hook – Natural Gas Liquids

40

Marcus Hook – Natural Gas Liquids

41

PDH at Marcus Hook In Development

Global Propylene Supply and Demand

- Global Propylene market is expected to grow by 33MM Metric Tons by 2020

- Lighter feed to crackers

- PDH is a preferred choice

43

Propylene Supply and Demand

44

Why PDH in Marcus Hook?

Perfect location for local demand Better logistics

Perfect location for propylene export to North West EuropeAdvantaged shipping and logistics costsDelivered cash cost competitive with international markets

Perfect location for Petrochemical ProjectExisting infrastructure, Lower CAPEX, Optimized schedulePlenty of dock capacity, uncrowded ship channelGovernment support for MHIC industrial redevelopment

ME 2 assures long term, reliable propane supply

45

Propylene – Propane Spread 2000 – 2014

$/mt

Source: IHS Global

46

Marcus Hook Industrial Complex

MarinerInfrastructure

PROPOSEDPDH

47

Summary

Key SXL Takeaways – Recent History

49

Strategic Focus on Crude and Natural Gas Liquids

First Mover… First West Texas crude projects on line since the shale boom First Marcellus ethane pipeline on line First waterborne propane exports from the Northeast First waterborne ethane export project (Mid-2015 with ME1)

Robust Organic Program 13 Successful Open Seasons since 2011 ~ $ 2.5 B Organic Capital Plan in 2014 (~ $ 4 B last 4 years) ~ $ 1 B in M&A over last five years

Commitment to Rewarding our Owners 10 consecutive quarters of 5 % distribution growth 5 year unit price growth over 400 %

Scheduled Project Start-up

50

Key SXL Takeaways – Going Forward

51

Commitment to Growth 14th Open Season in progress

New phase of growth in processing at Marcus Hook

Opportunities within the Energy Transfer family

M&A - Actively looking for right, strategic opportunities

Commitment to Rewarding our Owners Competitive, sustainable distribution growth

Commitment to Investment Grade credit rating Excellent balance sheet

• Long-term target of 3.5x to 4.0x Debt to Adjusted EBITDA Balance Debt and Equity issuance to maintain rating

• $1.5B revolver for liquidity

Appendix

2010 2011 2012 2013 LTM*

348 322 531 474 530 Interest expense, net 73 89 79 77 70 Depreciation and amortization expense 64 86 139 265 289 Impairment charge 3 31 9 - - Provision for income taxes 8 25 32 30 28 Non-cash compensation expense 5 6 8 14 16 Unrealized losses / (gains) on commodity risk management activities 2 (2) 3 (1) (3) Proportionate share of unconsolidated affiliates' interest, depreciation

and provision for income taxes 24 16 21 20 21 Adjustments to commodity hedges resulting from "push-down" accounting - - (12) - - Amortization of excess joint venture investment - - - 2 3 Non-cash accrued liability adjustment - - - (10) (10) Gain on investments in affiliates (128) - - - -

Adjusted EBITDA(1) 399 573 810 871 944 Interest expense, net (73) (89) (79) (77) (70) Provision for income taxes(2) (8) (27) (34) (24) (31) Amortization of fair value adjustments on long-term debt - - (6) (23) (17) Distributions versus Adjusted EBITDA of unconsolidated affiliates (36) (17) (28) (27) (32) Maintenance capital expenditures (37) (42) (50) (53) (63) Distributable Cash Flow attributable to noncontrolling interests (3) (10) (11) (16) (13) Acquisition costs reimbursement - - - 9 12

Distributable Cash Flow (DCF)(1) 242 388 602 660 730

(1)

(2)

Twelve Months Ended December 31,

Net Income

Management of the Partnership believes Adjusted EBITDA and distributable cash flow information enhances an investor's understanding of a business’s ability to generate cash for payment of distributions and other purposes. Adjusted EBITDA and Distributable Cash Flow do not represent and should not be considered alternatives to net income or cash flows from operating activities as determined under United States generally accepted accounting principles (GAAP) and may not be comparable to other similarly titled measures of other businesses. Historical amounts presented have been recast to conform to current period.

During the third quarter 2014, we changed our definition of distributable cash flow to conform to the presentation utilized by Energy Transfer Partners, L.P., the controlling member of our general partner. This change did not have a material impact on our distributable cash flows. Prior period amounts have been recast to conform to current presentation.

SXL Non-GAAP Financial Measures

($MM)

53*LTM = Last Twelve Months, period ended September 30, 2014

2010 2011 2012 2013 LTM*

Crude Oil Pipelines 156 207 275 349 394 Crude Oil Acquisition & Marketing 39 148 239 233 164 Terminal Facilities 127 149 225 233 306 Refined Products Pipelines 77 69 71 56 80 Total Adjusted EBITDA 399 573 810 871 944

Interest expense, net (73) (89) (79) (77) (70) Provision for income taxes(1) (8) (27) (34) (24) (31) Maintenance Capital Expenditures (37) (42) (50) (53) (63) Amortization of fair value adjustment on long-term debt - - (6) (23) (17) Distributions versus adjusted EBITDA of unconsolidated affiliates (36) (17) (28) (27) (32) Distributable cash flow attributable to noncontrolling interests (3) (10) (11) (16) (13) Acquisition costs reimbursement - - - 9 12

Distributable Cash Flow (DCF) 242 388 602 660 730

Expansion Capital(2) 146 171 324 965 2,207

Total Distribution (accrual basis) 193 214 277 378 468 Distribution Coverage Ratio 1.3x 1.8x 2.2x 1.7x 1.6x

Historical Financial Results($MM)

54

(1) During the third quarter 2014, we changed our definition of distributable cash flow to conform to the presentation utilized by Energy Transfer Partners, L.P., the controlling member of our general partner. This change did not have a material impact on our distributable cash flows. Prior period amounts have been recast to conform to current presentation.

(2) Excludes major acquisitions

*LTM = Last Twelve Months, period ended September 30, 2014

Consolidated JV's:

SXL 60.3% SXL 91.0% SXL 83.8%Chevron 28.3% Chevron 9.0% Citgo 16.2%Citgo 11.4%

Equity Interest JV's:

Shell 36.0% Buckeye 34.6% ExxonMobil 53.4% Phillips 66 46.0%Marathon 24.5% Shell 18.9% SXL 31.5% ExxonMobil 40.0%Phillips 66 19.4% Citgo 18.4% Citgo 9.5% SXL 14.0%SXL 13.3% SXL 17.1% Marathon 5.6%American Capital Group 6.8% ExxonMobil 11.0%

SXL 50%Vitol 50%

Undivided Interest JV's:Harbor

SXL 66.7% Plains 63.0%Phillips 66 33.3% SXL 37.0%

Explorer* West Shore Wolverine**

West Texas Gulf

Yellowstone

Mesa

InlandMid-Valley

SunVit

Joint Venture Ownership

Bold - denotes operator* Operated by Explorer’s employees** Operated by Wolverine’s employees

55

Crude Oil Pipeline System

42% of total EBITDA for the twelve months ended September 30, 2014

Approximately 5,300 miles of crude oil trunk lines located in the Southwest and Midwest U.S.Approximately 500 miles of gathering lines

60.3% controlling interest in West Texas Gulf Pipeline, approximately 600-mile crude oil pipeline

91.0% controlling interest in Mid-Valley Pipeline, approximately 1,000-mile crude oil pipeline

56

Crude Oil Acquisition and Marketing

17% of total EBITDA for the twelve months ended September 30, 2014

Crude truck fleet of over 300 trucks

Purchase crude oil at the wellhead from producers and in bulk from aggregators at major pipeline interconnections and trading locations

Buying and selling crude oil of different grades, at different locations in order to maximize value

Marketing crude oil to major integrated oil companies, independent refiners and resellers through various types of sale and exchange transactions

Wellhead volumes of approximately 400,000 barrels per day from approximately 3,000 producers who operate approximately 60 thousand active leases

Storing inventory during contango market conditions – maintain balanced book to mitigate commodity risk

Transporting crude oil on our pipelines and trucks or when necessary or cost effective, pipelines or trucks owned and operated by third parties

57

Terminal Facilities 32% of total EBITDA for the twelve months ended September 30, 2014 Nederland, TX Crude Oil Terminal - One of the largest onshore crude facilities in U.S. 22 million barrel capacity currently

Eagle Point, NJ Crude Oil and Refined Products Terminal 5 million barrel capacity for crude oil and refined product storagePipeline and rail connections with import/export capabilities

Marcus Hook Industrial ComplexPipeline, rail and trucking connections with import/export capabilities5 million barrel capacity for refined product and NGL storage

• Includes five underground NGL storage caverns Refinery Terminal Facilities with combined 5 million barrel capacityServe Philadelphia area refineries

39 active Refined Products Marketing Terminals located in 11 states with a combined capacity of 8 million barrels

Inkster, MI LPG Terminal with a capacity of approximately 1 million barrels Total terminal capacity of approximately 46 million barrels Patented technology to blend butane into gasoline

58

Refined Products Pipeline System

9% of total EBITDA for the twelve months ended September 30, 2014

Refined products pipeline system (approximately 2,300 miles), located in the Northeast, Midwest and Southwest U.S.

Equity interest in four product pipelinesExplorer (13.3%)West Shore (17.1%)Wolverine (31.5%)Yellowstone (14.0%)

83.8% controlling interest in Inland Pipeline, an approximately 350-mile refined products pipeline system

59

$0.00

$0.50

$1.00

$1.50

$2.00

2009 2010 2011 2012 2013 CAD*

Average Annual Distribution(per LP unit)

Distribution History

10 consecutive quarter over quarter distribution increases of 5%

38 consecutive quarterly distribution increases

Current annualized distribution of $1.53

DistributionCoverage 1.5x 1.3x 1.8x 2.2x 1.7x

LP/GPSplit (%)

50/50

85/15

63/37

98/2

60

$1.06

$0.38

$0.33

$1.53

*CAD: Current Annualized Distribution @ $1.53 per LP Unit

Note: Values adjusted for the two-for-one unit split completed on June 12, 2014

$1.5 Billion Revolving Credit Facility

($MM)

61

(1) Citibank is the administrative agent for the $1.5 billion revolver(2) PNC Bank is administrative agent and sole lender on a separate $35MM West Texas Gulf revolver

$100MM Lenders $40.5MM LendersCitibank(1) $100.0 Bank of Nova Scotia $40.5Barclays Bank 100.0 BNP Paribas 40.5Bank of Tokyo-Mitsubishi UFJ 100.0 Comerica Bank 40.5PNC Bank(2) 100.0 Deutsche Bank 40.5TD Bank 100.0 DNB Capital 40.5Wells Fargo Bank 100.0 Goldman Sachs Bank 40.5Subtotal $600.0 Morgan Stanley Senior Funding 40.5

SunTrust Bank 40.5Subtotal $324.0

$64MM LendersBank of America $64.0Compass Bank 64.0Credit Suisse 64.0JPMorgan Chase Bank 64.0Mizuho Bank 64.0Royal Bank of Canada 64.0 Lender Royal Bank of Scotland 64.0 $100.0MM Lenders Total $600.0UBS 64.0 $64.0MM Lenders Total 576.0US Bank 64.0 $40.5MM Lenders Total 324.0Subtotal $576.0 Total $1,500.0

$1.5B FacilityAllocation

FacilityAllocation

FacilityAllocation

FacilityAllocation

Debt to Adjusted EBITDA

(1) In accordance with purchase accounting guidance, the Partnership's Senior Notes were adjusted to fair value (“FV”) upon the closing of Energy Transfer's acquisition of the Partnership's general partner in October 2012.

2009 2010 2011 2012 2013Debt to Adjusted EBITDA Ratio

Total Debt 868 1,229 1,698 1,732 2,503 Less: Unamortized FV adjustments, net(1) - - - 143 120

868 1,229 1,698 1,589 2,383

Adjusted EBITDA (trailing 12 months) 372 399 573 810 871

Debt to Adjusted EBITDA Ratio 2.3x 3.1x 3.0x 2.0x 2.7x

December 31,($MM)

62

Capitalization

(1) In accordance with purchase accounting, the Partnership's Senior Notes were accounted for at fair value upon the closing of Energy Transfer's acquisition of the Partnership's general partner. At 09/30/2014, there was $105 MM of net unamortized fair value adjustments.

(2) New $1.5 billion revolver closed in November 2013, replaced the existing SXL revolvers.

($MM) As of 9/30/14Debt

Senior Notes, net 2,975 fixedUnamortized fair value adjustments, net(1) 105 $1.5 B SXL Revolver (matures November 2018)(2) 525 floating $35 MM WTG Revolver (matures April 2015) 35 floating

Total Debt(1) 3,640

EquityLimited Partners 5,966 General Partner 928

Total Partners’ Capital 6,894 Non-Controlling Interest 124

Total Equity 7,018

Rating: BBB / Baa3 / BBB (S&P, Moody’s, Fitch), stable outlook

63

Debt Maturity Schedule at 9/30/2014($MM)

Note: Excludes borrowings under the revolvers

5.50% 4.25% 5.30%4.95%6.10%6.13% 4.65% 3.45% 6.85%

64

November 2002 Joint-venture interests in 3 refined product pipelines from Unocal, for $54MM

Wolverine (31.5%), West Shore (9.2%), and Yellowstone (14.0%)

November 2002 43.8% joint-venture interest from Sunoco/Unocal in West Texas Gulf crude pipeline for $11MM

September 2003 Additional joint-venture interest in West Shore for $4MM increasing ownership

interest from 9.2% to 12.3%

March 2004 Logistics assets of Eagle Point refinery from Sunoco, Inc. for $20MM

April 2004 Baltimore, MD and Manassas, VA refined product terminal facilities from ConocoPhillips for $12MM

June 2004 Additional 1/3rd joint-venture interest in Harbor Pipeline from El Paso for $7MM, increasing ownership

interest to 2/3rds

November 2004 Columbus, OH refined product terminal facilities from Certified Oil for $8MM

August 2005 Texas crude oil pipeline system from ExxonMobil for $100MM

December 2005

March 2006

37% joint-venture interest in Mesa crude oil pipeline system from Sunoco/Chevron for $7MM

Texas crude oil pipeline system from Black Hills for $41MM

Texas crude oil pipeline system from Alon for $68MM

August 2006

June 2007

November 2008

55.3% joint-venture interest in Mid-Valley crude oil pipeline from Sunoco, Inc. for $65MM

50% joint-venture interest in a refined products terminal in Syracuse, NY from ExxonMobil for $13MM

Texas refined products pipeline system and terminal facilities from ExxonMobil for $186MM

Acquisition History ($1.5B Since IPO)

65

September 2009 Oklahoma crude oil pipeline from Excel Pipeline LLC and Romulus, MI refined products terminal facility

from R.K.A. Petroleum LLC for an aggregate $50MM

July 2010 Butane blending business from Texon L.P. for $152MM including inventory

Additional joint-venture interest in West Shore from BP for $7MM increasing ownership

interest from 12.3% to 17.1%

Additional joint-venture interest in Mid-Valley from BP for $58MM increasing ownership

interest from 55.3% to 91.0%

August 2010 Additional joint-venture interest in West Texas Gulf from BP for $27MM increasing ownership

interest from 43.8% to 60.3%

May 2011 83.8% controlling joint-venture interest in Inland refined products pipeline for $99MM

July 2011 Eagle Point Tank Farm from Sunoco, Inc. for $100MM in deferred distribution units

August 2011 Crude Oil Acquisition and Marketing business from Texon L.P. for $222MM including inventory

East Boston products terminal and pipeline from ConocoPhillips for $73MM including inventory

April 2013

March 2014

May 2014

Marcus Hook Industrial Complex from Sunoco, Inc. for $60MM

Additional joint-venture interest in Explorer Pipeline from Chevron for $42MM increasing ownership

interest from 9.4% to 13.3%

Crude Oil Acquisition and Marketing business from EDF for $80MM including inventory

Acquisition History ($1.5B Since IPO), Continued

66

SXL Key Financial and Operating Statistics

67

2010 2011Total Total 1st 2nd 3rd 4th Total 1st 2nd 3rd 4th Total 1st 2nd 3rd Total

Financial highlights (in millions)

Sales and other operating revenue

Crude Oil Pipelines 221$ 319$ 80$ 100$ 108$ 110$ 398$ 95$ 122$ 139$ 139$ 495$ 131$ 138$ 144$ 413$ Crude Oil Acquisition and Marketing 7,282 10,163 3,192 3,056 3,010 2,888 12,146 3,259 4,047 4,244 3,968 15,518 4,094 4,432 4,497 13,023 Terminal Facilities 287 435 135 170 101 206 612 183 176 177 215 751 287 283 298 868 Refined Products Pipelines 120 130 31 32 33 35 131 30 32 34 34 130 41 40 46 127 Intersegment eliminations (102) (142) (37) (45) (45) (50) (177) (55) (66) (66) (68) (255) (76) (72) (70) (218)

Total sales and other operating revenue 7,808$ 10,905$ 3,401$ 3,313$ 3,207$ 3,189$ 13,110$ 3,512$ 4,311$ 4,528$ 4,288$ 16,639$ 4,477$ 4,821$ 4,915$ 14,213$

Adjusted earnings before interest, taxes, depreciation and amortization (Adjusted EBITDA)

Crude Oil Pipelines 156$ 207$ 60$ 70$ 73$ 72$ 275$ 61$ 88$ 98$ 102$ 349$ 93$ 104$ 95$ 292$ Crude Oil Acquisition and Marketing 39 148 47 57 54 81 239 112 70 18 33 233 12 53 66 131 Terminal Facilities 127 149 47 74 52 52 225 54 70 47 62 233 86 97 61 244 Refined Products Pipelines 77 69 15 17 25 14 71 9 16 18 13 56 17 26 24 67 Total Adjusted EBITDA 399$ 573$ 169$ 218$ 204$ 219$ 810$ 236$ 244$ 181$ 210$ 871$ 208$ 280$ 246$ 734$

Operating highlights

Crude Oil PipelinesPipeline throughput (thousands of barrels per day "bpd") 1,183 1,587 1,467 1,571 1,601 1,584 1,556 1,582 1,890 1,976 2,009 1,866 2,041 2,130 2,204 2,126 Pipeline revenue per barrel (cents) 50.7 55.0 59.6 70.0 73.6 75.6 69.9 67.0 70.8 76.3 75.2 72.7 71.6 71.2 70.8 71.2

Crude Oil Acquisition and MarketingCrude oil purchases (thousands of bpd) 638 663 631 700 692 669 673 750 796 716 734 749 840 854 894 863 Gross profit per barrel purchased (cents) (1) 21.0 66.0 89.5 97.1 91.5 138.0 104.1 172.0 101.8 33.9 55.9 91.4 21.1 74.8 85.9 61.4 Average crude oil price (per barrel) 79.55$ 95.14$ 102.94$ 93.50$ 92.19$ 88.20$ 94.19$ 94.34$ 94.23$ 105.82$ 97.50$ 98.00$ 98.61$ 102.98$ 97.21$ 99.60$

Terminal Facilities (thousands of bpd)Refined products terminals throughput 488 492 487 515 495 451 487 414 454 432 422 431 413 420 420 418 Nederland terminal throughput 729 757 697 690 721 787 724 850 932 968 977 932 1,322 1,216 1,262 1,266 Refinery terminals throughput 465 443 383 345 381 411 380 325 444 495 324 397 226 345 297 290

Refined Products Pipelines (2)

Pipeline throughput (thousands of bpd) 468 522 528 591 576 601 582 522 599 577 586 571 521 551 582 552 Pipeline revenue per barrel (cents) 70.0 68.3 65.1 59.5 62.2 63.0 61.6 62.9 59.1 64.3 63.9 62.5 88.3 79.4 85.5 84.4

2012 2013 2014

SXL Key Financial and Operating Statistics

68

2010 2011Total Total 1st 2nd 3rd 4th Total 1st 2nd 3rd 4th Total 1st 2nd 3rd Total

Reconciliation of Segment Operating Income to Net Income Attributable to Sunoco Logistics Partners L.P. (in millions)

Operating income:Crude Oil Pipelines 113$ 181$ 52$ 63$ 67$ 49$ 231$ 38$ 65$ 74$ 80$ 257$ 68$ 79$ 68$ 215$ Crude Oil Acquisition and Marketing 36 137 34 52 48 69 203 100 57 5 22 184 (1) 39 51 89 Terminal Facilities 94 85 37 60 39 44 180 31 46 27 27 131 60 59 52 171 Refined Products Pipelines 28 20 4 4 - (3) 5 (4) (3) (2) (3) (12) - 3 1 4

Total segment operating income 271 423 127 179 154 159 619 165 165 104 126 560 127 180 172 479 Interest expense, net (73) (89) (24) (21) (20) (14) (79) (19) (17) (22) (19) (77) (16) (21) (14) (51) Gain on investments in affiliates 128 - - - - - - - - - - - - - - - Other income 30 13 2 5 11 5 23 2 7 7 5 21 4 7 7 18 Provision for income taxes (8) (25) (8) (8) (8) (8) (32) (6) (9) (8) (7) (30) (5) (8) (8) (21) Net income 348 322 97 155 137 142 531 142 146 81 105 474 110 158 157 425 Net income attributable to noncontrolling interests (2) (9) (2) (3) (3) (3) (11) (2) (3) (3) (3) (11) (3) (2) (2) (7) Net income attributable to Partners 346$ 313$ 95$ 152$ 134$ 139$ 520$ 140$ 143$ 78$ 102$ 463$ 107$ 156$ 155$ 418$

Reconciliation of Net Income to Adjusted EBITDA and Distributable Cash Flow (in millions)

Net income 348$ 322$ 97$ 155$ 137$ 142$ 531$ 142$ 146$ 81$ 105$ 474$ 110$ 158$ 157$ 425$ Add: Interest expense, net 73 89 24 21 20 14 79 19 17 22 19 77 16 21 14 51 Add: Depreciation and amortization expense 64 86 25 25 26 63 139 64 64 68 69 265 69 74 77 220 Add: Impairment charge 3 31 9 - - - 9 - - - - - - - - - Add: Provision for income taxes 8 25 8 8 8 8 32 6 9 8 7 30 5 8 8 21 Add: Non-cash compensation expense 5 6 3 2 1 2 8 4 2 4 4 14 5 3 4 12 Add: Unrealized (gain)/losses on commodity risk management activities 2 (2) - 3 3 (3) 3 (3) (1) (8) 11 (1) (1) 8 (21) (14) Add: Amortization of excess joint venture investment - - - - - - - - 1 - 1 2 - 1 1 2 Add: Proportionate share of unconsolidated affiliates interest, depreciation and provision for income taxes 24 16 3 4 9 5 21 4 6 6 4 20 4 7 6 17 Less: Adjustments to commodity hedges resulting from "push-down" accounting - - - - - (12) (12) - - - - - - - - - Less: Non-cash accrued liability adjustment - - - - - - - - - - (10) (10) - - - - Less: Gain on investments in affiliates (128) - - - - - - - - - - - - - - - Adjusted EBITDA 399 573 169 218 204 219 810 236 244 181 210 871 208 280 246 734 Less: Interest expense, net (73) (89) (24) (21) (20) (14) (79) (19) (17) (22) (19) (77) (16) (21) (14) (51) Less: Provision for current income taxes (3) (8) (27) (7) (9) (8) (10) (34) (7) (4) (7) (6) (24) (7) (9) (9) (25) Less: Amortization of fair value adjustments on long-term debt - - - - - (6) (6) (6) (6) (5) (6) (23) (4) (4) (3) (11) Less: Distributions versus Adjusted EBITDA of unconsolidated affiliates (36) (17) (3) (6) (16) (3) (28) (3) (8) (10) (6) (27) (6) (10) (10) (26) Less: Maintenance capital expenditures (37) (42) (7) (11) (11) (21) (50) (4) (18) (15) (16) (53) (18) (13) (16) (47) Less: Distributable cash flow attributable to noncontrolling interests (3) (10) (3) (3) (3) (2) (11) (3) (5) (5) (3) (16) (3) (4) (3) (10) Add: Acquisition costs reimbursement - - - - - - - - 3 3 3 9 3 3 3 9 Distributable Cash Flow (3) 242$ 388$ 125$ 168$ 146$ 163$ 602$ 194$ 189$ 120$ 157$ 660$ 157$ 222$ 194$ 573$

(1)

(2)

(3)

2012 2013 2014

Represents total segment sales and other operating revenue minus cost of products sold and operating expenses divided by total crude purchases.

Excludes amounts attributable to equity ownership interests which are not consolidated.

During the third quarter 2014, we changed our definition of distributable cash flow to conform to the presentation utilized by Energy Transfer Partners, L.P., the controlling member of our general partner. This change did not have a material impact on our distributable cash flows.