Investor Presentation January 2017
Forward Looking Statements This presentation contains forward-looking statements within the meaning of federal securities laws regarding MPLX LP ( MPLX ) and Marathon Petroleum Corporation ( MPC ). These forward-looking statements relate to, among other things, expectations, estimates and projections concerning the business and operations of MPLX and MPC, including proposed strategic initiatives. You can identify forward-looking statements by words such as anticipate, believe, design, estimate, expect, forecast, goal, "guidance," imply, intend, objective, opportunity, outlook, "plan, position, pursue, prospective, predict, project, "potential," seek, strategy, target, could, may, should, would, will or other similar expressions that convey the uncertainty of future events or outcomes. Such forward-looking statements are not guarantees of future performance and are subject to risks, uncertainties and other factors, some of which are beyond the companies control and are difficult to predict. Factors that could cause MPLX's actual results to differ materially from those implied in the forward-looking statements include: negative capital market conditions, including a persistence or increase of the current yield on common units, which is higher than historical yields, adversely affecting MPLX s ability to meet its distribution growth guidance; risk that the synergies from the acquisition of MarkWest Energy Partners, L.P. ( MarkWest ) by MPLX may not be fully realized or may take longer to realize than expected; disruption from the MPLX/MarkWest merger making it more difficult to maintain relationships with customers, employees or suppliers; risks relating to any unforeseen liabilities of MarkWest; the time, costs and ability to obtain regulatory or other approvals and consents and otherwise consummate the strategic initiatives discussed herein and other proposed transactions; the satisfaction or waiver of conditions in the agreements governing the strategic initiatives discussed herein and other proposed transactions; our ability to achieve the strategic and other objectives related to the strategic initiatives discussed herein and other proposed transactions; adverse changes in laws including with respect to tax and regulatory matters; inability to agree with respect to the timing of and value attributed to assets identified for dropdown; the adequacy of MPLX's capital resources and liquidity, including, but not limited to, availability of sufficient cash flow to pay distributions, and the ability to successfully execute its business plans and growth strategy; the timing and extent of changes in commodity prices and demand for crude oil, refined products, feedstocks or other hydrocarbon-based products; continued/further volatility in and/or degradation of market and industry conditions; changes to the expected construction costs and timing of projects; completion of midstream infrastructure by competitors; disruptions due to equipment interruption or failure, including electrical shortages and power grid failures; the suspension, reduction or termination of MPC's obligations under MPLX's commercial agreements; modifications to earnings and distribution growth objectives; the level of support from MPC, including dropdowns, alternative financing arrangements, taking equity units, and other methods of sponsor support, as a result of the capital allocation needs of the enterprise as a whole and its ability to provide support on commercially reasonable terms; compliance with federal and state environmental, economic, health and safety, energy and other policies and regulations and/or enforcement actions initiated thereunder; changes to MPLX's capital budget; other risk factors inherent to MPLX s industry; and the factors set forth under the heading "Risk Factors" in MPLX's Annual Report on Form 10-K for the year ended Dec. 31, 2015, and Quarterly Report on Form 10-Q for the quarter ended March 31, 2016, filed with the Securities and Exchange Commission (SEC). Factors that could cause MPC s actual results to differ materially from those implied in the forward-looking statements include: the time, costs and ability to obtain regulatory or other approvals and consents and otherwise consummate the strategic initiatives discussed herein; the satisfaction or waiver of conditions in the agreements governing the strategic initiatives discussed herein; our ability to achieve the strategic and other objectives related to the strategic initiatives discussed herein; adverse changes in laws including with respect to tax and regulatory matters; inability to agree with the MPLX conflicts committee with respect to the timing of and value attributed to assets identified for dropdown; risks described above relating to MPLX and the MPLX/MarkWest merger; changes to the expected construction costs and timing of projects; continued/further volatility in and/or degradation of market and industry conditions; the availability and pricing of crude oil and other feedstocks; slower growth in domestic and Canadian crude supply; the effects of the lifting of the U.S. crude oil export ban; completion of pipeline capacity to areas outside the U.S. Midwest; consumer demand for refined products; transportation logistics; the reliability of processing units and other equipment; MPC s ability to successfully implement growth opportunities; modifications to MPLX earnings and distribution growth objectives; compliance with federal and state environmental, economic, health and safety, energy and other policies and regulations, including the cost of compliance with the Renewable Fuel Standard, and/or enforcement actions initiated thereunder; changes to MPC s capital budget; other risk factors inherent to MPC s industry; and the factors set forth under the heading "Risk Factors" in MPC's Annual Report on Form 10-K for the year ended Dec. 31, 2015, filed with the SEC. In addition, the forward-looking statements included herein could be affected by general domestic and international economic and political conditions. Unpredictable or unknown factors not discussed here, in MPLX's Form 10-K or Form 10-Q or in MPC's Form 10-K could also have material adverse effects on forward-looking statements. Copies of MPLX's Form 10-K and Form 10-Q are available on the SEC website, MPLX's website at http://ir.mplx.com or by contacting MPLX's Investor Relations office. Copies of MPC's Form 10-K are available on the SEC website, MPC's website at http://ir.marathonpetroleum.com or by contacting MPC's Investor Relations office. Non-GAAP Financial Measures Adjusted EBITDA, distributable cash flow (DCF) and distribution coverage ratio are non-gaap financial measures provided in this presentation. Adjusted EBITDA and DCF reconciliations to the nearest GAAP financial measure are included in the Appendix to this presentation. Distribution coverage ratio is the ratio of DCF attributable to GP and LP unitholders to total GP and LP distributions declared. Adjusted EBITDA, DCF and distribution coverage ratio are not defined by GAAP and should not be considered in isolation or as an alternative to net income attributable to MPLX or MPC, net cash provided by operating activities or other financial measures prepared in accordance with GAAP. The EBITDA forecasts related to certain projects were determined on an EBITDA-only basis. Accordingly, information related to the elements of net income, including tax and interest, are not available and, therefore, reconciliations of these non-gaap financial measures to the nearest GAAP financial measures have not been provided.
Strategic Plan to Enhance Unitholder Value October 27, 2016 Announcement: Aggressive dropdown strategy* MPC plans to offer assets with ~$350 MM of annual EBITDA to MPLX by the end of 2017, including ~$235 MM by the end of 1Q 2017 Following these initial dropdowns and as soon as practicable, MPC expects to offer its remaining MLP-eligible EBITDA of $1 B to MPLX by the end of 2019 Evaluate strategic opportunities to highlight and capture the value of MPC s general partner interest in MPLX and optimize the partnership s cost of capital January 3, 2017 Update: Significantly accelerated dropdowns* MPLX expects to acquire assets with ~$1.4 B of annual EBITDA from MPC in 2017, including ~$250 MM by the end of 1Q 2017 MPLX expects to exchange newly issued LP units for MPC s economic interests in the GP, including IDRs, in conjunction with completion of dropdowns (expected in 2017) *Subject to market and other conditions and pending requisite approvals 3
MPLX Anticipates Dropdowns of ~$1.4 B of EBITDA from MPC As Soon As Practicable (Expected in 2017) Dropdown of ~$250 MM of annual EBITDA expected to close in first quarter 2017 Dropdown of ~$350 MM of annual EBITDA expected to close by the end of fourth quarter 2017 Dropdown of ~$800 MM of annual EBITDA, including the fuels distribution business expected to close in 2017 following receipt of tax clearance. If tax clearance is delayed for fuels distribution, then ~$200 MM would be dropped no later than the 1Q 2018 with the remainder dropped following receipt of tax clearance. ~$250 MM of EBITDA dropped ~$350 MM of EBITDA dropped 4Q16 1Q17 2Q17 3Q17 4Q17 1Q18 12/31/16 3/31/17 6/30/17 9/30/17 12/31/17 3/31/18 ~$800 MM of EBITDA dropped following receipt of tax clearance Note: All transactions subject to requisite approvals, market and other conditions, including tax and other regulatory clearances 4
MPC Assets Expected to be Acquired by MPLX in 2017 ~$1.4 B of Estimated Annual EBITDA Pipelines ~5,400 miles of additional pipelines (owns, leases or has an ownership interest) Marine Equity in 50/50 blue water JV with Crowley Terminals 61 light product; ~20 MMBBL storage; 187 loading lanes 18 asphalt; ~4 MMBBL storage; 68 loading lanes Utica investments (crude & condensate trucking and truck/barge terminals) Railcars Refineries Fuels Distribution 21 owned and 2,189 leased 793 general service; 1,102 high pressure; 315 open-top hoppers 59 MMBBL storage (tanks and caverns) 25 rail loading racks and 26 truck loading racks; 7 owned and 11 non-owned docks 2 condensate splitter investments 20 B gallons of fuels distribution volume at MPC/Speedway 5
Superior Fuels Distribution Business Model Services Model has Significant Advantages from Alternatives Services Model Marketing Model (Wholesale Distribution) Marketing Model (Rack-to-Retail) Business Description MPC outsources fuels marketing services to MPLX for those same services currently performed by MPC; generates revenue at MPLX Services performed for current MPC sales volumes Purchase MPC s marketing businesses Marketing costs incurred to generate revenues Exposure to daily margin volatility, credit risk and bankruptcy of marketing customers Precedents models purchase, market, and transport fuel from independent sellers to third party and related party entities Services performed for Speedway volumes Revenue Generation MPLX receives service fee (fixed) per gallon on fuels sold by MPC; not exposed to daily margin volatility Variable margin per gallon on fuels sold Fixed fee and/or margin (variable) per gallon Inventory MPLX has no fuel inventory risk or working capital cost Fuel inventory risk and working capital cost High volatility (requires leased/owned storage capacity) Precedent models may have fuel inventory risk and working capital costs MLP Qualifying Income No precedent models; pending IRS regulations and will likely require a private letter ruling Precedent models include portions of: Susser/Sunoco LP, Global Partners, Delek Logistics Precedent models include portions of: Susser/Sunoco LP, CrossAmerica Partners 6
Elimination of IDRs Significant Value to MPLX MPLX expects to exchange newly issued LP units for MPC s economic interests in the GP, including IDRs Expected to reduce MPLX s cost of capital Expected to enhance MPLX distribution growth MPC would continue to retain control of the GP following this exchange To be undertaken in conjunction with completion of dropdowns, with details of transaction to be announced following receipt of requisite approvals and tax clearance for all dropdowns (expected in 2017) Note: All transactions subject to requisite approvals, market and other conditions, including tax and other regulatory clearances 7
Financing of Acquisitions from MPC Dropdowns 50% debt and 50% equity, with equity financing to be funded through MPLX LP units issued to MPC at market price Expect valuation multiples consistent with recent industry precedents ranging from ~7.0x to ~9.0x EBITDA Elimination of IDRs Exchange of newly issued MPLX LP units for MPC s economic interests in the GP Expect transaction value of 15.0x 20.0x pro forma GP/IDR distributions Committed to maintaining investment grade credit profile The dropdown and IDR exchange transactions are achievable with pro forma net leverage <=4.0x Note: All transactions subject to requisite approvals, market and other conditions, including tax and other regulatory clearances 8
MPLX and MPC Interests are Aligned The combination of dropdowns and GP/IDR buy-in is anticipated to lower MPLX s cost of capital going forward Dropdowns enhance and provide greater visibility to distribution growth GP/IDR buy-in removes IDR burden and lowers equity cost of capital Large Cap MLP with balanced mix of earnings following dropdowns Majority of L&S segment EBITDA supported by contracts with MPC Diversified customer and basin exposure supporting G&P segment EBITDA MPC as sponsor has interests aligned with MPLX LP unitholders MPC will own the general partner and a majority of MPLX LP units, completely aligning interests toward continuing MPLX distribution growth and managing MPLX to be competitive and attractively valued MPLX assets are integral to MPC s operations Note: All transactions subject to requisite approvals, market and other conditions, including tax and other regulatory clearances 9
About MPLX Growth-oriented, diversified MLP with high-quality, strategically located assets with leading midstream position Two primary businesses Logistics & Storage includes transportation and storage of crude oil, refined products and other hydrocarbon-based products Gathering & Processing includes gathering, processing, and transportation of natural gas and the gathering, transportation, fractionation, storage and marketing of NGLs Investment grade credit profile with strong financial flexibility MPC as sponsor has interests aligned with MPLX MPLX assets are integral to MPC Growing stable cash flows through continued investment in midstream infrastructure As of September 30, 2016 See appendix for legend 10
Logistics & Storage Segment Overview High-quality, well-maintained assets that are integral to MPC 1,008 miles of common carrier crude oil pipelines 1,900 miles of common carrier product pipelines Barge dock with approximately 78,000 BPD throughput capacity Four tank farms with approximately 4.5 MM barrels of available storage capacity Butane cavern with 1 MM barrels of available storage capacity 18 towboats and 205 tank barges moving light products, heavy oils, crude oil, renewable fuels, chemicals and feedstocks Stable cash flows with fee-based revenues and minimal direct commodity exposure 11
Executing a Comprehensive Utica Strategy Phased infrastructure investment Cornerstone Pipeline commenced operations on time and under budget Hopedale pipeline connection completed December 2016 Utica build-out mid-2017 estimated completion Links Marcellus and Utica condensate and natural gasoline with Midwest refiners Allows diluent movements to Canada Leverages existing MPC/MPLX pipelines and right of way Budgeted investments ~$255 MM ~$40 MM annual EBITDA 12
Equity Participation in Bakken Pipeline System Announced agreement to participate in the Dakota Access Pipeline (DAPL) and the Energy Transfer Crude Oil Pipeline (ETCOP) projects, collectively referred to as the Bakken Pipeline System Expected MPLX investment of $500 MM, subject to closing conditions Estimated to deliver ~470 MBPD from the Bakken/Three Forks production area to the Midwest and Gulf Coast Source: Enbridge 13
Gathering & Processing Segment Overview Raw Natural Gas Production Gathering and Compression Processing Plants Mixed NGLs Fractionation Facilities NGL Products Ethane Propane Normal Butane Isobutane Natural Gasoline One of the largest NGL and natural gas midstream service providers Gathering capacity of 5.5 Bcf/d 50% Marcellus/Utica; 50% Southwest Processing capacity of 7.6 Bcf/d* ~70% Marcellus/Utica; ~20% Southwest C2 + Fractionation capacity of 500 MBPD** ~90% Marcellus/Utica Primarily fee-based business with highly diverse customer base and established long-term contracts *Includes processing capacity of non-operated joint venture **Includes condensate stabilization capacity 14
The Marcellus/Utica Resource Play is the Leading U.S. Natural Gas Growth Play Rest of U.S. Billion Cubic Feet per Day (Bcf/d) 67 65 63 61 59 57 Marcellus & Utica account for over 25% of total U.S. Gas Supply Marcellus & Utica Rest of U.S. 55 3 Dec-09 Dec-10 Dec-11 Dec-12 Dec-13 Dec-14 Dec-15 Dec-16 27 23 19 15 11 7 Marcellus & Utica Billion Cubic Feet per Day (Bcf/d) Note: Wellhead gas production (before flaring and NGL extraction) Sources: As of December 29, 2016. Bloomberg (PointLogic Energy /LCI Energy Insight Estimates) 15
Gathering & Processing Marcellus & Utica Operations Houston Complex Sherwood Complex Hopedale Complex 2.8 5.5 417 25 0 Bcf/d Gathering capacity Bcf/d Processing capacity MBPD C2+ Fractionation capacity MBPD Cond. Stabilization capacity 16
Gathering & Processing Marcellus & Utica Operations Processed volumes averaged over 4.3 Bcf/d in 3Q 2016 2016: Processed volumes expected to increase ~15% over prior year Gathered volumes expected to increase ~20% over prior year 2017: Processed volumes expected to increase ~10% to ~15% over prior year Gathered volumes expected to be flat over prior year Area Processed Volumes Available Capacity (MMcf/d) (a) Average Volume (MMcf/d) Utilization (%) Marcellus 4,155 3,273 79% Houston 555 467 84% Majorsville 1,070 778 73% Mobley 920 701 76% Sherwood 1,200 1,069 89% Keystone 410 258 63% Utica 1,325 1,050 79% Cadiz 525 487 93% Seneca 800 563 70% 3Q 2016 Total 5,480 4,323 79% 2Q 2016 Total 5,215 4,106 79% (a) Based on weighted average number of days plant(s) in service. Excludes periods of maintenance 17
Gathering & Processing Marcellus & Utica Fractionation 2016 fractionated volumes expected to increase ~30% over prior year 2017 fractionated volumes expected to increase ~15% to ~20% over prior year Area Fractionated Volumes Available Capacity (MBPD) (a) Average Volume (MBPD) Utilization (%) 3Q16 Total C3+ 227 189 83% 3Q16 Total C2 190 126 66% 2Q16 Total C3+ 227 176 78% 2Q16 Total C2 182 116 64% (a) Based on weighted average number of days plant(s) in service. Excludes periods of maintenance 18
Gathering & Processing Southwest Operations Hidalgo Complex Carthage Complex Buffalo Creek Complex Javelina Complex 2.7 1.5 29 1.4 0 Bcf/d Gathering capacity Bcf/d* Processing capacity MBPD C2+ Fractionation capacity Bcf/d *Includes 40% of processing capacity through the Partnership s Centrahoma Joint Venture Transmission capacity 19
Gathering & Processing Southwest Operations 2016: Processed volumes expected to increase ~15% over prior year Gathered volumes expected to increase ~2% over prior year 2017: Processed volumes expected to increase ~3% to ~8% over prior year West Texas (Delaware Basin) and Western Oklahoma (STACK) to support majority of increase Gathered volumes expected to be flat over prior year Area Processed Volumes Available Capacity (MMcf/d) (a) Average Volume (MMcf/d) Utilization (%) West Texas (b) 200 168 84% East Texas 600 514 86% Western OK 425 346 81% Southeast OK (c) 120 120 100% Gulf Coast 142 105 74% 3Q 2016 Total 1,487 1,253 84% 2Q 2016 Total 1,383 1,092 79% (a) Based on weighted average number of days plant(s) in service. Excludes periods of maintenance (b) West Texas is comprised of the Hidalgo plant in the Delaware Basin (c) Processing capacity includes Partnership s portion of Centrahoma JV and excludes volumes sent to third parties 20
2017 Organic Growth Capital Forecast $1.2 to $1.6 B Gathering & Processing Projects Shale Resource Capacity Est. Completion Date Logistics & Storage Projects Est. Completion Date Rich- and Dry-Gas Gathering (a) Western Oklahoma - STACK Rich-Gas and Oil Gathering Marcellus and Utica N/A Ongoing Cana Woodford N/A Ongoing Utica Infrastructure Build-out Mid-2017 Robinson Butane Cavern 2018 Texas City Tank Farm 2018 Hopedale III C3+ Fractionation and NGL logistics (b) Marcellus and Utica 60,000 Bbl/d 1Q17 Sherwood VII Processing Plant Marcellus 200 MMcf/d 2Q17 Keystone C2 Fractionation Marcellus 20,000 Bbl/d 3Q17 Sherwood VIII Processing Plant Marcellus 200 MMcf/d 4Q17 Majorsville II C2 Fractionation Marcellus 40,000 Bbl/d 4Q17 NGL Pipeline Expansions Marcellus N/A 2017 and 2018 Majorsville VII Processing Plant Marcellus 200 MMcf/d 2018 Harmon Creek Processing Plant Marcellus 200 MMcf/d 2018 Harmon Creek C2 Fractionation Marcellus 20,000 Bbl/d 2018 Cadiz IV Processing Plant (c) Utica 200 MMcf/d 2018 (a) Utica Rich-Gas Gathering is a joint venture between MarkWest Utica EMG s and Summit Midstream LLC. Dry-Gas Gathering in the Utica Shale is completed through a joint venture with MarkWest and EMG (b) MarkWest and MarkWest Utica EMG shared fractionation capacity (c) MarkWest Utica EMG Joint Venture 21
Focus on Solutions to Enhance Northeast NGL Market Lead the development of infrastructure to link supply of Northeast NGLs with market demand and enhance value for producer customers Ethane Propane Largest fully integrated de-ethanization system in Marcellus and Utica shales Access to all major takeaway pipelines: ATEX, Mariner East and Mariner West Well-positioned to support development of potential steam crackers in Northeast Supporting the next phase of NGL marketing with unit train deliveries from the region Progressing infrastructure options to move propane to East Coast and Gulf Coast markets Butanes Exploring long-term butane-to-alkylate project to create additional in-basin demand Natural gasoline Cornerstone and Utica build-out projects critical to delivery of natural gasoline to Midwest refinery markets and Western Canada 22
MPLX Northeast Operations Well-Positioned in Ethane Market Ethane demand growing as exports and steam cracker development continues in Gulf Coast and Northeast MPLX well-positioned to support producer customers rich-gas development with extensive distributed de-ethanization system Based on current utilization, MPLX can support the production of an additional ~70 MBPD of purity ethane with existing assets Opportunity to invest $500 MM to $1 B to support Northeast ethane recovery over the next five years Seneca Ohio Harmon Creek Cadiz Pennsylvania Majorsville Mobley Sherwood West Virginia Houston Keystone MPLX De-ethanization Facility MPLX Processing Complex MPLX Planned De-ethanization Facility Steam Cracker Planned Steam Cracker Proposed MPLX Ethane Pipeline ATEX Pipeline Mariner West Pipeline Mariner East 1 Pipeline 23
Strong Financial Flexibility to Manage and Grow Asset Base Committed to maintaining investment grade credit profile Completed a $1 B private placement of convertible preferred securities with third-party investors in 2Q 2016 Completed ~$500 MM of opportunistic ATM issuances through the first nine months of 2016 ($MM except ratio data) As of 9/30/16 Cash and cash equivalents 208 Total assets 16,415 Total debt 4,412 Redeemable preferred units 1,000 Total equity 10,154 Consolidated total debt to LTM pro forma adjusted EBITDA ratio (a) 3.5x Remaining capacity available under $2.0 B revolving credit agreement 1,997 Remaining capacity available under $500 MM credit agreement with MPC (a) Calculated using face value total debt and last twelve month pro forma Adjusted EBITDA, which is pro forma for acquisitions and excludes impairments. Face value total debt includes approximately $439 MM of unamortized discount and approximately $7 MM of unamortized debt issuance costs as of September 30, 2016. 500 24
MPLX Long-Term Value Proposition for Investors and Stakeholders Underlying assets are of high quality and serve some of the most prolific basins in the U.S. Diverse revenue stream with long-term fee-based contracts Robust portfolio of high-return strategic opportunities benefiting producer customers and overall energy infrastructure build-out Strong sponsor with aligned interests Optimization of the partnership s cost of capital Significant portfolio of MLP-qualifying assets expected to be offered by end of 2017 Well-positioned to continue delivering attractive returns over the long term 25
Appendix 26
MPLX and MPC are Aligned MPLX Organizational Structure 2% GP interest Marathon Petroleum Corporation and Affiliates (NYSE: MPC) 100% interest 22% Public LP interest Preferred Common Class B MPLX GP LLC (our General Partner) MPLX LP* (NYSE: MPLX) (the Partnership ) r 76% LP interest MPC views MPLX as integral to its operations and is aligned with its success and incentivized to grow MPLX MPC owns 22% LP interest and 100% of MPLX s GP interest and IDRs MPLX Operations LLC 100% interest MarkWest Energy Partners, L.P. 100% interest 100% interest Hardin Street Marine LLC MPLX Pipe Line Holdings LLC MPLX Terminal and Storage LLC MarkWest Hydrocarbon, L.L.C. MarkWest Operating Subsidiaries As of Sept 2, 2016 *Preferred convertible securities are included with the public ownership percentage and depicted on an as-converted basis. All Class B units are owned by M&R MWE Liberty, LLC and included with the public ownership percentage and depicted on an as-converted basis. 27
Gathering & Processing Contract Structure Durable long-term partnerships across leading basins Marcellus Utica Southwest Resource Play Marcellus, Upper Devonian Utica Haynesville, Cotton Valley, Woodford, Anadarko Basin, Granite Wash, Cana-Woodford, Permian, Eagle Ford Producers 14 including Range, Antero, EQT, CNX, Noble, Southwestern, Rex and others 10 including Antero, Gulfport, Ascent, Rice, Rex, PDC and others 140 including Anadarko, Newfield, Devon, BP, Chevron, PetroQuest and others Contract Structure Long-term agreements initially 10-15 years, which contain renewal provisions Long-term agreements initially 10-15 years, which contain renewal provisions Long-term agreements initially 10-15 years, which contain renewal provisions Volume Protection (MVCs) 65% of 2017 capacity contains minimum volume commitments 25% of 2017 capacity contains minimum volume commitments 15% of 2017 capacity contains minimum volume commitments Area Dedications 4 MM acres 3.9 MM acres 1.4 MM acres Inflation Protection Yes Yes Yes 28
Logistics & Storage Contract Structure Fee-based assets with minimal commodity exposure (c) MPC has historically accounted for over 85% of the volumes shipped on MPLX s crude and product pipelines 100% of the volumes transported via MPLX s inland marine vessels MPC has entered into multiple long-term transportation and storage agreements with MPLX Terms of up to 10 years, beginning in 2012 Pipeline tariffs linked to FERC-based rates Indexed storage fees Fee-for-capacity inland marine business 2015 Revenue Customer Mix 23% 8% $130 MM (a,b) $47 MM 69% MPC Commited MPC Additional Third Party MPC = 92% $400 MM Notes: (a) Includes revenues generated under Transportation and Storage agreements with MPC (excludes marine agreements) (b) Volumes shipped under joint tariff agreements are accounted for as third party for GAAP purposes, but represent MPC barrels shipped (c) Commodity exposure only to the extent of volume gains and losses 29
U.S. Natural Gas and NGL Trade Flows Changing 2000 2020 Paradigm shift from U.S. Northeast being a significant importer to a significant exporter Driven by Marcellus and Utica production growth Infrastructure continuing to build out to reflect changes in trade flows 30
Northeast Operations Well-Positioned to Access All Major NGL Markets* Edmonton Markets Mid-Con Markets Gulf Coast Markets Midwest Markets Ontario Markets Northeast Operations MPLX 2016 NGL Marketing by Transport Distribution by Rail Distribution by Pipeline Distribution by Truck Mid-Atlantic Markets Northeast Markets Chesapeake Terminal 60% - 65% 30% - 35% 5% - 10% Access to all major NGL markets in the U.S. and the world Key takeaway solutions underway such as Utica infrastructure build-out, Mariner East 2 and additional projects Northeast exports are geographically and structurally advantaged to Europe and parts of South America MPLX developing a comprehensive export solution for producers *Excludes ethane 31
Northeast Operations Well-Positioned in Ethane Market Gulf Coast Markets Distribution by Pipeline Mariner West Ontario Markets Northeast Operations Mariner East Exports Operate 190 MBPD of de-ethanization capacity in the Marcellus & Utica shales Produced 126 MBPD of purity ethane in 3Q 2016, a 78% increase from prior year quarter Supply ethane to multiple locations including Canadian, Gulf Coast and international markets Satisfy demand from new large-scale ethane crackers 32
MPLX s Commodity Price Sensitivities 90% fee-based net operating margin, 10% commodity exposed for 2017 Maintain active hedging program and have currently hedged ~30% of our 2017 commodity exposure Annual 2017 sensitivities to commodity price changes (assumes no hedges): Product Commodity Price Change Annual DCF Impact Natural Gas Liquids (Mont Belvieu) $.05 per weighted average gallon (a) ~$18 MM Crude Oil (WTI) $1 per barrel ~$1 MM Natural Gas (Henry Hub) $.50 per MMbtu <$1 MM NOTE: Net Operating Margin is calculated as segment revenue less purchased product costs less realized derivative gains (losses). (a) The composition is based on MPLX s average projected barrel of approximately: Ethane: 35%, Propane: 35%, Iso-Butane: 6%, Normal Butane: 12%, Natural Gasoline: 12%. 33
Forecast 12-15% distribution growth in 2017; double-digit distribution growth in 2018 2016 Forecast: Financial Measure 2016 Forecast Net Income (a) Adjusted EBITDA (b) Net cash provided by operating activities Distributable Cash Flow (b) $140 MM - $240 MM $1.3 B - $1.4 B $1.1 B - $1.2 B $1.0 B - $1.1 B Distribution Growth Rate (c) 12% - 15% Organic Growth Capital Expenditures (d) $1.1 B - $1.2 B (a) Guidance includes impairment charges of $89 MM related to an equity method investment and $130 MM related to goodwill established in connection with the MarkWest merger. (b) Non-GAAP measure calculated before the distribution to preferred units and excluding impairment charges related to an equity method investment and goodwill. See reconciliation in appendix. (c) Full year distribution growth rate. (d) Excludes non-affiliated JV members' share of capital expenditures. 34
MPLX s 2016 Forecast - Reconciliation Adjusted EBITDA and Distributable Cash Flow from Net Income ($MM) Low High Net income 140 240 Plus: Depreciation and amortization 540 540 Impairment expense (a) 130 130 Net interest and other financial costs 220 220 Adjustment for equity investment earnings & distributions (b) 215 215 Other 58 58 Adjusted EBITDA 1,303 1,403 Less: Adjusted EBITDA attributable to noncontrolling interests 3 3 Adjusted EBITDA attributable to MPLX LP 1,300 1,400 Less: Net interest and other financial costs 220 220 Maintenance capital 60 60 Other 20 20 Distributable cash flow attributable to MPLX LP 1,000 1,100 Less Preferred unit distributions 41 41 Distributable cash flow available to GP and LP unitholders 959 1,059 (a) Includes a pretax, non-cash goodwill impairment charge. (b) Includes a pretax, non-cash impairment of $89 MM related to an equity method investment. 35
MPC s Fully Integrated Downstream System As of September 30, 2016 Refining and Marketing Seven-plant refining system with ~1.8 MMBPCD capacity One biodiesel facility and interest in three ethanol facilities One of the largest wholesale suppliers in our market area One of the largest producers of asphalt in the U.S. ~5,400 Marathon Brand retail outlets across 19 states Owns/operates 61 light product terminals and 18 asphalt terminals, while utilizing third-party terminals at 120 light product and two asphalt locations 2,210 owned/leased railcars, 173 owned transport trucks Speedway ~2,770 locations in 22 states Second largest U.S. owned/operated c-store chain Midstream Owns, leases or has interest in ~8,400 miles of crude and refined product pipelines 18 owned inland waterway towboats with ~205 owned barges and 14 leased barges Owns/operates over 5,500 miles of gas gathering and NGL pipelines Owns/operates 54 gas processing plants, 13 NGL fractionation facilities and two condensate stabilization facilities Marketing Area MPC Refineries Light Product Terminals MPC owned and Part-owned Third Party Asphalt/Heavy Oil Terminals MPC Owned Third Party Water Supplied Terminals Coastal Inland Pipelines MPC Owned and Operated MPC Interest: Operated by MPC MPC Interest: Operated by Others Pipelines Used by MPC Renewable Fuels Ethanol Facility Biodiesel Facility Tank Farms Butane Cavern MarkWest Facility Pipelines Barge Dock 36