Investor Presentation January 2019

Investor Presentation January 2019

Company Information NYSE Ticker NGL Energy Partners LP Contact Information Corporate Headquarters NGL Energy Partners LP 6120 South Yale Avenue, Suite 805 Tulsa, Oklahoma 74136 Website www.nglenergypartners.com Investor Relations Contact us at (918) 481-1119 or e-mail us at NGL Unit Price (1) $ 10.56 Market Capitalization (1)(2) $ 1.74 Billion Enterprise Value (1)(2) $ 4.16 Billion Yield (1) 14.77% InvestorInfo@nglep.com Forward Looking Statements This presentation includes forward looking statements within the meaning of federal securities laws. All statements, other than statements of historical fact, included in this presentation are forward looking statements, including statements regarding the Partnership s future results of operations or ability to generate income or cash flow, make acquisitions, or make distributions to unitholders. Words such as anticipate, project, expect, plan, goal, forecast, intend, could, believe, may and similar expressions and statements are intended to identify forward-looking statements. Although management believes that the expectations on which such forward-looking statements are based are reasonable, neither the Partnership nor its general partner can give assurances that such expectations will prove to be correct. Forward looking statements rely on assumptions concerning future events and are subject to a number of uncertainties, factors and risks, many of which are outside of management s ability to control or predict. If one or more of these risks or uncertainties materialize, or if underlying assumptions prove incorrect, the Partnership s actual results may vary materially from those anticipated, estimated, projected or expected. Additional information concerning these and other factors that could impact the Partnership can be found in Part I, Item 1A, Risk Factors of the Partnership s Annual Report on Form 10-K for the year ended March 31, 2018 and in the other reports it files from time to time with the Securities and Exchange Commission. Readers are cautioned not to place undue reliance on any forward-looking statements contained in this presentation, which reflect management s opinions only as of the date hereof. Except as required by law, the Partnership undertakes no obligation to revise or publicly update any forward-looking statement. (1) Market Data and Unit Count as of 1/11/2018. (NGL-PB ticker for Class B Preferred Units) (2) Balance Sheet Data as of 9/30/2018, Market Capitalization and Enterprise Value include Preferred Equity 2

NGL Energy Partners LP Overview 3

Segment Business Contribution Overview Crude Logistics Purchases and transports crude oil for resale to pipeline injection points, storage terminals, barge loading facilities, rail facilities, refineries and other trade hubs Provides transportation, terminaling, and storage of crude oil and condensate to third parties for a fixed-fee per barrel Long term, take-or-pay contracts on Grand Mesa Pipeline Water Solutions Provides services for the treatment, processing, and disposal of wastewater and solids generated from oil and natural gas production Revenue streams from the disposal of wastewater and solids, transportation of water through pipelines, truck and frac-tank washouts, and sales of recovered hydrocarbons and freshwater Refined Products/ Renewables Purchase refined petroleum products primarily in the Gulf Coast, Southeast, and Midwest regions of the United States and schedule them for delivery primarily on the Colonial, Plantation, Magellan and NuStar pipelines Sell our products to commercial and industrial end users, independent retailers, distributors, marketers, government entities, and other wholesalers Purchase unfinished gasoline blending components for subsequent blending into finished gasoline to supply our marketing business as well as third parties Liquids Transports, stores, and markets NGLs to and from refiners, gas processors, propane wholesalers, propane retailers, proprietary terminals, petrochemical plants, diluent markets and other merchant users of NGLs Large provider of butane to refiners for gasoline blending Utilizes underground storage to take advantage of seasonal demand Note: On July 10 th 2018, NGL Energy Partners LP announced that it closed the previously announced transaction to sell the remainder of its Retail Propane Business. See press release on NGL Energy Partners website 4

Business Diversity NGL LOGO Crude Logistics Water Solutions Refined Products/ Renewables Liquids Primary Drivers: Crude Oil Production and Transportation/ Storage Demand Water Volumes, Rig Count and Crude Oil Price Motor Fuels Supply/Demand and Basis Differentials Butane Blending, Weather and NGL Production Benefits From: Higher Prices Higher Prices Lower Prices Lower Prices Targeted EBITDA Contribution %: 35% 40% 10%-15% 10%-15% With the sale of its Retail Propane assets, NGL is making a strategic shift in its business which positions the Partnership to focus on, and reinvest in, Crude Logistics and Water Solutions, its two best performing and largest growth platforms 5

Diversified Across Multiple Businesses and Producing Basins Bakken Shale Marcellus Shale Green River Basin Pinedale Anticline DJ Basin Jonah Field Niobrara Shale Wattenberg Field Mississippi Lime Granite Wash Permian Basin NGL Owned/Leased Assets NGL Assets Water Services NGL Utilized Assets Common Carrier Propane Pipelines Colonial Products Pipeline Santa Fe Products Pipeline Magellan Products Pipeline NuStar Products Pipeline Eagle Ford NGL Rack Marketing Terminal NGL Gas Blending Terminal TransMontaigne Terminal NGL Renewable Marketing Terminal NuStar Energy Terminal Basins Assets and Marketing Presence Crude Barges and Tug Boats Crude Oil Logistics NGL Crude Terminal Grand Mesa Pipeline 6

NGL Operational Assumptions Business Strategy Build a Diversified Vertically Integrated Energy Business Transport crude oil from the wellhead to refiners Wastewater from the wellhead to treatment for disposal, recycle or discharge Natural Gas Liquids from fractionators / hubs to refineries and end users Refined Products from refiners to customers Achieve Organic Growth by Investing in New Assets Projects that increase volumes, enhance our operations and generate attractive rates of return Accretive organic growth opportunities that originate from assets we own and operate Invest in existing businesses such as crude oil logistics and water solutions which provide high quality, fee based revenues Accretive Growth through Strategic Acquisitions Build upon our vertically integrated business Scale our existing operating platforms Enhance our geographic diversity Continue our successful track record of acquiring companies and assets at attractive prices Focus on Businesses that Generate Long- Term Fee Based Cash Flows Focus on long-term, fee based contracts and back-to-back transactions that minimize commodity price exposure Increase cash flows that are supported by certain fee-based, multi-year contracts that include acreage dedications or volume commitments Disciplined Capital Structure Target leverage levels that are consistent with investment grade companies Maintain sufficient liquidity to manage existing and future capital requirements and take advantage of market opportunities Prudent distribution coverage to manage commodity cycles and fund growth opportunities 7

Operating Segments 8

Crude Logistics Platform Our Crude Oil Logistics segment purchases crude oil from producers and transports it to refineries or for resale at pipeline injection stations, storage terminals, barge loading facilities, rail facilities, refineries, and other trade hubs, and provides storage, terminaling, trucking, marine and pipeline transportation services through its owned assets Grand Mesa Pipeline Crude Assets Crude Transportation Crude Marketing ~550 miles of 20 Crude oil pipeline from the DJ Basin to Cushing, OK 150,000 BPD capacity 16 total truck unloading bays Own 6 storage terminal facilities 3.6 MMbbls of storage in Cushing 1.7 MMbbls of storage in addition to Cushing Own 10 tow boats, 22 barges with >25Mbbls per barge capacity 797 GP railcars leased or owned 163 owned trucks and 260 owned trailers Operations are centered near areas of high crude oil production, such as the Bakken, DJ, Permian, Eagle Ford, Anadarko, STACK, SCOOP, Granite Wash, Mississippi Lime, and southern Louisiana at the Gulf of Mexico 970,000 BBL origin tankage 27 LACT units NGL Cushing Crude Oil Storage Tanks 4 NGL Crude Logistics Tows 9

Segment Grand Mesa Contribution Pipeline Grand Mesa Share of Capacity ~550 miles of 20 Crude oil pipeline from the DJ Basin to Cushing, OK NGL/Grand Mesa have 37.5% undivided joint interest 150,000 BPD capacity DJ Basin Origin Station Terminals Lucerne & Riverside Terminals in Weld County, CO 16 total truck unloading bays capable of unloading over 325 trucks per day in aggregate 970,000 BBL origin tankage Niobrara Shale Wattenberg Field Batching Capabilities Gathering Connectivity Grand Mesa offers two unique batching specs allowing producers to preserve their crude oil quality The Lucerne origin has inbound receipt connections to multiple gathering systems including: Platte River Midstream Saddle Butte Pipeline Noble Midstream NGL Crude Terminal Grand Mesa Pipeline Cushing Storage Destination Terminal NGL s Cushing Terminal has 3.6 million barrels of total shell capacity Offers producers connectivity to multiple markets including the Gulf Coast via TransCanada Marketlink Financial Guidance Total volumes for FY19 expected to average ~115kbpd Average remaining contract term on the pipeline is approximately 7 years = Lucerne & Riverside = Platteville Source: Current rig locations denoted by a black rig icon and the heat map represents permit activity in the last 180 days with permits denoted as dots based on data from DrillingInfo as of 8/7/18 10

Segment Crude Oil Contribution Logistics Crude WTI Spot Price Area of Operation $100 $80 $60 $40 $20 $- 12/31/2015 12/31/2016 12/31/2017 12/31/2018 Grand Mesa Pipeline FY 2019 Forecast Assumptions Total volumes average ~115kbpd Crude Assets Cushing market rates reduced with no assumed Contango Glass Mountain Sale in FY 2018 Crude Oil Marketing/Transportation Three new tow boats are put into service (1 every three months starting in June) Assumed Crude Price forward curve April 1, 2018 March 31, 2019 ($64.56-$59.63) $200 $160 $120 $80 $40 $- Adjusted EBITDA (In Millions) $165-175 $118 $12 $73 $61 $59 $13 $11 $107 $28 $48 $48 FY 2014 FY 2015 FY 2016 FY 2017 FY 2018 FY 2019E Glass Mountain Crude Oil Logistics 11

Water Solutions Platform Our Water Solutions segment provides services for the treatment and disposal of wastewater generated from crude oil and natural gas production and for the disposal of solids such as tank bottoms, drilling fluids and drilling muds and performs truck and frac tank washouts. In addition, our Water Solutions segment sells the recovered hydrocarbons that result from performing these services as well as freshwater Water Disposal Recycling & Freshwater Solids Solutions Water Pipelines ~134 completed SWD wells with over 3.2 million BPD of total capacity spanning: Pinedale Anticline (WY) DJ (CO) Eagle Ford (TX) Midland (TX) Delaware (TX) 24x7 operations at most locations 1 water recycling facilities with 65,000 BPD of total capacity Recycling opportunities in Delaware Basin Over 60 million barrels of water recycled and discharged since inception 11.6 million barrels per year of freshwater rights in New Mexico 23 million barrels per year of freshwater capacity in Texas 8 solids disposal facilities with 60,000 BPD of total capacity in Texas 2 solids facilities in Colorado Solids Processing Facility (C6) Solids Slurry Injection (C9) Provides producers with in-field disposal alternative for Gels, High Solids Content Water, Water and Oil-Based Mud, and Tank Bottoms 2 landfill facilities in permitting stages in New Mexico ~100 miles of water pipelines owned by NGL plus > 75 miles under development ~100 miles of water pipelines owned by producers Currently disposing of > 404,000 BPD of wastewater via pipelines (both NGL and producer owned) Provides producers with in-field disposal alternative for Gels, High Solids Content Water, Water and Oil-Based Mud, and Tank Bottoms generated from oil and natural gas production and drilling activities NGL saltwater disposal facility with solids processing capacity Note: Includes FY2019 Q1 Acquisitions and South Pecos assets 12

South Pecos Water Disposal Divestiture Highlights Transaction Highlights Represents continued progress towards NGL s capital allocation strategy Cash proceeds of $238.8 million at closing plus additional consideration upon meeting certain criteria Proceeds will be used to reduce outstanding indebtedness, improve compliance leverage to under 3.0x (1) by fiscal year-end and enhance liquidity NGL continues to focus on a self-funding model for growth opportunities as well as reducing overall leverage Asset Map Central Reeves 4 Central Reeves 3 Central Reeves Central Reeves 5 Barstow Pecos Highway 17S Pecos 2 Ranger Pecos South Pecos 3 REEVES COUNTY Pyote WARD COUNTY Supports NGL's ongoing strategy in the northern Delaware Allows NGL to focus more fully on high return opportunities around our consolidated and growing position in the TX / NM state-line area Recently acquired a large land position in the northern Delaware, where NGL is developing additional disposal facilities and significant pipeline infrastructure Continue to own and operate over 1MMBbls/d of permitted disposal capacity in the Delaware Basin following the transaction Toyah 4 Toyah 8 Toyah 6 Toyah 7 PECOS COUNTY Legend In-Service Approved Permit Pending Permit Producer E to Pecos Pipeline Central Reeves to Pecos Pipeline Producer Pipeline County Line Major Highways, Major Roads Note: Expected to close Q4 FY2019 (1) Assumes FY19 Public Guidance and all proceeds are utilized to repay compliance debt prior to 3/31/19 13

Delaware Basin Characteristics Salt Water Disposal Facilities & Disposal Wells Water Pipelines NGL has 34 Salt Water Disposal Facilities & 50 Disposal Wells in-service 31 Facilities in Texas and 3 in New Mexico NGL has 1 Solids Disposal Facilities in-service at its Orla Facility NGL has 45 pipeline tie-ins currently in-service Pipelines (owned and third party) are moving ~265k bpd in the basin >50 miles of owned water pipelines in-service ~75 miles of water pipeline projects in progress at various stages of development Includes trunk line from Carlsbad, New Mexico to North of Pecos, Texas (Western Express) Sample of Delaware Customers Crude Crude Oil Production in the Delaware Basin reached 43.7 Production (1) million BBLs (~1.5mm bpd) in April 2018 Market Produced Water to Crude Ratio of Approximately 4 to 1 Dynamics (1) Total Water Disposal Market of ~6.0mm bpd (based on April 2018 crude production and water to crude ratio) Water Disposal Market still very fragmented Continue to see robust produced and flow back water demand Demand expected to increase with production Capital Focus NGL invested ~$235 million in acquisitions YTD thru 9/30/18 in Fiscal Year 2019 NGL invested ~$100 million in Delaware Basin organic projects YTD thru 9/30/18 in Fiscal Year 2019 Expected return of 5x or better on acquisitions and organic projects Note: Includes FY2019 Acquisitions and South Pecos assets (1) Delaware Basin Production Statistics by County per DrillingInfo Data as of 11/8/18 14

Delaware Basin SWD Facilities & Pipelines Acquisition of ~122,000 acres through the purchase of the Beckham and McCloy ranches, including locations for over 20 saltwater disposal wells and 11.6 million barrels of annual fresh water rights in New Mexico Expands service offerings to producers with capabilities to provide fresh water, recycling and treatment, cuttings landfill disposal, and produced water disposal in Eddy and Lea Counties Total cost of the acquisitions was approximately $93 million with an estimated full year run-rate Adjusted EBITDA contribution of $18 million Note: Includes FY2019 Q1 Acquisitions and South Pecos assets 15

Segment Water Solutions Contribution U.S Oil Rig Count (1) Area of Operation 500 400 300 200 100 0 12/31/2015 12/31/2016 12/31/2017 12/31/2018 Permian Basin Eagle Ford Basin DJ Basin FY 2019 Forecast Assumptions Adjusted EBITDA (In Millions) Primary growth focused in Permian (Delaware) and DJ basins Average skim oil percentage forecasted at 0.37% for each disposal volume Assumed Crude Price forward curve April 1, 2018 March 31, 2019 ($64.56-$59.63), further adjusted for Differentials and Hedges Pipelines, Solids disposal, Washouts, and other service revenues increase with volumes $300 $200 $100 $68 $126 $72 $63 $117 $180-200 Growth capital and planned acquisitions adds several new facilities and disposal wells to existing footprint ~$235 million in acquisitions ~$240-265 million in organic growth capex $- FY 2014 FY 2015 FY 2016 FY 2017 FY 2018 FY 2019E Note: Includes FY2019 Q1 Acquisitions and South Pecos assets (1) Baker Hughes as of December 2018. 16

NGL Liquids Platform Our Liquids segment provides natural gas liquids procurement, storage, transportation, and supply services to customers through assets owned by us and third parties. We also sell butanes and natural gasolines to refiners and producers for use as blending stocks and diluent and assist refineries by managing their seasonal butane supply needs Propane/Butane Wholesale NGL Terminals Sawtooth Office locations in Denver, Chicago, Calgary, Houston, Tulsa Fleet of ~4,300 railcars 28 transloading units 400 Customers Shipper on 5 common carrier pipelines Approximately 2.8 million barrels of leased underground storage, 0.35 million barrels of above ground storage 19 Terminals with throughput capacity of ~11.3 million gallons per day 10 terminals with rail unloading capability 4 Multi-products terminals 9 Pipe-connected terminals 5 Caverns ~6.0 million barrels of butane and propane storage capacity in Utah Newly created JV structure to store refined products Railcar Rack NGL Thackerville Liquids Terminal West Memphis NGL Wholesale Liquids Terminal 17

Segment Liquids Contribution Heating Degree Days Area of Operation FY 2019 Forecast Assumptions Adjusted EBITDA (In Millions) Propane/Butane Wholesale Assumes a normal winter (5-year average of HDD) Assumes butane blending economics are better for refiners than FY 2018 NGL Terminals Results are determined by propane demand Sawtooth Newly created JV structure with additional commercial development drive Additional rights to store refined products $150 $100 $50 $- $87 $93 $101 $64 $50 $60-75 FY 2014 FY 2015 FY 2016 FY 2017 FY 2018 FY 2019E 18

Refined Products & Renewables Platform Our Refined Products and Renewables segment conducts gasoline, diesel, ethanol, and biodiesel marketing operations. In addition, in certain storage locations, our Refined Products and Renewables segment may also purchase unfinished gasoline blending components for subsequent blending into finished gasoline to supply our marketing business as well as third parties Southeast Gas Blending Rack Marketing and Other Line Space on Colonial and Plantation pipelines Long-term Lease of TLP SE Terminals along Colonial and Plantation Pipelines Approximately 7.0 million barrels of storage capacity TLP-Collins Storage facility in Collins, MS 1.15 million barrels capacity Colonial Pipeline in/out Nustar Storage Facility in Linden, NJ 1.2 million barrels capacity Rack marketing services from over 180 terminals in 34 states providing diesel and gasoline products Margins driven by normal supply/demand activity as well as disruption events such as weather or refinery/pipeline issues Utilizing 3 major Pipelines Magellan NuStar Explorer Ethanol and Biodiesel Blending Approximately 1.0 million barrels of storage capacity Collins, MS Refined Products Terminal 19

Segment Refined Products/Renewables Contribution DOE Total U.S. Gas Supplied (1) Area of Operation 10,000 9,800 9,600 9,400 9,200 9,000 8,800 8,600 8,400 8,200 8,000 2011 to 2015 Range 2011 to 2015 Average 2016 2017 2018 FY 2019 Forecast Assumptions Southeast (Colonial and Plantation pipelines) Average gross margin of $0.03 per gallon Renewables blending contributes ~$4.0 million of gross margin Gas Blending Nymex delivery point allows for increased price protection for Southeast volumes Rack Marketing and Other Diesel demand growth in the Permian basin Increased storage capacity to utilize for blending No significant legislative impact (Renewables) $150 $100 $50 $- Adjusted EBITDA (In Millions) $134 $125 $79 $55-80 $49 $8 FY 2014 FY 2015 FY 2016 FY 2017 FY 2018 FY 2019E (1) Department of Energy EIA weekly data for 12/28/18. 20

Financial Overview 21

Financial Objectives Strong Balance Sheet The Partnership has made significant strides with ~$1.5 billion in asset sales and debt reduction in LTM and will continue to pursue a flexible balance sheet with a leverage target of less than 3.25x on a compliance basis Goal of achieving investment grade rating Cash Flow Predictability Increasing fee-based business and long-term contracts with high credit quality customers Transitioning to a more traditional midstream repeatable cash flow model Lower Cost of Capital Continue to pursue opportunities to find and execute on low cost of capital financing in the current and future environments Consistently pursuing strategies that increase NGL s unit price and lower cost of debt Crude and Water segments provide accretive growth platforms Accretive Capital Projects Accretive growth through organic growth projects and strategic acquisitions focused on assets backed by multi-year fee based contracted cash flows Sufficient liquidity to operate the business and execute growth objectives Robust Distribution Coverage Targeting over 1.3x distribution coverage Excess distribution coverage will be used to strengthen the balance sheet and fund growth opportunities 22

2 nd Quarter Update Segment Summary Crude Oil Logistics outperformed expectations primarily due to strong results from Grand Mesa as the pipeline continues to benefit from increased production out of the DJ Basin as well as improved margins in most basins. Water Solutions performed below expectations due to lower-than-expected skim oil cut and basin differentials impacting the net price received for skim oil sales. Refined Products/Renewables performed below expectations due to significant price volatility and minor supply disruptions, offset by stronger demand at our wholesale locations, especially in the Southeast and West Texas. Second half of FY2019 should benefit from contango. Liquids performed above expectations as a result of higher margins due to increased prices, improved railcar utilization and increased volumes attributable to an increase in NGL volumes being transported via railcar due to increased production and thirdparty pipeline infrastructure issues. Executed balance sheet and leverage improving transactions: Note Repurchases: Announced Redemption of all outstanding 6.875% Senior Notes due 2021 and subsequently redeemed in October Asset Sales: Sold Retail Propane sale for a gross consideration of $900 million in cash Water growth initiated: Completed Water acquisitions of approximately $235 million, primarily in the Delaware Basin Invested approximately $140 million on new SWD facilities, disposal wells, and pipelines Quarterly Summary Performance ($ s In Millions) (2) Sep-18 Sep-17 % Variance Total Volume (In Thousand's) Refined Products/Renewables Gasoline (BBL's) 47,067 26,459 78% Diesel (BBL's) 12,057 14,990-20% Ethanol (BBL's) 621 978-37% Biodiesel (BBL's) 250 568-56% Crude Oil (BBL's) 11,891 8,562 39% Crude Oil (Owned Pipelines) (BBL's) 9,578 8,182 17% Liquids Propane (GAL's) 266,654 257,775 3% Butane (GAL's) 131,424 125,419 5% Other NGL's (GAL's) 124,935 102,009 22% Water Solutions Permian Basin (BBL's) 489,861 273,290 79% Eagle Ford Basin (BBL's) 271,059 209,792 29% DJ Basin (BBL's) 166,152 108,952 53% Other Basins (BBL's) 80,577 63,443 27% Total Water Processed (BBL's) 1,007,649 655,477 54% Total Revenue $ 6,654.6 $ 3,876.7 72% Total Cost of Sales $ 6,509.5 $ 3,757.4 73% (1) Adjusted EBITDA $ 95.4 $ 90.8 5% Distributable Cash Flow (1) $ 40.1 $ 35.1 14% Distribution to LP Unitholders $ 0.39 $ 0.39 0% TTM Distribution Coverage 0.95x 0.80x Maintenance Capex $ 15.3 $ 7.9 93% Growth Capex with Investments $ 208.1 $ 58.1 258% Covenant Compliance Leverage 3.7x 5.4x Total Debt (Excluding Working Capital Facility) $ 1,791.2 $ 2,195.4-18% Working Capital Facility $ 759.0 $ 869.5-13% Total Liquidity $ 775.0 $ 696.8 11% (1) Does not include acquisition expenses. (2) Covenant Compliance Leverage excludes the working capital facility and includes Pro Forma effects of projects in construction, recent acquisitions/divestitures and redemption of the 6.875% Senior Notes 23

Performance Metrics Adjusted EBITDA (In Millions) Acquisition, Growth and Maintenance Capex (In Millions) (1) $1,269 $443 $424 $381 $408 $450 $961 $24 $184 $271 $600 $491 $334 $133 $160 $138 $164 $162 $59 $14 $32 $35 $30 $26 $50 $38 $270-295 $235 $40-45 IPO FY 2013 FY 2014 FY 2015 FY2016 FY 2017 FY2018 FY2019E FY 2013 FY 2014 FY 2015 FY2016 FY 2017 FY 2018E FY 2019E Acquisitions Growth Capital Maintenance Capital Distributable Cash Flow & Total Distributions (In Millions) (2) Distribution Coverage $169 $168 $320 $266 $290 $274 $210 $182 $180 >$250 $225 $235 1.0x 1.2x 0.9x 1.2x 0.8x 1.1x 1.3x Target FY 2014 FY 2015 FY2016 FY 2017 FY2018 FY2019E Distributable Cash Flow Distributions FY 2014 FY 2015 FY2016 FY 2017 FY2018 FY2019E (1) Does not include TLP capital expenditures (2) Includes the GP and preferred unit distributions, if any, and assumes the most recent quarterly distribution annualized 24

Credit Profile $1,200 $800 $400 6.00x 4.50x 3.00x 1.50x 2.9x Debt Maturities as of 9/30/18 (In Millions) Covenant Compliance Leverage 3.2x 3.2x 3.9x $961 This is tied out $353 $367 (1) 4.7x 4.4x $611 (2) 3.25x or less $389 $- Apr-18 Apr-19 Apr-20 Apr-21 Apr-22 Apr-23 Apr-24 Apr-25 Credit Facility due 10/2021 5.125% Notes due 7/2019 6.875% Notes due 10/2021 7.500% Notes due 11/2023 6.125% Notes due 2/2025 3.25x Target Capitalization (In Thousands) 9/30/2018 6/30/2018 Variance Cash and Equivalents $ 36,374 $ 13,682 $ 22,692 Total Debt: Senior Secured Revolving Credit Facilities Working Capital Facility 759,000 1,060,500 (301,500) Acquisition Facility 65,000 265,500 (200,500) 5.125% Senior Notes due 2019 353,424 353,424-6.875% Senior Notes due 2021 (1) 367,048 367,048-7.500% Senior Notes due 2023 610,947 610,947-6.125% Senior Notes due 2025 389,135 389,135 - Other Long-Term Debt 5,654 5,815 (161) Total Debt, Excluding Working Capital Facility $ 1,791,208 $ 1,991,869 $ (200,661) 10.75% Class A Convertible Preferred Units $ 104,362 $ 91,559 $ 12,803 Equity: General Partner (50,613) (50,919) 306 Limited Partners 2,046,621 1,740,410 306,211 Class B preferred limited partners 202,731 202,731 - Accumulated Other Comprehensive Loss (270) (257) (13) Noncontrolling interests 78,945 79,463 (518) Total Capitalization $ 4,172,984 $ 4,054,856 $ 118,128.00x FY 2013 FY 2014 FY 2015 FY2016 FY 2017 FY 2018 FY 2019E (1) 6.875% Senior Notes were called and retired as of October 16 th, 2018 (2) Covenant Compliance Leverage excludes acquisition expenses, excludes the working capital facility and includes Pro Forma adjustments for projects in construction or recent acquisitions/divestitures. Total Indebtedness at September 30, 2018 per the Partnership s Credit Facility and used for covenant compliance totaled $1.4 billion as pro forma credit was given for the redemption of the 6.875% Senior Notes.. 25

NGL Operational Assumptions Key Investment Highlights Diversified and Attractive Asset Base Multiple business segments with significant geographic diversity reduce cash flow volatility Presence in the highest rate of return oil & gas producing regions in North America as well as the highest growing population areas for consumer demand Natural hedge between certain business segments reduces commodity price volatility and risk exposure Vertical and Horizontal Integration Vertical integration allows for capture of margin across the value chain from wellhead to end-user Emphasis on asset ownership drives ability to capitalize on multiple revenue/bolt-on opportunities Offer a menu of services to producers and customers Stable Cash Flows Focus on medium to long-term, repeatable fee-based cash flows Combination of fee-based, take-or-pay, acreage dedication, margin-based and cost-plus revenue contracts Targeting ~70% fee based revenues in normal commodity price environment Strong Credit Profile and Liquidity Targeting a distribution coverage over 1.3x on a TTM basis Excess distribution coverage will be reinvested in growth opportunities and reduce indebtedness Targeting a capital structure with compliance leverage of under 3.25x and total leverage under 5.0x Experienced & Incentivized Management Team Extensive industry and MLP experience with proven record of acquiring, integrating, operating and growing successful businesses Senior management holds significant limited partner interests, which strengthens alignment of incentives with lenders and public unitholders Supportive general partner which is privately owned, of which over 65% is held by current and former management and directors, with no indebtedness 26

Appendix 27

NGL Organizational Chart Members 100% NGL Energy Holdings LLC G.P. (DE LLC) 0.1% GP Interest IDR s 123,741,462 C.U. Outstanding 99.9% LP Interest Limited Partners NGL Energy Partners LP (NYSE: NGL) (DE LP) 100% NGL Energy Operating LLC (DE LLC) NGL Crude Logistics (NGL Crude Logistics, LLC) (1) NGL Water Solutions (NGL Water Solutions, LLC) NGL Liquids (NGL Liquids, LLC) NGL Refined Products/Renewables (TransMontaigne LLC) (1) Includes the operations of our Legacy Gavilon crude oil logistics, refined products, and renewables businesses. 28

2Q 19 Adjusted EBITDA & DCF Walk Three Months Ended September 30, Six Months Ended September 30, 2018 2017 2018 2017 (in thousands) (in thousands) Net income (loss) $ 354,939 $ (173,579) $ 185,650 $ (237,286) Less: Net loss (income) attributable to noncontrolling interests 518 (80) 863 (132) Less: Net loss attributable to redeemable noncontrolling interests 48 288 446 685 Net income (loss) attributable to NGL Energy Partners LP 355,505 (173,371) 186,959 (236,733) Interest expense 41,367 50,288 87,779 99,566 Income tax expense 815 111 1,466 570 Depreciation and amortization 53,507 69,426 115,082 137,489 EBITDA 451,194 (53,546) 391,286 892 Net unrealized (gains) losses on derivatives (1,893) 18,077 17,060 16,076 Inventory valuation adjustment 25,770 (2,165) 1,168 (21,347) Lower of cost or market adjustments - 5,333 (413) 9,411 (Gain) loss on disposal or impairment of assets, net (403,185) 111,451 (301,418) 100,238 (Gain) loss on early extinguishment of liabilities, net - (1,943) 137 1,338 Equity-based compensation expense 19,219 6,065 24,730 14,886 Acquisition expense 2,863 264 4,115 (54) Revaluation of liabilities - 5,600 800 5,600 Gavilon legal matter settlement - - 35,000 - Other 1,402 1,616 3,219 2,641 Adjusted EBITDA 95,370 90,752 175,684 129,681 Less: Cash interest expense 38,892 47,344 82,732 93,715 Less: Income tax expense 815 111 1,466 570 Less: Maintenance capital expenditures 15,299 7,994 27,689 14,521 Less: Other 309 233 309 233 Distributable Cash Flow $ 40,055 $ 35,070 $ 63,488 $ 20,642 29

2Q 19 & 2Q 18 Adjusted EBITDA by Segment Crude Oil Logistics Water Solutions Liquids Three Months Ended September 30, 2018 Refined Products and Renewables (in thousands) Corporate and Other Discontinued Operations Consolidated Operating income (loss) $ 31,022 $ 9,770 $ 10,758 $ (29,507) $ (35,352) $ - $ (13,309) Depreciation and amortization 18,870 26,342 6,459 320 759-52,750 Amortization recorded to cost of sales - - 36 1,348 - - 1,384 Net unrealized (gains) losses on derivatives (6,142) 1,788 2,476 - - - (1,878) Inventory valuation adjustment - - - 25,770 - - 25,770 Loss on disposal or impairment of assets, net 3,367 730 1,004-887 - 5,988 Equity-based compensation expense - - - - 19,219-19,219 Acquisition expense - - 1-2,864-2,865 Other income (expense), net 9 (370) 9 263 1,560-1,471 Adjusted EBITDA attributable to unconsolidated entities - 423 - - - - 423 Adjusted EBITDA attributable to noncontrolling interest - 26 (229) - - - (203) Other 1,351 104 16 (70) - - 1,401 Discontinued operations - - - - - (511) (511) Adjusted EBITDA $ 48,477 $ 38,813 $ 20,530 $ (1,876) $ (10,063) $ (511) $ 95,370 Crude Oil Logistics Water Solutions Liquids Three Months Ended September 30, 2017 Refined Products and Renewables (in thousands) Corporate and Other Discontinued Operations Consolidated Operating income (loss) $ 1,196 $ (7,548) $ (118,107) $ 21,042 $ (16,459) $ - $ (119,876) Depreciation and amortization 20,958 25,253 6,141 324 919-53,595 Amortization recorded to cost of sales 84-71 1,351 - - 1,506 Net unrealized gains on derivatives 2,170 3,022 12,682 - - - 17,874 Inventory valuation adjustment - - - (2,165) - - (2,165) Lower of cost or market adjustments - - (2,476) 7,809 - - 5,333 (Gain) loss on disposal or impairment of assets, net (157) 915 117,729 (7,528) - - 110,959 Equity-based compensation expense - - - - 6,065-6,065 Acquisition expense - - - - 264-264 Other income, net 50 2 3 167 1,415-1,637 Adjusted EBITDA attributable to unconsolidated entities 3,798 127-1,216 1-5,142 Adjusted EBITDA attributable to noncontrolling interest - (190) - - - - (190) Revaluation of liabilities - 5,600 - - - - 5,600 Other 1,502 92 22 - - - 1,616 Discontinued operations - - - - - 3,392 3,392 Adjusted EBITDA $ 29,601 $ 27,273 $ 16,065 $ 22,216 $ (7,795) $ 3,392 $ 90,752 30

2Q 19 YTD & 2Q 18 YTD Adjusted EBITDA by Segment Six Months Ended September 30, 2018 Crude Oil Logistics Water Solutions Liquids Refined Products and Renewables Corporate and Other (in thousands) Discontinued Operations Consolidated Operating (loss) income $ (68,716) $ 10,739 $ 13,381 $ (485) $ (52,782) $ - $ (97,863) Depreciation and amortization 38,099 51,651 12,927 641 1,477-104,795 Amortization recorded to cost of sales 80-73 2,696 - - 2,849 Net unrealized losses on derivatives 1,270 10,898 4,813 - - - 16,981 Inventory valuation adjustment - - - 1,168 - - 1,168 Lower of cost or market adjustments - - (504) 91 - - (413) Loss (gain) on disposal or impairment of assets, net 105,261 3,205 994 (3,026) 889-107,323 Equity-based compensation expense - - - - 24,730-24,730 Acquisition expense - - 161-4,000-4,161 Other income (expense), net 23 (370) 44 246 (32,241) - (32,298) Adjusted EBITDA attributable to unconsolidated entities - 369-476 - - 845 Adjusted EBITDA attributable to noncontrolling interest - (86) (551) - - - (637) Revaluation of liabilities - 800 - - - - 800 Gavilon legal matter settlement - - - - 35,000-35,000 Other 2,901 204 33 80 - - 3,218 Discontinued operations - - - - - 5,025 5,025 Adjusted EBITDA $ 78,918 $ 77,410 $ 31,371 $ 1,887 $ (18,927) $ 5,025 $ 175,684 Six Months Ended September 30, 2017 Crude Oil Logistics Water Solutions Liquids Refined Products and Renewables Corporate and Other (in thousands) Discontinued Operations Consolidated Operating income (loss) $ 5,553 $ (8,702) $ (126,879) $ 35,538 $ (34,185) $ - $ (128,675) Depreciation and amortization 41,793 49,261 12,471 648 1,839-106,012 Amortization recorded to cost of sales 169-141 2,781 - - 3,091 Net unrealized losses on derivatives 1,511 3,022 11,313 - - - 15,846 Inventory valuation adjustment - - - (21,347) - - (21,347) Lower of cost or market adjustments - - - 9,411 - - 9,411 (Gain) loss on disposal or impairment of assets, net (3,716) 185 117,729 (15,056) - - 99,142 Equity-based compensation expense - - - - 14,886-14,886 Acquisition expense - - - - (54) - (54) Other income, net 94 20 7 335 2,914-3,370 Adjusted EBITDA attributable to unconsolidated entities 7,620 281-2,107 - - 10,008 Adjusted EBITDA attributable to noncontrolling interest - (434) - - - - (434) Revaluation of liabilities - 5,600 - - - - 5,600 Other 2,413 185 43 - - - 2,641 Discontinued operations - - - - - 10,184 10,184 Adjusted EBITDA $ 55,437 $ 49,418 $ 14,825 $ 14,417 $ (14,600) $ 10,184 $ 129,681 31