Barclays MLP Corporate Access Day

March 2016

Disclaimers

2

Forward Looking StatementsThis presentation contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. We make these forward-looking statements in reliance on the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995. You typically can identify forward-looking statements by words such as “anticipates,” “believes,” “could,” “may,” “should,” “estimates,” “expects,” “forecasts,” “targets,” “projects,” “will,” “guidance,” “assumes” and “outlook” or other similar expressions. These statements discuss future expectations, contain projections of results of operations or of financial condition or state other forward-looking information. These statements are based upon various assumptions, many of which are based, in turn, upon further assumptions, including examination of historical operating trends made by the management of JP Energy Partners LP (the “ Partnership”). Although the Partnership believes that these assumptions were reasonable when made, because assumptions are inherently subject to significant uncertainties and contingencies, which are difficult or impossible to predict and are beyond its control, the Partnership cannot give assurance that it will achieve or accomplish these expectations, beliefs or intentions. These forward-looking statements involve risks and uncertainties. When considering these forward- looking statements, you should keep in mind the risk factors and other cautionary statements in the Partnership’s 10-K and other documents on file with the Securities and Exchange Commission. The risk factors and other factors noted in the Partnership’s public filings could cause the Partnership’s actual results to differ materially from those contained in any forward-looking statement. Given the uncertainties and risk factors that could cause our actual results to differ materially from those contained in any forward-looking statement, we caution investors not to unduly rely on our forward-looking statements. We disclaim any obligations to and do not intend to update or announce publicly the result of any revisions to any of the forward-looking statements in this presentation to reflect future events or developments.

This document includes certain non-GAAP financial measures as defined under SEC Regulation G. A reconciliation of those measures to most directly comparable GAPP measures is provided in the appendix to this presentation.

Non-GAAP MeasuresAdjusted EBITDA is defined as net income (loss) plus (minus) interest expense (income), income tax expense (benefit), depreciation and amortization expense, asset impairments, (gains) losses on asset sales, certain non-cash charges such as non-cash equity compensation and non-cash vacation expense, non-cash (gains) losses on commodity derivative contracts (total (gain) loss on commodity derivatives less net cash flow associated with commodity derivatives settled during the period) and selected (gains) charges and transaction costs that are unusual or non-recurring and other selected items that impact comparability.

We define distributable cash flow as Adjusted EBITDA less net cash interest paid, income taxes paid and maintenance capital expenditures.

Q4 and FY 2015 Review

Q4 2015: Segment Performance

4

Adjusted EBITDA by Segment ($mm)Segment Q4 Performance Drivers

NGL Distribution & Sales

• Higher margins from more favorable market conditions, cost control

• Partially offset by volume declines related to unseasonably warm weather

Crude Oil Pipelines & Storage

• Higher volumes from the expansion of the Silver Dollar Pipeline System

• Addition of a significant new customer during the third quarter of 2015

Refined Products Terminals & Storage

• Expense control, capital improvements, butane blending

• Moderately lower margins from a shift in refined product volume mix

3.1

6.2

5.6

3.3

6.8

7.9

Refined ProductsTerminals &

Storage

Crude Oil Pipelines& Storage

NGL Distribution &Sales

4Q15 4Q14

FY 2015: Segment Performance

5

Segment FY 2015 Performance Drivers

NGL Distribution & Sales

• Higher margins from more favorable market conditions, cost control

• Increase volumes from organic growth and completion of Southern Propane acquisition in May 2015

Crude Oil Pipelines & Storage

• Reduced margins from low oil prices, increased competition

• Partially offset by higher sales volumes and throughput from Silver Dollar expansions

Refined Products Terminals & Storage

• Addition of butane blending, expense control, capital improvements

• Moderately lower margins from a shift in refined product volume mix

10.7

25.3

15.5

10.9

23.1

30.9

Refined ProductsTerminals &

Storage

Crude Oil Pipelines& Storage

NGL Distribution &Sales

FY15 FY14

Adjusted EBITDA by Segment ($mm)

Balance Sheet & Liquidity (February 22, 2016)

6

Strong Metrics, Access to Capital

• Maintained conservative leverage below 3.5x throughout 2015, including 3.4x in 4Q15

‒ Leverage ratio remains below peer average and JPEP long-term target of ~3.5-4.0x

• $97 million unused credit facility capacity1

• Strong interest coverage of 8.5x

• Ample liquidity and balance sheet capacity to support capital needs

Available Liquidity ($mm)1

Available debt capacity expected to fully support planned 2016 organic capex

___________________________1. As of February 22, 2016

Credit Facility

Borrowings, $150

Outstanding Letters of

Credit, $28

Unused Credit Facility Capacity,

$97

JP Energy Growth Update

8

Timeline of Achievements Supporting our Growth

Oct

2014

Jan

2015 Mar

2016

Jan

2016

Jun

2015

October 2014

Completed Initial Public

Offering

Jan 2015

Announced first quarterly

distribution

May 2015

Completed immediately accretive Southern Propane

acquisition

February 2015

Announced strategic extension of Silver

Dollar Pipeline in the Midland Basin

April 2015

Announced Silver Dollar Pipeline interconnection

agreement with Magellan Midstream Partners

Feb 2016

Completed MidConbusiness sale

Feb 2016

Announces ethanol unit train project and interconnection

agreement at North Little Rock Refined Products Terminal

2015 Major Accomplishments

9

Major Accomplishments

• Growth: Grew Adjusted EBITDA by 31% year-over-year excluding the impact of corporate overhead

support from our General Sponsor

• Silver Dollar Pipeline volumes grew 35% year-over-year

• Retail Propane volumes grew 16% year-over-year

• Balance Sheet: Maintained under 3.5x leverage ratio for each quarter of 2015

• Below our long term target of 3.5 – 4.0x

• Acquisitions: Completed the purchase of Southern Propane, a non-heating degree day driven

industrial propane distribution business

• Organic Projects:

• Completed Phase I of our 50+ mile strategic extension of our Silver Dollar Pipeline system

north into Reagan County

• Completed inline butane blending upgrade at our North Little Rock refined product terminal

• Completed the interconnection of our Silver Dollar System to Magellan Longhorn Pipeline,

adding additional optionality to our pipeline customers

$+

$+

$+

$+

$+

$+

$

$+

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!P

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Mertzon

Big Lake

Barnhart

I R I O NI R I O N

R E A G A NR E A G A N

C R O C K E T TC R O C K E T T

S T E R L I N GS T E R L I N G

G L A S S C O C KG L A S S C O C K

T O M G R E E NT O M G R E E N

U P T O NU P T O N

S C H L E I C H E RS C H L E I C H E R

M I D L A N DM I D L A N DC O K EC O K E

P E C O SP E C O S

JPEP - Silver Dollar Pipeline

$+ Future Truck Station

$ EP CPF 8-24

$+ Stations/Interconnects

Active Pipeline

Future Construction

Project Completions / Announcements

Completed: Phase II of the Regan County Extension

• In January 2016, we completed Phase II of our Reagan County extension to our Silver Dollar Pipeline

• Expands our system north through Reagan County and into Glasscock County

• The project was completed on time and significantly under budget

• Project is base loaded by a 10-yr fee based gathering agreement with Discovery Natural Resources dedicating 53,000 acres in Reagan, Glasscock, Sterling and Irion Counties

Announced: North Little Rock Ethanol Rail Project / Magellan Pipeline Connection

• In February 2016, we initiated an expansion of our rail facilities at our North Little Rock terminal materially improving the terminal’s ethanol offloading efficiency

• New system capable of offloading up to 108 train cars per delivery

• Facility capable of blending and distributing 9 million gallons of ethanol a month

• Also announced our connection to Magellan’s Little Rock Pipeline allowing JP Energy’s customers to deliver to the terminal via Gulf Coast and Midcontinent refineries Offload equipment similar to the North Little Rock design

10

Phase II

Growing a Diverse Mix of Stable Cash Flows

11___________________________1. Based on Adjusted EBITDA for the year ended December 31, 20152. Based on planned Adjusted EBITDA for the year ended December 31, 2016

Fee Based Fixed Margin Variable Margin

Crude Oil Pipeline & Storage

Refined Products Terminals

Crude Oil & NGL Trucking

NGL Fixed Margin Product Sales

Crude Oil and NGL & Supply

Logistics

NGL Variable Margin

Product Sales

Refined Product Sales

• Pipeline throughput fees

• Crude oil storage fees

• Throughput volume fees

• Fee-basedtrucking for third parties

• NGL sales under fixed price & hedged contracts

• Typically back-to-back transactionsat index-based prices

• NGL salesat market prices

• Product sales that vary with market prices

2015 Adjusted EBITDA1 2016 Planned Adjusted EBITDA2

Variable Margin,

33%

Fee Based,

48%

Fixed Margin,

19%

Variable Margin,

44%

Fee Based,

42%

Fixed Margin,

15%

2016 Financial Guidance

2016 Adjusted EBITDA Guidance

13

2016 JP Energy Guidance

• 2016 Adjusted EBITDA of $50 - $56 million before considering any corporate overhead support(1)

or any acquisitions we may undertake during the year

• Expected 2016 Adjusted EBITDA growth is largely attributed to items within our control,

including expense reductions and efficiency improvements

• Targeting 1x 2016 distribution coverage, which could include some level of corporate overhead

support from our general partner

• $25 - $35 million of 2016 growth capital expenditures including an estimated $15 million on our

Silver Dollar Pipeline

• Continue to maintain a strong balance sheet and adequate liquidity on our revolving credit facility

• Expect proceeds to JP Energy Partners as well as reduction in working capital and letters of

credit from the previously disclosed expected sale of our Mid-Continent Crude Oil Supply and

Logistics assets

___________________________1. Corporate overhead support is at the discretion of our general partner

2016 Adjusted EBITDA Guidance by Segment

14

2016 Adjusted EBITDA and DCF Guidance ($mm)(1)(2)(3)

___________________________1. 2016 excludes the potential benefit of any corporate overhead support that could be received from our general partner2. Quarterly low / high guidance range will not sum to 2016 totals3. Crude Oil Pipelines and Storage includes Adjusted EBITDA previously attributable to the Crude Oil Supply and Logistics segment

We consolidated the Crude Oil Supply and Logistics segment into the Crude Oil Pipelines and Storage segment in Q4 2015 to better align with the operations and management of this business

1Q16 2Q16 3Q16 4Q16 2016 2015 Growth

Adjusted EBITDA Guidance Range YoY

Crude Oil Pipelines and Storage 5 - 7 6 - 8 6 - 8 6 - 8 26 - 27 24 2 - 3

Refined Products Terminals 2 - 3 2 - 3 2 - 3 2 - 3 10 - 12 11 (1) - 1

NGL Distribution and Sales 12 - 13 9 - 10 7 - 8 11 - 12 38 - 41 31 7 - 10

Corporate (7) - (6) (6) - (5) (6) - (5) (6) - (5) (24) - (23) (19) (5) - (4)

Total Adjusted EBITDA 12 - 17 11 - 16 9 - 14 13 - 18 50 - 56 47 3 - 9

Distributable Cash Flow 9 - 14 7 - 12 6 - 11 11 - 16 39 - 45 39 0 - 6

Common Units Coverage 1.5x - 2.4x 1.2x - 1.9x 1.0x - 1.8x 1.7x - 2.6x 1.6x - 1.8x 1.6x

Total Units Coverage 0.8x - 1.2x 0.6x - 1.0x 0.5x - 0.9x 0.9x - 1.3x 0.8x - 0.9x 0.8x

Included in 2015 results are $5.5 million of corporate overhead support from out sponsor. There is no corporate overhead support included in the 2016 guidance

$40

$43

$45

$48

$50

$53

$55

$58

$60

2015 Forecast CorporateReductions

NGL Reductions TruckingEffeciency

Improvement

PPE Full YearMargin

Other EBITDAChanges

2016 Budget

Expense Reductions Driving Controllable Growth

15___________________________1. Excludes any potential benefit from general partner corporate overhead support in 2016

Adjusted EBITDA Walk-Forward ($mm)(1)

Absolute Control

Some Control

Less Control / Market Sensitive

2015 ForecastCorporate Expense

Reductions

NGL Expense Reductions

Trucking Efficiency

Improvement

Annualizing NGL Current Margin

Other EBITDA Changes

2016 Guidance Range

Lower professional fees

Reduced engineering needs

Elimination of COO Position

Improved technology

Lower T&E Lower advertising Lower fleet costs Other efficiency

initiatives

Improvement in logistics and efficiency

Full year benefit of lower propane prices

Partially subject to market conditions

Net unallocated impact of other factors

$ 0

$ 2

$ 4

$ 6

$ 8

$ 10

$ 12

$ 14

$ 16

4Q14 1Q15 2Q15 3Q15 4Q15 Low High

Strong Common Unit Distribution Coverage

16___________________________1. 4Q14 is adjusted for certain previously disclosed one time items2. Assumes current units outstanding for distributions. Numbers vary slightly by quarter. Excludes any potential future corporate overhead support

Quarterly Distributable Cash Flow ($mm)(1)(2)

Common Unit Distribution

Total Unit Distribution

Discussion

• Approximately half of the units outstanding are subordinated to the common unit holders, including public unit holders

• Expect considerable coverage for common unit distributions

• Achieved over 1x distribution coverage in both the 1Q15 and 4Q15

2016 Quarterly Average DCF

Common Units Coverage 1.6x 2.2x 0.7x 1.4x 2.0x 1.6x 1.8x

Total Units Coverage 0.8x 1.1x 0.4x 0.7x 1.0x 0.8x 0.9x

Crude Oil Pipelines and Storage

17

• Expect 2016 Adjusted EBITDA to increase $3 million year-over-year

• Modest expectations for volume growth on our Silver Dollar Pipeline

• Expect full year average barrels per day (“bpd”) on the Silver Dollar System of 30 – 35

mbpd

• Adjusted EBITDA growth is expected to be largely the result of improved efficiencies in our

crude trucking operations and lower headcount

• Crude Oil Pipelines and Storage 2016 Initiatives:

• Efficiency improvement efforts including optimized fleet placement and truck utilization

• Crude Oil Pipelines and Storage segment intends to focus in the Permian Basin and the Eagle

Ford in 2016 as we expect to complete the sale of our Mid-Continent business in Q1 2016

2016 Adjusted EBITDA Guidance Overview

2016 Crude GuidanceMidpoint

SDP Fully Utilized Crude Recovery PotentialEBITDA

Asymmetric Crude Price / Volume Exposure

18

• Approximately 20% of 2016 Adjusted EBITDA guidance for all

operational segments is sensitive to crude volumes or margins

• Of this amount ~66% is contracted, fee based pipeline tariff with

limited volume growth expectations

• A majority of 2016 forecasted volumes are related to current pipe-

connected wells, requiring no additional drilling or growth capex

• A 20% change in our 2016 pipeline throughput expectation

impacts Adjusted EBITDA by approximately $2 million, or less than

4% of our total estimated 2016 Adjusted EBITDA

Limited Further Crude Related Downside: 2016 Total Segment Adjusted EBITDA

Considerable Upside from Crude Market Recovery: EBITDA Growth Potential

Potential Incremental EBITDA

• The Silver Dollar Pipeline throughput capacity is 130 mbpd;

approximately 25% utilized at current volumes

• Lower capex required for incremental volumes

• We expect Permian Basin volumes to increase considerably when

oil prices begin to recover

• Long-term fully utilized pipeline income could increase JP Energy

Adjusted EBITDA by 60%+ over 2016 guidance

Non-Crude Sensitive, 79%

Crude Sensitive, 21%

• Refined Products Terminals Adjusted EBITDA is expected to be relatively flat year-over-year

• Slight volume improvement expectation due to new customers added late in 2015 and our

Ethanol Rail project in North Little Rock

• The current forward curve indicates reduced margins for butane blending activities

• Refined Products Terminals 2016 Initiatives:

• Immediately accretive Ethanol Rail Project at our North Little Rock Terminal

• Increase storage rental income with extension of the contango market

• A 10% change in refined product prices versus our forecast would have a $0.3 million impact on

forecasted Adjusted EBITDA

Refined Products Terminals

19

2016 Adjusted EBITDA Guidance Overview

• NGL Distribution and Sales Adjusted EBITDA is expected to grow considerably year-over-year

• Full year benefit of cylinder exchange margin improvement

• Growing retail distribution volumes offsetting some margin pressure

• Considerable expense improvement in fleet costs and lower headcount

• NGL Distribution and Sales 2016 Initiatives:

• Expense initiatives across our NGL platform, partially from improved technology

• Expand markets to improve southwest footprint and focus on non-heating degree day

demand

• Increase transportation marketing activity

• A 10% change in Cylinder Exchange volumes versus our forecast would have a $1.3 million impact

on Adjusted EBITDA

• A 5% change in Retail Propane margins versus our forecast would have a $2.5 million impact on

Adjusted EBITDA

NGL Distribution and Sales

20

2016 Adjusted EBITDA Guidance Overview

• Normalized corporate overhead expense (before any benefit from General Partner support) is

expected to decline year-over-year

• Lower public company expenses

• Lower headcount

• 2016 Corporate Initiatives:

• Reduced T&E spend through improved tracking

• Centralized procurement team reduces costs throughout the company

• Reduced audit expense through improved processes

• Implementation of lower cost technology solutions

Corporate

21

2016 Overhead Guidance Overview

Selected Examples of Cost and Operating Expense Reductions

22

~$2.0 million in net 2016 savings from our crude trucking operations from:

Positioning fleet closer to customers, reducing trucking miles

Reducing fuel, repair and maintenance costs

Improving truck utilization across fleet

>$2.5 million in net 2016 reductions in our NGL segment due to:

Streamlining workforce

Optimizing fleet

Increasing operational efficiencies

$2.0 million of 2016 reduction in corporate overhead from:

Capturing efficiencies across our business

Investing in in new technology

Reduced headcount

Appendix

Non-GAAP Reconciliation – Adjusted EBITDA

24

2015 2014 2015 2014

Segment Adjusted EBITDA

Crude oil pipelines and storage 6,811$ 6,237$ 23,119$ 25,339$

Refined products terminals and storage 3,266 3,057 10,867 10,723

NGL distribution and sales 7,901 5,623 30,896 15,511

Discontinued operations (559) 521 1,209 5,002

Corporate and other (3,257) (5,422) (19,226) (24,924)

Total Adjusted EBITDA 14,162 10,016 46,865 31,651

Depreciation and amortization (12,796) (11,356) (46,852) (40,230)

Goodwill impairment (29,896) - (29,896) -

Interest expense (1,527) (1,353) (5,375) (8,981)

Loss on extinguishment of debt - - - (1,634)

Income tax (expense) benefit (422) (302) (754) (300)

Gain (loss) on disposal of assets, net 493 (112) (909) (1,137)

Unit-based compensation (434) (640) (1,217) (1,658)

Total gain (loss) on commodity derivatives (858) (13,032) (3,057) (13,762)

67 1,554 14,821 1,071

Early settlement of commodity derivatives - - (8,745) -

Corporate overhead support from general partner (2,500) - (5,500) -

Transaction costs and other 1,056 (2,301) (1,877) (3,766)

Discontinued operations (13,281) (1,090) (16,160) (14,277)

Net loss (45,936)$ (18,616)$ (58,656)$ (53,023)$

Three months ended December 31,

Net cash (receipts) payments for commodity derivatives

settled during the period

Year ended December 31,

(in thousands)

Non-GAAP Reconciliation – Distributable Cash Flow

25

Three months

ended

December 31,

2015

Year ended

December 31,

2015

Net cash provided by operating activities 21,775$ 46,041$

Depreciation and amortization (13,365) (49,133)

Goodwill impairment (37,835) (37,835)

Asset impairment (4,970) (4,970)

Derivative valuation changes (3,285) 11,340

Amortization of deferred financing costs (227) (909)

Unit-based compensation (434) (1,309)

Loss on disposal of assets 367 (1,028)

Bad debt expense (213) (1,212)

Other non-cash items (1,937) (1,744)

Changes in assets and liabilities (5,812) (17,897)

Net loss (45,936)$ (58,656)$

Depreciation and amortization 12,796 46,852

Goodwill impairment 29,896 29,896

Interest expense 1,527 5,375

Income tax expense 422 754

(Gain) loss on disposal of assets, net (493) 909

Unit-based compensation 434 1,217

Total gain (loss) on commodity derivatives 858 3,057

(67) (14,821)

Early settlement of commodity derivatives - 8,745

Corporate overhead support from general partner 2,500 5,500

Transaction costs and other (1,056) 1,877

Discontinued operations 13,281 16,160

Adjusted EBITDA 14,162$ 46,865$

Less:

Cash interest paid, net of interest income 1,318 4,527

Cash taxes paid - 450

Maintenance capital expenditures, net 718 3,109

Distributable cash flow 12,126$ 38,779$

Less:

Distributions 12,017 48,063

Amount in excess of (less than) distributions 109$ (9,284)$

Distribution coverage 1.01x 0.81x

Net cash payments for commodity derivatives

settled during the period

(in thousands)