2016 UBS MLP One-on-One Conference

January 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.

JP Energy Partners Overview

JP Energy Partners LP (JPEP) Overview

4

• NYSE Listed: JPEP

• Formed in May 2010

• JPEP is a publicly traded, diversified master

limited partnership with operations including:

• Crude Oil Pipelines & Storage

• Refined Products Terminals & Storage

• NGL Distribution & Sales

• JPEP Trading Summary (1)

• Unit Price: $4.42

• Units Outstanding: 36.6M

• Market Cap: 161.8M

• Current Yield: 29.4%

(1) As of January 7, 2016 Close. Units Outstanding are as of September 30, 2015.

Well Positioned for 2016 and Beyond

Solid Position in Active Basins Fully Integrated Solution Solid Financial Position

• Network of midstream

assets in core of Midland

Basin

• Eagle Ford position

capitalizes on strong

fundamentals, drilling

activity and provides

potential future drop-

down

• Manage physical

movement of petroleum

products from

origination to

destination

• Three complimentary

business segments

connecting upstream to

downstream

• Natural hedge to

seasonality and

commodity price

changes

• Large percentage of fee-

based business

• Low commodity price

sensitivity

• Strong balance sheet

• Strong sponsor with

drop-down opportunities

Enables Long-Term Growth

• Execute on backlog of

organic growth

opportunities

• Pursue potential

acquisitions

• Initiate drop-downs

• Execute pipeline

expansions

5

6

Crude Oil Pipelines and Storage

– Fixed EBITDA crude storage contract

– Fixed throughput rate on the Silver Dollar Pipeline

– Crude oil trucking and “fee equivalent” lease gathering primarily

focused on driving volumes to our pipeline systems

– Long-term volume growth in the Southern Wolfcamp from existing

contracted producers with long-term fee-based commitments

– Pursuing additional customer acreage and MVC within JP Energy’s

capture area and continuing to expand the pipeline system

Refined Products Terminals and Storage

– Fixed fees for throughput and storage

– Fixed fees for blending services, injection of additives and ancillary

services, including product handling and transfer services

NGL Distribution and Sales

– Retail and industrial distribution is primarily “cost plus” or fixed-

margin business

– Recent acquisitions of Southern Propane and NGL truck services

add to fee-based and fixed margin earnings

– Utilize hedges to minimize volatility in our cylinder exchange

earnings

Focu

sed

on

Gro

win

g Fe

e-b

ased

Cas

h F

low

s NGL Distribution

and Sales

Refined Products Terminals

and Storage

Crude Oil Pipelines &

Storage

Segment Adjusted EBITDA Mix: 3Q15 TTM

Growing, Fee-Based Cash Flows with High Quality Customer Base

NGL Distribution and Sales, 45%

Crude Oil Pipelines and Storage, 39%

Refined Products

Terminals and Storage, 17%

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Timeline of Achievements Supporting our Growth

Oct

2014

Nov

2014

Dec

2014

Jan

2015

Feb

2015

Mar

2015

Apr

2015

Announced Strategic Extension of Silver Dollar Pipeline in the Midland

Basin

Pipeline expansion north into Reagan and Glasscock Counties. ~51-mile expansion base loaded by a 53,000 acre 10 year dedication.

Phase I completed in September, Phase II expected completion in January 2016

Announced Silver Dollar Pipeline Interconnection Agreement with

Magellan Midstream Partners

Executed interconnection agreement with an affiliate of Magellan to connect the Silver Dollar Pipeline

System to Magellan’s Longhorn pipeline at Barnhart Terminal in Crockett County, TX. Placed in service in

Q3 2015

Announced Southern Propane Acquisition

Agreed to acquire substantially all of the assets of Southern Propane. Southern Propane

services mostly industrial and commercial clients in the greater

Houston area

Completed Southern Propane Acquisition

Completed previously announced Southern

Propane acquisition for $16.3 million

May

2015 Jun

2015

Completed Initial Public Offering

Completed IPO, listing JP Energy Partners shares on the New York Stock

Exchange (NYSE)

Announced First Quarterly Distribution

Announced first quarterly distribution equivalent to

minimum quarterly distribution (MQD) of $0.3250/unit

Overview

Silver Dollar Pipeline – Recent Updates

8

Reagan Lateral

• Completed Phase I of the project in September 2015 on time and under budget. Includes 32-miles of pipeline and associated truck and measurement facilities. Expect Phase II to be completed in January 2016

• Expands capture area in the Midland Basin by extending Silver Dollar north into Reagan and Glasscock. Lateral is base loaded by a 53,000 acre 10 year dedication

Magellan Longhorn Interconnect

• In September 2015, completed an interconnection between the Silver Dollar Pipeline and the Longhorn Pipeline at Barnhart Terminal in Crocket County, TX

• Provides third take-away option for producers and provides producers with direct access from the core of the Midland Basin to Houston end markets

Reagan

Irion

Crockett

Sterling

Glasscock

Tom Green

Silver Dollar Pipeline - Reagan Lateral

Legend

Reagan Lateral Station

Future Station

Stations

Active Pipeline

Reagan Lateral

Rail

Major Highways

Oxy Barnhart Station (Centurion Interconnect

to Colorado City)

Owens Station(Plains Interconnect

to Midland)

MidwayTruck

Station

Future TruckStation

Future TruckStation

TruckStation

TruckStation

Magellan Barnhart Station (Longhorn Interconnect

to E. Houston – Q3 2015)

Planned Expansion

Midland (via Plains)

Colorado City (via Oxy Cline’s

Centurion)

Silver Dollar

Houston (via Magellan Longhorn)

Financial Strategy

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Maintain Stable Cash Flows

• Long term contracts for our crude oil pipelines

• Refined products and NGL segments offer diversification in mature markets but with considerable growth opportunities

Deliver Consistent Distribution Growth

• Near-term organic growth projects being pursued in existing businesses

• Potential strategic drop-downs from JP Development and Republic Midstream could further bolster growth

• Remain open to acquisition opportunities that are strategic to the platform

Commitment to Financial Flexibility

• Revolver has ~$87 million in availability as of December 31, 2015

• Target 3.5-4.0x leverage over the long-term

Comprehensive Risk Management

• Established policies and procedures to monitor and manage risks associated with commodity prices, counterparty credit and interest rates

• Commodity price exposure is minimized through fixed-fee contracts or margin-based arrangements

2016 Financial Guidance

2016 Adjusted EBITDA Guidance

11

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

12

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 23 - 24 3 - 3

Refined Products Terminals 2 - 3 2 - 3 2 - 3 2 - 3 10 - 12 10 - 11 (0) - 1

NGL Distribution and Sales 12 - 13 9 - 10 7 - 8 11 - 12 38 - 41 30 - 31 8 - 10

Corporate (7) - (6) (6) - (5) (6) - (5) (6) - (5) (24) - (23) (18) - (17) (6) - (6)

Total Adjusted EBITDA 12 - 17 11 - 16 9 - 14 13 - 18 50 - 56 46 - 48 4 - 8

Distributable Cash Flow 9 - 14 7 - 12 6 - 11 11 - 16 39 - 45 36 - 39 3 - 6

Common Units Coverage 1.5x - 2.3x 1.1x - 1.9x 1.0x - 1.7x 1.7x - 2.5x 1.6x - 1.8x 1.5x - 1.6x

Total Units Coverage 0.7x - 1.2x 0.6x - 1.0x 0.5x - 0.9x 0.9x - 1.3x 0.8x - 0.9x 0.7x - 0.8x

$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

13___________________________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 Low High

Strong Common Unit Distribution Coverage

14___________________________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

• Expect 1x total unit distribution coverage in 4Q15

2016 Quarterly Average DCF

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

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

Crude Oil Pipelines and Storage

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• 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

16

• 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

17

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

18

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

19

2016 Overhead Guidance Overview

Selected Examples of Cost and Operating Expense Reductions

20

~$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

Balance Sheet and Liquidity

21

Strong Metrics, Access to Capital

• Leverage ratio expected to remain at or below

JPEP long-term target of 3.5-4.0x throughout

2016

• $87 million unused credit facility capacity1

• Ample liquidity and balance sheet capacity to

support capital needs

• Do not expect any equity issuance in 2016

unless we execute a sizeable acquisition

Available Liquidity ($mm) (1)(2)

Available debt capacity expected to fully support planned 2016 organic capex

___________________________1. As of December 31, 20152. Does not include sale proceeds from expected Mid-Continent asset divestiture

Credit Facility

Borrowings, $162

Outstanding Letters of

Credit, $26

Unused Credit Facility

Capacity, $87

Appendix

Non-GAAP Reconciliation – Adjusted EBITDA

Nine months ended

September 30,

2015

(in thousands)

Segment Adjusted EBITDA

Crude oil pipelines and storage 17,593$

Crude oil supply and logistics 394

Refined products terminals and storage 7,601

NGL distribution and sales 23,083

Corporate and other (15,971)

Total Adjusted EBITDA 32,700

Depreciation and amortization (35,768)

Interest expense (4,069)

Income tax (expense) benefit (333)

Gain (loss) on disposal of assets, net (1,395)

Unit-based compensation (875)

Total gain (loss) on commodity derivatives (1,449)

15,918

Early settlement of commodity derivatives (8,745)

Non-cash inventory costing adjustment (2,671)

Corporate overhead support from general partner (3,000)

Transaction costs and other (3,033)

Net loss (12,720)$

Net cash (receipts) payments for commodity derivatives

settled during the period

23

Non-GAAP Reconciliation – Distributable Cash Flow

24

Nine months ended

September 30,

2015

Net cash provided by operating activities 24,266$

Depreciation and amortization (35,768)

Derivative valuation changes 14,625

Amortization of deferred financing costs (682)

Unit-based compensation (875)

Loss on disposal of assets (1,395)

Bad debt expense (999)

Other non-cash items 193

Changes in assets and liabilities (12,085)

Net loss (12,720)$

Depreciation and amortization 35,768

Interest expense 4,069

Income tax expense 333

(Gain) loss on disposal of assets, net 1,395

Unit-based compensation 875

Total gain (loss) on commodity derivatives 1,449

(15,918)

Early settlement of commodity derivatives 8,745

Non-cash inventory costing adjustment 2,671

Corporate overhead support from general partner 3,000

Transaction costs and other 3,033

Adjusted EBITDA 32,700$

Less:

Cash interest paid, net of interest income 3,209

Cash taxes paid 450

Maintenance capital expenditures, net 2,290

Distributable cash flow 26,751$

Less:

Distributions 36,040

Amount in excess of (less than) distributions (9,289)$

Distribution coverage 0.74x

Net cash payments for commodity derivatives

settled during the period

(in thousands)