Jp energy mlpa conference jun2016-final

1. MLPA Investor Conference
June 2016

2. Disclaimers
2
Forward Looking Statements
This 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 Measures
We define Adjusted EBITDA 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.

3. Company Overview

4. JP Energy Partners LP (JPEP) Overview
4
• JPEP is a publicly traded, diversified MLP
• We operate in three segments:
(1) As of May 24, 2016 Close
JPEP Summary
Unit Price1 $7.34
Market Cap ($mm)1 261
Equity Yield1 17.7%
Units Outstanding (mm) 36.6
Leverage Ratio 3.1x
2015 Adj. EBITDA ($mm) 46.9
Crude Oil
Pipelines &
Storage
Refined
Products
Terminals &
Storage
NGL
Distribution
& Sales
Our crude oil assets include crude oil
storage, gathering and transportation to
ensure reliable services and throughput
for producers, marketers and refiners
Our refined products assets include
transportation, storage, rail and
terminalling
Our NGL assets include propane
operations that encompass supply and
logistics, transportation and storage
throughout the U.S.

5. Segment Overviews

6. Crude Oil Pipelines and Storage
6
Segment Overview
• Crude Oil Storage
• Asset: 3.0 million barrels of shell capacity in Cushing, OK
• Services Offered: Lease crude storage capacity to a
customer
• Gross Margin: 100% fee based
• Contracted to a single customer who we charge a
fixed monthly fee per barrel of shell capacity (not
based on usage)
• Expenses: Outsourced services for fixed monthly fee
• Silver Dollar Pipeline System
• Asset: ~148-mile pipeline system
• Services Offered: Provide crude oil gathering services for
producers targeting the Spraberry and Wolfcamp
formations in the Midland Basin
• Gross Margin: Back-to-back buy-sell agreements where
we earn a transportation fee
• Our pipeline operations are underpinned by long-
term, fee-based contracts with three leading
producers in the Midland Basin
• Additionally, our Crude Oil Supply and Logistics
assets supply additional volume to the pipeline
generally under 30-day evergreen contracts
• Expenses: Mostly fixed expense business
Silver Dollar Pipeline Map
Other Silver Dollar Pipeline Details
• Throughput capacity of ~130,000 barrels per day (bpd)
• Three interconnections to third-party, long-haul pipelines
• System includes crude oil shell storage capacity of
~140,000 bbls, offering us operational flexibility and the
ability to take advantage of favorable pricing
environments
$+
$+
$+
$+
$+
$+
!P
!P
!P
!P
Owens Station
(Plains Interconnect
to Midland)
Midway
Station
Rocker B
Station
Radio Tower
Station
Oxy Barnhart Station
(Oxy Clineshale
Interconnect to
Colorado City)
Magellan Barnhart Station
(Longhorn Interconnect
to E. Houston)
Iraan
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
U P T O NU P T O N
S T E R L I N GS T E R L I N G
S C H L E I C H E RS C H L E I C H E R
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
M I D L A N DM I D L A N D
P E C O SP E C O S
C O K EC O K E
Sources: Esri, USGS, NOAA
J P E P :J P E P :
S i l v e r D o l l a r P i p e l i n eS i l v e r D o l l a r P i p e l i n e
$+ Stations/Interconnects
Active Pipeline
Future Construction
!P Nearby Cities
µWGS 1984
31 MAY 2016

7. Crude Oil Pipelines and Storage (con’t)
7
Segment Overview
• Crude Oil Supply and Logistics
• Assets: 74 crude oil gathering trucks in the
Midland Basin, Eagleford and Texas Panhandle. 4
crude oil truck injection stations in the Midland
Basin
• Services Offered: Marketing and transportation of
crude oil and condensate with particular focus of
gathering in the Midland basin for delivery onto
our Silver Dollar Pipeline system
• Gross Margin: Primarily back-to-back buy-sell
agreements linked to the same price index; we
make a pre-determined marketing or
transportation margin on the difference between
the buy and sell price
• Gross margin includes all trucking and
pipeline costs
• Expenses: Lease rep salaries, regional fleet
supervisors, fleet dispatch, fleet maintenance and
repair, truck yard leases
Crude Oil Supply and Logistics

8. Refined Products Terminals and Storage
8
Segment Overview
• Refined Products Terminals and Storage
• Assets: Two terminals located in North Little
Rock, AR and Caddo Mills, TX
• Services Offered: Transport refined products to or
from storage or transportation systems (pipelines,
rail, trucks)
• Example: Receive RBOB from Explorer
pipeline, store for a week and deliver to
customer truck for transportation to a
local gas station
• Gross Margin:
• Throughput fees based on the volume of
product redelivered, typically evergreen
fee-based contracts
• Storage fees based on barrels stored per
month
• Additive services fees based on additive
(ethanol, proprietary additive, biodiesel)
injection volume
• Sale of product primarily from butane
blending activities
• Expenses: Relatively fixed costs to operate the
terminals
Terminals in Large Metropolitan Areas
Other Refined Products Terminals Detail
• Large, active terminals:
• North Little Rock: 41,000 bpd / 550,000 bbls 2015
throughput / storage capacity
• Caddo Mills: 21,000 bpd / 770,000 bbls 2015
throughput / storage capacity

9. NGL Distribution & Sales
9
Segment Overview
• Retail, Commercial and Wholesale Propane
• Assets: Trucks, tanks and 39 customer service
locations; also 28 regulated community central
distribution systems
• Services Offered: Procurement and delivery of
propane or refined fuels to one of ~100k commercial
or residential locations
• Gross Margin: Per gallon price charged to customer
less our supply, transportation and commodity costs
(Laid-in-costs or “LIC”)
• Most contracts allow us to pass on our LIC
creating a fixed margin
• Expenses: Cost to manage and deliver the product
• NGL Transportation
• Assets: 43 tank trucks
• Services Offered: Gathering and transportation of
NGL and condensate for producers, gas processing
plants, refiners and fractionators
• Gross Margin: Per gallon transportation fee or
marketing spread less cost to transport the product
• Expenses: Cost to manage the dispatch, marketing
and accounting of the transportation
Retail, Commercial and Wholesale Propane Footprint

10. NGL Distribution & Sales (cont’d)
10
Segment Overview
• Cylinder Exchange
• Assets: Cylinders, cages, trucks, 52 depots and 8
production facilities to process and fill empty
cylinders
• Services Offered: Production and delivery of 20-
pound propane cylinders to retail locations across
the 48 continental United Sates for sale to end-
users for use in barbeque grills, patio heaters and
other appliances
• Gross Margin: Per cylinder price charged to retail
locations for exchanged tanks; separate price for
sold tanks (i.e. no return of an empty tank)
• Contract length and nature range by retail
locations
• Expenses: Cost to clean, fill and deliver cylinders
Cylinder Exchange Footprint

11. JP Energy Growth Update

12. 12
Timeline of Achievements Supporting our Growth
Oct
2014
Jan
2015 Mar
2016
Jan
2016
Jun
2015
October 2014
Completed
Initial Public
Offering
January 2015
Announced first
quarterly
distribution
May 2015
Completed immediately
accretive Southern Propane
acquisition for $14.9mm
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
February 2016
Completed MidCon
marketing business
sale for $9.7mm
February 2016
Announced ~$5mm ethanol unit
train project and interconnection
agreement at North Little Rock
Refined Products Terminal

13. 2015 Major Accomplishments
13
Growth
Balance
Sheet
Acquisitions
Organic
Projects
• Grew Adjusted EBITDA by 31% YoY excluding the impact of corporate
overhead support from our general partner
• Silver Dollar Pipeline volumes grew 35% year-over-year
• Retail Propane volumes grew 16% year-over-year
• Maintained under 3.5x leverage ratio for each quarter of 2015
• Below our long term target of 3.5 – 4.0x
• Completed the purchase of Southern Propane, a non-heating degree
day driven industrial propane distribution business
• Completed Phase I of our 50+ mile strategic extension of our Silver Dollar
Pipeline system north into Reagan County (Phase II completed in 1Q16)
• Completed inline butane blending upgrade at our North Little Rock
refined products terminal
• Completed the interconnection of our Silver Dollar System to Magellan
Longhorn Pipeline, adding additional optionality to our pipeline customers

14. Project Completions / Announcements
14
$+
$+
$+
$+
$+
$+
$
$+
!P
!P
!P
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 D
C 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
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-year 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 per 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
Phase II

15. Financial Overview

16. Q1 2016: Segment Performance
16
Adjusted EBITDA by Segment ($mm)Segment Q1 Performance Drivers
NGL
Distribution
& Sales
• Higher margins from more favorable
market conditions, cost control
• Partially offset by volume declines
from unseasonably warm weather
Crude Oil
Pipelines &
Storage
• Decrease in sales and throughput
volumes from reduced customer
activity and increased competition
• Largely offset by an increase in
crude oil sales margin from
improved cost efficiencies
Refined
Products
Terminals &
Storage
• Expense control, capital
improvements, butane blending
• Partially offset by lower throughput
due to a non-recurring increase in
volumes in the prior year quarter
2.8
4.9
12.0
2.9
4.8
12.3
0.0 5.0 10.0 15.0
Refined
Products
Terminals &
Storage
Crude Oil
Pipelines
& Storage
NGL
Distribution
& Sales
1Q16 1Q15

17. Balance Sheet & Liquidity (May 2, 2016)
17
Strong Metrics, Access to Capital
• Exited Q1 2016 with a leverage ratio of 3.1x;
down from 3.4x in the previous quarter
• Maintained conservative leverage below
3.5x throughout 2015
• Leverage ratio remains below peer average
and JPEP long-term target of ~3.5-4.0x
• $106.5 million unused credit facility
capacity1
• Strong interest coverage of 7.5x
• Ample liquidity and balance sheet capacity
to support capital needs
Available Liquidity ($mm)1
Available debt capacity expected to fully support planned 2016 organic capex
___________________________
1. As of May 2, 2016
Unused Credit
Facility
Capacity, 106.5
Outstanding
Letters of
Credit, 14.5
Credit Facility
Borrowings,
154

18. 2016 Adjusted EBITDA Guidance
18
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
___________________________
1. Corporate overhead support is at the discretion of our general partner

19. 2016 Adjusted EBITDA Guidance by Segment
19
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 partner
2. Quarterly low / high guidance range will not sum to 2016 totals
3. 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 our sponsor. There is no
corporate overhead support included in the 2016 guidance

20. $40
$43
$45
$48
$50
$53
$55
$58
$60
2015 Forecast Corporate
Reductions
NGL Reductions Trucking
Effeciency
Improvement
PPE Full Year
Margin
Other EBITDA
Changes
2016 Budget
Expense Reductions Driving Controllable Growth
20___________________________
1. Excludes any potential benefit from general partner corporate overhead support in 2016
Adjusted EBITDA Walk-Forward ($mm)(1)
Absolute Control
Some Control
Less Control /
Market Sensitive
2015 Forecast
Corporate
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

21. $ 0
$ 2
$ 4
$ 6
$ 8
$ 10
$ 12
$ 14
$ 16
4Q14 1Q15 2Q15 3Q15 4Q15 1Q16 Low High
Strong Common Unit Distribution Coverage
21___________________________
1. 4Q14 is adjusted for certain previously disclosed one time items
2. 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 1Q15, 4Q15 and
1Q16
2016 Quarterly Average DCF
Common Units Coverage 1.6x 2.2x 0.7x 1.4x 2.0x 2.1x 1.6x 1.8x
Total Units Coverage 0.8x 1.1x 0.4x 0.7x 1.0x 1.0x 0.8x 0.9x

22. 2016 Crude Guidance
Midpoint
SDP Fully Utilized Crude Recovery Potential
EBITDA
Asymmetric Crude Price / Volume Exposure
22
• 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%

23. Selected Examples of Cost and Operating Expense
Reductions
23
~$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

24. Appendix

25. Non-GAAP Reconciliation – Adjusted EBITDA
25
Year ended December31,
2015 2016 2015
(in Thousands) (in Thousands)
Segment Adjusted EBITDA
Crude oil pipelines and storage 23,119$ 4,813$ 4,881$
Refined products terminals and storage 10,867 2,858 2,822
NGL distribution and sales 30,896 12,289 12,025
Discontinued operations 1,209 (371) 2,650
Corporate and other (19,226) (5,408) (7,189)
Total Adjusted EBITDA 46,865 14,181 15,189
Depreciation and amortization (46,852) (11,536) (10,763)
Goodwill impairment (29,896) - -
Interest expense (5,375) (2,430) (1,116)
Income tax expense (754) (416) (22)
Loss on disposal of assets, net (909) (1,132) (113)
Unit-based compensation (1,217) (559) (406)
Total (loss) gain on commodity derivatives (3,057) (135) 135
Net cash payments for commodity derivatives settled during the period 14,821 388 3,192
Early settlement of commodity derivatives (8,745) - -
Non-cash inventory costing adjustment - 153 -
Corporate overhead support from general partner (5,500) (1,500) -
Transaction costs and other (1,877) (74) (2,374)
Discontinued operations (16,160) (168) (3,057)
Net (loss) income (58,656)$ (3,228)$ 665$
Three months ended March 31,

26. Non-GAAP Reconciliation – Distributable Cash Flow
26
Year ended December
31, 2015
(in Thousands)
Net cash provided by operating activities 46,041$
Depreciation and amortization (49,133)
Goodwill impairment (37,835)
Asset impairment (4,970)
Derivative valuation changes 11,340
Amortization of deferred financing costs (909)
Unit-based compensation (1,309)
Loss on disposal of assets (1,028)
Bad debt expense (1,212)
Other non-cash items (1,744)
Changes in assets and liabilities (17,897)
Net loss (58,656)$
Depreciation and amortization 46,852
Goodwill impairment 29,896
Interest expense 5,375
Income tax expense 754
(Gain) loss on disposal of assets, net 909
Unit-based compensation 1,217
Total gain (loss) on commodity derivatives 3,057
(14,821)
Early settlement of commodity derivatives 8,745
Corporate overhead support from general partner 5,500
Transaction costs and other 1,877
Discontinued operations 16,160
Adjusted EBITDA 46,865$
Less:
Cash interest paid, net of interest income 4,527
Cash taxes paid 450
Maintenance capital expenditures, net 3,109
Distributable cash flow 38,779$
Less:
Distributions 48,063
Amount in excess of (less than) distributions (9,284)$
Distribution coverage 0.81x
Net cash payments for commodity derivatives
settled during the period