Jp energy january 2016 ubs 1x1 conference

1. 2016 UBS MLP One-on-One Conference
January 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
Adjusted 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.

3. JP Energy Partners Overview

4. 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.

5. 5
Well Positioned for 2016 and Beyond
2
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

6. 5
 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
FocusedonGrowingFee-basedCashFlows
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%

7. 7
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

8. 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)
Midway
Truck
Station
Future Truck
Station
Future Truck
Station
Truck
Station
Truck
Station
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)

9. Financial Strategy
6
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

10. 2016 Financial Guidance

11. 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

12. 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 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 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

13. $40
$43
$45
$48
$50
$53
$55
$58
$60
2015 Forecast Corporate
Reductions
NGL Reductions Trucking
Effeciency
Improvement
PPE Full Year
Margin
Other EBITDA
Changes
2016 Budget
Expense Reductions Driving Controllable Growth
13___________________________
1. Excludes any potential benefit from General Partner corporate overhead support in 2016
Adjusted EBITDA Walk-Forward ($mm)(1)
Absolute Control
Some Control
Less Control /
Market Sensitive
2015 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

14. $ 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 items
2. 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

15. Crude Oil Pipelines and Storage
15
• 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

16. 2016 Crude Guidance
Midpoint
SDP Fully Utilized Crude Recovery Potential
EBITDA
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%

17. • 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

18. • 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

19. • 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

20. 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

21. 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, 2015
2. 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

22. Appendix

23. 15
Non-GAAP Reconciliation – Adjusted EBITDA
Nine months ended
September 30,
2015
(in thousands)
Segment AdjustedEBITDA
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 AdjustedEBITDA 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 fromgeneral partner (3,000)
Transaction costs and other (3,033)
Net loss (12,720)$
Net cash (receipts) payments for commodity derivatives
settled during the period

24. Non-GAAP Reconciliation – Distributable Cash Flow
24
Nine months ended
September 30,
2015
Net cash providedby 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 taxexpense 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 fromgeneral partner 3,000
Transaction costs and other 3,033
AdjustedEBITDA 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)