Investor PresentationAugust 2016 1

Cautionary statement

2

This presentation includes forward-looking statements. These statements relate to, among other things, projections of operational volumetrics and improvements, growth projects, cash flows and capital expenditures. We have used the words "anticipate,” "believe," "could," "estimate," "expect," "intend," "may," "plan," "predict," "project," "should," "will," "potential," and similar terms and phrases to identify forward-looking statements in this presentation. Although we believe the assumptions upon which these forward-looking statements are based are reasonable, any of these assumptions could prove to be inaccurate and the forward-looking statements based on these assumptions could be incorrect. Our operations and future growth involve risks and uncertainties, many of which are outside our control, and any one of which, or a combination of which, could materially affect our results of operations and whether the forward-looking statements ultimately prove to be correct. Actual results and trends in the future may differ materially from those suggested or implied by the forward-looking statements depending on a variety of factors, which are described in greater detail in our filings with the SEC. Construction of projects described in this presentation is subject to risks beyond our control including cost overruns and delays resulting from numerous factors. In addition, we face risks associated with the integration of acquired businesses, decreased liquidity, increased interest and other expenses, assumption of potential liabilities, diversion of management’s attention, and other risks associated with acquisitions and growth. Please see our Risk Factor disclosures included in our Annual Report on Form 10-K for the year ended December 31, 2015 filed on March 7, 2016 and on Form 10-Q for the quarter ended March 31, 2016 filed on May 9, 2016. All future written and oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by the previous statements. We undertake no obligation to update any information contained herein or to publicly release the results of any revisions to any forward-looking statements that may be made to reflect events or circumstances that occur, or that we become aware of, after the date of this presentation.

3

American Midstream OverviewKey Business Highlights

Second quarter 2016 Adjusted EBITDA of $36.1 million and Distributable Cash Flow of $25.4 million, an increase of 150% and 165%, from second quarter 2015

Top-tier, second quarter distribution coverage of 1.94 times

AMID asset footprint covers 10,000 square miles of Gulf of Mexico production, and transports a total of 1.6 Bcf/d of natural gas, over 100,000 barrels per day of oil crude, and 45,000 barrels per day of NGLs.

Terminals segment contracted capacity averaged over two million barrels, an increase of 39%

.

¹ ‐ as of 8/9/2016² ‐ At quarter end 6/30/2016

Gross Margin by Segment as of Q2 2016

Gathering and Processing

64%Transmission

23%

Terminals 13%

Market Capitalization¹ 374$ Distribution Coverage² 1.94xCurrent Yield¹ 13.7%

EBITDA² 163$ Total Indebtedness² 678$ Leverage² 4.15x

Total Outstanding Units 50.2

American Midstream Partners, LP ($ millions except units)

$125 - $13585 - 9560 - 70

Adjusted EBITDADistributable Cash FlowGrowth Capital Expenditures

2016 Guidance ($ millions)

Strategically Positioned Asset Portfolio

4Brunswick terminal operations located in Georgia not shown on map. See slide 18 for map..

Asset position, in every major basin provides strong growth footprint

Link and lever philosophy to provide customers with greater optionality and produce stronger returns

Operate assets along the value chain to drive synergies and create operational continuity

Best in Class Fee-Based Cash Flows

5

EBITDA: $66.3 MM

AL $75 MM unit purchase program

Delta House Drop Down of fee-based cash flow driven by deep-water Gulf of Mexico production

6

Track Record of Strategic Growth and Value Creation Acquisitions / Drop Downs: acquire complimentary assets to consolidate, grow and enhance our competitive position

Asset Optimization: link complementary assets to create cost and commercial synergies and repurpose underutilized assets to create new opportunities

Organic Growth and Expansion: expand assets to develop competitive position within existing regions while aggressively pursuing new well connections, interconnects and markets

EBITDA: $31.9 MM

Blackwater Terminal Drop Down diversifies asset platform, adding fee-based cash-flows

High Point System drop down in the Eastern Gulf of Mexico

Equity restructuring of IDRs incentivizes AMID growth

ArcLight Capital (“AL”) acquires controlling interest in AMID general partner

2013 2014 2015 2016

EBITDA: $45.6 MM

Lavaca System acquisition of fee-based gathering system and entry into the Eagle Ford Shale

Republic Midstream crude oil gathering system, central delivery terminal complex, and takeaway pipeline; AMID receives option to purchase interest in Republic

EBITDA(G): $125 -135 MM

$225 MM Gulf of Mexico acquisitions expanding AMID foot print and creating integrated off-shore crude oil and natural gas system

Headquarters relocated from Denver to Houston

7.3x

11.8x

8.2x10.1x 10.5x

15.0x

10.6x

0.0x

5.0x

10.0x

15.0x

AMID PennTex Blueknight JP Energy Martin DCP Midcoast

EV to Adjusted EBITDA

Undervalued vs. Peers in Multiple Metrics

7

4.9x

11.6x

8.2x 7.7x 7.5x

10.3x

5.8x

0.0x

5.0x

10.0x

15.0x

AMID PennTex Blueknight JP Energy Martin DCP Midcoast

Price to Distributable Cash Flow

American Midstream is under valued by approximately 25% versus peers based on full year 2016 estimates

2016 Avg. – 7.0x

2016 Avg. – 9.2x

30% Discount to Peers

20% Discount to Peers

Strategic Gulf Coast Acquisition - Creates Integrated Platform

8

Acquired 200 miles of pipelines from Chevron, including the Henry Gas Gathering System, as well as an additional ~1% interest in Delta House

$225 million acquisition – with better than projected second quarter 2016 results

Partnership is able to leverage off existing asset in the Gulf Coast to expand overall service offering to customers

Terminal Overview Overall terminal utilization of 95% with contracted, fee-

based cash flows

Annualized revenue growth of approximately 30%

Three locations with 2.2 MMBbls of contracted storage

Strategically located facilities, in key markets, serving local refiners and chemical manufacturers

Overview Growth OpportunitiesHarvey Development of 1.3 MMBbls of additional tank storage

and second ship dock

Application submitted to Parish

Estimate capital costs for expansion - $50 - $60 million for tankage, manifold and interconnect at highly attractive EBITDA multiples and estimated in-service early 2018

Brunswick Development of new crude oil customer and associated

tankage

Harvey Over 1 MMBbls of storage capacity

Full-service storage site in the Port of New Orleans, rail, truck, barge, and deep-water service, potential to expand to more than 2 million barrels

Deepwater ship-dock construction complete with capacity to handle vessels with up to a 750-foot

Westwego Over 900 MBbls of storage capacity

Services refiners, chemical manufactures and commodity brokers with incremental storage coming online at low multiples

Accommodate up to a 700-foot vessels

Brunswick Over 200 MBbls of storage capacity

Accommodate vessels with up to a 700-foot vessels

Current Business

9

Transmission Overview 2.5 Bcf/d of capacity with 1.4 Bcf/d subscribed,

comprised of 1,400 miles of pipeline carrying natural gas, crude oil, and NGLs

Fixed-fee, contracted revenue with investment-grade counterparties

Increase connectivity into markets currently not serviced

Current customer requesting incremental capacity with potential for new inter-connects for additional volumes

Current Business Growth OpportunitiesGrowth Strategy Expand transmission assets to handle molecule further

down the value chain

Addition of inter-connects and tie-ins to access incremental volumes

Midla Midla Natchez pipeline expected to be completed by

year end

$8 million of incremental revenue over next four years

High Point Repurpose an underutilized gas pipeline to NGL

transportation service

Alatenn 200 MMcf/d interstate natural-gas pipeline delivering

to industrial customers in northwestern Alabama, as well as to the city gates of Decatur and Huntsville, Alabama

Bamagas 450 MMcf/d natural-gas pipeline serving two power

plants in North Alabama

High Point 650 miles of natural-gas and liquids pipeline in

southeast Louisiana as well as the shallow-water and deep-shelf Gulf of Mexico delivering product to on-shore processing facilities

Midla and MLGT ~198 MMcf/d interstate natural-gas pipeline linking the

Monroe Natural Gas Field and inter-connects with the Transco Pipeline system and Gulf South Pipeline system to customers near Baton Rouge, Louisiana

Current Business

10

Gathering and Processing Overview Gathering positions in all major US basins with over

1,500 miles of pipe and 400 MMcf/d of throughput

Solid footprint for organic growth with ability to provide incremental services to existing customers and nearby connectivity for new customers

Connectivity to production fields, processing facilities and take-away pipelines

Production of approximately 300 Mgal/d with the ability to handle off-spec and sour volumes

Overview Growth OpportunitiesGathering Increase well connectivity

Become NGL shipper & leverage to establish fractionation position

Processing Expand processing volumes; leverage existing

connectivity

Add assets along the value-chain

Bakken 50 miles of pipe and 40,000 Bbl/d of crude and

provides access refinery, rail, and pipeline markets

Eagle Ford 200 miles of pipe and 220 MMcf/d of natural gas to

third party processingEast Texas 710 miles of pipe, 70 MMcf/d of processing 9,750

Bbls/d of NGL fractionation and processing at Chapel Hill; processing (including off-spec), fractionation and rail capabilities at Longview

Gulf Coast On- and off-shore gathering with delivery to

processing and fraction facilities with sour natural-gas treating and cryogenic processing

Permian 200 miles of pipe and 220 MMcf/d of natural gas

cryogenic processing plant and processing of rich gas at Yellow Rose facility

Current Business

11

$31.9$45.6

$66.3

2013 2014 2015 2016G

$125 - $135

3.7x

4.4x 4.6x

~4.0x

2013 2014 2015 2016G

12

$16.2$32.7

$46.6

2013 2014 2015 2016G

$85 - $95

Execution of Balance Sheet Management

Continual Adjusted EBITDA GrowthOngoing Distributable Cash Flow Growth

CAGR = 60%CAGR = 77%

Balance Sheet Fortification and Cash Flow Growth Maintain prudent fiscal discipline and position American

Midstream for growth

Since 2013, 77% CAGR in distributable cash flow

Since 2013, 60% EBITDA growth driven by organic projects and accretive acquisitions

Compelling Total Return Investment

Sustainable Distribution

Fee-based Cash Flow

Strong Balance Sheet

Supportive Sponsor

Growth Visibility

Improved financial flexibility; leverage to ~4.0x in 2016

90% fee-based cash flow – investment grade counterparties

Fee-based organic growth and actively pursuing strategic

Record of multiple, accretive drop downs and significant financial support

Quarterly distribution coverage of 1.9X

13

Diversified Portfolio

Aligned assets across multiple geographic areas

Experienced Team Senior management team averaging 29 years of experience

Appendix: Partnership Overview

14

Gathering and Processing

15

Asset Overviews

System1

Pipeline Design

Capacity (MMcf/d)

Processing Design

Capacity (MMcf/d)

Length of Pipeline (miles)

Longview2* 50 50 620

Chapel Hill2* 20 20 90

Yellow Rose2 40 40 47

Mesquite* - - -

Lavaca 218 N/A 203

Chatom* 25 25 24

Bazor Ridge 22 22 169

Magnolia 120 N/A 116

Burns Point N/A 200 N/A

Quivira 140 N/A 34

Gloria / Lafitte 151 N/A 178

Other Systems 3 100 N/A 56

Total 886 357 1,537

Longview (East Texas) – Acquired October 2014• Gathering system that feeds two cryogenic processing plants in Gregg County, TX• Off-spec processing includes fractionation and stabilization units with 7,000 bbls/d of condensate

and off-spec NGL treating capacityChapel Hill (East Texas) – Acquired October 2014• Gathering system located in Tyler, TX that feeds a cryogenic processing plant, fractionation unit,

190,000 gallons of storage capacity, and truck racks to deliver propaneYellow Rose (Permian) – Acquired October 2014• Gathering and processing system consists of low pressure, rich-gas gathering lines that feed a

processing plant located in Martin County, TXMesquite (Odessa, Texas)• Processing facility with 5,000 bbls/d high RVP condensate treatment and 5,000 bbls/d off-spec NGL

treatment• Operations commenced April 2016Lavaca (Eagle Ford) – Acquired January 2014• Constructed in 2011 and located in the East Oil and East Gas Condensate zones of the Eagle Ford

in Gonzales and Lavaca Counties, TX – 70,000 dedicated acres• Over 200 miles of low- and high-pressure pipeline ranging from three to 12 inches in diameter with

over 31,000 hp of leased compressionChatom (AL / MS state line)• Gathers natural gas from onshore oil and natural gas wells in AL and MS• Provides processing, fractionation and sulfur recovery servicesBazor Ridge (AL / MS state line)• Processes rich associated natural gas from oil wells targeting Upper SmackoverMagnolia (AL) • Intrastate pipeline system gathers coal-bed methane in Central Alabama to sell primarily into the

interstate market as well as a local distribution company, municipality, and small industrial facility• Delivers natural gas to a Transco interconnect• New SNG interconnect and additional compression added in Q4 2015 to meet customer demandBurns Point / Quivira (SE Louisiana)• Quivira gathering system originates in offshore Louisiana and terminates at Burns Point cryogenic

processing plantGloria / Lafitte (SE Louisiana)• Gloria System provides onshore and offshore natural gas gathering, compression, and processing

services in SE Louisiana and Gulf of Mexico• The Lafitte gathering system delivers volumes to local refineryBakken Crude Oil Gathering System (Bakken) – Acquired October 2014• ~50-mile crude oil gathering system with 40,000 bbls/d of design capacity located in the core of

McKenzie County, ND

1. Bakken crude oil gathering system not reflected in chart.2. 2014 throughput reflects daily and average volume from Oct - Dec. 3. Includes Offshore Texas systems. *Longview fractionation capacity of 8,500 bbls/d; Chapel Hill 1,250 bbls/d; Chatom 1,900 bbls/d; and Mesquite 5,000 bbls/d.

Longview operations, East Texas

Transmission

16

Asset Overviews

High Point System (SE Louisiana)• Intrastate system connected to 75+ receipt points that collects

natural gas from both onshore and offshore producing regions in SE Louisiana and the shallow-water and deep-shelf Gulf of Mexico

• System comprised of FERC-regulated transmission assets and non-jurisdictional gathering assets

• Gulf of Mexico water depths up to 500 feet with focus on oil and liquids-rich reservoirs

• Delivers to TOCA gas processing plant, operated by EnterpriseAlaTenn / Bamagas / Trigas (Primarily northern Alabama)• FERC-regulated interstate (AlaTenn) and intrastate (Bamagas and

Trigas) gas pipelines supply natural gas to industrial end-users, local distribution companies, and municipal markets including cities of Athen, Decatur and Huntsville, Alabama

• 100% of Bamagas capacity of 450 MMcf/d contracted under long-term firm transportation agreements

Midla/MLGT (Eastern Louisiana)• FERC-regulated (“Midla”) interstate pipeline linking Monroe natural

gas field in Northern Louisiana and other supply interconnects to various power plants owned by Entergy, serving local distribution companies and municipalities in Louisiana and Mississippi including Vidalia, Louisiana and Natchez, Mississippi

• Midla received FERC approval to construct the Midla-Natchez pipeline with completion expected late 2016

• MLGT is an intrastate pipeline that serves the Baton Rouge Area in southern Louisiana with investment-credit grade rated customers

Chalmette (SE Louisiana)• Intrastate asset serving industrial markets in Southeast New

Orleans, LA

System

Approx. Pipeline Design

Capacity (MMcf/d)

Length of Pipeline (miles)

High Point 1,120 574

AlaTenn/Bamagas/ Trigas 710 383

Midla/MLGT 518 432

Chalmette 125 39

Total 2,473 1,428

Duncanville Compressor Station, Magnolia

Terminals

17

Asset Overviews

• Three facilities: Westwego, LA; Harvey, LA; Brunswick, GA• Majority of revenues derived from fee-based, “take-or-pay” storage

agreements with remainder from fee-based ancillary services• Primary products stored include: caustic soda, vacuum gas oil, D.E.A.,

asphalt, fertilizer (UAN), synthetic drilling fluids, vegetable oils, biodiesel

• Harvey is a full-service storage site, providing rail, truck, barge, and deep-water service with the potential to expand to more than 2 million barrels of storage capacity

• Harvey and Westwego deep-water docks allow for vessels of up to 700 feet length overall (“LOA”) and 750 feet LOA, respectively

Terminal

Terminal Storage Capacity (Mbbls)

Year Ended

12/31/14

Contracted Capacity 12/31/14

Year Ended

12/31/15

Contracted Capacity 12/31/15

Westwego 1,045 100% 1,045 93.9%

Harvey 238 16.4% 535 72.9%

Brunswick 221 100% 221 100%

Total 1,504 86.8% 1,801 88.4%

Harvey Deepwater ShipdockTerminal Locations

Gulf of Mexico Joint Ventures and Investments

18

Interest OverviewSystem

Interest Held

Pipeline (miles) Product

Design Capacity

Delta House 13.9% - - -

Destin 49.7% 255 Natural Gas 1.2 Bcf/d

Okeanos 66.7% 100 Natural Gas 1.0 Bcf/d

Wilprise 25.3% 30 Liquids 60,000 Bbls/d

Tri-States 16.7% 161 Liquids 80,000 Bbls/d

Other 60.0% 200 Natural Gas / Saltwater

n/a

Main Pass Oil Gathering

66.7% 98 Oil 160,000 Bbls/d

Delta House Floating Production System

Delta House• Floating production system located in the Mississippi Canyon region in

deepwater Gulf of Mexico; operated by LLOG exploration• 10 wells online with life-of-lease dedication for production handling and a

fixed fee-based structure on oil and gas export pipelines• Nameplate capacity of 80,000 Bbl/d oil and 200 MMcf/d of gas and peak

processing capacity of 100,000 Bbl/d oil and 240 MMcf/d of gasDestin• FERC-regulated gas pipeline• 120-mile offshore portion moves gas from producing platforms, including

Delta House to MP260 and continuing to Pascagoula processing plant• 135-mile onshore portion transports gas to multiple pipelines and storage

facilities in MississippiOkeanos• Gas gathering system that connects multiple producer platforms to MP260 Tri-States and Wilprise• FERC-regulated NGL pipelines• Tri-States receives gas from three plants and terminates at Kenner

Junction, feeding one fractionation facility and two NGL pipelines• Tri-States connects to Wilprise pipeline at Kenner Junction and terminates

in Sorrento, LouisianaOther• Joint venture with Panther of natural gas, oil, and saltwater pipelines;

acquired from Chevron • AMID to operate ~110 miles of natural gas and saltwater pipelines,

including Henry Gas Gathering SystemMain Pass Oil Gathering • Joint venture with Panther• Crude gathering system located offshore southeast Louisiana

Appendix: Non-GAAP Financial Measures

19

Non-GAAP Financial MeasuresThis presentation includes forecasted and historical non-GAAP financial measures, including “Gross Margin,” “Adjusted EBITDA” and “Distributable Cash Flow.” Each has important limitations as an analytical tool because it excludes some, but not all, items that affect the most directly comparable GAAP financial measures. Management compensates for the limitations of these non-GAAP financial measures as analytical tools by reviewing the nearest comparable GAAP financial measures, understanding the differences between the measures and incorporating these data points into management’s decision-making process.

You should not consider any of gross margin, Adjusted EBITDA or DCF in isolation or as a substitute for or more meaningful than our results as reported under GAAP. Gross margin, Adjusted EBITDA and DCF may be defined differently by other companies in our industry. Our definitions of these non-GAAP financial measures may not be comparable to similarly titled measures of other companies, thereby diminishing their utility.

We define Adjusted EBITDA as net income (loss) attributable to the Partnership, plus interest expense, income tax expense, depreciation, amortization and accretion expense, certain non-cash charges such as non-cash equity compensation expense, unrealized losses on commodity derivative contracts, debt issuance costs, return of capital from unconsolidated affiliates, transaction expenses and selected charges that are unusual or nonrecurring, less interest income, income tax benefit, unrealized gains on commodity derivative contracts, and selected gains that are unusual or nonrecurring. The GAAP measure most directly comparable to our performance measure Adjusted EBITDA is Net income (loss) attributable to the Partnership.

DCF is a significant performance metric used by us and by external users of the Partnership's financial statements, such as investors, commercial banks and research analysts, to compare basic cash flows generated by us to the cash distributions we expect to pay the Partnership's unitholders. Using this metric, management and external users of the Partnership's financial statements can compute the coverage ratio of estimated cash flows to planned cash distributions. DCF is also an important financial measure for the Partnership's unitholders since it serves as an indicator of the Partnership's success in providing a cash return on investment. Specifically, this financial measure may indicate to investors whether we are generating cash flow at a level that can sustain or support an increase in the Partnership's quarterly distribution rates. DCF is also a quantitative standard used throughout the investment community with respect to publicly traded partnerships and limited liability companies because the value of a unit of such an entity is generally determined by the unit's yield (which in turn is based on the amount of cash distributions the entity pays to a unitholder). DCF will not reflect changes in working capital balances.

We define DCF as Adjusted EBITDA plus interest income, less cash paid for interest expense, normalized maintenance capital expenditures, and dividends related to the Series A and Series C convertible preferred units. The GAAP financial measure most comparable to DCF is Net income (loss) attributable to the Partnership.

The GAAP measure most directly comparable to forecasted Adjusted EBITDA and DCF is forecasted net income (loss) attributable to the Partnership. Net income (loss) attributable to the Partnership is forecasted to be approximately $20 million to $25 million in 2016.

Segment gross margin and gross margin are metrics that we use to evaluate our performance. We define segment gross margin in our Gathering and Processing segment as revenue generated from gathering and processing operations and realized gains or (losses) on commodity derivatives, less the cost of natural gas, crude oil, NGLs and condensate purchased and revenue from construction, operating and maintenance agreements ("COMA"). Revenue includes revenue generated from fixed fees associated with the gathering and treatment of natural gas and crude oil and from the sale of natural gas, crude oil, NGLs and condensate resulting from gathering and processing activities under fixed-margin and percent-of-proceeds arrangements. The cost of natural gas, NGLs and condensate includes volumes of natural gas, NGLs and condensate remitted back to producers pursuant to percent-of-proceeds arrangements and the cost of natural gas purchased for our own account, including pursuant to fixed-margin arrangements.

We define segment gross margin in our Transmission segment as revenue generated from firm and interruptible transportation agreements and fixed-margin arrangements, plus other related fees, less the cost of natural gas purchased in connection with fixed-margin arrangements. Substantially all of our gross margin in this segment is fee-based or fixed-margin, with little to no direct commodity price risk.

We define segment gross margin in our Terminals segment as revenue generated from fee-based compensation on guaranteed firm storage contracts and throughput fees charged to our customers less direct operating expense which includes direct labor, general materials and supplies and direct overhead.

We define gross margin as the sum of our segment gross margin for our Gathering and Processing, Transmission and Terminals segments. The GAAP measure most directly comparable to gross margin is net income (loss) attributable to the Partnership.

20

Appendix: Non-GAAP Financial Measures (IN $ MILLIONS)

21

2016 2015Reconciliation of Adjusted EBITDA to Net income (loss) attributable to the Partnership:Net income (loss) attributable to the Partnership (4,583)             (2,065)            Add:Depreciation, amortization and accretion expense 10,690             9,250              Interest expense 5,937               3,360              Debt issuance costs 1,340               46                    Unrealized (gain) loss on derivatives, net 2,555               (157)                Non‐cash equity compensation expense 1,025               550                  Transaction expenses 3,782               ‐                       Income tax expense 540                   297                  Proceeds from equity method investment, return of capital 14,916             496                  

Deduct:COMA income (23)                    229                  OPEB plan net periodic benefit 4                       3                      Other, net (a) (19)                    232                  Gain (loss) on sale of assets, net 80                     (2,970)             

Adjusted EBITDA 36,141            14,515           Deduct:Cash interest expense 5,909               3,325              Normalized maintenance capital 1,084               1,550              Series A and C Convertible Preferred Payment 3,751               ‐                       

Distributable Cash Flow 25,397            9,640              

Three months ended June 30,