Investor Presentation 3Q16 Financial Results April 2017 November - - PowerPoint PPT Presentation

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Investor Presentation 3Q16 Financial Results April 2017 November - - PowerPoint PPT Presentation

Hegh LNG Partners LP The Floating LNG Infrastructure MLP Investor Presentation 3Q16 Financial Results April 2017 November 17, 2016 Forward-Looking Statements This presentation contains certain forward-looking statements concerning future


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SLIDE 1

Höegh LNG Partners LP – The Floating LNG Infrastructure MLP 3Q16 Financial Results November 17, 2016 Investor Presentation April 2017

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SLIDE 2

Forward-Looking Statements

2 This presentation contains certain forward-looking statements concerning future events and our operations, performance and financial condition. Forward- looking statements include, without limitation, any statement that may predict, forecast, indicate or imply future results, performance or achievements, and may contain the words “believe,” “anticipate,” “expect,” “estimate,” “project,” “will be,” “will continue,” “will likely result,” “plan,” “intend” or words or phrases

  • f similar meanings. These statements involve known and unknown risks and are based upon a number of assumptions and estimates that are inherently

subject to significant uncertainties and contingencies, many of which are beyond our control. Actual results may differ materially from those expressed or implied by such forward-looking statements. Important factors that could cause actual results to differ materially include, but are not limited to: FSRU and LNG carrier market trends, including hire rates and factors affecting supply and demand; our anticipated growth strategies; our anticipated receipt of dividends and repayment of indebtedness from subsidiaries and joint ventures; the effects of volatility in global prices for crude oil and natural gas; the effect of the worldwide economic environment; turmoil in the global financial markets; fluctuations in currencies and interest rates; general market conditions, including fluctuations in hire rates and vessel values; changes in our operating expenses, including drydocking and insurance costs; our ability to make or increase cash distributions on the units and the amount of any such distributions; our ability to comply with financing agreements and the expected effect of restrictions and covenants in such agreements; the future financial condition of our existing or future customers; our ability to make additional borrowings and to access public equity and debt capital markets; planned capital expenditures and availability of capital resources to fund capital expenditures; the exercise of purchase options by customers; our ability to maintain long-term relationships with our customers; our ability to leverage the relationships of Höegh LNG Holdings (“HLNG”) and its reputation in the shipping industry; our ability to purchase the 49% interest in the Höegh Grace entities or additional vessels from Höegh LNG in the future; our ability to integrate and realize the anticipated benefits from the acquisition of the 51% interest in the Höegh Grace entities; our continued ability to enter into long-term, fixed-rate charters; the operating performance of our vessels; our ability to maximize the use of our vessels, including the redeployment or disposition of vessels no longer under long-term charters; expected pursuit of strategic

  • pportunities, including the acquisition of vessels; our ability to compete successfully for future chartering and newbuilding opportunities; timely acceptance
  • f our vessels by their charterers; termination dates and extensions of charters; the cost of, and our ability to comply with, governmental regulations and

maritime self-regulatory organization standards, as well as standard regulations imposed by our charterers applicable to our business; demand in the FSRU sector or the LNG shipping sector in general and the demand for our vessels in particular; availability of skilled labor, vessel crews and management; our incremental general and administrative expenses as a publicly traded limited partnership and our fees and expenses payable under the ship management agreements, the technical information and services agreement and the administrative services agreements; the anticipated taxation of Höegh LNG Partners LP and distributions to our unitholders; estimated future maintenance and replacement capital expenditures; our ability to retain key employees; customers’ increasing emphasis on environmental and safety concerns; potential liability from any pending or future litigation; potential disruption of shipping routes due to accidents, political events, piracy or acts by terrorists; future sales of our common units in the public market; our business strategy and other plans and objectives for future operations; our ability to successfully remediate any material weaknesses in our internal control

  • ver financial reporting and our disclosure controls and procedures; and other factors listed from time to time in the reports and other documents that we

file with the SEC, including our Annual Report on Form 20-F for the year ended December 31, 2016 and subsequently quarterly reports on Form 6-K. All forward-looking statements included in this presentation are made only as of the date hereof. We do not intend to release publicly any updates or revisions to any forward-looking statements contained herein to reflect any change in our expectations with respect thereto or any change in events, conditions or circumstances on which any such statement is based.

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SLIDE 3

3

Glossary

  • “HMLP” – Höegh LNG Partners LP
  • “HLNG” – Höegh LNG Holdings Ltd.
  • “Höegh LNG Group” – HMLP and HLNG
  • “Grace Holding” – The sole owner of the entities that own and operate the Höegh Grace
  • “FSRU” – Floating Storage and Regasification Unit
  • “ABKN” – AB Klaipedos Nafta
  • “EGAS” – Egyptian Natural Gas Holding Company
  • “PGN” – Perusahaan Gas Negara
  • “GNL Penco” – Import terminal in Chile (JV of Biobiogenera , Cheniere and EDF)
  • “SPEC” – Sociedad Portuaria El Cayao S.A. E.S.P. (JV of Promigas and private equity)
  • “GEI” – Global Energy Infrastructure Ltd.
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SLIDE 4

4

Höegh LNG Partners LP – A Differentiated LNG Infrastructure Provider

(1) $6.2 billion of firm contract backlog across Höegh LNG Group; backlog is calculated as the full monthly hire rate multiplied by the number of months remaining on the contract, assuming full utilization. (2) Consists of approximately 10.7% of the total outstanding common units and 100% of the outstanding subordinated units. HLNG also holds all of the incentive distribution rights.

A Growth-Oriented MLP Providing Critical Energy Infrastructure on Stable, Long-term Contracts

Operations world-wide:

  • The only pure play FSRU company
  • Most modern FSRU fleet in the market
  • 12.2 years average remaining contract length
  • Firm contract backlog of $2.2 billion(1)

53.6% Höegh LNG Holdings Ltd. (Oslo Børs: HLNG) 46.4%(2) LNG Infrastructure asset development MLP Investors

Höegh LNG Group

Green – operational Yellow – development

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SLIDE 5

5

Höegh LNG Partners LP (NYSE:HMLP) – Investment Summary

  • The only publicly listed FSRU pure play
  • Current fleet of five FSRUs on long-term, fixed-rate contracts

Pure Play Owner and Operator of FSRUs

  • Average vessel age of 3.8 years(1)
  • Meeting critical energy infrastructure needs
  • Leading player in highly concentrated FSRU market

Modern Fleet Providing Critical Energy Infrastructure

  • Average remaining contract term of 12.2 years plus options(2)
  • Earliest contract expiry in 2025(3), with no near-term debt maturities
  • No direct commodity exposure and limited Opex exposure(4)

Full Employment on Fixed, Long-term Contracts

  • Committed pipeline of high-quality dropdown assets
  • Dropdowns typically evaluated once assets go on long-term contract
  • Accretive acquisitions of FSRUs expected to drive distribution growth

Dropdown Pipeline for Built-in Distribution Growth

  • LNG is especially competitive fuel at current prices
  • Readily available LNG supply drives FSRU adoption globally
  • Oil and coal displacement with environmental benefits over both

Attractive FSRU Market Conditions

  • Recognized leader in the LNG space for 40+ years
  • Extensive technical and maritime expertise and relationships
  • Favorable financing terms highlight value of sponsor support

Supportive, Industry-Leading Sponsor

(1) As of March 31, 2017 (2) As of March 31, 2017 including the Höegh Grace, 19.2 years including options (3) Includes HMLP option to charter FSRU Höegh Gallant to HLNG after end of EGAS contract (4) Extent of Opex exposure depends on vessel contract

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6

Stable Cash Flows, Fully Covered Distributions and Growth

15.2 15.2 16.1 25.7 24.1 24.3 24.9 25.8 5 10 15 20 25 30 1Q15 2Q15 3Q15 4Q15 1Q16 2Q16 3Q16 4Q16

Segment EBITDA(1)(2),$m

9.6 9.1 9.2 12.9 11.0 12.7 12.5 13.3 0.0 5.0 10.0 15.0 20.0 25.0 30.0 1Q15 2Q15 3Q15 4Q15 1Q16 2Q16 3Q16 4Q16

Distributable Cash Flow(1), $m

+22%

Distribution

Coverage(1):

1.18x 1.0x 1.15x 1.14x 0.97x(3) 1.21x(4) 6.8 6.8 7.6 9.9 8.0 7.9 8.8 8.1 0.0 5.0 10.0 15.0 20.0 25.0 30.0 1Q15 2Q15 3Q15 4Q15 1Q16 2Q16 3Q16 4Q16

  • Adj. Net Income(1), $m

(1) Adjusted Net Income, Segment EBITDA, Distributable cash flow and Coverage are non-GAAP financial measures. For a definition of each of these non-GAAP financial measures and reconciliations to their most directly comparable US GAAP financial measure, please see the Appendix. (2) Excludes principal payment on direct financing lease, amortization in revenues for above market contracts and equity in earnings of JVs: amortization for deferred revenue. (3) 0.97x based on distribution for 4Q16 (4) Reflects distribution coverage on units existing prior to common unit offering in December 2016.

0.3375 0.3375 0.3375 0.4125 0.4125 0.4125 0.4125 0.4125 0.43

0.0 0.1 0.2 0.3 0.4 0.5 0.6 1Q15 2Q15 3Q15 4Q15 1Q16 2Q16 3Q16 4Q16 1Q17

Distribution, $/unit

+4.24%

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SLIDE 7

Floating Storage and Regasification Units

(“FSRUs”)

7

FSRUs Provide a Critical Link in the Global LNG Supply Chain

Seaborne Transportation Regasification Market Liquefaction Downstream Midstream Upstream Production

Floating regasification grants access to inexpensive global LNG with a significant advantage in both cost and lead-time vs. an onshore import terminal

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SLIDE 8

The Decision to Contract an FSRU

8

Security of supply Seasonal demand Back-up for hydro Transportation Balance of trade New gas fired generation

  • China, Lithuania,

ME

  • Colombia, Brazil
  • India, Pakistan,

Bangladesh

  • Lithuania
  • Egypt imports to

cover gas deficit

  • Indonesia (intra-

country LNG trade)

  • Colombia, Ghana,

Ivory Coast and South Africa

Competitively priced LNG increasingly makes natural gas attractive for baseload generation

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SLIDE 9

The FSRU – The Fastest and Most Cost Effective Path to LNG Imports

9

  • Compared to land-based terminals, an FSRU offers the following advantages:
  • Half the time: six months to three years (order in advance)
  • Half the cost: $0.3/MMBtu*
  • Limited environmental footprint: terminal is floating, mooring can be removed
  • Flexibility: can be relocated, re-employed, or traded as LNG carrier

*Based on open loop and full utilization

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SLIDE 10

10

Successful Follow-on Offering and Acquisition of Höegh Grace

Acquisition

  • 51% Höegh Grace
  • $370 million gross valuation
  • Minimum 10-year contract
  • Closed Jan 3, 2017
  • Management has recommended to the

board 4-5% distribution increase for 1Q17

Follow-on

  • $112 million net proceeds
  • $92 million cash consideration for Höegh

Grace

  • Upsized on strong demand
  • New unit count of 32,911,159(1)
  • HMLP trading liquidity much improved

(1) Consisting of 19,755,099 common units and 13,156,060 subordinated units

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11

HMLP Fleet Enlarged and Diversified to Five FSRUs

Neptune

  • Operating as an FSRU in Turkey under subcontract from Engie
  • Higher revenue and cost in JV segment reflect preparatory work in 4Q16

GDF Suez Cape Ann

  • Departed China – returned to Engie’s LNGC pool pending future FSRU project –

contract rate remains unchanged

PGN FSRU Lampung

  • Located offshore Sumatra, Indonesia, to replace imported liquid fuels with

domestic LNG to support electricity demand

Höegh Gallant

  • Chartered by EGAS to cover Egypt’s deficit in domestic gas supply
  • Maintenance in 1Q17 expected to reduce hire by approximately 5 days equivalent

Höegh Grace

  • Chartered by SPEC to service a new LNG import terminal in Cartagena, on the

Atlantic coast of Colombia

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SLIDE 12

Unit Type Ownership Built Region Charterer 2 1 8 2 2 2 2 2 2 2 4 2 2 6 2 2 8 2 3 2 3 2 2 3 4 2 3 6 2 3 8 Current HMLP Fleet Neptune FSRU 50% 2009 Turkey Engie GDF Suez Cape Ann FSRU 50% 2010 China Engie PGN FSRU Lampung FSRU 100% 2014 Indonesia PGN Höegh Gallant FSRU 100% 2014 Egypt EGAS/HLNG Höegh Grace FSRU 51% 2016 Colombia SPEC Contracted Revenue Option

Long-Term Contracts with Stable Cash Flows and Distribution Coverage

12

(1) Economic interest; ownership interest 49% (2) Previously GDF-Suez (3) As of March 31, 2017 (2) (1) (2)

  • 12.2 years(3) average remaining contract length, with earliest expiry in 2025(4)
  • No direct exposure to volatile commodity prices and limited Opex exposure(5)
  • Strong sovereign and utility counterparties reliant on HMLP for crucial energy infrastructure

– Additional guarantee from HLNG in case of FSRU Höegh Gallant Fixed Rate, Contracted Cash Flow Supports Growing, Long-Term Distributions

(4) Includes HMLP option to charter FSRU Höegh Gallant to HLNG after end of EGAS contract (5) Extent of Opex exposure depends on contract

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SLIDE 13

Unit Type Ownership Built Region Charterer 2018 2020 2022 2024 2026 2028 2030 2032 2034 2036 2038 Dropdown Candidates at HLNG Independence FSRU 100% 2014 Lithuania ABKN Höegh Grace FSRU 49% 2016 Colombia SPEC HN2552 FSRU 100% 2017E Ghana Quantum Power HN2865 FSRU 100% 2018E Pakistan GEIL HN2909 FSRU 100% 2018E

  • Open

SHI NB FSRU 100% 2019E Chile GNL Penco Contracted Revenue Option

(2) (1)

New Long-Term Contract Awards Provide an Opportunity to Drive Distribution Growth

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(1) Subject to negotiation of definitive terms, approval by the conflicts committee of HMLP, the boards of directors of HMLP and HLNG and execution of definitive documentation. There can be no assurance that any transaction will be consummated. (2) Dropdown requires charterer consent (3) Subject to various conditions

  • HLNG awarded two new FSRU contracts in 4Q17 – Ghana and Pakistan(3)
  • 20 year contracts provide long-term stability and visibility
  • Participation of resource owning “supermajors” in Pakistan project
  • Flexibility to reassign units between projects to better match delivery and start-up dates
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SLIDE 14

Delivering In Accordance With Strategy

14

Ordered newbuilding Ordered newbuilding Long-term contract Long-term contract

  • 20 year contract with

GEI in Pakistan with startup 2Q 2018

  • Annual EBITDA:

USD 36 million

  • Signed LOI for one

plus three optional FSRU newbuildings

  • Firm agreement

signed 17 January 2017

  • 20 year contract with

Quantum Power in Ghana with startup 2018

  • Annual EBITDA:

USD 36 million

  • Signed shipbuilding

contract for one FSRU newbuilding

  • Delivery 4Q 2018

Refinanced bond

  • Issued new 5yr NOK

1,500 million senior unsecured bond

  • 13% buyback of

HLNG01

Raised equity in HMLP

  • Sold 51% of Höegh

Grace to HMLP

  • HMLP raised USD

112 million

Financing milestones Commercial milestones

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SLIDE 15

(2014) (2015) (2017) (2018) (2018/19) (T+12mo) (2020) (2017)

Another Milestone in HMLP’s Growth Trajectory

  • 51% of Höegh Grace is the first step on path to HMLP’s goal of doubling in size by 2020

and diversifying its portfolio

  • Increased diversification set to add to a strong track-record of project execution
  • Strong FSRU fundamentals and support of HLNG underpin trajectory

Anticipated(1) Expected to be offered to HMLP at start

  • f 5yr+ contract(1)

T Date of order Existing HMLP Fleet

(2019)

(1) There can be no assurance that any acquisition or dropdown transactions will be consummated.

15

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SLIDE 16

Accelerating FSRU Contracts Reflect LNG’s Attractiveness and Availability

2011 2012 2013 2014 2015 2016 BW Gas

 

Excelerate

   

Golar LNG

       

Sum 3 2 2 4 3 6

16

(1) Does not include cancelled projects, contract renewals and sublets Source: Press releases / public disclosures

Long-term FSRU contract award(1)

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SLIDE 17

Ghana FSRU to Import Competitively Priced LNG

  • Key terms: 20 + 5 years,

EBITDA USD ~36m annually, startup 2Q 2018

  • Counterpart: Quantum Power

(QP), FSRU #7

  • Strategic rationale: Replace

expensive liquid oil products with LNG and to cover energy deficit in power generation

  • Structure: HLNG charters FSRU

to QP, which builds the mooring system and pipeline to shore. QP has the Tolling Agreement with GNPC where GNPC pays a fixed fee to QP for the FSRU, pipeline and other infrastructure services. GNPC imports LNG and sells regasified LNG to the end consumers

17

Source: Navionics maps, Quantum Power

New pipeline to be provided by Quantum Power

FSRU site

Port of Tema and the offshore FSRU infrastructure

Spread mooring system (QP) Pipeline to shore (QP)

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SLIDE 18

Pakistan FSRU Project on Schedule for Mid 2018 Startup

18

  • Key terms: 20 + 5 + 5 years,

EBITDA USD ~36m annually, startup 2Q 2018

  • Counterpart: Global Energy

Infrastructure (GEI), FSRU#9

  • Rationale: Cover energy deficit

in power production and industry by using low cost LNG

  • HoA between a consortium of

Qatar Petroleum, ExxonMobil, Total, Mitsubishi Corp. and Höegh LNG for the construction

  • f the terminal less FSRU
  • Structure: GEI has LNG

purchase agreements (Qatargas) and will sell the regasified LNG in the domestic market. HLNG charters the FSRU to GEI, the consortium provides the terminal infrastructure to GEI under a Tolling Agreement

FSRU site

Source: Navionics maps

Easy access from sea

Port Qasim and the GEI FSRU project

16 km offshore pipeline route, to be constructed by the consortium Independence-like jetty to be constructed by the consortium Onshore gas grid LNG from world markets Onshore facilities

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SLIDE 19

Höegh LNG Group’s FSRUs and the Opportunity Set for the Future

19 Smaller markets targeted by barges and conversions

In Operation 21 Under Construction 12 Planned or Possible >40

Source: Press releases / public disclosures

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The Market Metrics that are Capturing the Attention of LNG Consumers

5 10 15 20 25

Contracted LNG price discount to oil maintained

Brent Japan LNG ($/MMBTU) 5 10 15 20 25

LNG's price advantage over oil increasing

Brent LNG Singapore Spot ($/MMBTU) 2 4 6 8 10 12

Gas increasingly competitive against coal in Europe

NBP ARA Coal ($/MMBTU) 10 20 30 40 50 60

Projected Top LNG Suppliers - 2020

100 200 300 400 500

LNG expected to remain attractively priced

LNG Supply LNG Contracted (MTPA)

CO2 ↓ NO2 ↓ Efficiency ↑ Flexibility ↑ Energy Security ↑

Source: Bloomberg, Poten & Partners, Japanese Ministry of Economy, Trade and Industry

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SLIDE 21

LNG Volumes Expanding on Liquefaction Capacity Additions

  • LNG production rose by 17mt, or

by ~7%, in 2016

 The first year of meaningful growth since 2011

  • Liquefaction capacity was 37mt

higher y/y at end-2016; utilization

  • f newly added capacity to

increase in 2017

  • 35 countries imported LNG in

2016, up from 18 ten years ago

  • Several countries started

importing LNG in 2016 : Colombia, Jamaica, Pakistan

21

Liquefaction capacity and production 2000 - 2022

Source: Clarksons Platou, Shell LNG outlook 2017

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SLIDE 22

New Market Entrants Prefer FSRUs for Their LNG Imports

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~80% FSRUs ~65% FSRUs Mostly land based terminals New markets1 Recent market entrants2,3 Established LNG markets

LNG importing countries: Existing and planned/potential

Already have FSRUs FSRUs planned or under construction Have FSRUs, but market is dominated by land based terminals

Source: Cheniere 3Q16 presentation, amended by Höegh LNG

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SLIDE 23

More Fragmented Competition, But Limited Orderbook

  • The orderbook stands at 12

FSRUs, of which 4 are uncommitted

  • Uncommitted FSRUs (4

newbuildings, 1 existing vessel) compare to 14% of the total fleet and orderbook

  • f FSRUs
  • Four existing FSRUs are

serving contracts that are about to expire, or at contracts with undetermined timelines

23

6 8 7 1 1 1 3 1 1 3 1 1 2 2 4 6 8 10 12 Höegh LNG Excelerate Golar LNG BW Gas Other Units

FSRU fleet and orderbook1 by owner and employment

On contract Available Committed NB Uncommitted NB

OLT MOL Gazprom Exmar Maran Kolin

1 Orderbook defined as firm orders, excluding LOIs, options, conversions

FSRU fleet and orderbook1 by owner and employment

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Höegh LNG Partners LP (NYSE:HMLP) – Investment Summary

  • The only publicly listed FSRU pure play
  • Current fleet of five FSRUs on long-term, fixed-rate contracts

Pure Play Owner and Operator of FSRUs

  • Average vessel age of 3.8 years(1)
  • Meeting critical energy infrastructure needs
  • Leading player in highly concentrated FSRU market

Modern Fleet Providing Critical Energy Infrastructure

  • Average remaining contract term of 12.2 years plus options(2)
  • Earliest contract expiry in 2025(3), with no near-term debt maturities
  • No direct commodity exposure and limited Opex exposure(4)

Full Employment on Fixed, Long-term Contracts

  • Committed pipeline of high-quality dropdown assets
  • Dropdowns typically evaluated once assets go on long-term contract
  • Accretive acquisitions of FSRUs expected to drive distribution growth

Dropdown Pipeline for Built-in Distribution Growth

  • LNG is especially competitive fuel at current prices
  • Readily available LNG supply drives FSRU adoption globally
  • Oil and coal displacement with environmental benefits over both

Attractive FSRU Market Conditions

  • Recognized leader in the LNG space for 40+ years
  • Extensive technical and maritime expertise and relationships
  • Favorable financing terms highlight value of sponsor support

Supportive, Industry-Leading Sponsor

(1) As of March 31, 2017 (2) As of March 31, 2017 including the Höegh Grace, 19.2 years including options (3) Includes HMLP option to charter FSRU Höegh Gallant to HLNG after end of EGAS contract (4) Extent of Opex exposure depends on vessel contract

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SLIDE 25

Appendix

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SLIDE 26

26

Accounting for 51% Höegh Grace

  • HMLP will consolidate in its financial statements the Höegh Grace for Q1 2017 with:
  • 100% of time charter revenues and 100% of the expenses for the Höegh Grace in

the individual line items of the income statement

  • Income statement will reflect:
  • Non-controlling interest for the 49% of the net income of the Höegh Grace
  • Controlling interest for HMLP’s share of net income
  • 100% of assets and 100% of the liabilities for the Höegh Grace in the individual line

items of the balance sheet

  • Balance sheet will reflect as a separate component of total equity:
  • Non-controlling interest
  • Partner’s equity
  • Segment EBITDA will include 51% of the Höegh Grace’s EBITDA in the segment profit

measure

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27

Prudent Replacement Capex, Coverage and Debt Maturity Profile

107 62 17 170 119 0.0 0.5 1.0 1.5 2.0 2.5 20 40 60 80 100 120 140 160 180 200 3q16 4q16 1q17 2q17 3q17 4q17 1q18 2q18 3q18 4q18 1q19 2q19 3q19 4q19 1q20 2q20 3q20 4q20 2021 2022 Contract backlog, $bn Maturing debt, $m

Maturity of HMLP debt

$34m Seller's Credit / RCF Bank debt balloon Bank debt amortization Contract backlog $85m RCF (2020)(2)

Gallant(1) Lampung(1) Grace #1(1) (1) Excludes export credit tranches on Lampung, Gallant and Grace#1 that are repaid over 12 years provided commercial tranches are refinanced (2) $10.2 million drawn as of March 2017 (3) Based on existing HMLP assets only

  • First debt maturity in 2019 at which time firm contracted backlog is expected to exceed

$1.5 billion(3)

  • Amortization of bank debt partially offset by $85 million RCF from HLNG(2)
  • Steady deleveraging through replacement capex and coverage
  • Scope to refinance Seller’s Credit and RCF externally
  • Importantly, replacement capex includes provision for dry-docking if for HMLP’s account

Neptune CA

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SLIDE 28

28

Income Statement

Three months ended Year ended December 31, December 31, (in thousands of U.S. dollars) 2016 2015 2016 2015 REVENUES Time charter revenues $ 23,308 23,426 91,107 $ 57,465 Total revenues 23,308 23,426 91,107 57,465 OPERATING EXPENSES Vessel operating expenses (3,372) (4,136) (16,080) (9,679) Construction contract expenses — — (315) — Administrative expenses (2,682) (2,435) (9,718) (8,733) Depreciation and amortization (2,639) (2,630) (10,552) (2,653) Total operating expenses (8,693) (9,201) (36,665) (21,065) Equity in earnings (losses) of joint ventures 18,632 8,012 16,622 17,123 Operating income (loss) 33,247 22,237 71,064 53,523 FINANCIAL INCOME (EXPENSE), NET Interest income 160 293 857 7,568 Interest expense (6,135) (6,517) (25,178) (17,770) Gain (loss) on derivative instruments 661 482 1,839 949 Other items, net (554) 632 (3,333) (2,678) Total financial income (expense), net (5,868) (5,110) (25,815) (11,931) Income (loss) before tax 27,379 17,127 45,249 41,592 Income tax expense (2,446) (52) (3,872) (313) Net income (loss) $ 24,933 17,075 41,377 $ 41,279

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SLIDE 29

29

Segment Reporting

(1) Segment EBITDA is a non-GAAP financial measure. For a definition of Segment EBITDA and reconciliations to net income, the most directly comparable US GAAP financial measure, please see the Appendix. (2) Eliminations reverse each of the income statement line items of the proportional consolidation amounts for Joint venture FSRUs and record the Partnership’s share of the Joint venture FSRUs’ net income (loss) to Equity in earnings (loss) of joint ventures.

Three months ended December 31, 2016 Joint venture Majority FSRUs Total held (proportional Segment Elimin- Consolidated (in thousands of U.S. dollars) FSRUs consolidation) Other reporting ations (2) reporting Time charter revenues $ 23,308 11,218 — 34,526 (11,218) $ 23,308 Total revenues 23,308 11,218 — 34,526 23,308 Operating expenses (3,999) (2,626) (2,055) (8,680) 2,626 (6,054) Equity in earnings (losses) of joint ventures — — — — 18,632 18,632 Segment EBITDA(1) 19,309 8,592 (2,055) 25,846 Depreciation and amortization (2,639) (2,395) — (5,034) 2,395 (2,639) Operating income (loss) 16,670 6,197 (2,055) 20,812 33,247 Gain (loss) on derivative instruments 661 16,120 — 16,781 (16,120) 661 Other financial income (expense), net (5,412) (3,685) (1,117) (10,214) 3,685 (6,529) Income (loss) before tax 11,919 18,632 (3,172) 27,379 — 27,379 Income tax expense (2,430) — (16) (2,446) — (2,446) Net income (loss) $ 9,489 18,632 (3,188) 24,933 — $ 24,933

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SLIDE 30

30

Financial Income and Expense

Three months ended December 31,

(in thousands of U.S. dollars)

2016 2015 Interest income

$ 160 $ 293

Interest expense: Interest expense (5,389) (5,696) Commitment fees (279) (287) Amortization of debt issuance cost and fair value of debt assumed (467) (534) Total interest expense (6,135) (6,517) Gain (loss) on derivative instruments 661 482 Other items, net: Unrealized foreign exchange gain (loss) 140 1,245 Realized foreign exchange gain (loss) (94) 54 Bank charges, fees and other (45) (39) Withholding tax on interest expense and other (555) (628) Total other items, net (554) 632 Total financial income (expense), net

$ (5,868) $ (5,110)

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SLIDE 31

31

Balance Sheet

(1) In November 2015, the FASB issued revised guidance for the classification of deferred taxes, Balance Sheet Classification of Deferred Taxes. Under the new guidance, companies are required to classify all deferred tax assets and liabilities as non-current on the balance sheet instead of separating deferred taxes into current and non-current amounts. The Partnership is implementing the guidance as of December 31, 2016 and has adjusted the balance sheet as of December 31, 2015 on a retrospective basis. The reclassification has reduced current assets and liabilities by $381 and $450, respectively, and increased long-term assets and long-term liabilities by $381 and $450, respectively as of December 31, 2015.

As of As of December 31, December 31, (in thousands of U.S. dollars) 2016 2015 ASSETS Current assets Cash and cash equivalents $ 18,915 $ 32,868 Restricted cash 8,055 10,630 Other current assets 23,586 24,056 Total current assets 50,556 67,554 Long-term assets Restricted cash 14,154 15,198 Cash designated for acquisition 91,768 — Vessels, net of accumulated depreciation 342,591 353,078 Net investment in direct financing lease 286,626 290,111 Other long-term assets 24,772 37,802 Total long-term assets 759,911 696,189 Total assets $ 810,467 $ 763,743 LIABILITIES AND EQUITY Current liabilities Current portion of long-term debt $ 32,208 $ 32,208 Amounts due to owners and affiliates 1,374 10,604 Other current liabilities 24,234 29,409 Total current liabilities 57,816 72,221 Long-term liabilities Long-term debt 300,440 330,635 Revolving credit and seller’s credit due to owners and affiliates 43,005 47,000 Other long-term liabilities 44,416 64,089 Total long-term liabilities 387,861 441,724 Total liabilities 445,677 513,945 Total Equity 364,790 249,798 Total liabilities and equity $ 810,467 $ 763,743

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SLIDE 32

Distributable Cash Flow

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(1) Segment EBITDA and Distributable cash flow are non-GAAP measures. For a definition of each of these non-GAAP measures and reconciliations to their comparable US GAAP financial measures, please see the Appendix. (2) The Partnership’s interest in the joint ventures’ interest income, interest expense and amortization of debt issuance cost is $2, $3,642 and $45, respectively. (3) Computed as distribution per unit multiplied by units outstanding prior to December offering to fund 2017 acquisition of 51% interest in Grace Holding to compute Coverage ratio – Pre-

  • ffering units which is comparable to prior periods. Grace Holding will contribute to DCF in Q1 2017 but the increase in common units was in December 2016.

Three months ended

(in thousands of U.S. dollars) December 31, 2016

Segment EBITDA (1) $ 25,846 Cash collection/Principal payment on direct financing lease 824 Amortization in revenues for above market contracts 605 Equity in earnings of JVs: Amortization of deferred revenue (528) Interest income (2) 162 Interest expense (2) (9,822) Amortization of debt issuance cost (2) and fair value of debt assumed 512 Other items, net (554) Unrealized foreign exchange losses (gains) (141) Current income tax expense (99) Other adjustments: Indemnification paid by Höegh LNG after quarter end for non-budgeted expenses & losses 404 Estimated maintenance and replacement capital expenditures (3,870) Distributable cash flow (DCF) (1) $ 13,339 Declared distribution 13,717 Coverage ratio – Declared distribution 0.97x Distribution on units existing prior to December 2016 offering 10,971(3) Coverage ratio – Pre-offering units 1.21x

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SLIDE 33

Reconciliation of Distributable Cash Flow to Net Cash Provided by Operating Activities

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(1) Distributable cash flow is a non-GAAP liquidity measure. For a definition of distributable cash flow, please see the Appendix.

Three months ended

(in thousands of U.S. dollars) December 31, 2016

Distributable cash flow (1) $ 13,339 Indemnification paid by Höegh LNG after quarter end for non-budgeted expenses & losses (404) Estimated maintenance and replacement capital expenditures 3,870 Equity in earnings of JVs: Amortization of deferred revenue 528 Equity in earnings of JVs: Amortization of debt issuance cost (45) Equity in earnings of JVs: Depreciation and amortization (2,395) Equity in earnings of JVs: Gain (loss) on derivative instruments 16,120 Equity in losses (earnings) of joint ventures (18,632) Cash collection/Principal payment on direct financing lease (824) Changes in accrued interest expense and interest income 987 Other adjustments 302 Changes in working capital (7,366) Net cash provided by operating activities $ 5,479

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SLIDE 34

(1) Other financial items consist of gains and losses on derivative instruments and other items, net including foreign exchange gains or losses and withholding tax on interest expense.

34

Segment EBITDA

Three months ended March 31, June 30, September 30, December 31, March 31, June 30, September 30, December 31, (in thousands of U.S. dollars) 2015 2015 2015 2015 2016 2016 2016 2016 Reconciliation to net income (loss) Net income (loss) $ 2,578 16,438 5,185 17,075 (1,040) 4,062 13,425 $ 24,933 Interest income (2,427) (2,425) (2,423) (293) (273) (232) (192) (160) Interest expense, net 3,800 3,710 3,744 6,517 6,406 6,354 6,283 6,135 Depreciation and amortization 8 8 8 2,630 2,630 2,636 2,647 2,639 Income tax expense 93 59 109 52 449 501 476 2,446 Other financial items (1) 979 942 922 (1,114) 702 636 261 3,685 Equity in earnings of JVs: Interest expense, net 4,027 4,089 4,029 3,968 3,865 3,787 3,755 2,395 Equity in earnings of JVs: Depreciation and amortization 2,177 2,309 2,456 2,286 2,379 2,376 2,378 (107) Equity in earnings of JVs: Other financial items (1) 3,953 (9,897) 2,109 (5,422) 9,010 4,174 (4,139) (16,120) Segment EBITDA $ 15,187 15,233 16,139 25,699 24,128 24,294 24,893 $ 25,846

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SLIDE 35

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Notes

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Contact: www.hoeghlngpartners.com ir@hoeghlngpartners.com