As confidentially submitted to the Securities and Exchange Commission on November 5, 2018

Registration No. 333-         

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

Confidential Draft Submission No. 3

FORM S-1
REGISTRATION STATEMENT UNDER
THE SECURITIES ACT OF 1933

NFE Financial Holdings LLC
(Exact Name of Registrant as Specified in Its Charter)

111 W. 19^th Street, 8^th Floor
New York, NY 10011
(516) 268-7400
(Address, Including Zip Code, and Telephone Number,
Including Area Code, of Registrant’s Principal Executive Offices)

Cameron D. MacDougall, Esq.
111 W. 19^th Street, 8^th Floor
New York, NY 10011
(516) 268-7400
(Name, Address, Including Zip Code, and Telephone Number, Including Area Code, of Agent for Service)

Copies to:

Approximate date of commencement of proposed sale to the public:
As soon as practicable after this registration statement becomes effective.

If any of the securities being registered on this Form are to be offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act of 1933, check the following box.  o

If this Form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.  o

If this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, please check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.  o

If this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.  o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transaction period for complying with any new or revised financial accounting standards provided pursuant to Section 7(a)(2)(B) of the Securities Act.  o

CALCULATION OF REGISTRATION FEE

The registrant hereby amends this registration statement on such date or dates as may be necessary to delay its effective date until the registrant shall file a further amendment that specifically states that this registration statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933, or until the registration statement shall become effective on such date as the Securities and Exchange Commission, acting pursuant to said Section 8(a), may determine.

Subject to Completion, dated          , 2018

PRELIMINARY PROSPECTUS

NFE Financial Holdings LLC

Class A shares
Representing Limited Liability Company Interests

This is the initial public offering of Class A shares representing limited liability company interests of NFE Financial Holdings LLC. We are offering           Class A shares. We were recently formed by New Fortress Energy Holdings LLC and have elected to be treated as a corporation for U.S. federal income tax purposes. We expect that the initial public offering price will be between $       and $       per Class A share.

Prior to this offering, there has been no public market for our Class A shares. We intend to apply to list our Class A shares on Nasdaq Global Select Market under the symbol “NFE.”

We are an “emerging growth company” and are eligible for reduced reporting requirements for this prospectus and future filings. Please read “Summary—Our Emerging Growth Company Status.”

Investing in our Class A shares involves risks. Please read “Risk Factors” beginning on page 20.

These risks include the following:

The underwriters may purchase up to an additional          Class A shares from us at the public offering price, less the underwriting discount, within 30 days from the date of this prospectus.

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or determined if this prospectus is truthful or complete. Any representation to the contrary is a criminal offense.

The underwriters expect to deliver the Class A shares to purchasers on or about                   , 2018 through the book-entry facilities of The Depository Trust Company.

Prospectus dated       , 2018

TABLE OF CONTENTS

You should rely only on the information contained in this prospectus or in any free writing prospectus we may authorize to be delivered to you. We have not, and the underwriters have not, authorized any other person to provide you with information different from that contained in this prospectus and any free writing prospectus. If anyone provides you with different or inconsistent information, you should not rely on it. You should not assume that the information contained in this registration statement is accurate as of any date other than the date on the front cover of this registration statement. Our business, financial condition, results of operations and prospects may have changed since such dates. We are not, and the underwriters are not, making an offer to sell these securities in any jurisdiction where an offer or sale is not permitted.

This prospectus contains forward-looking statements that are subject to a number of risks and uncertainties, many of which are beyond our control. Please read “Risk Factors” and “Forward-Looking Statements.”

Industry and Market Data

The data included in this prospectus regarding the industries in which we operate, including trends in the market and our position and the position of our competitors, is based on a variety of sources, including independent industry publications, government publications and other published independent sources, information obtained from customers, distributors, suppliers, trade and business organizations and publicly available information (including the reports and other information our competitors file with the Securities and Exchange Commission (the “SEC”), which we did not participate in preparing and as to which we make no representation), as well as our good-faith estimates, which have been derived from management’s knowledge and experience in the industries in which we operate. Estimates of market size and relative positions in a market are difficult to develop and inherently uncertain. Accordingly, investors should not place undue weight on the industry and market share data presented in this prospectus.

GLOSSARY OF TERMS

As commonly used in the liquefied natural gas industry, to the extent applicable and as used in this prospectus, the terms listed below have the following meanings:

SUMMARY

This summary highlights selected information appearing elsewhere in this prospectus. Because it is abbreviated, this summary does not contain all of the information that you should consider before investing in our Class A shares. While this summary highlights what we consider to be the most important information about us, you should read this entire prospectus carefully including, in particular, “Risk Factors,” “Forward-Looking Statements,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the consolidated financial statements and notes included elsewhere in this prospectus. The information presented in this prospectus assumes (i) an initial public offering price of $   per Class A share (the mid-point of the price range set forth on the cover page of this prospectus), (ii) unless otherwise indicated, that the underwriters’ option to purchase additional Class A shares is not exercised and (iii) excludes Class A shares reserved for issuance under our equity incentive plan. This summary is qualified in its entirety by the more detailed information and financial statements and notes thereto included elsewhere in this prospectus.

Unless the context otherwise requires, references in this prospectus to “Company,” “NFE,” “we,” “our,” “us” or like terms refer to NFE Financial Holdings LLC and its subsidiaries. When used in a historical context, “our,” “us,” “we” or like terms refer to New Fortress Energy Holdings LLC, a Delaware limited liability company (“New Fortress Energy Holdings”), our predecessor for financial reporting purposes. References in this prospectus to “NFI” refer to New Fortress Intermediate LLC, which following the transactions discussed in this prospectus, will own our operating subsidiaries, including NFE Atlantic Holdings LLC (“NFE Atlantic”) as well as limited assets or liabilities of New Fortress Energy Holdings held prior to the completion of this offering. Upon the completion of this offering, we will own a controlling   % membership interest in NFI (through our role as the sole managing member of NFI), and New Fortress Energy Holdings will own a non-controlling   % membership interest in NFI. You should also see the “Glossary of Terms” for definitions of some of the terms we use to describe our business and industry and other terms used in this prospectus.

NFE Financial Holdings LLC

Overview

We are an integrated gas-to-power company that seeks to use “stranded” natural gas to satisfy the world’s large and growing power needs. Our mission is to provide modern infrastructure solutions to create cleaner, reliable energy while generating a positive economic impact worldwide. Our business model is simple, yet, we believe, unique for the liquefied natural gas (“LNG”) industry. We aim to deliver targeted energy solutions to customers around the world, thereby reducing their energy costs and diversifying their energy resources, while also reducing pollution and generating compelling margins.

We aim to deliver targeted energy solutions by employing a four-part integrated LNG production and delivery model:

Liquefaction – Our approach is to enter into long-term, largely fixed-price contracts for feedgas, then liquefy that gas at or proximate to its site of extraction, minimizing transport and pipeline costs for the feedgas producers. We are currently developing two liquefiers in the Marcellus area of Pennsylvania, each of which is expected to have the capacity to produce approximately 3 to 4 million gallons of LNG (which is the equivalent of 250,000 to 350,000 MMBtu) per day, and intend to develop five or more additional liquefiers over the next five years.

Logistics – We expect to own or control the logistics assets necessary to deliver LNG to our customers through our “logistics pipeline.” Tanker trucks will transport LNG from our liquefiers to a port on the Delaware river for Marcellus sourced LNG or the Gulf of Mexico for Mid-Continent sourced LNG, at which point LNG will be transloaded directly to large marine vessels.

Shipping – We have long-term charters for both large-scale floating storage units (“FSUs”) and floating storage and regasification units (“FSRUs”), and smaller liquefied natural gas carriers (“LNGCs”). These assets transport LNG from ports to our downstream terminals for ultimate delivery to our customers. There is approximately a five day sail time from port to our downstream terminals in the Caribbean.

Terminals – Through our network of current and planned downstream terminals, we will be positioned to deliver gas and power solutions to our customers seeking either to transition from environmentally dirtier distillate fuels such as ADO and heavy fuel oil (“HFO”) or to purchase natural gas to meet their current fuel needs. Our goal is to build 10 - 20 downstream terminals over the next five years.

We believe this compelling business model will provide opportunities to generate average revenues of approximately $10.00 per MMBtu, including both fuel sales and capacity charges (we often invest capital in infrastructure in connection with our entry into a new market, and customers agree to pay a “capacity charge” as consideration for the right to use the underlying infrastructure). We expect individual contract pricing is likely to range between $8.00 and $13.00 per MMBtu, depending on the customer’s size, purchased volume, credit profile, the complexity of the delivery and the infrastructure required to deliver it.

NFE’s Global Market Landscape

We believe that the world is “long” gas and “short” power, and that natural gas is a compelling fuel for power production. But because much of the world’s natural gas reserves are not directly connected by pipeline to electricity producers and other end users, it must be otherwise transported. An efficient way to transport is through the conversion of natural gas to LNG, which involves treating natural gas to remove impurities and then chilling it to approximately negative 260 degrees Fahrenheit, a process generally referred to as liquefaction. In LNG form, natural gas is typically transported in bulk by containers or tankers hauled by rail or truck or by marine vessels, such as LNG carriers. Once delivered to its end destination, LNG can be reconverted to natural gas through a process referred to as “regasification.”

Today approximately 70% of the world’s electricity is consumed by 10 countries and over a billion people, or approximately 14% of the world’s population, currently lack access to electricity, according to the International Energy Agency’s October 2017 report. As economic development worldwide spurs demand for electricity, approximately 1.5 million MW of new power is expected to be needed by 2040, according to Exxon Mobil’s 2017 Outlook on Energy. To satisfy these power needs with gas-fired power would require approximately 3.75 billion gallons of LNG (or 310 TBtu) per day (based upon an estimated conversion of 2,500 gallons per day of LNG for every MW of power capacity) and an additional 347 mtpa of liquefaction capacity. Further, we believe that many countries around the world – keenly focused on economics as well as the environment – will increasingly look to natural gas to displace environmentally dirtier fuels such as HFO, ADO and coal that are used to generate power, particularly if natural gas is cheaper than these environmentally dirtier fuels. For example, most islands in the Caribbean generate 90% to 100% of their electricity from HFO or ADO, as compared to less than 1% of electricity generation in the United States. We believe there is a significant market opportunity.

Liquefaction projects currently under construction are expected to come online by 2020. Afterward, LNG supply growth is expected to slow through 2025. According to the Shell 2018 LNG Outlook Report, from 2020 through 2025, LNG supply estimates are almost half that of demand expectations. By 2025, this equates to an addressable LNG market with 450 mtpa (approximately 740 million gallons per day) of demand, which management estimates to represent a global market value of approximately $212 billion per annum. Based on this report, by 2025, we expect the shortfall in supply to be approximately 200 mtpa versus current operating plants and 100 mtpa versus projects under construction. This shortfall is the equivalent of approximately 50 to 100 liquefiers of similar capacity to one of our liquefiers in Pennsylvania.

We plan to capitalize on this growing supply-demand gap and create new markets for natural gas by developing liquefaction assets, particularly in areas with significant “stranded” reserves, which we define as natural gas reserves not connected to large interstate or transnational pipelines. That is, not only are these reserves not connected by pipeline to end users, they are not connected to any significant pipeline – as is the case in Pennsylvania.

Our Business Model

As an integrated gas-to-power LNG company, our business model spans the entire production and delivery chain from natural gas procurement and liquefaction to logistics, shipping, terminals and conversion or development of natural gas-fired generation. While historically, liquefaction, transportation, regasification and power generation have been financed separately, the segregation of such projects has inhibited the development of natural gas-fired power in many developing countries. In executing this business model, we have the capability to build or arrange any necessary infrastructure ourselves without reliance on multilateral financing sources or traditional project finance structures, so that we maintain our strategic flexibility.

Our goal is to purchase gas, liquefy it, and transport it to one of our Terminals (as defined herein) at a cost of approximately $4.20 per MMBtu or less (before owner’s costs such as marketing and administrative costs, financing costs and contingencies). We expect our downstream transportation, shipping and regasification costs to approximate $1.50 per MMBtu, which is consistent with the costs of our current operations. Our goal is to sell substantially all of this gas to downstream customers under long-term contracts at targeted pricing in excess of approximately $10.00 per MMBtu, including both fuel sales and capacity charges. Gas not delivered to downstream customers would be sold on the spot market. Currently, the market price for LNG delivered via LNGC is approximately $8.00 to $12.00 per MMBtu, depending on the size of cargoes purchased. For contracted delivery, assuming the costs and sales prices described above, we seek to earn a margin of $4.30 per MMBtu, or $0.36 per gallon, which would equal a margin of 40% or more, on our gas sales. For spot sales, we seek to earn

an attractive margin by adjusting our sales price based on current market rates. Our operations, which are currently conducted at our LNG storage and regasification terminal at the Port of Montego Bay, Jamaica (the “Montego Bay Terminal”) and at our liquefaction, storage and production facility in Miami, Florida (the “Miami Facility”), are currently generating revenue on sales of approximately 400,000 gallons of LNG (33,000 MMBtu) per day. We have contracts, letters of intent or expect to secure contracts in the near term to sell LNG volumes in excess of 8.3 million gallons (685,000 MMBtu) per day, which includes approximately 1.1 million gallons per day that are currently contracted. We are in active discussions with additional customers who may have significant demand for additional LNG, although there can be no assurance that these discussions will result in additional contracts or the terms of such contracts.

Our Terminals

Downstream, we have five terminals operational or under development. Our terminals will position us to access customers in a number of attractive markets around the world.

We look to build terminals in locations where the need for LNG is significant. In these markets, we first seek to identify and establish “beachhead” target markets for the sale of LNG, natural gas or natural gas-fired power. We then seek to convert and supply natural gas to additional power customers. Finally, our goal is to expand within the market by supplying additional industrial and transportation customers.

We currently have two operational terminals and three under development, as described below. We design and construct terminals to meet the supply and demand specifications of our current and potential future customers in the applicable region. Our terminals currently operating or under development are expected to be capable of receiving between 700,000 and 6 million LNG gallons (58,000 and 500,000 MMBtu) per day depending upon the needs of our customers and potential demand in the region. Set forth below is additional detail regarding each terminal:

Montego Bay, Jamaica – Our Montego Bay Terminal commenced commercial operations in October 2016. The terminal is capable of processing up to 740,000 LNG gallons (61,000 MMBtu) per day and features approximately 7,000 cubic meters of onsite storage. It supplies natural gas to 145MW turbines at the power plant operated by Jamaican Public Service Company Limited (“JPS”) pursuant to a long-term take-or-pay contract for natural gas equivalent to approximately 300,000 gallons of LNG (25,000 MMBtu) per day. The Montego Bay

Terminal also supplies several on-island industrial users with natural gas or LNG pursuant to other long-term take-or-pay contracts. Our Montego Bay Terminal is currently operating at 36% capacity to service JPS and these other industrial users. We have the ability to service other potential customers with the excess capacity of the Montego Bay Terminal, and we are seeking to enter into long-term contracts with new customers for such purposes. We deliver LNG to the Montego Bay Terminal via small LNGC.

Old Harbour, Jamaica – Our marine LNG storage and regasification terminal in Old Harbour, Jamaica (the “Old Harbour Terminal” and, together with the Montego Bay Terminal, the “Jamaica Terminals”) is substantially complete and expected to commence commercial operations in the first quarter 2019. It is capable of processing approximately 6 million gallons of LNG (500,000 MMBtu) per day. The Old Harbour Terminal is expected to supply gas to a new 190MW Old Harbour power plant (the “Old Harbour Power Plant”) operated by South Jamaica Power Company Limited (“JPC”) pursuant to a long-term take-or-pay contract for natural gas equivalent to approximately 350,000 gallons of LNG (29,000 MMBtu) per day. We also expect the Old Harbour Terminal to supply gas to a new 94MW power plant that we are constructing, and, subject to agreement on terms, approximately 269,000 gallons of LNG (22,000 MMBtu) per day to the alumina refinery operated by Jamalco, an entity owned by the government of Jamaica with a focus on bauxite mining and alumina production in Jamaica. We expect that our Old Harbour Terminal will operate at 16% capacity to service JPC and Jamalco. We will have the ability to service other potential customers with the excess capacity of the Old Harbour Terminal, and we are seeking to enter into long-term contracts with new customers for such purposes. The Old Harbour Terminal is an offshore terminal with storage and regasification equipment via FSRU. The offshore design eliminates the need for expensive storage tanks and permanent, onshore infrastructure.

San Juan, Puerto Rico – Our San Juan facility is currently under development and is expected to commence commercial operations in the second quarter 2019. It is designed as a landed multi-fuel handling facility located in the Port of San Juan, Puerto Rico (the “San Juan Facility”). The San Juan Facility is being constructed with multiple truck loading bays to provide LNG to on-island industrial users. In addition, we have submitted a proposal to the Puerto Rico Electric Power Authority (“PREPA”) to convert and supply natural gas to Units 5 and 6 of the San Juan Combined Cycle Power Plant – which have a capacity of 440MW. The power plant is currently running on diesel, and we plan to convert the power plant to run on natural gas and provide approximately 25 TBtu of natural gas per year, which would equal approximately 850,000 gallons of LNG (70,000 MMBtu) per day. We expect the conversion to natural gas under our proposal would allow PREPA to realize significant, recurring annual cost savings of approximately $250 million (based on current diesel pricing and information provided in PREPA’s request for proposals) after one time conversion costs while also using a more sustainable, environmentally friendly form of energy.

La Paz, Baja California Sur, Mexico – Our La Paz terminal is currently under development and is expected to commence commercial operations in October 2019. It is being designed as an LNG receiving terminal located at the Port of Pichilingue in Baja California Sur, Mexico, where LNG will be delivered via a small LNGC vessel or barge (the “La Paz Terminal”). Initially, the La Paz Terminal is expected to supply approximately 225,000 gallons of LNG (18,000 MMBtu) per day for a 94MW gas-fired mobile power unit that we plan to develop, own, and operate. Similarly, we expect that we will use the La Paz Terminal infrastructure, which includes truckloading bays, to facilitate the conversion of, and supply approximately 180,000 gallons of LNG (15,000 MMBtu) per day to the 80MW Los Cabos power plant, as well as regional industrial users such as ferries and hotels.

Shannon, Ireland – Our Ireland terminal is currently under development and is expected to commence commercial operations in the fourth quarter 2020. We intend this terminal to include a floating storage facility with onshore regasification equipment and pipeline connection into the distribution system of Gas Networks Ireland, Ireland’s national gas network (the “Ireland Terminal” and, together with the Jamaica Terminals, the San Juan Facility and the La Paz Terminal, our “Terminals”). We plan to deliver LNG to the terminal via a traditional size LNGC and offload it into the FSU moored at the dock. The equipment on site will have the capacity to import and regasify more than 6 million gallons of LNG (500,000 MMBtu) per day, which is the equivalent of Ireland’s total foreign natural gas imports. Additionally, the planning permission approval for the terminal includes the ability to build an integrated 500MW power plant on-site with priority dispatch.

Our Liquefaction Assets

We intend to supply all existing and future customers with LNG produced primarily at our own liquefaction facilities. We have one operational liquefaction facility in Miami and are currently developing two liquefaction

facilities in Pennsylvania (our “Pennsylvania Facilities” and, together with the Miami Facility, the “Liquefaction Facilities”) and plan to develop five or more additional liquefaction facilities over the next five years.

We believe that, by building smaller facilities and optimizing efficiencies, we will be able to construct our liquefaction facilities significantly faster and more economically than those typically developed in the industry. We expect to construct each liquefaction facility for a total cost (including ancillary logistics infrastructure) of between $750 to $850 million, which implies an anticipated cost of LNG production of approximately $374 per ton. There can be no assurance development costs will not exceed our targets. If we can achieve these cost targets, this would be considerably more cost-effective than the industry’s published liquefaction costs, which range from $511 to $867 per ton excluding ancillary infrastructure. Each of our liquefaction facilities is anticipated to produce between 3-4 million gallons of LNG (250,000 – 330,000 MMBtu) per day, or between 1.75 – 2.5 mtpa of LNG.

We constructed the Miami Facility, which commenced commercial operations in 2016, in under 12 months at a cost to build of approximately $70 million. The Miami Facility employs what we believe is one of the largest private ISO container fleets in the world. It has one liquefaction train, with liquefaction production capacity of approximately 100,000 gallons of LNG (8,200 MMBtu) per day and was 95.5% dispatchable during 2017. The facility also has three LNG storage tanks, with total capacity of approximately 270,000 gallons (22,000 MMBtu). The plant also includes two separate LNG transfer areas capable of serving both truck and rail. We are currently delivering approximately 31,000 gallons of LNG per day from the Miami Facility pursuant to long-term, take-or-pay contracts.

We are in advanced stages of the design, development and permitting for our first Pennsylvania Facility, and we expect it to be substantially complete in the fourth quarter of 2020. We expect our first Pennsylvania Facility to have the capacity to liquefy 3-4 million gallons of LNG (250,000 – 330,000 MMBtu) per day. We have already entered into a 15-year contract to acquire all of the feedgas needed to operate our first Pennsylvania Facility at capacity, with pricing that is generally fixed at $2.50 per MMBtu. Once LNG is produced at this facility, a dedicated tanker truck fleet will transport the LNG to a nearby port. We are currently developing plans with a suitable port approximately 195 miles away along the Delaware river, and we expect to finalize a long-term contract prior to the completion of this offering. Under these plans, we expect that LNG will be transferred directly from tanker truck to marine vessel through multiple transloading bays, allowing for simultaneous and continuous operations. From there, our dedicated fleet of marine vessels will be able to transport the LNG to our Terminals and then on to our customers. We are also in the process of developing our second Pennsylvania Facility and expect to begin commercial operations in the third quarter of 2021.

Pending completion and commissioning of our liquefiers in development, we expect to continue to supply our downstream customers with LNG and natural gas sourced from a combination of our Miami Facility and purchases of LNG on the open market. We are drawing on our experience from the construction and operation of our Miami Facility to optimize the development of our Pennsylvania Facilities.

Our Customers

Our downstream customers are, and we expect future customers to be, a mix of power, transportation and industrial users of natural gas and LNG. We seek to substantially reduce our customers’ fuel costs while providing them with a cleaner-burning, more environmentally friendly fuel source. In addition, we also intend to sell power and steam directly to some of our customers.

We seek to enter into long-term, take-or-pay contracts to deliver natural gas or LNG, which generally include targeted pricing of approximately $10.00 per MMBtu. Pricing for any particular customer depends on the size of the customer, purchased volume, the customer’s credit profile, the complexity of the delivery and the infrastructure required to deliver it, and there can be no assurance we will acheive our targeted pricing. In general, the better the credit and larger the size of the user, the lower the contract price of our fuel.

To date, we have contracts, letters of intent or expect to secure contracts in the near term to sell LNG volumes in excess of 8.3 million gallons (685,000 MMBtu) per day, which includes approximately 1.1 million gallons per day currently contracted. Our operations, which are currently conducted primarily at our Montego Bay Terminal and at our Miami Facility, are currently generating revenue from sales of approximately 400,000 gallons (33,000 MMBtu) per day. Our ambition is to continue to aggressively grow this customer portfolio. We are in active discussions with additional customers who may have significant demand for additional LNG.

Growth Opportunities and Track Record

As the world continues to electrify and demand for power grows, we believe that countries will continue to look to natural gas as a viable, efficient, cost-effective and more environmentally friendly fuel. With a potential 3.75 billion LNG-gallon-per-day addressable market created by the approximately 1.5 million MW of new power expected to be needed by 2040, according to Exxon Mobil’s 2017 Outlook on Energy, we see multiple opportunities for our business to grow.

Proven Ability to Execute. We are confident in our ability to execute and scale our business model to support our expected growth because we have a successful track record of infrastructure project development. We developed, constructed and commissioned our Miami Facility, a 100,000 gallon-per-day (8,300 MMBtu) liquefier in Miami-Dade County, Florida, in under 12 months. This liquefier includes two truckloading bays capable of loading LNG tank trucks at 200 gallons-per-minute per truck, and through which we currently service our South Florida customers. We also ship ISO tankers by rail to Port Everglades for shipment to customers in the Bahamas and Barbados. We followed our Miami Facility by designing, permitting, constructing and commissioning our Montego Bay Terminal in under 14 months. This terminal is equipped with 7,000 cubic meters (2 million gallons) of on-land storage, has a direct pipeline connection to JPS’s 145MW turbines at the Bogue Power Plant, and has two truckloading bays for deliveries to on-island customers. We also expect to commission our Old Harbour Terminal starting in December 2018. Construction is complete, and we expect our chartered FSRU to arrive in the fourth quarter 2018. When operational, the Old Harbour Terminal will service a new 190MW power plant operated by JPC and a new 94MW plant that we have begun constructing at Jamalco. These projects demonstrate our proven ability to design, construct and commission large and complex infrastructure projects on accelerated timeframes and encompassing a broad range of operations – liquefaction, logistics, onshore terminals, offshore terminals, pipeline connections, marine assets and integrated power generation assets.

Growth Opportunity — Africa. In Sub-Saharan Africa, 590 million people, or 57% of the population, lack access to electricity. As a result, power generation on the continent is anticipated to more than double to 253GW by 2030. Natural gas consumption is expected to grow by nearly 150% over this timeframe, outpacing nearly every other fuel. We recognize the immense opportunity that Africa affords and are opening our first office in Ghana in late 2018. We have engaged with multiple local counterparties, and we anticipate deploying meaningful capital in African projects in the future.

Business Strategies

Our primary business objective is to provide superior returns to our shareholders as a vertically integrated energy infrastructure company. We intend to accomplish this objective by implementing the following strategies:

from which we expect to supply electricity to JPS under a long-term contract. Because we intend to control the entire “spark spread” from upstream production to delivery of electricity to a customer or grid, we are able to capture economic value in a way a traditional power producer likely cannot. For example, the cost of fuel is a pass-through for most power producers. Because we would supply these power plants with our own LNG and natural gas, we capture fuel economics which can be significant.

Competitive Strengths

We believe we are well positioned to achieve our primary business objectives and execute our business strategies based on the following competitive strengths:

additional capital to expand uses with our largest customers and to secure new customers at favorable margins. We expect that significant expansion of our liquefaction capabilities and our delivery logistics chain through the development, ownership and operation of the Pennsylvania Facilities, together with the current operations at the Miami Facility, will enable us to supply our existing and future customers with LNG produced primarily at our own Liquefaction Facilities and will help to reduce the risk of future LNG price variations.

Our Relationship with New Fortress Energy Holdings and its Affiliates

Following the completion of this offering, New Fortress Energy Holdings will retain a significant interest in us through its ownership of            Class B shares, representing a       % voting and non-economic limited liability company interest in us and a          % economic interest in NFI.

A substantial majority of the equity of New Fortress Energy Holdings is owned by Fortress Equity Partners (A) LP (the “Fortress Shareholder”), a Delaware limited partnership. The Fortress Shareholder is managed by FIG LLC, a Delaware limited liability company (“FIG LLC”), which is an affiliate of Fortress Investment Group LLC (“Fortress”).

While our relationship with New Fortress Energy Holdings and its affiliates is a significant strength, it is also a source of potential conflicts. Please read “—Controlled Company Status” and “Risk Factors.”

Our Emerging Growth Company Status

We are an “emerging growth company” as defined in the Jumpstart Our Business Startups Act, or “JOBS Act.” For as long as we are an emerging growth company, unlike other public companies, we will not be required to:

We will cease to be an “emerging growth company” upon the earliest of:

In addition, Section 107 of the JOBS Act also provides that an emerging growth company can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act of 1933 (the “Securities Act”) for complying with new or revised accounting standards. In other words, an emerging growth company can delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. We have elected to use the extended transition period for complying with new or revised accounting standards under Section 102(b)(2) of the JOBS Act, that allows us to delay the adoption of new or revised accounting standards that have different effective dates for public and private companies until those standards apply to private companies. As a result of this election, our financial statements may not be comparable to companies that comply with public company effective dates.

Controlled Company Status

Because New Fortress Energy Holdings will initially hold approximately       % of the voting power of our shares following the completion of this offering (or approximately       % if the underwriters’ option to purchase additional Class A shares is exercised in full), we expect to be a controlled company as of the completion of the offering under the Sarbanes-Oxley Act and Nasdaq Global Select Market (“NASDAQ”) rules. A controlled company does not need its board of directors to have a majority of independent directors or to form an independent compensation or nominating and corporate governance committee. As a controlled company, we will remain subject to rules of the Sarbanes-Oxley Act and NASDAQ that require us to have an audit committee composed entirely of independent directors. Under these rules, we must have at least one independent director on our audit committee by the date our Class A shares are listed on NASDAQ, at least two independent directors on our audit committee within 90 days of the listing date, and at least three independent directors on our audit committee within one year of the listing date. We expect to have           independent directors upon the closing of this offering.

If at any time we cease to be a controlled company, we will take all action necessary to comply with the Sarbanes-Oxley Act and NASDAQ rules, including by appointing a majority of independent directors to our board of directors, subject to a permitted “phase-in” period.

Risk Factors

An investment in our Class A shares involves risks associated with our business, regulatory and legal matters, our limited liability company structure and the tax characteristics of our Class A shares. Below is a summary of certain key risk factors that you should consider in evaluating an investment in our Class A shares. However, this list is not exhaustive. Please read the full discussion of these risks and the other risks described under “Risk Factors” and “Forward-Looking Statements.”

These risks include the following:

Formation Transactions and Structure

NFE was formed as a Delaware limited liability company by New Fortress Energy Holdings on August 6, 2018. NFE currently has no assets or liabilities and has conducted no operations. New Fortress Energy Holdings currently owns all of the outstanding membership interests of the subsidiaries through which we operate our business, including NFE Atlantic. New Fortress Energy Holdings’ only asset other than cash is its investments in consolidated subsidiaries.

Following this offering and the related transactions described below, NFE will be a holding company whose only material asset will consist of membership interests in NFI, which will own all of the outstanding membership interests in NFE Atlantic. NFE will be the sole managing member of NFI, will be responsible for all operational, management and administrative decisions relating to NFI’s business and will consolidate financial results of NFI and its subsidiaries.

In connection with this offering, the following transactions have occurred or will occur:

The diagram under “—Organizational Structure” below depicts a simplified version of our organization and ownership structure after giving effect to this offering and the related formation transactions.

For further details on our agreements with New Fortress Energy Holdings and its affiliates, please read “Certain Relationships and Related Transactions.”

We refer to the above transactions throughout this prospectus as the “Transactions.”

Our Class A shares and Class B shares

Our first amended and restated limited liability company agreement (the “operating agreement”) will provide for two classes of shares, Class A shares and Class B shares, representing limited liability company interests in us. Only the holders of our Class A shares are entitled to participate in any dividends our board of directors may declare. Each Class A share will also be entitled to one vote on the limited matters to be voted on by our shareholders. We expect to list our Class A shares for trading on NASDAQ under the symbol “NFE.”

Class B shares are not entitled to receive dividends but will be entitled to vote on the same basis as the Class A shares. Holders of Class A shares and Class B shares will vote together as a single class on all matters

presented to our shareholders for their vote or approval, except as otherwise required by applicable law. We do not intend to list the Class B shares on any stock exchange. All of our Class B shares will initially be owned by New Fortress Energy Holdings. For a description of the rights and privileges of shareholders under our operating agreement, including voting rights, please read “Our Operating Agreement.”

Redemption Right

Following this offering, under the NFI limited liability company agreement (the “NFI LLC Agreement”), New Fortress Energy Holdings and any permitted transferees of New Fortress Energy Holdings’ NFI LLC Units will, subject to certain limitations, have the right (the “Redemption Right”) to cause NFI to acquire all or a portion of their NFI LLC Units for, at NFI’s election, (i) Class A shares at a redemption ratio of one Class A share for each NFI LLC Unit redeemed, subject to conversion rate adjustments for equity splits, equity dividends and reclassification and other similar transactions or (ii) an equivalent amount of cash. NFI will determine whether to issue Class A shares or cash based on facts in existence at the time of the decision, which we expect would include the relative value of the Class A shares (including the trading price for the Class A shares at the time), the cash purchase price, the availability of other sources of liquidity to acquire the NFI LLC Units and alternative uses for such cash. As the sole managing member of NFI, our decision to make a cash payment upon the redemption of NFI LLC Units will be made by a committee of our board of directors. Alternatively, upon the exercise of the Redemption Right, NFE (instead of NFI) will have the right (the “Call Right”) to, for administrative convenience, acquire each tendered NFI LLC Unit directly from the redeeming NFI unitholder for, at its election, (x) one Class A share, subject to conversion rate adjustments for equity splits, equity dividends and reclassification and other similar transactions or (y) an equivalent amount of cash. In addition, upon a change of control of NFE, NFE will have the right to require each holder of NFI LLC Units (other than NFE) to exercise its Redemption Right with respect to some or all of such unitholder’s NFI LLC Units, at NFE’s election. In connection with any redemption of NFI LLC Units pursuant to the Redemption Right or our Call Right, the corresponding number of Class B shares will be automatically cancelled.

For purposes of any transfer or exchange of NFI LLC Units initially owned by New Fortress Energy Holdings and our Class B shares, the NFI LLC Agreement and our operating agreement will contain provisions effectively linking each NFI LLC Unit with one of our Class B shares. Class B shares cannot be transferred without transferring an equal number of NFI LLC Units and vice versa.

For additional information, please read “Certain Relationships and Related Transactions—Agreements with Affiliates in Connection with the Transactions—Amended and Restated Limited Liability Company Agreement of NFI.”

Holding Company Structure

Our post-offering organizational structure will allow New Fortress Energy Holdings to retain a direct equity ownership in NFI, which will be classified as a partnership for U.S. federal income tax purposes following the offering. Investors in this offering will, by contrast, hold a direct equity ownership in us in the form of Class A shares, and an indirect ownership interest in NFI through our ownership of NFI LLC Units. Although we were formed as a limited liability company, we have elected to be taxed as a corporation for U.S. federal income tax purposes.

Pursuant to our operating agreement and the NFI LLC Agreement, our capital structure and the capital structure of NFI will generally replicate one another and will provide for customary antidilution mechanisms in order to maintain the one-for-one exchange ratio between the NFI LLC Units and our Class A shares.

For additional information, please read “—Organizational Structure” and “Certain Relationships and Related Transactions—Agreements with Affiliates in Connection with the Transactions—Amended and Restated Limited Liability Company Agreement of NFI.”

Conflicts of Interest

Although we have established certain policies and procedures designed to mitigate conflicts of interest, there can be no assurance that these policies and procedures will be effective in doing so. It is possible that actual, potential or perceived conflicts of interest could give rise to investor dissatisfaction, litigation or regulatory enforcement actions.

One or more of our officers and directors have responsibilities and commitments to entities other than us. For example, we have some of the same directors and officers as other entities affiliated with Fortress. In

addition, we do not have a policy that expressly prohibits our directors, officers, securityholders or affiliates from engaging in business activities of the types conducted by us for their own account. Fortress and its members, managers, officers and employees may pursue acquisition opportunities that we may acquire or dispose of assets in which such persons have a personal interest. In the event of a violation of this code of business conduct and ethics that does not constitute bad faith, willful misconduct, gross negligence or reckless disregard of our directors’ or officers’ duties, our directors, officers or employees will not be liable to us.

Our key agreements, including our operating agreement and the NFI LLC Agreement, were negotiated among related parties, and their respective terms, including fees and other amounts payable, may not be as favorable to us as terms negotiated at an arm’s-length basis with unaffiliated parties.

We may compete with entities affiliated with Fortress for certain business opportunities. From time to time, affiliates of Fortress may focus on investments in assets in industries in which we currently, and may seek to in the future, operate. These affiliates may have meaningful access to capital, which may change over time depending upon a variety of factors, including, but not limited to, available equity capital and debt financing, market conditions and cash on hand. Fortress has multiple existing and planned funds focused on investing in the industries in which we currently, and may seek to in the future, operate, each with significant current or expected capital commitments. We may also co-invest with these funds in certain business opportunities.

Organizational Structure

The following is a simplified diagram of our ownership structure after giving effect to this offering and the related transactions assuming the underwriters do not exercise their option to purchase additional Class A shares.

Principal Executive Offices and Internet Address

Our principal executive offices are located at 111 W. 19^th Street, 8^th Floor, New York, New York 10011 and our telephone number is (516) 268-7400. Our website is located at www.newfortressenergy.com. We expect to make our periodic reports and other information filed with or furnished to the SEC available, free of charge, through our website, as soon as reasonably practicable after those reports and other information are electronically filed with or furnished to the SEC. Information on our website or any other website is not incorporated by reference into this prospectus and does not constitute a part of this prospectus.

The Offering

We will contribute the net proceeds of this offering to NFI in exchange for NFI’s issuance to us of             NFI LLC Units. NFI will use the net

proceeds to complete the construction of our Terminals and Liquefaction Facilities, as well as for working capital and general corporate purposes, including the development of future projects. Please read “Use of Proceeds” for additional information.

If the underwriters exercise their option to purchase additional Class A shares in full, the additional net proceeds will be approximately $       million (based on an assumed initial offering price of $      per Class A share, the mid-point of the price range set forth on the cover page of this prospectus). The net proceeds from any exercise of such option will be contributed to NFI in exchange for NFI’s issuance to us of additional NFI LLC Units. After the application of the net proceeds from this offering, we will own a      % membership interest in NFI (or a      % membership interest if the underwriters’ option to purchase additional Class A shares is exercised in full). Please read “Security Ownership of Certain Beneficial Owners and Management.”

Summary Historical Financial Data

NFE was formed on August 6, 2018 and does not have historical financial results. NFE currently has no assets or liabilities and has conducted no operations. The following table shows summary historical financial information of New Fortress Energy Holdings, our predecessor, for the periods and as of the dates indicated. The summary historical financial data as of and for the years ended December 31, 2017 and 2016 was derived from the audited historical consolidated financial statements of New Fortress Energy Holdings included elsewhere in this prospectus.

You should read the information set forth below together with “Use of Proceeds,” “Selected Historical Financial Data,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and our consolidated financial statements and related notes included elsewhere in this prospectus. The historical financial results are not necessarily indicative of results to be expected for any future periods.

RISK FACTORS

Investing in our Class A shares involves risks. You should carefully consider the following risk factors together with all of the other information included in this prospectus in evaluating an investment in our Class A shares. Additional risks not presently known to us or that we currently deem immaterial could also materially affect our business.

If any of the following risks were to occur, our business, financial condition and results of operations could be materially adversely affected. In that case, the trading price of our Class A shares could decline and you could lose all or part of your investment.

Risks Related to Our Business

We have not yet completed construction and commissioning of all of our Terminals and Liquefaction Facilities. There can be no assurance that our Terminals and Liquefaction Facilities will operate as described in this prospectus, or at all.

While our marine LNG storage and regasification terminal approximately three nautical miles from the Old Harbour Power Plant (the “Old Harbour Terminal” and, together with the Montego Bay Terminal, the “Jamaica Terminals”) is substantially complete, it must still undergo extensive testing and commissioning before operations can commence. With respect to our Pennsylvania Facilities, though we are in the advanced stages of design, development and permitting of our first Pennsylvania Facility, we have not reached a final investment decision regarding such facility. As such, we have not entered into binding construction contracts or obtained all necessary environmental, regulatory, construction and zoning permissions. There can be no assurance that we will be able to enter into the contracts required for the development of these assets on commercially favorable terms, if at all, or that we will be able to obtain all of the environmental, regulatory, construction and zoning permissions we need. In particular, we will require agreements with ports proximate to our Liquefaction Facilities capable of handling the transload of LNG direct from our transportation assets to our occupying vessel. If we are unable to enter into favorable contracts or to obtain the necessary regulatory and land use approvals on favorable terms, we may not be able to construct and operate these assets as described in this prospectus, or at all. Furthermore, if we do enter into the necessary contracts and obtain regulatory approvals for the construction and operation of the Liquefaction Facilities, there can be no assurance that such operations will allow us to successfully export LNG to our facilities, or that we will succeed in our goal of reducing the risk to our operations of future LNG price variations. If we are unable to construct, commission and operate all of our Terminals and Liquefaction Facilities as described in this prospectus, or, when and if constructed, they do not accomplish the goals described in this prospectus, or if we experience delays or cost overruns in construction, our business, operating results, cash flows and liquidity could be materially and adversely affected. Expenses related to our pursuit of contracts and regulatory approvals related to our Terminals and Liquefaction Facilities still under development may be significant and will be incurred by us regardless of whether these assets are ultimately constructed and operational.

Our ability to implement our business strategy may be materially and adversely affected by many known and unknown factors.

Our business strategy relies upon our future ability to successfully market natural gas to end-users, develop and maintain cost-effective logistics in our supply chain and construct, develop and operate energy-related infrastructure in the U.S., Jamaica, Mexico, Ireland and other countries where we do not currently operate. Our strategy assumes that we will be able to expand our operations into other countries, including countries in the Caribbean, enter into long-term GSAs and/or PPAs with end-users, acquire and transport LNG at attractive prices, develop infrastructure, including the Old Harbour Terminal, the Pennsylvania Facilities and the CHP Plant, as well as other future projects, into efficient and profitable operations in a timely and cost-effective way, obtain approvals from all relevant federal, state and local authorities, as needed, for the construction and operation of these projects and other relevant approvals, and obtain long-term capital appreciation and liquidity with respect to such investments. Our strategy may also be affected by future governmental laws and regulations. Our strategy also assumes that we will be able to enter into strategic relationships with energy end-users, power utilities, LNG providers, shipping companies, infrastructure developers, financing counterparties and other partners. These assumptions are subject to significant economic, competitive, regulatory and operational uncertainties, contingencies and risks, many of which are beyond our control. Additionally, in furtherance of our

business strategy, we may acquire operating businesses or other assets in the future. Any such acquisitions would be subject to significant risks and contingencies, including the risk of integration and we may not be able to realize the benefits of any such acquisitions.

Our future ability to execute our business strategy is uncertain, and it can be expected that one or more of our assumptions will prove to be incorrect and that we will face unanticipated events and circumstances that may adversely affect our proposed business. Any one or more of the following factors may have a material adverse effect on our ability to implement our proposed strategy and achieve our targets:

If we experience any of these failures, such failure may adversely affect our financial condition, results of operations and ability to execute our business strategy.

We have a limited operating history, and an investment in our Class A shares is highly speculative.

We have a limited operating history and track record. As a result, our prior operating history and historical financial statements may not be a reliable basis for evaluating our business prospects or the future value of our Class A shares. We commenced operations on February 25, 2014, and we had net losses of approximately $1.6 million in 2014, $14.2 million in 2015, $32.9 million in 2016 and $31.7 million in 2017. Our strategy may not be successful, and if unsuccessful, we may be unable to modify it in a timely and successful manner. We cannot give you any assurance that we will be able to implement our strategy on a timely basis, if at all, or achieve our internal model or that our assumptions will be accurate. Accordingly, your investment in our Class A shares is speculative and subject to a high degree of risk. Prior to investing in our Class A shares, you should understand that there is a possibility of the loss of your entire investment.

We will continue to incur significant capital and operating expenditures while we develop infrastructure for our supply chain, including for the completion of our Terminals and Liquefaction Facilities under construction, as well as other future projects. We will need to invest significant amounts of additional capital to implement our strategy. We have not yet entered into all arrangements necessary to obtain and ship LNG to the Jamaica Terminals, and we have not completed constructing all of our Terminals and Liquefaction Facilities. Any delays beyond the expected development period for these assets would prolong, and could increase the level of, operating losses and negative operating cash flows. Our future liquidity may also be affected by the timing of construction financing availability in relation to the incurrence of construction costs and other outflows and by the timing of receipt of cash flows under our customer contracts in relation to the incurrence of project and operating expenses. Our ability to generate any positive operating cash flow and achieve profitability in the future is dependent on, among other things, our ability to develop an efficient supply chain and successfully and timely complete necessary infrastructure, including our Terminals and Liquefaction Facilities under construction, and fulfill our gas delivery obligations under our customer contracts.

We may not be profitable for an indeterminate period of time.

We have a limited operating history and did not commence revenue-generating activities until 2016, and therefore did not achieve profitability as of December 31, 2017. We will invest a substantial portion of the proceeds of this offering in capital expenditures or in pursuit of development opportunities. We will need to make a significant initial investment to complete construction and begin operations of all of our Terminals and Liquefaction Facilities, and we will need to make significant additional investments to develop, improve and operate them, as well as all related infrastructure. We also expect to make significant expenditures and investments in identifying, acquiring and/or developing other future projects. We also expect to incur significant expenses in connection with the launch and growth of our business, including costs for LNG purchases, rail and truck transportation, shipping and logistics and personnel. We will need to raise significant additional debt and equity capital to achieve our goals.

We may not be able to achieve profitability, and if we do, we cannot assure you that we would be able to sustain such profitability in the future. Our failure to achieve or sustain profitability would have a material adverse effect on our business and the value of our Class A shares.

Because we are currently dependent upon a limited number of customers, the loss of a significant customer could adversely affect our operating results.

A limited number of customers currently represent a substantial majority of our income. Our operating results are currently contingent on our ability to maintain LNG, natural gas, steam and power sales to these customers. At least in the short term, we expect that a substantial majority of our sales will continue to arise from a concentrated number of customers, such as power utilities, railroad companies and industrial end-users. We expect the substantial majority of our revenue for the near future to be from JPS, JPC and Jamalco. We may be unable to accomplish our business plan to diversify and expand our customer base by attracting a broad array of customers, which could negatively affect our business, results of operations and financial condition.

Our current ability to generate cash is substantially dependent upon the performance by customers under long-term contracts that we have entered into, and we could be materially and adversely affected if any customer fails to perform its contractual obligations for any reason, including nonpayment and nonperformance.

Our current results of operations and liquidity are, and will continue to be in the near future, substantially dependent upon performance by JPS and JPC, which have each entered into long-term GSAs and, in the case of

JPS, a PPA in relation to the power produced at the CHP Plant, with us, and Jamalco, which has entered into a long-term SSA with us. Our GSAs, PPA and SSA have a weighted average of 14.3 years remaining under such contracts, weighted based on contracted volumes. Our near term ability to generate cash is dependent on JPS’s, JPC’s and Jamalco’s continued willingness and ability to perform their obligations under their respective contracts. If any of JPS, JPC or Jamalco fails to perform its obligations under its contract, our operating results, cash flow and liquidity could be materially and adversely affected, even if we were ultimately successful in seeking damages from JPS, JPC or Jamalco for a breach of the contract.

Risks of nonpayment and nonperformance by customers are a consideration in our businesses, and our credit procedures and policies may be inadequate to sufficiently eliminate customer credit risk. In assessing customer credit risk, we perform background checks on our potential customers before we enter into a long-term contract with them. As part of the background check, we assess a potential customer’s credit profile and financial position, including their operating results, liquidity and outstanding debt, as well as certain macroeconomic factors regarding the region(s) in which they operate. These procedures help us to appropriately assess customer credit risk on a case-by-case basis, but these procedures may not be effective in assessing credit risk in all instances. As part of our business strategy, we intend to target customers who have not been traditional purchasers of natural gas, including customers in developing countries, and these customers may have greater credit risk than typical natural gas purchasers. Therefore, we may be exposed to greater customer credit risk than other companies in the industry. In particular, JPS and JPC, which are public utility companies in Jamaica, could be subject to austerity measures imposed on Jamaica by the International Monetary Fund (the “IMF”) and other international lending organizations. Jamaica is currently subject to certain public spending limitations imposed by agreements with the IMF, and any changes under these agreements could limit JPS’s and JPC’s ability to make payments under their long-term GSAs and, in the case of JPS, its ability to make payments under its PPA, with us. In addition, our ability to operate the CHP Plant is dependent on our ability to enforce the related lease. General Alumina Jamaica (“GAJ”), one of the lessors, is a subsidiary of Noble Group, which is undergoing a financial restructuring that was recently approved by its shareholders. If GAJ is involved in a bankruptcy or similar proceeding, such proceeding could negatively impact our ability to enforce the lease. If we are unable to enforce the lease due to the bankruptcy of GAJ or for any other reason, we could be unable to operate the CHP Plant or to execute on our contracts related thereto, which could negatively affect our business, results of operations and financial condition.

Further, adverse economic conditions in our industry increase the risk of nonpayment and nonperformance by customers, particularly customers that have sub-investment grade credit ratings.

Our contracts with our customers are subject to termination under certain circumstances.

Our contracts with our customers contain various termination rights. For example, each of our long-term customer contracts, including the contracts with JPS, JPC and Jamalco, contains various termination rights allowing our customers to terminate the contract, including, without limitation:

We may not be able to replace these contracts on desirable terms, or at all, if they are terminated. Contracts that we enter into in the future may contain similar provisions. If any of our current or future contracts are terminated, such termination could have a material adverse effect on our business, contracts, financial condition, operating results, cash flows, liquidity and prospects.

Cyclical or other changes in the demand for and price of LNG and natural gas may adversely affect our business and the performance of our customers and could have a material adverse effect on our business, contracts, financial condition, operating results, cash flows, liquidity and prospects.

Our business and the development of energy-related infrastructure and projects generally is based on assumptions about the future availability and price of natural gas and LNG and the prospects for international natural gas and LNG markets. Natural gas and LNG prices have at various times been and may become volatile due to one or more of the following factors:

Adverse trends or developments affecting any of these factors – in particular prior to our Pennsylvania Facilities becoming operational – could result in decreases in the prices at which we are able to sell LNG and natural gas or increases in the prices we have to pay for natural gas or LNG, which could materially and adversely affect the performance of our customers, and could have a material adverse effect on our business, contracts, financial condition, operating results, cash flows, liquidity and prospects. In particular, because we have not currently procured fixed-price, long-term LNG supply (our plan being to liquefy natural gas ourselves in our Liquefaction Facilities), increases in LNG prices and/or shortages of LNG supply could be material and adverse to our business.

Our business is dependent upon obtaining substantial additional funding from various sources, which may not be available or may only be available on unfavorable terms.

The net proceeds from this offering will not be sufficient to fully execute our business plan. After giving effect to this offering and committed debt financing of $    million, we believe that our cash resources will be sufficient to meet projected capital expenditures, financing obligations and operating requirements related to the construction and development of our Pennsylvania Facilities, the Ireland Terminal, the San Juan Facility and the La Paz Terminal, which are further described in “Business.” In the future, we expect to pursue additional offerings of debt or equity securities to assist us in developing our operations. If we are unable to secure additional funding, or if it is only available on terms that we determine are not acceptable to us, we may be unable to fully execute our business plan and our business, financial condition or results of operations may be adversely affected. Our ability to raise additional capital will depend on financial, economic and market conditions and other factors, many of which are beyond our control. We cannot assure you that such additional

funding will be available on acceptable terms, or at all. To the extent that we raise additional equity capital by issuing additional securities at any point in the future, our then-existing shareholders may experience dilution. Debt financing, if available, may subject us to restrictive covenants that could limit our flexibility in conducting future business activities and could result in us expending significant resources to service our obligations. If we are unable to comply with these covenants and service our debt, we may lose control of our business and be forced to reduce or delay planned investments or capital expenditures, sell assets, restructure our operations or submit to foreclosure proceedings, all of which would result in a material adverse effect upon our business and reduce the value of your investment.

A variety of factors beyond our control could impact the availability or cost of capital, including domestic or international economic conditions, increases in key benchmark interest rates and/or credit spreads, the adoption of new or amended banking or capital market laws or regulations, the re-pricing of market risks and volatility in capital and financial markets as well as general risks applicable to the energy sector. Our financing costs could increase or future borrowings or equity offerings may be unavailable to us or unsuccessful, which could cause us to be unable to pay or refinance our indebtedness or to fund our other liquidity needs. We also rely on borrowings under our debt instruments to fund our capital expenditures. If any of the lenders in the syndicates backing these debt instruments were unable to perform on its commitments, we may need to seek replacement financing, which may not be available as needed, or may be available in more limited amounts or on more expensive or otherwise unfavorable terms.

We may not be able to generate sufficient cash to service all of our indebtedness and may be forced to take other actions to satisfy our obligations under our indebtedness, which may not be successful.

Our ability to make scheduled payments on or to refinance our existing or future debt obligations depends on our financial condition and operating performance, which are subject to prevailing economic and competitive conditions and to certain financial, business, legislative, regulatory and other factors beyond our control. We may be unable to maintain a level of cash flows from operating activities sufficient to permit us to fund our day-to-day operations or to pay the principal, premium, if any, and interest on our indebtedness. As of September 30, 2018, we had $130 million of total indebtedness outstanding, excluding deferred financing costs, and, as of the closing of this offering, we expect to have $    million of total indebtedness outstanding.

If our cash flows and capital resources are insufficient to fund our debt service obligations and other cash requirements, we could face substantial liquidity problems and could be forced to reduce or delay investments and capital expenditures or to sell assets or operations, seek additional capital or restructure or refinance our indebtedness or operations. We may not be able to affect any such alternative measures, if necessary, on commercially reasonable terms or at all and, even if successful, such alternative actions may not allow us to meet our scheduled debt service obligations. The agreements that govern our indebtedness restrict our ability to dispose of assets and use the proceeds from any such dispositions and our ability to raise debt capital to be used to repay our indebtedness when it becomes due. We may not be able to consummate those dispositions or to obtain proceeds in an amount sufficient to meet any debt service obligations then due.

Our inability to generate sufficient cash flows to satisfy our debt obligations, or to refinance our indebtedness on commercially reasonable terms or at all, would materially and adversely affect our financial position and results of operations and our ability to satisfy our obligations.

If we cannot make scheduled payments on our debt, we will be in default and, as a result, lenders under any of our existing and future indebtedness could declare all outstanding principal and interest to be due and payable, the lenders under our debt instruments could terminate their commitments to loan money, our secured lenders could foreclose against the assets securing such borrowings and we could be forced into bankruptcy or liquidation, in each case, which could result in your losing your investment.

Failure to maintain sufficient working capital could limit our growth and harm our business, financial condition and results of operations.

We have significant working capital requirements, primarily driven by the delay between the purchase of and payment for natural gas and the extended payment terms that we offer our customers. Differences between the date when we pay our merchant clients and the date when we receive payments from our customers may adversely affect our liquidity and our cash flows. We expect our working capital needs to increase as our total business increases. If we do not have sufficient working capital, we may not be able to pursue our growth

strategy, respond to competitive pressures or fund key strategic initiatives, such as the development of our facilities, which may harm our business, financial condition and results of operations.

Operation of our LNG infrastructure and other facilities that we may construct involves significant risks.

As more fully discussed in this prospectus, our existing facilities and expected future facilities face operational risks, including the following: performing below expected levels of efficiency, breakdowns or failures of equipment, operational errors by trucks, tankers or tug operators, operational errors by us or any contracted facility operator, labor disputes and weather-related or natural disaster interruptions of operations.

Any of these risks could disrupt our operations and increase our costs, which would adversely affect our business, operating results, cash flows and liquidity.

The operation of the CHP Plant will involve particular, significant risks.

The operation of the CHP Plant will involve particular, significant risks, including, among others: failure to maintain the required power generation license(s) or other permits required to operate the CHP Plant; pollution or environmental contamination affecting operation of the CHP Plant; the inability, or failure, of any counterparty to any plant-related agreements to perform their contractual obligations to us including, but not limited to, the Lessor’s obligations to us under the CHP Plant Lease; and planned and unplanned power outages due to maintenance, expansion and refurbishment. We cannot assure you that future occurrences of any of the events listed above or any other events of a similar or dissimilar nature would not significantly decrease or eliminate the revenues from, or significantly increase the costs of operating, the CHP Plant. If the CHP Plant is unable to generate or deliver power to JPS, pursuant to the PPA, or steam (or gas to power Jamalco’s boilers in lieu of steam) to Jamalco, pursuant to the SSA, JPS or Jamalco, as applicable, may not be required to make payments under their respective agreements so long as the event continues. JPS and Jamalco, as counterparties to the PPA and SSA, respectively, and the counterparties to any other key plant-related agreements may have the right to terminate those agreements for certain failures to generate or deliver power or steam, as applicable. As a consequence, there may be reduced or no revenues from the CHP Plant which could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects. In addition, termination of the SSA may give rise to termination rights under the CHP Plant Lease. If JPS terminates the PPA, Jamalco terminates the SSA, or any counterparty to any other key plant-related agreement terminates such agreement, we may not be able to enter into a replacement agreement with respect to the CHP Plant on terms as favorable as the terminated agreement.

Hurricanes or other natural or manmade disasters could result in an interruption of our operations, a delay in the completion of our infrastructure projects, higher construction costs or the deferral of the dates on which payments are due under our customer contracts, all of which could adversely affect us.

Storms and related storm activity and collateral effects, or other disasters such as explosions, fires, seismic events, floods or accidents, could result in damage to, or interruption of operations in our supply chain, including at our facilities or related infrastructure, as well as delays or cost increases in the construction and the development of our proposed facilities or other infrastructure. Changes in the global climate may have significant physical effects, such as increased frequency and severity of storms, floods and rising sea levels; if any such effects were to occur, they could have an adverse effect on our marine and coastal operations. Due to the concentration of our current and anticipated operations in southern Florida and the Caribbean, we are particularly exposed to the risks posed by hurricanes, tropical storms and their collateral effects. For example, the 2017 Atlantic hurricane season caused extensive and costly damage across Florida and the Caribbean, including Puerto Rico. We are unable to predict with certainty the impact of future storms on our customers, our infrastructure or our operations.

If one or more tankers, terminals, pipelines, facilities, equipment or electronic systems that we own, lease or operate or that deliver products to us or that supply our facilities and customers’ facilities are damaged by severe weather or any other disaster, accident, catastrophe, terrorist or cyber-attack or event, our operations and construction projects could be delayed and our operations could be significantly interrupted. These delays and interruptions could involve significant damage to people, property or the environment, and repairs could take a week or less for a minor incident to six months or more for a major interruption. Any event that interrupts the revenues generated by our operations, or that causes us to make significant expenditures not covered by insurance, and could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

We do not, nor do we intend to, maintain insurance against all of these risks and losses. We may not be able to maintain desired or required insurance in the future at rates that we consider reasonable. The occurrence of a significant event not fully insured or indemnified against could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

Our insurance may be insufficient to cover losses that may occur to our property or result from our operations.

Our current operations and future projects are subject to the inherent risks associated with LNG, natural gas and power operations, including explosions, pollution, release of toxic substances, fires, seismic events, hurricanes and other adverse weather conditions, and other hazards, each of which could result in significant delays in commencement or interruptions of operations and/or result in damage to or destruction of the our facilities and assets or damage to persons and property. In addition, such operations and the vessels of third parties on which our current operations and future projects may be dependent face possible risks associated with acts of aggression or terrorism. Some of the regions in which we operate are affected by hurricanes or tropical storms. We do not, nor do we intend to, maintain insurance against all of these risks and losses. In particular, we do not carry business interruption insurance for hurricanes and other natural disasters. Therefore, the occurrence of one or more significant events not fully insured or indemnified against could create significant liabilities and losses which could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

We may be unable to procure adequate insurance coverage at commercially reasonable rates in the future. For example, environmental regulations have led in the past to increased costs for, and in the future may result in the lack of availability of, insurance against risks of environmental damage or pollution. A catastrophic release of natural gas, marine disaster or natural disasters could result in losses that exceed our insurance coverage, which could harm our business, financial condition and operating results. Any uninsured or underinsured loss could harm our business and financial condition. In addition, our insurance may be voidable by the insurers as a result of certain of our actions.

Changes in the insurance markets attributable to terrorist attacks or political change may also make certain types of insurance more difficult for us to obtain. In addition, the insurance that may be available may be significantly more expensive than our existing coverage.

From time to time, we may be involved in legal proceedings and may experience unfavorable outcomes.

In the future we may be subject to material legal proceedings in the course of our business, including, but not limited to, actions relating to contract disputes, business practices, intellectual property and other commercial and tax matters. Such legal proceedings may involve claims for substantial amounts of money or for other relief or might necessitate changes to our business or operations, and the defense of such actions may be both time consuming and expensive. Further, if any such proceedings were to result in an unfavorable outcome, it could have a material adverse effect on our business, financial position and results of operations.

Our success depends on key members of our management, the loss of any of whom could disrupt our business operations.

We depend to a large extent on the services of our chief executive officer, Wesley R. Edens, and some of our other executive officers. The loss of the services of Mr. Edens or one or more of our other key executives could disrupt our operations and increase our exposure to the other risks described in this “Risk Factors” section. We do not maintain key man insurance on Mr. Edens or any of our employees. As a result, we are not insured against any losses resulting from the death of our key employees.

Our construction of energy-related infrastructure is subject to operational, regulatory, environmental, political, legal and economic risks, which may result in delays, increased costs or decreased cash flows.

The construction of energy-related infrastructure, including our Terminals and Liquefaction Facilities, as well as other future projects, involves numerous operational, regulatory, environmental, political, legal and economic risks beyond our control and may require the expenditure of significant amounts of capital during construction and thereafter. These potential risks include, among other things, the following:

A materialization of any of these risks could adversely affect our ability to achieve growth in the level of our cash flows or realize benefits from future projects, which could have a material adverse effect on our business, financial condition and results of operations.

We expect to be dependent on our primary building contractor and other contractors for the successful completion of our energy-related infrastructure.

Timely and cost-effective completion of our energy-related infrastructure, including our Terminals and Liquefaction Facilities, as well as future projects, in compliance with agreed specifications is central to our business strategy and is highly dependent on the performance of our primary building contractor and our other contractors under our agreements with them. The ability of our primary building contractor and our other contractors to perform successfully under their agreements with us is dependent on a number of factors, including their ability to:

Until we have entered into an EPC contract for a particular project, in which the EPC contractor agrees to meet our planned schedule and projected total costs for a project, we are subject to potential fluctuations in construction costs and other related project costs. We expect to enter into an EPC contract for our first Pennsylvania Facility in the fourth quarter of 2018. Although some agreements may provide for liquidated damages if the contractor fails to perform in the manner required with respect to certain of its obligations, the events that trigger a requirement to pay liquidated damages may delay or impair the operation of the applicable facility, and any liquidated damages that we receive may be delayed or insufficient to cover the damages that we suffer as a result of any such delay or impairment. The obligations of our primary building contractor and our other contractors to pay liquidated damages under their agreements with us are subject to caps on liability, as set forth therein. Furthermore, we may have disagreements with our contractors about different elements of the

construction process, which could lead to the assertion of rights and remedies under their contracts and increase the cost of the applicable facility or result in a contractor’s unwillingness to perform further work. If any contractor is unable or unwilling to perform according to the negotiated terms and timetable of its respective agreement for any reason or terminates its agreement for any reason, we would be required to engage a substitute contractor. This would likely result in significant project delays and increased costs, which could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

We are relying on third party engineers to estimate the future rated capacity and performance capabilities of our existing and future facilities, and these estimates may prove to be inaccurate.

We are relying on third parties for the design and engineering services underlying our estimates of the future rated capacity and performance capabilities of our Terminals and Liquefaction Facilities, as well as other future projects. If any of these facilities, when actually constructed, fails to have the rated capacity and performance capabilities that we intend, our estimates may not be accurate. Failure of any of our existing or future facilities to achieve our intended future capacity and performance capabilities could prevent us from achieving the commercial start dates under our customer contracts and could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

We may not be able to purchase or receive physical delivery of natural gas in sufficient quantities and/or at economically attractive prices to satisfy our delivery obligations under the GSAs, PPA and SSA, which could have a material adverse effect on us.

Under the GSAs with JPS and JPC, we are required to deliver to JPS and JPC specified amounts of natural gas at specified times, while under the SSA with Jamalco, we are required to deliver steam, and under the PPA with JPS, we are required to deliver power, each of which also requires us to obtain sufficient amounts of LNG. However, we may not be able to purchase or receive physical delivery of sufficient quantities of LNG to satisfy those delivery obligations, which may provide JPS or JPC or Jamalco with the right to terminate its GSA, PPA or SSA, as applicable. In addition, price fluctuations in natural gas and LNG may make it expensive or uneconomical for us to acquire adequate supply of these items (until our Pennsylvania Facilities are operational).

Until the Pennsylvania Facilities become fully operational, we will be dependent upon third party LNG suppliers and shippers and other tankers and facilities to provide delivery options to and from our tankers and energy-related infrastructure. If LNG were to become unavailable for current or future volumes of natural gas due to repairs or damage to supplier facilities or tankers, lack of capacity, impediments to international shipping or any other reason, our ability to continue delivering natural gas, power or steam to end-users could be restricted, thereby reducing our revenues. Additionally, under tanker charters, we will be obligated to make payments for our chartered tankers regardless of use. We may not be able to enter into contracts with purchasers of LNG in quantities equivalent to or greater than the amount of tanker capacity we have purchased. Any permanent interruption at any key LNG supply chains that caused a material reduction in volumes transported on or to our tankers and facilities could have a material adverse effect on our business, financial condition, operating results, cash flow, liquidity and prospects.

We intend to enter into purchase agreements pursuant to which we expect to have the option to purchase LNG to supply the Jamaica Terminals that will facilitate delivery of natural gas to JPS, JPC and Jamalco until the Pennsylvania Facilities are operational. Failure to secure contracts for the purchase of a sufficient amount of natural gas could materially and adversely affect our business, operating results, cash flows and liquidity.

Recently, the LNG industry has experienced increased volatility. If market disruptions and bankruptcies of third party LNG suppliers and shippers negatively impacts our ability to purchase a sufficient amount of LNG or significantly increases our costs for purchasing LNG, our business, operating results, cash flows and liquidity could be materially and adversely affected. There can be no assurances that we will complete the Pennsylvania Facilities or be able to supply our facilities with LNG produced at our own facilities. Even if we do complete the Pennsylvania Facilities, there can be no assurance that they will operate as we expect or that we will succeed in our goal of reducing the risk to our operations of future LNG price variations.

We face competition based upon the international market price for LNG or natural gas.

Our business is subject to the risk of natural gas and LNG price competition at times when we need to replace any existing customer contract, whether due to natural expiration, default or otherwise, or enter into new customer contracts. Factors relating to competition may prevent us from entering into new or replacement

customer contracts on economically comparable terms to existing customer contracts, or at all. Such an event could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects. Factors which may negatively affect potential demand for natural gas from our business are diverse and include, among others:

In addition, we may not be able to successfully execute on our strategy to supply our existing and future customers with LNG produced primarily at our own facilities upon completion of the Pennsylvania Facility. See “Risk Related to Our Business—We have not yet completed construction and commissioning of all of our Terminals and Liquefaction Facilities. There can be no assurance that our Terminals and Liquefaction Facilities will operate as described in this prospectus, or at all.”

Technological innovation may render our processes obsolete.

The success of our current operations and future projects will depend in part on our ability to create and maintain a competitive position in the natural gas liquefaction industry. In particular, although we plan to build out our delivery logistics chain in Northern Pennsylvania using proven technologies such as those currently in operation at our Miami Facility, we do not have any exclusive rights to any of these technologies. In addition, such technologies may be rendered obsolete or uneconomical by legal or regulatory requirements, technological advances, more efficient and cost-effective processes or entirely different approaches developed by one or more of our competitors or others, which could materially and adversely affect our business, ability to realize benefits from future projects, results of operations, financial condition, liquidity and prospects.

Changes in legislation and regulations could have a material adverse impact on our business, results of operations, financial condition, liquidity and prospects.

Our business is subject to governmental laws, rules, regulations and requires permits that impose various restrictions and obligations that may have material effects on our results of operations. In addition, each of the applicable regulatory requirements and limitations is subject to change, either through new regulations enacted on the federal, state or local level, or by new or modified regulations that may be implemented under existing law. The nature and extent of any changes in these laws, rules, regulations and permits may be unpredictable and may have material effects on our business. Future legislation and regulations or changes in existing legislation and regulations, or interpretations thereof, such as those relating to the liquefaction, storage, or regasification of LNG, or its transportation could cause additional expenditures, restrictions and delays in connection with our operations as well as other future projects, the extent of which cannot be predicted and which may require us to limit substantially, delay or cease operations in some circumstances. Revised, reinterpreted or additional laws and regulations that result in increased compliance costs or additional operating costs and restrictions could have an adverse effect on our business, the ability to expand our business, including into new markets, results of operations, financial condition, liquidity and prospects.

Increasing trucking regulations may increase our costs and negatively impact our results of operations.

We are developing a transportation system specifically dedicated to transporting LNG from our Liquefaction Facilities to a nearby port, from which our LNG can be transported to our operations in the Atlantic Basin and elsewhere. This transportation system may include trucks that we or our affiliates own and operate. Any such

operations would be subject to various trucking safety regulations, including those which are enacted, reviewed and amended by the Federal Motor Carrier Safety Administration (“FMCSA”). These regulatory authorities exercise broad powers, governing activities such as the authorization to engage in motor carrier operations, driver licensing, insurance requirements, financial reporting and review of certain mergers, consolidations and acquisitions, and transportation of hazardous materials. To a large degree, intrastate motor carrier operations are subject to state and/or local safety regulations that mirror federal regulations but also regulate the weight and size dimensions of loads.

All federally regulated carriers’ safety ratings are measured through a program implemented by the FMCSA known as the Compliance Safety Accountability (“CSA”) program. The CSA program measures a carrier’s safety performance based on violations observed during roadside inspections as opposed to compliance audits performed by the FMCSA. The quantity and severity of any violations are compared to a peer group of companies of comparable size and annual mileage. If a company rises above a threshold established by the FMCSA, it is subject to action from the FMCSA. There is a progressive intervention strategy that begins with a company providing the FMCSA with an acceptable plan of corrective action that the company will implement. If the issues are not corrected, the intervention escalates to on-site compliance audits and ultimately an “unsatisfactory” rating and the revocation of the company’s operating authority by the FMCSA, which could result in a material adverse effect on our business and consolidated results of operations and financial position.

Any trucking operations would be subject to possible regulatory and legislative changes that may increase our costs. Some of these possible changes include changes in environmental regulations, changes in the hours of service regulations which govern the amount of time a driver may drive or work in any specific period, onboard black box recorder device requirements or limits on vehicle weight and size.

We may not be able to renew or obtain new or favorable charters or leases, which could adversely affect our business, prospects, financial condition, results of operations and cash flows.

We have obtained long-term leases and corresponding rights-of-way agreements with respect to the land on which the Jamaica Terminals, the pipeline connecting the Montego Bay Terminal to the Bogue Power Plant, the Miami Facility and the CHP Plant are situated. However, we do not own the land. As a result, we are subject to the possibility of increased costs to retain necessary land use rights. If we were to lose these rights or be required to relocate, our business could be materially and adversely affected. The Miami Facility is currently located on land we are leasing from an affiliate. Any payments under the existing lease or future modifications or extensions to the lease could involve transacting with an affiliate. We have also entered into LNG tanker charters in order to secure shipping capacity for our import of LNG to the Jamaica Terminals.

Our ability to renew existing charters or leases for our current projects or obtain new charters or leases for our future projects will depend on prevailing market conditions upon expiration of the contracts governing the leasing or charter of the applicable assets. Therefore, we may be exposed to increased volatility in terms of rates and contract provisions. Likewise, our counterparties may seek to terminate or renegotiate their charters or leases with us. If we are not able to renew or obtain new charters or leases in direct continuation, or if new charters or leases are entered into at rates substantially above the existing rates or on terms otherwise less favorable compared to existing contractual terms, our business, prospects, financial condition, results of operations and cash flows could be materially adversely affected.

We may not be able to successfully enter into contracts or renew existing contracts to charter tankers and to lease or acquire ship-to-ship kits in the future, which may result in us not being able to meet our obligations.

We enter into time charters of ocean-going tankers for the transportation of LNG, which extend for varying lengths of time. We also rely on two ship-to-ship kits, one of which we currently own and one of which we currently lease, and one ship-to-shore kit, which we currently own, to transmit LNG between ships and to transport it onshore. We may need to purchase additional kits, or upgrade our existing kits, in the future. We may not be able to successfully enter into contracts or renew existing contracts to charter tankers and to lease or acquire kits in the future, which may result in us not being able to meet our obligations. We are also exposed to changes in market rates and availability for tankers and kits, which may affect our earnings. Fluctuations in rates result from changes in the supply of and demand for capacity and changes in the demand for seaborne carriage of commodities. Because the factors affecting the supply and demand are outside of our control and are unpredictable, the nature, timing, direction and degree of changes in industry conditions are also unpredictable.

We rely on the operation of tankers under our time charters and kits to transfer LNG between ships. The operation of ocean-going tankers and kits carries inherent risks. These risks include the possibility of:

We do not currently maintain a redundant supply of ships, ship-to-ship kits or other equipment. As a result, if our current equipment fails, is unavailable or insufficient to service our production, we may need to procure new equipment, which may not be available or be expensive to obtain. Any such occurrence could interrupt our operations and increase our operating costs. Any of these results could have a material adverse effect on our business, financial condition and operating results.

The operation of LNG carriers is inherently risky, and an incident resulting in significant loss or environmental consequences involving an LNG vessel could harm our reputation and business.

Cargoes of LNG and our chartered vessels are at risk of being damaged or lost because of events such as:

An accident involving our cargoes or any of our chartered vessels could result in any of the following:

Any of these circumstances or events could increase our costs or lower our revenues.

If our chartered vessels suffer damage as a result of such an incident, they may need to be repaired. The loss of earnings while these vessels are being repaired would decrease our results of operations. If a vessel we charter were involved in an accident with the potential risk of environmental impacts or contamination, the resulting media coverage could have a material adverse effect on our reputation, our business, our results of operations and cash flows, weaken our financial condition and negatively affect our ability to pay dividends.

Our chartered vessels operating in international waters, now or in the future, will be subject to various international and local laws and regulations relating to protection of the environment.

Our chartered vessels’ operations in international waters and in the territorial waters of other countries are regulated by extensive and changing international, national and local environmental protection laws, regulations, treaties and conventions in force in international waters, the jurisdictional waters of the countries in which our vessels operate, as well as the countries of our vessels’ registration, including those governing oil spills, discharges to air and water, and the handling and disposal of hazardous substances and wastes. The International Maritime Organization (“IMO”) International Convention for the Prevention of Pollution from Ships of 1973, as amended from time to time, and generally referred to as “MARPOL,” can affect operations of our chartered vessels. In addition, our chartered LNG vessels may become subject to the International Convention on Liability and Compensation for Damage in Connection with the Carriage of Hazardous and Noxious Substances by Sea (the “HNS Convention”), adopted in 1996 and subsequently amended by a Protocol to the HNS Convention in April 2010. Other regulations include, but are not limited to, the designation of Emission Control Areas (“ECAs”) under MARPOL, the IMO International Convention on Civil Liability for Oil Pollution Damage of 1969, as amended from time to time, the International Convention on Civil Liability for Bunker Oil Pollution Damage, the IMO International Convention for the Safety of Life at Sea of 1974, as amended from time to time, the International Safety Management Code for the Safe Operation of Ships and for Pollution Prevention (the “ISM Code”), the IMO International Convention on Load Lines of 1966, as amended from time to time and the International Convention for the Control and Management of Ships’ Ballast Water and Sediments in February 2004.

Moreover, the overall trends are towards more regulations and more stringent requirements which are likely to add to our costs of doing business. We contract with leading vessel providers in the LNG market and look for them to take the lead in maintaining compliance with all such requirements, although the terms of our charter agreements may call for us to bear some or all of the associated costs. While we believe we are similarly situated with respect to other companies that charter vessels, we cannot assure you that these requirements will not have a material effect on our business.

Our chartered vessels operating in U.S. waters, now or in the future, will also be subject to various federal, state and local laws and regulations relating to protection of the environment, including the OPA, the CERCLA, the CWA and the CAA. In some cases, these laws and regulations require governmental permits and authorizations before conducting certain activities. These environmental laws and regulations may impose substantial penalties for noncompliance and substantial liabilities for pollution. Failure to comply with these laws and regulations may result in substantial civil and criminal fines and penalties. As with the industry generally, our chartered vessels’ operations will entail risks in these areas, and compliance with these laws and regulations, which may be subject to frequent revisions and reinterpretation, may increase our overall cost of business.

There may be shortages of LNG tankers worldwide, which could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

We rely on ocean-going LNG tankers and freight carriers (for ISO containers) for the movement of LNG. Consequently, our ability to provide services to our customers could be adversely impacted by shifts in tanker market dynamics, shortages in available cargo capacity, changes in policies and practices such as scheduling, pricing, routes of service and frequency of service, or increases in the cost of fuel, taxes and labor, and other factors not within our control. The construction and delivery of LNG tankers require significant capital and long construction lead times, and the availability of the tankers could be delayed to the detriment of our LNG business and our customers because of:

Changes in ocean freight capacity, which are outside our control, could negatively impact our ability to provide natural gas if LNG shipping capacity is adversely impacted and LNG transportation costs increase because we may bear the risk of such increases and may not be able to pass these increases on to our customers. Material interruptions in service or stoppages in LNG transportation could adversely impact our business, results of operations and financial condition.

Competition in the LNG industry is intense, and some of our competitors have greater financial, technological and other resources than we currently possess.

We plan to operate in the highly competitive area of LNG production and face intense competition from independent, technology-driven companies as well as from both major and other independent oil and natural gas companies and utilities.

Many competing companies have secured access to, or are pursuing development or acquisition of, LNG facilities in North America. We may face competition from major energy companies and others in pursuing our proposed business strategy to provide liquefaction and export products and services. In addition, competitors have and are developing LNG terminals in other markets, which will compete with our LNG facilities. Some of these competitors have longer operating histories, more development experience, greater name recognition, larger staffs and substantially greater financial, technical and marketing resources than we currently possess. We also face competition for the contractors needed to build our facilities. The superior resources that some of these competitors have available for deployment could allow them to compete successfully against us, which could have a material adverse effect on our business, ability to realize benefits from future projects, results of operations, financial condition, liquidity and prospects.

Failure of LNG to be a competitive source of energy in the markets in which we operate, and seek to operate, could adversely affect our expansion strategy.

Our operations are, and will be, dependent upon LNG being a competitive source of energy in the markets in which we operate. In the United States, due mainly to a historic abundant supply of natural gas and discoveries of substantial quantities of unconventional, or shale, natural gas, imported LNG has not developed into a significant energy source. The success of the domestic liquefaction component of our business plan is dependent, in part, on the extent to which natural gas can, for significant periods and in significant volumes, be produced in the United States at a lower cost than the cost to produce some domestic supplies of other alternative energy sources, and that it can be transported at reasonable rates through appropriately scaled infrastructure.

Potential expansion in the Caribbean and other parts of world where we may operate is primarily dependent upon LNG being a competitive source of energy in those geographical locations. For example, in the Caribbean, due mainly to a lack of regasification infrastructure and an underdeveloped international market for natural gas, natural gas has not yet developed into a significant energy source. The success of our operations in the Caribbean is dependent, in part, on the extent to which LNG can, for significant periods and in significant volumes, be produced internationally and delivered to Caribbean customers at a lower cost than the cost to deliver other alternative energy sources.

Political instability in foreign countries that export LNG, or strained relations between such countries and countries in the Caribbean, may also impede the willingness or ability of LNG suppliers and merchants in such countries to export LNG to the Caribbean. Furthermore, some foreign suppliers of LNG may have economic or other reasons to direct their LNG to non-Caribbean markets or from or to our competitors’ LNG facilities. Natural gas also competes with other sources of energy, including coal, oil, nuclear, hydroelectric, wind and solar energy, which may become available at a lower cost in certain markets.

As a result of these and other factors, natural gas may not be a competitive source of energy in the markets we intend to serve or elsewhere. The failure of natural gas to be a competitive supply alternative to oil and other alternative energy sources could adversely affect our ability to deliver LNG or natural gas to our customers in the Caribbean or other locations on a commercial basis.

Any use of hedging arrangements may adversely affect our future operating results or liquidity.

To reduce our exposure to fluctuations in the price, volume and timing risk associated with the purchase of natural gas, we may enter into futures, swaps and option contracts traded or cleared on the Intercontinental Exchange and the New York Mercantile Exchange or over-the-counter (“OTC”) options and swaps with other natural gas merchants and financial institutions. Hedging arrangements would expose us to risk of financial loss in some circumstances, including when:

The use of derivatives also may require the posting of cash collateral with counterparties, which can impact working capital when commodity prices change. However, we do not currently have any hedging arrangements, and failure to properly hedge our positions against changes in natural gas prices could have a material adverse effect on our business, financial condition and operating results.

Our risk management strategies cannot eliminate all LNG price and supply risks. In addition, any non-compliance with our risk management strategies could result in significant financial losses.

When engaged in marketing activities, it is our strategy to maintain a manageable balance between LNG purchases, on the one hand, and sales or future delivery obligations, on the other hand. Through these transactions, we seek to earn a margin for the LNG purchased by selling LNG for physical delivery to third-party users, such as public utilities, shipping/marine cargo companies, industrial users, railroads, trucking fleets and other potential end-users converting from traditional diesel or oil fuel to natural gas. These strategies cannot, however, eliminate all price risks. For example, any event that disrupts our anticipated supply chain could expose us to risk of loss resulting from price changes if we are required to obtain alternative supplies to cover these transactions. We are also exposed to basis risks when LNG is purchased against one pricing index and sold against a different index. Moreover, we are also exposed to other risks, including price risks on LNG we own, which must be maintained in order to facilitate transportation of the LNG to our customers or to our facilities. In addition, our marketing operations involve the risk of non-compliance with our risk management policies. We cannot assure you that our processes and procedures will detect and prevent all violations of our risk management strategies, particularly if deception or other intentional misconduct is involved. If we were to incur a material loss related to commodity price risks, including non-compliance with our risk management strategies, it could have a material adverse effect on our financial position, results of operations and cash flows. There can be no assurance that we will complete the Pennsylvania Facilities or be able to supply our facilities and the CHP Plant with LNG produced at our own facilities. Even if we do complete the Pennsylvania Facilities, there can be no assurance that it will operate as described in this prospectus or that we will succeed in our goal of reducing the risk to our operations of future LNG price variations.

We may experience increased labor costs, and the unavailability of skilled workers or our failure to attract and retain qualified personnel could adversely affect us.

We are dependent upon the available labor pool of skilled employees, including truck drivers. We compete with other energy companies and other employers to attract and retain qualified personnel with the technical skills and experience required to construct and operate our energy-related infrastructure and to provide our customers with the highest quality service. In addition, the tightening of the transportation related labor market due to the shortage of skilled truck drivers may affect our ability to hire and retain skilled truck drivers and require us to pay increased wages. Our affiliates in the United States who hire personnel on our behalf are also subject to the Fair Labor Standards Act, which governs such matters as minimum wage, overtime and other working conditions. We are also subject to applicable labor regulations in the other jurisdictions in which we operate, including Jamaica. We may face challenges and costs in hiring, retaining and managing our Jamaican and other employee base. A shortage in the labor pool of skilled workers, particularly in Jamaica or the United States, or other general inflationary pressures or changes in applicable laws and regulations, could make it more difficult for us to attract and retain qualified personnel and could require an increase in the wage and benefits packages that we offer, thereby increasing our operating costs. Any increase in our operating costs could materially and adversely affect our business, financial condition, operating results, liquidity and prospects.

Our current lack of asset and geographic diversification could have an adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

The substantial majority of our anticipated revenue in 2018 and 2019 will be dependent upon our assets and customers in Jamaica. Jamaica has historically experienced economic volatility and the general condition and performance of the Jamaican economy, over which we have no control, may affect our business, financial condition and results of operations. Due to our current lack of asset and geographic diversification, an adverse development at the Jamaica Terminals, in the energy industry or in the economic conditions in Jamaica, would have a significantly greater impact on our financial condition and operating results than if we maintained more diverse assets and operating areas.

We may incur impairments to goodwill or long-lived assets.

We test our long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of these assets may not be recoverable. We currently intend to test goodwill for impairment annually, or more frequently as circumstances dictate. Significant negative industry or economic trends, and decline of our market capitalization, reduced estimates of future cash flows for our business segments or disruptions to our business could lead to an impairment charge of our long-lived assets, including goodwill. Our valuation methodology for assessing impairment requires management to make judgments and assumptions based on historical experience and to rely heavily on projections of future operating performance. Projections of future operating results and cash flows may vary significantly from results. In addition, if our analysis results in an impairment to our goodwill or long-lived assets, we may be required to record a charge to earnings in our consolidated financial statements during a period in which such impairment is determined to exist, which may negatively impact our operating results.

A major health and safety incident involving LNG or the energy industry more broadly or relating to our business may lead to more stringent regulation of LNG operations or the energy business generally, could result in greater difficulties in obtaining permits, including under environmental laws, on favorable terms, and may otherwise lead to significant liabilities and reputational damage.

Health and safety performance is critical to the success of all areas of our business. Any failure in health and safety performance from our operations may result in an event that causes personal harm or injury to our employees, other persons, and/or the environment, as well as the imposition of injunctive relief and/or penalties for non-compliance with relevant regulatory requirements or litigation. Any such failure that results in a significant health and safety incident may be costly in terms of potential liabilities, and may result in liabilities that exceed the limits of our insurance coverage. Such a failure, or a similar failure elsewhere in the energy industry (including, in particular, LNG liquefaction, storage, transportation or regasification operations), could generate public concern, which may lead to new laws and/or regulations that would impose more stringent requirements on our operations, have a corresponding impact on our ability to obtain permits and approvals, and otherwise jeopardize our reputation or the reputation of our industry as well as our relationships with relevant regulatory agencies and local communities. Individually or collectively, these developments could adversely impact our ability to expand our business, including into new markets. Similarly, such developments could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

The swaps regulatory and other provisions of the Dodd-Frank Wall Street Reform and Consumer Protection Act (the “Dodd-Frank Act”) and the rules adopted thereunder and other regulations, including European Market Infrastructure Regulation (“EMIR”) and Regulation on Wholesale Energy Market Integrity and Transparency (“REMIT”), could adversely affect our ability to hedge risks associated with our business and our operating results and cash flows.

Title VII of the Dodd-Frank Act established federal regulation of the OTC derivatives market and made other amendments to the Commodity Exchange Act that are relevant to our business. The provisions of Title VII of the Dodd-Frank Act and the rules adopted thereunder by the Commodity Futures Trading Commission (“CFTC”), the SEC and other federal regulators may adversely affect our ability to manage certain of our risks on a cost-effective basis. Such laws and regulations may also adversely affect our ability to execute our strategies with respect to hedging our exposure to variability in expected future cash flows attributable to the future sale of our LNG inventory and to price risk attributable to future purchases of natural gas to be utilized as fuel to operate our facilities, our CHP Plant and to secure natural gas feedstock for the Liquefaction Facilities.

The CFTC has proposed new rules setting limits on the positions in certain core futures contracts, economically equivalent futures contracts, options contracts and swaps for or linked to certain physical commodities, including natural gas, held by market participants, with limited exemptions for certain bona fide hedging and other types of transactions. The CFTC has also adopted final rules regarding aggregation of positions, under which a party that controls the trading of, or owns 10% or more of the equity interests in, another party will have to aggregate the positions of the controlled or owned party with its own positions for purposes of determining compliance with position limits unless an exemption applies. The CFTC’s aggregation rules are now in effect, though CFTC staff have granted relief—until August 12, 2019—from various conditions and requirements in the final aggregation rules. With the implementation of the final aggregation rules and upon the adoption and effectiveness of final CFTC position limits rules, our ability to execute our hedging strategies described above could be limited. It is uncertain at this time whether, when and in what form the CFTC’s proposed new position limits rules may become final and effective.

Under the Dodd-Frank Act and the rules adopted thereunder, we may be required to clear through a derivatives clearing organization any swaps into which we enter that fall within a class of swaps designated by the CFTC for mandatory clearing and we could have to execute trades in such swaps on certain trading platforms. The CFTC has designated six classes of interest rate swaps and credit default swaps for mandatory clearing, but has not yet proposed rules designating any other classes of swaps, including physical commodity swaps, for mandatory clearing. Although we expect to qualify for the end-user exception from the mandatory clearing and trade execution requirements for any swaps entered into to hedge our commercial risks, if we fail to qualify for that exception and have to clear such swaps through a derivatives clearing organization, we could be required to post margin with respect to such swaps, our cost of entering into and maintaining such swaps could increase and we would not enjoy the same flexibility with the cleared swaps that we enjoy with the uncleared OTC swaps we enter. Moreover, the application of the mandatory clearing and trade execution requirements to other market participants, such as Swap Dealers, may change the cost and availability of the swaps that we use for hedging.

As required by the Dodd-Frank Act, the CFTC and the federal banking regulators have adopted rules requiring certain market participants to collect initial and variation margin with respect to uncleared swaps from their counterparties that are financial end-users and certain registered Swap Dealers and Major Swap Participants. The requirements of those rules are subject to a phased-in compliance schedule, which commenced on September 1, 2016. Although we believe we will qualify as a non-financial end user for purposes of these rules, were we not to do so and have to post margin as to our uncleared swaps in the future, our cost of entering into and maintaining swaps would be increased. Our counterparties that are subject to the Basel III capital requirements may increase the cost to us of entering into swaps with them or, although not required to collect margin from us under the margin rules, require us to post collateral with them in connection with such swaps in order to offset their increased capital costs or to reduce their capital costs to maintain those swaps on their balance sheets.

The Dodd-Frank Act also imposes regulatory requirements on swaps market participants, including Swap Dealers and other swaps entities as well as certain regulations on end-users of swaps, including regulations relating to swap documentation, reporting and recordkeeping, and certain business conduct rules applicable to Swap Dealers and other swaps entities. Together with the Basel III capital requirements on certain swaps market participants, these regulations could significantly increase the cost of derivative contracts (including through requirements to post margin or collateral), materially alter the terms of derivative contracts, reduce the availability of derivatives to protect against certain risks that we encounter, and reduce our ability to monetize or restructure our existing derivative contracts and to execute our hedging strategies. If, as a result of the swaps regulatory regime discussed above, we were to forgo or reduce our use of swaps to hedge our risks, such as commodity price risks that we encounter in our operations, our operating results and cash flows may become more volatile and could be otherwise adversely affected.

EMIR may result in increased costs for OTC derivative counterparties and also lead to an increase in the costs of, and demand for, the liquid collateral that EMIR requires central counterparties to accept. Although we expect to qualify as a non-financial counterparty under EMIR and thus not be required to post margin under EMIR, our subsidiaries and affiliates operating in the Caribbean may still be subject to increased regulatory requirements, including recordkeeping, marking to market, timely confirmations, derivatives reporting, portfolio reconciliation and dispute resolution procedures. Regulation under EMIR could significantly increase the cost of

derivatives contracts, materially alter the terms of derivatives contracts and reduce the availability of derivatives to protect against risks that we encounter. The increased trading costs and collateral costs may have an adverse impact on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

Our subsidiaries and affiliates operating in the Caribbean may be subject to REMIT as wholesale energy market participants. This classification imposes increased regulatory obligations on our subsidiaries and affiliates, including a prohibition to use or disclose insider information or to engage in market manipulation in wholesale energy markets, and an obligation to report certain data. These regulatory obligations may increase the cost of compliance for our business and if we violate these laws and regulations, we could be subject to investigation and penalties.

Failure to obtain and maintain permits, approvals and authorizations from governmental and regulatory agencies on favorable terms with respect to the design, construction and operation of our facilities could impede operations and construction and could have a material adverse effect on us.

The design, construction and operation of energy-related infrastructure, including our existing and proposed facilities, the import and export of LNG and the transportation of natural gas, are highly regulated activities at the federal, state and local levels. Approvals of the DOE under Section 3 of the NGA, as well as several other material governmental and regulatory permits, approvals and authorizations, including under the CAA and the CWA and their state analogues, may be required in order to construct and operate an LNG facility and export LNG. Permits, approvals and authorizations obtained from the FERC, DOE and other federal and state regulatory agencies also contain ongoing conditions, and additional requirements may be imposed. Certain federal permitting processes may trigger the requirements of the National Environmental Policy Act (“NEPA”), which requires federal agencies to evaluate major agency actions that have the potential to significantly impact the environment. Compliance with NEPA may extend the time and/or increase the costs for obtaining necessary governmental approvals associated with our operations and create independent risk of legal challenges to the adequacy of the NEPA analysis, which could result in delays that may adversely affect our business, contracts, financial condition, operating results, cash flow, liquidity and profitability. We may also be subject to yet additional requirements in Jamaica, Bermuda, Mexico, Ireland or other jurisdictions, including with respect to land use approvals needed to construct and operate our facilities.

We cannot control the outcome of any review and approval process, including whether or when any such permits, approvals and authorizations will be obtained, the terms of their issuance, or possible appeals or other potential interventions by third parties that could interfere with our ability to obtain and maintain such permits, approvals and authorizations or the terms thereof. If we are unable to obtain and maintain such permits, approvals and authorizations on favorable terms, we may not be able to recover our investment in our projects. Many of these permits, approvals and authorizations require public notice and comment before they can be issued, which can lead to delays to respond to such comments, and even potentially to revise the permit application. There is no assurance that we will obtain and maintain these governmental permits, approvals and authorizations on favorable terms, or that we will be able to obtain them on a timely basis, and failure to obtain and maintain any of these permits, approvals or authorizations could have a material adverse effect on our business, financial condition, operating results, liquidity and prospects. Moreover, many of these permits, approvals and authorizations are subject to administrative and judicial challenges, which can delay and protract the process for obtaining and implementing permits and can also add significant costs and uncertainty.

Existing and future environmental, health and safety laws and regulations could result in increased compliance costs or additional operating costs or construction costs and restrictions.

Our business is now and will in the future be subject to extensive federal, state and local laws and regulations both in the United States and in other jurisdictions where we operate that regulate and restrict, among other things, the siting and design of our facilities, discharges to air, land and water, with particular respect to the protection of human health, the environment and natural resources from risks associated with storing, receiving and transporting LNG; the handling, storage and disposal of hazardous materials, hazardous waste and petroleum products; and remediation associated with the release of hazardous substances. For example, PHMSA has promulgated detailed regulations governing LNG facilities under its jurisdiction to address LNG facility siting, design, construction, equipment, operations, maintenance, personnel qualifications and training, fire protection and security. None of our LNG facilities are subject to PHMSA’s jurisdiction, but state and local regulators can impose similar siting, design, construction and operational requirements.

Federal and state laws impose liability, without regard to fault or the lawfulness of the original conduct, for the release of certain types or quantities of hazardous substances into the environment. As the owner and operator of our facilities, we could be liable for the costs of cleaning up any such hazardous substances that may be released into the environment at or from our facilities and for resulting damage to natural resources.

Many of these laws and regulations, such as the CAA and the CWA, and analogous state laws and regulations, restrict or prohibit the types, quantities and concentration of substances that can be emitted into the environment in connection with the construction and operation of our facilities, and require us to obtain and maintain permits and provide governmental authorities with access to our facilities for inspection and reports related to our compliance. For example, the Pennsylvania Department of Environmental Protection laws and regulations will apply to the construction and operation of the Pennsylvania Facilities. Relevant local authorities may also require us to obtain and maintain permits associated with the construction and operation of our facilities, including with respect to land use approvals. Failure to comply with these laws and regulations could lead to substantial liabilities, fines and penalties or capital expenditures related to pollution control equipment and restrictions or curtailment of our operations, which could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

Other future legislation and regulations could cause additional expenditures, restrictions and delays in our business and to our proposed construction, the extent of which cannot be predicted and which may require us to limit substantially, delay or cease operations in some circumstances. In October 2017, the U.S. Government Accountability Office issued a legal determination that a 2013 interagency guidance document was a “rule” subject to the Congressional Review Act (“CRA”). This legal determination could open a broader set of agency guidance documents to potential disapproval and invalidation under the CRA, potentially increasing the likelihood that laws and regulations applicable to our business will become subject to revised interpretations in the future that we cannot predict. Revised, reinterpreted or additional laws and regulations that result in increased compliance costs or additional operating or construction costs and restrictions could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

Greenhouse Gases/Climate Change. From time to time, there may be federal and state regulatory and policy initiatives to reduce GHG emissions in the United States from a variety of sources. Other federal and state initiatives are being considered or may be considered in the future to address GHG emissions through, for example, United States treaty commitments or other international agreements, direct regulation, a carbon emissions tax, or cap-and-trade programs.

Responding to scientific reports regarding threats posed by global climate change, the U.S. Congress has in the past considered legislation to reduce emissions of GHGs. In addition, some states and foreign jurisdictions have individually or in regional cooperation, imposed restrictions on GHG emissions under various policies and approaches, including establishing a cap on emissions, requiring efficiency measures, or providing incentives for pollution reduction, use of renewable energy sources, or use of replacement fuels with lower carbon content.

The adoption and implementation of any U.S. federal, state or local regulations or foreign regulations imposing obligations on, or limiting emissions of GHGs from, our equipment and operations could require us to incur significant costs to reduce emissions of GHGs associated with our operations or could adversely affect demand for natural gas and natural gas products. The potential increase in our operating costs could include new costs to operate and maintain our facilities, install new emission controls on our facilities, acquire allowances to authorize our GHG emissions, pay taxes related to our GHG emissions, and administer and manage a GHG emissions program. We may not be able to recover such increased costs through increases in customer prices or rates. In addition, changes in regulatory policies that result in a reduction in the demand for hydrocarbon products that are deemed to contribute to GHGs, or restrict their use, may reduce volumes available to us for processing, transportation, marketing and storage. These developments could have a material adverse effect on our financial position, results of operations and cash flows.

In addition, due to concerns over climate change, numerous countries around the world have adopted or are considering adopting laws or regulations to reduce GHG emissions. In December 2015, the U.S. and 195 other nations attending the United Nations Climate Change Conference adopted the Paris Agreement on global climate change, which establishes a universal framework for addressing GHG emissions based on nationally determined contributions. The Paris Agreement calls for zero net anthropogenic GHG emission to be reached during the second half of the 21^st century. Each party is to prepare a plan on its contributions to reach this goal; each plan

is to be filed in a publicly available registry. The Paris Agreement does not create any binding obligations for nations to limit their GHG emissions but rather includes pledges to voluntarily limit or reduce future emissions. It also creates a process for participating countries to review and increase their intended emissions reduction goals every five years. The ultimate impact of the Paris Agreement depends on its ratification and implementation by participating countries, and cannot be determined at this time. Although the United States became a party to the Paris Agreement in April 2016, the Trump administration subsequently announced in June 2017 its intention either to withdraw from the Paris Agreement or renegotiate more favorable terms. However, the Paris Agreement stipulates that participating countries must wait four years before withdrawing from the agreement. It is not possible to know how quickly renewable energy technologies may advance, but the increased use of renewable energy could ultimately reduce future demand for hydrocarbons. These developments could have a material adverse effect on our financial position, results of operations and cash flows.

Fossil Fuels. Our business activities depend upon a sufficient and reliable supply of natural gas feedstock, and are therefore subject to concerns in certain sectors of the public about the exploration, production and transportation of natural gas and other fossil fuels and the consumption of fossil fuels more generally. Legislative and regulatory action, and possible litigation, in response to such public concerns may also adversely affect our operations. We may be subject to future laws, regulations, or actions to address such public concern with fossil fuel generation, distribution and combustion, greenhouse gases and the effects of global climate change. Our customers may also move away from using fossil fuels such as LNG for their power generation needs for reputational or perceived risk-related reasons. These matters represent uncertainties in the operation and management of our business, and could have a material adverse effect on our financial position, results of operations and cash flows.

Hydraulic Fracturing. Certain of our suppliers employ hydraulic fracturing techniques to stimulate natural gas production from unconventional geological formations (including shale formations), which currently entails the injection of pressurized fracturing fluids (consisting of water, sand and certain chemicals) into a well bore. Moreover, hydraulically fractured natural gas wells account for a significant percentage of the natural gas production in the U.S.; the U.S. Energy Information Administration reported in 2016 that hydraulically fractured wells provided two-thirds of U.S. marketed gas production in 2015. The requirements for permits or authorizations to conduct these activities vary depending on the location where such drilling and completion activities will be conducted. Several states have adopted or are considering adopting regulations to impose more stringent permitting, public disclosure or well construction requirements on hydraulic fracturing operations, or to ban hydraulic fracturing altogether. As with most permitting and authorization processes, there is a degree of uncertainty as to whether a permit will be granted, the time it will take for a permit or approval to be issued and any conditions which may be imposed in connection with the granting of the permit. Certain regulatory authorities have delayed or suspended the issuance of permits or authorizations while the potential environmental impacts associated with issuing such permits can be studied and appropriate mitigation measures evaluated. In addition to state laws, some local municipalities have adopted or are considering adopting land use restrictions, such as city ordinances, that may restrict the performance of or prohibit the well drilling in general and/or hydraulic fracturing in particular.

Hydraulic fracturing activities are typically regulated at the state level, but federal agencies have asserted regulatory authority over certain hydraulic fracturing activities and equipment used in the production, transmission and distribution of oil and natural gas, including such oil and natural gas produced via hydraulic fracturing. Federal and state legislatures and agencies may seek to further regulate or even ban such activities. For example, the Delaware River Basin Commission (“DRBC”), a regional body created via interstate compact responsible for, among other things, water quality protection, water supply allocation, regulatory review, water conservation initiatives, and watershed planning in the Delaware River Basin, has implemented a de facto ban on hydraulic fracturing activities in that basin since 2010 pending the approval of new regulations governing natural gas production activity in the basin. More recently, the DRBC has stated that it will consider new regulations that would ban natural gas production activity, including hydraulic fracturing, in the basin. If additional levels of regulation or permitting requirements were imposed on hydraulic fracturing operations, natural gas prices in North America could rise, which in turn could materially adversely affect the relative pricing advantage that has existed in recent years in favor of domestic natural gas prices (based on Henry Hub pricing). Increased regulation or difficulty in permitting of hydraulic fracturing, and any corresponding increase in domestic natural gas prices, could materially adversely affect demand for LNG and our ability to develop commercially viable LNG facilities.

We are subject to numerous governmental export laws and trade and economic sanctions laws and regulations. A failure by us to comply with such laws and regulations could subject us to liability and have a material adverse impact on our business, results of operations or financial condition.

We conduct business throughout the world and our business activities and services are subject to various applicable import and export control laws and regulations of the United States and other countries, particularly countries in the Caribbean. We must also comply with U.S. trade and economic sanctions laws, including the U.S. Commerce Department’s Export Administration Regulations and economic and trade sanctions regulations maintained by the U.S. Treasury Department’s Office of Foreign Assets Control. Although we take precautions to comply with all such laws and regulations, violations of governmental export control and economic sanctions laws and regulations could result in negative consequences to us, including government investigations, sanctions, criminal or civil fines or penalties, more onerous compliance requirements, loss of authorizations needed to conduct aspects of our international business, reputational harm and other adverse consequences.

We are also subject to anti-corruption laws and regulations, including the U.S. Foreign Corrupt Practices Act (“FCPA”), which generally prohibit companies and their intermediaries from making improper payments to foreign officials for the purpose of obtaining or keeping business and/or other benefits. Although we have adopted policies and procedures that are designed to ensure that we, our employees and other intermediaries comply with the FCPA, there is no assurance that these policies and procedures will work effectively all of the time or protect us against liability under anti-corruption laws and regulations, including the FCPA, for actions taken by our employees and other intermediaries with respect to our business or any businesses that we may acquire. If we are not in compliance with anti-corruption laws and regulations, including the FCPA, we may be subject to criminal and civil penalties and other remedial measures, including changes or enhancements to our procedures, policies and control, as well as potential personnel change and disciplinary actions, which could have an adverse impact on our business, results of operations and financial condition.

In addition, in certain countries we serve or expect to serve our customers through third-party agents and other intermediaries, such as customs agents. Violations of applicable import, export, trade and economic sanctions laws and regulations by these third-party agents or intermediaries may also result in adverse consequences and repercussions to us. There can be no assurance that we and our agents and other intermediaries will be in compliance with export control and economic sanctions laws and regulations in the future. In such event of non-compliance, our business and results of operations could be adversely impacted.

Risks Relating to the Jurisdictions in Which We Operate

We are currently highly dependent upon economic, political and other conditions and developments in the Caribbean, particularly Jamaica, and the other jurisdictions in which we operate.

We currently conduct a meaningful portion of our business in Jamaica. As a result, our current business, results of operations, financial condition and prospects are materially dependent upon economic, political and other conditions and developments in Jamaica.

We currently have interests and operations in Jamaica and the United States and currently intend to expand into the Caribbean, Mexico, Ireland and other geographies, and such interests are subject to governmental regulation in each market. The governments in these markets differ widely with respect to structure, constitution and stability and some countries lack mature legal and regulatory systems. To the extent that our operations depend on governmental approval and regulatory decisions, the operations may be adversely affected by changes in the political structure or government representatives in each of the markets in which we operate. Recent political, security and economic changes have resulted in political and regulatory uncertainty in certain countries in which we operate or may pursue operations. Some of these countries have experienced political, security and economic instability in the recent past and may experience instability in the future.

Any slowdown or contraction affecting the local economy in a jurisdiction in which we operate could negatively affect the ability of our customers to purchase LNG, natural gas, steam or power from us or to fulfill their obligations under their contracts with us. If the economy in Jamaica or other jurisdictions in which we operate worsens because of, for example:

then our business, results of operations, financial condition and prospects may also be significantly affected by actions taken by the government in the jurisdictions in which we operate. Caribbean governments traditionally have played a central role in the economy and continue to exercise significant influence over many aspects of it. They may make changes in policy, or new laws or regulations may be enacted or promulgated, relating to, for example, monetary policy, taxation, exchange controls, interest rates, regulation of banking and financial services and other industries, government budgeting and public sector financing. These and other future developments in the Jamaican economy or in the governmental policies in our Caribbean markets may reduce demand for our products, adversely affect our business, financial condition, results of operations or prospects.

For example, JPS and JPC are subject to the mandate of the OUR. The OUR regulates the amount of money that power utilities in Jamaica, including JPS and JPC, can charge their customers. Though the OUR cannot impact the fixed price we charge our customers for LNG, pricing regulations by the OUR and other similar regulators could negatively impact our customers’ ability to perform their obligations under our GSAs and, in the case of JPS, the PPA, which could adversely affect our business, financial condition, results of operations or prospects.

Our financial condition and operating results may be adversely affected by foreign exchange fluctuations.

Our consolidated financial statements are presented in U.S. dollars. Therefore, fluctuations in exchange rates used to translate other currencies into U.S. dollars will impact our reported consolidated financial condition, results of operations and cash flows from period to period. These fluctuations in exchange rates will also impact the value of our investments and the return on our investments. Additionally, some of the jurisdictions in which we operate may limit our ability to exchange local currency for U.S. dollars.

A portion of our cash flows and expenses may in the future be incurred in currencies other than the U.S. dollar. Our material counterparties’ cash flows and expenses may be incurred in currencies other than the U.S. dollar. We cannot be sure that non-U.S. currencies will not be subject to volatility and depreciation or that the current exchange rate policies affecting these currencies will remain the same. We may choose not to hedge, or we may not be effective in efforts to hedge, this foreign currency risk. Depreciation or volatility of the Jamaican dollar against the U.S. dollar or other currencies could cause counterparties to be unable to pay their contractual obligations under our agreements or to lose confidence in us and may cause our expenses to increase from time to time relative to our revenues as a result of fluctuations in exchange rates, which could affect the amount of net income that we report in future periods.

We have operations in multiple jurisdictions and may expand our operations to additional jurisdictions, including jurisdictions in which the tax laws, their interpretation or their administration may change. As a result, our tax obligations and related filings are complex and subject to change, and our after-tax profitability could be lower than anticipated.

We are subject to income, withholding and other taxes in the United States on a worldwide basis and in numerous state, local and foreign jurisdictions with respect to our income and operations related to those jurisdictions. Our after-tax profitability could be affected by numerous factors, including the availability of tax credits, exemptions and other benefits to reduce our tax liabilities, changes in the relative amount of our earnings subject to tax in the various jurisdictions in which we operate, the potential expansion of our business into or otherwise becoming subject to tax in additional jurisdictions, changes to our existing businesses and operations, the extent of our intercompany transactions and the extent to which taxing authorities in the relevant jurisdictions respect those intercompany transactions.

In addition, our after-tax profitability may be affected by changes in the relevant tax laws and tax rates, regulations, administrative practices and principles, judicial decisions, and interpretations, in each case, possibly with retroactive effect. The United States recently enacted tax reform legislation in Public Law No. 115-97, commonly referred to as the Tax Cuts and Jobs Act, and the Multilateral Convention to Implement Tax Treaty Related Measures to Prevent BEPS recently entered into force among the jurisdictions that ratified it, both of which could result in further changes to our global taxation. These tax reforms provided for new and complex

provisions that significantly change how the United States and other jurisdictions tax entities and operations, and those provisions are subject to further legislative change and administrative guidance and interpretation, all of which may differ from our interpretation. Other countries in which we operate may also undergo tax reforms that could adversely impact our after-tax profitability.

Risks Inherent in an Investment in Us

New Fortress Energy Holdings has the ability to direct the voting of a majority of our shares, and its interests may conflict with those of our other shareholders.

Upon completion of this offering, New Fortress Energy Holdings will initially own, an aggregate of approximately    Class B shares representing       % of our voting power (or approximately       % if the underwriters’ option to purchase additional Class A shares is exercised in full). New Fortress Energy Holdings’ beneficial ownership of greater than 50% of our voting shares means New Fortress Energy Holdings will be able to control matters requiring shareholder approval, including the election of directors, changes to our organizational documents and significant corporate transactions. This concentration of ownership makes it unlikely that any other holder or group of holders of our Class A shares will be able to affect the way we are managed or the direction of our business. The interests of New Fortress Energy Holdings with respect to matters potentially or actually involving or affecting us, such as future acquisitions, financings and other corporate opportunities and attempts to acquire us, may conflict with the interests of our other shareholders. Given this concentrated ownership, New Fortress Energy Holdings would have to approve any potential acquisition of us. The existence of a significant shareholder may have the effect of deterring hostile takeovers, delaying or preventing changes in control or changes in management, or limiting the ability of our other shareholders to approve transactions that they may deem to be in the best interests of our company. Moreover, New Fortress Energy Holdings’ concentration of share ownership may adversely affect the trading price of our Class A shares to the extent investors perceive a disadvantage in owning stock of a company with a significant shareholder.

In addition, New Fortress Energy Holdings may have different tax positions from us that could influence its decisions regarding whether and when to support the disposition of assets, the incurrence or refinancing of new or existing indebtedness. In addition, the determination of future tax reporting positions, the structuring of future transactions and the handling of any challenge by any taxing authority to our tax reporting positions may take into consideration New Fortress Energy Holdings’s tax or other considerations which may differ from the considerations of us or our other stockholders.

New Fortress Energy Holdings may compete with us.

Our governing documents will provide that New Fortress Energy Holdings is not prohibited from engaging in other businesses or activities, including those that might be in direct competition with us. In addition, New Fortress Energy Holdings may compete with us for investment opportunities and may own an interest in entities that compete with us. Additionally, our operating agreement provides that if New Fortress Energy Holdings or an affiliate or any of their officers, directors or employees acquire knowledge of a potential transaction that could be a corporate opportunity, they have no duty, to the fullest extent permitted by law, to offer such corporate opportunity to us, our Class A shareholders or our affiliates. This may create actual and potential conflicts of interest between us and New Fortress Energy Holdings and result in less than favorable treatment of us and our Class A shareholders.

Our operating agreement, as well as Delaware law, will contain provisions that could discourage acquisition bids or merger proposals, which may adversely affect the market price of our Class A shares and could deprive our investors of the opportunity to receive a premium for their shares.

Our operating agreement will authorize our board of directors to issue preferred shares without shareholder approval in one or more series, designate the number of shares constituting any series, and fix the rights, preferences, privileges and restrictions thereof, including dividend rights, voting rights, rights and terms of redemption, redemption price or prices and liquidation preferences of such series. If our board of directors elects to issue preferred shares, it could be more difficult for a third party to acquire us. In addition, some provisions of our operating agreement could make it more difficult for a third party to acquire control of us, even if the change of control would be beneficial to our shareholders. These provisions include:

There are certain provisions in our operating agreement regarding exculpation and indemnification of our officers and directors that differ from the Delaware General Corporation Law (“DGCL”) in a manner that may be less protective of the interests of our Class A shareholders.

Our operating agreement provides that to the fullest extent permitted by applicable law our directors or officers will not be liable to us. By contrast, under the DGCL, a director or officer would be liable to us for (i) breach of duty of loyalty to us or our shareholders, (ii) intentional misconduct or knowing violations of the law that are not done in good faith, (iii) improper redemption of shares or declaration of dividends, or (iv) a transaction from which the director derived an improper personal benefit. In addition, our operating agreement provides that we indemnify our directors and officers for acts or omissions to the fullest extent provided by law. By contrast, under the DGCL, a corporation can only indemnify directors and officers for acts or omissions if the director or officer acted in good faith, in a manner he reasonably believed to be in the best interests of the corporation, and, in criminal action, if the officer or director had no reasonable cause to believe his conduct was unlawful. Accordingly, our operating agreement may be less protective of the interests of our Class A shareholders, when compared to the DGCL, insofar as it relates to the exculpation and indemnification of our officers and directors.

Shareholders will experience immediate and substantial dilution of $       per Class A share.

The assumed initial public offering price of $       per Class A share (the mid-point of the price range set forth on the cover page of this prospectus) exceeds our pro forma net tangible book value of $       per Class A share. Based on the assumed initial public offering price of $       per Class A share, shareholders will incur immediate and substantial dilution of $       per Class A share in the pro forma net tangible book value per share. This dilution results primarily because the assets contributed to us by New Fortress Energy Holdings are recorded at their historical cost in accordance with generally accepted accounting principles (“GAAP”), and not their fair value. Please read “Dilution.”

We do not intend to pay cash dividends on our Class A shares. Consequently, your only opportunity to achieve a return on your investment is if the price of our Class A shares appreciates.

We do not plan to declare cash dividends on our Class A shares in the foreseeable future. Consequently, your only opportunity to achieve a return on your investment in us will be if you sell your Class A share at a price greater than you paid for it. There is no guarantee that the price of our Class A shares that will prevail in the market will ever exceed the price that you pay in this offering.

We may issue preferred shares, the terms of which could adversely affect the voting power or value of our Class A shares.

Our operating agreement will authorize us to issue, without the approval of our shareholders, one or more classes or series of preferred shares having such designations, preferences, limitations and relative rights, including preferences over our Class A shares respecting dividends and distributions, as our board of directors

may determine. The terms of one or more classes or series of preferred shares could adversely impact the voting power or value of our Class A shares. For example, we might grant holders of preferred shares the right to elect some number of our directors in all events or on the happening of specified events or the right to veto specified transactions. Similarly, the repurchase or redemption rights or liquidation preferences we might assign to holders of preferred shares could affect the residual value of the Class A shares.

The market price of our Class A shares could be adversely affected by sales of substantial amounts of our Class A shares in the public or private markets or the perception in the public markets that these sales may occur, including sales by New Fortress Energy Holdings after the exercise of the Redemption Right or other large holders.

After this offering, we will have          Class A shares and          Class B shares outstanding, assuming no exercise of the underwriters’ option to purchase additional Class A shares. The Class A shares sold in this offering will be freely tradable without restriction under the Securities Act except for any Class A shares that may be held or acquired by our directors, officers or affiliates, which will be restricted securities under the Securities Act. The NFI LLC Units held by New Fortress Energy Holdings and any Class A shares New Fortress Energy Holdings acquires through the exercise of the Redemption Right will be subject to resale restrictions under a 180-day lock-up agreement with the underwriters. Each of the lock-up agreements with the underwriters may be waived in the discretion of certain of the underwriters. Sales by New Fortress Energy Holdings after the exercise of the Redemption Right or other large holders of a substantial number of our Class A shares in the public markets following this offering, or the perception that such sales might occur, could have a material adverse effect on the price of our Class A shares or could impair our ability to obtain capital through an offering of equity securities. In addition, we have agreed to provide registration rights to New Fortress Energy Holdings. Alternatively, we may be required to undertake a future public or private offering of Class A shares and use the net proceeds from such offering to purchase an equal number of NFI LLC Units from New Fortress Energy Holdings. Please read “Shares Eligible for Future Sale.”

There is no existing market for our Class A shares and a trading market that will provide you with adequate liquidity may not develop. The price of our Class A shares may fluctuate significantly, and shareholders could lose all or part of their investment.

Prior to this offering, there has been no public market for the Class A shares. After this offering, there will be only             publicly-traded Class A shares. We do not know the extent to which investor interest will lead to the development of a trading market or how liquid that market might be. Class A shareholders may not be able to resell their Class A shares at or above the initial public offering price. Additionally, the lack of liquidity may result in wide bid-ask spreads, contribute to significant fluctuations in the market price of the Class A shares and limit the number of investors who are able to buy the Class A shares.

The initial public offering price for our Class A shares will be determined by negotiations between us and the representatives of the underwriters and may not be indicative of the price of the Class A shares that will prevail in the trading market. The market price of our Class A shares may decline below the initial public offering price. The market price of our Class A shares may also be influenced by many factors, some of which are beyond our control, including:

We expect to be a “controlled company” within the meaning of NASDAQ rules and, as a result, will qualify for and intend to rely on exemptions from certain corporate governance requirements.

Upon completion of this offering, New Fortress Energy Holdings will hold a majority of the voting power of our shares. As a result, we expect to be a controlled company within the meaning of NASDAQ corporate governance standards. Under NASDAQ rules, a company of which more than 50% of the voting power for the election of directors is held by an individual, a group or another company is a controlled company and may elect not to comply with certain NASDAQ corporate governance requirements, including the requirements that:

These requirements will not apply to us as long as we remain a controlled company. A controlled company does not need its board of directors to have a majority of independent directors or to form independent compensation and nominating and governance committees. Following this offering, we intend to utilize some or all of these exemptions. Accordingly, you may not have the same protections afforded to shareholders of companies that are subject to all of the corporate governance requirements of NASDAQ. See “Management.”

For as long as we are an emerging growth company, we will not be required to comply with certain reporting requirements that apply to other public companies, including those relating to auditing standards and disclosure about our executive compensation.

The JOBS Act contains provisions that, among other things, relax certain reporting requirements for “emerging growth companies,” including certain requirements relating to auditing standards and compensation disclosure. We are classified as an emerging growth company. For as long as we are an emerging growth company, which may be up to five full fiscal years, unlike other public companies, we will not be required to, among other things, (i) provide an auditor’s attestation report on management’s assessment of the effectiveness of our system of internal control over financial reporting pursuant to Section 404(b) of the Sarbanes-Oxley Act, (ii) comply with any new requirements adopted by the PCAOB requiring mandatory audit firm rotation or a supplement to the auditor’s report in which the auditor would be required to provide additional information about the audit and the financial statements of the issuer, (iii) provide certain disclosures regarding executive compensation required of larger public companies, or (iv) hold nonbinding advisory votes on executive compensation. We currently intend to take advantage of the exemptions described above. We have also elected to use the extended transition period for complying with new or revised accounting standards under Section 102(b)(2) of the JOBS Act. This election allows us to delay the adoption of new or revised accounting standards that have different effective dates for public and private companies until those standards apply to private companies. As a result, our financial statements may not be comparable to companies that comply with public company effective dates, and our stockholders and potential investors may have difficulty in analyzing our operating results if comparing us to such companies. We will remain an emerging growth company for up to five years, although we will lose that status sooner if we have more than $1.07 billion of revenues in a fiscal year, have more than $700.0 million in market value of our Class A shareholders held by non-affiliates, or issue more than $1.0 billion of non-convertible debt over a three-year period.

To the extent that we rely on any of the exemptions available to emerging growth companies, you will receive less information about our executive compensation and internal control over financial reporting than issuers that are not emerging growth companies. If some investors find our Class A shares to be less attractive as a result, there may be a less active trading market for our Class A shares and our Class A share price may be more volatile.

If we fail to develop or maintain an effective system of internal controls, we may not be able to accurately report our financial results or prevent fraud. As a result, current and potential shareholders could lose confidence in our financial reporting, which would harm our business and the trading price of our Class A shares.

Effective internal controls are necessary for us to provide reliable financial reports, prevent fraud and operate successfully as a publicly traded company. If we cannot provide reliable financial reports or prevent fraud, our reputation and operating results would be harmed. In connection with the preparation of our financial statements for the year ended December 31, 2017, we concluded there was a significant deficiency in our internal controls over financial reporting. While we implemented measures, or expect to implement measures, to address this deficiency, we cannot be certain that our efforts to develop and maintain our internal controls will be successful, that we will be able to maintain adequate controls over our financial processes and reporting in the future or that we will be able to comply with our obligations under Section 404 of the Sarbanes-Oxley Act. In connection with our efforts to maintain effective internal controls, we intend to hire additional accounting personnel as well as to make additional investments in software and systems. Any failure to develop or maintain effective internal controls, or difficulties encountered in implementing or improving our internal controls, could harm our operating results or cause us to fail to meet our reporting obligations. Ineffective internal controls could also cause investors to lose confidence in our reported financial information, which would likely have a negative effect on the trading price of our Class A shares.

We will incur increased costs as a result of being a public company.

We have no history operating as a publicly traded company. As a newly public company with shares listed on NASDAQ, we will need to comply with an extensive body of regulations that did not apply to us previously, including certain provisions of the Sarbanes-Oxley Act, the Dodd-Frank Wall Street Reform and Consumer Protection Act, regulations of the SEC and NASDAQ requirements. We expect these rules and regulations will increase our legal, accounting and other expenses that we did not incur prior to this offering and make some activities more time-consuming and costly. For example, as a result of becoming a public company, we intend to add independent directors and create additional board committees. In addition, we may incur additional costs associated with our public company reporting requirements and maintaining directors’ and officers’ liability insurance. Because of the limitations in coverage for directors, it may be more difficult for us to attract and retain qualified persons to serve on our board of directors or as executive officers. We estimate that we will incur approximately $    million of incremental costs per year associated with being a publicly traded company; however, it is possible that our actual incremental costs of being a publicly traded company will be higher than we currently estimate. We are currently evaluating and monitoring developments with respect to these rules, which may impose additional costs on us and have a material adverse effect on our business, prospects, financial condition, results of operations and cash flows.

If securities or industry analysts do not publish research or reports about our business, if they adversely change their recommendations regarding our Class A shares or if our operating results do not meet their expectations, our share price could decline.

The trading market for our Class A shares will be influenced by the research and reports that industry or securities analysts publish about us or our business. If one or more of these analysts cease coverage of our company or fail to publish reports on us regularly, we could lose viability in the financial markets, which in turn could cause our share price or trading volume to decline.

NFE is a holding company. NFE’s sole material asset after completion of this offering will be its equity interest in NFI, and accordingly, NFE will be dependent upon distributions from NFI to pay taxes and cover its corporate and other overhead expenses.

NFE is a holding company and will have no material assets other than its equity interest in NFI. Please read “Summary—Organizational Structure.” NFE has no independent means of generating revenue. To the extent NFI has available cash and subject to the terms of NFI’s credit agreements and any other debt instruments, we intend to cause NFI to make (i) pro rata distributions to its unitholders, including NFE, in an amount sufficient to allow NFE to pay its taxes, (ii) at the election of certain holders of NFI LLC Units, additional distributions in an amount generally intended to allow such holders to satisfy their respective income tax liabilities with respect to their allocable share of the income of NFI (based on certain assumptions and conventions), which additional distributions may be made on a pro rata basis to all holders of NFI LLC Units or a non-pro rata basis in

redemption of NFI LLC Units from the relevant holders, and (iii) non pro rata distributions to NFE in an amount at least sufficient to reimburse NFE for its corporate and other overhead expenses. To the extent that NFE needs funds and NFI or its subsidiaries are restricted from making such distributions under applicable law or regulation or under the terms of their financing arrangements or are otherwise unable to provide such funds, NFE’s liquidity and financial condition could be adversely affected.

In certain circumstances, NFI will be required to make tax distributions to holders of NFI LLC Units, and such tax distributions may be substantial. To the extent NFE receives tax distributions in excess of its actual tax liabilities and retains such excess cash, the holders of NFI LLC Units would benefit from such accumulated cash balances if they exercise their Redemption Right.

Pursuant to the NFI LLC Agreement, NFI will make generally pro rata distributions to the holders of NFI LLC Units, including NFE, in an amount sufficient to allow NFE to satisfy its actual tax liabilities. In addition, to the extent NFI has available cash and certain holders of NFI LLC Units require additional distributions to satisfy their assumed income tax liabilities with respect to their allocable share of the income of NFI (based on certain assumptions and conventions) and elect to receive such distributions, NFI will be required to make additional tax distributions in an amount generally intended to allow such other holders of NFI LLC Units to satisfy their assumed income tax liabilities. These additional tax distributions may be made either (x) on a pro rata basis to all unitholders, including NFE, or (y) on a non-pro rata basis to unitholders other than NFE in redemption of a number of NFI LLC Units from each such unitholder with a value equivalent to the amount of the additional tax distribution to such unitholder.

The amount of such additional tax distributions will be determined based on certain assumptions, including assumed income tax rates, and will be calculated after taking into account other distributions (including other tax distributions) made by NFI. To the extent additional tax distributions are made pro rata based on ownership, additional tax distributions may significantly exceed the actual tax liability for many of the holders of NFI LLC Units, including NFE. If NFE retains the excess cash it receives from such distributions, the holders of NFI LLC Units would benefit from any value attributable to such accumulated cash balances as a result of their exercise of the Redemption Right. However, we intend to take steps to eliminate any material excess cash balances, which could include, but is not necessarily limited to, a distribution of the excess cash to holders of our Class A shares or the reinvestment of such cash in NFI for additional NFI LLC Units.

In addition, regardless of whether such additional tax distributions are made pro rata or in redemption of NFI LLC Units, the tax distributions that NFI may be required to make may be substantial. In addition, the amount of any additional tax distributions NFI is required to make likely will exceed the tax liabilities that would be owed by a corporate taxpayer similarly situated to NFI. Funds used by NFI to satisfy its obligation to make tax distributions will not be available for reinvestment in our business, except to the extent additional tax distributions are made on a pro rata basis and NFE uses any excess cash it receives to reinvest in NFI for additional NFI LLC Units.

If NFI were to become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes, significant tax inefficiencies might result.

We intend to operate such that NFI does not become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes. A “publicly traded partnership” is a partnership the interests of which are traded on an established securities market or are readily tradable on a secondary market or the substantial equivalent thereof. Under certain circumstances, redemptions of NFI LLC Units pursuant to the Redemption Right (or our Call Right) or other transfers of NFI LLC Units could cause NFI to be treated as a publicly traded partnership. Applicable U.S. Treasury regulations provide for certain safe harbors from treatment as a publicly traded partnership, and we intend to operate such that redemptions or other transfers of NFI LLC Units qualify for one or more such safe harbors. For example, we intend to limit the number of unitholders of NFI, and the NFI LLC Agreement, which will be entered into in connection with the closing of this offering, will provide for limitations on the ability of unitholders of NFI to transfer their NFI LLC Units and will provide us, as managing member of NFI, with the right to impose restrictions (in addition to those already in place) on the ability of unitholders of NFI to redeem their NFI LLC Units pursuant to the Redemption Right to the extent we believe it is necessary to ensure that NFI will continue to be treated as a partnership for U.S. federal income tax purposes.

If NFI were to become a publicly traded partnership, significant tax inefficiencies might result for us and for NFI, including as a result of our inability to file a consolidated U.S. federal income tax return with NFI.

USE OF PROCEEDS

We expect the estimated net proceeds from this offering to be approximately $       million, before offering expenses and after deducting underwriting discounts and commissions, based on an assumed initial public offering price of $       per Class A share (the mid-point of the price range set forth on the cover of this prospectus). If the underwriters exercise their option to purchase additional Class A shares in full, we expect the estimated net proceeds to be approximately $       million. See “Underwriting (Conflicts of Interest).”

We will contribute the net proceeds of this offering to NFI in exchange for NFI’s issuance to us of NFI LLC Units. NFI intends to use the net proceeds from this offering in the following manner: (i) $    million to complete the construction of the Old Harbour Terminal, (ii) $    million to complete the construction of the Pennsylvania Facilities, (iii) $    million to complete the construction of the CHP Plant, (iv) $    million to complete the construction of the La Paz Terminal, (v) $    million to complete the construction of the San Juan Facility, (vi) $    million to complete the construction of the Ireland Terminal and (vii) $    million for general company purposes, including the development of future projects. If the underwriters exercise their option to purchase additional Class A shares in full, the additional net proceeds will be approximately $       million (based on an assumed initial offering price of $       per Class A share, the mid-point of the price range set forth on the cover page of this prospectus). The net proceeds from any exercise of such option will be contributed to NFI in exchange for NFI’s issuance to us of NFI LLC Units. After the application of the net proceeds from this offering, we will own a       % membership interest in NFI (or a       % membership interest if the underwriters’ option to purchase additional Class A shares is exercised in full). Please read “Security Ownership of Certain Beneficial Owners and Management.” For a description of our Terminals and Liquefaction Facilities, see “Business.”

Pending any use, the net proceeds of this offering may be invested in short-term, interest-bearing investment-grade securities.

Assuming no exercise of the underwriters’ option to purchase additional Class A shares, a $1.00 increase (decrease) in the assumed initial public offering price of $       per Class A share would increase (decrease) the net proceeds from this offering received by us, after deducting the underwriting discounts and commissions and estimated offering expenses, by approximately $       million, assuming the number of Class A shares offered by us, as set forth on the cover page of this prospectus, remains the same.

CAPITALIZATION

The following table sets forth our cash and cash equivalents and our capitalization as of December 31, 2017:

The as adjusted information set forth in the table below is illustrative only and will be adjusted based on the actual initial public offering price and other terms of this offering determined at pricing. You should read this table in conjunction with “Summary—Formation Transactions and Structure,” “Use of Proceeds,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our consolidated financial statements and related notes contained elsewhere in this prospectus.

DILUTION

Dilution is the amount by which the offering price per Class A share in this offering will exceed the pro forma net tangible book value per share after the offering. On a pro forma basis as of             , 2018, after giving effect to the offering of Class A shares and the Transactions, our net tangible book value was approximately $       million, or $       per Class A share. Purchasers of Class A shares in this offering will experience substantial and immediate dilution in pro forma net tangible book value per Class A share for financial accounting purposes, as illustrated in the following table.

The following table sets forth the number of Class A and Class B shares that we will issue and the total consideration contributed to us by New Fortress Energy Holdings and by the purchasers of Class A shares calculated before deducting estimated underwriting discounts and commissions and estimated offering expenses payable by us (in millions, except per share amounts):

DIVIDEND POLICY

We do not anticipate declaring or paying any cash dividends to holders of our Class A shares in the foreseeable future. We currently intend to retain future earnings, if any, to finance the expansion of our business. Our future dividend policy is within the discretion of our board of directors and will depend upon then-existing conditions, including our results of operations and financial condition, capital requirements, business prospects, statutory and contractual restrictions on our ability to pay dividends, including restrictions contained in our debt agreements, and other factors our board of directors may deem relevant.

SELECTED HISTORICAL FINANCIAL DATA

NFE was formed on August 6, 2018 and does not have historical financial results. NFE currently has no assets or liabilities and has conducted no operations. The following table shows selected historical financial information of New Fortress Energy Holdings, our predecessor, for the periods and as of the dates indicated. The selected historical financial data as of and for the years ended December 31, 2017 and 2016 was derived from the audited historical consolidated financial statements of New Fortress Energy Holdings included elsewhere in this prospectus.

You should read the information set forth below together with “Use of Proceeds,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and our consolidated financial statements and related notes included elsewhere in this prospectus. The historical financial results are not necessarily indicative of results to be expected for any future periods.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS

Certain information contained in this discussion and analysis or set forth elsewhere in this prospectus or accompanying marketing material, including information with respect to our plans, strategy, projections and expected timeline for our business and related financing, includes forward-looking statements that involve risks and uncertainties. Forward-looking statements contained in this prospectus are estimates based upon current information and involve a number of risks and uncertainties. Actual events or results may differ materially from the results anticipated in these forward-looking statements as a result of a variety of factors.

You should read “Risk Factors” and “Forward-Looking Statements” elsewhere in this prospectus for a discussion of important factors that could cause actual results to differ materially from the results described in or implied by the forward-looking statements contained in the following discussion and analysis.

The following information should be read in conjunction with our consolidated financial statements and accompanying notes included elsewhere in this prospectus, as well as the information presented under “Selected Historical Financial Data.” Our financial statements have been prepared in accordance with GAAP. This information is intended to provide investors with an understanding of our past performance and our current financial condition and is not necessarily indicative of our future performance. Please refer to “—Factors Impacting Comparability of Our Financal Results” for further discussion. Unless otherwise indicated, dollar amounts are presented in thousands.

Unless the context otherwise requires, references to “Company,” “NFE,” “we,” “our,” “us” or like terms refer to NFE Financial Holdings LLC and its subsidiaries. When used in a historical context, “Company,” “we,” “our,” “us,” or like terms refer to New Fortress Energy Holdings LLC, a Delaware limited liability company (“New Fortress Energy Holdings”), our predecessor for financial reporting purposes.

Overview

We are engaged in providing energy and logistical services to end users worldwide seeking to convert their operating assets from diesel or heavy fuel oil (“HFO”) to LNG. The Company currently has liquefaction and regasification operations in the United States and Jamaica. We currently source LNG from a combination of our own liquefaction facility in Miami, Florida and purchases on the open market. We are developing the infrastructure necessary to supply all of our existing and future customers with LNG produced primarily at our own facilities. We expect that control of our vertical supply chain, from liquefaction to delivery of LNG, will help to reduce our exposure to LNG price variations and enable us to supply our existing and future customers with LNG at a price that reflects production at our own facilities, reinforcing our competitive standing in the LNG market. Our strategy is simple: we seek to manufacture our own LNG at attractive prices, using fixed-price feedstock, and we seek to sell natural gas (delivered through LNG infrastructure) or gas-fired power to customers that sign long-term, take-or-pay contracts.

Our Current Operations

Our management team has successfully employed our strategy to secure long-term, take-or-pay contracts with Jamaica Public Service Company Limited (“JPS”), the sole public utility in Jamaica, South Jamaica Power Company Limited (“JPC”), an affiliate of JPS, and Jamalco, a joint venture between General Alumina Jamaica LLC (“GAJ”), a subsidiary of Noble Group, and Clarendon Alumina Production Limited (“CAP”), an entity owned by the Government of Jamaica, with a focus on bauxite mining and alumina production in Jamaica (“Jamalco”), each of which is described in more detail below. Certain assets built to service JPS have, and the assets built to service JPC and Jamalco will have, capacity to service other customers. We currently procure our LNG either by purchasing it under a multi-cargo contract from a supplier or by manufacturing it in our natural gas liquefaction, storage and production facility located in Miami-Dade County, Florida (the “Miami Facility”). In the future, we intend to develop the infrastructure necessary to supply our existing and future customers with LNG produced primarily at our own facilities, including our expanded delivery logistics chain in Northern Pennsylvania (the “Pennsylvania Facilities”).

Montego Bay Terminal

Our storage and regasification terminal in Montego Bay, Jamaica (the “Montego Bay Terminal”) serves as our supply hub for the north side of Jamaica, providing gas to JPS to fuel the 145MW turbines at the Bogue Power Plant in Montego Bay, Jamaica (the “Bogue Power Plant”). The Montego Bay Terminal commenced

commercial operations on October 30, 2016 and stores approximately two million gallons of LNG in seven storage tanks. The Montego Bay Terminal also consists of an ISO loading facility that can transport LNG to all of our industrial and manufacturing (“small-scale”) sales across the island. The small-scale business provides these users with an alternative fuel to support their business operations and limit reliance on monopolistic utilities.

Miami Facility

Our Miami Facility began operation in April 2016. We believe, based on available data, it is the first privately owned natural gas liquefaction plant in Florida. This facility enables us to produce LNG for our customers and reduces our dependence on other suppliers for LNG. The facility is the first plant to successfully export domestically produced LNG from the lower 48 states to a non-free trade agreement country and it employs one of the largest ISO container fleets in the world. The Miami Facility provides LNG to small-scale customers in south Florida including Florida East Coast Railway via our train loading facility and other customers throughout the Caribbean using ISO containers.

Results of Operations

Revenues

For the year ended December 31, 2017, the Miami Facility available to produce LNG over 95.5% of the time. We have executed three contracts in 2016, three contracts in 2017 and one contract year-to-date in 2018 to provide customers with LNG from our Miami Facility. We continue to build our small-scale pipeline of customers and are in advanced dialogues with various domestic and international customers across the utility, power, industrial and transportation sectors to execute additional long-term purchase contracts.

During the year ended December 31, 2017, the Montego Bay Terminal was available over 98.5% of the time. We have also generated revenue from our small-scale customers by supplying LNG directly to industrial end-users in Jamaica.

Operating revenue from LNG and natural gas sales for the year ended December 31, 2017 was $82,104 which increased by $63,489 from $18,615 for the year ended December 31, 2016. The increase in revenue was attributable to twelve months of operations at the Miami Facility and Montego Bay Terminal during the year ended December 31, 2017 whereas the Miami Facility and Montego Bay Terminal were operating for eight and two months, respectively, during the year ended December 31, 2016.

The Company leases certain facilities and equipment, including the Montego Bay Terminal, to its customers which are accounted for as direct financing leases. We currently generate a majority of other revenue from interest recognized from these direct financing leases. Other revenue for the year ended December 31, 2017 was $15,158 which increased $12,378 from $2,780 for the year-ended December 31, 2016. The increase is attributable to twelve months of operations at the Montego Bay Terminal during the year ended December 31, 2017 whereas the Montego Bay Terminal operated for two months in 2016.

Cost of sales

Cost of sales includes the procurement of feedgas or LNG as applicable, shipping and logistics costs to deliver LNG to our facilities and regasification and terminal operating expenses to provide product to our customers. Our LNG and natural gas supply are purchased from third parties or converted in our liquefaction facilities. Costs to convert natural gas to LNG, including labor and other direct costs to operate our liquefaction facility are also included in Cost of sales. Cost of sales for the year ended December 31, 2017 was $78,692 which increased $55,945 from $22,747 for the year ended December 31, 2016. The increase in Cost of Sales was attributable to twelve months of operations at the Miami Facility and Montego Bay Terminal for the year ended December 31, 2017, whereas the Miami Facility and Montego Bay Terminal were operating for eight and two months, respectively, for the year ended December 30, 2016.

Operations and maintenance

Operations and maintenance relates to costs of operating our Miami Facility exclusive of conversion costs reflected in Cost of sales. Operations and maintenance for the year ended December 31, 2017 was $7,456 which increased $2,251 from $5,205 for the year-ended December 31, 2016. The increase is primarily a result of the Miami Facility operating for twelve months in 2017 in comparison to operating for eight months in 2016.

Selling, general and administrative

Selling, general and administrative includes employee travel costs, insurance, and costs associated with development activities for projects that are in initial stages and development is not yet probable. Selling, general and administrative also includes compensation expenses for our corporate employees, including our executives, as well as professional fees for our advisors. Selling, general and administrative for the year ended December 31, 2017 was $33,343 which increased $15,183 from $18,160 for the year-ended December 31, 2016 primarily as a result of increased development activities and employee travel as well as increased headcount.

Depreciation and amortization

Depreciation and amortization for the year ended December 31, 2017 was $2,761 which increased $420 from $2,341 for the year ended December 31, 2016. The increase is primarily a result of twelve months of operations at the Miami Facility and the purchase of additional equipment and vehicles which were placed into service during 2017.

Interest expense

Interest expense for the year ended December 31, 2017 was $6,456, which increased $1,351 from $5,105 for the year ended December 31, 2016, primarily as a result of interest on the MoBay Loan (as defined below) of $3,611 and $643 and Miami Loan (as defined below) of $2,845 and $1,803 for the years ended December 31, 2017 and December 31, 2016, respectively, net of capitalized interest recognized during construction in the year ended December 31, 2016. During 2017, we raised equity capital, which funded a majority of our capital expenditures resulting in a decrease in capitalized interest compared to December 31, 2016. The increase in interest expense is partially offset by the reduction of interest expense on the Corporate Loan which was repaid at maturity in June 2016.

Other income, net

Other income, net for the year ended December 31, 2017 was $301 which increased $248 from $53 for the year-ended December 31, 2016, primarily as a result of an increase in interest income and realized foreign currency gain.

Loss on extinguishment of debt

Loss on extinguishment of debt for the year ended December 31, 2016 was $1,177, which was recognized as a result of the extinguishment of the Corporate Loan on June 3, 2016.

Tax provision (benefit)

Tax provision (benefit) for the year ended December 31, 2017 was $526, which increased $887 from ($361) for the year ended December 31, 2016 due to a decrease in net taxable losses in foreign jurisdiction when comparing 2017 to 2016.

Factors Impacting Comparability of Our Financial Results

Our historical results of operations and cash flows are not indicative of results of operations and cash flows to be expected in the future, principally for the following reasons:

In addition, we currently purchase the majority of our supply of LNG from third parties. For the year ended December 31, 2017, our first full year of commercial operations, we sourced 94.1% of our LNG volumes from third parties. NFE is in the process of developing in-basin liquefaction facilities that will vertically integrate our supply and eliminate the need to source LNG from third parties; this, combined with lower cost production, should significantly impact our results of operations and cash flows from both contracted and expected downstream sales.

Liquidity and Capital Resources

We believe we will have sufficient liquidity, cash flow from operations and access to additional capital sources to fund our capital expenditures and working capital needs for the next twelve months. We expect to fund our current operations and continued development of additional facilities through a combination of cash on hand, additional debt and the proceeds from this offering. We expect to make significant capital expenditures to build out our Terminals and Liquefaction Facilities. We have assumed total expenditures for all completed and existing projects to be approximately $500,000, with approximately $285,000 having already been spent through September 30, 2018. This estimate represents the complete construction of projects in Jamaica and Miami. We are currently exploring opportunities to expand our business into new markets, including the Caribbean, Mexico and we will require significant additional capital to implement our strategy.

Cash Flows

The following table summarizes the changes to our cash flows for the years ended December 31:

Cash (used in) operating activities

Our cash flow used in operating activities was $54,892 in 2017, which increased by $11,399 from $43,493 in 2016. For both the year ended December 2017 and 2016, we had net loss that comprised a significant portion of cash used in operating activities due to the continued expansion of our operations in Jamaica. A significant portion of cash used in operations for the year ended December 31, 2017 was attributed to an increase in deposits attributed to a prepayment for LNG supply.

Cash (used in) investing activities

Our cash flow used in investing activities was $52,396 in 2017, which decreased by $51,644 from $104,040 in 2016. The decrease in cash flow used in investing activities is due to significant cash expenditures incurred in 2016 as the Company completed construction of its Miami Facility and its Montego Bay Terminal. The decrease was offset by construction that began in 2017 on JPC’s Old Harbour Power Plant in Old Harbour, Jamaica (the “Old Harbour Power Plant”) resulting in approximately $28,500 in capital expenditures. The decrease was also partially offset by a restriction of $15,000 as collateral posted for performance under a gas sales agreement with a customer, and $7,000 of collateral posted with LNG suppliers for an upcoming delivery.

Cash provided by financing activities

Our cash flow provided by financing activities was $11,346 in 2017, which decreased by $266,353 from $277,699 in 2016. The decrease in cash flow provided by financing activities is due to the Company issuing Class A shares in June 2016 in exchange for $300,505. The Company also received additional borrowings under the MoBay Loan of $44,000. The receipt of debt and equity capital in 2016 was offset by the repayment of Corporate Loan of $65,000. In December 2017, the Company undertook an additional capital raise of $70,100 of which $20,100 of cash was received during the year and the remainder in January 2018. This capital contribution was offset by principal payments on the Miami Loan and the MoBay Loan of $5,828.

Long-Term Debt

Montego Bay Loan Agreement

In June 2016, NFE North Holdings Limited (“NFE North”), a wholly owned subsidiary of the Company entered into a syndicated loan agreement (the “MoBay Loan Agreement”) providing for a $44,000 term loan facility (the “MoBay Loan”) in connection with the construction and development of the Montego Bay Terminal and related infrastructure. The maturity date for each loan drawn under the MoBay Loan is the day immediately preceding the seventh anniversary of the drawdown date of such loan.

Outstanding amounts under the MoBay Loan accrue interest at a per annum rate of 8.10%. During the continuance of any uncured event of default by the borrower, interest will instead accrue at a per annum rate of 14.10%, subject to any applicable grace period. The MoBay Loan is required to be repaid in advance of the maturity date in consecutive, equal monthly payments, with the remaining outstanding amount due on the maturity date. The MoBay Loan may be prepaid at any time, upon 30 days’ prior written notice to the agent, subject to a prepayment fee of 2% of any amount being prepaid for prepayments during the one year period from the date of the first loan drawdown of the MoBay Loan, or 1% of any amount being prepaid for prepayments during the period commencing one year from the date of the first loan drawdown of the MoBay Loan and expiring on the fifth anniversary of such date. Prepayments made after the fifth anniversary of the date of the

first loan drawdown of the MoBay Loan are not subject to any prepayment fee. Prepayment of 100% of the outstanding principal amount of the MoBay Loan, and any accrued and unpaid interest thereon, is required to be made, by notice from the agent acting on the direction of the majority lenders, upon the event of any change of control or a merger (as defined in the MoBay Loan Agreement and does not include an IPO or similar liquidity event) of NFE North that is not consented to by the lenders or any material adverse change (as defined in the MoBay Loan Agreement).

The borrower’s obligations under the MoBay Loan Agreement are guaranteed by Atlantic Energy Holdings Limited (Barbados), our subsidiary and parent company of NFE North and is secured by the LNG Terminal in Montego Bay, Jamaica. The MoBay Loan Agreement contains customary representations and warranties, positive and negative covenants, including certain financial covenants, and such negative covenants include, among other things, restrictions on security interests and additional indebtedness, restrictions on sales or disposals of assets, and restrictions on capital expenditures.

Under the terms of the MoBay Loan, NFE North is required to maintain a Debt Service Reserve Account (the “DSR Account”) in an amount equivalent to principal and interest due in the next six months. During the years ended December 31, 2017 and 2016, $2,615 and $1,812, respectively, was deposited in the DSR Account and is included as a component of restricted cash on the Company’s consolidated balance sheet.

During the construction period of certain projects in 2016, related interest expense and borrowings costs were capitalized. Interest expense, inclusive of amortized debt fees for the years ended December 31, 2017 and 2016, totaled $3,611 and $1,990, respectively, of which $0 and $1,347, respectively, was capitalized as a finance lease.

Financial covenants stipulated by the MoBay Loan Agreement were not effective until December 31, 2017. As of December 31, 2017, NFE North was in compliance with all covenants under this agreement.

The Company used the net proceeds of the Term Loan Facility entered into in August 2018 to repay the MoBay Loan in full in September 2018.

Miami Loan Agreement

In November 2014, LNG Holdings (Florida) LLC (“LHFL”), a controlled subsidiary, entered into a Credit Agreement (the “Miami Loan”) with a bank for an initial aggregate amount of $40,000, maturing on May 24, 2018, in connection with the construction of the Miami Facility. Borrowings under the loan bear interest at a rate selected by LHFL of either (i) a LIBOR based rate, with a floor of 1.00%, plus a spread of 5.00%, or (ii) subject to a floor of 2%, a Base Rate equal to the higher of (a) the Prime Rate, (b) the Federal Funds Rate plus ½ of 1% or (c) the 1-month LIBOR rate plus the difference between the applicable LIBOR margin and Base Rate margin, plus a spread of 4.00%. Subject to certain conditions, the Miami Loan can be extended for an additional term of up to 18 months. If the Miami Loan is extended past the original maturity date, the spread on LIBOR and Base Rate increases to 5.50% and 4.50%, respectively. The Miami Loan also requires unused commitment fees of 1.25% per annum on undrawn amounts. The Miami Loan is secured by all of the assets of LHFL, which consists primarily of the Miami Facility.

On May 16, 2018, the Company extended the maturity to November 2019. To execute the extension option, the Company paid an extension fee of $388, equating to 1% of the outstanding principal at that time.

The Miami Loan requires periodic payments of interest on either a monthly, quarterly or semi-annual basis where LHFL selected the monthly interest rate option. In addition, with respect to LIBOR based borrowings, LHFL, at its option, may elect to defer up to ten interest periods outstanding at any point in time. The Miami Loan also requires annual amortization in an amount equal to 1% of the amount outstanding. The Miami Loan can be prepaid without penalty after the first anniversary of the closing of the Miami Loan. At December 31, 2017 and 2016, interest was calculated on the borrowing based on a 3-month LIBOR rate (1% floor) plus a spread of 5%, bearing a total interest rate of 6.57% and 6.00%, respectively. Interest expense, inclusive of amortized debt fees for the years ended December 31, 2017 and 2016, totaled $2,845 and $2,740 respectively, of which $0 and $937 was capitalized.

Under the terms of the Miami Loan, LHFL is required to maintain the DSR Account in the amount of $912. Such amount is included as a component of restricted cash on the Company’s consolidated balance sheet (see Note 6 of the Notes to the Consolidated Financial Statements).

As of December 31, 2017 and 2016, LHFL was in compliance with all of the covenants under this agreement.

The Company used the net proceeds of the Term Loan Facility entered into in August 2018 to repay the Miami Loan in full in August 2018.

Term Loan Facility

On August 16, 2018, the Company entered into a Term Loan Facility (the “Term Loan Facility”) to borrow term loans, available in three draws, up to an aggregate principal amount of $240,000. Borrowings under the Term Loan Facility bear interest at a rate selected by the Company of either (i) a LIBOR based rate, plus a spread of 4.0%, or (ii) subject to a floor of 1%, a Base Rate equal to the higher of (a) the Prime Rate, (b) the Federal Funds Rate plus ¹∕2 of 1% or (c) the 1-month LIBOR rate plus the difference between the applicable LIBOR margin and Base Rate margin, plus a spread of 3.0%. The Term Loan Facility is set to mature on August 14, 2019 and is repayable in quarterly installments of $600, with a balloon payment due on the maturity date. The Company has the option to extend the maturity date for two additional six month periods; upon the exercise of each extension option, the spread on LIBOR and Base Rate increases by 0.5%. To exercise the extension option, the Company must pay a fee equal to 1.0% of the outstanding principal balance at the time of the exercise of the option.

The Term Loan Facility is secured by mortgages on certain properties owned by the Company’s subsidiaries, in addition to other collateral. The Company is required to comply with certain financial covenants and other restrictive covenants customary for facilities of this type, including restrictions on indebtedness, liens, acquisitions and investments, restricted payments and dispositions. The Term Loan Facility also provides for customary events of default, prepayment and cure provisions.

The Term Loan Facility funded $130,000 less fees at closing. The remaining capacity of $110,000 under the Term Loan Facility is subject to a delayed draw feature, resulting in $40,000 funded at the payoff of the Miami Loan and then the remainder funded in September 2018 at the payoff of the Mobay Loan.

The Company used the net proceeds of the Term Loan Facility to repay the Miami Loan in full during August 2018. The Company used the net proceeds of the Term Loan Facility to repay the Mobay Loan in September 2018. The remaining proceeds will be used for general corporate purposes, including capital expenditures and future construction projects under development.

Off Balance Sheet Arrangements

As of December 31, 2017, other than operating leases and certain contractual obligations for the purchase of LNG and natural gas, we had no transactions that met the definition of off-balance sheet arrangements that may have a current or future material effect on our consolidated financial position or operating results.

Contractual Obligations

We are committed to make cash payments in the future pursuant to certain of our contracts. The following table summarizes certain contractual obligations in place as of December 31, 2017:

Long-Term debt obligations

For information on our long-term debt obligations, see “—Liquidity and Capital Resources—Long-Term Debt.” The amounts included in the table above are based on the total debt balance, scheduled maturities and interest rates in effect at December 31, 2017. On May 16, 2018, the Company extended the maturity of the Miami Loan to November 2019; this extension of principal payments and the corresponding interest costs has been reflected in the table above.

The Company used proceeds from the Term Loan Facility to repay both the Miami Loan and the MoBay Loan in accordance with their respective terms; these repayments have not not been reflected in the table above. The Company has borrowed $240,000 under the Term Loan Facility with a scheduled maturity of August 14, 2019. Principal payments of $600 are due each quarter; the Company will be required to pay $600 in principal payments in 2018 and the remaining principal balance of $239,400 in 2019. Based on the interest rate of 6.08% in effect as of the closing of the Term Loan Facility, the Company is committed to pay $5,477 in interest payments in 2018 and $9,034 in interest payments prior to the maturity date in 2019.

Purchase obligations

The Company is party to contractual purchase commitments with terms of 38 months and 60 months, principally take-or-pay contracts, which require the purchase of minimum quantities of natural gas. These commitments are designed to assure sources of supply and are not expected to be in excess of normal requirements.

On December 20, 2016, the Company committed to the purchase of at least 16,800,000 MMBtu or ~756,000 cubic meters of LNG, with half of the commitment delivered in 2017 and half in 2018.

In addition to the above disclosed commitments, in September 2016 the Company made a commitment of up to an estimated $180,000 to build a gas-fired combined heat and power plant in Jamaica under a Joint Development Agreement with a third party prior to commercial agreements being finalized. In August and October 2017 respectively, a Power Purchase Agreement and Steam Supply Agreement were executed, obligating the Company to complete the development subject to the conditions set forth in those agreements.

In March 2018, the Company entered into a 15 year agreement with a large production company for gas supply to our first Pennsylvania Facility, which was subsequently amended and restated in September 2018. This agreement provides for 100% of the required supply of feedgas to the facility, inclusive of all support functions of the plant, including transportation and power supply. The terms of the agreement require the Company to obtain all requisite permits and make a final investment decision before the agreement is effective.

Lease obligations

Future minimum lease payments under non-cancellable operating leases are noted in the above table. The Company’s lease obligations are primarily related to LNG vessel time charters, office space, a land site lease, and a marine port berth lease. Office space includes a newly fabricated space shared with affiliated companies in New York with a month to month lease, and an office space under construction in downtown Miami, with a lease term of 84 months. The land site lease is held with an affiliate of the Company and has an initial term up to five years, and the marine port berth lease had an initial term up to 10 years. Both leases contain renewal options.

The Company entered into several lease agreements during 2018 in Mexico and Puerto Rico. Such agreements include securing certain facilities, wharf areas, office space and specified port areas for development of terminals. Terms for these leases range from 20 to 30 years, and certain of these leases contain extension terms. One-time fees paid subsequent to December 31, 2017 to secure leases were $19,000. Fixed lease payments under these leases are expected to be approximately $1,200 and some of these leases contain variable components based on LNG processed. The Company has also restricted funds of approximately $2,200 as collateral for these leases.

Summary of Critical Accounting Estimates

The preparation of consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the consolidated financial statements and the accompanying notes. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates. Management evaluates its estimates and related assumptions regularly, and will continue to do so as we further launch and grow our business. We believe that the accounting policies discussed below are critical to understanding our historical and future performance, as these policies relate to the more significant areas involving management’s judgments and estimates.

Revenue recognition

Operating revenue from the sales of LNG and natural gas are recognized when the LNG or natural gas is delivered to the customer, either when the natural gas arrives at the customer’s flange or at the time that title to

the LNG is transferred to the customer. Title typically transfers either when shipped or delivered to the customers’ storage facilities, depending on the terms of the contract.

The Company leases certain facilities and equipment to its customers which are accounted for as direct financing leases. Direct financing leases, net on our consolidated balance sheet represents the minimum lease payments due, net of unearned revenue. The lease payments are segregated into principal and interest components similar to a loan. Unearned revenue is recognized on an effective interest method over the lease term and is recorded within Other revenue in the consolidated statement of operations and comprehensive loss. The principal components of the lease payment is reflected as a reduction to the net investment in the finance lease.

The Company’s contracts with customers to supply LNG may also contain a lease of equipment. The Company allocates consideration received from customers between lease and non-lease components based on the relative fair value of each component. The fair value of the lease component is estimated based on the cost of the leased items plus an expected profit margin. The estimated fair value of the non-lease component is based on estimated volumes to be delivered at an estimated price or contractual price. The estimated fair value of the leased equipment, as a percentage of the estimated total revenue from LNG and leased equipment at inception, will establish the allocation percentage to determine the minimum lease payments and the amount to be accounted for under the revenue recognition guidance.

Impairment

LNG liquefaction facilities, and other long-lived assets held and used by the Company are reviewed periodically for potential impairment whenever events or changes in circumstances indicate that a particular assets’ carrying value may not be recoverable. Recoverability generally is determined by comparing the carrying value for the asset to the expected undiscounted future cash flows of the asset. If the carrying value of the asset is not recoverable, the amount of impairment loss is measured as the excess, if any, of the carrying value of the asset over its estimated fair value. The estimated undiscounted future cash flows are based on projections of future operating results; these projections contain estimates of the value of future contracts that have not yet been obtained, future commodity pricing, our future cost structure, among others. Projections of future operating results and cash flows may vary significantly from actual results. Management reviews its estimates of cash flows on an ongoing basis using historical experience, business plans, overall market conditions, and other factors.

JOBS Act

In April 2012, the Jumpstart Our Business Startups Act of 2012, or the JOBS Act, was enacted. Section 107 of the JOBS Act provides that an “emerging growth company,” or EGC, can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act of 1933, as amended, or the Securities Act, for complying with new or revised accounting standards. Thus, an EGC can delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. We intend to take advantage of the exemptions discussed above. Accordingly, the information contained herein may be different than the information you receive from other public companies.

We are in the process of evaluating the benefits of relying on other exemptions and reduced reporting requirements under the JOBS Act. Subject to certain conditions, as an EGC, we intend to rely on certain of these exemptions, including without limitation, (1) providing an auditor’s attestation report on our system of internal controls over financial reporting pursuant to Section 404(b) of the Sarbanes-Oxley Act and (2) complying with any requirement that may be adopted by the Public Company Accounting Oversight Board, or PCAOB, regarding mandatory audit firm rotation or a supplement to the auditor’s report providing additional information about the audit and the financial statements, known as the auditor discussion and analysis. We will remain an EGC until the earlier of (i) the last day of the fiscal year in which we have total annual gross revenues of $1.07 billion or more; (ii) the last day of the fiscal year following the fifth anniversary of the date of the completion of this offering; (iii) the date on which we have issued more than $1.00 billion in nonconvertible debt during the previous three years; or (iv) the date on which we are deemed to be a large accelerated filer under the rules of the Securities and Exchange Commission or SEC.

Recent Account Standards

For descriptions of recently issued accounting standards, see Note 3 - Adoption of new and revised standards of our Notes to Consolidated Financial Statements.

Quantitative And Qualitative Disclosures About Market Risk

In the normal course of business, the Company encounters several significant types of market risks including commodity and interest rate risks.

Commodity Price Risk

Commodity price risk is the risk of loss arising from adverse changes in market rates and prices. We are able to limit our exposure to fluctuations in natural gas prices as our pricing in contracts with customers is based on the Henry Hub index price plus a contractual spread. Our exposure to market risk associated with LNG price changes may adversely impact our business. We do not currently have any derivative arrangements to protect against fluctuations in commodity prices, but to mitigate the effect of fluctuations in LNG prices on our operations, we may enter into various derivative instruments.

Interest Rate Risk

Debt that we incurred under the Miami Loan and the Term Loan Facility bore interest at variable rates and exposed us to interest rate risk. We repaid the Miami Loan with proceeds received from the Term Loan Facility. Interest is calculated under the terms of the Term Loan Facility based on our selection, from time to time, of one of the index rates available to us plus an applicable margin that varies based on certain factors. See “—Liquidity and Capital Resources—Long-Term Debt.” Assuming the full $240,000 principal amount remains outstanding, the impact on interest expense of a 1% increase or decrease in the interest rate that was in place upon closing of the Term Loan Facility would be approximately $2,400 per year. We do not currently have or intend to enter into any derivative arrangements to protect against fluctuations in interest rates applicable to our outstanding indebtedness.

Foreign Currency Exchange Risk

We primarily conduct our operations in U.S. dollars, and as such, our results of operations and cash flows have not materially been impacted by fluctuations due to changes in foreign currency exchange rates. We expect our international operations to continue to grow in the near term. We do not currently have any derivative arrangements to protect against fluctuations in foreign exchange rates, but to mitigate the effect of fluctuations in exchange rates on our operations, we may enter into various derivative instruments.

BUSINESS

Overview

We are an integrated gas-to-power company that seeks to use “stranded” natural gas to satisfy the world’s large and growing power needs. Our mission is to provide modern infrastructure solutions to create cleaner, reliable energy while generating a positive economic impact worldwide. Our business model is simple, yet, we believe, unique for the LNG industry. We aim to deliver targeted energy solutions to customers around the world, thereby reducing their energy costs and diversifying their energy resources, while also reducing pollution and generating compelling margins.

We aim to deliver targeted energy solutions by employing a four-part integrated LNG production and delivery model:

Liquefaction – Our approach is to enter into long-term, largely fixed-price contracts for feedgas, then liquefy that gas at or proximate to its site of extraction, minimizing transport and pipeline costs for the feedgas producers. We are currently developing two liquefiers in the Marcellus area of Pennsylvania, each of which is expected to have the capacity to produce approximately 3 to 4 million gallons of LNG (which is the equivalent of 250,000 to 350,000 MMBtu) per day, and intend to develop five or more additional liquefiers over the next five years.

Logistics – We expect to own or control the logistics assets necessary to deliver LNG to our customers through our “logistics pipeline.” Tanker trucks will transport LNG from our liquefiers to a port on the Delaware river for Marcellus sourced LNG or the Gulf of Mexico for Mid-Continent sourced LNG, at which point LNG will be transloaded directly to large marine vessels.

Shipping – We have long-term charters for both large-scale FSUs and FSRUs, and smaller LNGCs. These assets transport LNG from ports to our downstream terminals for ultimate delivery to our customers. There is approximately a five day sail time from port to our downstream terminals in the Caribbean.

Terminals – Through our network of current and planned downstream terminals, we will be positioned to deliver gas and power solutions to our customers seeking either to transition from environmentally dirtier distillate fuels such as ADO and HFO or to purchase natural gas to meet their current fuel needs. Our goal is to build 10 - 20 downstream terminals over the next five years.

We believe this compelling business model will provide opportunities to generate average revenues of approximately $10.00 per MMBtu, including both fuel sales and capacity charges (we often invest capital in infrastructure in connection with our entry into a new market, and customers agree to pay a “capacity charge” as consideration for the right to use the underlying infrastructure). We expect individual contract pricing is likely to range between $8.00 and $13.00 per MMBtu, depending on the customer’s size, purchased volume, credit profile, the complexity of the delivery and the infrastructure required to deliver it.

NFE’s Global Market Landscape

We believe that the world is “long” gas and “short” power, and that natural gas is a compelling fuel for power production. But because much of the world’s natural gas reserves are not directly connected by pipeline to electricity producers and other end users, it must be otherwise transported. An efficient way to transport is through the conversion of natural gas to LNG, which involves treating natural gas to remove impurities and then chilling it to approximately negative 260 degrees Fahrenheit, a process generally referred to as liquefaction. In LNG form, natural gas is typically transported in bulk by containers or tankers hauled by rail or truck or by marine vessels, such as LNG carriers. Once delivered to its end destination, LNG can be reconverted to natural gas through a process referred to as “regasification.”

Today approximately 70% of the world’s electricity is consumed by 10 countries and over a billion people, or approximately 14% of the world’s population, currently lack access to electricity, according to the International Energy Agency’s October 2017 report. As economic development worldwide spurs demand for electricity, approximately 1.5 million MW of new power is expected to be needed by 2040, according to Exxon Mobil’s 2017 Outlook on Energy. To satisfy these power needs with gas-fired power would require approximately 3.75 billion gallons of LNG (or 310 TBtu) per day (based upon an estimated conversion of 2,500 gallons per day of LNG for every MW of power capacity) and an additional 347 mtpa of liquefaction

capacity. Further, we believe that many countries around the world – keenly focused on economics as well as the environment – will increasingly look to natural gas to displace environmentally dirtier fuels such as HFO, ADO and coal that are used to generate power, particularly if natural gas is cheaper than these environmentally dirtier fuels. For example, most islands in the Caribbean generate 90% to 100% of their electricity from HFO or ADO, as compared to less than 1% of electricity generation in the United States. We believe there is a significant market opportunity.

Liquefaction projects currently under construction are expected to come online by 2020. Afterward, LNG supply growth is expected to slow through 2025. According to the Shell 2018 LNG Outlook Report, from 2020 through 2025, LNG supply estimates are almost half that of demand expectations. By 2025, this equates to an addressable LNG market with 450 mtpa (approximately 740 million gallons per day) of demand, which management estimates to represent a global market value of approximately $212 billion per annum. Based on this report, by 2025, we expect the shortfall in supply to be approximately 200 mtpa versus current operating plants and 100 mtpa versus projects under construction. This shortfall is the equivalent of approximately 50 to 100 liquefiers of similar capacity to one of our liquefiers in Pennsylvania.

We plan to capitalize on this growing supply-demand gap and create new markets for natural gas by developing liquefaction assets, particularly in areas with significant “stranded” reserves, which we define as natural gas reserves not connected to large interstate or transnational pipelines. That is, not only are these reserves not connected by pipeline to end users, they are not connected to any significant pipeline – as is the case in Pennsylvania.

Our Business Model

As an integrated gas-to-power LNG company, our business model spans the entire production and delivery chain from natural gas procurement and liquefaction to logistics, shipping, terminals and conversion or development of natural gas-fired generation. While historically, liquefaction, transportation, regasification and power generation have been financed separately, the segregation of such projects has inhibited the development of natural gas-fired power in many developing countries. In executing this business model, we have the capability to build or arrange any necessary infrastructure ourselves without reliance on multilateral financing sources or traditional project finance structures, so that we maintain our strategic flexibility.

Our goal is to purchase gas, liquefy it, and transport it to one of our Terminals at a cost of approximately $4.20 per MMBtu or less (before owner’s costs such as marketing and administrative costs, financing costs and contingencies). We expect our downstream transportation, shipping and regasification costs to approximate $1.50 per MMBtu, which is consistent with the costs of our current operations. Our goal is to sell substantially all of this gas to downstream customers under long-term contracts at targeted pricing in excess of approximately $10.00 per MMBtu, including both fuel sales and capacity charges. Gas not delivered to downstream customers would be sold on the spot market. Currently, the market price for LNG delivered via LNGC is approximately $8.00 to $12.00 per MMBtu, depending on the size cargoes purchased. For contracted delivery, assuming the costs and sales prices described above, we seek to earn a margin of $4.30 per MMBtu, or $0.36 per gallon, which would equal a margin of 40% or more, on our gas sales. For spot sales, we seek to earn an attractive margin by adjusting our sales price based on current market rates. Our operations, which are currently conducted at our Montego Bay Terminal and at our Miami Facility, are currently generating revenue on sales of approximately 400,000 gallons of LNG (33,000 MMBtu) per day. We have contracts, letters of intent or expect to secure contracts in the near term to sell LNG volumes in excess of 8.3 million gallons (685,000 MMBtu) per day, which includes approximately 1.1 million gallons per day that are currently contracted. We are in active discussions with additional customers who may have significant demand for additional LNG, although there can be no assurance that these discussions will result in additional contracts or the terms of such contracts.

Our Terminals

Downstream, we have five terminals operational or under development. Our Terminals will position us to access customers in a number of attractive markets around the world.

We look to build terminals in locations where the need for LNG is significant. In these markets, we first seek to identify and establish “beachhead” target markets for the sale of LNG, natural gas or natural gas-fired power. We then seek to convert and supply natural gas to additional power customers. Finally, our goal is to expand within the market by supplying additional industrial and transportation customers.

We currently have two operational terminals and three under development, as described below. We design and construct terminals to meet the supply and demand specifications of our current and potential future customers in the applicable region. Our Terminals currently operating or under development are expected to be capable of receiving between 700,000 and 6 million LNG gallons (58,000 and 500,000 MMBtu) per day depending upon the needs of our customers and potential demand in the region. Set forth below is additional detail regarding each terminal:

Montego Bay, Jamaica – Our Montego Bay Terminal commenced commercial operations in October 2016. The terminal is capable of processing up to 740,000 LNG gallons (61,000 MMBtu) per day and features approximately 7,000 cubic meters of onsite storage. It supplies natural gas to 145MW turbines at the power plant operated by JPS pursuant to a long-term take-or-pay contract for natural gas equivalent to approximately 300,000 gallons of LNG (25,000 MMBtu) per day. The Montego Bay Terminal also supplies several on-island industrial users with natural gas or LNG pursuant to other long-term take-or-pay contracts. We have total aggregate contracted volumes of approximately 378,000 gallons of LNG (32,000 MMBtu) per day at our Montego Bay Terminal with an average contract length of 17.8 years. Our Montego Bay Terminal is currently operating at 36% capacity to service JPS and these other industrial users. We have the ability to service other potential customers with the excess capacity of the Montego Bay Terminal, and we are seeking to enter into long-term contracts with new customers for such purposes. We deliver LNG to the Montego Bay Terminal via small LNGC.

Old Harbour, Jamaica – Our Old Harbour Terminal is substantially complete and expected to commence commercial operations in the first quarter 2019. It is capable of processing approximately 6 million gallons of LNG (500,000 MMBtu) per day. The Old Harbour Terminal is expected to supply gas to the Old Harbour Power Plant operated JPC pursuant to a long-term take-or-pay contract for natural gas equivalent to approximately 350,000 gallons of LNG (29,000 MMBtu) per day. We also expect the Old Harbour Terminal to supply gas to a new 94MW power plant that we are constructing, and, subject to agreement on terms, approximately 269,000 gallons of LNG (22,000 MMBtu) per day to the alumina refinery operated by Jamalco, an entity owned by the government of Jamaica with a focus on bauxite mining and alumina production in Jamaica. We have total aggregate contracted volumes of approximately 619,000 gallons of LNG (51,200 MMBtu) per day at our Old Harbour Terminal with an average contract length of 14.4 years. We expect that our Old Harbour Terminal will operate at 16% capacity to service JPC and Jamalco. We will have the ability to service other potential customers with the excess capacity of the Old Harbour Terminal, and we are seeking to enter into long-term contracts with new customers for such purposes. The Old Harbour Terminal is an offshore terminal with storage and regasification equipment via FSRU. The offshore design eliminates the need for expensive storage tanks and permanent, onshore infrastructure.

San Juan, Puerto Rico – Our San Juan Facility is currently under development and is expected to commence commercial operations in the second quarter 2019. It is designed as a landed multi-fuel handling facility located in the Port of San Juan, Puerto Rico. The San Juan Facility is being constructed with multiple truck loading bays to provide LNG to on-island industrial users. In addition, we have submitted a proposal to PREPA to convert and supply natural gas to Units 5 and 6 of the San Juan Combined Cycle Power Plant – which have a capacity of 440MW. The power plant is currently running on diesel, and we plan to convert the power plant to run on natural gas and provide approximately 25 TBtu of natural gas per year, which would equal approximately 850,000 gallons of LNG (70,000 MMBtu) per day. We expect the conversion to natural gas under our proposal would allow PREPA to realize significant, recurring annual cost savings of approximately $250 million (based on current diesel pricing and information provided in PREPA’s request for proposals) after one time conversion costs while also using a more sustainable, environmentally friendly form of energy.

La Paz, Baja California Sur, Mexico – Our La Paz Terminal is currently under development and is expected to commence commercial operations in October 2019. It is being designed as an LNG receiving terminal located at the Port of Pichilingue in Baja California Sur, Mexico, where LNG will be delivered via a small LNGC vessel or barge. Initially, the La Paz Terminal is expected to supply approximately 225,000 gallons of LNG (18,000 MMBtu) per day under an intercompany GSA for a 94MW gas-fired mobile power unit that we plan to develop,

own, and operate. Similarly, we expect that we will use the La Paz Terminal infrastructure, which includes truckloading bays, to facilitate the conversion of, and supply approximately 180,000 gallons of LNG (15,000 MMBtu) per day to the 80MW Los Cabos power plant, as well as regional industrial users such as ferries and hotels.

Shannon, Ireland – Our Ireland Terminal is currently under development and is expected to commence commercial operations in the fourth quarter 2020. We intend this terminal to include a floating storage facility with onshore regasification equipment and pipeline connection into the distribution system of Gas Networks Ireland, Ireland’s national gas network. We plan to deliver LNG to the terminal via a traditional size LNGC and offloaded into the FSU moored at the dock. The equipment on site will have the capacity to import and regasify more than 6 million gallons of LNG (500,000 MMBtu) per day, which is the equivalent of Ireland’s total foreign natural gas imports. Additionally, the planning permission approval for the terminal includes the ability to build an integrated 500MW power plant on-site with priority dispatch.

Our Liquefaction Assets

We intend to supply all existing and future customers with LNG produced primarily at our own Liquefaction Facilities. We have one operational liquefaction facility in Miami, are currently developing our Pennsylvania Facilities and plan to develop five or more additional liquefaction facilities over the next five years.

We believe that, by building smaller and optimizing efficiencies, we will be able to construct our Liquefaction Facilities significantly faster and more economically than those typically developed in the industry. We expect to construct each liquefaction facility for a total cost (including ancillary logistics infrastructure) of between $750 to $850 million, which implies an anticipated cost of LNG production of approximately $374 per ton. There can be no assurance development costs will not exceed our targets. If we achieve these cost targets, this is considerably more cost-effective than the industry’s published liquefaction costs, which range from $511 to $867 per ton excluding ancillary infrastructure. Each of our Liquefaction Facilities is anticipated to produce between 3-4 million gallons of LNG (250,000 – 330,000 MMBtu) per day, or between 1.75 – 2.5 mtpa of LNG.

We constructed the Miami Facility, which commenced commercial operations in 2016, in under 12 months at a cost to build of approximately $70 million. The Miami Facility employs what we believe is one of the largest private ISO container fleets in the world. It has one liquefaction train, with liquefaction production capacity of approximately 100,000 gallons of LNG (8,200 MMBtu) per day and was 95.5% dispatchable during 2017. The facility also has three LNG storage tanks, with total capacity of approximately 270,000 gallons (22,000 MMBtu). The plant also includes two separate LNG transfer areas capable of serving both truck and rail. We are currently delivering approximately 31,000 gallons of LNG per day from the Miami Facility pursuant to long-term, take-or-pay contracts.

We are in advanced stages of the design, development and permitting for our first Pennsylvania Facility, and we expect it to be substantially complete in the fourth quarter of 2020. We expect our first Pennsylvania Facility to have the capacity to liquefy 3-4 million gallons of LNG (250,000 – 330,000 MMBtu) per day. We have already entered into a 15-year contract to acquire all of the feedgas needed to operate our first Pennsylvania Facility at capacity, with pricing that is generally fixed at $2.50 per MMBtu. Once LNG is produced at this facility, a dedicated tanker truck fleet will transport the LNG to a nearby port. We are currently developing plans with a suitable port approximately 195 miles away along the Delaware river, and we expect to finalize a long-term contract prior to the completion of this offering. Under these plans, we expect that LNG will be transferred directly from tanker truck to marine vessel through multiple transloading bays, allowing for simultaneous and continuous operations. From there, our dedicated fleet of marine vessels will be able to transport the LNG to our Terminals and then on to our customers. We are also in the process of developing our second Pennsylvania Facility and expect to begin commercial operations in the third quarter of 2021.

Pending completion and commissioning of our liquefiers in development, we expect to continue to supply our downstream customers with LNG and natural gas sourced from a combination of our Miami Facility, which operated at 28% capacity during the first half of 2018, and purchases of LNG on the open market. We are drawing on our experience from the construction and operation of our Miami Facility to optimize the development of our Pennsylvania Facilities.

Our Current Customers

Our downstream customers are, and we expect future customers to be, a mix of power, transportation and industrial users of natural gas and LNG. We seek to substantially reduce our customers’ fuel costs while providing them with a cleaner-burning, more environmentally friendly fuel source. In addition, we also intend to sell power and steam directly to some of our customers.

We seek to enter into long-term, take-or-pay contracts to deliver natural gas or LNG, which generally include targeted pricing of approximately $10.00 per MMBtu. Pricing for any particular customer depends on the size of the customer, purchased volume, the customer’s credit profile, the complexity of the delivery and the infrastructure required to deliver it, and there can be no assurance we will achieve our targeted pricing. In general, the better the credit and larger the size of the user, the lower the contract price of our fuel.

To date, we have contracts, letters of intent or expect to secure contracts in the near term to sell LNG volumes in excess of 8.3 million gallons (685,000 MMBtu) per day, which includes approximately 1.1 million gallons per day currently contracted with a weight average remaining term of 14.3 years. Our operations, which are currently conducted primarily at our Montego Bay Terminal and at our Miami Facility, are currently generating revenue from sales of approximately 400,000 gallons (33,000 MMBtu) per day. Our ambition is to continue to aggressively grow this customer portfolio. We are in active discussions with additional customers who may have significant demand for additional LNG.

Our Jamaica Customers

We have several contracts with government affiliated entities in Jamaica, including contracts with JPS, JPC and Jamalco (the “Jamaica GSAs”) as further described below. The Jamaica GSAs represent 50% of Jamaica’s installed capacity and sales of approximately 919,000 gallons (76,000 MMBtu) of LNG per day. The Jamaica GSAs have remaining terms of at least 20 years, with mutual options to extend, subject to certain conditions.

We refer to the structure of our contracts as “take-or-pay” because they include a firm obligation to take a fixed quantity of product at a stated price and provisions that ensure we will be made whole in the case of our customer’s failure to accept all or a part of the contracted volumes or for termination by our customer. Pricing under these contracts generally consists of a fixed fee plus a variable rate, and, in some cases, an additional index price or volume discount. Our contracts also provide for annual inflation-based adjustments and reimbursement for government charges incurred. The aggregate minimum quantities we are required to deliver, and our counterparties are required to purchase, under the Jamaica GSAs initially total approximately 39,973 MMBtu per day.

Bogue Power Plant

We have executed a 22-year agreement to supply JPS’s Bogue Power Plant in Montego Bay, Jamaica with natural gas. The Bogue Power Plant is an approximately 211MW capacity power plant converted to run on natural gas as well as ADO. We believe the Bogue Power Plant is a compelling example of the power of our business strategy.

The plant was originally constructed to burn natural gas, but, because the plant could not procure sufficient amounts of natural gas, the plant has burned ADO in recent years. We provide a comprehensive solution for JPS to use natural gas to power turbines with 145MW power generation capacity at the Bogue Power Plant at prices that are economically attractive compared to ADO in exchange for JPS entering into a long-term, take-or-pay supply agreement with us. Under the terms of the agreement, we ship LNG to Jamaica, regasify it and ultimately deliver natural gas to the Bogue Power Plant. We constructed the Montego Bay Terminal that commenced commercial operations on October 30, 2016. The Montego Bay Terminal has the capacity to store approximately two million gallons of LNG in seven storage tanks. The facility has regasification equipment and a pipeline capable of transporting sufficient natural gas to support approximately up to 250MW of generation capacity.

Old Harbour Power Plant

We have also executed an agreement to supply JPC’s Old Harbour Power Plant in Old Harbour, Jamaica with natural gas and back-up ADO for 20 years. The Old Harbour Power Plant will be an approximately 190MW capacity dual fuel plant owned by JPC.

Similar to our agreement with JPS regarding the Bogue Power Plant, we provide a comprehensive solution to JPC to use natural gas at the Old Harbour Power Plant at prices that are economically attractive relative to distillate fuel alternatives in exchange for JPC entering into a long-term, take-or-pay supply agreement with us. Under the terms of the agreement, we will ship LNG to Jamaica, regasify it and ultimately deliver natural gas to the Old Harbour Power Plant with ADO available as a back-up supply when natural gas is not available. Development has begun at the Old Harbour Terminal and is expected to be completed in the second half of 2018. Upon completion, the Old Harbour Terminal is expected to have the capacity to store up to 33 million gallons of LNG in a floating marine storage unit. The facility will have regasification equipment and a pipeline capable of transporting natural gas to the Old Harbour Power Plant to support approximately 400MW of generation capacity. We have secured binding EPC contracts for substantially all of the projected budget for the Old Harbour Terminal, and construction began in August 2017. We have also secured back-up ADO fuel supply under a contract with Petrojam.

Jamalco Combined Heat & Power Plant

We have also executed a suite of agreements, including a 20 year SSA to supply Jamalco with steam for use in its alumina refinery operations and a 20 year PPA to supply electricity to JPS, to support our development of the CHP Plant. The CHP Plant will be a 94MW capacity power plant and will be fueled by natural gas with the ability to run on diesel as a backup fuel source. We will ship LNG to Jamaica, regasify it at the Old Harbour Terminal and deliver it to the CHP Plant, which will be owned by our wholly owned subsidiary NFE South Power. We have obtained a power generation license for the CHP Plant and we expect construction to be completed by the first quarter of 2020.

Jamaica Industrial End-User Sales

We have entered into multiple long-term contracts to sell LNG directly to industrial end-users in Jamaica. To fulfill the requirements of our end-user customers, we transport LNG through our Jamaica Terminals (either from our Liquefaction Facilities in the United States or from third parties in market purchases) and deliver such LNG directly to customers.

For example, we have entered into a 10-year agreement to supply Red Stripe with LNG to power its brewery operations through Red Stripe’s own CHP facility located on-site at its brewery in Kingston, Jamaica. We constructed the necessary LNG storage and regasification infrastructure “behind the fence” at Red Stripe’s factory in less than three months, and natural-gas powered operations commenced on October 6, 2017. Red Stripe estimates that its conversion to natural gas will save it at least $336,000 per year (not including conversion costs). The agreement with Red Stripe is the first of what we aim to be many such arrangements to supply LNG directly to industrial end-users in Jamaica and elsewhere utilizing our end-to-end, fully integrated LNG supply network.

Other Contracts

In September 2018, we amended and restated our GSA with an affiliate of Chesapeake Energy Corporation (“Chesapeake”) to provide for the delivery of natural gas to our Pennsylvania Facilities. Deliveries will commence once the first Pennsylvania Facility has completed commissioning and testing and is capable of receiving the minimum volume of gas. The initial contract term is 15 years and we will purchase gas from Chesapeake at a price equal to a fixed fee plus a variable rate, subject to a minimum volume.

Growth Opportunities and Track Record

As the world continues to electrify and demand for power grows, we believe that countries will continue to look to natural gas as a viable, efficient, cost-effective and more environmentally friendly fuel. With a potential 3.75 billion LNG-gallon-per-day addressable market created by the approximately 1.5 million MW of new power expected to be needed by 2040, according to Exxon Mobil’s 2017 Outlook on Energy, we see multiple opportunities for our business to grow.

Proven Ability to Execute. We are confident in our ability to execute and scale our business model to support our expected growth because we have a successful track record of infrastructure project development. We developed, constructed and commissioned our Miami Facility, a 100,000 gallon-per-day (8,300 MMBtu) liquefier in Miami-Dade County, Florida, in under 12 months. This liquefier includes two truckloading bays capable of

loading LNG tank trucks at 200 gallons-per-minute per truck, and through which we currently service our South Florida customers. We also ship ISO tankers by rail to Port Everglades for shipment to customers in the Bahamas and Barbados. We followed our Miami Facility by designing, permitting, constructing and commissioning our Montego Bay Terminal in under 14 months. This terminal is equipped with 7,000 cubic meters (2 million gallons) of on-land storage, has a direct pipeline connection to JPS’s 145MW turbines at the Bogue Power Plant, and has two truckloading bays for deliveries to on-island customers. We also expect to commission our Old Harbour Terminal starting in December 2018. Construction is complete, and we expect our chartered FSRU to arrive in the fourth quarter 2018. When operational, the Old Harbour Terminal will service a new 190MW power plant operated by JPC and a new 94MW plant that we have begun constructing at Jamalco. These projects demonstrate our proven ability to design, construct and commission large and complex infrastructure projects on accelerated timeframes and encompassing a broad range of operations – liquefaction, logistics, onshore terminals, offshore terminals, pipeline connections, marine assets and integrated power generation assets.

Growth Opportunity — Africa. In Sub-Saharan Africa, 590 million people, or 57% of the population, lack access to electricity. As a result, power generation on the continent is anticipated to more than double to 253GW by 2030. Natural gas consumption is expected to grow by nearly 150% over this timeframe, outpacing nearly every other fuel. We recognize the immense opportunity that Africa affords and are opening our first office in Ghana in late 2018. We have engaged with multiple local counterparties, and we anticipate deploying meaningful capital in African projects in the future.

Business Strategies

Our primary business objective is to provide superior returns to our shareholders as a vertically integrated energy infrastructure company. We intend to accomplish this objective by implementing the following strategies:

develop and optimize our Caribbean infrastructure to provide natural gas, LNG, steam or electricity in readily usable form directly to our customers in Jamaica and other places in the Caribbean, such as Puerto Rico. Beyond these prospects, we intend to selectively identify and market our services to energy customers who view natural gas or LNG as a compelling alternative to other fuel sources that will allow us to further expand our footprint.

Competitive Strengths

We believe we are well positioned to achieve our primary business objectives and execute our business strategies based on the following competitive strengths:

Competition

In marketing LNG and natural gas, we compete for sales of LNG and natural gas with a variety of competitors, including: major integrated marketers who have large amounts of capital to support their marketing operations and offer a full-range of services and market numerous products other than natural gas; producer

marketers who sell their own natural gas production or the production of an affiliated natural gas production company; small geographically focused marketers who focus on marketing natural gas for the geographic area in which their affiliated distributor operates; and aggregators who gather small volumes of natural gas from various sources, combine them and sell the larger volumes for more favorable prices and terms than would be possible selling the smaller volumes separately.

However, we do not expect to experience significant competition for our LNG logistics services with respect to the Jamaica Terminals because we have entered into fixed GSAs with JPS and JPC for the Jamaica Terminals. If and when we have to replace our agreements with JPS or JPC, we may compete with other then-existing LNG logistics companies for these customers.

There are no other liquefaction terminals currently in operation in south Florida. However, a number of plants are currently under development in the region that could compete with our Miami Facility.

In purchasing LNG as part of our logistics business, we will compete for supplies of LNG with:

Government Regulation

Our LNG infrastructure is and operations are subject to extensive regulation under federal, state and local statutes, rules, regulations and laws, as well as foreign regulations and laws. These laws require, among other things, consultations with appropriate federal, state and other agencies and that we obtain, maintain and comply with applicable permits, approvals and other authorizations for the siting and conduct of our business. These regulatory requirements increase our costs of operations and construction, and failure to comply with such laws could result in consequences such as substantial penalties and/or the issuance of administrative orders to cease or restrict operations until we are in compliance.

DOE Export

The DOE issued orders authorizing us, through our subsidiary, American LNG Marketing or its designee, to export up to a combined total of the equivalent of 60,000 mtpa (approximately 3.02 Bcf/yr) of domestically produced LNG by tanker from the Miami Facility to FTA countries for a 20-year term and to non-FTA countries for a 20-year term under contracts with terms of two years or longer. The 20-year term of the authorizations commenced on February 5, 2016, the date of first export from the Miami Facility. The DOE has also authorized American LNG Marketing to export LNG from the Miami Facility to FTA and non-FTA countries under short-term (less than two years) agreements or on a spot cargo basis. Any LNG exported under the short-term authorization would be counted toward the quantity authorized under the long-term authorizations. These authorizations from the DOE are only applicable to exports of LNG produced at our Miami Facility, and exports of LNG from a liquefaction facility other than the Miami Facility (such as the Pennsylvania Facilities) to FTA and/or non-FTA countries will require us to obtain new authorizations from the DOE.

Exports of natural gas to FTA countries are “deemed to be consistent with the public interest” and authorization to export LNG to FTA countries shall be granted by the DOE without “modification or delay.” FTA countries which import LNG now or will do so in the near future include Chile, Mexico, Singapore, South Korea and the Dominican Republic. Exports of natural gas to non-FTA countries are considered by the DOE in the context of a comment period whereby interveners are provided the opportunity to assert that such authorization would not be consistent with the public interest.

Pipelines and Hazardous Materials Safety Administration

Many LNG facilities are also subject to regulation by the DOT, through the PHMSA; PHMSA has established requirements relating to the design, installation, testing, construction, operation, replacement and management of “pipeline facilities,” which PHMSA has defined to include LNG facilities that liquefy, store,

transfer, or vaporize natural gas transported by pipeline in interstate or foreign commerce. PHMSA has promulgated detailed, comprehensive regulations governing LNG facilities under its jurisdiction at Title 49, Part 193 of the United States Code of Federal Regulations. These regulations address LNG facility siting, design, construction, equipment, operations, maintenance, personnel qualifications and training, fire protection and security. Variances from these regulations may require obtaining a special permit from PHMSA, the issuance of which is subject to public notice and comment and consultation with other federal agencies, which could result in delays, perhaps substantial in length, to the construction of our facilities where such variances are needed; additionally, PHMSA may condition, revoke, suspend or modify the special permits it issues.

In recent years, PHMSA’s regulation of pipeline facilities has become more stringent. For example, in March 2016, the PHMSA released a comprehensive proposed rulemaking concerning gas pipeline safety that, if adopted, would, among other things, regulate many currently-unregulated gathering lines in rural areas, expand the integrity management requirements beyond “High Consequence Areas” to apply to gas pipelines in newly-defined “Moderate Consequence Areas,” and require pressure testing of many formerly-grandfathered pipelines in place before 1970 to determine their maximum allowable operating pressures. In January 2017, PHMSA issued a pre-publication version of a final rule that amends its pipeline safety regulations for the design, construction, testing, operation and maintenance of hazardous liquids pipelines. Although the Trump Administration has not yet taken any action to finalize these proposed rules, they remain pending. Similar to these efforts, PHMSA’s regulation of LNG facilities could become more stringent in the future.

Environmental Regulation

Our LNG infrastructure and operations are subject to various international, federal, state and local laws and regulations as well as foreign laws and regulations relating to the protection of the environment, natural resources and human health. These environmental laws and regulations may require the installation of controls on emissions and structures to prevent or mitigate any potential harm to human health and the environment. These laws and regulations may also lead to substantial penalties for noncompliance and substantial liabilities for incidents arising out of the operation of our facilities. Many of these laws and regulations restrict or prohibit the types, quantities and concentration of substances that can be released into the environment and can lead to substantial civil and criminal fines and penalties for non-compliance.

Clean Air Act

Our LNG infrastructure is subject to the federal CAA and comparable state and local laws. We may be required to incur certain capital expenditures over the next several years for equipment to control air emissions as a condition to maintaining or obtaining permits and approvals. Alternatively, we may be required to restrict or limit the amount of LNG we produce or ship in order to obtain or maintain a permit. We do not believe, however, that our operations, or the construction and operations of our Liquefaction Facilities, will be materially and adversely affected by any such requirements.

In 2009, the EPA promulgated and finalized the Mandatory Greenhouse Gas Reporting Rule for multiple sections of the economy. This rule requires mandatory reporting of GHG emissions from stationary fuel combustion sources as well as all fugitive emissions throughout LNG infrastructure. From time to time, Congress has considered proposed legislation directed at reducing GHG emissions, and the EPA has defined GHG emissions thresholds for requiring certain permits for new and existing industrial sources. In addition, many states have already taken regulatory action to monitor and/or reduce emissions of GHGs, primarily through the development of GHG emission inventories or regional GHG cap and trade programs. It is not possible at this time to predict how future regulations or legislation may address GHG emissions and impact our business. However, future regulations and laws could result in increased compliance costs or additional operating restrictions and could have a material adverse effect on our business, financial position, operating results and cash flows.

Coastal Zone Management Act (“CZMA”)

LNG infrastructure may be subject to the review and requirements of the CZMA when facilities are located within the coastal zone. The CZMA is administered by the states (in Florida, via the Florida Coastal Management Program, which is coordinated by the Florida Department of Environmental Protection). This program is implemented to ensure that impacts to coastal areas are consistent with the intent of the CZMA and each state’s respective CZMA-authorized program to manage the coastal areas.

Clean Water Act

Our LNG infrastructure is also subject to the federal CWA and analogous state and local laws. The CWA imposes strict controls on the discharge of pollutants into the waters of the United States, including discharges of wastewater and storm water runoff and fill/discharges into waters of the United States. Permits must be obtained prior to discharging pollutants into state and federal waters and before constructing infrastructure that requires the dredging and filling of waters of the United States. The CWA is administered by the EPA, the U.S. Army Corps of Engineers (“USACE”) and by the states via the applicable state agency.

We are required to comply with numerous other federal, state and local environmental, health and safety laws and regulations in addition to those previously discussed. These additional laws include, for example, the Rivers and Harbors Act, the federal Resource Conservation and Recovery Act and comparable state statutes, the Endangered Species Act, the National Historic Preservation Act and the Emergency Planning and Community Right-to-Know Act.

Moreover, our current operations and future projects may be subject to additional federal permits, orders, approvals and consultations required by other federal agencies under these and other statutes, including the DOE, Advisory Council on Historic Preservation, the USACE, U.S. Department of Commerce, National Marine Fisheries Services, U.S. Department of the Interior, U.S. Fish and Wildlife Service, the EPA and U.S. Department of Homeland Security. In addition, federal permitting processes may trigger the requirements of NEPA, which requires federal agencies to evaluate major agency actions that have the potential to significantly impact the environment. State permitting regimes may require similar consultations with applicable state-level agencies and/or the preparation of a similar assessment of environmental impacts pursuant to state law.

Additional federal permits that may be required to conduct our current operations or pursue future projects include, for example, a USACE Section 404 permit under the CWA and a Section 10 of the Rivers and Harbors Act Permit, a Title V Operating Permit under the CAA, a Prevention of Significant Deterioration Permit under the CAA and, where applicable, Federal Aviation Administration determinations or approvals relating to certain ground construction activities.

Other local laws and regulations, including local zoning laws and fire protection codes, may also affect where and how we operate.

The costs of compliance with these requirements are not expected to have a material adverse effect on our business, financial condition or results of operations.

Environmental Regulation in Ireland

LNG deliveries, storage, regasification and use are extensively regulated in Ireland. Ireland regulates these operations at a national and local level through organic legislation and an array of permits. Ireland’s National Planning Board is the primary regulator for planning and construction, while the Irish Environmental Protection Agency issues industrial emissions licenses that regulate environmental and operational permitting. Safety regulation in Ireland is regulated pursuant to the Control of Major Accidents regime, which sets out various safety criteria that the LNG facility must meet. We are in the process of applying for all necessary permits to build and complete the Ireland Terminal. The issuance of many of these permits will be subject to administrative or judicial challenges, including by non-governmental groups that act on behalf of citizens. For example, in September 2018, an Irish non-governmental organization filed a judicial challenge to the extension of a planning permission associated with our Ireland Terminal, which could delay or protract the process for obtaining and implementing this permission. While we believe that the extension was properly issued, it is not clear how Ireland’s High Court will rule on such a challenge, or whether the ruling of the High Court will be subject to any further appeal.

Environmental Regulation in Mexico

Mexican law comprehensively regulates all aspects of the receipt, delivery, storage, re-vaporization of LNG as well as the generation and transmission of electricity. Various federal agencies in Mexico regulate these activities, including the Environment, Natural Resources & Fisheries Ministry and the Agency for Safety, Energy & Environment, which issues permits for all activities associated with the use of fossil fuels. State and local agencies also regulate these activities, issuing permits and authorizing the use of property for such purposes. In order to be able to obtain various permits for operations under Mexican law, the project must first complete

environmental and social impact analyses according to the requirements of Mexican law. Each such impact analysis is subject to further appeal. Mexican law allows the governmental entities and, in certain cases, individuals to pursue claims against violators of environmental laws or permits issued pursuant to such laws.

U.S. and International Maritime Regulations of LNG Vessels

IMO is the United Nations agency that provides international regulations governing shipping and international maritime trade. The requirements contained in the ISM Code promulgated by the IMO govern the shipping of our LNG cargoes and the operations of any vessels we use in our operations. Among other requirements, the ISM Code requires the party with operational control of a vessel to develop an extensive safety management system that includes, among other things, the adoption of a policy for safety and environmental protection setting forth instructions and procedures for operating its vessels safely and also describing procedures for responding to emergencies.

Vessels that transport gas, including LNG carriers, are also subject to regulation under various international programs such as the International Code for the Construction and Equipment of Ships Carrying Liquefied Gases in Bulk (the “IGC Code”) published by the IMO. The IGC Code provides a standard for the safe carriage of LNG and certain other liquid gases by prescribing the design and construction standards of vessels involved in such carriage. The completely revised and updated IGC Code entered into force on January 1, 2016, with an implementation/application date of July 1, 2016. The amendments were developed following a comprehensive five-year review and are intended to take into account the latest advances in science and technology. Compliance with the IGC Code must be evidenced by a Certificate of Fitness for the Carriage of Liquefied Gases in Bulk. MARPOL regulates air emissions through Annex VI regulations for the Prevention of Air Pollution from Ships (“Annex VI”), entered into force on May 19, 2005. Annex VI sets limits on sulfur oxide and nitrogen oxide emissions from ship exhausts, emissions of volatile compounds from cargo tanks and incineration of specific substances, and prohibits deliberate emissions of ozone depleting substances.

Additionally, more stringent emission standards apply in coastal areas designated as ECAs, such as the U.S. and Canadian coastal areas, which are designated by the Marine Environment Protection Committee. Effective August 1, 2012, certain coastal areas of North America were designated ECAs. Furthermore, as of January 1, 2014, portions of the U.S. Caribbean Sea were designated ECAs. Annex VI Regulation 14, which came into effect on January 1, 2015, set a 0.1% sulfur limit in areas of the Baltic Sea, North Sea, North America, and U.S. Caribbean Sea that are ECAs.

Amended Annex VI also establishes new tiers of stringent nitrogen oxide emissions standards for new marine engines, depending on their date of installation. The North Sea and Baltic Sea have been formally designated as ECAs for nitrogen oxides effective January 1, 2021. U.S. air emissions standards are now equivalent to these amended Annex VI requirements. Additional or new conventions, laws and regulations may be adopted that could require the installation of expensive emission control systems.

We transact with leading vessel providers in the LNG industry and look to them to ensure that each of our chartered vessels is in compliance with applicable international and in-country requirements. Nevertheless, the IMO continues to review and introduce new regulations. It is impossible to predict what additional regulations, if any, may be passed by the IMO and what effect, if any, such regulation may have on our operations.

LNG and Natural Gas Marketing Governmental Regulation

Commodity Futures Trading Commission

The Dodd-Frank Act provides for federal regulation of the OTC derivatives market and entities, such as us, that participate in that market. The regulatory regime created by the Dodd-Frank Act is designed primarily to (1) regulate certain participants in the swaps markets, including entities falling within the categories of “Swap Dealer” and “Major Swap Participant,” (2) require clearing and exchange trading of certain classes of swaps as designated by the CFTC, (3) increase swap market transparency through robust reporting and recordkeeping requirements, (4) reduce financial risks in the derivatives market by imposing margin or collateral requirements on both cleared and, in certain cases, uncleared swaps, (5) provide the CFTC with expanded authority to establish position limits on certain swaps and futures products as it finds necessary and appropriate, and (6) otherwise enhance the rulemaking and enforcement authority of the CFTC and the SEC regarding the derivatives markets. As required by the Dodd-Frank Act, the CFTC, the SEC and other regulators have been

promulgating rules and regulations implementing the regulatory provisions of the Dodd-Frank Act, although neither the CFTC nor the SEC has yet adopted or implemented all of the rules required by the Dodd-Frank Act. In addition, the CFTC and its staff regularly issue rule amendments and guidance, policy statements and letters interpreting or taking no-action positions, including time-limited no action positions, regarding the derivatives provisions of the Dodd-Frank Act and the rules of the CFTC under these provisions.

A provision of the Dodd-Frank Act requires the CFTC, in order to diminish or prevent excessive speculation in commodity markets, to adopt rules, as it finds necessary and appropriate, imposing new position limits on certain futures contracts, options contracts and economically equivalent physical commodity swaps and on OTC swaps that perform a significant price discovery function with respect to certain markets. In that regard, the CFTC has proposed position limits rules that would modify and expand the applicability of position limits on the amounts of certain core futures contracts and economically equivalent futures contracts, options contracts and swaps for or linked to certain physical commodities, including Henry Hub natural gas, that market participants may hold, subject to limited exemptions for certain bona fide hedging and other types of transactions. It is uncertain at this time whether, when and in what form the CFTC’s proposed new position limits rules may become final and effective.

Pursuant to rules adopted by the CFTC, six classes of OTC interest rate and credit default swaps must be cleared through a derivatives clearing organization and executed on an exchange or swap execution facility. The CFTC has not yet proposed to designate any other classes of swaps, including swaps relating to physical commodities, for mandatory clearing, but could do so in the future. Although we expect to qualify for the “end-user exception” from the mandatory clearing and exchange-trading requirements applicable to any swaps that we enter into to hedge our commercial risks, the mandatory clearing and exchange-trading requirements may apply to other market participants, including our counterparties (who may be registered as Swap Dealers), with respect to other swaps, and the application of such rules may change the cost and availability of the swaps that we use for hedging.

As required by provisions of the Dodd-Frank Act, the CFTC and federal banking regulators have adopted rules to require Swap Dealers and Major Swap Participants, including those that are regulated financial institutions, to collect initial and variation margin with respect to uncleared swaps from their counterparties that are financial end-users, registered Swap Dealers or Major Swap Participants. These rules do not require collection of margin from commercial end-users who qualify for the end-user exception from the mandatory clearing requirement or certain other counterparties. We expect to qualify as such a commercial end-user with respect to the swaps that we enter into to hedge our commercial risks. However, the Dodd-Frank Act’s swaps regulatory provisions and the related rules may also adversely affect our existing derivative contracts and restrict our ability to monetize such contracts, cause us to restructure certain contracts, reduce the availability of derivatives to protect against risks or to optimize assets, adversely affect our ability to execute our hedging strategies and impact the liquidity of certain swaps products, all of which could increase our business costs.

Under the Commodity Exchange Act as amended by the Dodd-Frank Act, the CFTC is directed generally to prevent manipulation, including by fraudulent or deceptive practices, in two markets: (1) physical commodities traded in interstate commerce, including physical energy and other commodities, as well as (2) financial instruments, such as futures, options and swaps. Pursuant to the Dodd-Frank Act, the CFTC has adopted additional anti-manipulation and anti-disruptive trading practices regulations that prohibit, among other things, manipulative or deceptive schemes in the physical commodities, futures, options and swaps markets. Should we violate these laws and regulations, we could be subject to a CFTC enforcement action and material penalties, possibly resulting in changes in the rates we can charge.

European Market Infrastructure Regulation

EMIR is a European Union (“EU”) regulation designed to increase the stability of the OTC derivative markets throughout the EU member states. EMIR regulates OTC derivatives, central counterparties and trade repositories and imposes requirements for certain market participants with respect to derivatives reporting, clearing and risk mitigation. In addition, certain market participants are subject to a central counterparty clearing obligation and collateral requirements. All non-cleared derivatives require risk management, including timely confirmations of transactions, portfolio reconciliation, portfolio compression (when there exist 500 or more OTC derivatives outstanding with a counterparty) and dispute resolution. In addition, standards for the imposition of margin requirements under EMIR were proposed in June 2015, under which the exchange of initial and variation

margin in respect of certain non-cleared derivatives would be required, including from non-financial counterparties that are above the EMIR clearing threshold for the class of derivatives involved. Further, for non-cleared derivatives, outstanding contracts must be marked to market value daily or marked to model where conditions necessitate. Other EMIR risk management requirements for non-cleared derivatives are being considered, but those requirements have yet to be finalized.

Under EMIR, covered entities must report all derivatives concluded and any modification or termination of a derivative to a registered or recognized trade repository within one business day of the transaction. Records related to derivatives must be retained for at least five years following termination.

Regulation on Wholesale Energy Market Integrity and Transparency

REMIT is an EU regulation that prohibits market manipulation and insider trading in European wholesale energy markets and imposes various obligations on participants in these markets. REMIT requires persons who enter into transactions, including the placing of orders to trade, in one or more wholesale energy markets in the EU to notify the applicable national regulatory authority (“NRA”) of suspected breaches and implement procedures to identify breaches. All market participants, such as us, must disclose inside information and cannot use inside information to buy or sell wholesale energy products for their own account or on behalf of a third party, directly or indirectly, induce others to buy or sell wholesale energy products based on inside information, or disclose such inside information to any other person except in the normal course of employment. Market participants must also register with the relevant NRA (the Office of Gas and Electricity Markets is the NRA in the United Kingdom) and provide a record of wholesale energy market transactions to the European Agency for the Cooperation of Energy Regulators (“ACER”) and information on capacity and utilization for production, storage, consumption or transmission.

Market participants and third parties acting on their behalf are required to report transactions in wholesale energy contracts admitted to trading at organized market places and fundamental data from the European Network of Transmission System Operators for Electricity central information transparency platforms to ACER. Additional records of transactions and fundamental data with respect to the remaining wholesale energy contracts (OTC standard and non-standard supply contracts and transportation contracts) and reportable fundamental data from transmission system operators, storage system operators and LNG system operators had to be provided to ACER as of April 7, 2016.

Markets in Financial Instruments Directive and Regulation (“MiFID II”)

MiFID II refers to an EU directive and regulation (together with supplementary delegated acts) that came into effect on January 3, 2018. Under the current regulatory regime, set out in the Markets in Financial Instruments Directive (“MiFID”), we are exempt from needing authorization of any commodity derivative trading activities. MiFID II will narrow the scope of exemptions currently available under MiFID and broaden the directive’s application to the trading of MiFID commodity derivatives that can be physically settled and are traded on an organized trading facility, in addition to those that are traded on regulated markets or multilateral trading facilities.

To the extent that we trade on our own account in MiFID commodity derivatives after MiFID II comes into force, we expect to be able to do so without requiring (i) authorization from any competent authority in the European Union or (ii) (if and when available) registration with the European Securities and Markets Authority (“ESMA”) as a third country firm by relying, if needed by the relevant licensing laws of the EU jurisdictions in which our counterparties are based, on the “ancillary activity” exemption under MiFID II on the basis that (1) such activity is ancillary to our main business, when considered on a group basis, and that main business is not the provision of investment services or market making in relation to MiFID commodity derivatives; (2) we do not apply a high-frequency algorithmic trading technique; and (3) (if required to do so) we notify the relevant competent authority on an annual basis that we are relying on this exemption and, upon request, report the basis upon which we fall within the exemption. If, however, (x) no general exemption is available to us in the relevant EU jurisdiction in which any of our counterparties are based, (y) we are unable to meet the ancillary activity exemption, and (z) no other MiFID II exemption is available to us, we will need to become either authorized by the appropriate EU competent authority or (if applicable) register with ESMA as a third country firm in order to trade on our own account in MiFID commodity derivatives. Authorization by an EU competent authority would require our compliance with a variety of prudential and conduct of business rules.

Further, if we were to become authorized under MiFID II, we would be deemed to be a financial counterparty (instead of a non-financial counterparty that is not subject to the EMIR clearing obligation) for the purpose of EMIR. This may require us to clear relevant OTC derivative contracts through a central counterparty and subject us to additional reporting obligations and risk mitigation requirements under EMIR, including collateral exchange and marking transactions either to market or to an approved model.

Irrespective of whether we are required to be authorized or registered under MiFID II we will be directly and indirectly impacted by MiFID II’s commodity derivatives position limits and position reporting requirements which include powers given to EU competent authorities to require persons to reduce their commodity derivatives positions.

Market Abuse Regulation (“MAR”)

MAR, which came into effect on July 3, 2016, updated and strengthened the previous EU market abuse framework by extending its scope to new markets and by introducing new requirements. MAR’s scope was extended to MiFID financial instruments traded on an EU multilateral trading facility and (with effect from MiFID II implementation on January 3, 2018) on an EU organized trading facility as well as other financial instruments the price or value of which depends on, or has an effect on the price or value of financial instruments. The previous EU market abuse framework applied only to financial instruments admitted to trading on formally designated EU regulated markets and their related financial instruments. Further, MAR extends the EU market abuse framework to include behavior in relation to certain EU emission allowances and to certain spot commodity contracts. MAR effectively prohibits market abuse concerning relevant EU securities, derivatives, emission allowance products and certain spot commodity markets. This includes (i) the prohibition of trading in MiFID financial instruments on the basis of inside information, (ii) the improper disclosure of inside information relating to MiFID financial instruments, emission allowances or certain spot commodity contracts and (iii) the manipulation of prices of MiFID financial instruments, certain auctioned emission allowance products and certain spot commodity contracts using a number of prohibited behaviors or techniques.

Local Partners

One of our subsidiaries, Atlantic Distribution Holdings SRL, has entered into a partnership framework agreement, dated as of August 23, 2017 (the “PFA”), with DevTech Environment Limited (“DevTech”). We have partnered with DevTech to pursue strategic investment opportunities related to energy, transportation and infrastructure projects in Jamaica with a total projected cost of development, construction or acquisition of no more than $5 million per project.

Pursuant to the terms of the PFA, when we make an investment related to services provided by DevTech, DevTech will receive 10% of the equity capital in the new investment in exchange for a capital contribution in that proportion. In addition, DevTech will receive profits interests entitling DevTech to 5% of all future distributions once the parties have received a return on the investment equal to their capital contributions.

Customers

Because of our limited operating history and stage of development, a limited number of customers currently represent a large percentage of our income. During 2017, JPS accounted for more than 10% of our revenues.

Seasonality

Activity in the Caribbean is often lower during the North Atlantic hurricane season of June through November, although following a hurricane, activity may decrease as there may be business interruptions as a result of damage or destruction to our facilities or the countries in which we operate. Due to these seasonal fluctuations, results of operations for individual quarterly periods may not be indicative of the results that may be realized on an annual basis.

Our Insurance Coverage

We maintain customary insurance coverage for our business and operations. Our domestic insurance related to property, equipment, automobile, general liability, and workers’ compensation is provided through policies customary for the business and exposures presented, subject to deductibles typical in the industry. Internationally, we also maintain insurance related to property, equipment, automobile, general liability, and the portion of workers’ compensation not covered under a governmental program and are in the process of obtaining environmental liability insurance.

We maintain risk property insurance, including windstorm and flood, related to the operation of the Miami Facility and builders risk insurance at the Montego Bay Terminal. We also maintain pollution liability insurance in the U.S. and other policies in the U.S. and outside of the U.S. customary for our industry.

Legal Proceedings

In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against us. While the amounts may be substantial, we are unable to predict with certainty the ultimate outcome of such claims and proceedings. We believe that the ultimate outcome of any matter currently pending will not materially affect our business, financial condition, liquidity or results of operations.

Our Employees

We had 147 full-time employees as of September 30, 2018.

MANAGEMENT

Management of NFE Financial Holdings LLC

Upon consummation of this offering our operating agreement will provide that our board of directors shall consist of not less than three and not more than nine directors as the board of directors may from time to time determine. Our board of directors currently consists of two directors. Our board of directors will be divided into three classes that are, as nearly as possible, of equal size. Each class of directors will be elected for a three-year term of office, but the terms are staggered so that the term of only one class of directors expires at each annual general meeting. The initial terms of the Class I, Class II and Class III directors will expire in 2020, 2021 and 2022, respectively. All officers serve at the discretion of the board of directors.

Upon consummation of this offering, we will have     directors. We expect our board of directors to determine that Messrs.         will qualify as independent directors under the corporate governance standards of NASDAQ.

Our operating agreement does not provide for cumulative voting in the election of directors, which means that the holders of a majority of our issued and outstanding voting shares can elect all of the directors standing for election, and the holders of the remaining shares will not be able to elect any directors. New Fortress Energy Holdings’ beneficial ownership of greater than 50% of our voting shares means New Fortress Energy Holdings will be able to control matters requiring shareholder approval, which includes the election of directors.

In evaluating director candidates, our board of directors will assess whether a candidate possesses the integrity, judgment, knowledge, experience, skill and expertise that are likely to enhance the board’s ability to manage and direct our affairs and business, including, when applicable, to enhance the ability of committees of the board to fulfill their duties.

Executive Officers and Directors

The following table shows information for our executive officers and directors upon the consummation of this offering. Directors hold office until their successors have been elected or qualified or until the earlier of their death, resignation, removal or disqualification. Executive officers serve at the discretion of the board. There are no family relationships among any of our directors or executive officers. Some of our directors and our executive officers also serve as executive officers of New Fortress Energy Holdings.

Wesley R. Edens— Mr. Edens has been our Chief Executive Officer and a member of our board of directors since August 2018. He is the Co-Chief Executive Officer of Fortress and has been a member of the board of directors of Fortress since November 2006. Mr. Edens has been a member of the Management Committee of Fortress since co-founding Fortress in May 1998. Fortress Equity Partners (A) LP, a private equity fund managed by an affiliate of Fortress, currently owns a substantial majority of the equity of New Fortress Energy Holdings. Mr. Edens is responsible for oversight of Fortress’ private equity and publicly traded alternative investment businesses. He is the Chairman of the board of directors of each of New Media Investment Group Inc. (a publisher of print and online media), New Senior Investment Group Inc. (a real estate investment trust with a diversified portfolio of senior housing properties located across the United States), and Drive Shack Inc. (an owner and operator of golf-related leisure and entertainment business). He is a director of Mapeley Limited (a large full service real estate outsourcing and investment company in the United Kingdom).

Mr. Edens previously served on the board of the following publicly traded companies and registered investment companies: OneMain Holdings, Inc. (a leading consumer finance company) from November 2010 to June 2018, Fortress Transportation and Infrastructure Investors LLC (which owns and acquires high quality

infrastructure and equipment essential for the transportation of goods and people globally) from May 2015 to May 2016; Intrawest Resorts Holdings Inc. (a resort and adventure company) from January 2014 to July 2017; Gaming and Leisure Properties, Inc. (an owner and operator in the gaming and racing industry) from October 2013 to October 2016; Nationstar Mortgage Holdings Inc. (a residential mortgage loan originator and servicer) from 2012 to July 2016; New Residential (a real estate investment trust primarily focused on investing in residential real estate related assets) from April 2013 to May 2016; Brookdale Senior Living Inc., from September 2005 to June 2014; GAGFAH S.A. from September 2006 to June 2014; PENN National Gaming Inc. from October 2008 to November 2013; GateHouse Media Inc. from June 2005 to November 2013; Aircastle Limited from August 2006 to August 2012; RailAmerica Inc. from November 2006 to October 2012; Eurocastle Investment Limited, from August 2003 to November 2011; Whistler Blackcomb Holdings Inc., from October 2010 to November 2012; Fortress Registered Investment Trust, from December 1999 until deregistered with the SEC in September 2011; and FRIT PINN LLC, from November 2001 until deregistered with the SEC in September 2011.

Prior to co-founding Fortress, Mr. Edens was a partner and managing director of BlackRock Financial Management Inc. (an investment management firm), where he headed BlackRock Asset Investors, a private equity fund. In addition, Mr. Edens was formerly a partner and managing director of Lehman Brothers.

Mr. Edens’ extensive credit, private equity finance and management expertise, extensive experience as an officer and director of public companies and his deep familiarity with our Company led the Board to conclude that Mr. Edens should serve as a director.

Christopher S. Guinta— Mr. Guinta has been our Chief Financial Officer since August 2018, and the Chief Financial Officer of New Fortress Energy Holdings since April 2017. Prior to joining NFE, Mr. Guinta served as Chief Financial Officer of Ranger Offshore Inc. from November 2011 to April 2017. Prior to Ranger, Mr. Guinta served as an associate at SunTx Capital Partners from April 2009 to November 2011. Before joining SunTx Capital Partners, Mr. Guinta served as an associate at Citi Capital Markets in the Investment Banking Division. Mr. Guinta graduated from The University of Texas at Austin with a Bachelor of Business Administration and a Masters in Professional Accounting.

Michael J. Utsler— Mr. Utsler has been our Chief Operating Officer since October 2018. Mr. Utsler has over 35 years of experience in the energy industry. Prior to joining us, Mr. Utsler served as Chief Operating Officer of Woodside Energy Ltd. from December 2013 to October 2018. Prior to Woodside Energy Ltd., Mr. Utsler served in various roles for BP p.l.c. (“BP”) from January 1999 to November 2013, including most recently as Chief Operating Officer and President of the BP Gulf Coast Restoration Organization from August 2010 to November 2013. Before BP, Mr. Utsler served in various roles for Amoco Corporation from 1978 to 1998. Mr. Utsler received a Bachelor of Science degree in Petroleum Engineering from The University of Oklahoma.

Randal A. Nardone— Mr. Nardone has been a member of our board of directors since August 2018. He has also been a member of the board of directors of Fortress since November 2006 and has been a member of the Management Committee of Fortress since he co-founded it in 1998. Mr. Nardone served as Fortress’s Chief Executive Officer from July 2013 through December 2017, after serving as its Interim Chief Executive Officer from December 2011 to July 2013. Mr. Nardone is a director of Eurocastle Investment Limited. Mr. Nardone also previously served on the board of directors of Alea Group Holdings (Bermuda) Ltd. from July 2007 to September 2014; GAGFAH S.A. from September 2006 to June 2014; and Brookdale Senior Living, Inc. from January 2011 to June 2014. Mr. Nardone was previously a managing director of UBS from May 1997 to May 1998. Prior to joining UBS in 1997, Mr. Nardone was a principal of BlackRock. Prior to joining BlackRock, Mr. Nardone was a partner and a member of the executive committee at the law firm of Thacher Proffitt & Wood. Mr. Nardone received a Bachelor of Arts in English and Biology from the University of Connecticut and a Juris Doctorate from Boston University School of Law. We believe that Mr. Nardone’s leadership, management experience and experience with corporate and securities law bring valuable experience to our board of directors.

C. William Griffin— Bill Griffin will become a member of our board of directors in connection with our listing on NASDAQ. Mr. Griffin has more than 45 years of experience in financial services. He currently serves as Executive Vice President, Enterprise Strategy of ServiceLink, LLC, helping deliver end-to-end solutions to large financial institutions, a position he has held since January 2017. Prior to that, Mr. Griffin served in various capacities within Fidelity National Financial, Inc. (“Fidelity”) and its affiliates, including as Executive Vice

President of Black Knight Financial Services from January 2014 to December 2016 and Executive Vice President of Sales and Marketing for Lender Processing Services from November 2011 to December 2013. He also served as President and Chief Executive Officer from 2002 to 2003 when Lender Processing Services was acquired by Fidelity. Mr. Griffin holds a Bachelor of Business Administration degree from The University of Georgia. We believe that Mr. Griffin’s leadership and extensive financial experience will bring significant value to our board of directors.

John J. Mack— John Mack will become a member of our board of directors in connection with our listing on NASDAQ. From March 2012 until his retirement in December 2014, Mr. Mack served as a Senior Advisor for Kohlberg, Kravis, Roberts & Co., L.P. Prior to that, Mr. Mack served as Chairman of the Board of Morgan Stanley, a financial services company, from June 2005 to December 2011, and served as the Chief Executive Officer of Morgan Stanley from June 2005 until December 2009, during which time he oversaw the firm’s conversion into a bank holding company. Mr. Mack was Co-Chief Executive Officer of Credit Suisse Group from 2003 to 2004 and the President, Chief Executive Officer and a director of Credit Suisse First Boston from 2001 to 2004. He became the President, Chief Operating Officer and a director of Morgan Stanley Dean Witter & Co. in May 1997 and served in that position until 2001. Mr. Mack joined Morgan Stanley in May 1972 in the bond department and served as head of the Worldwide Taxable Fixed Income Division from 1985 to 1992, became a member of the board of directors in 1987, became Chairman of the Operating Committee in March 1992 and became President in June 1993. Mr. Mack is a senior advisor to Morgan Stanley & Co. LLC and serves on the board of directors of Glencore International AG, a subsidiary of Glencore PLC, and LendingClub Corporation. Mr. Mack holds a Bachelor of Arts degree in history from Duke University. Mr. Mack was chosen to serve on our board of directors because of his extensive experience advising and managing banking and financial services companies. We believe that Mr. Mack’s strong business leadership experience brings important insight and skills to our board of directors.

Matthew Wilkinson— Matthew Wilkinson will become a member of our board of directors in connection with our listing on NASDAQ. Mr. Wilkinson currently serves as a director at ICG Advisors. Prior to that, Mr. Wilkinson served as vice president of strategy for Kayne Anderson Capital Advisors from January 2017 to March 2018. Prior to joining Kayne Anderson Capital Advisors, Mr. Wilkinson was with the State of Michigan Retirement Systems (“SMRS”) from July 2011 to January 2017, most recently serving as a senior portfolio manager in the short-term, absolute return and real return division from September 2014 to January 2017, where he built out and managed a real assets portfolio with $2 billion in commitments and a special situations portfolio with over $800 million in commitments for SMRS. Prior to SMRS, he founded and operated his own investment firm primarily focused on investing in small cap equities. Mr. Wilkinson holds an M.B.A. from Michigan State University and a B.A. (magna cum laude) from Ohio State University. We believe that Mr. Wilkinson’s leadership, management experience and strong background in corporate finance, bring important and valuable skills to our board of directors.

Status as a Controlled Company

Because New Fortress Energy Holdings will initially hold approximately    % of the voting power of our shares following the completion of this offering, we expect to be a controlled company as of the completion of the offering under the Sarbanes-Oxley Act and NASDAQ corporate governance standards. A controlled company does not need its board of directors to have a majority of independent directors or to form independent compensation and nominating and governance committees. Although we are not required to do so, we will establish independent compensation and nominating and governance committees upon completion of this offering. As a controlled company, we will remain subject to the rules of the Sarbanes-Oxley Act and NASDAQ that require us to have an audit committee composed entirely of independent directors. Under these rules, we must have at least one independent director on our audit committee by the date our Class A shares are listed on NASDAQ, at least two independent directors on our audit committee within 90 days of the listing date, and at least three independent directors on our audit committee within one year of the listing date.

If at any time we cease to be a controlled company, we will take all action necessary to comply with the Sarbanes-Oxley Act and NASDAQ corporate governance standards, including by appointing a majority of independent directors to our board of directors, subject to a permitted “phase-in” period.

Director Independence

The Board is in the process of reviewing the independence of our directors using the independence standards of NASDAQ and the SEC.

Committees of the Board of Directors

Audit Committee

We are required to have an audit committee of at least three members, and all of its members are required to meet the independence and experience standards established by NASDAQ and the Securities Exchange Act of 1934, as amended, subject to certain transitional relief during the one-year period following consummation of this offering as described above. We will establish an audit committee compliant with NASDAQ and SEC rules prior to the completion of this offering and expect       will serve as members of such committee. SEC rules also require that a public company disclose whether or not its audit committee has an “audit committee financial expert” as a member.        will satisfy the definition of “audit committee financial expert.” We expect to adopt an audit committee charter defining the committee’s primary duties in a manner consistent with the rules of the SEC and NASDAQ standards.

The audit committee will assist the board of directors in its oversight of the integrity of our financial statements and our compliance with legal and regulatory requirements and company policies and controls. The audit committee will have the sole authority to (1) retain and terminate our independent registered public accounting firm, (2) approve all auditing services and related fees and the terms thereof performed by our independent registered public accounting firm, and (3) pre-approve any non-audit services and tax services to be rendered by our independent registered public accounting firm. The audit committee will also be responsible for confirming the independence and objectivity of our independent registered public accounting firm. Our independent registered public accounting firm will be given unrestricted access to the audit committee and our management.

Compensation Committee

We will establish a compensation committee compliant with NASDAQ and SEC rules prior to the completion of this offering and expect       will serve as members of such committee. This committee will establish salaries, incentives and other forms of compensation for officers and other employees. The compensation committee will also administer our incentive compensation and benefit plans. We expect to adopt a compensation committee charter defining the committee’s primary duties in a manner consistent with the rules of the SEC and NASDAQ or market standards.

Nominating and Corporate Governance Committee

We will establish a nominating and corporate governance committee compliant with NASDAQ and SEC rules prior to the completion of this offering and expect       will serve as members of such committee. This committee will identify, evaluate and recommend qualified nominees to serve on our board of directors, develop and oversee our internal corporate governance processes and maintain a management succession plan. We expect to adopt a nominating and corporate governance committee charter defining the committee’s primary duties in a manner consistent with the rules of the SEC and NASDAQ or market standards.

Advisory Committee Regarding Our Communities & The Environment

We recognize that billions of people around the planet lack access to affordable power. We seek to provide the capital, expertise and vision to address this problem while also making a positive impact on the communities in which we operate and the environment. Upon the consummation of this offering, we intend to establish an advisory committee (the “Advisory Committee”) to assist the board of directors in providing a meaningful and positive impact in the areas where we conduct our business. We intend to collaborate with the Advisory Committee to help improve the quality of life and increase advancement opportunities for members of the communities in which we operate. While our product is more environmentally friendly than many traditional distillate fuels, we recognize that our business has an environmental impact. As such, we intend to collaborate with the Advisory Committee to reduce any environmental impact we may have and help contribute to preserving our environment.

Compensation Committee Interlocks and Insider Participation

None of our executive officers serve on the board of directors or compensation committee of a company that has an executive officer that serves on our board of directors or compensation committee. No member of our board of directors is an executive officer of a company in which one of our executive officers serves as a member of the board of directors or compensation committee of that company.

Code of Business Conduct and Ethics

Prior to the completion of this offering, our board of directors will adopt a code of business conduct and ethics applicable to our employees, directors and officers, in accordance with applicable U.S. federal securities laws and the corporate governance rules of NASDAQ. Any waiver of this code may be made only by our board of directors and will be promptly disclosed as required by applicable U.S. federal securities laws and the corporate governance rules of NASDAQ.

EXECUTIVE COMPENSATION

As an “emerging growth company,” we are required to provide a Summary Compensation Table and an Outstanding Equity Awards at Fiscal Year End Table, as well as limited narrative disclosures regarding executive compensation for our last completed fiscal year.

We were formed on August 6, 2018 and, as a result, did not have executive officers during 2017. However, because (1) all of the assets and operations of New Fortress Energy Holdings (our predecessor for financial reporting purposes) will be contributed to NFI (which will be our subsidiary) in connection with this offering and such assets and operations will constitute our only assets and operations and (2) one of our executive officers was also an executive officer of New Fortress Energy Holdings and provided the same type of services to New Fortress Energy Holdings in 2017 as they provide to us, we have included disclosure regarding compensation paid to the executive officers of New Fortress Energy Holdings for the 2017 fiscal year. The only individuals serving as officers of New Fortress Energy Holdings during 2017 were Christopher Guinta and Christopher Carey.

Christopher Carey resigned from his position as Chief Financial Officer of New Fortress Energy Holdings effective February 10, 2017. Christopher Guinta was appointed as Chief Financial Officer of New Fortress Energy Holdings effective as of April 10, 2017 and he serves as our Chief Financial Officer as well.

2017 Summary Compensation Table

The following table provides information regarding the compensation earned by the named executive officers during the fiscal year ended December 31, 2017.

Narrative Disclosure to Summary Compensation Table

Base Salary

Base salary is a fixed component of compensation for each year, which may be increased from time to time based on the individual’s performance and other factors as determined by the sole member of New Fortress Energy Holdings. Base salaries were originally set pursuant to negotiations with the named executive officer at the time of hire. Mr. Carey’s annualized base salary prior to his resignation was $275,000. Mr. Guinta’s annualized base salary during 2017 was $350,000. For additional information on the elements of Mr. Carey’s and Mr. Guinta’s compensation, see “Narrative Disclosure to Summary Compensation Table — Carey Offer Letter” and “Narrative Disclosure to Summary Compensation Table — Guinta Offer Letter,” below.

Cash Bonus

For 2017, Mr. Carey's target bonus opportunity was 75% of his annualized base salary. However, due to his resignation on February 10, 2017, Mr. Carey did not receive a bonus.

For 2017, Mr. Guinta’s target bonus opportunity was 125% of his annualized base salary, with a guaranteed annual bonus for 2017 in an amount equal to $250,000. Following a review of performance by New Fortress Energy Holdings and its subsidiaries as well as Mr. Guinta’s contribution to that performance, New Fortress Energy Holdings elected to pay Mr. Guinta an annual bonus for 2017 in an amount equal to $400,000. For additional information regarding the elements of Mr. Carey’s and Mr. Guinta’s compensation, see “Narrative Disclosure to Summary Compensation Table — Carey Offer Letter” and “Narrative Disclosure to Summary Compensation Table — Guinta Offer Letter,” below.

Long-Term Incentive Awards

The named executive officers were not granted long-term incentive awards during 2017. However, in connection with this offering, we intend to adopt a long-term incentive plan. For more details on the terms of the long-term incentive plan, see “Long Term Incentive Plan,” below.

Guinta Offer Letter

On March 14, 2017, NFE Management, LLC entered into an offer letter (the “Guinta Offer Letter”) with Mr. Guinta. The Guinta Offer Letter provides Mr. Guinta with (a) an annualized base salary of $350,000, (b) a discretionary target bonus opportunity equal to 125% of annual base salary (with a guaranteed $250,000 bonus for calendar year 2017), (c) a sign-on bonus of $75,000, which is required to be repaid by Mr. Guinta in the event of his resignation or termination of employment for Cause (as defined below) prior to the first anniversary of his start date, (d) subject to the adoption of a definitive equity compensation plan, an equity award grant with a grant date value of $2,500,000, which will be governed by the terms of such equity compensation plan and the applicable documents underlying the grant, and (e) eligibility to participate in the broad-based employee benefit plans, as may be adopted from time to time, subject to the eligibility requirements of such employee benefit plans.

The Guinta Offer Letter also contains certain restrictive covenants, including (a) non-competition and non-solicitation covenants that are applicable during Mr. Guinta’s term of employment, and for twelve months following his resignation or termination of his employment for Cause and (b) restrictions on disclosure of confidential information.

As used in the Guinta Offer Letter, “Cause” generally means Mr. Guinta’s (i) willful misconduct or gross negligence in the performance of his duties; (ii) failure to perform his duties or to follow the lawful directives of the board of directors; (iii) commission of, indictment for, conviction of, or pleading of guilty or nolo contendere to, a felony or any crime involving moral turpitude; (iv) failure to cooperate in any audit or investigation of the business or financial practices of any member of NFE Management, LLC or any of its affiliates or any facility managed by any of the foregoing entities (collectively, the “Company Group”); (v) performance of any material act of theft, embezzlement, fraud, malfeasance, dishonesty or misappropriation of the property of any member of the Company Group; or (vi) breach of the Guinta Offer Letter or any other agreement with a member of the Company Group, including (without limitation), a violation of the code of conduct or other written policy of any such entity.

Carey Offer Letter

On March 23, 2016, NFE Management, LLC entered into an offer letter (the “Carey Offer Letter”) with Mr. Carey. As discussed in more detail below, Mr. Carey’s employment with NFE Management, LLC terminated effective as of February 10, 2017. The Carey Offer Letter provided Mr. Carey with (a) an annualized base salary of $275,000, (b) a discretionary target bonus opportunity equal to 75% of annual base salary, (c) a relocation bonus in the amount of $50,000, (d) the ability to participate in a long term equity incentive plan, if such a plan were ultimately adopted, and (e) eligibility to participate in the broad-based employee benefit plans, as may be adopted from time to time, subject to the eligibility requirements of such employee benefit plans.

The Carey Offer Letter also contained certain restrictive covenants, including (a) non-competition and non-solicitation covenants that were applicable during Mr. Carey’s term of employment and for 12 months thereafter and (b) restrictions on disclosure of confidential information.

Carey Separation Letter

On February 26, 2017, NFE Management, LLC entered into a separation letter (the “Separation Letter”) that confirmed the agreement that was reached between Mr. Carey and NFE Management, LLC in connection

with his resignation as Chief Financial Officer, effective as of February 10, 2017. Pursuant to the terms of the Separation Letter, Mr. Carey received a lump sum cash payment of $50,000 and a benefit reimbursement equal to $73. In connection with the payment, Mr. Carey (i) affirmed that he remained bound by all non-solicitation, non-interference, non-competition and confidentiality restrictions set forth in his prior agreements with NFE Management, LLC and its affiliates and (ii) agreed to release certain potential employment-based claims.

Outstanding Equity Awards at 2017 Fiscal Year-End

The named executive officers had not been granted equity awards as of December 31, 2017.

NFE 2018 Omnibus Incentive Plan

Introduction

Prior to the completion of this offering, we will adopt the NFE 2018 Omnibus Incentive Plan (the “Plan”). The purposes of the Plan will be to provide additional incentives to selected employees, directors, independent contractors and consultants of NFE or its affiliates, to strengthen their commitment, motivate them to faithfully and diligently perform their responsibilities and to attract and retain competent and dedicated persons who are essential to the success of our business and whose efforts will impact our long-term growth and profitability. To accomplish these purposes, the Plan will provide for the issuance of options, share appreciation rights (“SARs”), restricted shares, restricted share units (“RSUs”), share bonuses, other share-based awards and cash awards.

Effective as of the date of the offering, we intend to grant RSUs under the Plan. We intend to grant to Mr. Guinta an award with a grant date value of approximately $     . For Mr. Utsler, we intend to grant an award with a grant date value of approximately $     .

Effective as of the date of the offering, we also intend to grant RSUs under the Plan to our non-employee directors. It is anticipated that the awards to directors will have a grant date value of approximately $1,000,000, calculated based on the price per share in this offering, and that such awards will vest in three equal installments on the date of each of the three annual meetings following the date of grant.

Summary of Expected Plan Terms

A total number of our Class A shares equal to 10% of our outstanding Class A shares as of the completion of this offering will be reserved and available for issuance under the Plan, as increased on the first day of each fiscal year beginning in calendar year 2020 by a number of our Class A shares equal to the number of Class A shares underlying awards that may be settled in Class A shares that were granted under the Plan during the immediately prior fiscal year.

Once subject to an award under the Plan, Class A shares will not again become available for issuance under the Plan, regardless of whether such Class A shares are actually delivered or whether the applicable award is paid or settled in cash. To the extent that an award can only be settled in cash, such award will not be counted against the total number of our Class A shares available for grant under the Plan.

The Plan will initially be administered by our board of directors, although it may be administered by either our board of directors or any committee of our board of directors. The plan administrator may interpret the Plan and may prescribe, amend and rescind rules and make all other determinations necessary or desirable for the administration of the Plan.

The Plan permits the plan administrator to select the officers, employees, non-employee directors, independent contractors and consultants of NFE or its affiliates who will receive awards, to determine the terms and conditions of those awards, including but not limited to the exercise price or other purchase price of an award, the number of our Class A shares or cash or other property subject to an award, the term of an award and the vesting schedule applicable to an award, and to amend the terms and conditions of outstanding awards.

RSUs and restricted shares may be granted under the Plan. The plan administrator will determine the purchase price, vesting schedule and performance objectives, if any, applicable to the grant of RSUs and restricted shares. If the restrictions, performance objectives or other conditions determined by the plan administrator are not satisfied, the RSUs and restricted shares will be forfeited. Subject to the provisions of the Plan and the applicable individual award agreement, the plan administrator may provide for the lapse of restrictions in installments or the acceleration or waiver of restrictions (in whole or part) under certain

circumstances as set forth in the applicable individual award agreement, including the attainment of certain performance goals, a participant’s termination of employment or service or a participant’s death or disability. The rights of RSU and restricted shareholders upon a termination of employment or service will be set forth in individual award agreements.

Unless the applicable award agreement provides otherwise, participants with restricted shares will generally have all of the rights of a Class A shareholder during the restricted period, including the right to vote and receive dividends declared with respect to such restricted shares. Dividends declared during the restricted period with respect to such restricted shares may be paid or distributed when accrued, or may become payable if the underlying restricted shares vest. During the restricted period, participants with RSUs will generally not have any rights of a Class A shareholder, but, if the applicable individual award agreement so provides, may be credited with dividend equivalent rights. Dividend equivalents may be paid or distributed when accrued, or may be paid at the time that our Class A shares in respect of the related RSUs are delivered to the participant.

We may issue share options under the Plan. Options granted under the Plan may be in the form of non-qualified options or “incentive share options” within the meaning of Section 422 of the Internal Revenue Code, as set forth in the applicable individual option award agreement. The exercise price of all options granted under the Plan will be determined by the plan administrator, but in no event may the exercise price be less than 100% of the fair market value of the related Class A shares on the date of grant. The maximum term of all share options granted under the Plan will be determined by the plan administrator, but may not exceed ten years. Each share option will vest and become exercisable (including in the event of the optionee’s termination of employment or service) at such time and subject to such terms and conditions as determined by the plan administrator in the applicable individual option agreement.

SARs may be granted under the Plan either alone or in conjunction with all or part of any option granted under the Plan. A free-standing SAR granted under the Plan entitles its holder to receive, at the time of exercise, an amount per share equal to the excess of the fair market value (at the date of exercise) of a Class A share over the base price of the free-standing SAR. A SAR granted in conjunction with all or part of an option under the Plan entitles its holder to receive, at the time of exercise of the SAR and surrender of the related option, an amount per share equal to the excess of the fair market value (at the date of exercise) of a Class A share over the exercise price of the related option. Each SAR will be granted with a base price that is not less than 100% of the fair market value of the related Class A shares on the date of grant. The maximum term of all SARs granted under the Plan will be determined by the plan administrator, but may not exceed ten years. The plan administrator may determine to settle the exercise of a SAR in Class A shares, cash, or any combination thereof.

Each free-standing SAR will vest and become exercisable (including in the event of the SAR holder’s termination of employment or service) at such time and subject to such terms and conditions as determined by the plan administrator in the applicable individual free-standing SAR agreement. SARs granted in conjunction with all or part of an option will be exercisable at such times and subject to all of the terms and conditions applicable to the related option.

Other share-based awards, valued in whole or in part by reference to, or otherwise based on, our Class A shares (including dividend equivalents) may be granted under the Plan. Dividends or dividend equivalents awarded under the Plan may be paid or distributed when accrued, or may be subject to the same restrictions, conditions and risks of forfeiture as the underlying awards and only become payable if the underlying awards vest. The plan administrator will determine the terms and conditions of such other share-based awards, including the number of Class A shares to be granted pursuant to such other share-based awards, the manner in which such other share-based awards will be settled (e.g., in Class A shares, cash or other property), and the conditions to the vesting and payment of such other share-based awards (including the achievement of performance objectives).

Bonuses payable in fully vested Class A shares and awards that are payable solely in cash may also be granted under the Plan.

The plan administrator may grant equity-based awards and incentives under the Plan that are subject to the achievement of performance objectives selected by the plan administrator in its sole discretion.

In the event of a merger, consolidation, reclassification, recapitalization, spin-off, spin-out, repurchase, reorganization, corporate transaction or event, special or extraordinary dividend or other extraordinary distribution

(whether in the form of Class A shares, cash or other property), share split, reverse share split, subdivision or consolidation, combination, exchange of shares, or other change in corporate structure affecting our Class A shares, an equitable substitution or proportionate adjustment shall be made, at the sole discretion of the plan administrator, in (i) the aggregate number of our Class A shares reserved for issuance under the Plan, (ii) the kind and number of securities subject to, and the exercise price or base price of, any outstanding options and SARs granted under the Plan, (iii) the kind, number and purchase price of our Class A shares, or the amount of cash or amount or type of property, subject to outstanding restricted shares, RSUs, share bonuses and other share-based awards granted under the Plan, or (iv) the performance goals and periods applicable to award granted under the Plan. Equitable substitutions or adjustments other than those listed above may also be made as determined by the plan administrator. In addition, the plan administrator may terminate all outstanding awards for the payment of cash or in-kind consideration having an aggregate fair market value equal to the excess of the fair market value of Class A shares, cash or other property covered by such awards over the aggregate exercise price or base price, if any, of such awards, but if the exercise price or base price of any outstanding award is equal to or greater than the fair market value of our Class A shares, cash or other property covered by such award, the board of directors may cancel the award without the payment of any consideration to the participant.

Each participant will be required to make arrangements satisfactory to the plan administrator regarding payment of an amount up to the maximum statutory tax rates in the participant’s applicable jurisdictions with respect to any award granted under the Plan, as determined by us. We have the right, to the extent permitted by law, to deduct any such taxes from any payment of any kind otherwise due to the participant. With the approval of the plan administrator, the participant may satisfy the foregoing requirement by either electing to have us withhold from delivery of our Class A shares, cash or other property, as applicable, or by delivering already owned unrestricted Class A shares, in each case, having a value not exceeding the applicable taxes to be withheld and applied to the tax obligations, determined based on the greatest withholding rates that may be used without creating adverse accounting treatment with respect to such award. We may also use any other method of obtaining the necessary payment or proceeds, as permitted by law, to satisfy our withholding obligation with respect to any award.

The Plan provides the board of directors with authority to amend, alter or terminate the Plan, but generally such action may not impair the rights of any participant with respect to outstanding awards without the participant’s consent. The plan administrator may amend an award, prospectively or retroactively, but generally such amendment may not impair the rights of any participant without the participant’s consent. Shareholder approval of any such action will be obtained if required to comply with applicable law.

The Plan will terminate on the tenth anniversary of the effective date of the Plan (although awards granted before that time will remain outstanding in accordance with their terms).

We intend to file with the SEC a registration statement on Form S-8 covering the Class A shares issuable under the Plan.

Director Compensation

We were formed on August 6, 2018 and, as a result, did not have any directors during 2017. New Fortress Energy Holdings (our predecessor for financial reporting purposes) did not award any compensation to members of its board of directors during 2017.

Following the closing of this offering, non-employee directors will receive an annual cash retainer equal to $100,000 per year, payable semiannually. Additionally, the chair of the Audit Committee of the board of directors will receive an additional $10,000 annual cash retainer, payable semiannually. As described in additional detail above under the heading “NFE 2018 Omnibus Incentive Plan – Introduction,” upon the completion of this offering, non-employee directors will also receive a grant of RSUs under the Plan equal to $1,000,000 (calculated based on the price per share in this offering), which will vest in equal parts on the day following each of our first three annual meetings.

SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT

The following table sets forth the beneficial ownership of our Class A shares and Class B shares that will be issued and outstanding upon the consummation of this offering and the related transactions, and assuming the underwriters do not exercise their option to purchase additional Class A shares and held by:

Unless otherwise noted, the address for each beneficial owner listed below is 111 W. 19^th Street, 8^th Floor, New York, New York 10011.

CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

The terms of the transactions and agreements disclosed in this section were determined by and among affiliated entities and, consequently, are not the result of arm’s length negotiations. These terms are not necessarily at least as favorable to the parties to these transactions and agreements as the terms that could have been obtained from unaffiliated third parties.

Agreements with Affiliates in Connection with the Transactions

In connection with this offering, we will enter into certain agreements with New Fortress Energy Holdings, as described in more detail below.

Contribution Agreement

In connection with the closing of this offering, we will enter into a contribution agreement that will effect the Transactions, including the transfer of the ownership interests in NFI to us, and the use of the net proceeds of this offering. While we believe this agreement is on terms no less favorable to any party than those that could have been negotiated with an unaffiliated third party, it will not be the result of arm’s-length negotiations. All of the transaction expenses incurred in connection with these transactions will be paid from the proceeds of this offering.

Shareholders’ Agreement

General

Prior to the completion of this offering, we will enter into the Shareholders’ Agreement with New Fortress Energy Holdings.

As discussed further below, the Shareholders’ Agreement will provide certain rights to New Fortress Energy Holdings and its affiliates.

Our Shareholders’ Agreement will provide that the parties thereto will use their respective reasonable efforts (including voting or causing to be voted all of our voting shares beneficially owned by each) so that no amendment is made to our operating agreement in effect as of the date of the Shareholders’ Agreement that would add restrictions to the transferability of our shares by New Fortress Energy Holdings or its permitted transferees which are beyond those provided for in our operating agreement, the Shareholders’ Agreement or applicable securities laws, or that nullify the rights set out in the Shareholders’ Agreements of New Fortress Energy Holdings or its permitted transferees unless such amendment is approved by New Fortress Energy Holdings.

Designation and Election of Directors

Our Shareholders’ Agreement will provide that, for so long as the Shareholders’ Agreement is in effect, we and New Fortress Energy Holdings shall take all reasonable actions within our respective control (including voting or causing to be voted all of the securities entitled to vote generally in the election of our directors held of record or beneficially owned by New Fortress Energy Holdings or its affiliates, and, with respect to us, including in the slate of nominees recommended by the board those individuals designated by New Fortress Energy Holdings) so as to elect to the board, and to cause to continue in office, not more than       directors (or such other number as New Fortress Energy Holdings may agree in writing), of whom, at any given time:

In accordance with the Shareholders’ Agreement, New Fortress Energy Holdings has designated      ,       and       for election to our board of directors.

Indemnification

The agreement will provide that we will indemnify New Fortress Energy Holdings and its officers, directors, employees, agents and affiliates against losses arising out of third-party claims (including litigation matters and other claims) based on, arising out of or resulting from:

In addition, we will agree to indemnify New Fortress Energy Holdings and its officers, directors, employees, agents and affiliates against losses, including liabilities under the Securities Act and the Exchange Act, relating to misstatements in or omissions from the registration statement of which this prospectus is a part and any other registration statement or report that we file, other than misstatements or omissions made in reliance on information relating to and furnished by New Fortress Energy Holdings for use in the preparation of that registration statement or report, against which New Fortress Energy Holdings will agree to indemnify us.

Registration Rights

Demand Rights. Under our Shareholders’ Agreement, New Fortress Energy Holdings will have, for so long as New Fortress Energy Holdings directly or indirectly beneficially owns, together with its affiliates, an amount of our Class A and Class B shares (whether owned at the time of this offering or subsequently acquired) equal to or greater than 1% of the Class A and Class B shares issued and outstanding immediately after the consummation of this offering (a “Registrable Amount”), “demand” registration rights that allow New Fortress Energy Holdings, for itself and for its affiliates and permitted transferees, at any time after 180 days following the consummation of this offering, to request that we register under the Securities Act an amount of Class A shares equal to or greater than a Registrable Amount. New Fortress Energy Holdings, for itself and for its affiliates and permitted transferees, will be entitled to unlimited demand registrations so long as such persons, together, beneficially own a Registrable Amount. We will also not be required to effect any demand registration within one month of a “firm commitment” underwritten offering to which the requestor held “piggyback” rights, described below, and which included at least 50% of the Class A shares requested by the requestor to be included. We will not be obligated to grant a request for a demand registration within three months of any other demand registration.

Piggyback Rights. For so long as New Fortress Energy Holdings beneficially owns, together with its affiliates and permitted transferees, a Registrable Amount, New Fortress Energy Holdings (and its affiliates and permitted transferees) will also have “piggyback” registration rights that allow them to include Class A shares that they own in any public offering of equity securities initiated by us (other than those public offerings

pursuant to registration statements on Form S-4 or Form S-8 or pursuant to an employee benefit plan arrangement) or by any of our other shareholders that have registration rights. These “piggyback” registration rights will be subject to proportional cutbacks based on the manner of the offering and the identity of the party initiating such offering.

Shelf Registration. Under our Shareholders’ Agreement, we will grant to New Fortress Energy Holdings or any of its respective permitted transferees, for so long as New Fortress Energy Holdings, together with its affiliates and permitted transferees, beneficially owns a Registrable Amount, the right to request a shelf registration on Form S-3 providing for offerings of Class A shares issuable upon exercise of the Redemption Right to be made on a continuous basis until all shares covered by such registration have been sold, subject to our right to suspend the use of the shelf registration prospectuses for a reasonable period of time (not exceeding 60 days in succession or 90 days in the aggregate in any 12 month period) if we determine that certain disclosures required by the shelf registration statement would be detrimental to us or our shareholders. In addition, New Fortress Energy Holdings, for itself and for its affiliates and permitted transferees, may elect to participate in such shelf registrations within ten days after notice of the registration is given.

Indemnification; Expenses; Lock-ups. Under our Shareholders’ Agreement, we will agree to indemnify the applicable selling shareholder and its officers, directors, employees, managers, members partners, agents and controlling persons against any losses or damages resulting from any untrue statement or omission of material fact in any registration statement or prospectus pursuant to which it sells Class A shares, unless such liability arose from the applicable selling shareholder’s misstatement or omission, and the applicable selling shareholder will agree to indemnify us against all losses caused by its misstatements or omissions. We will pay all registration and offering-related expenses incidental to our performance under the Shareholders’ Agreement, and the applicable selling shareholder will pay its portion of all underwriting discounts, commissions and transfer taxes, if any, relating to the sale of its Class A shares under the Shareholders’ Agreement. We have agreed to enter into, and to cause our officers and directors to enter into, lock-up agreements in connection with any exercise of registration rights by New Fortress Energy Holdings, for itself and for its affiliates and permitted transferees.

Information Rights

Under our Shareholders’ Agreement, New Fortress Energy Holdings will have the right to request certain information from us.

Assistance in the Sale of New Fortress Energy Holdings’ Shares

Under our Shareholders’ Agreement, if New Fortress Energy Holdings seeks to sell its Class A shares other than pursuant to a registration statement, we shall use our reasonable best efforts to assist New Fortress Energy Holdings in the sale process, including by providing information to potential purchasers as requested by New Fortress Energy Holdings.

In addition, if the board of the directors starts and then abandons a sale process and New Fortress Energy Holdings indicates that it wants to sell its Class A shares, we shall permit New Fortress Energy Holdings to engage in discussions with potential purchasers who participated in the abandoned sales process. We shall be obligated to assist New Fortress Energy Holdings in any such sale process to the extent required by the paragraph above.

Amended and Restated Limited Liability Company Agreement of NFI

The form of NFI LLC Agreement is filed as an exhibit to the registration statement of which this prospectus forms a part, and the following description of the NFI LLC Agreement is qualified in its entirety by reference thereto.

Redemption Rights

Following this offering, under the NFI LLC Agreement, New Fortress Energy Holdings and any permitted transferees of their NFI LLC Units will, subject to certain limitations, have the right, pursuant to the Redemption Right, to cause NFI to acquire all or a portion of its NFI LLC Units for, at NFI’s election, (i) Class A shares at a redemption ratio of one Class A share for each NFI LLC Unit redeemed, subject to conversion rate adjustments

for equity splits, equity dividends and reclassification and other similar transactions or (ii) an equivalent amount of cash. NFI will determine whether to issue Class A shares or cash based on facts in existence at the time of the decision, which we expect would include the relative value of the Class A shares (including trading prices for the Class A shares at the time), the cash purchase price, the availability of other sources of liquidity to acquire the NFI LLC Units and alternative uses for such cash. As the sole managing member of NFI, our decision to make a cash payment upon the redemption of NFI LLC Units will be made by a committee of our board of directors. Wesley Edens and Randal Nardone will serve as members of such committee. Alternatively, upon the exercise of the Redemption Right, NFE (instead of NFI) will have the right, pursuant to the Call Right, to, for administrative convenience, acquire each tendered NFI LLC Unit directly from the redeeming NFI unitholder for, at its election, (x) one Class A share, subject to conversion rate adjustments for equity splits, equity dividends and reclassification and other similar transactions or (y) an equivalent amount of cash. In addition, upon a change of control of NFE, NFE will have the right to require each holder of NFI LLC Units (other than NFE) to exercise its Redemption Right with respect to some or all of such unitholder’s NFI LLC Units. In connection with any redemption of NFI LLC Units pursuant to the Redemption Right or our Call Right, the corresponding number of Class B shares will be cancelled.

For purposes of any transfer or exchange of NFI LLC Units initially owned by New Fortress Energy Holdings and our Class B shares, the NFI LLC Agreement and our operating agreement will contain provisions effectively linking each NFI LLC Unit with one of our Class B shares. Class B shares cannot be transferred without transferring an equal number of NFI LLC Units and vice versa.

Distributions and Allocations

In accordance with the NFI LLC Agreement, subject to the requirement to make tax distributions described below, we will have the right to determine when distributions will be made to the holders of NFI LLC Units and the amount of any such distributions. Following this offering, if we authorize a distribution, such distribution will be made to the holders of NFI LLC Units generally on a pro rata basis in accordance with their respective percentage ownership of NFI LLC Units.

NFI will allocate its net income or net loss for each year to the holders of NFI LLC Units pursuant to the terms of the NFI LLC Agreement, and the holders of NFI LLC Units, including NFE, will generally incur U.S. federal, state and local income taxes on their share of any taxable income of NFI. Net income and losses of NFI generally will be allocated to the holders of NFI LLC Units on a pro rata basis in accordance with their respective percentage ownership of NFI LLC Units, subject to requirements under U.S. federal income tax law that certain items of income, gain, loss or deduction be allocated disproportionately in certain circumstances. To the extent NFI has available cash and subject to the terms of NFE’s credit agreements and any other debt instruments, we intend to cause NFI to make (i) generally pro rata distributions to its unitholders, including NFE, in an amount sufficient to allow NFE to pay its taxes, (ii) at the election of certain holders of NFI LLC Units, additional distributions in an amount generally intended to allow such holders to satisfy their respective income tax liabilities with respect to their allocable share of the income of NFI (based on certain assumptions and conventions), which additional distributions may be made on a pro rata basis to all holders of NFI LLC Units or a non-pro rata basis in redemption of NFI LLC Units from the relevant holders, and (iii) non-pro rata distributions to NFE in an amount at least sufficient to reimburse it for its corporate and other overhead expenses.

Issuance of Equity

The NFI LLC Agreement will provide that, except as otherwise determined by us, at any time NFE issues a Class A share or any other equity security, the net proceeds received by NFE with respect to such issuance, if any, shall be concurrently invested in NFI, and NFI shall issue to NFE one NFI LLC Unit or other economically equivalent equity interest unless such net proceeds are used by NFE to acquire a NFI LLC Unit pursuant to NFE’s exercise of the Call Right. Conversely, if at any time, any of NFE’s Class A shares are redeemed, repurchased or otherwise acquired, NFI shall redeem, repurchase or otherwise acquire an equal number of NFI LLC Units held by NFE, upon the same terms and for the same price, as our Class A shares are redeemed, repurchased or otherwise acquired.

Other Transactions with Related Persons

Miami Ground Lease

We lease the property for our Miami Facility from an affiliate of Fortress.

The Lease. Our subsidiary, LNG Holdings (Florida) LLC (“Florida Holdings”), is the owner and operator of the Miami Facility. Florida Holdings holds rights to the real property on which the Miami Facility is located pursuant to that certain Ground Lease Agreement dated November 20, 2014 (the “Miami Lease”), by and between FDG LR 7 LLC, as landlord (“Miami Landlord”), and Florida Holdings, as tenant (in such capacity, “Miami Tenant”). The Miami Landlord is owned by certain funds managed by an affiliate of Fortress.

Term. The term of the Miami Lease commenced November 20, 2014, and expires November 19, 2019. The term will automatically extend for five additional periods of five years each (unless Miami Tenant notifies Miami Landlord otherwise as set forth in the Miami Lease).

Rent; Security. Miami Tenant pays base rent in the amount of $270,000 per year, which amount shall escalate by 2.5% on each anniversary of the commencement date. Miami Tenant has delivered a security deposit in the amount of $135,000, which will be reduced to $70,000 upon commencement of the first renewal term, and further reduced to $0 upon commencement of the second renewal term. Miami Tenant has the right to provide the security deposit in the form of letter of credit.

Net Lease. Miami Tenant is responsible for all other costs attributable to the Miami leased premises and Miami Facility, including all property taxes, insurance, and utilities, as well as all maintenance, repair, and replacement costs.

Private Aircraft

Mr. Edens owns or leases an aircraft that we charter from a third-party aircraft operator for business purposes in the ordinary course of operations. We incurred $2.9 million and $1.6 million for the years ended December 31, 2017 and 2016, respectively, and such amounts are included within Selling, general and administrative charges reimbursed to FIG LLC pursuant to the management services agreement described below. We paid the aircraft operator market rates for the charters. The operator remits a portion of these amounts to Mr. Edens.

Administrative Services Agreement

We are party to an administrative services agreement with FIG LLC, an affiliate of Fortress, pursuant to which FIG LLC provides us with certain back-office services and charges us for selling, general and administrative expenses incurred to provide these services. For the years ended December 31, 2017 and 2016, we paid FIG LLC $3.9 million and $2.2 million, respectively, for services provided under the administrative services agreement.

Procedures for Review, Approval and Ratification of Transactions with Related Persons

SEC rules define “transactions with related persons” to include any transaction in which the Company is a participant, the amount involved exceeds $120,000, and in which any “related person,” including any officer, director, nominee for director or beneficial holder of more than 5% of any class of our voting securities or an immediate family member of any of the foregoing, has a direct or indirect material interest. We expect that our Board will adopt a written policy that outlines procedures for approving transactions with related persons, and that any such transactions will be reviewed and approved or ratified by a majority of our disinterested and independent directors pursuant to the procedures outlined in any such policy. In determining whether to approve or ratify a transaction with a related person, we expect that the independent and disinterested directors will consider a variety of factors they deem relevant, such as: the terms of the transaction; the terms available to unrelated third parties; the benefits to the Company; and the availability of other sources for comparable assets, products or services.

DESCRIPTION OF SHARES

Class A Shares

Voting Rights. Holders of Class A shares are entitled to one vote per share held of record on all matters to be voted upon by the shareholders. Holders of our Class A shares and Class B shares vote together as a single class on all matters presented to our shareholders for their vote or approval, except with respect to the amendment of certain provisions of our amended and restated certificate of incorporation that would alter or change the powers, preferences or special rights of the Class B shares so as to affect them adversely, which amendments must be by a majority of the votes entitled to be cast by the holders of the shares affected by the amendment, voting as a separate class, or as otherwise required by applicable law. The holders of Class A shares do not have cumulative voting rights in the election of directors.

Dividend Rights. Holders of our Class A shares are entitled to ratably receive dividends when and if declared by our board of directors out of funds legally available for that purpose, subject to any statutory or contractual restrictions on the payment of dividends and to any prior rights and preferences that may be applicable to any outstanding preferred shares.

Liquidation Rights. Upon our liquidation, dissolution, distribution of assets or other winding up, the holders of Class A shares are entitled to receive ratably the assets available for distribution to the shareholders after payment of liabilities and the liquidation preference of any of our outstanding preferred shares.

Other Matters. The Class A shares have no preemptive or conversion rights and are not subject to further calls or assessment by us. There are no redemption or sinking fund provisions applicable to the Class A shares. All outstanding Class A shares, including the Class A shares offered in this offering, are fully paid and non-assessable.

Class B Shares

Generally. In connection with the reorganization and this offering, the NFI unitholders will receive one Class B share for each NFI LLC Unit that they hold. Accordingly, the NFI unitholders will have a number of votes in NFE equal to the aggregate number of NFI LLC Units that they hold. Class B shares cannot be transferred without transferring an equal number of NFI LLC Units and vice versa.

Voting Rights. Holders of our Class B shares are entitled to one vote per share held of record on all matters to be voted upon by the shareholders. Holders of our Class A shares and Class B shares vote together as a single class on all matters presented to our shareholders for their vote or approval, except with respect to the amendment of certain provisions of our amended and restated certificate of incorporation that would alter or change the powers, preferences or special rights of the Class B shares so as to affect them adversely, which amendments must be by a majority of the votes entitled to be cast by the holders of the shares affected by the amendment, voting as a separate class, or as otherwise required by applicable law. The holders of Class B shares do not have cumulative voting rights in the election of directors.

Dividend and Liquidation Rights. Holders of our Class B shares do not have any right to receive dividends, unless the dividend consists of our Class B shares or of rights, options, warrants or other securities convertible or exercisable into or exchangeable for Class B shares paid proportionally with respect to each outstanding Class B share and a dividend consisting of Class A shares or of rights, options, warrants or other securities convertible or exercisable into or exchangeable for Class A shares on the same terms is simultaneously paid to the holders of Class A shares. Holders of our Class B shares do not have any right to receive a distribution upon our liquidation or winding up.

Preferred Shares

Pursuant to our operating agreement, our board of directors by resolution may establish one or more series of preferred shares having such number of shares, designations, dividend rates, relative voting rights, conversion or exchange rights, redemption rights, liquidation rights and other relative participation, optional or other special rights, qualifications, limitations or restrictions as may be fixed by the board without any further shareholder approval. The rights with respect to a series of preferred shares may be more favorable to the holder(s) thereof than the rights attached to our Class A shares. It is not possible to state the actual effect of the issuance of any

preferred shares on the rights of holders of our Class A shares until our board of directors determines the specific rights attached to such preference share. The effect of issuing preferred shares may include, among other things, one or more of the following:

Transfer Agent and Registrar

Duties

American Stock Transfer & Trust Company, LLC will serve as the registrar and transfer agent for the Class A shares. We will pay all fees charged by the transfer agent for transfers of Class A shares except the following, which must be paid by our Class A shareholders:

There will be no charge to our Class A shareholders for disbursements of any dividends. We will indemnify the transfer agent, its agents and each of their stockholders, directors, officers and employees against all claims and losses that may arise out of acts performed or omitted for its activities in that capacity, except for any liability due to any gross negligence or intentional misconduct of the indemnified person or entity.

Resignation or Removal

The transfer agent may resign, by notice to us, or be removed by us.

Transfer of Class A shares and Class B shares

Upon the transfer of a Class A share or a Class B share in accordance with our operating agreement, the transferee of the Class A share or Class B share shall be admitted as a member with respect to the class of shares transferred when such transfer and admission are reflected in our books and records. Each transferee:

We will cause any transfers to be recorded on our books and records from time to time (or shall cause the transfer agent to do so, as applicable).

We may, at our discretion, treat the nominee holder of a Class A share or Class B share as the absolute owner. In that case, the beneficial holder’s rights are limited solely to those that it has against the nominee holder as a result of any agreement between the beneficial owner and the nominee holder.

Class A shares and Class B shares are securities and any transfers are subject to the laws governing the transfer of securities.

Until a Class A share or Class B share has been transferred on our books, we and the transfer agent may treat the record holder of the Class A share or Class B share as the absolute owner for all purposes, except as otherwise required by law or stock exchange regulations.

OUR OPERATING AGREEMENT

Organization and Duration

Our limited liability company was formed on August 6, 2018, and will remain in existence until dissolved in accordance with our operating agreement.

Purpose

Under our operating agreement, we are permitted to engage in any business activity that lawfully may be conducted by a limited liability company organized under Delaware law and, in connection therewith, to exercise all of the rights and powers conferred upon us pursuant to the agreements relating to such business activity.

Agreement to be Bound by our Operating Agreement; Power of Attorney

By purchasing our Class A shares, you will be admitted as a member of our limited liability company and will be deemed to have agreed to be bound by the terms of our operating agreement. Pursuant to this agreement, each Class A shareholder and each person who acquires Class A shares from a Class A shareholder grants to certain of our officers (and, if appointed, a liquidator) a power of attorney to, among other things, execute and file documents required for our qualification, continuance or dissolution. The power of attorney also grants certain of our officers the authority to make certain amendments to, and to make consents and waivers under and in accordance with, our operating agreement.

Amendment of Our Operating Agreement

Amendments to our operating agreement may be proposed only by or with the consent of our board of directors. To adopt a proposed amendment, our board of directors is required to seek written approval of the holders of the number of shares required to approve the amendment or call a meeting of our shareholders to consider and vote upon the proposed amendment. Except as set forth below, an amendment must be approved by holders of a majority of the outstanding shares.

Prohibited Amendments. No amendment may be made that would:

The provision of our operating agreement preventing the amendments having the effects described in any of the clauses above can be amended upon the approval of holders of at least two-thirds of the outstanding shares.

No Shareholder Approval. Our board of directors may generally make amendments to our operating agreement without the approval of any shareholder or assignee to reflect: