As filed with the Securities and Exchange Commission on January 14 , 2019

Registration No. 333- 228339

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

Amendment No. 2
to
FORM S-1
REGISTRATION STATEMENT UNDER
THE SECURITIES ACT OF 1933

New Fortress Energy 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)

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

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.

We believe this compelling business model will provide opportunities to generate average revenues in excess 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). 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 demand expectations exceed supply estimates and, at 2025, 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. According to the 2018 World LNG Report by the International Gas Union, existing global liquefaction capacity is estimated to be 369 mtpa. 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 our liquefier 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 export facilities 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 $7.00 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 12.4 million gallons (1,025,000 MMBtu) per day, which includes approximately 2.2 million gallons per day that we expect to sell to customers under existing contracts. 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 or that we will achieve our target pricing or margins. See “Risk Factors—Our ability to implement our business strategy may be materially and adversely affected by many known and unknown factors.”

Our Terminals

Downstream, we have six 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 four 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 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 42% 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 of 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 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 150MW power plant that we are constructing, and 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 also entered

into a 20-year steam supply agreement (“SSA”) to supply Jamalco with steam for use in its alumina refinery operations. 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 of 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, the Puerto Rico Electric Power Authority (“PREPA”) selected our proposal to convert and supply natural gas to Units 5 and 6 of the San Juan Combined Cycle Power Plant (the “San Juan Power Plant”) – which together have a capacity of 440MW. The San Juan Power Plant is currently running on diesel, and we plan to convert the San Juan Power Plant to run on natural gas and provide up to approximately 25 TBtu of natural gas per year, which would equal approximately 850,000 gallons of LNG (70,000 MMBtu) per day. We are in advanced stages of finalizing an agreement with PREPA for the conversion of the San Juan Power Plant and the right to provide natural gas to PREPA for use as fuel for Units 5 and 6 of the San Juan Power Plant. The agreement is currently under review by the Puerto Rico Energy Bureau (the “PREB”) and the Financial Oversight and Management Board for Puerto Rico (the “FOMB”). Although we expect such review to be completed by the end of January 2019, there can be no assurance that such regulatory review will be completed on this timeline or that we will not need to make adjustments to the agreement as a result of such regulatory review. We expect the conversion to natural gas would allow PREPA to realize significant, recurring annual cost savings of approximately $285 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 – We were awarded a public tender to build, own and operate an LNG regasification terminal (the “La Paz Terminal”) on August 13, 2018. The La Paz terminal is currently under development and is expected to commence commercial operations in the fourth quarter of 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 from a mothership moored nearby. Initially, the La Paz Terminal is expected to supply approximately 225,000 gallons of LNG (18,000 MMBtu) per day for a 93MW 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 85MW Los Cabos power plant owned by Comision Federal de Electridad, as well as regional industrial users such as ferries and hotels.

Shannon, Ireland – We have entered into an agreement to purchase all of the ownership interests in a project company that owns the rights to develop and operate an LNG terminal and a CHP plant on the Shannon Estuary near Ballylongford, Ireland. We intend this terminal to include a 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. 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. We will begin construction of the Ireland Terminal once we have secured contracts with downstream customers for volumes that are sufficient to support the development.

Dominican Republic – We are in the advanced stages of negotiations to enter into a long-term contract for the supply of up to 1.7 million gallons of LNG per day (140,500 MMBtu) to supply power plants with natural gas in the Southeastern portion of the Dominican Republic. We plan to develop an LNG import terminal off the Southeastern coast of the Dominican Republic which will receive shipments of LNG via an LNGC and will transfer the LNG onshore. LNG will be transferred from an LNGC to an FSRU which will be semi-permanently

moored at the terminal and will be transported via a subsea pipeline to the San Pedro de Macoris area where the natural gas will be sent on to power plants in the region. The LNG import terminal may also be utilized to transport natural gas to industrial users in the Dominican Republic. We anticipate commencing commercial operations in the first quarter of 2020.

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 one liquefaction facility in Pennsylvania (our “Pennsylvania Facility” 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 approximately 3.6 million gallons of LNG (298,000 MMBtu) per day, or approximately 2.23 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 96.6% dispatchable during 2018. The facility also has three LNG storage tanks, with total capacity of approximately 1,000 cubic meters. 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 Pennsylvania Facility, and we are targeting completion in the first quarter of 2021. In January 2019, we entered into a definitive engineering, procurement and construction agreement (the “EPC Agreement”) with a global engineering, procurement and construction company specializing in energy infrastructure (the “Contractor”) for the construction of our Pennsylvania Facility. We expect our Pennsylvania Facility to have the capacity to liquefy approximately 3.6 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 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 in the advanced stages of negotiating a long-term lease with a company managed by an affiliate of Fortress for the use of a facility at a port approximately 195 miles away along the Delaware River, and we expect to finalize the lease prior to the completion of this offering. Under such lease, we expect to have exclusive rights to use such facility for the term of the lease and that LNG will be transferred directly from tanker truck, rail or other non-pipeline means to marine vessels 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, from which we will deliver natural gas or LNG to our customers. We expect to have liquefaction capacity of approximately 3.6 million gallons of LNG per day after the completion of our Pennsylvania Facility.

At the completion of this offering, we will have spent approximately $350 million in building and developing our facilities since 2014 and have commitments to spend an additional approximately $1.35 billion. We expect to fund these commitments through a combination of cash on hand, operating cash flows, additional borrowings and proceeds from this offering. Pending completion and commissioning of our liquefier 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 under a multi-cargo contract with Centrica LNG Company Limited (“Centrica”). We are drawing on our experience from the construction and operation of our Miami Facility to optimize the development of our Pennsylvania Facility.

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 12.4 million gallons (1,025,000 MMBtu) per day, which includes approximately 2.2 million gallons per day that we expect to sell to customers under existing contracts. 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. Pending completion and commissioning of our liquefier 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 under a multi-cargo contract with Centrica. We have entered into contracts with Centrica for the purchase of cargoes of 1.1 billion gallons of LNG (86.8 million MMBtu). The cargoes are scheduled for delivery between June 2019 and December 2021. 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 commissioned our Old Harbour Terminal in December 2018. Construction of the Old Harbour Terminal was completed in October 2018, and our chartered FSRU arrived in December 2018. When operational, the Old Harbour Terminal will service a new 190MW power plant operated by JPC and a new 150MW power 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 opened 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.

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:

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 147,058,824 Class B shares, representing a 86.9% voting and non-economic limited liability company interest in us, and a 86.9% 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 86.9% of the voting power of our shares following the completion of this offering (or approximately 85.2% 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 six 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.

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 disinterested members 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 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.”

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.

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 $56.5 million (based on an assumed initial offering price of $18.00 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 13.1% membership interest in NFI (or a 14.8% 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.”

capital appreciation and liquidity with respect to such investments. We cannot assure you if or when we will enter into contracts for the sale of LNG and/or natural gas, the price at which we will be able to sell such LNG and/or natural gas or our costs for such LNG and/or natural gas. Thus, there can be no assurance that we will achieve our target pricing, costs or margins. 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.

Additionally, our strategy may evolve over time. 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 business. Any one or more of the following factors may have a material adverse effect on our ability to implement our strategy and achieve our targets:

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.”).

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. Our limited history also means that we continue to develop and implement various policies and procedures including those related to data privacy and other matters. We will need to continue to build our team to implement our strategies.

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 and our strategy includes the construction of additional 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.

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, assuming the accuracy of our assumptions relating to construction, 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 Facility, the San Juan Facility and the La Paz Terminal, which are further described in “Business.” In the future, we expect to incur additional indebtedness to assist us in developing our operations, including opportunistically refinancing and/or upsizing our Term Loan Facility following the consummation of this offering. 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. Additionally, we may need to adjust the timing of our planned capital expenditures and facilities development depending on the availability of such additional funding. 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 could 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, risks relating to the credit risk of our customers and the jurisdictions in which we operate, 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 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.

Our business is heavily dependent upon our international operations, particularly in Jamaica, and any disruption to those operations would adversely affect us.

Our operations in Jamaica began in October 2016, when our Montego Bay Terminal commenced commercial operations, and continue to grow. Jamaica is subject to political instability, acts of terrorism, natural disasters, in particular hurricanes, extreme weather conditions, crime and similar other risks which may negatively impact our operations in the region. We may also be affected by trade restrictions, such as tariffs or other trade controls. Additionally, tourism is a significant driver of economic activity in the Caribbean. As a result, tourism directly and indirectly affects local demand for our LNG and therefore our results of operations. Trends in tourism in the Caribbean are primarily driven by the economic condition of the tourists' home country or territory, the condition of their destination, and the affordability and desirability of air travel and cruises. Additionally, unexpected factors could reduce tourism at any time, including, local or global economic recessions, terrorism, pandemics, severe weather or natural disasters. If we are unable to continue to leverage on the skills and experience of our international workforce and members of management with experience in the jurisdictions in which we operate to manage such risks, we may be unable to provide LNG at an attractive price and our business could be materially affected.

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 and as a result, are subject to any risks specific to those entities and the jurisdictions and markets in which they operate.

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 or will enter into in the near future , 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. As of January 9, 2019, our GSAs, PPA and SSA have a weighted average of 12.4 years remaining under such contracts, weighted based on contracted volumes. While certain of our long-term contracts contain minimum volume commitments, our expected sales to customers under existing contracts is substantially in excess of such minimum volume commitments. Our near term ability to generate cash is dependent on JPS’s, JPC’s and Jamalco’s continued willingness and ability to continue purchasing our products and services and 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. Additionally, as many of our facilities are still in developmental stage, our entry into long-term contracts before such facilities are fully operational exposes us to extended counter-party credit risk.

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. In addition, PREPA is currently subject to bankruptcy proceedings pending in the U.S. District Court for the District of Puerto Rico. As a result, PREPA’s ability to meet its payment obligations under its contracts will be largely dependent upon funding from the Federal Emergency Management Agency or other sources. PREPA’s contracting practices in connection with restoration and repair of PREPA’s electrical grid in Puerto Rico, and the terms of certain of those contracts, have been subject to comment and are the subject of review and hearings by U.S. federal and Puerto Rican governmental entities. In the event that PREPA does not have or does not obtain the funds necessary to satisfy obligations to us under the agreement we are negotiating with PREPA or terminates the agreement prior to the end of the agreed term, our financial condition, results of operations and cash flows could be materially and adversely affected. Additionally, we may face difficulties in enforcing our contractual rights against contractual counterparties that have not submitted to the jurisdiction of U.S. courts.

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 Facility 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. There can be no assurance we will achieve our target cost or pricing goals. 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. Additionally, we intend to rely on long term, largely fixed-price contracts for the feedgas that we need in order to manufacture and sell our LNG. Our actual costs and any profit realized on the sale of our LNG may vary from the estimated amounts on which our contracts for feedgas were originally based. There is inherent risk in the estimation process, including significant changes in the demand for and price of LNG as a result of the factors listed above, many of which are outside of our control.

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 $280 million of total indebtedness outstanding (which does not give effect to additional indebtedness we may incur following the consummation of this offering).

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 suppliers 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, including trucking accidents while transporting natural gas, 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.

Global climate change may in the future increase the frequency and severity of weather events and the losses resulting therefrom, which could have a material adverse effect on the economies in the markets in which we operate or plan to operate in the future and therefore on our business.

Over the past several years, changing weather patterns and climatic conditions, such as global warming, have added to the unpredictability and frequency of natural disasters in certain parts of the world, including the markets in which we operate and intend to operate, and have created additional uncertainty as to future trends. There is a growing consensus today that climate change increases the frequency and severity of extreme weather events and, in recent years, the frequency of major weather events appears to have increased. We cannot predict whether or to what extent damage that may be caused by natural events, such as severe tropical storms and hurricanes, will affect our operations or the economies in our current or future market areas, but the increased frequency and severity of such weather events could increase the negative impacts to economic conditions in these regions and result in a decline in the value or the destruction of our liquefiers and downstream facilities or affect our ability to transmit LNG. In particular, if one of the regions in which our terminals are operating or under development is impacted by such a natural catastrophe in the future, it could have a material adverse effect on our business. Further, the economies of such impacted areas may require significant time to recover and there is no assurance that a full recovery will occur. Even the threat of a severe weather event could impact our business, financial condition or the price of our Class A shares.

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. Mr. Edens does not have an employment agreement with us. 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 entered into an EPC contract for our Pennsylvania Facility in the first quarter of 2019. See “Business—Our Liquefaction Assets—Pennsylvania EPC Agreement.” 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, which could be particularly difficult in certain of the markets in which we plan to operate. 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.

We are 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. If any third parties, such as an affiliate of Chesapeake Energy Corporation (“Chesapeake”), were to default on their obligations under our contracts or seek bankruptcy protection, we may not be able to purchase or receive a sufficient quantity of natural gas in order to satisfy our delivery obligations under our GSAs, PPA and SSA with LNG produced at our own liquefaction facilities. 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.

While we have entered into contracts with Centrica to purchase a substantial portion of our expected LNG volumes for 2019 and 2020, we will need to purchase significant additional LNG volumes to meet our delivery obligations to our downstream customers. 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 Facility or be able to supply our facilities with LNG produced at our own facilities. Even if we do complete the Pennsylvania Facility, there can be no assurance that it 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 as well as local law. 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 LNG 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 and weaken our financial condition.

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 of which have been in operation longer than us.

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 Facility 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 Facility, 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 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 Facility. 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 additional markets in the Caribbean (including Puerto Rico and the Dominican Republic), 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.

Our after-tax profitability may also 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. Additionally, the Multilateral Convention to Implement Tax Treaty Related Measures to Prevent BEPS recently entered into force among the jurisdictions that have ratified it. Both of these recent changes 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 147,058,824 Class B shares representing 86.9% of our voting power (or approximately 85.2% 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.

Furthermore, prior to the completion of this offering, we will enter into the Shareholders’ Agreement with New Fortress Energy Holdings. The Shareholders’ Agreement will provide New Fortress Energy Holdings with the right to designate a certain number of nominees to our board of directors so long as New Fortress Energy Holdings and its affiliates collectively beneficially own at least 5% of the outstanding Class A shares and Class B shares. In addition, our operating agreement will provide certain entities controlled by Wesley Edens and Randal Nardone (the “Consenting Entities”) the right to approve certain material transactions so long as the Consenting Entities and their affiliates collectively, directly or indirectly, own at least 30% of the outstanding Class A shares and Class B shares. See “Certain Relationships and Related Transactions—Shareholders’ Agreement.”

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 and the incurrence or refinancing of new or existing indebtedness. In addition, the detemination 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’ tax or other considerations, which may differ from the considerations of NFE or our other shareholders.

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 $ 14.00 per Class A share.

The assumed initial public offering price of $18.00 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 $4.00 per Class A share. Based on the assumed initial public offering price of $18.00 per Class A share, shareholders will incur immediate and substantial dilution of $14.00 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 22,200,000 Class A shares and 147,058,824 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 22,200,000 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 continue 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 will need 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, compliance 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. We intend to enter into an administrative services agreement with FIG LLC, an affiliate of Fortress, in connection with the closing of this offering, pursuant to which FIG LLC will provide us with certain back-office services and charge us for selling, general and administrative expenses incurred to provide these services. FIG LLC will also continue to provide compliance services for the foreseeable future and any transition will take place over time. 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 $2 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 will cause NFI to make (i) pro rata distributions to holders of NFI LLC Units, including NFE, in an amount sufficient to allow NFE to pay its taxes, (ii) additional pro rata distributions to all holders of NFI LLC Units in an amount generally intended to allow holders of NFI LLC Units (other than NFE) to satisfy their respective income tax liabilities with respect to their allocable share of the income of NFI (based on certain assumptions and conventions and as determined by an entity controlled by Wesley Edens and Randal Nardone (“NFI Holdings”)) 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, NFI will be required to make additional pro rata tax distributions to all holders of NFI LLC Units in an amount generally intended to allow the holders of NFI LLC Units (other than NFE) to satisfy their assumed tax liabilities with respect to their allocable share of the income of NFI (based on certain assumptions and conventions and as determined by NFI Holdings). For this purpose, the determination of available cash will take into account, among other factors, (i) the existing indebtedness and other obligations of NFI and its subsidiaries and their anticipated borrowing needs, (ii) the ability of NFI and its subsidiaries to take on additional indebtedness on commercially reasonable terms and (iii) any necessary or appropriate reserves.

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. 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, 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 NFE or certain other holders of NFI LLC Units use any excess cash received to reinvest in NFI for additional NFI LLC Units. In addition, because cash available for additional tax distributions will be determined taking into account the ability of NFI and its subsidiaries to take on additional borrowing, NFI may be required to increase its indebtedness in order to fund additional tax distributions. Such additional borrowing may adversely affect our financial condition and business operations by, without limitation, limiting our ability to borrow in the future for other purposes, such as capital expenditures, and increasing our interest expense and leverage ratios.

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.

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”) customers 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 – Nine months ended September 30, 2018 compared to nine months ended September 30, 2017

Revenues

Operating revenue from LNG and natural gas sales for the nine months ended September 30, 2018 was $69,545, which increased by $8,892 from $60,653 for the nine months ended September 30, 2017. The increase in operating revenue between the nine-month periods was attributable to increased sales to the Bogue Power Plant and additional small-scale customers.

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 nine months ended September 30, 2018 was consistent with the nine months ended September 30, 2017.

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 nine months ended September 30, 2018 was $68,625, which increased $10,771 from $57,854 for the nine months ended September 30, 2017. The increase in Cost of sales between the nine-month periods was attributable to increased volumes sold to customers and a higher cost of LNG purchased.

Operations and maintenance

Operations and maintenance relates to costs of operating our Miami Facility and Montego Bay Terminal exclusive of conversion costs reflected in Cost of sales. Operations and maintenance for the nine months ended September 30, 2018 was $5,750, which increased $981 from $4,769 for the nine months ended September 30, 2017. The increase is primarily a result of increased general maintenance costs at these facilities.

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 nine months ended September 30, 2018, was $40,827, which increased $19,663 from $21,164 for the nine months ended September 30, 2017 primarily as a result of increased development activities related to the initial phases of projects in Puerto Rico and Mexico as well as increased employee travel and headcount.

Depreciation and amortization

Depreciation and amortization for the nine months ended September 30, 2018 was $2,258, which increased $227 from $2,031 for the nine months ended September 30, 2017. The increase is primarily a result of additional equipment purchases placed in service for small-scale customers.

Interest expense

Interest expense for the nine months ended September 30, 2018 was $6,389, which increased $1,539 from $4,850 for the nine months ended September 30, 2017, primarily as a result of financing costs amortized for the Term Loan Facility of $1,020.

Other (income), net

Other income, net for the nine months ended September 30, 2018 was ($515), which increased $440 from ($75) for the nine months, ended September 30, 2017, primarily as a result of interest income and realized foreign currency gain.

Loss on extinguishment of debt

Loss on extinguishment of debt for the nine months ended September 30, 2018 was $618, which was recognized as a result of the repayment of the Miami Loan and MoBay Loan in August and September 2018, respectively.

Tax provision (benefit)

Tax provision (benefit) for the nine months ended September 30, 2018 was $399, which decreased $420 from $819 for the nine months ended September 30, 2017 due to an increase in net taxable losses in foreign jurisdiction when comparing 2018 to 2017.

Results of Operations — Year ended December 31, 2017 compared with year ended December 31, 2016

Revenues

For the year ended December 31, 2017, the Miami Facility was available to produce LNG over 95.5% of the time. We have executed three contracts in 2016, three contracts in 2017 and one contract in the nine months ended September 30, 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 s ales

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 substantially reduce 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.

Cash (used in) operating activities

Our cash flow used in operating activities was $53,156 in the nine months ended September 30, 2018, which increased by $17,173 from $35,983 in the nine months ended September 30, 2017. For both nine month periods ended September 30, 2018 and 2017, 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 the increase in cash used in operations was attributed to increases in other operating assets accounts.

Cash (used in) investing activities

Our cash flow used in investing activities was $105,152 in the nine months ended September 30, 2018, which increased by $69,043 from $36,109 in the nine months ended September 30, 2017. The increase in cash flow used in investing activities is due to significant cash expenditures incurred in 2018 related to construction of the regasification terminal to support JPC’s Old Harbour Power Plant.

Cash provided by (used in) financing activities

Our cash flow provided by financing activities was $125,503 in the nine months ended September 30, 2018, which increased by $132,559 from $(7,056) in the nine months ended September 30, 2017. The increase in cash flow provided by financing activities is due to cash received from debt proceeds offset by cash payments of deferred financing costs and repayments of debt. In December 2017, the Company undertook an additional capital raise of $70,100 of which $50,000 of cash was received in January 2018. The Company also issued 665,843 shares in January 2018 for $20,150 in proceeds. These capital contributions were offset by principal payments on the Miami Loan and the MoBay Loan of $4,371. On August 16, 2018, the Company entered into the Term Loan Facility to borrow an aggregate principal amount of $240,000. Through September 30, 2018, the Company had drawn $130,000 of the total available amount and used these proceeds to repay both the Miami Loan and the MoBay Loan.

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

Term Loan Facility

On August 16, 2018, the Company entered into a Term Loan Facility (as may be amended, from time to time, the “Term Loan Facility”) to borrow term loans, available in three draws, up to an aggregate principal amount of $240,000. On December 31, 2018, the Company amended its Term Loan Facility to, among other things, (i) increase the amount available for borrowing thereunder from $240,000 to $500,000, (ii) extend the initial maturity date to December 31, 2019, (iii) modify certain provisions relating to restrictive covenants and existing financial covenants, and (iv) remove the mandatory prepayment required with the net proceeds received in connection with an initial public offering. 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 highest 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 contains certain covenants that require additional contracted revenue to be obtained within certain time periods, and an event of default or additional fee payments may result if those targets are not met in the future. The Term Loan Facility is set to mature on December 31, 2019 and is repayable in quarterly installments of $1,250, 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 interest rate spread on LIBOR and Base Rate increases by 0.5%. To exercise each 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.

As of December 31, 2018, the total principal amount outstanding under the Term Loan Facility was $280,000. Future borrowing capacity of $220,000 under the Term Loan Facility is subject to a delayed draw feature that expires on February 15, 2019. We expect to borrow under the delayed draw prior to its expiration.

The Company used the net proceeds of the Term Loan Facility to repay the Miami Loan and the Mobay Loan in full during August 2018 and September 2018, respectively. The proceeds of the Term Loan Facility funded on or after December 31, 2018 will be used to make capital expenditures to complete the San Juan Facility, as well as for additional storage and regasification facilities for small-scale customers.

Following completion of this offering, we may opportunistically seek to refinance the Term Loan Facility, including to increase total available borrowings. We cannot assure you whether we will be able to successfully refinance such facility, or the final terms thereof, including the ability to increase amounts available for borrowing.

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 was the day immediately preceding the seventh anniversary of the drawdown date of such loan.

Outstanding amounts under the MoBay Loan accrued interest at a per annum rate of 8.10%. The MoBay Loan could 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 during the one year period from the date of the first loan drawdown of the MoBay Loan, or 1% of any amount being prepaid 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.

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 nine months ended September 30, 2018 and 2017, totaled $2,402 and $2,735 respectively. 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. The Company was subject to a prepayment fee of 1% on the MoBay Loan, and paid $345 in September 2018 to lenders in conjunction with the repayment of the MoBay Loan. Unamortized deferred financing costs recorded as a reduction in long-term debt at the time of the repayment were $1,404. These unamortized deferred financing costs were written off in conjunction with the repayment and included within Loss on extinguishment of debt along with the prepayment penalty.

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 bore 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 highest 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 could be extended for an additional term of up to 18 months.

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 required 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, could elect to defer up to ten interest periods outstanding at any point in time. The Miami Loan also required annual amortization in an amount equal to 1% of the amount outstanding. The Miami Loan could be prepaid without penalty after the first anniversary of the closing of the Miami Loan. At the time of the extinguishment of the debt in August 2018 and as of the years ended December 31, 2017 and 2016, interest was calculated based on 7.58%, 6.57% and 6.00%, as of the end of each respective period. Interest expense, inclusive of amortized debt fees for the nine months ended September 30, 2018 and 2017, totaled $1,989 and $2,106, 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.

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. The outstanding principal balance at the time of the repayment was $38,707; the Company agreed to repay lenders $37,255 to extinguish the liability, and as such, a gain on extinguishment of $1,452 was recorded within Loss on extinguishment of debt. The gain was partially offset by the write-off of unamortized deferred financing costs recorded as a reduction in long-term debt of $321.

Off Balance Sheet Arrangements

As of September 30, 2018 and 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.

As of September 30, 2018, there have been no material changes to the commitments and contractual obligations table above outside the ordinary course of business, except as noted below.

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 as of 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 been reflected in the table above. On December 31, 2018, the Company amended its Term Loan Facility as described under “—Liquidity and Capital Resources—Long-Term Debt.” As of December 31, 2018, the Company has borrowed $280,000 under the Term Loan Facility with a scheduled maturity of December 31, 2019. Future borrowing capacity of $220,000 under the Term Loan Facility is subject to a delayed draw feature that expires on February 15, 2019. We expect to borrow under the delayed draw prior to its expiration. Principal payments of $1,250 are due each quarter; the Company will be required to pay the remaining principal balance on the maturity date. Based on the interest rate of 6.19% in effect as of September 30, 2018, 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. Following the completion of this offering, we may opportunistically seek to refinance the Term Loan Facility, including to increase total available borrowings. We cannot assure you whether we will be able to successfully refinance such facility, or the final terms thereof, including the ability to increase amounts available for borrowing.

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 GSA agreement with an affiliate of Chesapeake Energy Corporation (“Chesapeake”), a large exploration and production company, for gas supply to our 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 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. The terms of the agreement require the Company to obtain all requisite permits and make a final investment decision before the agreement is effective.

In December 2018, the Company entered into a contract with Centrica LNG Company Limited for the purchase of cargoes of 1.1 billion gallons of LNG (86.8 million MMBtu) scheduled for delivery between June 2019 and December 2021. Payment for each cargo is due in advance of each shipment.

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 additional 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 $21,871. Fixed lease payments under these leases are expected to be approximately $18,193 over the respective lease terms and some of these leases contain variable components based on LNG processed.

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.

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