Construction workers look on at the FortisBC Tilbury LNG expansion project in Delta, B.C., Monday, Nov. 16, 2015. CP Images photo

From the Canadian Energy Centre

By Ven Venkatachalam

Lower costs for natural gas, shipping and liquefaction give Canada an edge in the emerging global LNG market

Worldwide concerns about energy security have put a renewed focus on the international liquefied natural gas (LNG) industry. The global demand for LNG is expected to increase over the next few decades.

Global demand growth will be driven primarily by Asian markets where the need for LNG is expected to increase from 277 million tonnes (MT) in 2025 to 509 MT by 2050 (see Figure 1). By 2050 the demand for LNG in Europe will be 83 MT and in Africa 20 MT. In South America too, demand will increase – from 13 MT in 2025 to 31 MT in 2050.

Source: Derived from Rystad Energy, Gas and LNG Markets Solution.

In North America (Canada, Mexico, and United States) a number of LNG projects that are either under construction or in the planning stages will benefit from the rise in global LNG demand.

North American LNG production is expected to grow from 112 MT in 2025 to over 255 MT by 2050 (see Figure 2). In Canada, the LNG projects under construction or in the planning stages include LNG Canada Phases 1 & 2, Woodfibre LNG, Cedar LNG, the Tilbury LNG expansion, and Ksi Lisims LNG. Canada’s LNG production is expected to grow from just 2 MT in 2025 to over 43 MT by 2050. In the United States production is projected to increase from 108 MT in 2025 to 210 MT in 2050.

Source: Derived from Rystad Energy, Gas and LNG Markets Solution.

This CEC Fact Sheet uses Rystad Energy’s Gas and LNG Markets Solution¹ to benchmark the cost competitiveness of LNG projects that are under construction and proposed in Canada compared to other LNG projects under construction and planned elsewhere in North America. (Note that the content of this report does not represent the views of Rystad Energy.)

The LNG cost competitiveness benchmarking analysis used the following performance metrics:

• LNG plant free-on-board (FOB) cost break-even;
• Total LNG plant cost (for delivery into Asia and Europe).

The objective of this LNG cost competitiveness benchmarking is to compare the competitiveness of Canadian LNG projects against those of major competitors in the United States and Mexico. The selection of other North American LNG facilities for the benchmark comparison with Canadian LNG projects (LNG Canada, the Tilbury LNG Expansion, Woodfibre LNG, Cedar LNG, and Ksi Lisims LNG) is based on the rationale that virtually all Canadian LNG plants are under construction or in the planning stage and that they compare well with other North American LNG plants that are also under construction or are being planned between 2023 and 2050. Further, to assess the cost competitiveness of the various LNG projects more accurately, we chose only North American LNG facilities with sufficient economic data to enable such a comparison. We compared the cost competitiveness of LNG coming from these other North American projects with LNG coming from Canada that is intended to be delivered to markets in Asia and Europe.

1. Rystad Energy is an independent energy research company providing data, analytics, and consultancy services to clients around the globe. Its Gas and LNG Markets Solution provides an overview of LNG markets worldwide. The Solution covers the entire value chain associated with gas and LNG production, country and sector-level demand, and LNG trade flows, infrastructure, economics, costs, and contracts through 2050. It allows for the evaluation of the entire LNG market infrastructure, including future planned projects, as well as the benchmarking of costs for LNG projects (Rystad Energy, 2024).

Comparison of LNG project FOB cost break-even (full cycle)

Figure 3 provides a comparison of the free-on-board (FOB) cost break-even for LNG facilities under construction or being planned in North America. FOB break-even costs include upstream and midstream costs for LNG excluding transportation costs (shipping) as seen from the current year. Break-even prices assume a discount rate of 10 percent and represent the point at which the net present value for an LNG project over a 20- to 30-year period becomes positive, including the payment of capital and operating costs, inclusive of taxes.

Among the selected group of North American LNG projects are Canadian LNG projects with an FOB break-even at the lower end of the range (US$7.18 per thousand cubic feet (kcf)) to those at the higher end (US$8.64 per thousand cubic feet (kcf)).

LNG projects in the United States tend to settle in the middle of the pack, with FOB break-even between US$6.44 per kcf and US$8.37 per kcf.

Mexico LNG projects have the widest variation in costs among the selected group of projects, ranging from US$6.94 per kcf to US$9.44 per kcf (see Figure 3).

Source: Derived from Rystad Energy, Gas and LNG Markets Solution.

Total costs by project for LNG delivery to Asia and Europe

The total cost by LNG plant includes FOB cost break-even, transportation costs, and the regasification tariff. Figure 4 compares total project costs for LNG destined for Asia from selected North American LNG facilities.

Canadian LNG projects are very cost competitive, and those with Asia as their intended market tend to cluster at the lower end of the scale. The costs vary by project, but range between US$8.10 per kcf and US$9.56 per kcf, making Canadian LNG projects among the lowest cost projects in North America.

The costs for Mexico’s LNG projects with Asia as the intended destination for their product tend to cluster in the middle of the pack. Costs among U.S. LNG facilities that plan to send their product to Asia tend to sit at the higher end of the scale, at between US$8.90 and US$10.80 per kcf.

Source: Derived from Rystad Energy, Gas and LNG Markets Solution.

Figure 5 compares total project costs for LNG to be delivered to Europe from select North American LNG facilities.

Costs from U.S. LNG facilities show the widest variation for this market at between US$7.48 per kcf and US$9.42 per kcf, but the majority of U.S. LNG facilities tend to cluster at the lower end of the cost scale, between US$7.48 per kcf and US$8.61 per kcf (see Figure 5).

Canadian projects that intend to deliver LNG to Europe show a variety of costs that tend to cluster at the middle to higher end of the spectrum, ranging from US$9.60 per kcf to and US$11.06 per kcf.

The costs of Mexico’s projects that are aimed at delivering LNG to Europe tend to cluster in the middle of the spectrum (US$9.11 per kcf to US$10.61 per kcf).

Source: Derived from Rystad Energy, Gas and LNG Markets Solution.

Conclusion

LNG markets are complex. Each project is unique and presents its own challenges. The future of Canadian LNG projects depends upon the overall demand and supply in the global LNG market. As the demand for LNG increases in the next decades, the world will be searching for energy security.

The lower liquefaction and shipping costs coupled with the lower cost of the natural gas itself in Western Canada translate into lower prices for Canadian LNG, particularly that destined for Asian markets. Those advantages will help make Canadian LNG very competitive and attractive to markets worldwide.

From the Daily Caller News Foundation

By DAVID BLACKMON

For two years now, I and others have been pointing out the reality that there is no real “energy transition” happening around the world. Two new items of information came to light this week that irrevocably prove the point.

It is true that governments across the western world appear to be working to bankrupt their countries by pouring trillions of debt-funded dollars, Euros and British pounds into central planning efforts to subsidize renewables and electric vehicles into existence. That reality cannot be denied. The trouble is that no amount of debt money can turn the markets and the markets aren’t cooperating.

Despite all the government largesse that has spurred major additions of wind and solar generation capacity, those weather-reliant energy sources can’t even keep up with the pace of rising demand for electricity. As a result, the markets dictated that the world consumed record levels of coal, natural gas, oil and even wood during 2023. Yes, we are still burning vast amounts of wood for electricity, despite an alleged “transition” from wood to coal which began 500 years ago.

That is reality, dictated by the markets.

Two new bits of data came to light this week that pound the final nails into the coffin of the narrative around the energy transition. A report in the Financial Times, citing data compiled by Grid Strategies, reveals that the buildout of new high-voltage transmission lines in the United States slowed to a trickle in 2023, with just 55.5 additional miles installed. That collapse comes despite the Biden government’s recognition that a massive expansion of this type of transmission lines must happen to accommodate the demands of any true “transition” to renewables.

The Financial Times quotes a 2023 assessment by the Department of Energy that found that “regional transmission must more than double and interregional transmission must grow more than fivefold by 2035 to meet decarbonization targets.” DOE admits such a pace would add more than 50,000 miles of new transmission in just 11 years, which is almost 1,000 times the pace of adds during 2023. Yikes.

A crucial aspect of that DOE study to understand is that it was conducted before we began to understand the true magnitude of additional power demands that will result from the explosive growth of AI technology just now starting to come to full bloom. It was just this past January, at the WEF Forum in Davos, where OpenAI CEO Sam Altman told the audience he believes generation capacity on the grid will have to double over the next decade just to fill the AI demands alone. That is what is needed in addition to the rising demands for EV charging, industrial growth, population growth and economic growth.

The second piece of compelling data arising this week comes from a Bloomberg story headlined, “Data Centers Now Need a Reactor’s Worth of Power, Dominion Says.” The key thing to understand about this story is that the piece is only referencing the needs of planned new data centers being built in Northern Virginia to feed AI development in that tiny sliver of the United States.

This key excerpt from the story says it all: “Over the past five years, Dominion has connected 94 data centers that, together, consume about four gigawatts of electricity, Blue said. That means that just two or three of the data center campuses now being planned could require as much electricity as all the centers Dominion hooked up since about 2019.”

That is not just rapid growth, it is exponential growth in power demand from a single developing technology.

Demand growth needs such as this aren’t going to be filled by unpredictable, unreliable, weather-dependent generation like windmills and solar arrays. And let’s face it: The United States is not going to be able to continue expanding renewables without finding some way to create a massive expansion of transmission. Why build the generation if you can’t move the electricity?

What it all means is that all the grand Biden Green New Deal plans to shut down America’s remaining coal fleet and much of its natural gas generation fleet are going to have to wait, because the market will not allow them. That’s reality, and reality does not care about anyone’s green transition dreams.

David Blackmon is an energy writer and consultant based in Texas. He spent 40 years in the oil and gas business, where he specialized in public policy and communications.

The views and opinions expressed in this commentary are those of the author and do not reflect the official position of the Daily Caller News Foundation.