Alaska officials, concerned the state’s once-dominant role in U.S. energy production will continue slipping, are taking a fresh look at helping to jump-start a combined natural gas treatment plant, gas pipeline and LNG export project that would free vast volumes of natural gas now stranded at the state’s North Slope. A new study commissioned by the state found that it could make sense for Alaska to take a 20% or higher equity stake in the project, but that there are significant risks the state would need to mitigate. Today we look at whether the 49th state can make a long-stalled plan by producers to move North Slope gas to market a reality by the mid-2020s.
Ask any American about Alaska and one of the first things that will come to mind is oil, and the oil pipeline that was built in the 1970s to move crude south from the North Slope’s Prudhoe Bay. “Alaskan natural gas” doesn’t roll off most tongues. But as we explored a few months ago in “’Some Plans Are Bigger than Others’—Alaska LNG Exports” the North Slope has some of the world’s biggest gas reserves. The Alaska Department of Natural Resources (ADNR) estimates there are 200 Tcf of unproven and 35 Tcf of proven conventional gas reserves onshore and offshore on the North Slope’s Prudhoe Bay and Point Thomson areas and in waters off the north coast of Alaska. Still, despite years of talk about possible gas pipelines, there is still no outlet—no way out--for all that gas. Instead, Prudhoe Bay producers continue to re-inject 8 Bcf/d of gas into oil wells.
Since the 1970s there has been hope of piping North Slope gas south to the Lower 48, but the last of those plans dried up by 2011-12 after the shale revolution led to the development of major new gas resources in the Barnett, Marcellus, Haynesville and other shale plays much closer to U.S. gas users. That shifted the discussion among Alaska energy giants like ExxonMobil, ConocoPhillips and BP—and TransCanada, which has been working with the state under the Alaska Gas line Inducement Act--to the idea of building about 800 miles of south-bound gas pipeline, a gas treatment plant, and an LNG export terminal in south-central Alaska (see Figure 1).
Source: Alaska Gas Pipeline Project Office (http://gasline.alaska.gov/) Click to Enlarge
The primary market for the resulting LNG would be Asia, which buys about 70% of the LNG produced worldwide and whose LNG demand curve has been rising 8%/year the past five years. The catch is, the capital costs associated with all the required infrastructure are high—even by energy industry standards—and gas/LNG producers from Qatar, Australia, western Canada and the Lower 48 already are racing to reach long-term supply deals with Asia’s largest gas consumers. Time’s a-wasting, as they say, and in recent months there has been a new push to assemble the complex financial package needed to make Alaska’s gas export dreams finally happen.
Just last week (week of November 17), a top executive at ExxonMobil laid out the project’s challenges at the Alaska Resource Development Council Conference, and ADNR released a Black & Veatch study it commissioned on how the state might change its gas royalties or taxes—or even take an equity stake in the treat-pipe-and-export project—to help make the project a “go.” Two primary challenges the project faces, ExxonMobil said, are:
- LNG projects with a capacity equivalent to more than 50 Bcf/d are being planned around the world, but less than 40 Bcf/d of additional LNG capacity is likely to be needed by 2030 to keep pace with expected LNG demand growth.
- Big LNG customers prefer to enter into supply deals with LNG exporters whose terminals and other infrastructure can be built quickly, because that reduces the risk of entering into a long-term LNG supply deal based on too-high prices. The Alaska project would likely take five years or more to come online from the time of final investment decision (FID). The target FID for the Alaska project is 2017-18, with a commercial operation date of 2023-24, or several years behind the first group of LNG exports terminals planned for the U.S. Gulf Coast, West Coast and western Canada.
Black & Veatch said in its study that the Prudhoe Bay and Thomson Point areas have the gas reserves to supply the project’s total needs, at least into the early 2040s, and by then those reserves could almost certainly be supplemented with new, “yet-to-find” fields nearby (see Figure 2). It also said the international LNG market is “illiquid” and “opaque,” with few participants and based primarily on long-term, 20-year-plus contracts. And, it said, the Alaska project would be costly: $10 billion for the gas treatment plant; $12 billion for a 42-inch diameter pipeline with eight compressor stations; and $23 billion for a three-train, 17.4 Mtpa liquefaction plant and export facility.
To access the remainder of “Might As Well Jump”—Will Alaska Jump-Start Gas Exports? you must be logged as a RBN Backstage Pass™ subscriber.
Full access to the RBN Energy blog archive which includes any posting more than 5 days old is available only to RBN Backstage Pass™ subscribers. In addition to blog archive access, RBN Backstage Pass™ resources include Drill-Down Reports, Spotlight Reports, Spotcheck Indicators, Market Fundamentals Webcasts, Get-Togethers and more. If you have already purchased a subscription, be sure you are logged in For additional help or information, contact us at [email protected] or 888-613-8874.