- higher crude transportation fuels Enbidge's profit beat; Reuters;
- Enbridge reports strong third quarter 2019 results; press release;
- dividend remains unchanged (reported two days ago)
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Back to the Bakken
Active rigs:
| $56.38 | 11/8/2019 | 11/08/2018 | 11/08/2017 | 11/08/2016 | 11/08/2015 |
|---|---|---|---|---|---|
| Active Rigs | 54 | 66 | 53 | 38 | 64 |
These wells are yet to report this week --
Friday, November 8, 2019: 28 for the month; 123 for the quarter:
- 35691, conf, CLR, Hereford Federal 15X-17HSL, Elm Tree, producing and a big well;
- 35440, conf, Hess, GO-Elvin Garfield-156-97-1918H-8, Dollar Joe, no production data,
- 36353, conf, Abraxas, Jore Yellowstone 2H, North Fork, no production data,
- 35441, conf, Hess, GO-Elvin Garfield 156-97-1918H-9, Dollar Joe, no production data,
- 35294, conf, BR, Prairie Rose 1A MBH-ULW, Corral Creek, producing, albeit not much;
- 35437, conf, Hess, GO-Elvin Garfield 156-97-1918H-1, Dollar Joe, no production data,
- 35283, conf, Enerplus, Mulberry 149-93-21B-22H-TF, Mandaree, producing, a nice well;
- 34947, conf, Whiting, Moline 41-15-1H, Tyrone, producing, a nice well;
- 34926, conf, CLR, Collison 9-23H1, Avoca, another nice Collison well in the Avoca oil field;
A number of proposed liquefaction plants and LNG export terminals along the U.S. Gulf Coast are racing to secure regulatory approvals and line up sales and purchase agreements, all in the hope of reaching final investment decisions before their rivals. Yet, these Texas and Louisiana projects now face competition from a facility that would be sited more than 3,000 miles away, in the icy waters just off the North Slope of Alaska. Qilak LNG would use a “near-shore” liquefaction plant in the Beaufort Sea off Point Thomson, AK, to supercool the region’s nearby, abundant and now largely stranded supplies of natural gas, load the resulting LNG onto ice-breaking carriers, and use these carriers to make shuttle runs to and from LNG customers in Asia. Today, we review the Qilak LNG project and the economic and logistic rationales driving it.
The state of Alaska and producers along its North Slope near Prudhoe Bay have a crude oil and natural gas problem on their hands. On the crude side, production from the Alaska North Slope (ANS) region peaked at 2 MMb/d in 1988 — 11 years after the 2.1-MMb/d Trans Alaska Pipeline System (TAPS) from the North Slope to Valdez, AK, was completed. Since then, ANS oil output has been declining steadily; in 2018, it averaged only 464 Mb/d, according to the Energy Information Administration (EIA), and in the first eight months of 2019, ANS production fell to less than 450 Mb/d.
As flows through TAPS ratchet down below 550 Mb/d, more and more mitigation is needed to keep the oil moving through the pipe due to freezing, wax buildup and other problems that come with lower flows. Worse yet, if and when volumes on TAPS fall much below 350 Mb/d, all bets would be off on whether the pipeline could continue to operate without a major re-do.
Then there’s the gas conundrum. North Slope oil fields also produce large volumes of associated gas, and while mixed NGLs can be removed from the gas stream and sent down with the crude on TAPS, there’s no way to market the remaining natural gas. The ANS gas is stranded. Literally stuck in the middle of nowhere because plans for a big gas pipeline from the North Slope to the Lower 48 never gained traction. Fortunately, there’s been a good local use for the gas: every day, about 8 Bcf is re-injected into the ANS oil fields to help maintain pressure and force more oil to the surface. Enhanced oil recovery, in other words. But for reasons too complicated to get into here, the re-injected gas does less and less good as the amount of oil still in the ground declines.
With declining oil production — and declining state revenues from that production — there’s been a big push on for several years now to finally make use of at least some of the many trillions of cubic feet of gas that have been re-injected into the ANS oil fields.
The state’s Alaska Gasline Development Corp. (AGDC) and three energy companies (ExxonMobil, BP and Conoco) had been working together to advance the $45-billion-plus Alaska LNG project, which would process 2.5 Bcf/d of North Slope natural gas; transport it 800 miles through a new, 42-inch-diameter pipeline to Nikiski, AK, on Cook Inlet on the Kenai Peninsula south of Anchorage; supercool the gas into LNG at a new three-train, 17.4-million-metric-ton-per-annum (MMtpa) liquefaction complex; and ship the LNG to Asian buyers. In 2016, though, the three energy companies decided not to provide financial support for the next phase of the project (namely, front-end engineering design, or FEED), leaving AGDC as the sole entity still working on it.
Which brings us to Qilak LNG, a North Slope liquefaction and LNG export project that is being developed by an affiliate of Lloyds Energy.
(Qilak, an Inupiat word for the environment — land, sea and sky — is pronounced KEE-lack.)
The proposed first phase of the project calls for the development of a 4-MMtpa liquefaction plant that would be constructed in a shipyard in Japan, South Korea or China, then floated to a site a few miles off the coast of Point Thomson in waters deep enough to receive large LNG carriers. The development of a second and third plant of identical design off Prudhoe Bay, AK (just west of Thomson Point) and the Mackenzie Delta (just across the Alaska-Canada line Northwest Territories) is possible, if project economics and LNG demand warrant.Much more at the link.
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