The recent downgrade of Hurricane Energy's Lancaster field recoverable reserves estimates has led Norwegian energy intelligence Rystad Energy to revise its expectations for the UKCS overall and say that the basin might never again hit output levels of more than 2 million barrels of oil equivalent a day.
Rystad has said that oil and gas output in the United Kingdom’s continental shelf (UKCS) has declined steadily since its peak at 4.3 million barrels of oil equivalent per day (boepd) in 1999, "never exceeding 2 million boepd after 2010."
However, promising exploration results by Hurricane Energy in fractured basement reservoirs, previously untapped in the UK, were until earlier this year expected to revive the country’s output to 2.1 million boepd by 2035, according to Rystad Energy’s estimates. Now, Rystad says, those hopes have been dashed.
To remind, a technical committee recently examined possible geological and reservoir models for the Lancaster field and found that estimated recoverable reserves, assuming no remedial action, have been reduced from 37.3 million barrels to 16 million, of which 6.6 million have already been produced.
"Major Blow"
"A recent jaw-dropping downgrade of Hurricane Energy’s Lancaster field revealed that the reservoir is more complex than previously thought. The result is a drastic resource downgrade for the company’s entire asset portfolio, as all its resources lie in fractured basement reservoirs. This is a major blow to the outlook for the UK’s future petroleum production, as fractured basement resources were estimated to account for nearly one-fifth of the future oil and gas output from the UKCS," Rystad said.
The downgrade has incited Rystad Energy to revise its production forecast for the UKCS.
"Our projections now show that production will never again exceed the threshold of 2 million boepd but will instead reach a maximum of 1.7 million boepd in 2035 before dwindling to nearly nothing by the middle of the century. UKCS production stood at 1.65 million boepd last year and is set to fall to 1.59 million boepd in 2020," Rystad said.
Entire UKCS output forecast affected
"The entire UKCS long-term production forecast has been impacted quite significantly. The main takeaway here is that we may never again see any significant production upsurge in UKCS production. A possible game-changer could now only be a development of technical skills for producing from fractured basement reservoirs to increase the recovery factor,“ says Olga Savenkova, upstream analyst at Rystad Energy.
Basement plays on the UKCS were largely ignored in terms of evaluation and investment until Hurricane Energy emerged in 2004, founded on the belief that these complex reservoir systems were a significantly untapped resource in the North Sea.
Hurricane
In its press statement released Thursday, Rystad Energy provided a detailed history and analysis of Hurricane Energy's Lancaster adventure.
Rystad wrote:
"Hurricane first embarked on an exploration campaign to prove the producibility of the Lancaster fractured basement and has since announced robust results of more than 2 billion barrels of oil equivalent (boe) in fractured basement reservoir resources believed to be discovered.
Lancaster became the UK’s first fractured basement field in 2015 and is located on the Rona Ridge in the West of Shetland area. The reservoir is penetrated by six wells, the first of which was drilled in 1974. This first well-encountered oil in the basement reservoir, but as the basement was not the drilling target the potential was discounted at the time.
In 2009, Hurricane embarked on an exploration campaign to prove the producibility of the Lancaster fractured basement. Since then, Hurricane has drilled 11 wells across its licenses in the area and announced four fractured basement discoveries: Lancaster, Lincoln, Halifax and Warwick West. Hurricane is so far the only company in the UK that has drilled into a fractured basement.
The first phase of development of the Rona Ridge assets, the Lancaster early production system (EPS), was brought on stream in 2019. However, production data from the Lancaster EPS didn’t confirm original expectations on reservoir properties. The reservoir pressure fell more rapidly than anticipated, which lead to a substantial resource downgrade across the fractured basement portfolio.
The downgrade has slashed Hurricane’s estimated resources by nine-tenths and triggered the stock to plummet. The total 2P+2C resource estimate for fractured basement resources dropped to 0.2 billion barrels of oil equivalent from the 2.3 billion boe reported by Hurricane in its 2017 competent person’s report (CPR).
The recovery estimate for the two existing wells at Lancaster EPS, assuming no further activity, has been more than halved by Hurricane Energy, to 16.0 million barrels from 37.3 million barrels. The remaining 2P reserves on 1 September 2020 are estimated to be 9.4 million barrels. Reflecting these new technical interpretations, the estimate of 2C contingent resources at Lancaster has been reduced to 58 million barrels remaining from 486 million barrels in the 2017 CPR."
"The 2C resources for the basement alone at the Lincoln field were reduced to 45 million barrels. Resource revisions for Halifax have not yet been communicated but, based on the Lancaster revisions, we now estimate these resources to 88 million barrels – a game-changing reduction from the previous 1.235 billion barrels," Rystad said.
According to Rystad, basement reservoir developments are recognized throughout the world as oil-bearing and commercially productive, yet remain largely overlooked.
"Currently, more than 100 fields are producing from basement reservoirs, but the volumes produced are comparatively small as fractured basement reservoirs have low porosity and low-permeability rock. The rock is generally unable or very poorly suited to store hydrocarbons, but weathering and movements in the rock have created fractures where hydrocarbons can be stored and move inside the rock," Rystad said.
"To better understand the fracture network size and thus the reservoir size and oil volumes, an extended well test over a longer period is an option. A shorter-duration test can say something about the reservoir quality and the achievable production rate but cannot determine the size of the reservoir," Rystad explained.
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