Jump to content

Lancaster oilfield

Add links
Coordinates: 60°11′N 3°52′W / 60.183°N 3.867°W / 60.183; -3.867
From Wikipedia, the free encyclopedia

This is an old revision of this page, as edited by Citation bot (talk | contribs) at 01:48, 5 June 2022 (Alter: title. | Use this bot. Report bugs. | Suggested by Abductive | Category:Wikipedia articles in need of updating from May 2022 | #UCB_Category 492/687). The present address (URL) is a permanent link to this revision, which may differ significantly from the current revision.

Lancaster oilfield
Lancaster oilfield is located in North Sea
Lancaster oilfield
Location of Lancaster oilfield
CountryUnited Kingdom
RegionUnited Kingdom territorial waters
LocationWest of Shetland
Block205/21a, 205/22a, 205/26b and 205/22b
Offshore/onshoreoffshore
Coordinates60°11′N 3°52′W / 60.183°N 3.867°W / 60.183; -3.867
OperatorHurricane Energy
Field history
Discovery2009
Start of developmentNovember 2016
Start of productionJune 2019
Production
Current production of oil13,300 barrels per day (~6.63×10^5 t/a)
Estimated oil in place3,333 million barrels (~4.547×10^8 t)
Producing formationsNaturally fractured Precambrian age granitic basement

The Lancaster oilfield is an offshore oil field in Scottish territorial waters 100 kilometres (62 mi) west of Shetland and 170 kilometres (110 mi) north of mainland Scotland in water depths of around 155 metres (509 ft). It comprises licence blocks 205/21a, 205/22a, 205/26b and 205/22b in Licence P1368 (Central), all of which are fully owned by Hurricane Energy.[1] It is the first naturally fractured basement oilfield in the United Kingdom Continental Shelf to reach production.

History

Exploration well 205-21-1A was drilled in 1974 by Royal Dutch Shell. It discovered light oil in naturally fractured Precambrian age granitic basement but was plugged and abandoned.[2] This was the first well drilled by semi-submersible rig Ocean Voyager after construction. An astonishing feat West of Shetland in wintertime.

In 2009, Hurricane Energy drilled well 205/21a-4 much deeper into the naturally fractured basement and discovered a substantial column of light crude oil with 38° API and a flow rate of 1,367 barrels (217 m3) of oil per day. Subsequently, a sidetrack well, 205/21a-4Z, was drilled in 2010 which flowed light oil at 2,885 barrels (459 m3) of oil per day. The 205/21a-4 well was plugged and abandoned. The 205/21a-4Z well was suspended.

Well 205/21a-6 was drilled in 2014. This included a one kilometre horizontal section. It produced a natural flow rate of 5,300 barrels (840 m3) of oil per day. This increased to 9,800 barrels (1,560 m3) per day with an electric submersible pump ("ESP"). Both figures were constrained by surface equipment capabilities and it was reported that the well could deliver 20,000 barrels (3,180 m3) per day with a modest 120psi drawdown under production conditions.[3] The well had a very high productivity index[4] ("PI") of 160 stb/psi/d. It was suspended as a future producer.

Well 205/21a-7 was drilled in 2016 and produced 11,000 barrels (1,700 m3) of oil per day with an ESP. It was subsequently sidetracked as 205/21a-7Z to include a one kilometre horizontal section. This produced a natural flow rate of 6,520 barrels (1,037 m3) of oil per day or 15,375 barrels (2,444 m3) per day with an ESP, both of which were constrained by the test equipment used, and a very high PI of 147 stb/psi/d. It too was suspended as a future producer.[1][5]

Early Production System

In 2016, Hurricane committed to an Early Production System ("EPS") using the Aoka Mizu[6] Floating production storage and offloading vessel ("FPSO"), chartered from Bluewater Energy Services, for an initial six-year period with an option to extend to ten years.[7] This will be used to generate revenue and evaluate the reservoir properties over an initial testing period expected to take 6 to 12 months followed by a production period for the remainder of the duration. The results of the initial testing will inform decisions regarding potential full field development. The EPS utilises wells 205/21a-7Z and 205/21a-6. Revenue generated from oil sales will help to fund further activities in the Lancaster Field and the adjacent Halifax, Warwick and Lincoln fields.[1]

Reserves, contingent resources and initially in place volumes

The Competent Persons Report ("CPR") published by RPS Energy on May 8, 2017, provided the following estimates of reserves, contingent resources and initially in place volumes;[8]

  • Reserves
  • Contingent resources
    • 1C: 129.1 million bbl (21 million m3) of oil equivalent
    • 2C: 486.1 million bbl (77 million m3)
    • 3C: 1,116.7 million bbl (178 million m3)
  • Initially in place volumes
    • Low estimate: 1,571 million bbl (250 million m3) of oil equivalent
    • Best estimate: 2,326 million bbl (370 million m3)
    • High estimate: 3,333 million bbl (530 million m3)

These estimates will be re-assessed during 2020 and 2021 taking account of the findings from the Early Production System. In July 2020, Hurricane announced that the prospective resources might be materially downgraded as a result of experience with the Early Production System. An updated Competent Person's Report is expected to be published before the end of the first quarter of 2021. A further update is expected to be issued with Hurricane's interim financial results in September 2020.

First oil

The Aoka Mizu FPSO arrived at the Lancaster field on 17 March 2019. Two days later, it was successfully hooked-up to the turret mooring system buoy.[9] On 11 May 2019 hydrocarbons began flowing into the processing system of the Aoka Mizu. Following a 72-hour production test during which the planned production rate of 20,000 barrels (3,200 m3) of oil per day was achieved, a press release announcing first oil was issued on 4 June 2019.[10] When announcing first oil, Hurricane Energy forecast that production for the first three months would be 9,000 barrels (1,400 m3) of oil per day and 13,000 barrels (2,100 m3) per day for the following three months giving a combined average of 11,000 barrels (1,700 m3) of oil per day for the first six months with production being constrained by testing activities.[11]

Testing phase

This phase involves testing the two production wells individually and together. Early test results exceeded expectations. Substantially higher flow rates and PIs[4] were demonstrated.[12]

Each of the two production wells flowed at more than 16,500 barrels (2,620 m3) of oil per day without the need for ESP assistance. The natural flow rates were 211% higher than previous tests for the 205/21a-6 well and 153% higher than previous tests for 205/21a-7Z.

Well 205/21a-6 demonstrated a PI of 205 stb/psi/d (29.3% above previous tests) and well 205/21a-7Z demonstrated a PI of 190 stb/psi/d (28.1% above previous tests).

Production from first oil until the end of 2019 averaged 13,300 barrels (2,110 m3) of oil per day[13] which was 20.9% higher than was forecast when first oil was announced. Production in 2020 was expected to be 17,000 barrels (2,700 m3) of oil per day, planned as 20,000 barrels (3,200 m3) per day at 85% uptime, which includes allowances for operational downtime and shut-ins for potential tie-ins and/or de-bottlenecking.[13] This was subject to review based upon the results of the ongoing testing phase.

The horizontal sections of the two wells are a few hundred meters apart and the natural fracture network is such that they effectively behave as a single well. Various combinations of flow rates were tested across the two wells including periods where one or both wells were shut in.

As production continued, the water cut in the 7Z well steadily increased. Although the horizontal section of this well is hundreds of meters long, the current production interval, which is near the heel of the well, coincides with a fracture containing what is currently believed to be perched water. As a result, Hurricane decided to shut in the 7Z well and test the 6 well by itself. Hurricane is considering options to relocate the production interval of the 7Z well away from the zone of perched water but any such scheme, which would require a drilling rig, is unlikely to take place during 2020. As a result of these issues, Hurricane has withdrawn production guidance for 2020.

In July 2020, Hurricane announced that ESPs had been commissioned on both wells and that production from the 7Z well had recommenced delivering a combined production of around 15,000 bopd.

Hurricane Energy is continuing to test and analyse the reservoir properties and expects to update its assessment of the Lancaster Field during 2020. This might materially reduce the prospective resources. Subsequently, an updated Competent Person's Report is expected to be published in the first quarter of 2021.

Future activities

The Oil and Gas Authority required that Hurricane Energy spuds at least one additional sub vertical well before 22 December 2021 in order to further establish the size of the Lancaster Field. In addition, consideration was being given to drilling another production well. If this happened, it would be tied back to the Aoka Mizu FPSO.[14] As a result of the COVID-19 pandemic, this date was extended by one year.

Design work to link the Aoka Mizu FPSO to the West of Shetland Pipeline ("WOSP") is ongoing. This will enable surplus natural gas to be transported to Sullom Voe Terminal in the Shetland Isles of Scotland for processing rather than being flared.[15]

The production capacity of the Aoka Mizu is forecast to increase to 35,000 barrels (5,600 m3) of oil per day in 2022,[16] planned as 40,000 barrels (6,400 m3) per day at 87.5% uptime. Some of this capacity is currently intended to be used for the adjacent Lincoln oilfield, in which Hurricane Energy has a 50% stake, pending full field development of that asset.[13]

A full field development final investment decision for the Lancaster Field depends on the outcome of the Early Production System test phase.[13] This may involve a farm-out or could be undertaken by Hurricane Energy itself.[17]

References

  1. ^ a b c "EVALUATION OF HURRICANE ENERGY PLC'S LANCASTER FIELD WITHIN LICENCE P.1368". hurricaneenergy.com. 2 May 2017.
  2. ^ Cannon, S. J. C.; Ellis, D. (9 June 2014). Hydrocarbon Exploration to Exploitation West of Shetlands. ISBN 9781862396524.
  3. ^ "Hurricane Energy : Post-Well Analysis: Lancaster Appraisal Well 205/21a-6 | MarketScreener". www.marketscreener.com.
  4. ^ a b "What is Productivity Index (PI)? - Definition from Petropedia".
  5. ^ "Released Well 205/21a-4, 4Z, 5, 5 RE". 17 November 2015.
  6. ^ "Aoka Mizu – Bluewater".
  7. ^ "Updated: Hurricane starts exploring options for full Lancaster development - News for the Energy Sector". 23 September 2019.
  8. ^ "Investegate |Hurricane Energy PLC Announcements | Hurricane Energy PLC: Publication of Competent Person's Report". www.investegate.co.uk.
  9. ^ Hurricane Energy plc (19 March 2019). "Operational Update: Hook-up of FPSO at the Lancaster Field" (PDF) – via q4europe.com.
  10. ^ Hurricane Energy plc (5 June 2019). "Operational Update: Lancaster EPS First Oil" (PDF) – via q4europe.com.
  11. ^ "Hurricane Energy has reached a very significant milestone at Lancaster field, but exploration results key". 5 June 2019.
  12. ^ "Investegate |Hurricane Energy PLC Announcements | Hurricane Energy PLC: Half-year Results 2019".
  13. ^ a b c d "Hurricane Energy set to generate US$165mln of 2019 revenue from Lancaster EPS". 13 December 2019.
  14. ^ Hurricane Energy plc (13 December 2019). "Trading and Operational Update & P1368 Licence Update" (PDF) – via q4europe.com.
  15. ^ "Hurricane updates west of Shetland basement developments". Offshore magazine. 20 September 2019.
  16. ^ "Corporate Presentation, Q3 2019". Hurricane Energy plc.
  17. ^ "Hurricane Energy is ticking all the boxes as it approaches major value catalysts". 17 May 2018.
Retrieved from "https://en.wikipedia.org/w/index.php?title=Lancaster_oilfield&oldid=1091560441"