Jersey Oil & Gas today announced a significant increase in 2C contingent resource estimate for the Buchan oil field, within the Greater Buchan Area ("GBA").

Dynamic reservoir modelling of the P50 stock tank oil initially in place ("STOIIP") case has recently been completed by Schlumberger Oilfield UK Plc ("Schlumberger"), using their proprietary INTERSECT high resolution reservoir simulator.  Such new and comprehensive dynamic models provide a robust forecast for the P50 case for the Buchan oil field, having fully incorporated all available subsurface information and successfully history matched 36 years of production data. This project workstream has now been independently peer reviewed as part of a wider scope reviewing the development concept by Vysus Group (formerly Lloyds Register's Energy Business), a global engineering and technical consultancy.

Subsurface Highlights:

Dynamic reservoir modelling has determined that the P50 estimate of the technically recoverable resources for the Buchan oil field is 126 million stock tank barrels ("MMstb"), representing an increase of over 50% on previous estimates derived from decline curve analysis:

• The new dynamic model used inputs from the high resolution 2018 PGS 3D seismic survey data, together with the static and dynamic well data and field production history
• The Buchan sandstone reservoir is a well-connected, dual porosity and permeability system
• Buchan oil quality is light sweet crude at 33.5° API
• The expected ultimate recovery factor is 54% of original oil in place, with historic field production having recovered 29% of the P50 STOIIP estimate
• Planned future production will be achieved using optimally located deviated wells placed high in the structure with water injection

GBA development project update:

• As a result of this increase, the GBA core volume, including the Buchan oil field and volumes from the J2 and Verbier oil discoveries, is now forecast to have 2C contingent resources of 162 MMstb or 172 million barrels of oil equivalent ("MMboe") including associated gas
• Preliminary economics for the GBA core development, which includes Buchan, J2 and Verbier are very encouraging - higher volumes serve to reduce unit costs and drive economic efficiencies
• Having selected our preferred development concept for the GBA hub development, management is now finalising the Concept Select report and economics for submission to the OGA ("Oil and Gas Authority") with the aim of commencing FEED in Q3 2021
• The Company continues to advance its technical and economic evaluation work in respect of electrifying the GBA in order to make it a low carbon emissions project
• Today's increase in volumes comes ahead of the anticipated launch of the Company's GBA farm-out process later this quarter seeking to attract industry partnership to join JOG in unlocking the significant value that exists within this very exciting major North Sea area hub development project

Andrew Benitz, CEO of JOG, commented:
"I am delighted with the results of dynamic modelling which result in an increase in the estimated contingent resource volumes of light sweet crude in the proven, conventional reservoir at Buchan by over 50%. These compelling results demonstrate the substantial inherent value of the Buchan field and the wider GBA development.

"We recognised the potential of Buchan at an early stage and have maintained our strategic focus on this area in the heart of the Central North Sea with the benefit of aggregation of high value assets becoming self-evident. The GBA development project presents a very compelling investment case that we believe will have wide industry appeal.  We look forward to formally engaging with industry in due course and attracting the right industry partnership aligned and committed to the GBA's future success."

Buchan oil field (JOG 100% W.I.)

The Buchan oil field was discovered by well 21/1-1, drilled by Transworld Petroleum and Texaco in 1974 into a pronounced and relatively elevated horst block at the eastern end of the Buchan Horst.

The well encountered a significant oil column, in excess of 900 ft, in fractured, Upper Old Red Sandstone that flowed 890 bopd on test. The reservoir was significantly over-pressured at 3,400 psi above hydrostatic pressure. The oil is sweet and under-saturated with an average GOR of 285 scf/stb and gravity of 33°API. Subsequent appraisal drilling tested up to 5000 bopd on test (21/01-2) and demonstrated an oil column in excess of 1,900 ft (well 21/1a-6). The field was brought into production by BP in 1981 with nine development wells and initial production peaked at 54,537 bopd.

The field exceeded all initial production expectation and 148 mmstb of oil have been produced under natural depletion with aquifer support to the cessation of production (COP) in May 2017.

The reservoir pressure has over time declined by 5,000psi but has been relatively stable at approximately 2500 psi from 1992 to the COP. Oil production continued until May 2017, when the Buchan Alpha platform was shut in for safety reasons relating to the platform infrastructure.

The licence is classified as a straight to Second Term licence with a four year duration to submit for approval a Field Development Plan (FDP) for the re-development of the Buchan oil field and the development of the J2 (well 20/5a-10y) oil discovery.

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