P1368 Relinquishment Report 2019

P1368 Relinquishment Report 2019 HEX-LAN-ENG-REP-0045-A1

HUR-COR-OGA-REP-0003-1

24th February 2020

Produced by: Clare Slightam

P1368 Relinquishment Report 2019

2 of 30 HUR-COR-OGA-REP-0003-1 24 February 2020

Amendment Record

Revision Date Description Author Checked Approved

1 24/02/20 Revision following OGA comments CS OL RT

0 14/01/20 Final version CS OL RT

A0 03/01/20 Draft CS OL RT

Notes


24 February 2020 HUR-COR-OGA-REP-0003-1 3 of 30

Contents

1 Licence Information ........................................................................................................................ 5

2 Licence Synopsis .............................................................................................................................. 5

2.1 Equity Split .............................................................................................................................. 5

2.2 Licence Relinquishment .......................................................................................................... 5

3 Work Programme Summary ........................................................................................................... 6

3.1 Seismic .................................................................................................................................... 6

3.2 Wells ........................................................................................................................................ 6

4 Database ......................................................................................................................................... 7

5 Prospectivity Update ....................................................................................................................... 7

5.1 Whirlwind ................................................................................................................................ 8

5.2 Strathmore .............................................................................................................................. 8

5.2.1 Core description & Sedimentology ................................................................................. 9

5.2.2 Development Review ...................................................................................................... 9

5.3 Remaining Prospectivity ....................................................................................................... 10

6 Further Technical Work Undertaken ............................................................................................ 10

7 Resource and Risk Summary ......................................................................................................... 12

7.1 Whirlwind Discovery ............................................................................................................. 12

7.2 Strathmore Discovery ........................................................................................................... 12

7.3 Lower Cretaceous Fan Lead .................................................................................................. 12

8 Conclusions ................................................................................................................................... 13

9 Clearance ...................................................................................................................................... 13

10 Maps and Figures .......................................................................................................................... 14

List of Figures

Figure 1: Blocks operated by Hurricane 2005 – 2007 during the Initial Term of Licence P1368. Projection ED50 Zone 30N. ................................................................................................................... 14

Figure 2: Blocks operated by Hurricane in 2008 – 2011 during the Second Term of Licence P1368. Projection ED50 Zone 30N. ................................................................................................................... 15

Figure 3: Blocks operated by Hurricane 2011 – 2019 during the Third Term of Licence P1368. Projection ED50 Zone 30N...................................................................................................................................... 16

Figure 4: Licence subdivision during the third term. Projection ED50 Zone 30N. ................................ 17

Figure 5: Retained area of Licence P1368 in the third term. Projection ED50 Zone 30N. .................... 18

Figure 6: Seismic and well basemap for Licence P1368 as originally awarded. Projection ED50 Zone 30N. ....................................................................................................................................................... 19

Figure 7: Wells drilled by Hurricane on Licence P1368. Projection ED50 Zone 30N. ........................... 20



Figure 8: Top basement structure map over part of Licence P1368 (as awarded). Contour interval 200m, projection ED50 Zone 30N. ........................................................................................................ 21

Figure 9: Top basement structure map over Whirlwind Discovery. Wells shown in green; ODT contour from 205/22-1A also highlighted in green (3200m TVDSS). Note that the contour is constrained to the licence boundary at northern limit of Block 205/21a).......................................................................... 22

Figure 10: Illustrative cross-section through 205/22-1A and 205/21a-5 on Whirlwind showing the oil accumulation in both the Valhall Formation and basement in green. ................................................. 23

Figure 11: NW-SE seismic section through Whirlwind (PSTM). Oil shows in wells 205/21a-5 and 205/22-1A highlighted along with ODT from 205/22-1A. ................................................................................. 24

Figure 12: CPI over drilled interval of Valhall Formation and basement for 205/21a-5 ...................... 25

Figure 13: Strathmore Otterbank Sandstone depth map showing key wells ....................................... 26

Figure 14: NW-SE seismic section through (PSTM) through well 205/26a-3 showing the disposition of the Otterbank Sandstone relative to the Rona Ridge ........................................................................... 27

Figure 15: NW-SE PSDM seismic section across the East Solan Basin showing interpreted presence and pinch-out of the Aptian Fan within Block 205/26c. The southwestern part of the line ties to the Solan Field area. .............................................................................................................................................. 28

Figure 16: Aptian fan depth map, contour interval 25m showing interpreted closure as a polygon. Projection ED50 Zone 30N. ................................................................................................................... 29

Figure 17: Remaining prospectivity in the retained part of Licence P1368, Licence P2294 and Licence P2308 and relinquished areas of P1368. Projection ED50 Zone 30N. ................................................. 30

List of Tables

Table 5.1: Strathmore PVT properties used in the development review ............................................... 9

Table 6.1: Technical work undertaken on Licence P1368 ..................................................................... 11

Table 7.1: Contingent resources for the Whirlwind Discovery (oil case) .............................................. 12

Table 7.2: Contingent resources for the Whirlwind Discovery (gas condensate case) ........................ 12

Table 7.3: Contingent resources associated with the Strathmore Discovery in Block 204/30a ........... 12

Table 7.4: Lower Cretaceous Fan Lead potential recoverable volumes ............................................... 12



1 Licence Information

Licence Number: P1368

Licence Round: 23rd

Licence Type: Frontier

Block Numbers (Extension of Third Term): 205/21a, 205/22a, 205/26b

Award date: 22/12/2005

End of Initial Term: 22/12/2007

End of Second Term: 22/12/2011

Extension of Third Term: 16/12/2019

End of Third Term: 22/12/2024

Equity as of 16/12/2019:

P1368 Central: Hurricane (GLA) Ltd (100%); Current operator: Hurricane Energy Plc

P1368 South: Hurricane (GWA) Ltd (50%), Spirit Energy Ltd (50%); Current operator: Hurricane Energy Plc

Work Programme Summary:

• Shoot 450 km of 2D seismic data

• Acquire 600 km2 of 3D seismic data

• Reprocess 400 km of existing 2D seismic data

• Drill one well to a depth of 1100 m or to the Pre-Jurassic, whichever is the shallower

Licence Status: Extension of Third Licence Term

2 Licence Synopsis

2.1 Equity Split

Frontier Licence P1368 was awarded as part of the 23rd Licensing Round on December 22nd, 2005. A map showing the blocks awarded under this Licence can be seen in Figure 1. The original Licence was operated by Hurricane Exploration PLC with 50% equity, with Sunshine Oil PLC holding the remaining 50% interest. In June 2008 Hurricane obtained Sunshine’s share in the licence and became 100% licence holder and operator. Spirit Energy Ltd farmed into P1368 South with a 50% non-operated interest on 3/9/2018.

2.2 Licence Relinquishment

At the end of the Initial Term a relinquishment area was agreed with DECC (the mandatory relinquishment required after the first two years). The blocks retained for the Second Term were 204/30a, 205/21a, 205/22a and 205/26b, as shown in Figure 2. The blocks retained into the Third Term were a reduced area of the same blocks retained into the Second Term (Figure 3). Figure 4 shows the licence area retained into the Third Term with a redefined licence subdivision; Figure 5 shows the area retained in the extension of the third term.



This relinquishment report covers the areas surrendered during the third term at the point of licence extension. A relinquishment report was provided to DECC at the end of the Second Term.

3 Work Programme Summary

3.1 Seismic

Hurricane acquired over 1400 km2 of existing 3D seismic data over the licence area. This formed part of the PGS megasurvey 3D dataset. In addition, TGS shot 1520 km of long offset 2D on behalf of Hurricane. It was not considered necessary to reprocess the existing 2D data, so it was agreed with DECC that the additional 2D data that had been shot would substitute the reprocessing commitment made on application.

980 km2 of the PGS megasurvey was reprocessed in 2018 & 2019 by Shearwater. PSTM and PSDM volumes were both produced. The 3D reprocessing project did not form part of the licence work commitment.

3.2 Wells

Hurricane had one drill-or-drop commitment on Licence P1368. The decision was made to drill well 205/24-1 in August 2006, which met this commitment. In addition, Hurricane have drilled another eight wells on the licence which were not part of the original work commitment.

The wells drilled by Hurricane on Licence P1368 are as follows:

• 205/24-1 was drilled in 2006 on the Wellington Prospect with Hurricane Exploration Plc as Operator (50%) and Sunshine Oil Plc as a partner (50%). The well targeted a 3-way dip, fault bounded closure on the southern flank of the Rona Ridge. The primary reservoir target was the Upper Jurassic Rona Member. The well reached a TD of 1235 m MD in Triassic aged sandstone. Only trace oil shows were encountered in the Rona Member so the well was plugged and abandoned.

• 205/21a-4 was drilled in 2009 on the Lancaster Prospect, a large 4-way dip closure at basement level located at the crest of the Rona Ridge. It was operated by Hurricane Exploration Plc on a 100% basis. The primary reservoir target was the fractured Lewisian Basement. Oil shows were seen in both the basement and the overlying Lower Cretaceous Victory Formation. The well was tested and flowed light oil (38oAPI) at a maximum rate of 1,367 bopd from the fractured basement. However, flow rates were compromised due to a combination of mechanical problems and severe formation damage. Following testing, the well was suspended with a view to drilling a sidetrack.

• 205/21a-4Z was drilled as a sidetrack to 205/21a-4 in 2010 and was operated by Hurricane on a 100% basis. The purpose of the sidetrack was to determine deliverability for the fractured basement and to further evaluate the fracture properties. Oil was encountered in the Lewisian Basement and in the overlying Victory Formation. Under DST a maximum flow rate of 2,885 bopd of 38oAPI oil was recorded.

• 205/21a-5 was also drilled in 2010 on the Whirlwind Prospect. Whirlwind is a large (some 30 km2) 4-way dip closure at basement level located north of the Lancaster Field in a deeper structural setting. An oil column was encountered in the thick Lower Cretaceous Valhall Formation overlying the basement and within the basement. The well was suspended in 2010 for future re-entry for a DST. In 2011 a DST was undertaken and light volatile oil / condensate



was successfully flowed to surface from the open hole section. The well currently has a suspended completion status (AB1); it is anticipated that the well will be plugged and abandoned (AB3) within 1 year of the P1368 Deed of Variation (subject to boat availability, regulator approval, weather and board approval).

• 205/21a-6 is a horizontal appraisal well, drilled in 2014 on the Lancaster Field. Hurricane Energy plc were Operator of the well on a 100% basis. Light oil was encountered in the basement and overlying Victory Formation, and an open hole DST was conducted over the basement penetrated by the 8 ½” hole. Flow rates of 9,800 bopd were achieved using an ESP and 5,300 bopd under natural flow. 205/21a-6 is currently producing on the Lancaster Field.

• 205/21a-7 was drilled on the Lancaster Field in 2016 by Hurricane Energy plc on a 100% basis with Petrofac Facilities Management Limited (PFML) acting as the well operator. Light oil was encountered in the Victory Formation and Lewisian Basement. Stable flow rates of 10,930 stb/d were obtained using an ESP and 6,300 stb/d from natural flow. The well was sidetracked on completion of the DST.

• 205/21a-7Z was drilled on the Lancaster Field in 2016 by Hurricane Energy plc on a 100% basis, with PFML acting as the well operator. The well was sidetracked from the 205/21a-7 well and penetrated over 1 km of Lewisian Basement horizontally. Stable flow rates of 15,375 stb/d were achieved using an ESP and 6,520 stb/d under natural conditions. 205/21a-7Z is currently producing on the Lancaster Field.

• 205/26b-12 was drilled on the Lincoln Prospect by Hurricane Energy plc on a 100% basis, with PFML acting as the well Operator. Lincoln lies to the southwest of Lancaster on the Rona Ridge and is a 3-way dip fault bounded closure at basement level. Oil shows were observed in extensively fractured basement, and gas peaks were elevated throughout the basement section. No DST was carried out and the well was plugged and abandoned.

• 205/26b-14 was drilled in 2019 on Lincoln with partner Spirt Energy on a 50-50 basis; PFML acted as well operator. The well was drilled horizontally through the fractured Lewisian Basement to evaluate hydrocarbon properties and reservoir productivity. The well produced a stable rate of 9,900 bopd using an ESP and a stable natural flow rate of 5,140 bopd of dry, 41.5oAPI oil. It is currently left suspended in order to obtain interference data using memory gauges left downhole.

4 Database

A map of seismic and well data utilised by Hurricane for prospect evaluation is shown in Figure 6. Wells drilled by Hurricane, as listed in Section 3.2, are shown in Figure 7.

5 Prospectivity Update

Hurricane’s main objective when applying for Licence P1368 was to evaluate the hydrocarbon potential of the fractured Lewisian Basement; a top basement structure map is shown in Figure 8. However, there was reservoir potential identified in the Triassic sands as proven in the stranded Strathmore oil discovery. In the Jurassic, the Rona Sandstone has variable reservoir properties but numerous oil shows and a number of leads were identified which have since been discounted. Also of Jurassic age is the Solan Sandstone, which is the reservoir of the Solan Field in Block 205/26a. Within the Lower Cretaceous there is reservoir potential within both sandstones and limestones, whilst Upper



Cretaceous sands, if present, may also represent a viable target. For the basement, all of the identified prospectivity (Lancaster, Whirlwind, Lincoln, Warwick and Halifax) has now been drilled.

5.1 Whirlwind

Hurricane were obliged to relinquish the Whirlwind Discovery, located with the ‘P1368 North’ licence, in 2019 as part of the licence extension into the third term. Whirlwind is situated on a downthrown basement block north of the Rona Ridge. A large (approximately 34 km2) 4-way dip closure exists at basement level in Blocks 205/21 and 205/22 (Figure 9). BP drilled well 205/22-1A in 1974 and encountered hydrocarbons in the Lower Cretaceous Valhall Formation and Jurassic Rona Member directly overlying the basement, as shown in the illustrative cross-section (Figure 10). The shows in the Rona Sandstone from this well provide an oil down to (ODT) of 3200m TVDSS, which corresponds to the mapped 4-way dip closure at basement level. Geochemistry commissioned by Hurricane on core chips taken from the basement core in this well indicated that the hydrocarbon column continued into the basement. A single RFT pressure measurement for this well, combined with the sonic log response implied that the basement at Whirlwind was significantly overpressured by around 1685 psi.

Well 205/21a-5 was drilled as an inclined well (57o) and encountered oil shows within a thick interval of reefal Valhall Limestone directly overlying the basement. Shows continued into the basement to the TD of the well (Figure 12). 205/21a-5 was drilled significantly overbalance due to the interpretation of overpressure from 205/22-1A, and high drilling fluid losses of 3,800 bbl were lost to formation ahead of the DST. The reservoir pressure recorded by the DST was overpressured, but significantly less than expected at only 645 psi. The well did not fully clean up during the DST and rates of 200-400 bbl/d were achieved comprised mainly of drilling brine, with limited total volumes flowed to surface. The light (48 – 52o API gravity) hydrocarbons produced may not be reflective of true formation fluid due to the significant drawdown that was applied to the reservoir, leading to the gassier component of the hydrocarbon preferentially being produced over the liquid phase. For this reason, both a light volatile oil and gas condensate are equally as valid interpretation of reservoir fluid. A further test of the reservoir is required to fully assess deliverability of both the Valhall Formation and basement.

5.2 Strathmore

The Strathmore Discovery, located within the ‘P1368 Southwest’ licence, which lies in the East Solan Basin, was also relinquished in 2019. The Triassic sediments within the Strathmore area have been assigned to three formations. The earliest is the Griesbachian Formation which is overlain by the Otterbank and Foula Formations. Discovery well 205/26a-3 flowed 240 bopd of a 23° API oil from the Triassic Otterbank Sandstone reservoir; the remaining Triassic section is not considered to have any reservoir potential.

Four wells drilled and logged in the Otterbank Sandstone:

• 204/30a-2 penetrated a full sequence of Otterbank (179m) below the OWC

• 204/30a-3 penetrated a partial sequence of Otterbank, also below the OWC

• 205/26a-3 (the Strathmore discovery well) encountered a full sequence of Otterbank (187m) above the OWC

• 205/26a-4 encountered a full sequence of Otterbank (178m) but was drilled down dip of the discovery well and penetrated the reservoir just above the OWC.

The location of these wells can be seen in the top Otterbank Sandstone depth map shown in Figure 13. A seismic section through 205/26a-3 shows the disposition of the Otterbank Sandstone relative to the Rona Ridge in Figure 14.



5.2.1 Core description & Sedimentology

Leppard Sedimentology reviewed the available core data for 204/30a-2, 204/30a-3 and 205/26a-3 and concluded that the reservoir quality of the Triassic Sandstones appears to be affected by carbonate cementation, grain size and facies.

The Foula Formation is variably cemented with carbonate cements; overall it is finer grained than the Otterbank Formation and has significantly poorer reservoir quality. The prospective Otterbank Formation has significantly less carbonate cement. It has been subdivided into upper and lower divisions; the lower division has slightly coarser grain sizes and somewhat better reservoir quality. The best reservoir quality is found within the aeolian and fluvial facies and there is little to choose between them. The fluvial facies is more variable in quality due to local variations in the proportion of detrital clay and mud rip-up clasts etc. The sandy sabkha and other minor facies include higher proportions of detrital clay and have generally poor reservoir quality.

5.2.2 Development Review

Equipoise Solutions Ltd/ERC Ltd undertook a depth conversion on key seismic horizons over the Strathmore area. A static and dynamic model were built following a review of the reservoir geology, petrophysics, and fluid data available (Table 5.1). The dynamic model was used to screen possible development scenarios for both fields. Scoping economics of each development scenario were also conducted, with some price sensitivities included based on oil price forecast and facilities costs.

Table 5.1: Strathmore PVT properties used in the development review

Strathmore was also reviewed by Senergy; this included a review of all legacy data and incorporated an assessment of the permeability of the Otterbank Sandstone. The permeability review examined core data and test data to establish the potential range of permeability and the most appropriate method to upscale core permeability to DST test scale. It attempted to provide an assessment of reservoir permeability based on integrating all available data. Following on from the data review, Senergy conducted a field development review in which they concluded that there was potential development opportunity in the Strathmore Field, but further appraisal and testing needed to be carried out to constrain the reservoir, establish deliverability and the extent of an asphaltene mat recognised in well 205/26a-3. The field development review revisited the Equipoise study, updating the Equipoise dynamic model with Senergy’s permeability work and adjusting well placement / numbers, using high angle wells and hydraulically fractured injectors. Both Equipoise and Senergy agreed that the main issue regarding potential development of the Strathmore Discovery was the in-situ permeability.

Three sets of core permeability data exist:

• 205/26a-3 air permeability data (cleaned and drilled core, 400 psia overburden)

• 205/26a-4 oil permeability data ('fresh state' core, 3,000 psia overburden)

Sample # Saturation Pressure (psia)

Oil FVF (rb/stb)

Oil Gravity (°API)

Solution GOR (scf/stb)

Oil Viscosity (cp)

Gas Gravity

1.12 640 1.124 22.87 102 5.37 1.096

1.14 645 1.124 22.76 102 6.67 1.094

1.19 645 1.129 22.86 107 5.21 1.112

BHS01 620 n/a n/a 92 n/a 1.122



• 205/26a-4 helium permeability data (cleaned and drilled core, 400 psia overburden)

Data from different sources offer conflicting values of permeability, which causes uncertainty in the likely recovery factors for the field. For example, Equipoise noted that the average core derived permeability for DST 1/1A test interval was 94.2 mD, yet the permeability derived from pressure transient analysis for 205/26a-3 DST1/1A is 5 mD. Equipoise rejected the core derived permeability data, commenting that they ‘…conclude that the core measured permeabilities are not representative of the reservoir’ and that ‘It is our view that the most reliable predictor of permeability from the perspective of hydrocarbon production is that derived from well testing, despite the low flow rates achieved from these tests.’

Senergy concluded that ‘The information from the well tests in 205/26a-3 is inconclusive and the PLT results are of little use’ and furthermore that ‘It is believed that a combination of well or formation damage and viscosity variation within the reservoir could be responsible for the low productivity of the well. Consequently, provided a future well is designed and completed to mitigate against formation damage, and the viscosity uncertainties are addressed, there could be upside potential in the Otterbank Sandstone.’

An appraisal well with DST programme is therefore required to fully evaluate the deliverability of the Otterbank Sandstone.

5.3 Remaining Prospectivity

The only remaining prospectivity considered viable within the original P1368 Licence area is within the Lower Cretaceous in the East Solan Basin, an as yet untested play. A submarine fan of probable Aptian age is present in Block 205/26b, seen on seismic as a thickening package within the Lower Cretaceous sequence on the northern margin of the East Solan Basin (Figure 15). The trapping mechanism involves up-dip stratigraphic pinch out onto the edge of the Rona Ridge with the seal provided by Lower and Upper Cretaceous shales. Some fault control on the fan distribution and seal potential is also suggested. The Kimmeridge Clay Formation in the central (downdip) part of the East Solan Basin provides the main source kitchen. Figure 16 illustrates the limit of the lead based on the interpreted limit of sand deposition, pinch-out and spill point / closure, the lead extending eastwards into Block 205/27. Geological risks for the lead include sand fairway presence, seal integrity and updip seal.

Figure 17 shows both the drilled and undrilled prospects identified in Licence P1368.

6 Further Technical Work Undertaken

Table 6.1 overleaf lists technical work undertaken over Licence P1368 and the prospectivity it applies to.



Project Prospect Company

Comprehensive geochemistry project

Regional project GHGeochem (lab work)

APT (lab work)

IGI Ltd (interpretation)

Interpretation of released gravity and magnetic data

Regional project ARKeX

3D seismic reprocessing (PSTM & PSDM)

Regional project Shearwater Ltd

Extensive analogue field review Basement prospectivity Hurricane Energy

Interpretation of log and sidewall core datasets

Basement prospectivity Hurricane Energy & external contractors

Model building & dynamic simulation

Basement prospectivity Hurricane Energy

Seismic diffraction imaging Basement prospectivity PetroTrace

Attribute & coherency analysis of seismic data

Basement prospectivity Hurricane Energy

Development review including depth conversions, static modelling in Petrel, and dynamic modelling in Eclipse

Strathmore Equipoise Solutions Ltd/ERC Ltd

Permeability and development review of the Strathmore Discovery, including a report, Petrel model and Eclipse simulation

Strathmore Senergy

Core description and sedimentology report for wells 204/30a-2, 204/30a-3 and 205/6a-3

Strathmore Leppard Sedimentology

Table 6.1: Technical work undertaken on Licence P1368



7 Resource and Risk Summary

7.1 Whirlwind Discovery

The following contingent resources have been assigned to the Whirlwind Discovery located in Blocks 205/21a and 205/22a. Due to the uncertainty over fluid composition, an oil case (Table 7.1) and a gas condensate case (Table 7.2) are presented.

Oil Case 1C 2C 3C

Oil (MMstb) 59 117 203

Associated gas (Bscf) 236 528 1,017

Total (MMboe) 98 205 373

Table 7.1: Contingent resources for the Whirlwind Discovery (oil case)

Gas Condensate Case 1C 2C 3C

Condensate (MMstb) 18 44 84

Dry Gas (Bscf) 437 808 1,303

Total (MMboe) 91 179 301

Table 7.2: Contingent resources for the Whirlwind Discovery (gas condensate case)

7.2 Strathmore Discovery

The contingent resources presented for Strathmore in Table 7.3 are shown for Block 204/30a only, there is additional resource potential within Block 205/26a which did not form part of the P1368 Licence.

Contingent Resources 1C 2C 3C

Oil (MMstb) 20 32 57

Table 7.3: Contingent resources associated with the Strathmore Discovery in Block 204/30a

7.3 Lower Cretaceous Fan Lead

The following prospective resource potential has been estimated for the Lower Cretaceous fan lead as mapped across the relinquished part of 205/26b and adjoining block 205/27.

Unrisked Resources

P90 P50 P10 Mean

Oil MMBO 3 9 24 12

Table 7.4: Lower Cretaceous Fan Lead potential recoverable volumes



8 Conclusions

Due to the terms of a Frontier Licence, large areas of P1368 had to be relinquished despite Hurricane recognising that prospectivity remained within the P1368 licence area (as demonstrated by Figure 11). Ultimately, this led to Hurricane Energy re-applying for relinquished acreage both in subsequent licensing rounds and also out of round, resulting in some of the identified prospectivity being re-licenced and subsequently drilled and discoveries being made. As demonstrated by the Lancaster Field, this area of the West of Shetland shelf is still very prospective and standalone field development solutions can be successfully implemented. Upon implementation of a full field development at Lancaster there may be the potential to tie back other discoveries (such as Strathmore and Whirlwind) as satellite developments, or standalone development solutions may also be possible.

9 Clearance

Hurricane Energy confirm that OGA is free to publish the Report and that all 3rd party ownership rights (on any contained data and/or interpretations) have been considered and appropriately cleared for publication purposes.



10 Maps and Figures

Figure 1: Blocks operated by Hurricane 2005 – 2007 during the Initial Term of Licence P1368. Projection ED50 Zone 30N.



Figure 2: Blocks operated by Hurricane in 2008 – 2011 during the Second Term of Licence P1368. Projection ED50 Zone 30N.



Figure 3: Blocks operated by Hurricane 2011 – 2019 during the Third Term of Licence P1368. Projection ED50 Zone 30N.



Figure 4: Licence subdivision during the third term. Projection ED50 Zone 30N.



Figure 5: Retained area of Licence P1368 in the third term. Projection ED50 Zone 30N.



Figure 6: Seismic and well basemap for Licence P1368 as originally awarded. Projection ED50 Zone 30N.



Figure 7: Wells drilled by Hurricane on Licence P1368. Projection ED50 Zone 30N.



Figure 8: Top basement structure map over part of Licence P1368 (as awarded). Contour interval 200m, projection ED50 Zone 30N.



Figure 9: Top basement structure map over Whirlwind Discovery. Wells shown in green; ODT contour from 205/22-1A also highlighted in green (3200m TVDSS). Note that the contour is constrained to the licence boundary at northern limit of Block 205/21a.



Figure 10: Illustrative cross-section through 205/22-1A and 205/21a-5 on Whirlwind showing the oil accumulation in green in both the Valhall Formation and basement.



Figure 11: NW-SE seismic section through Whirlwind (PSTM). Oil shows in wells 205/21a-5 and 205/22-1A highlighted along with ODT from 205/22-1A.



Figure 12: CPI over drilled interval of Valhall Formation and basement for 205/21a-5



Figure 13: Strathmore Otterbank Sandstone depth map showing key wells



Figure 14: NW-SE seismic section through (PSTM) through well 205/26a-3 showing the disposition of the Otterbank Sandstone relative to the Rona Ridge



Figure 15: NW-SE PSDM seismic section across the East Solan Basin showing interpreted presence and pinch-out of the Aptian Fan within Block 205/26c. The southwestern part of the line ties to the Solan Field area.



Figure 16: Aptian fan depth map, contour interval 25m showing interpreted closure as a polygon. Projection ED50 Zone 30N.



Figure 17: Remaining prospectivity in the retained part of Licence P1368, Licence P2294 and Licence P2308 and relinquished areas of P1368. Projection ED50 Zone 30N.

Documents

P1368 Relinquishment Report 2019