1 Licence Information 4. 2 Licence Synopsis 4. 3 Work Programme Summary 5. 4 Database 6. 5 Prospectivity Update 8
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2 Table of Contents 1 Licence Information 4 2 Licence Synopsis 4 3 Work Programme Summary 5 4 Database 6 5 Prospectivity Update 8 6 Further technical work undertaken 16 7 Clearance 16 P1610 Page 2 of 16
3 List of Figures Figure 1: Location map showing original extent of licence P Figure 2: Location map showing extent of licence into Second term... 5 Figure 3: Available 3D seismic datasets over licence P Figure 4: Summary Stratigraphic Column for Moray Firth... 8 Figure 5: Map showing prospectivity at time of licence application... 9 Figure 6: Base Chalk depth map showing location of Magnolia well & Geo-seismic line (Fig. 7) Figure 7: Magnolia Prospect Geo-seismic Line (courtesy of Schlumberger) Figure 8: 13/23a-7A Lower Cretaceous CPI Figure 9: P1610 Remaining identified prospectivity Figure 10: Top K50 Depth map over Captain sand channels Figure 11: Seismic line (TWT) across Minos Prospect (courtesy of Schlumberger) Figure 12: Well 13/23-1 CPI Figure 13: Wester Ross Top Ettrick Depth map Figure 14: Seismic line (TWT) through 13/23-1 (Courtesy of TGS) List of Tables Table 1: Exploration well database... 7 Table 2: Minos volumetrics Table 3: Wester Ross discovery volumetrics P1610 Page 3 of 16
4 1 Licence Information Licence Number: Licence Round: P th Award Date: 12 th February 2009 Licence Type: Traditional Block Numbers: 13/22a Operator & Equity: Partners & Equity: Dana Petroleum (BVUK) Limited - 45% Summit Exploration and Production Limited 25%, Atlantic Petroleum 20%, Trap Oil Ltd 10% Dana Petroleum (BVUK) Limited confirms that the DECC is free to publish this Report and that all 3rd party ownership rights (on any contained data and/or interpretations) have been considered and appropriately cleared for publication purposes. 2 Licence Synopsis Licence P1610 was awarded to Bow Valley Petroleum (UK) Ltd, Petro Summit Investment UK Ltd and Reach Exploration (UK) Ltd on the 12 th February 2009 as a traditional licence in the 25 th Licence round. The initial term was 4 years, ending 11 th February Figure 1 shows the original extent of the block 13/23a. The licence was granted on a four year drill-or-drop programme. The primary target was the Minos lead. In 2009 Dana Petroleum (BVUK) Limited became the operator of the block after the acquisition of Bow Valley. In July 2011 Trap Oil Ltd came onto the block following their purchase of Reach Oil and Gas. In September 2012 Atlantic Petroleum farmed into the block taking 20% of Summit s equity. On Feb 1 st 2013 the partnership were granted a 9 month extension to the first term in order to accommodate the delays to the delivery of the rig that was contracted to drill the Magnolia prospect. At the end of the first term (10/11/2013), 50% of the licence was relinquished (Figure 2). P1610 Page 4 of 16
5 Figure 1: Location map showing original extent of licence P1610 Figure 2: Location map showing extent of licence into Second term 3 Work Programme Summary The Licence commitment was to re-process 200Km2 of 3D Seismic Data and then to either drill one well to 3000m or into the Ettrick B Sands, whichever is shallower, on the Minos Prospect. P1610 Page 5 of 16
6 In 2009 the agreement with DECC was reached that 162km2 of seismic data would be purchased and inverted. In 2012 the well requirements were changed to a well drilled to 1500m or to penetrate the Ettrick B or older, whichever is deeper after the risking on the Minos prospect made the prospect un-economic. There are no outstanding commitments on the licence. 4 Database Several 3D seismic datasets cover block 13/23a. These are shown in Figure 3. Figure 3: Available 3D seismic datasets over licence P1610 The re-processing of the WesternGeco seismic was completed in 2010 and the inversion was completed in TGS NOPEC 2010 and Polarcus Halibut Horst 2014 surveys also cover the licence but were not licenced by all partners. A considerable number of wells, both exploration and development, have been drilled in the vicinity of block 13/23a. The key wells used in this evaluation are detailed in Table 1. P1610 Page 6 of 16
7 Well Year Operator Comments 13/ Texaco P&A w/ oil shows 13/ Texaco P&A w/ oil shows 13/ Texaco P&A Dry hole 13/23a Talisman P&A Dry hole 13/23b Talisman P&A w/ oil shows 13/23b-5Z 2005 Talisman P&A w/ oil shows 13/23b-5Y 2005 Talisman P&A w/ oil shows 13/23a Talisman P&A Dry 13/23a-7,7A 2013 Dana P&A Dry 13/23d Dana Oil discovery 13/ Texaco Captain Field Discovery well 13/22b Kerr-McGee Phoenix Discovery 13/22a Texaco Captain 13/22b Kerr-McGee P&A 13/22b Kerr-McGee P&A 13/22a Texaco Captain 13/22c BG Group P&A Dry hole 13/24b BG Group Blake Field Oil well 13/24a BG Group Blake Field Oil Well 13/24a BG Group Blake Field Oil Well 13/24a BG Group Blake Field Oil Well 13/28a Occidental Ross Field Oil Well 13/28a-6a 1992 BP P&A w/ oil shows 13/29b Amerada Hess P&A w/ oil shows 13/29b BG Group Blake Field Oil Well Table 1: Exploration well database P1610 Page 7 of 16
8 5 Prospectivity Update The primary source rock is the Kimmeridge Clay Formation (KCF) (Figure 4). Prospectivity relies on long distance migration of hydrocarbons from deeper parts of the basin to the east, from either the Witch Ground Graben or the northern part of the Central Graben. The primary reservoirs in the licence area are Lower Cretaceous turbidite sandstones, specifically the Carrack Formation Captain Sandstone Member and Valhall Formation Coracle and Punt Sandstone members. Jurassic sandstones are also present, specifically the Kimmeridge Clay Formation Burns (Ettrick) Sandstone Member and Heather Formation Ross Sandstone Member. The oldest intervals with recognised reservoir potential are sandstones of Permian and Devonian age. These have been hydrocarbon-bearing in the Ross Field and Dee Discovery of the Inner Moray Firth. Figure 4: Summary Stratigraphic Column for Moray Firth The first well drilled on block 13/23 in 1991 was the Wester Ross discovery (13/23-1). However, the low test rate and seismic structure indicate a small connected volume. P1610 Page 8 of 16
9 When P1610 was awarded the key prospect identified on the licence was the Lower Cretaceous Minos prospect. Magnolia was one of the identified leads (Figure 5). Figure 5: Map showing prospectivity at time of licence application Though Minos was the highest graded prospect in the licence application, further work suggested that the connected volume was small and the risk on charge was too high and the Magnolia well was drilled to fulfil the licence commitment. Magnolia Prospect Magnolia is a 3-way dip closure and one way pinch-out onto the Halibut Horst. Pre-drill 60% of the STOIIP of Magnolia was considered to be in block 13/22d and 40% on 13/23a. The structure was drilled by well 13/23a-7,7A. 13/23a-7 was spudded in February 2013 but after 2 days of drilling the BHA became stuck in the 17 ½ hole. It was not possible to free the string and as a result the well was re-spudded. Well 13/23a-7A TD d in the Devonian. The well encountered 302ft of high quality Lower Cretaceous sands. No hydrocarbons were encountered (See Figures 6, 7, & 8). The most likely failure mechanism was charge. P1610 Page 9 of 16
10 Figure 6: Base Chalk depth map showing location of Magnolia well & Geo-seismic line (Fig. 7) Figure 7: Magnolia Prospect Geo-seismic Line (courtesy of Schlumberger) P1610 Page 10 of 16
11 Figure 8: 13/23a-7A Lower Cretaceous CPI The prospectivity identified as remaining on the licence is shown in Figure 9. P1610 Page 11 of 16
12 Figure 9: P1610 Remaining identified prospectivity Minos Prospect Though the Minos prospect was the highest graded prospect in the licence application, further work suggested that the connected volume was small and the risk on charge was too high. The expected reservoir in Minos is the Lower Cretaceous Captain Sandstone Member (Table 2 & Figures 10 & 11). P90 P50 P10 STOIIP Oil (MMbl) RESERVES (MMbl) Table 2: Minos volumetrics P1610 Page 12 of 16
13 Figure 10: Top K50 Depth map over Captain sand channels Figure 11: Seismic line (TWT) across Minos Prospect (courtesy of Schlumberger) P1610 Page 13 of 16
14 Wester Ross Discovery 13/23-1 Well 13/23-1 encountered oil bearing Ettrick D sands. The rate was low (266 bopd) and seismic mapping suggests that the trap is small. There is upside potential if the updip pinchout of these sands can be proved. See Table 3 & Figures P90 P50 P10 STOIIP Oil (MMbl) RESERVES (MMbl) Table 3: Wester Ross discovery volumetrics Figure 12: Well 13/23-1 CPI P1610 Page 14 of 16
15 Figure 13: Wester Ross Top Ettrick Depth map Figure 14: Seismic line (TWT) through 13/23-1 (Courtesy of TGS) P1610 Page 15 of 16
16 Additional Lower Cretaceous leads have been identified: Lygaera & Lysander. These are ontrend with existing Lower Cretaceous discoveries, but regional work has identified that they are interpreted to lie in a migration shadow. Albacorra is a Jurassic lead, however, trap definition, seal and hence hydrocarbon retention is the key risk. 6 Further technical work undertaken Dana Petroleum (BVUK) Limited has carried out a regional geological and petroleum system review of the greater Magnolia area. The conclusions of these studies indicated that limited prospectivity remains in block 13/23a. 7 Clearance Dana Petroleum (BVUK) Limited and partners confirm that DECC is free to publish this report and that all 3rd party ownership rights (on any contained data and/or interpretations) have been considered and appropriately cleared for publication purposes. P1610 Page 16 of 16
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