Relinquishment Report. for. Licence P1972 Blocks 3/9e,3/10a and 3/15b. September 2015

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1 Relinquishment Report for Licence P1972 Blocks 3/9e,3/10a and 3/15b September

2 CONTENT Licence Summary & Status Technical Evaluation Introduction 27th Round Application Well data base Seismic Work Programme Regional Geology Tertiary Paleocene Geology Jurassic and Triassic Exploration Objectives Conclusion Clearance Tertiary Ninian Fan Jurassic Brent and Statfjord Formation. Remaining Exploration Potential 2

3 LICENCE SUMMARY AND STATUS Licence Number: P1972 Blocks: 3/9e,3/10a and 3/15b (see Table 1 for co-ordinates) Equity Holding : MOL Energy UK (57%) and Tullow Oil(Int)Norge Ltd (43%) 27th Round applicants Wintershall E&P Ltd and Spring Energy UK Exploration Ltd Licence Round : 27th Round awarded on 01/01/2013 Initial term expires 01/01/2017 Drill or drop 1st January 2017 GEOSCIENCE EVALUATION Introduction Licence P1972 which includes Blocks 3/9e,3/10a and 3/15b is located at the southern end of the East Shetland Basin.The blocks lie in a contiguous postion to the Norway territorial boundary. The area is dominated in the UK by the Jurassic Brent reservoir system with the major oil and gas-condensate fields Ninian/Alwyn /Dunbar /Ellon and Martin Linge in Norway in close proximity. A key well, Total well 3/15-15 was drilling the Fettercairn Prospect at the time of application. This well was a test of the Brent/Statfjord reservoir system.the well result was subsequently released as a dry hole (Fig 1). 27th Round UK Application The Blocks 3/9e,3/10a and 3/15b were applied for in the UK 27th round by Wintershall and their co-venture Spring.The primary reservoir objective was to protect the extension of a large Paleocene Fan(Ninian) that had been interpreted extending for Norway into the UK. The Wintershall interpretation was done in Norway with little data integration from the UK.One of the key uncertainties of the prospect was the updip closure on the UK side. Other pre-cretaceous opportunities were recognised on the acreage but the targets were either deep or poorly defined on seismic. Well data base The wells in the UK have been integrated into the interpretation.the key wells in the area are indicated in Figure 2. Most of the significant wells and discoveries are located on the major Brent rotated fault Blocks and the prograding Dornoch delta system. Seismic Work Programme The committed work programme was to obtain 142sqkms of Alwyn(94) 3D seismic and merge and reprocess pre stack with an extensive 3D Norway survey.the work programme also included a full AVO analysis to validate the integrity of the Ninian Palaecene fan prospect. The programme also included the integration of all avialable well information especially in the UK with reference to those wells that lie updip to the west of the Ninian fan closure. The data volume was also used to look for secondary Jurassic Brent or Triassic Statfjord opportunities. Stratigraphic column A stratigraphic column defines the majors plays in this part of the East Shetland Basin.The column has also been used to reference other potential exploration targets that have not been evaluated or absent on the Licence (Fig 3). 3

4 REGIONAL GEOLOGY Tertiary Paleocene Geology The development of the Iceland Plume controlled the tectonic activity in the Northern North Sea and resulted in an uplift of the Scottish Highlands and the East Shetland Platform. Erosion of the uplifted area resulted in the input of sediment into North Sea area. This led to a change from calcareous deposition that prevailed throughout the Cretaceous, to a siliclastic depositional system that dominated throughout the Paleocene. There was an overall fall in sea level during the Paleocene that resulted in progression from basinal to deltaic sedimentation within the East Shetland Basin. Basinal conditions continued to the east in the Viking Graben of Norway. Despite the fluctuations in sea level, the transport direction of sediments remained generally west to east towards the basin centre, and the coastline was generally orientated north to south. The Paleocene has been sub-divided into the Montrose and Moray groups. This report will focus on the prospectivity of the Moray Group which is divided into the Sele and Balder formations. The Sele Formation in the East Shetland Basin comprises deltaic and shelf Dornoch sandstones which prograde out into the Viking Graben, where slope and basinal sands and mudstones dominate. The Odin and Hermod Sands are basinal equivalents to the Dornoch Sands. To the west of the Dornoch delta, sands are replaced by a mud-prone shelf area crossed by rare sand channels. This is overlain by the transgressive Balder Formation that in the East Shetland Basin are composed predominately of volcanic tuffs and mudstones. Jurassic and Triassic The licenced blocks 3/9e,3/10a and 3/15b are located in the south western part of the prolific East Shetland Basin where exploration focus has been on pre-cretaceous structural traps. EXPLORATION OBJECTIVES Tertiary Ninian Fan Prospect The major Exploration target was the Tertiary Paleocene pre-balder Odin and Hermod Sands defined by a slope-basin fan system in front of the easterly progressive Dornoch delta system. The Ninian Fan prospect was defined by Wintersall Norway based on a Top Balder seismic Amplitude interpretation with little well or seismic control from the UK. The current Technical review of the Ninian fan prospect has incorporated several key UK wells and seismic. The current results are summarised below. Rock Physics and fluid substitution 2D models have been generated for wells 3/10b-2 and 3/9a-5 which demonstrate that a stronger and dominant negative reflection is expected to be seen when hydrocarbons bearing Odin/Hermod sands are present below the Balder. However these sands are thin and are within the tuning thickness of the Balder side-lobe. Very subtle changes in the AVO gradient were observed for various modelled sand/tuff/shale fluid cases.on seismic an AVO class 4 type anomaly can be expected. Well UK3/9a-5 encountered porous Odin sands directly underlying an acoustically hard Top Balder event. Downlapping hard events onto the Balder tuff are also seen in UK well 3/9a-8 which is also coincident with a higher Balder amplitude. However the nearby UK3/10b-2 well did not encountred Odin or Hermod sands although higher amplitudes and wedging are observed below the Balder on seismic. Hence the observation from the regional and local well control is that the Ninian Fan model as defined is incorrect. There is no evidence to suggest that widespread sands extend far into the base of slope and basin.the well control especially 3/14e-16A would suggest that the sands are localised and possibly thin rapidly down slope. The seismic facies may suggest localised channels and that much of the fan is not sand rich. The Ninian fan prospect was defined mostly on the hard Balder reflection which is not an indicator of hydrocarbon bearing sand presence in this area.the seismic interpretation and amplitudes supports channels deposition on a slope to basin and that most of the sand prone facies is channel.the Odin and Hermod sands have been encountered in many of the immediate offset wells irrespective of seismic amplitude.it is also difficult to exclude adjacent dry holes which are also within the amplitude closure. A fringe of higher amplitudes have been observed around the Dornoch Delta slope and have been extensively drilled with no success. 4

5 Summary The Odin/Hermod sands are low impedance low contrast sands which are located locally below anomalously hard tuffaceous Balder. The Top of the sand is affected by the hard Balder wavelet sidelobes.the Odin sands are expected to create an negative impedance contrast to the Balder but are within the tuning thickness of the Balder sidelobes. Hence the negative impedance is basically a sidelobe interference effect in the majority of the Ninian fan outline.another aspect of the trap is the critical up-dip seal which is not robust as the 3/10b-1 and 2 wells have encountered an Odin sandstone togather with a sand prone Dornoch Fm both of which were water wet. With better seismic data and AVO analysis there maybe some exploration opportunities in the channels. Jurassic Brent and Statfjord Formation The Top Brent Structural depth map highlights that most of the licence sits in the hanging wall of a major Brent Fault system and downthrown to the major fields (Fig 4). The structural interpretation has highlighted a series of small downthrown Brent/Statfjord traps but deep within the current acreage.the success of the Fettercairn prospect 3/15a-15 might have added some prospectivity to the 3/15e Block but this well was dry and the 3/15f Block has now been relinquished by Total. The MOL operated acreage also covers the NE Flank of the Ellon high but lies in the saddle of the ridge which separates the Ellon Field from the Alwyn Fields. Hence below the field contacts. The footwall section of the Ellon Field lies within the Western part of Block 3/15d but has been tested by the 3/15a-4 & 6 wells which encountered oil and gas shows in the Brent and Statfjord units. Remaining Exploration Potential The remaining Exploration potential in the licence appears to be very limited. There maybe a high risk Lower Cretaceous fairway that could be explored extending into the North Viking Graben of Norway. An Upper Jurassic reservoir target, an erosional remnant of the footwall Brent and Statfjord may also be a future target. These are not currently recognised as targets based on the regional reservoir fairways. CONCLUSION MOL Energy UK Ltd took over over the Operatorship of this licence in 2013 as part of an acquisition package from Wintershall. A Technical review concluded that no economic prospectivity was identified. As a result MOL and co-venturer Tullow have agreed to relinquish. CLEARANCE MOL Energy UK Ltd confirms that DECC is free to publish this document and that any relevent third party ownership rights have been cleared for publication purposes. 5

6 Fig 1: Location Map (MOL/Tullow acreage highlighted in red) 6

3/9a-11(Total 1997) Susp Gas/Cond well (Lunde &Statfjord) No Brent TD Triassic (Heron Gp) 3/9a-5&8 Control well for Ninian Fan 3/15-4(Total 1978) P&A Gas Shows (Brent/Statfjord) TD Triassic Statfjord

7 3/9a-11(Total 1997) Susp Gas/Cond well (Lunde &Statfjord) No Brent TD Triassic (Heron Gp) 3/9a-5&8 Control well for Ninian Fan 3/15-4(Total 1978) P&A Gas Shows (Brent/Statfjord) TD Triassic Statfjord 3/15-6 (Total 1992) P&A Dry Hole L.Cret on Statfjord Brent 3/15-3(Total 1974) P&A oil shows Pal & Brent TD Statfjord 3/15-15 Re(Fettercairn) Total(2012/13) P&A dry Brent/Statfjord Fig 2 : Well database and Key critical wells 7

Evaluated through Norway PL509S Ninian Fan Lead invalidated No other viable prospectivity in the Tertiary on Licenced acreage No proven or interpreted Play type in this area. No proven Play potential.

8 Evaluated through Norway PL509S Ninian Fan Lead invalidated No other viable prospectivity in the Tertiary on Licenced acreage No proven or interpreted Play type in this area. No proven Play potential. Potential Pinch out traps absent or thin to west Local minor sands in upper section 3/10-1 (Rhum) Possible play potential from eroded Brent Highs. Dunbar/ North Alwyn /Ninian/Kells/Grant/Ellon/Jura/Martin Linge Brent Primary play in the Area. Absent over the licenced Area. Dunbar/N Alwyn Fields. Proven Play but no viable closures within Licence area Fig 3: Local area Play Summary types and potential 8

9 Brent Truncated Narrow zone of truncated Brent absent Eroded to West, fault plane to East 3/15a-15Re (Fettercairn) Drilled 2012/2013 Dry Hole MOL Operated Blocks Fig 4: Middle Jurassic Brent Fm structural Depth Map 9

10 All the coordinates below were specified using "European Datum 1950" Block 3/9e is the region bounded by the following coordinates: (1) 60 44'00.000"N 1 45'00.000"E (2) 60 44'00.000"N 1 46'00.000"E (3) 60 43'00.000"N 1 46'00.000"E (4) 60 43'00.000"N "E (5) 60 42'00.000"N 1 47,00.000"E (6) 60 42'00.000"N "E (7) 60 40'00.000"N 1 48' E (8) 60 40'00.000"N 1 45'00.000"E (9) 60 44'00.000"N 1 45'00.000"E Block 3/10a is the region bounded by the following coordinates: (1) 60 42'00.000"N 1 48'00.000"E (2) 60 42'00.000"N 1 51'00.000"E (3) 60 40'00.000"N 1 51'00.000"E (4) 60 40'00.000"N 1 48'00.000"E (5) 60 42'00.000"N 1 48'00.000"E Block 3/15b is the region bounded by the following coordinates: (1) 60 40'00.000"N 1 48'00.000"E (2) 60 40'00.000"N 1 55'31,726"E (3) 60 34'00.000"N "E (4) 60 34'00.000"N 1 55'00.000"E (5) 60 38'00.000"N 1 55'00.000"E (6) 60 38'00.000"N 1 53'00.000"E (7) 60 37'00.000"N 1 53'00.000"E (8) 60 37'00.000"N 1 52'00.000"E (9) 60 35'00.000"N 1 52'00.000"E (10) 60 35'00.000"N "E (11) 60 37'00.000"N 1 51'00.000"E (12) 60 37'00.000"N 1 50'00.000"E (13) 60 39'00.000"N "E (14) 60 39'00.000"N 1 48'00.000"E (15) 60 40'00.000"N E Table 1: Licence P1972 Block co ordinates 10

RELINQUISHMENT REPORT FOR LICENCE P.1663, BLOCK 29/4b and 29/5e

RELINQUISHMENT REPORT FOR LICENCE P.1663, BLOCK 29/4b and 29/5e Licence: P.1663 Blocks: 29/4b & 29/5e 25th Round Traditional Licence Operator: Ithaca Energy UK(Ltd) 100% Work Programme Summary The agreed