P.1619 License Relinquishment Report
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1 P.1619 License Relinquishment Report Effective Date: 14 th October 2015
2 1. Licence Information License Number: P.1619 License Round: 25 th License Type: Traditional Block Number(s): 21/27b Operator: MOL Energy UK Ltd. (75%) Partner(s): Sterling Resources UK Ltd. (25%) Date Award: 12 th February 2009 Expiry Date: 12 th February 2017 MOL Energy UK Ltd. gives permission for this report to be published. 2. Licence Synopsis The license P.1619 was initially awarded to Wintershall E&P Ltd. and Sterling Resources UK Ltd. on 12 th February 2009 as part of the 25 th Licence Round as a traditional license. Initial term obligations were fulfilled with seismic reprocessing and the drilling of the 21/27b-7 well in The drill-or-drop commitment was to drill at least 130 fttvd into the Ekofisk chalk formation. The well TD was more than 140 fttvd into the Ekofisk chalk and therefore met the stipulated DECC requirements. The license then entered the second 4-year term in 2013, which expires on 12 th February If the licence were being retained an FDP is required to be submitted to DECC prior to the expiration date. (Figure 1.) In March 2014, the license was acquired by MOL. However due to the high viscosity oil present in the Tay Sandstone target within the acreage, the project economics were not found to support a development. Licence P.1619 lies approximately 150 km east of Aberdeen in block 21/27b, located 19 kilometres west of the Guillemot West field (Figure 2).
3 Figure 1 - Licence Timeline Figure 2 - Location of P.1619 License
4 3. Work Programme Summary During the initial term, the asset was looked into in detail and scoping studies were performed in order to come up with suitable development options for this field. As a result, only EOR was thought of as a possible recourse to achieve a reasonable oil recovery. Besides the scoping studies 250 km2 of seismic data was reprocessed. Seismic examples of pre and post processing are shown in Figure 3 and 4. Figure 3 Original migrated crossline stacks x840, x920 and x1000 Figure 4 - Reprocessed PreSTM crossline stacks x840, x920 and x1000
5 In early 2013, the operator applied for a second term to DECC, in order to further evaluate Blakeney. On behalf of the partnership, the following work programme was offered by Wintershall seeking approval to carry it out: - A review of available data and literature on surrounding heavy oil assets - A revalidation and incorporation of new information into existing geological and reservoir engineering models - To identify potential enhanced oil recovery methods All second term work programme have been fulfilled which finally resulted in a comprehensive dynamic modelling. 4. Database Table 1 shows the seismic database utilised in the evaluation of Blakeney discovery. Survey Processing 2D/3D Notes AR28-91 Original & 2009 Repro 2D Angle stacks available AR28-95 Original & 2009 Repro 2D Angle stacks available F90/21 Original 2D PGS Megasurvey Original 3D Block 21/26 Coverage Western Geco Q21 3D Original 3D Covers 21/27 and 21/28 Western Geco Q21 3D Extension Table 1 - Utilized Seismic Database 2011 Reprocessing 3D Extension into 21/21 and reprocessed original area Figure 5 shows the seismic data coverage and the wells that have been integrated into the evaluation process.
6 Figure 5 - Seismic Data Coverage Map
7 5. Prospectivity Update Blakeney Blakeney is a four-way dip-closure at Eocene Tay Formation level, and lies within an area of similar heavy-oil accumulations which, despite a significant total STOIIP, remain undeveloped due to the viscous nature of the oil (Figure 6). Figure 6 summary of heavy oil discoveries in the Blakeney area. The accumulation is well delineated on seismic, including a seismic amplitude anomaly and flat spot on the reprocessed dataset. A representative line is shown in Figure 7, and a more detailed line in Figure 8, alongside a synthetic section. Figure 8 demonstrates the brightening at top Tay, and flat spot at the oil-water contact. Top Tay was picked as a soft event (red), becoming a zero-crossing over the oil-leg. Depth-conversion was carried out using a simplified pseudo-check-shot model from the 21/18-1 and 21/27b-7 wells. The intra-reservoir velocity difference between these two wells leads to a reservoir thickness uncertainty of +/- 12 metres. De-watering events in the overburden affect the top reservoir image. The resulting Top Tay depth structure map is shown in Figure 9.
8 Figure 7. Representative seismic line Xline /27b-7 Seismic OWC -> Model So = 80% Figure 8. Seismic line detail and synthetic model illustrating amplitude and flat-spot effects over Blakeney.
9 Figure 9. Top Tay reservoir depth structure map. The 21/27b-7 discovery well was drilled near the crest of the structure, and encountered a 73 foot heavy oil column at 3263 ft TVDSS, sitting in an overall 150 foot Tay section. A CPI is shown in Figure 10, and key reservoir, fluid, contact and STOIIP figures are tabulated below (Table 2). The reservoir is excellent quality, with high net-to-gross, porosity and permeability. The well was not tested, only oil and water sample were recovered with MDT chambers. The reservoir contains undersaturated oil with an average viscosity of 291 cp at reservoir conditions with a low gas-oil ratio of 95 scf/bbl. Despite being heavy, the oil seems very close to saturation as the measured bubble point is reported at 1443 psia for an initial reservoir pressure of ft TVDSS. The initial reservoir temperature is 105 F.
10 Fluid sample Figure /27b-7 log interpretation.
11 Trap Type Depth to crest (ft TVDss) 3263 OWC (ft TVDss) 3336 Oil column (ft) 73 Pay zone Formation Age 4 way dip closure Tay Sandstone Eocene Gross thickness (ft) 150 Net/gross ratio (%) 100 Porosity average (%) 36 Permeability average (md) Multi-Darcy, up to Hydrocarbons Oil density (API ) 14.5 Gas gravity (Air=1) Viscosity (cp) 291 ( ) live oil / 7000 dead 4 C Bubble point (psia) 1443 Gas/oil ratio (scf/bbl) 95 Formation volume factor Pressure (psia) Undesirables Formation water Salinity (ppm NaCl eq.) Field characteristics 1443 psia Asphaltenes ( wt%), Waxes TDS Initial pressure depth ft TVDSS) 3300 Temperature (C ) 40.5 Reserve Oil initially-in-place (mmstb) 92 Drive mechanism / Development scheme Hot Water and Polymer Co-injection Table 2 Blakeney Reservoir Properties
12 Feugh Feugh is a small 4 way dip closure at Eocene Tay Formation level, to the south east of, and similar to nearby Blakeney. The structure is well delineated on seismic, including a seismic amplitude anomaly and flat spot on the reprocessed dataset. A representative line shown in Figure 11 demonstrates the brightening at top Tay, and flat spot at the gas water contact. Depth-conversion was carried out using a simplified pseudo-check-shot model from the 21/18-1 and 21/27b-7 wells. The intrareservoir velocity difference between these two wells leads to a reservoir thickness uncertainty of +/- 12 metres. De-watering events in the overburden affect the top reservoir image. The resulting Top Tay depth structure map is shown in Figure 12. Flatspot Figure 11: NW-E Seismic line across Blakeney and Feugh
13 21/28-1 Figure 12: Feugh depth structure map The 21/28-1 discovery well was drilled to the eastern edge of the structure, and encountered a 29 foot column believed to be gas at 3303 ft TVDSS, sitting in an overall thin Tay section as it extends into Block 21/27b. A CPI is shown in Figure 13, and key reservoir, fluid, contact and IGIP figures are tabulated below (Table 3). The reservoir is excellent quality, with high net-to-gross, porosity and permeability. The well was not tested nor pressures taken and was P&A. Subsequent re-evaluation shows Feugh to be too small for any commercial development. Figure 13: 21/28-1 log interpretation and discussion as to which hydrocarbon phase the well encountered
14 Table 3 Feugh Reservoir Summary
15 6. Further Technical Work Undertaken on Blakeney Dynamic simulation modelling was conducted to estimate the oil recovery where different enhanced oil recovery techniques were applied, as primary depletion suggests very low recovery due to the high mobility ratio. The applicable EOR techniques were determined by the modified Taber s criteria. After screening, polymer and hot water flooding seemed to be technically feasible and practical methods. Estimates of incremental recovery from polymer flooding are quite modest as a substantial amount of the total polymer injected is lost to the aquifer and high oil losses to the aquifer are also observed. A combination of above techniques was also investigated and the simulations showed that hot water flooding followed by polymer co-injection would be the best EOR method to develop the field. 7. Resource and Risk Summary: Blakeney Based on the evaluations the base case recoverable resource is 20 mmboe, subject to an economic development scheme. Resource and Risk Summary Unrisked recoverable resources Prospect P Geological Risked Lead L Stratigraphic Chance of P50 Discovery D level Oil [mmbbls] Gas [bcf] Success % [mmboe] Name Low Base High Low Base High Blakeney D Eocene Table 4 - Resource and Risk Summary 8. Conclusions The base case STOIIP in Blakeney is 92 mmstb of heavy biodegraded viscous oil, which requires enhanced oil recovery techniques. Dynamic modelling showed that a tertiary recovery method could be a good approach to develop the field. However the estimated recovery factor does not exceed 30% and due to the offshore standalone location of the field, project economics are not supportive of a development. In comparison Feugh is a small non-commercial fallow gas discovery containing circa 15bcf gas in place. In light of these evaluations the operator, MOL Energy UK Ltd. and its partner Sterling Resources UK Ltd. agree to relinquish the Licence P.1619 as soon as possible.
16 9. Clearance The operator, MOL Energy UK Ltd. and its partner Sterling Resources UK Ltd. confirm that DECC is free to publish information documented in 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.
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