Relinquishment Report P.098 Block 30/2a Post-Tertiary Area ... · Round under licence P.2054 by Maersk Oil and GDF SUEZ E&P UK Ltd. Maersk Oil operates both licences with equity of

Courageous Licence Relinquishment Report

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Relinquishment Report – P.098

Block 30/2a Post-Tertiary Area (Courageous)

October 2015


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Contents

1. Licence and Field Information .................................................................................. 3

2. Project Overview ................................................................................................... 4

3. Licence Synopsis ................................................................................................... 5

4. Work Programme Summary .................................................................................... 6

4.1. Well results summary ................................................................................... 6

5. Database .............................................................................................................. 8

5.1. Courageous Well Database ............................................................................ 8

5.2. Seismic Database ........................................................................................ 8

6. Further Technical Work Undertaken ........................................................................ 11

6.1. Seismic Technologies...................................................................................11

6.2. Hydrocarbons Initially In Place......................................................................15

6.3. Resources and Production Forecast ...............................................................17

6.4. Well Engineering Overview ...........................................................................18

6.5. Development Concepts and Exports ..............................................................20

7. Resource and Risk Summary .................................................................................. 22

8. Conclusions .......................................................................................................... 23


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1. Licence and Field Information

The Courageous field was discovered in 1971 in block 30/2a of the Central North Sea,

approximately 240km East of Aberdeen, under the 3rd round licence P.098. The field

outline extends into block 30/1g, which was successfully acquired in the 27th Licence

Round under licence P.2054 by Maersk Oil and GDF SUEZ E&P UK Ltd. Maersk Oil

operates both licences with equity of 99.5%, whilst the remaining 0.5% interest is held

by GDF SUEZ E&P UK Ltd.

Courageous is a four-way dip closure with discovered hydrocarbons found in sands from

the distal reaches of the Palaeocene Forties turbidite fan. The field is NPNT and consists

of volatile oil in equilibrium with wet gas. The project development is based on

production without pressure support (reservoir base case), although the benefit of gas

and water injection have been investigated. Likewise, the benefit of stimulation by

propped hydraulic fracturing was considered, although the current base case relies on

unstimulated long horizontal wells. Artificial lift will be required to lift the wells later in

field life.

Figure 1.1 shows the location of the Courageous discovery within Quad 30 North relative

to other developments and discoveries in the area.

Figure 1.1 Courageous Location Map.


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2. Project Overview

The project timeline for the Courageous discovery has been driven by the June 2016

licence expiry for P.098. It was initiated as a development project in Q2 2012 and

entered the Maersk Oil Project Maturation Process (PMP) at the Select stage. On the

basis of limited facilities feasibilities studies, the base development concept assumed a

subsea tieback to the Total operated Elgin platform. Subsequent discussions with

potential host platforms in the area confirmed that the host modifications and associated

costs assumed were significantly underestimated. This placed pressure on the project

economics and led to the decision to recycle the Courageous project back to Assess, in

order that a wider range of development options could be considered. A complete

reservoir model rebuild was undertaken in parallel as it was believed that the

heterogeneity in the reservoir had not been adequately represented previously.

Throughout 2013 a significant amount of development screening work was undertaken

and the sub-surface model rebuild completed. The project was subsequently taken to an

Assess gate in Q1 2014 but failed to enter the Select stage due to:

No clear line of sight of a development concept – a subsea tieback to the

proposed new Jackdaw Central Processing Facility (CPF) had been carried as

the reference development case but ongoing discussions with BG in the run up

to the gate concluded that no commercial offer would be forthcoming.

Financial exposure in a low case sub-surface outcome – due to the uncertainty

in hydrocarbon presence in the East and West of the Courageous reservoir, the

low case economics presented at the Integrated Gate Review highlighted

significant downside exposure. Further appraisal of the field was recommended

to improve the low case economics, which also required the project to remain

within the Assess stage.

Throughout 2014 the project remained in the Assess stage. A Value of Information

exercise was conducted to determine the value of further appraisal. This led to the

decision to appraise the East of the Courageous discovery in Q4 2014. Due to licence

expiry constraints, it was necessary to progress the facilities work scope with a view to

having an approved Field Development Plan (FDP) in place by the end of 2015. The

facilities work was progressed on the basis of successful appraisal in the East and carried

forward the development options screened at the 2014 Assess gate.

The Courageous 30/2a-11 appraisal well was subsequently drilled in November 2014,

encountering the top reservoir 78ft deep to prognosis, with the reservoir section water

bearing. This significantly reduced the expected recoverable resource estimates for the

Courageous discovery, such that the economic feasibility of the development options

being considered could not be demonstrated. Following the appraisal well, further high

level option screening was conducted with the aim of identifying an economically viable

development solution.


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3. Licence Synopsis

The P.098 licence was initially granted in 1970 as part of the 3rd seaward round. It was

subsequently split into sub-areas of pre-Tertiary (including the Jackdaw discovery) and

post-Tertiary by way of an operating agreement amendment, with different equity

partnerships.

This document covers relinquishment of the post-Tertiary sub-area of the licence only, of

which Maersk Oil North Sea UK Ltd are operators with 99.5% equity, whilst GDF SUEZ

E&P UK Ltd holds the remaining 0.5%.

The end of the second term of this licence is 8th June 2016.


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4. Work Programme Summary

The original work programme for the P.098 licence was to carry out seismic survey work

and to drill at least one exploration well in the licence area. Both of these requirements

have been met for licence P.098. Under the licence agreement, hydrocarbons were

required to be commercially produced prior to the licence expiry in June 2016. The

appraisal well 30/2a-11 was drilled in late 2014 in an attempt to progress this objective.

4.1. Well results summary

Following agreement with DECC that the firm well commitment for licence P.2054 in

block 30/1g could be moved to 30/2a and still satisfy that component of the licence

commitment, appraisal well 30/2a-11 was drilled in 2014. The well location also

provided the opportunity to side-track into the Audacious discovery to the east, in the

event of a successful Courageous appraisal result.

The main objectives of the well were to confirm the presence of reservoir and the depth

of the free-water level within the Forties Sandstone interval. These objectives were only

partially met, with the well concluded after a short interval of Forties Sandstone was

penetrated, owing to the top reservoir being encountered below the expected oil-water

contact and found to be water-bearing. Weather conditions dictated that only 30ft of

Forties Sandstone could be penetrated prior to the drill string having to be hung-off, with

the decision to finish the well at that depth taken during the period of poor weather.

Top Forties F7 (Ichron scheme) was encountered 79ft deep, 15ft below the expected oil-

water contact (Figure 4.1). The seismically derived Top Sele horizon was encountered

75ft deep to prognosis. Porosity and Sw were not calculated across the penetrated

reservoir owing to the offset of the porosity tools from the bit within the LWD tool string.

Gamma Ray logs confirmed the presence of sand, whilst resistivity logs confirmed the

reservoir to be water-bearing. The penetration of a Forties age sandstone was confirmed

by biostratigraphic analysis. Given the unsuccessful Courageous discovery appraisal well,

a side-track into the Audacious discovery was not undertaken.


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Figure 4.1. Stratigraphy encountered in 30/2a-11 compared with the pre-appraisal

model (dashed lines). See Figure 6.4 for well locations.


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5. Database

An overview of the well and seismic database used in the analyses of the Courageous

discovery is summarised in section 5.1.

5.1. Courageous Well Database

The log data, core data, formation pressures and well test data available over the Forties

Sandstone interval in the wells that define the Courageous accumulation are presented in

Table 5.1. A further ten Courageous offset wells were considered in the building of the

Courageous static 3D model to constrain semi-regional facies models. Petrophysical

models were constructed only with the wells noted in Table 5.1. A more specific

Courageous discovery area of interest dynamic model was “cookie cuttered” out of this

static model.

Well GR Resistivity Neutron Density Sonic Core Formation

Pressures

DST

30/2-1 √ √ √ √ √ √ √

30/2a-5 √ √ √ √ √ √ √ √

30/2a-5Z √ √ √ √ √ √ √

30/2a-5Y √ √ √ √ √ √

30/2a-9 √ √ √ √ √ √ √

30/2a-9Z √ √ √ √ √ √ √

Table 5.1. Key wells used in the evaluation of the Courageous discovery.

Routine core analysis was available on all cored intervals whilst special core analysis was

undertaken in the 30/2a-5 and 30/2a-9 wells. Offset wells used for facies modelling

were; 30/1-1, 30/1c-2A, 30/1d-12, 30/2a-2, 30/2a-6, 30/2a-7, 30/2a-7Z, 30/2a-8,

30/3a-1, N1/2-1.

5.2. Seismic Database

The seismic dataset used for the geophysical interpretation of the Courageous discovery

was the CGG owned Cornerstone survey (Figure 5.1). This was due to data availability

and lateral coverage of this dataset which allowed regional wells to be incorporated into

the analysis. This was originally acquired by Veritas in 2001/2, at a 12.5 group interval,

60 fold data into a 6km cable.

This was reprocessed in 2010 in a regional Quad 30 mega merge from CGG as a full

PSDM Kirchoff migration with 25m line and trace spacing. The interpretation of

Courageous addressed an area defined by Line range 10800-13496, Trace range 20800-

24192 and TWT range 0-4secs.


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Figure 5.1. Map showing extent of seismic data across the Courageous licence.

Additional seismic data sets not used are also shown in addition to a 2013 Absolute

Acoustic Impedance volume which was generated by Maersk Oil for the Ockley discovery.

All of these seismic datasets are owned by CGG whilst differentiated by vintage for

clarity.

A CGG Broadseis dataset was additionally acquired over the greater Courageous area,

primarily to improve imaging of the deeper Jurassic structures but it provided an

alternative seismic volume to interpret upon. In the shallower Palaeocene interval where

top Sele is the key seismic marker, little variation was observed between all of the

datasets (Figure 5.2).


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Figure 5.2. The three picks of the Top Sele, picked on the Veritas (Helix), Cornerstone

and Broadseis volumes. In general the Veritas dataset gives the shallowest picks and the

Broadseis dataset the deepest. The differences appear to be constants between the

different vintages of survey. In this case the constant would be incorporated into the

calibration of the depth conversion scheme used for that survey and would become

insignificant. Only variations around that constant value would be significant. All of

these vintages of seismic dataset are owned by CGG (Veritas 2006 PSDM - seismic

dataset displayed). Data courtesy of CGG.


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6. Further Technical Work Undertaken

6.1. Seismic Technologies

An AVO effect is observed across the Courageous discovery, as indicated by the ratio of

the Far/Near envelope (Figure 6.1). Seismic Inversion has been undertaken twice on

seismic data in this area but with limited success. Neither of the inversion products has

been able to conclusively separate lithological or pore-fill parameters. The lack of

conformance to a closure and well based rock physics modelling indicate that the AVO

response appears related to Lithology only. It does appear to define the top of the main

Forties sand with reasonable confidence on a semi-regional basis but does not

differentiate intra-reservoir lithological variability.

Figure 6.1. Timeslice at Top Forties level of the Far/Near amplitude ratio. Far

amplitude greater than Near is gold, Near amplitude greater than Far is pale blue. This

correlates with a subjective judgement of higher sand/shale ratio but has no apparent

relationship to fluid-fill (CGGV Cornerstone - input seismic dataset displayed). Data

courtesy of CGG Cornerstone 3D.

Other seismic attributes such as residual dip and various forms of frequency

decomposition were used to assess gross facies distributions, particularly when

integrated with core based sedimentological interpretations. This allowed greater

confidence to be placed upon inclusion of general channel, lobe or sheet distributions in

the 3D geological model. The residual dip attribute allowed shallow dips to be identified

which might have controlled depositional patterns (Figure 6.2a & b). Frequency

decomposition was used to identify depositional features (Figure 6.3a) and latterly other

features, either structural or stratigraphic, by inclusion of the higher frequency data

(Figure 6.3b & c), commonly assumed to be mostly noise but found to be consistent with

previous frequency decomposition outputs but of higher resolution.


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Figure 6.2a. Residual Dip image 170ms above Top Ekofisk. Cutting through the lower

Forties interval, it shows clear structural control of the deposition pattern. This structure

may have been caused by movement of the Jurassic structure beneath, or dewatering

and compression of the underlying upper Cretaceous in the surrounding thick Cretaceous

areas (CGGV Cornerstone - input seismic dataset displayed). Data courtesy of CGG

Cornerstone 3D.


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Figure 6.2b. Residual Dip image 200ms above Top Ekofisk. The graben of west

Courageous is filled and two channels flow round the Courageous ridge to the east. East

of Courageous, the most westerly of these two channels skirts past the Jackdaw Forties

Sandstone discovery (Audacious, wells shown in green) and across the eastern side of

Courageous, while the easterly channel goes further eastwards into more open terrain

then southwards over the Blane Field. There is higher ground between the two channels,

hence the Jackdaw Forties Sandstone discovery (Audacious) sands may not be directly

correlatable with the Blane Field Forties sands (CGGV Cornerstone - input seismic dataset

displayed). Data courtesy of CGG Cornerstone 3D.

Figure 6.3a. Horizon slice near to Top Forties over the greater Courageous area

through a Frequency Decomposition volume. The narrow channel supplying sediment to

the west of Courageous is labelled A, whilst the broader channel round the east of the

Courageous high labelled B, indicates flow south over the east of Courageous and forms

a fan of grey and blue in this image (CGGV Cornerstone - input seismic dataset



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Figure 6.3b. Top Forties reservoir level in a high frequency Frequency Decomposition

volume, computed assuming frequencies were present that had previously not been seen

or were shown to be at least 30dB below the dominant. The visible lineations,

highlighted with white arrows, represent possible structural or stratigraphic boundaries in

the reservoir (CGGV Cornerstone - input seismic dataset displayed). Data courtesy of

CGG Cornerstone 3D.


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Figure 6.3c. Timeslice 160ft below Top Forties through a Frequency Decomposition

volume. Detail of some of the channels that feed Courageous are highlighted in green

and yellow. The blend uses 50Hz, 60Hz and 80Hz in Red, Green and Blue channels. The

image also shows some of the detail still visible in the high frequency tail of the

frequency spectrum at reservoir level (CGGV Cornerstone - input seismic dataset


6.2. Hydrocarbons Initially In Place

The Courageous reservoir is the Palaeocene Forties Sandstone comprising interbedded

deep marine sandstones and shales. Four major biostratigraphically defined reservoirs

zones have been interpreted and correlated semi-regionally, based upon a framework of

flooding surfaces represented by shales. The Courageous discovery is located within the

distal and marginal part of the Forties Fan, with reservoir sands deposited by turbidite

lobes. The sand prone parts of these lobes are present around the northern and eastern

flanks of the Courageous structure but are non-reservoir in their distal parts across the

south of the discovery. Well based average Net to Gross (net reservoir) ranges between

45% and 63%, average porosity ranges between 16% and 20% whilst average water

saturation is elevated, ranging between 53% and 79% (net reservoir). Permeability

ranges between 0.01mD and 170mD.

The top reservoir map is shown in Figure 6.4. This is not the top Forties Formation but

the first Forties reservoir sand in this area and represents the updated depth structure,

incorporating the 30/2a-11 appraisal well drilled in 2014. Both the static and dynamic

P90, P50 and P10 models were updated with this surface (Figure 6.5) and a depth

uncertainty workflow was undertaken to confirm that these models sat appropriately

within the GRV range, used as a proxy for STOIIP. This built upon an uncertainty

workflow undertaken prior to the 30/2a-11 appraisal well, which combined a multiple

scenario static modelling approach with a probabilistic dynamic approach, undertaken to


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assess the impact of the key subsurface uncertainties of reservoir architecture, free-

water level and development well productivity.

Figure 6.4. Post-appraisal Top F7 depth map, which represents the top reservoir (not a

direct comparison with Top Forties). The 30/2a-11 well resulted in the eastern terrace of

Courageous being significantly deeper than prognosed.

Figure 6.5. Post-appraisal cross-section through the 3D static model, highlighting the

change in top reservoir structure due to the 30/2a-11 appraisal well, facilitated within the

model by use of an Active Cell property as is shown.


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Table 6.1 shows the range of in-place oil and gas volumes for the Courageous discovery,

based upon the post 30/2a-11 update.

Hydrocarbons in Place P90 P50 P10

STOIIP (MMbbl) 59 82 113

GIIP (Bscf) 156 220 300

Total (MMboe) 86 120 165

Table 6.1. Courageous discovery HIIP summary.

6.3. Resources and Production Forecast

From the assessment completed in Q1 2014, it was concluded that the downside case for

the Courageous project carried too much risk, hence de-risking of the project was

required.

The presence of hydrocarbon in the western and eastern areas of the reservoir carried a

high degree of uncertainty, related predominantly to the presence and distribution of

sand. The technical assessment indicated the best location for the appraisal well was in

the eastern area of the discovery, because of larger in-place hydrocarbon volumes and a

conceptual model of improved reservoir quality compared with the western area.

Additionally, an appraisal side-track could reach the Audacious discovery from a well

located in 30/2a. A commitment well was however pending on the 30/1g block,

associated with the P.2054 licence award in the 27th round. On the basis of the

technical/economical assessment of the western and eastern appraisal locations, a

request was made to DECC to move the commitment well from 30/1g to 30/2a.

Approval to move the commitment well location was granted in July 2014.

Following the evaluation of 30/2a-11, which encountered top reservoir 78ft deeper than

prognosed, the static model was updated and numerical simulation work undertaken to

assess potential field development plans for Courageous. The base case Courageous

development consists of three horizontal development wells, each with 6,000ft reservoir

sections, located in the central area of the discovery, where in-place volumes have been

proven by wells 30/2a-5, 30/2a-5Y, 30/2a-9 and 3/2a-9Z. Hydraulic fracture stimulation

of the base case reservoir model was evaluated using multi-stage fracs in the horizontal

section of the wells but this was not considered as the base case development scenario.

Ultimate recovery P90 P50 P10

Gas (Bscf) 27.2 41.1 52.3

Oil (MMbbl) 6.7 11.3 16.2

Hydrocarbons (MMboe) 11.4 18.4 25.2

Table 6.2. Courageous Ultimate Recoverable Resources Summary.


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6.4. Well Engineering Overview

Prior to the drilling of the 30/2a-11 appraisal well in 2014, the reference case

development concept assumed a phased drilling approach, with four Courageous gas

lifted subsea production wells drilled prior to first oil and a further production well to be

drilled in the second year of production. This development concept required two drill

centres, with two wells planned from a Western centre and three from an Eastern centre.

Subsequently, the production well targets were updated to reflect the results of 30/2a-

11. The most south-easterly planned production well was removed from the

development concept and the orientation of the reservoir sections of the remaining wells

altered. A single drill centre, comprising three production wells was the resultant

reference case development concept, as shown in Figure 6.6.

Figure 6.6. Single drill centre production well trajectories. These wells all target areas

of the Courageous discovery which have been proven by the appraisal wells.

No significant flow assurance issues have been identified for Courageous. It should

however be noted that production chemistry studies performed to date have focused on

pipeline and facilities issues rather than any downhole issues. Potential downhole issues

are discussed below.

Courageous oil has a Wax Appearance Temperature of 31.5-36.5ºC, indicating that wax

formation will not present an issue for the lower completion (reservoir temperature

136oC) nor for the upper completion during normal production operations.

Based on crude assay data from atmospheric oil sample 1.30 (well 30/2a-5) the

Courageous Asphaltene (C7) content, measured by IP143, is 0.15% m/m. Asphaltenes

are therefore not expected to pose a risk to the lower completion.

From the ion analysis of water samples from well 30/2a-5, it is apparent that there could

be a risk of scale formation (particularly calcite scale) in the production flowlines and/or

wells. Calcite scale risk may be exacerbated above the gas lift injection mandrels, due to

the introduction of lift gas with a lower CO2 mol% than the Courageous gas. This has yet

to be confirmed by detailed calcite scale prediction modelling. Halite scale risk is deemed


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to be low due to the relatively low TDS of Courageous formation water (~100,000).

However, the anticipated high volumes of gas production and high reservoir temperature

mean that a halite scale risk review is recommended. Sand production has not been

experienced in any of the DSTs and geomechanical studies suggest significant sand face

failure is not expected under production conditions.

Courageous crude oil has a low water content. Later in field life, shearing of the oil and

produced water across the reservoir / well completion could lead to the formation of

stable emulsions. This has not been explored by production chemistry to date, but a risk

review is recommended.


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6.5. Development Concepts and Exports

The pre-appraisal Courageous discovery recoverable resources (P50 ~30 MMboe) align

with other fields in the North Sea that have historically been developed as tiebacks to 3rd

party host platforms. Figure 6.7 shows the available hosts in the area.

Figure 6.7. 3rd Party Tieback Options.

Preliminary flow assurance work suggests that 30km is the upper limit for a subsea tie-

back due to thermal (wax), slugging and hydraulic issues. At this point, the option to

produce Courageous via existing subsea infrastructure (e.g. Blane) or HP/HT wellhead

platforms (e.g. Jade) in the area is considered unlikely to be feasible, given the specific

flow assurance requirements.

Initial host discussions have been held with the relevant infrastructure operators within a

30km radius with a view to gauging the likely modifications required to integrate

Courageous fluids. Shearwater, Elgin and Judy have all stated that a Bridge Linked

Platform (BLP) will be required to access the main platform processing systems. Elgin

and Judy both have identified issues in providing a bridge landing point and therefore

technical feasibility is yet to be demonstrated. Shearwater would appear to be the most

likely host for a BLP in the area given that a bridge landing point was included in the

original design of Shearwater ‘A’ and the concept has been studied for a number of other

fields. Economic screening suggests that Courageous cannot support the CAPEX

associated with a BLP on its own and therefore some form of joint development would be

required to share development costs.


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The reference concept development case for Courageous is a tie-back to the Stella

facilities. The first phase of the Greater Stella Area (GSA) development of

Stella/Harrier/Hurricane is expected to start-up mid-2016. The development will see a

refit semi-sub (FPF-1) stationed over the main Stella field with oil and gas exported to

Norpipe (following initial period of tanker export) and CATS respectively. A schematic of

the development is shown in Figure 6.8.

Figure 6.8. Greater Stella Area Development Schematic.

Initial discussions with Ithaca have identified that it may be possible to use the reception

facilities (risers, inlet heater, separator, PWT) pre-installed for the Hurricane field giving

Courageous access to approximately 20 Mbpd liquid and 30 MMscfd gas processing

capacity. Hurricane is currently under appraisal and may now tie-in subsea via the Main

Drill Centre (MDC) manifold to access higher gas processing capacity through the

Stella/Harrier inlet system.

Preliminary flow assurance indicates that a Pipe-in-Pipe system will be required to

maintain fluid temperatures above the Wax Appearance Temperature (WAT) for all but

the shortest tie-back distances. Table 6.3 summarises the expected field architecture.

Pipeline Nominal Diameter Design Pressure Material Insulation

Production

Main: 10”-14”

(depending on host)

Infield: 6”- 8”

310 barg CRA Pipe-In-Pipe

Gas Lift Main: 4”

Infield: 3” Host Dependant Carbon Steel N/A

Electro-hydraulic

Umbilical Approx. 140mm OD - - -

Table 6.3. Provisional Courageous Flow-line Requirements.


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7. Resource and Risk Summary

The only prospectivity identified in the post-Tertiary sub-area of licence P.098 are the

Courageous and Audacious discoveries. The resource summaries for these discoveries

are shown in Table 7.1 and 7.2.

Recoverable Resources (MMboe) P90 P50 P10

Pre-appraisal 11.9 30.5 47.6

Post-appraisal (Q1 2015) 11.4 18.4 25.2

Table 7.1. Courageous discovery resource summary pre and post the 30/2a-11 appraisal

well.

Resource and Risk Summary

Discovery Name

Stratigraphic level

Unrisked recoverable resources Geological Chance of Success

Risked P50

(MMboe)

Oil (MMstb) Gas (Bcf)

L M H L M H

Courageous Forties Fm 6.7 11.3 16.2 27.2 41.1 52.3 100% 18.4

Audacious Forties Fm 4.5 8.12 17.9 2.4 4.4 9.9 50% 4.5

Table 7.2. Resource and risk summary – Courageous and Audacious. The Audacious

discovery volumes shown represent the pre 30/2a-11 appraisal well assessment. They

are considered to have been negatively impacted by the appraisal result.


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8. Conclusions

At this point in time, Maersk Oil cannot see a reasonable route for economic development

of the Courageous discovery that can be achieved within the stipulated licence timeframe

due to the combination of a) the limited size of the proven recoverable volumes following

the appraisal well drilled end of 2014 and b) the current low oil and gas prices.

In terms of remaining prospectivity, Maersk Oil does not identify any other undeveloped

discoveries or prospects which are economically attractive. In particular, appraisal well

30/2a-11 has down-graded the size of the Forties Sandstone reservoired Audacious

discovery (30/2a-6), which is considerably smaller than the Courageous discovery. The

Audacious discovery was the only other significant potential resource recognised in the

post-Tertiary sub-area.

In agreement with GDF SUEZ E&P UK Ltd, Maersk Oil are consequently surrendering sub-

area post-Tertiary of licence P.098.

Maersk Oil confirms that DECC is free to publish this report and that all 3rd party

ownership rights have been considered and appropriately cleared for publication

purposes.

Documents

Relinquishment Report P.098 Block 30/2a Post-Tertiary Area ... · Round under licence P.2054 by Maersk Oil and GDF SUEZ E&P UK Ltd. Maersk Oil operates both licences with equity of