Final Licence Relinquishment report
P1934
UKCS Blocks 210/7, 12 & 13
Date 22.12.2015
P1934 Relinquishment report
1 Licence Information
1
2 Licence Synopsis
1
3 Work Programme Summary
3
4 Exploration Activity
5
5 Resource and Risk Summary
11
6 Conclusions
12
7 Clearance
12
List of figures
2.1
3.1
4.1
4.2
4.3
4.4
4.5
4.6
Location map P1934 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Comparison of seismic data quality . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3
Well and Seismic Database . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6
Seismic section and geomodel . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7
Reservoir depositional setting . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8
Channel features on the East Shetland High . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8
BCU map with present day temperature . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9
Drainage patterns for hydrocarbon migration . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10
List of tables
5.1 Key parameters for resource calculations. *The reservoir is assumed to b . . . . 11
5.2 Resource and Risk Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12
P1934 Relinquishment report
1 Licence Information
Licence Number: P1934
Block Numbers: 210/7, 12 & 13
Area: 588 km2
Licence Round: 27th
Awarded: 1st January 2013
Drill\Drop: 1st January 2019
End of Initial Term: 31st December 2018
Licence Type: Frontier
Initial license holders: Norwegian Energy Company UK Limited (Operator) 100%
No later changes
All permissions to publish have been obtained.
2 Licence Synopsis
Licence P1934, blocks 210/7, 12 and 210/13 was awarded as a Frontier licence in the 27th UKCS
licensing round to Norwegian Energy Company UK Limited (Noreco).
Structural elements
The licence is located,Figure 2.1, in the South Western end of the Magnus Basin on the northern edge
of the East Shetland High.
Confined basin
• Only reasonable sedime
Underexplored
• Exploration has been foc
fault blocks and flanking
• 5-6 wells drilled in the ba
Jurassic and older sedim
marginal high and fault b
210/10-1, 210/15b-4, 21
Thick Cretaceous bas
Figure 2.1 Location map P1934
1 Licence Information
Cenozoic covers basin
highs
Ref.: pres-external
Page 1
P1934 Relinquishment report
The primary reservoir target, the Ida lead was Paleocene deep marine sandstones, with gas, in a
stratigraphic trap. The work programme to obtain 650 km of 2D long offset seismic and reprocess
600 km of existing 2D data was completed. Further work including a basin modelling study and a
study of the Upper Jurassic structural framework was also completed. The additional 2D seismic lines
together with the angle stacks from the reprocessing were useful for observation of channel like
features within the Paleocene but were too few for definition of a prospect. 3D seismic data is
required.
Resource potential is estimated at 382 - 908 - 1616 bcf of gas for Ida lead
Volume potential (showing P90 - P50 - P10) have been calculated for the Ida lead based on a large
stratigraphic trap, assuming one large connected prospect. This is probably unrealistic and 3D seismic
data is required to further delineate the volumes and risk.
Page 2
2 Licence Synopsis
P1934 Relinquishment report
3 Work Programme Summary
Initial work programme:
Start date 1st January 2013
Obtain 650 km of Long offset 2D seismic data
Reprocess 600 km 2D seismic
Carry out Basin modelling studies
drill or drop within 6 years
Obtain 650 km of 2D long offset seismic data
Noreco acquired the TGS non-proprietary 2D long offset survey data from the NSR-06,07,08,09 and
10 surveys, covering 650 km. Noreco also purchased 1104 km of the CFI_NSR_MAG13RE
reprocessed seismic data. This dataset includes angle stacks in addition to the full stack data and also
access to the gathers. The data is of good quality, Figure 3.1 and naturally gives a much better basis
for both spacial definition and AVO-type analysis than the existing dataset 2D seismic data sets. The
lower figure shows enhanced continuity and significantly better fault definition.
NSR10-41189 original
NSR10-41189 reprocessed
Ref.: 137350-v1
Figure 3.1 Comparison of seismic data quality. Seismic courtesy of TGS
3 Work Programme Summary
Page 3
P1934 Relinquishment report
Further work
Analysis of the angle stack volumes were used for reconnaissance AVO.
A basin modelling study was carried out using all the available wells in the area.
Page 4
3 Work Programme Summary
P1934 Relinquishment report
4 Exploration Activity
The exploration activity within the license and surrounding area has focused on developing a new
play model for Tertiary reservoir sequences. In particular the Paleocene which is a play not proven in
this area. The Palaeocene has been a secondary target in several older exploration wells drilled within
the Magnus basin but no discovery has been made. However, well 211/7a-2 encountered a 10 m oilbearing sand of good reservoir quality, thereby demonstrating that reservoir quality sands of this age
have the potential to be present.
Database
The database at the end of the licence period is shown in Figure 4.1. A number of 2D seismic surveys
were available. These were phase matched, filtered and smoothed.
The well database including all released wells and proprietary wells in Norway is also shown. The
most important well is 210/13-1 which provides a direct tie to the 2D seismic database. The well has
some poorly developed sandstones in the Lista Formation (Heimdal sandstone member equivalent.)
Noreco acquired the TGS non-proprietary 2D long offset survey data from the NSR-06,07,08,09 and
10 surveys, covering 650 km. Noreco also purchased 1104 km of the CFI_NSR_MAG13RE
reprocessed seismic data. This dataset includes angle stacks in addition to the full stack data and also
access to the gathers. The data is of good quality and naturally gives a much better basis for both
spacial definition and AVO-type analysis than the existing dataset 2D seismic data sets.
4 Exploration Activity
Page 5
P1934 Relinquishment report
350000
355000
360000
365000
370000
375000
380000
385000
210/5-1
6860000
6860000
6865000
6865000
345000
210/10-1
6830000
6835000
6830000
6835000
210/13-1
6840000
6840000
6845000
6845000
6850000
6850000
6855000
6855000
210/4-1
6815000
6825000
6815000
210/15a-3
210/19-3
6810000
6810000
6820000
6820000
6825000
210/14-2
210/14-1
210/19-4B
345000
350000
355000
360000
0
365000
370000
375000
380000
6805000
6805000
210/19-1 210/20-1
210/19-2
210/20-3
385000
2500 5000 7500 10000 12500m
Ref.: pres-confidential
1:300000
Figure 4.1 Well and Seismic Database. Red polygon is the Ida lead outline.
Page 6
4 Exploration Activity
P1934 Relinquishment report
Prospectivity Update
The play concept for the Ida lead is; deep marine sandy turbidites of Paleocene age with stratigraphic
trapping in the updip and lateral directions. The additional 2D seismic has helped with defining the
updip pinchout of the sequences within the Paleocene but is too sparse to help with reservoir presence
and quality. The seismic stratigraphy and the prospective level are illustrated in Figure 4.2.
Figure 4.2 Seismic section and geomodel. Seismic courtesy of TGS
UKCS 27th Licensing Round
Blocks 210/7, 210/12 & 210/13
June 2012
4 Exploration Activity
Page 7
P1934 Relinquishment report
The reservoir unit is thought to represent an Intra Palaeocene sand-dominated shoreface depositional
system fringing the then exposed basement rocks of the East Shetland High. A palaeogeographic map
is shown in Figure 4.3. Sedimentary environments within such a system are also detailed.
Figure 4.3 Reservoir depositional setting
This interpretation is based on strong seismic amplitudes on top of a forward stepping seismic
amplitude pattern upflank of well 210/13-1. Channelised features may also be recognised on the
seismic cross section in Figure 4.4. The shallow marine sandstone wedge pinches out updip onto the
margins of the East Shetland High, and grades downdip into shales of a mud-dominated offshore
environment
Figure 4.4 Channel features on the East Shetland High. Note the high amplitude anomolies within the
Paleocene sequence.
Seismic example courtesy of TGS
Ref.: 137350-v1
Page 8
3
4 Exploration Activity
P1934 Relinquishment report
The main target reservoir sequence is the Heimdal sandstone member within the Lista Fm. The
nearest well, 210/13-1, encountered primarily silt and mudstones but some sandstone stringers
described as fine to course grained which give positive indications of sand in the system. The most
likely sediment source is the East Shetland High, to the south, with sediments being deposited in a
restricted basin setting. Reservoir quality at these relatively shallow depths is likely to be very good in
the best facies.
Seal is dependent on stratigraphic pinchout in both updip and lateral directions which is difficult to
control on 2D seismic data.
Top seal is assumed to be some 500-800m of Palaeogene shales with lateral seal provided by the
basement rocks of the East Shetland High and base seal is provided by basement rocks of the East
Shetland High and Upper Cretaceous shales.
Petroleum systems
The Ida lead is assumed to be sourced from the Upper Jurassic Kimmeridge shale in the Magnus
Basin. Upper Jurassic clay successions have been found in wells in the basin, but its quality as a
source rock is not proven. Oil and gas shows in the basin, and the presence of oil filled sands in
211/7a-2 demonstrate that an active source is present.
Regional modelling of present and past temperatures indicates that, the shale is immature at presentday burial depths in the area of the defined lead. Down-flank it is oil mature, and within the main
Magnus Basin depocenter it is mature for gas generation as illustrated in Figure 4.5. The large
thickness of Cretaceous sediment within the main Magnus Basin depocenter has led to oil generation
from potential Upper Jurassic Kimmeridge shales starting in Late Cretaceous times and becoming
more and more gas mature throughout Palaeogene and Neogene. Gas is, therefore, considered the
most likely hydrocarbon type.
Temp gradient = 38°C/km
Average surface temp = 6°C
Figure 4.5 BCU map with present day temperature. Immature - Dark green, Oil mature-Light green to orange,
Gas mature -red
4 Exploration Activity
Page 9
P1934 Relinquishment report
As part of the basin modelling study an analysis of the drainage patterns are shown in Figure 4.6.
Three surfaces are modelled: Top Balder, Base Cretaceous and Top Cretaceous. With the current
understanding of reservoir distribution none of the maps show positive migration for Ida.
Basin modelling study – drainage pattern
•
•
•
At three levels
Dark red polygon is BCU depth at 4000 m
Black polygon id Ida outline
Figure 4.6 Drainage patterns for hydrocarbon migration
Page 10
4 Exploration Activity
P1934 Relinquishment report
5 Resource and Risk Summary
Resource estimates
The resource estimates have been calculated using the GeoXTM probabilistic modelling software
package. A wedge-shaped model has been used to reflect the reservoir thickness distribution, with a 0 m
minimum thickness at the pinch-out and 40 m at the down-dip limit. A mode thickness of 100 m is
used. All input parameters in the table below are reported as minimum, most likely and maximum
cases.
Table 5.1: Key parameters for resource calculations. *The reservoir is assumed to be a wedge
model, therefore no maximum thickness. Gas in place numbers reported reflect associated
gas.
Min
Total area (km2)
Most likely
Max
46
75
108
100
250
400
14
22
30
0
100-40
2090
4632
7095
Net to gross %
30
40
50
Porosity %
25
30
35
Hydrocarbon saturation %
50
75
80
110
115
120
60
70
75
Gas in place bcf
532
1283
2273
Gas reserves bcf
382
908
1616
Height of closure (m)
Net reservoir (m)
Thickness (crest-mid-base) (m)*
Gross Rock Volume (km2/m)
Gas expansion factor
Recovery factor % (gas)
Risk parameters
The reservoir risk is set to 0.7 based on the seismic evidence of channel-like features and the
structural location. Lack of well penetration of the actual reservoir adds to the risk.
The trap risk is set to 0.5 due to relatively thin section of top seal comprising silts and clays, and the
lateral seal in 3 directions as well as the base seal required to be the basement rocks of the East
Shetland High and or the Upper Cretaceous mud rich sequences.
Mature source rocks are considered to be proven in the Magnus Basin based on the shows in some
wells along the eastern and western margin of the Magnus Basin. However, some wells penetrated
possible Kimmeridge Clay Formation, but none of these have confirmed any "hot shale" presence.
Migration along Early Cretaceous fault zones may lead to focused charge point and is dependent of
any porosity as the fault zone diminishes in lateral extent upwards. The basin modelling study
indicates that there could be a drainage/charge capacity risk. Charge and migration risk is set to 0.5
The shallow burial depth may cause issues with hydrocarbon preservation due to the low pressure
and temperature. The retention risk is set to 0.5.
5 Resource and Risk Summary
Page 11
P1934 Relinquishment report
Risk summary
The overall chance of success for the Ida lead is 9% which is high risk. Resource potential, however is
large. 3D seismic data is required to map out the sequences and amplitude anomalies which may be
expected at these reservoir depths.
The resource and risk is summarised in Table 5.2.
Table 5.2 Resource and Risk Summary
Resource and Risk Summary
Unrisked recoverable resources
Prospect
Lead
Discovery
Name
P
L
D
Ida
P
Stratigraphic
level
Oil MMbbls
Low
Paleocene
Central
Gas BCF
High
Low
Central
High
382
908
1616
Geological
Chance of
Success %
Risked
P50
MMboe
9
15
6 Conclusions
It has not been possible to lower the risk on Ida within the current work programme. Chance of
reservoir presence has increased but migration and charge capacity have decreased. 3D seismic is
required to further evaluate the area.
7 Clearance
Norwegian Energy Company UK Limited (Noreco UK) confirm that DECC is free to publish this
report and that all third part ownership rights (on any contained data and/or interpretations) have
been considered and appropriately cleared for publication purposes.
Page 12
5 Resource and Risk Summary