The document summarizes a study on the potential for geological storage of carbon dioxide (CO2) in the southern Baltic Sea. It finds that there is large theoretical storage capacity beneath a thick caprock. However, the maximum injection rate depends on formation thickness and permeability. Dynamic modeling of a region in southern Sweden showed it could store CO2 from a limited number of industrial facilities. More data is needed, especially in areas like offshore Latvia, to identify suitable storage sites at a scale needed for the entire Baltic Sea region's projected emissions. Recommendations include reinterpreting existing seismic data and acquiring new data to better characterize reservoirs, seals, and fault structures.
Unlocking the Potential of the Cloud for IBM Power Systems
Unlocking Baltic Sea CCS Potential
1. BASTOR2 - Unlocking the potential for CCS in the
Baltic Sea
Webinar – 14 April 2015, 1800 AEST
2. Per Arne Nilsson
Per Arne brings thirty-five years of experience as
industry line manager and management consultant.
His international leadership experience includes
resident roles in Europe, Southeast Asia and the
Middle East. Over the last ten years he has become
ever more involved in the research and development
of Carbon Capture and Storage, CCS. He was the
Project Manager for the Bastor project (Baltic
STORage of CO2). Currently he is heading up the
work on a Strategic Research and Innovation Agenda
for the Swedish process industry in the view of
reduced CO2 emissions. He is also coordinating the
establishment of a Baltic Sea region CCS expertise
network.
3. Auli Niemi
Auli Niemi is Professor at Department of Earth Sciences,
Uppsala University, Sweden, heading the geohydrology
research group. Her earlier affiliations include Research
Professor at Technical Research Centre of Finland,
Visiting Professor at Royal Institute of Technology,
Stockholm, Sweden, visiting researcher at ETH, Zurich
and research associate at LBNL, USA. She has thirty
years of experience in characterization of flow and
transport in geological media. Within CCS research, she
has recently completed heading the large-scale
integrating EU FP7 project MUSTANG with focus on
geological storage in saline aquifers and is presently
Work Package leader in EUs ongoing CCS related R&D
projects TRUST, PANACEA and CO2QUEST. In the
Swedish/Baltic Sea CCS projects Bastor and
SwedestoreCO2 she and her research group have
especially worked on geohydrological/dynamic modeling
aspects of the storage.
4. QUESTIONS
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5. It is about building enough knowledge
Bastor – Baltic Storage of CO2
Per Arne Nilsson, Project Manager Bastor 2
14th April 2015
7. BASTOR –
Baltic Storage of CO2
Geology
Environmental Impact
Communication and Acceptance
International Law
Infrastructure for Transport
[2012 – 2014]
9. Is this idea advisable, considering the possible
Environmental Impact?
There is rich generic knowledge of the environmental state of the
Baltic Sea
The Nordstream and OPAB EIA’s built a genuine, industrial base for
what must be controlled in the exploration and deployment phases
The project delivered a checklist and a work plan for an EIA for a test
drilling and injection project
A serious environmental approach is one of a few
avenues to building sufficient general acceptance for
storage of CO2 under the Baltic Sea waters!
10. So, overall, what did we learn?
There are opportunities for CO2 storage
– At industrial scale from the Swedish sector of the Baltic Sea
– At (larger) regional scale, potentially further East
– Expanded regional collaboration is a prerequisite
Transboundary transport and storage necessary but international law
is not (yet) coming in support
Transport is (inter-) national infrastructure, prompting government
initiative
Building public support relates to the perception of climate threats and
to how environment impact can be kept in check
For industry, 2050 is only one or two investment cycles
away, so early action is of essence!
11. A vision to stretch for?
A Swedish demonstration project based
on SSAB in Oxelösund and/or Cementa in Slite
Storage from the Swedish sector in the closed Dalders
structure
Initially ship transport but growing into a pipeline system
Allows basically the project to operate under
current legislation
12. BASTOR – three critical questions:
How do we develop the necessary cooperation between
governments and industry?
How can we at sufficient speed mobilize enough resources for
research – and results?
How do we create effective incentives for base industry to reduce
emissions, while strengthening its international
competitiveness?
13. Post BASTOR – the immediate legacy:
Strategic Swedish Research
and Innovation Agenda
– Some 20+ partners, from
industry, academy and
agencies
– Proposed way forward to be
presented summer 2015
CCS Expertise Network
– Initiated by the Baltic Sea States
through the
Baltic Sea Region Energy
Cooperation (BASREC)
– In support of long term
development towards regional
CCS deployment
14. BALTIC CARBON FORUM 2015
INVITATION & PROGRAMME
2nd Baltic Sea Region CCS Conference
Welcome to the 2nd regional CCS Conference in Tallinn, 22nd-23rd April, 2015
in the Radisson Blu Hotel Olümpia, Tallinn.
Registration and hotel information on http://basrec.net/ccs-initiative/conference/
16. PRELIMINARY ANALYSIS AND MODELING OF THE
GEOLOGICAL STORAGE POTENTIAL OF CO2 IN
THE SOUTHERN BALTIC SEA
Auli Niemi
Uppsala University
Webinar by Global CCS Institute 14.4.2015
17. Co-workers
Zhibing Yang, Uppsala University, Sweden
Byeongju Jong
Tian Liang
Fritjof Fagerlund
Saba Joodaki
Richard Vernon, SLR Consulting, Irland
Nick O’Neill
Ric Pasquali
18. OUTLINE
• Preliminary CO2 storage capacity
estimates
• Static Modelling
• Dynamic modelling for selected regions
• Conclusions and Recommendations
19. THE STUDY AREA
• The study area is defined as previously mapped Palaeozoic
sedimentary basins in the Baltic Sea Area
• Cambrian reservoirs deeper than 800m below seabed are the best
storage sites
• Some potential in depleted oil and gas fields
• Saline aquifers in border monoclines have significant storage
capacity
Source: after Sliaupa S., 2009
21. RANKING OF BALTIC SEA SUB BASINS
FOR CO2 STORAGE
• Four main sub basins identified and ranked
in order of suitability for CO2 storage
• The border zones have potential storage
capacity in saline aquifers
• Existing oil and gas fields have some storage
capacity (e.g. Lotos refinery in Gdansk and
B3 Field offshore Poland)
Rank Basin Characteristics Score
1 Slupsk Border Zone Proven reservoir/seal pair, moderate size structures, offshore, large saline aquifer,
limited faulting, good accessibility, <500kms to strategic CO2 sources
0.76
2 Gdansk-Kura Depression Existing oil and gas production infrastructure, moderate sized structures, offshore,
fair accessibility, >500kms to some strategic CO2 sources
0.75
3 Liepaja Saldus Ridge Proven reservoir/seal pair, moderate size structures, offshore, fair accessibility,
<500kms to strategic CO2 sources
0.75
4 Latvian Estonian Lithuanian
Border Zone
Proven reservoir/seal pairs, small structures, potential saline aquifer, only small area
sufficiently deep for CO2 storage, accessible, 250kms to strategic CO2 sources
0.71
22. BASTOR 2 STORAGE CAPACITY
Following the ranking of the Baltic Sea sub-basins, storage
capacity calculations have been completed using the GeoCapacity
(2009) methodology.
23. DISTRIBUTION OF STORAGE CAPACITY IN
DEFINED STRUCTURES BY COUNTRY
Estimated CO2 Storage Capacity
(106
tonnes)
Latvia Lithuania Poland Kaliningrad
Hydrocarbon - Generic Storage Potential 28.87 3.28 54.33
Hydrocarbon - Field Storage Potential 1.86 2.62
Saline Aquifer - Field Storage Potential 633.46 18.99
TOTAL 633.46 30.72 5.90 73.32
Total 743.4
25. CAPROCK INTEGRITY
• Three possible modes
of seal failure
– top seal failure,
– migration up the
bounding fault planes
– leakage across fault
plane
• Top seal failure potential is low.
• Seal failure resulting in leakage across fault planes is more likely, however
the risk of this is still low.
• There is little or no risk of upward leakage of CO2 along fault planes.
• Smaller scale cross cutting fault structures are likely to be open and these
need to be considered as potential pathways for upward migration.
26. Model region for dynamic modeling
Data Resolution 1000m
Porosity 4,30% - 20,60%
permeability 8,5 mD - 300 mD
formation top -225 m - -1756 m
Thickness 0 m# - 82 m
Table 1. Summary of the geo-hydrological properties mapping from the static model
27. DYNAMIC MODELING – Approach
• Three approaches of increasing complexity were used
– Analytical and semi-analytical models for pressure
evolution, for preliminary estimation of the optimal
number of wells in various conditions, testing of effect
of average medium properties
– Simulation of plume and pressure evolution using
two numerical modeling approaches: TOUGH2/MP &
Vertical Equilibrium Approach (Gasda et al., 2009)
– Evaluation of plume tip advancement after
completion of injection phase (TOUGH2 & Analytical
solution)
28. RESERVOIR PRESSURE BEHAVIOUR
• CO2 injection rates per well are
governed by reservoir thickness and
permeability;
• The base case injection capacity is
2.5Mt per annum
• Increasing the number of wells will
increase the injection rate 0 0.2 0.4 0.6 0.8 1 1.2
1.2
1.4
1.6
1.8
2
2.2
2.4
2.6
x 10
7
Injection rate per well (Mt/yr)
Pressure(Pa)
Thickness 40 m
Thickness 50 m
Thickness 60 m
0 0.2 0.4 0.6 0.8 1 1.2
1
1.5
2
2.5
3
3.5
x 10
7
Injection rate per well (Mt/yr)
Pressure(Pa)
Permeability 20 mD
Permeability 40 mD
Permeability 80 mD
0 1 2 3 4 5 6
1.2
1.4
1.6
1.8
2
2.2
2.4
x 10
7
Total injection rate (Mt/yr)
Pressure(Pa)
3 wells
5 wells
7 wells
29. RESERVOIR PRESSURE BEHAVIOUR
-analytical model
• CO2 injection rates per well are
governed by reservoir thickness and
permeability;
• The base case injection capacity is
2.5Mt per annum
• Increasing the number of wells will
increase the injection rate 0 0.2 0.4 0.6 0.8 1 1.2
1.2
1.4
1.6
1.8
2
2.2
2.4
2.6
x 10
7
Injection rate per well (Mt/yr)
Pressure(Pa)
Thickness 40 m
Thickness 50 m
Thickness 60 m
0 0.2 0.4 0.6 0.8 1 1.2
1
1.5
2
2.5
3
3.5
x 10
7
Injection rate per well (Mt/yr)
Pressure(Pa)
Permeability 20 mD
Permeability 40 mD
Permeability 80 mD
0 1 2 3 4 5 6
1.2
1.4
1.6
1.8
2
2.2
2.4
x 10
7
Total injection rate (Mt/yr)
Pressure(Pa)
3 wells
5 wells
7 wells
30. RESERVOIR PRESSURE BEHAVIOUR
• CO2 injection rates per well are
governed by reservoir thickness and
permeability;
• The base case injection capacity is
2.5Mt per annum
• Increasing the number of wells will
increase the injection rate 0 0.2 0.4 0.6 0.8 1 1.2
1.2
1.4
1.6
1.8
2
2.2
2.4
2.6
x 10
7
Injection rate per well (Mt/yr)
Pressure(Pa)
Thickness 40 m
Thickness 50 m
Thickness 60 m
0 0.2 0.4 0.6 0.8 1 1.2
1
1.5
2
2.5
3
3.5
x 10
7
Injection rate per well (Mt/yr)
Pressure(Pa)
Permeability 20 mD
Permeability 40 mD
Permeability 80 mD
0 1 2 3 4 5 6
1.2
1.4
1.6
1.8
2
2.2
2.4
x 10
7
Total injection rate (Mt/yr)
Pressure(Pa)
3 wells
5 wells
7 wells
31. RESERVOIR PRESSURE BEHAVIOUR
• CO2 injection rates per well are
governed by reservoir thickness and
permeability;
• The base case injection capacity is
2.5Mt per annum
• Increasing the number of wells will
increase the injection rate 0 0.2 0.4 0.6 0.8 1 1.2
1.2
1.4
1.6
1.8
2
2.2
2.4
2.6
x 10
7
Injection rate per well (Mt/yr)
Pressure(Pa)
Thickness 40 m
Thickness 50 m
Thickness 60 m
0 0.2 0.4 0.6 0.8 1 1.2
1
1.5
2
2.5
3
3.5
x 10
7
Injection rate per well (Mt/yr)
Pressure(Pa)
Permeability 20 mD
Permeability 40 mD
Permeability 80 mD
0 1 2 3 4 5 6
1.2
1.4
1.6
1.8
2
2.2
2.4
x 10
7
Total injection rate (Mt/yr)
Pressure(Pa)
3 wells
5 wells
7 wells
33. MULTIWELL INJECTION SCENARIOS
• Example TOUGH2
simulation showing
overpressure build up
after 50 years of
injection
• 3 injection wells
• 0.5 Mt/yr injection rate
50km
Year 50
Over pressure %
34. CO2 PLUME SPREADING
• Plume thickness at the end of
50 years of injection (right)
• Plume migration at 3,000
years after injection (below)
6km
Simulated CO2 saturation for the case of k-30mD, residual CO2 saturation 0.2 at 3000 years
35. CONCLUSIONS
• There is large theoretical storage capacity in the Baltic Sea basin
beneath a 900 metre thick impermeable caprock.
• The maximum injection rate is sensitive to parameters such as
formation thickness and permeability, and analyzing the effect of their
local variability fully does require more detailed modelling than was
possible in this preliminary study
• The southern Swedish sector, where dynamic modelling was
undertaken, could be suitable as a storage site for CO2 captured
from a limited number of industrial facilities
• The reservoir quality in the presently modelled area is not suitable to
high injection rates and therefore not sufficient for commercial CO2
storage at the scale of projected emissions around the entire Baltic
Sea.
• There are sweet spots in the Cambrian reservoir such as onshore
Latvia, where there is commercial gas storage, and both onshore and
offshore Kaliningrad, where there in ongoing hydrocarbon production.
• Acquisition of further data will require much more regional cooperation
36. RECOMMENDATIONS
• Existing seismic line data should be calibrated to available well data
and reinterpreted to identify fault structures and map reservoir porosity
and permeability variations
• Improved estimates of seal fracture pressures based on well leak off
test data and core sample analyses are needed
• New seismic and well data is required, in particular in the north east of
the Dalders Monocline, including offshore Latvia, where this study has
indicated better reservoir qualities exist than in the current study area
• Reservoir formation data from core samples and wire line logs should
be obtained from any newly drilled wells to better understand porosity,
permeability and formation pressures associated with reservoirs in
different areas of the Baltic Sea
• Additional reservoir data covering both onshore and offshore
Kaliningrad should be obtained
• In order to achieve better understanding of the potential to store
captured CO2 in the region, Baltic Sea State cooperation is imperative.
37. THANK YOU FOR YOUR ATTENTION!
For more information, please contact;
Auli.Niemi@geo.uu.se
‘Final report on prospective sites for the geological storage of CO2 in the southern Baltic
Sea’ Published: 01 Feb 2014, Global CCS Institute, Elforsk, SLR Consulting
to be downloaded at http://www.globalccsinstitute.com/publications/final-report-
prospective-sites-geological-storage-co2-southern-baltic-sea
38. QUESTIONS / DISCUSSION
Please submit your questions in
English directly into the
GoToWebinar control panel.
The webinar will start shortly.
The study area is defined as previously mapped Palaeozoic sedimentary basins in the Baltic Sea Area.
The conclusion of the geological overview is that the only workable reservoir seal pair for CO2 storage is the Cambrian sandstones sealed by the Ordovician Silurian argillaceous carbonates and shales.
While storage in confined aquifers and closed structures is the preferred CO2 sequestration mechanism ( e.g. in the CCS-directive from the EC), it would significantly increase the potential of aquifers offshore Sweden if it can be shown theoretically and by demonstration and monitoring projects that CO2 can be trapped in monoclinal structures (Erlstrom, 2008).
The database consists of about 50 wells, with associated, maps, final well reports and some log data supplied by partners, purchased from Latvia, Poland and Russia and obtained from published reports.
From this database a regional map of sedimentary basins with CO2 storage potential was produced.
These basins were ranked according to a methodology by Bachau – “Screening & Ranking of Sedimentary Basins for Sequestration of CO2 in geological media in response to climate change” – Environmental Geology 2003.
In this initial ranking the Slupsk Border Zone has the highest priority because it contains the Dalders Monocline which is a probable CO2 storage structure that is accessible to Swedish CO2 point sources. The Gdansk-Kura Depression is geologically suitable for CO2 storage and has existing oil production infrastructure at PetroBaltic’s B3 field and Lukoil’s Kratsovskoye field. However access may be restricted depending on the storage capacity of the depleted oil and gas reservoirs when they become available. There are existing plans to use the offshore facilities in Poland to store CO2 from the Lotos refinery in Gdansk. The Liepaja Saldus Ridge is closer to CO2 sources in Finland and has potential CO2 storage in saline aquifers offshore Latvia. The LEL Border Zone has the lowest rank because only a small area is sufficiently deep for CO2 storage.
Following the ranking of the Baltic Sea sub-basins, storage capacity calculations have been completed using the GeoCapacity (2009) methodology.
Based on the available data for specific hydrocarbon fields, two separate calculation methodologies were used:
Generic Hydrocarbon Fields method where limited data is available the method is used. A simplified formula using the ultimate recoverable reserves (UR) and formation volume factors (FVF) for the oil and gas fields (Schuppers, et al., 2003).
Detailed Hydrocarbon Field method Calculations of CO2 storage capacity in hydrocarbon fields where detailed reservoir and formation data are available have been undertaken based on Bachu, et al., 2007.
Saline Aquifer Storage Capacity Estimates
Regional, Bulk Volume Estimate was performed using the modified formula by Bachu et al. (2007) as published in the GeoCapacity (2009) report
Trap Volume Estimate A trap specific theoretical storage capacity calculation was carried out for 8 offshore Latvia closures and for the Dalders Structure as presented in the Amoco 1996 report. The calculation was undertaken assuming the structures are open or semi-closed and assuming the Middle Cambrian Faludden sandstone is an unconfined aquifer.
This conceptual model assumes that the storage space is generated by displacing existing fluids and distributing the pressure increase in the surrounding and connected aquifer. This approach therefore assumes that available space is essentially the pore volume and the storage efficiency factor is dependent on the connectivity of the surrounding aquifer (GeoCapacity, 2009).
We calculated the amount of storage that is onshore – which is 56%.
The storage capacity was further broken down into countries. Latvia has most of the storage potential.
Health warnings
OOIP and EUR values used for hydrocarbon fields based on the LO&G report data are likely to be overestimated (demonstrated by Svenska data for 3 onshore Lithuanian fields).
40 new structures indentified in Poland (for a total surface of 1,046 km2) in addition to the 7 structures from BASTOR1, but no reservoir or field data are available for these structures. Hence, the total theoretical storage capacity for Poland still remains low.
Additional 145 structures have been identified in Kaliningrad from published literature. The combined surface area including these new structures is 708 km2 vs 419 km2 previously in BASTOR1 with more reliable structure outlines. Storage capacity estimations are still mostly based on EUR from the LO&G report with only an additional 15.1Mt from 12 additional structures (the largest of which is D6-1 field) for which more recent published EUR data is available..
Latvia storage capacity data is based on individual structure outlines and estimated based on well data form E6-1, E7-1 and P6 wells.
Based on the well and Cambrian depth structure map data available for the Baltic Sea area, four areas of interest have been identified for static modelling study of the CO2 storage sites.
For the four areas of interest, the depth of the Top of the Middle Cambrian sandstone reservoir has been selected as the reference layer for the static models as it extends throughout the whole Baltic Sea region. The Middle Cambrian is composed of several sandstone (SST) intervals of which the top one is the main reservoir, known as the Faludden SST (Sweden), Paradoxides Paradoxissimus (Poland) and Deimena SST (Latvia and Lithuania). The three additional surfaces are the bottom of the Middle Cambrian, the top of the Alum Shale (Upper Cambrian) and the top of the Ordovician. The Alum Shale and Ordovician act as cap rocks overlying the Faludden SST reservoir. Details of the available data are summarised in Table 24 below.
The Dalders Monocline and the Dalders Structure were selected for dynamic modelling. Both structures are large enough for commercial scale CO2 storage.
Out of the static model we produced a number of outputs including the maps shown here of porosity and permeability
The seal integrity study investigates basic overburden properties above the Middle Cambrian reservoir including stratigraphy, lithology and thickness as well as the nature of any faulting and fracturing observed in the two candidate structures for CO2 storage.
The petrophysical properties of the individual stratigraphic units derived from available wireline log data as well as petrophysical properties measured from cored samples are summarised in Table 27 below.
BASED ON THE PETROPHYSICAL DATA AND MAPS OF SEALING FORMATIONS AN ASSESSMENT OF THE CAPROCK INTEGRITY WAS PRODUCED.
CONCLUSIONS
A geologically and geometrically suitable site for CO2 sequestration has been identified in the Dalders structure and Dalders Monocline. Based on the analysis of the stratigraphic and petrophysical properties of the sealing formation at both sites, the following conclusions have been reached:
Three possible modes of seal failure have been identified for the Dalders structure, these include top seal failure, migration up the bounding fault planes and leakage across fault plane, with the former two considered to be the lowest risk.
The potential for top seal failure across the Baltic Basin has been considered in detail as part of this study. Whilst a relatively thin cover of Alum Shale directly overlies the reservoir in both the Dalders Structure and the Dalders Monocline, a significant thickness of between 500m and 1,000m of combined Ordovician and Silurian deposits comprising mainly shales and claystones act as the ultimate seal. The potential for top seal failure is therefore considered low.
Seal failure resulting in leakage across fault planes downthrown Ordovician carbonate lithologies is more likely. However the risk of this is still low when the thickness of the reservoir and large throws along the fault planes are considered.
The potential for migration of CO2 along fault planes has been considered in the context of the different structural events recorded in the Baltic Basin, the trends of the faults structures and their relationships with the reservoir and seals identified in the Dalders Structure and Monocline. The main boundaries of both structures are considered to be sealed leaving little or no risk of upward leakage or migration of CO2 along fault planes.
Evidence from analogous fields in the offshore Polish sector demonstrates that smaller scale cross cutting fault structures with particular E-W and NW-SE orientations) are likely to be open. These are associated with the development of gas chimneys and the upward migration of hydrocarbons from the Cambrian reservoir to overlying Ordovician limestones.
Based on the results of the static model described in Section 7, the Dalders Monocline and the Dalders Structure were selected for dynamic modelling.
The University of Uppsala Earth Sciences Department undertook the dynamic modelling of both structures, with a view to assessing the potential of the Middle Cambrian sandstone reservoir and adjacent formations to store CO2 and to provide a semi-quantitative analysis of the behaviours of the reservoir and CO2 plume during the course of injection and post-injection periods.
The specific objectives of the modelling included:
Define the reservoir pressure behaviour with respect to seal integrity for different injection scenarios based on the existing petrophysical reservoir properties and hydrogeological aquifer parameters;
Calculate the CO2 plume migration tip speed and distance and the potential for dissolution trapping;
Identify suitable multi-well injection scenarios in the Dalders Monocline to meet the estimated industrial CO2 storage requirements identified around the Baltic Sea.
1.8 x 107 Pa threshold injection pressure
The southern Swedish sector, where dynamic modelling was undertaken by Uppsala University, has relatively poor permeability and porosity characteristics. Maintaining the reservoir pressure at 50% above the hydrostatic pressure, limits the injection rate to 0.5Mt per well per annum over a 50 year period if five wells were to be used. The preliminary and indicative dynamic modelling for this area suggests that with 5 injection wells, a total injection capacity of 2.5 Mt per annum could be achieved. Reducing the injection period to say 25 years and increasing the number of wells could increase the total injection rate somewhat above this level. There may also be reservoir intervals with higher porosity and permeability where higher injection rates could be safely achieved. Thus it is possible that this area, including the Dalders structure, could be suitable as a storage site for CO2 captured from a limited number of industrial facilities.
1.8 x 107 Pa threshold injection pressure
The southern Swedish sector, where dynamic modelling was undertaken by Uppsala University, has relatively poor permeability and porosity characteristics. Maintaining the reservoir pressure at 50% above the hydrostatic pressure, limits the injection rate to 0.5Mt per well per annum over a 50 year period if five wells were to be used. The preliminary and indicative dynamic modelling for this area suggests that with 5 injection wells, a total injection capacity of 2.5 Mt per annum could be achieved. Reducing the injection period to say 25 years and increasing the number of wells could increase the total injection rate somewhat above this level. There may also be reservoir intervals with higher porosity and permeability where higher injection rates could be safely achieved. Thus it is possible that this area, including the Dalders structure, could be suitable as a storage site for CO2 captured from a limited number of industrial facilities.
1.8 x 107 Pa threshold injection pressure
The southern Swedish sector, where dynamic modelling was undertaken by Uppsala University, has relatively poor permeability and porosity characteristics. Maintaining the reservoir pressure at 50% above the hydrostatic pressure, limits the injection rate to 0.5Mt per well per annum over a 50 year period if five wells were to be used. The preliminary and indicative dynamic modelling for this area suggests that with 5 injection wells, a total injection capacity of 2.5 Mt per annum could be achieved. Reducing the injection period to say 25 years and increasing the number of wells could increase the total injection rate somewhat above this level. There may also be reservoir intervals with higher porosity and permeability where higher injection rates could be safely achieved. Thus it is possible that this area, including the Dalders structure, could be suitable as a storage site for CO2 captured from a limited number of industrial facilities.
1.8 x 107 Pa threshold injection pressure
The southern Swedish sector, where dynamic modelling was undertaken by Uppsala University, has relatively poor permeability and porosity characteristics. Maintaining the reservoir pressure at 50% above the hydrostatic pressure, limits the injection rate to 0.5Mt per well per annum over a 50 year period if five wells were to be used. The preliminary and indicative dynamic modelling for this area suggests that with 5 injection wells, a total injection capacity of 2.5 Mt per annum could be achieved. Reducing the injection period to say 25 years and increasing the number of wells could increase the total injection rate somewhat above this level. There may also be reservoir intervals with higher porosity and permeability where higher injection rates could be safely achieved. Thus it is possible that this area, including the Dalders structure, could be suitable as a storage site for CO2 captured from a limited number of industrial facilities.
A second multi well injection simulation using an injection rate of 1MT/yr in each well was carried out using the VE model. The results of this modelling are shown in Figure 28 below.
The overpressure ratio in the reservoir observed as a result of this simulation was recorded as being between 140% and 180%, with the overpressure distribution between the wells increasing more rapidly even after 20 years of injection. This results in a significantly larger overpressure area after 50 years of injection reaching the northern open boundary of the Monocline where values of up to approximately 30% overpressure were recorded.
Figure 28b also shows an increased CO2 plume thickness of 4m, as well as an increased radius of about 15km observed at each well with a main migration direction remaining towards the north. Despite this increase the size of the plume and its thickness remain insignificant with respect to the regional scale of the Monocline.
Avoid the areas where high overpressure has been modelled such as in the SW appendix with the strong red colour
Note that these simulations can show the pressure interference between the wells and facilitate site selection and the number of wells
Simulated CO2 saturation for the case of k-30mD, residual CO2 saturation 0.2 at 3000 years