- Pierre Rolf Cerasi
- Senior Research Scientist
- 993 40 928
- SINTEF AS
CO2 storage site containment (Task 10)
The focus is on leakage issues affecting sub-sea wells and the near-well area. The task is looking to maximise storage capacity with minimum risk of significant leakage. Through the research an atlas will be developed. The atlas will contain a check-list of well integrity issues compromising CO2 storage success.
Derisking of CO2 storage is very important in CCS. E.g. environmental scientists have expressed concerns with the risks related to CO2 storage offshore. Thus, the purpose of the geomechanics part of our research is to maximise storage capacity with minimum risk of a significant leakage to any layer under the sea bed, as the presence of CO2 can constitute an unacceptable hazard if it leaks then to the sea.
To be able to realize the above mentioned risk mitigation, improved geomechanical models for making predictions of fracturing near the injection wells are needed. The ambition is to create simple enough models so that these can easily be implemented in the codes the industry already possesses. The Task will work on this in cooperation with Task 9, as their main focus is structural derisking of rock faults.
The Task will also investigate the development of thermal stresses in proximity to the well and injection conditions (pressure, temperature), as they can lead to tensile stresses around the well. This can in turn develop into fracturing in the cement sheath or sealing shale layers. Tensile stress near the well and their consequences on reservoir containment will therefore be closely investigated, both in the short- and long-term perspectives. Also, the effect of exposure to CO2 on creep (shale or salt) will be researched, as creep could be a healing mechanism for initial leakage close to wells.
Although avoiding compromise in the near-well area remains unquestionably important, the wells themselves remain the most likely pathways for potential leakage of stored CO2. This is because wells make artificial short-cut routes all the way from reservoir to topside. Avoiding well leakage will be addressed by this Task by ensuring there are multiple barriers between the storage reservoir and the surface.
Through our research on CO2 well integrity, we will develop an atlas. The atlas will contain a check list of well integrity issues compromising CO2 storage success. E.g. the atlas will include an overview of cement bonding both to rock and to metal casing to put in industry cementing software when planning new wells or evaluating legacy wells.
In addition, the industry has reacted positively to proposed research on injectivity problems, as such issues have arisen in pilots such as Snøhvit and Ketzin. A methodology of which laboratory tests to perform in order to qualify injection wells for CO2 storage will accompany this atlas.
The activities above have been chosen in accordance with the preferences of Statoil, Shell and Total as expressed in the meetings with them
The report on the well integrity survey (Atlas of Well Integrity) was completed in 2020. The number of teleconferences with our partners across the Atlantic, Lawrence Livermore National Laboratory in California and the National Energy and Technology Laboratory in Pennsylvania, doubled as the reporting deadline approached. The learnings from the approximately 30 replies from operators in charge of CO2 injection wells all around the world were compared to published scientific literature. We have planned a joint USA-Norway workshop in 2021, where we will present the results and discuss the prioritisation of remaining research gaps.
Confident from the benchmarking of previous fault reactivation and hysteresis work using two different computer codes, we tackled shale creep modelling as a way to self-heal micro-annuli potentially developing between well cement sheath and surrounding caprock. A finite element simulation was set up where we looked at the competition between fluid pressure pushing apart the crack faces and shale creeping back in place through constant stress creep.
In our model, a behaviour law for the shale was derived from laboratory measurements done on small Draupne shale samples, exposed to different fluids including brine and super-critical CO2. Thus, our model extrapolates from the time-dependent stiffness uncovered in the fluid exposure tests to predict rock deformation up to 10 000 years after injection. The interesting results show a cross-over point from fracture closure to remaining open, depending on stress conditions and fluid pressure.
Main results 2019
Last year we completed the elaboration of a suggested laboratory methodology to measure the tensile strength of the cement to formation bond. Crucial tests were successfully performed on cement and shale composite plugs, where cement was cured under relevant field conditions.
The bond's tensile strength is the weakest link in maintaining well integrity and this is exacerbated when bonding to shales. This work led to the publication of two peer-reviewed papers, a presentation at the ARMA conference in New York. Many also acknowledged that finally there is a method to measure much needed input parameters for computer simulation work. The methodologies developed in Task 10 will be useful for recommended guidelines when evaluating storage capacity and derisking new considered sites.
In the event of large-scale CCS taking off, this will enable oil and gas or mining service companies equipped with good geomechanics laboratories to offer site survey studies in terms of expected well integrity performance.
Our collaboration with Lawrence Livermore National Laboratory (LLNL) was strengthened by mutual work on a well integrity problem survey. A detailed questionnaire was sent to all active CO2 injection operations worldwide. A first round of answers was received and analysed, giving unique insight in which difficulties are most encountered, and where future research efforts are needed. This work will feed into the Well Integrity Atlas, a compilation of well integrity issues encountered at CO2 storage operations, their severity, mitigation measures and their success. This will be available to all operators, such that learnings can be more readily distributed, but also naturally lead the research community in identifying and addressing remaining gaps.
Together we have proposed new models
We have collaborated closely with Task 9 and the supporting researcher project SPHINCSS. This has led to a series of conceptual numerical models of simple fault and stress conditions whereby permeability along the fault and hence leakage risk from a storage site increases.
The results, where the structure of the fractured zone on each side of the fault core is explicitly modelled using SINTEF's fracturing tool MDEM (modified discrete element method), are surprising as they predict that depleted reservoirs might be more at risk than virgin aquifers, due to stress history effects. The main conclusions have been confirmed using a commercial finite element tool, FLAC by ITASCA.
On the basis of this work, we have together with Task 9 proposed new models which address reactivation problems and help us understand specific differences between depleted oil and gas reservoirs and aquifers. This is crucial for gaining confidence in where to invest in CCS and how to scale up operations.
Successful measurement of the interface tensile strength between cement and caprock.
A further injection test was carried out with somewhat higher scCO2 inflow rate and the same counterflow of brine as before. The test resulted again in massive clogging of the rock core, this time on a larger volume and without helical instability.
Formulation of Atlas of well integrity questionnaire in the USA.
Impact and innovations
Work in Task 10 addresses face on the most pressing well integrity and near-well effects needing to be addressed in order to open for massive and large-scale sequestration of CO2. These are the issues remaining where especially legacy wells and high rate injection could compromise safe CCS operations.
The innovation resides in the new laboratory methods used to simply isolate the identified weak elements in all researched topics, so as to address the highest remaining risks at the lowest cost and most effective manner.
Task 10 deals with geomechanics and well integrity, focusing on derisking the well and near well area. The wells by which CO2 is injected in a storage reservoir are identified as the largest risk for leakage from the reservoir. A laboratory activity was initiated to look at injectivity loss due to precipitation of salt near the wells. The first test resulted in massive clogging of the rock core, even though low salinity was chosen to match North Sea conditions.
A small activity also looked at developing geological fault description in geomechanical software, to help predict conditions for a leakage to occur along a fault. This activity relates to work being done in task 9 on faults. The in-house SINTEF software MDEM was used to look at injection conditions where a conductive path would be created in the weak zone alongside a fault.
- Geological and geomechanical factors impacting loss of near-well permeability during CO2 injection - M. Torsæter, P. Cerasi.
- All microannuli are not created equal: Role of uncertainty and stochastic properties in well leakage prediction - Lavrov, Alexandre; Torsæter, Malin.
- Top Seal Undrained Pore Pressure Response - Sensitivity to Skempton's A - M. Duda. The 5th EAGE Fault & Top Seals conference
- CEMENT BOND STRENGTH MEASUREMENTS - Opedal, Nils van der Tuuk; Cerasi, Pierre; Vrålstad, Torbjørn. ASME 2019 38th International Conference on Ocean, Offshore and Arctic Engineering
- Tensile strength of cement to shale interface - A. M. Stroisz, K. Gawel, R. Bjørge, P. Cerasi. 53rd US Rock Mechanics/Geomechanics Symposium
- Modelling faults i the SINTEF MDEM code - Cerasi P., Rongved M., Bauer A. GHGT-14, Melbourne