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IOR NORWAY 2016
Recover for the future
Abstracts
Abstracts IOR NORWAY 20162
Theme 1 : Pilots and full field criteria for successMonitoring of the Ekofisk field with 4D seismic data from a
permanently installed seafloor systemPer Gunnar Folstad
ConocoPhillips Norge AS
IntroductionIn 1988, acquisition of the first 3D seismic survey took place over the Ekofisk field at about the same time as water rates from the already initiated injection program was becoming significant. Several industry reports during the 1990’s about reservoir indu-ced changes to the seismic signal from repeated 3D (or 4D) seismic surveys lead to the first 4D seismic survey over Ekofisk in 1999. The results of the survey were stun-ning with observations of seismic time-shifts from surface to top reservoir of up to
20ms, dominantly a result of water-wea-kening and compaction of flooded chalk layers (Figure 1).
These early observations lead to additi-onal 4D seismic surveys over the field in 2003, 2006 and 2008 until it was decided to install a permanent sea-floor system for frequent and efficient monitoring in 2010. The perma-nent system consists of a total of 200km of seismic cables and 40km of connection cables trenched 1.5m into the seafloor to form a seismic array of 3966 multi-component sensor stations with 50m/300m se-paration inline/crossline. Since installation, nine seismic surveys have been acquired with a plan to continue acquiring 1-2 surveys per year.
Permanent sensor positioning combined with a high focus on quality during acquisition and processing results in highly repeatable 4D data that provides detailed information about changes to the reservoir from injection and production.The 4D seismic data from the system are routinely used for many different purposes including optimization of new well locations and trajectories, suggestion and prioritization of well interventions, diagnose of well me-chanical issues and updates to the reservoir model. In addition to reser-voir applications, the data is used extensively for monitoring and surveil-lance of the im-pact of in-
jection, production, compaction and subsidence of the overburden.This paper will focus on the use of 4D seismic data for monitoring of water movements within the reservoir to make better decisions both for placement of new wells and waterflood optimization.
ExampleIn June 2014, water injection started from eight new wells located in the southern part of Ekofisk. 4D seismic surveys acquired in April/May and October/November 2014 (Figure 2) have been used to monitor early perfor-mance of these injectors and to optimize placement of new production wells in the area.
AcknowledgementsThis work was previously presented at the 2015 EAGE PRM Workshop in Oslo. Thanks to ConocoPhillips Skandina-via AS and the PL018 Partnership (Total E&P Norge AS, ENI Norge AS, Statoil Petroleum AS and Petoro AS) for their permission to publish this work.
Figure 1 Time-shift at Top Ekofisk between 4D seis-mic surveys in 1989 and 1999 showing dominantly weakening of chalk layers caused by water injection.
Figure 2 Maps of 4D acoustic impedance change across upper (EA) and lower (EL) Ekofisk formations after 3-4 months of water injection from VB wells.
Per Gunnar Folstad ConocoPhillips Norge AS
Abstracts IOR NORWAY 20163
CO2 Foam EOR Field Pilots for Efficient and More Sustainable
Petroleum ProductionArne Graue
Dept. of Physics and Technology, University of Bergen, NORWAY
Energy for the future is a major global challenge; alongside access to food and water and the concern for global warming. While the world is in need of more energy, there is a growing societal demand for more sustainable energy production. Due to the climate concern new energy resources need also to be cleaner; although the dependency on fossil fuels will continue; IEA estimates that 75% of energy consumption in 2035 will still be from fossil fuels. New energy resources need to be found and developed and the environmental footprint of current energy production needs to be reduced. Thus, CO
2 EOR, as a possible profitable CO
2 sequestration option, is considered an enabler
of Carbon Capture Utilization and Storage (CCUS). Early CO2 breakthrough and poor
sweep efficiency are the main challenges in CO2 EOR and up-scaling of laboratory
EOR to field performance is the ultimate challenge for the oil industry.
Applying foam for mobility control in CO2 EOR has the potential to overcome the challenge of unstable displacement
during CO2 injection that strongly limits the EOR potential. A successful CO
2 Foam EOR project provides synergy
between the need for increased energy production and the reduction in emission of anthropogenic CO2 by storage
in sedimentary rocks. The project will develop win-win EOR technology to maximize the oil recovery potential and ensure safe, long-term CO
2 storage at minimum storage costs; providing industry opportunities within CCUS.
An international collaboration, including 12 universities/research institutions and 10 oil and oil service companies in 5 countries in Europe and USA, combines expertise and the common goal to develop and test CO
2 foam systems with
mobility control at laboratory and field pilot scale to optimize CO2 integrated EOR (IEOR) and aquifer deposition. CO
2
foam systems for mobility control will be developed and tested in four inexpensive onshore field pilots in Texas and Mississippi, in both clastic and carbonate reservoirs. Assisted by field experience from the US pilots CO
2 Foam EOR
for field implementation on the Norwegian Continental Shelf will be developed.
Collaborating universities: Rice University, Houston, Texas (George Hirasaki), University of Texas at Austin (Keith Johnston, Quoc Nguyen), U. of Texas A&M (Jenn-Tai Liang), Stanford U. (Tony Kovscek), Imperial College, London (Martin Blunt), TREFLE Borde-aux (Henri Bertin;), New Mexico Tech (Randy Seright), MSU (Jason Keith), TU Delft (Bill Rossen, Pacelli Zitha), NTNU (Martin Landrø and Erik Lindeberg (SINTEF)), The National IOR Centre of Norway (Merete V. Madland and Svein M. Skjæveland (UiS)) and University of Bergen (Arne Graue (Head of Collaboration), Martin Fernø and Geir Ersland).
Project advantages:- CO
2 is commercially available in USA
- Oil industry in Texas has 30 years experience in CO2 EOR
- Cost associated with on-shore field tests is only a fraction of costs for off-shore field tests- Short inter-well distances in on-shore oil fields yield fast results for sweep and recovery- Foam and mobility control has significant potential for a quantum leap within EOR- Worldwide recognized researchers from 12 reputational institutions; all specialists on mobility control- Focus on up-scaling; the major challenge in obtaining reliable predictive models of oil recovery- Mobility control may establish next generation CO
2 EOR flooding providing less than 10% residual oil in swept zo-
nes; establishing a new era in EOR; 137 billion barrels of additional oil is the potential target in USA.
Prof. Arne GraueDept. of Physics and Technology, University of Bergen, NORWAY
Abstracts IOR NORWAY 20164
Water diversion EOR technique – Challenges related to Technology Development and Field Implementation
Kjetil Skrettingland
Statoil
Statoil and the license partners on Snorre have in cooperation with a research institute and service companies developed a technology to alternate the reservoir sweep pat-tern in oil fields with pressure support from water injection. The technology has been tested in a large scale field pilot on Snorre.
From 2008 to 2016 a systematic work of laboratory tests, small scale field test and large scale field pilot has been performed to qualify use of sodium silicate to establish a large scale in-depth permeability restriction to change the reservoir flow pattern. So-dium silicate is a green chemical (ref. PLONOR list), and are among other things used as nutrients in scrimps breeding, for binding soil and to improve water quality in rivers. From this technology development project it is also proven that sodium silicate can be used to make large scale in-depth permeability restrictions in oil field reservoirs.
The large scale field pilot required injection of large volumes of chemicals during several months. A new operational concept of using a shuttle tanker as a platform for chemical storage, mixing and injection directly into a subsea wa-ter injection well was developed to perform the large scale injection. The new operational concept has proven to be operationally robust.
With basis in this technology development project the presentation will deal with challenges related to technology development and further field implementation.
Kjetil Skrettingland Statoil
Abstracts IOR NORWAY 20165
Theme 2: Reservoir characterization and production optimization
Bayesian inversion methods for time-lapse seismic reservoir characterization and monitoring
Dario Grana
University of Wyoming
The construction of 3D reservoir models describing the spatial distribution of petrop-hysical and dynamic properties is a key step in reservoir modeling and fluid flow si-mulation. Generally, the only available data to condition reservoir models far away from the wells are seismic data. Rock properties can be obtained from seismic data as a solution of an inverse problem combining rock physics and seismic modeling with inverse theory. Probabilistic approaches provide the full posterior distribution of the inverse problem. In particular, uncertainty quantification for the estimation of reservoir properties can be obtained using Bayesian inversion methods, to estimate the posterior distributions of reservoir facies and reservoir properties, such as poro-sity, clay content and fluid saturations. In this approach, we calculate the conditional distribution of elastic properties conditioned by seismic data, we estimate the rock physics likelihood function and we finally compute the posterior distribution of facies and reservoir properties. This methodology can be then extended to joint inversion of time-lapse seismic data. Time-lapse seismic data can be used to monitor the fluid displacement and pressure variations during reservoir production. Production, inje-ction and depletion alter rock and fluid properties, such as saturation and pressure, causing a change in the elastic response of surface seismic waves. These changes can provide valuable information to monitor flow mechanisms within the reservoir and detect areas where hydrocarbon accumulates. In this work, we present a probabilistic method to quantitatively interpret time-lapse seismic data and estimate changes in reser-voir properties. First, a rock physics model calibrated at the well location is defined to link the changes in pressure and saturation to their geophysical response. Changes in saturation, at the seismic scale, can be described using Gassmann’s relations, whereas an empirical relation must be introduced to describe the pressure effect. The joint sa-turation-pressure model requires a set of well logs and laboratory measurements to determine the properties of the reservoir rock and fluid components and calibrate the empirical parameters of the model. We then include this model in the Bayesian inversion approach to estimate changes in saturation and pressure from time-lapse seismic mea-surements. In the proposed method, we combine the likelihood function of saturation and pressure changes given elastic property changes with the probability distributions of elastic changes estimated from time-lapse seismic data. The result of this methodology is a 3D model of the posterior distributions of reservoir property changes conditioned by time-lapse seismic data. We illustrate the method on a real dataset in the North Sea.
Dario GranaUniversity of Wyoming
Abstracts IOR NORWAY 20166
Can fluorescent nano-objects be used as reservoir tracers?Thomas Brichart
The National IOR Centre of Norway
Institutt for Energiteknikk (IFE)
Reservoir monitoring is an essential part of oil production optimization. In that respe-ct, tracers are very useful tools to study and understand flow patterns between wells during either regular water flooding operations, EOR/IOR pilots or field developments. Tracer information leads to a multitude of information such as preferential flow directi-ons, communication channels between injectors and producers, permeability, swept volumes, faults or large-scale heterogeneities.
Most of the currently available tracers suffer from limitations. Radioactive tracers raise concerns because of the negative attention of radioactivity in the public although they will be the best technical choices in many cases. In addition, their exploitation also requires specially trained personnel during handling and analysis. Most of the other available chemical or stable isotope ratio tracers involve a final detection using mass spectroscopy. Despite its efficiency and precision, this technique is ill adapted to on-site or online detection, as it requires a well-controlled environment as well as skilled workers to operate.Fluorescent tracers represent an alternative to current technologies. Because of its flexibility, it is possible to use fluorescence for on-site or online analysis. Furthermore, its cost-effectiveness and ease of use are two main ad-vantages. Despite the fact that oil in itself can produce a fluorescence signal, the multitude of available fluorescent compounds combined with advanced detection methods such as time-resolved spectroscopy could provide the oil industry with a variety of compatible fluorescent tracers.
In addition to fluorescence, nanotechnologies already represent the next big step in various other fields involving tracers (e.g. medicine). Nano-objects, whether organic (e.g. C-dots) or inorganic (e.g. silica, QD) have become a major research interest in the last few years. Their size allows the encapsulation of multiple compounds inside a single ob-jet. This property can be used in the domain of tracers to combine multiple dyes in a chemically “protected” fashion, thus permitting the production of optical codes and creating a new class of reservoir-applicable tracers. Furthermore, it is possible to modify and tailor the surface of nano-objects to fit specific requirements, therefore creating stealth or interacting tracers depending on the needs.
This presentation explores available fluorescent nano-objects as well as the on-going developments that are under way to evaluate the feasibility of such tracers.
Thomas BrichartThe National IOR Centre of Norway
Institutt for Energiteknikk (IFE)[email protected]
Assessing the Value of Information from Production Monitoring for Optimising Long-Term Reservoir Performance
Jan Dirk JansenDelft University of Technology
(TU Delft)
We propose a method to assess the value of information (VOI) from different types of measurements used to monitor oil production. We consider a Closed-Loop Reservoir Management (CLRM) workflow in which the production strategy is frequently opti-mized based on multiple static and/or dynamic reservoir models that are kept ‘ever green’ by near-continuous assimilation of measured production data or time-lapse seismics. The CLRM-VOI method is illustrated with simple examples which show that it is powerful but computationally very intensive. We conclude by discussing options to modify the method to make it suitable for realistically-sized reservoirs.
Jan Dirk JansenDelft University of Technology
(TU Delft)[email protected]
Abstracts IOR NORWAY 20167
Theme 3: Improved understanding/modeling of the IOR processes
The Benefits and Risks of Fractures in Enhanced Oil RecoveryRandy Seright
New Mexico Tech
Most enhanced oil recovery (EOR) practitioners fear the presence of fractures for their projects. If fractures extend the entire distance from an injection well to a production well, expensive EOR fluids can be wasted by direct channeling between the wells. Si-milarly, if fractures extend up or down from the productive strata, injected fluids can be lost “out of zone”. Both of these occurrences are good reasons to be wary of fractures. For some EOR processes, we sometimes forget the importance of fractures. For exam-ple, the impact of fractures is often neglected during CO2 flooding. Considerable effort has been expended developing water-alternating-gas (WAG) and foam processes to improve sweep efficiency for CO2 floods. However, these processes have limited ef-fectiveness in fractures. Ironically, most CO2 floods are applied in 1-10-md carbonates that are known to be naturally fractured. Processes that focus on improving sweep in fractures systems may be more effective in improving CO2 sweep efficiency than WAG or foam.
Under the right circumstances, fractures can provide substantial benefits for many EOR projects. Fractures are es-sential to surfactant-imbibition stimulation of oil shale and other tight rocks. For polymer floods using vertical injectors, injectivity would be prohibitively low if near well-bore fractures were not open. The shear-thinning character of biopolymer solutions (xanthan, scleroglucan, schizophylan, diutan) helps to improve injectivity, but usually not enough to achieve practical injection rates in vertical injectors. The shear-thic-kening character of synthetic polymer solutions (polyacrylamide, HPAM) accentuates injectivity losses—making it even more unlikely that polymer floods will be practical in vertical wells unless fractures are open. Ironically, many simulations of polymer flooding assume (1) HPAM solutions are strictly shear thinning and (2) injection wells are not fractured. The hope is that together, these two incorrect assumptions will lead to a valid prediction of polymer injectivity. Commonly, these simulations find false “economic optimums” of polymer concentration and viscosity that are significantly lower than expected. These false optimums result from artificial injectivity constraints imposed by assuming an absence of fractures. In reality, few polymer flooding field projects experience injectivity limitations because fractures or fracture-like features extend to accommodate the viscosity, particulate content, and rate of the injection fluid. The large surface area of these fractures also negates concern over mechanical degradation and injectivity reductions associated with shear-thickening of HPAM solutions. Fractures can also significantly increase sweep efficiency during flooding, depending on fracture length and orientation. Even for fractures that point directly from injectors towards producers, the loss of sweep efficiency may not outweigh the beneficial increase in injectivity until fracture extension exceeds half the distance between the injector-producer pair. So the real challenge is to ba-lance the benefits of fracture extension with the detrimental aspects of channeling and flow out of zones. Methods are available to help distinguish whether a channeling problem is due to fractures or to viscous fingering through porous rock.
Randy SerightNew Mexico Tech
Abstracts IOR NORWAY 20168
A study of in-situ combustion for heavy oil recoveryMargot Gerritsen
Stanford
Thermal recovery processes are wonderfully complex. For some time now, our research group has worked to understand the physics, improve the numerics and design simulati-on tools suitable for industrial process optimization.
I will give an overview of our laboratory and numerical experiments with the focus on mo-deling of kinetics at the laboratory and the reservoir scale. The process of interest to us currently is in-situ combustion, in collaboration with our partners at Ecopetrol, Colombia.
We use kinetic cell and combustion tube experiments in the laboratory combined with high resolution numerical experiments to understand the type of chemical reactions and front propagation behavior. At the lab scale, kinetics can be implemented in numerical solvers using the traditional Arrhenius approach. This is a well-known method, with the main challenge of finding representative chemical reactions and pseudo-components. Recently, we developed a new reaction-free approach (RFK) that uses experimental results directly. This is effective at the laboratory scale.
Upscaling kinetics to the reservoir scale is the outstanding question. Our WUGI scheme (Workflow-based Upscaling for Grid Independence) gives us a good proxy for reservoir scale in-situ combustion processes and does not require recalibration when computational grids are resized. We are currently working on upscaling RFK, as well as developing streamline-based proxies for in situ combustion, and I will outline the latest ideas in these areas also.
Margot GerritsenStanford
Impact of choke valves on the IOR polymer flooding: Lessons learned from large scale tests
Amare Mebratu, Halliburton; Arne Stavland and Siv Marie Åsen, IRIS; and Flavien Gathier, SNF.
Polymer flooding is one of the more promising EOR methods. The most frequently used EOR polymers are the high molecular weight HPAM-based polymers, which however are sensitive to shear degradation. It is therefore critical to be able to quantify the extent of degradation these polymers may undergo, under realistic conditions. It is also highly desirable to investigate any mitigating actions that may minimize degradation.
Here we present the main results from a recent large-scale polymer degradation test and conclude that standard choke-valves significantly degrade high molecular weight HPAM polymer as well as low molecular weight AMPS co-polymer. Polymer concentration af-fected degradation and the degradation was reduced from 76% to less than 10% simply by increasing the polymer concentration from 1 000 to 10 000 ppm. By decreasing the pressure gradient across the choke-valve, simply by increasing the choke-valve length, we significantly reduced the degradation; polymers revealing 60-70% degradation in standard choke-valves do not degrade in 200 to 400 meter long LPR chokes. Multiple choke-valves rigged in series did also reduce the poly-mer degradation.
A simple model based on applied shear rate matched experimental results from tube flow with ID varying from 0.1 to 50 mm well, both at low and high Reynolds number.
Arne StavlandThe National IOR Centre of
Norway IRIS
Abstracts IOR NORWAY 20169
Theme 4: The oil industry and IOR
Challenges and Opportunities with IOR/EOR on Johan SverdrupBjørn Egil Ludvigsen
Maersk Oil
The recently discovered Johan Sverdrup oil field is one of the largest in the North Sea with more than 2 billion bbls of recoverable oil. The field has exceptional reservoir quality with permeabilities more than 50 Darcy, and the main drainage strategy is peripheral water injection. However, even with recovery factors from water flooding in excess of 60%, large volumes of oil gather in the attic and other unswept areas.
While IOR is traditionally considered towards the end of a field life, early IOR considera-tions and studies to include the necessary flexibility in field design can be both econo-mically and strategically justified. An early screening of the IOR methods led to further detailed evaluations focusing on infill drilling, polymer, low salinity water injection (LSWI) and WAG injection.Field development planning is ongoing for future phases of Johan Sverdrup, and IOR is an integral part of these studies. This presentation gives an overview of opportunities and risks implementing IOR on Johan Sverdrup.
Bjørn Egil LudvigsenMaersk Oil
Flow of complex fluids in Enhanced Oil RecoveryMarcio Carvalho
Department of Mechanical Engineering
Pontificia Universidade Catolica do Rio de Janeiro (PUC-Rio)
Rio de Janeiro, Brazil
The most common oil recovery method used for displacing the oil and maintaining the reservoir pressure is water injection. However, in most cases, the recovery efficiency of this method is limited by the high fluid mobility ratio and reservoir heterogeneities. The non-linear flow properties of complex fluids through porous media give rise to multiphase flow displacement mechanisms that operate at different scales, from pore-level to Darcy scale. Experiments have shown that injection of oil-in-water emulsions and viscoelastic polymer solutions can be used as an effective enhanced-oil recovery (EOR) method, lea-ding to substantial increase in the volume of oil recovered. The mechanisms responsible for increasing the recovery factor in different EOR methods are not fully understood.
We study the effect of complex fluids (dispersions and viscoelastic polymer solution) both at pore and Darcy scale. Visualization of the flow of complex fluids through a trans-parent network of micro-channels, which serves as a model of a porous media, and pore network model reveal how the flow behavior improves the pore-level displacement effici-ency, leading to lower residual oil saturation. Oil recovery results during complex liquids flooding in tertiary mode (after water flooding) show how the improved oil recovery varies with flow conditions and fluid properties.
Marcio Carvalho Department of Mechanical
EngineeringPontificia Universidade Catolica
do Rio de Janeiro (PUC-Rio)Rio de Janeiro, Brazil
Abstracts IOR NORWAY 201610
Theme 5: Pore scale fundamentals
Direct modeling approaches to wettabilityMaša Prodanović1, Rahul Verma1 and Matteo Icardi2
1 Department of Petroleum and Geosystems Engineering, The University of Texas at Austin, Austin, TX, USA
2 Mathematics, Institute, University of Warwick, Coventry, UK
Understanding of pore-scale physics for multiphase flow in porous media is essential for accurate description of various flow phenomena. In particular, capillarity and wettability strongly influence capillary pressure-saturation and relative permeability relationships. Wettability is quantified by the contact angle of the fluid-fluid interface at the pore walls. In this work we compare a popular open-source finite volume computational fluid dy-namics solver with a new formulation of the level set method that models quasi-static capillarity-dominated displacement and is therefore less computationally expensive. The methods fundamentally differ in the way they capture interfaces, as well as in the number of equations solved and other implementation and algorithmic details. Both methods are able to solve curvature-driven displacement and implement arbitrary contact angles at pore walls. The methods are tested in rhomboidal packings of spheres for a range of contact angles and for different rhomboidal configura-tions. Predictions are validated against the semi-analytical solutions obtained by Mason and Morrow (1994). We evaluate the benefits and limitations of employing a less computationally intense method for semi-equilibrium capil-lary-dominated flows vs. the full approximation of the Navier-Stokes equation, also applicable to inertial and viscous flows. Finally, we discuss implications for simulations in larger and more complex geometries, as well as mixed wet-tability problems.
Maša ProdanovićThe University of Texas at
Can we measure core scale properties in pore scale models?Jan Ludvig Vinningland
The National IOR Centre of Norway
IRIS
Numerical pore scale investigations require pore space geometries with voxel resoluti-ons down to a few tens of nanometers. A key question when working with such small pieces of material is how well they represent macroscopic properties. How large samples, i.e. how many voxels, do we need to measure permeabilities that are comparable to core scale values? In other words, what is the representative elementary volume that should be used in simulations? Together with Sandia National Laboratories The National IOR Centre of Norway has obtained high-resolution pore space geometries from chalk core samples of different origin exposed to chemical alterations. In the talk I will present lattice Boltzmann simulations based on these geometries that focus on scale variation in flow properties and the effect of chemical changes.
Jan Ludvig VinninglandThe National IOR Centre of
Norway IRIS
Abstracts IOR NORWAY 201611
Confined fluid films, forces between mineral surfaces and the mechanical effects of pore fluid chemistry
Anja RøyneThe National IOR Centre of Norway
UiO
It has been long observed that the injection of fluids into chalk reservoirs can lead to compaction and subsidence, something which appears to be at least partly due to a che-mically induced change in the mechanical properties of the chalk. As water flooding is one of the most important methods for enhancing oil recovery from a reservoir, it is im-portant to understand what effects the injection of water of different chemical compositi-ons may have on the mechanical strength of the reservoir rock.
Recent experiments and models have shown that these mechanical effects can be explai-ned in terms of the interfacial forces that operate in nano-confined fluid films at the grain boundaries in chalk. The so-called water weakening effect refers to the inverse depen-dence of chalk strength with water activity in the pore fluid, and has been proposed to be a result of repulsive forces that arise between chalk grains due to water adsorption on their surfaces. It has also been observed that different io-nic species do not give the same mechanical effect at similar ionic strength, something that may also be understood in terms of surface adsorption. Repulsive and attractive interfacial forces are highly dependent on surface charge and the distributions of ions near the mineral surfaces.
At the moment, we lack the theoretical framework to fully describe these effects. We are therefore using experimental methods to directly measure the interaction between surfaces of calcite particles, which are the main constituents of chalk rocks. By gluing a calcite particle onto the cantilever of an Atomic Force Microscope (AFM), we can mea-sure how the attractive and repulsive forces between the calcite particle and a cleaved calcite substrate change as a function of fluid chemistry. We are also using the Surface Forces Apparatus (SFA) to measure forces across na-no-confined fluid films in well-defined geometries. In my talk, I will present some results from these experiments and show how they can be applied to understand how the mechanical properties of porous media are controlled by the pore fluid chemistry.
Anja RøyneThe National IOR Centre of
Norway UiO
Submicron investigations –What can we learn?Mona W. Minde 1,2,3, Udo Zimmerman1,3, Merete V. Madland1,3, Reidar Inge Korsnes1,3
1 The National IOR Centre of Norway, 2 IRIS, 3 University of Stavanger
Water injection has been applied with great success on the Norwegian continental shelf and has in addition to maintaining pore-pressure in the reservoir a significant EOR effect. To maximize this EOR effect, contributions from nano- to field-scale are needed. Study-ing rock – fluid interactions at nano and micron-scale leads to the understanding of EOR mechanisms at pore-scale. This is of crucial importance in the upscaling to field and thus valuable input as developing our own simulators for reservoir EOR-purposes. We work with a wide range of analytical methods to be able to map mineralogical changes and their effects at pore and core scale and to quantify the new-growth of minerals due to flooding with non-equilibrium brines under conditions similar to North Sea hydrocarbon reservoirs. Since some time, based on a long line of experiments, we have been able to link positively chemical alterations on pore-scale, as well as primary chemistry and texture of the rock, to changes in mechanical properties of the rocks. The amount -and distribution of secondary minerals depends on the type of injected brines together with the properties of the flooded material and induces changes in surface properties, surface area and wet-tability, thus having a significant impact on the recovery of hydrocarbons. Methods in use include whole-rock and stable isotope geochemistry, XRD, field emission gun scanning electron microscopy (FEG-SEM), Mineral Liberation Analyzer (MLA), transmission electron microscopy (TEM), nanoRaman and Nano Secondary Ion Mass Spectrometry (NanoSIMS).
Mona MindeThe National IOR Centre of
NorwayUniversity of Stavanger
Abstracts IOR NORWAY 201612
Theme 6: Simulation of IOR Processes
Flow -- an open source research tool for reservoir simulationRobert Klöfkorn
The National IOR Centre of Norway
IRIS
In this talk we will present highlights from Task 6 of the National IOR Centre of Norway. The overall focus of Task 6 is to provide improved modeling methodology and simulation capabilities for IOR applications.
This includes the development of new model formulations such as ”A Model for Reactive Flow in Fractured Media” (Andersen and Evje, 2016) and ”A Model for Wettability Alterati-on in Fractured Reservoirs” (Andersen, Evje, Kleppe, and Skjæveland, 2015).
Task 6 is also dedicated to contribute to the development and improvement of higher or-der numerical methods for state of the art reservoir simulation. For the simulation of IOR processes which include chemical reaction high resolution schemes are crucial. We will comment on the current state and the integration into the Open Porous Media (OPM) flow simulator called Flow (www.opm-project.org). Task 6 actively contributes to the develop-ment of Flow and then current state of the project is discussed.
Robert KlöfkornThe National IOR Centre of Norway
IORSim - an add on tool to ECLIPSE for simulating IOR processesAksel Hiorth1,2,3, Jan Sagen1,4, Arild Lohne1,3, Jan Nossen1,4, Aruoture Voke Omekeh1,3, Arne
Stavland1,3, Jarle Haukås1, 5, Terje Sira1, 4
1 The National IOR Centre of Norway, 2 University of Stavanger, 3 IRIS, 4 IFE, 5 Schlumberger
In the lab, it is possible to extract a large amount of oil from reservoir cores, by injecting fluids of varying composition. Based on the interpretation of lab results, mathematical and conceptual models are developed that can explain how and why oil is released from the cores. Sometimes there is a lack of consensus in the research community on the exact mechanism. Knowledge about the exact mechanisms is important, because the field recovery could be very sensitive to it. Therefore, it is important to have a tool that is capable of evaluating the effect of the various fluids on a case-by-case basis. The chal-lenge is that industry standard reservoir simulators do not have the possibility to fully simulate the physical and chemical rock fluid interactions that we know from lab experi-ments to be important for IOR processes. Because of this the predicted performance of an IOR process by industry standard reservoir simulators might be very uncertain.
One solution to the above challenges is to implement advanced physical and chemical mechanisms in research co-des. The draw back with this approach is that such codes usually are too slow when it comes to do a full field simula-tion and it could be a significant challenge for a research code to reproduce the historical oil and water production profiles from the field. Our approach is to let the industry standard reservoir simulator, in this case Eclipse, perform the fluid simulation, and then use a separate simulator, IORSim, to perform the IOR simulations. IORSim and Eclipse simulators communicate via restart files, making it possible to pass information back to Eclipse (e.g. changing rel. perm chemical interactions). We use a block sorting technique in IORSim to speed up species transport and chemical interactions. The sorting algorithm allows us to solve the whole transport problem implicitly without solving for all blocks simultaneously, and thus greatly improve the stability of the numerical problem. If the temperature option is
Aksel HiorthThe National IOR Centre of
Norway University of Stavanger
Abstracts IOR NORWAY 201613
not used in the reservoir simulator, we can use the thermal model implemented in IORSim.At the IOR conference the last year, we demonstrated how it was possible by this approach to include geochemistry in reservoir simulation. We implemented a geochemical module in IORSim, and used this module to predict changes in the water chemistry, and mineralogical changes between an injector and producer. The results compared well with field data. This year we focus on chemical reactions induced by the injected water that influence the reservoir perme-ability. We have implemented a new module in IORSim that is capable of simulating the injection of sodium silicate and the subsequent blocking due to the gel network formed by the polymerization of silica. The silica gel module takes into account the formation of nano-sized silica gel particles that are individually too small to plug the formati-on, but as the concentration increases these nano-sized silica gel particles will aggregate and then start to plug the formation when they reach a critical concentration. The plugged silica particles increase the specific surface area of the rock and reduce the permeability accordingly. The silica gel module covers some aspects of the polymerization of silica, but not all such as changes in pH, the presence of divalent ions, and high salinities. To do that we need to couple the silica and geochemical module, which has not been done yet. Rather, the main objective this year is to demonstrate that it is possible to pass information from IORSim to Eclipse, such that the water is diverted and the sweep is improved.
Methodologies and robust algorithms for subsurface simulatorsMary Wheeler
University of Texas at Austin
Enhanced oil recovery (chemical and gas flooding) and hydraulic fracturing is driving the development of a new generation of subsurface simulators. The central challenge is to design accurate mathematical models and robust numerical simulations as screening tools for maximizing economic benefits while minimizing environmental impacts. The latter is especially important since in situ reservoir properties are often difficult to determine everywhere with certainty. The mathematical models representing the underlying complex physical and chemical processes rely upon these reservoir properties for accurate predictions. In order to address this challenge a robust workflow comprised of coupled programs that account for multicomponent, multiscale, multiphase, thermal, flow, mechanics and transport through porous media is required.
The coupled toolset must be able to treat different physical processes such as fracture propagation, and/or polymer, foam or surfactant injection occurring in different parts of a domain using multiple numerical schemes. All of this while maintaining accuracy and computational efficiency. In addition, this problem solving environment or framework must also address the uncertainty associated with in situ reservoir properties using parameter estimation and optimal control capabilities. We describe methodologies and robust algorithms for addressing these issues that are currently being developed at the ICES Center for Subsurface Modeling at The University of Texas.
Mary Wheeler University of Texas at Austin
Abstracts IOR NORWAY 201614
List of posters1. To what degree will thermal cycles affect strength?Tijana Livada, Anders Nermoen, Ida Lykke Fabricius and Reidar I. Korsnes Dept. of Petroleum Technology, University of StavangerThe National IOR Centre of NorwayDept. of Civil Engineering, Technical University of Denmark Corresponding author: [email protected]
2. Effect of Calcium in Pore Scale Oil Trapping by Low Salinity Surfactant EOR at Water Wet conditionsHamid Hosseinzade Khanamiri, Jan Åge Stensen and Ole Torsæter Dept. of Petroleum Engineering and Applied Geophysics, NTNUSINTEF PetroleumCorresponding author: [email protected]
3. Interaction forces between two calcite surfaces as a function of fluid compositionS. Javadi, A.Røyne and A. HiorthDept. of Petroleum Engineering, University of StavangerIRIS AS, International Research Institute of Stavanger The National IOR Centre of NorwayCorresponding author: [email protected]
4. Parametric Representation of Boundary Flux in Multi-Region Fluid Flow ProblemsYiteng ZhangThe National IOR Centre of NorwayCorresponding author: [email protected]
5. CO2 Foam EOR Field PilotsMohan Sharma, Martin A. Fernø, Arne Graue and Svein M. Skjæveland Dept. of Petroleum Technology, University of StavangerDept. of Physics and Technology, University of Bergen The National IOR Centre of NorwayCorresponding author: [email protected]
6. Understanding EOR mechanisms at pore-scaleMona W. Minde, Udo Zimmerman, Merete V. Madland and Reidar Inge KorsnesDept. of Petroleum Engineering, University of StavangerIRIS AS, International Research Institute of Stavanger The National IOR Centre of Norway Corresponding author: [email protected]
7. An Experimental Study of Methane Hydrates in Sandstone Cores - with emphasis on production by pressure depletionStian Almenningen, Josef Flatlandsmo, Håkon Juliussen, Martin A. Fernø and Geir Ersland Dept. of Physics and Technology, University of Bergen Corresponding author: [email protected]
8. Investigation of Water Diversion by a Novel Polymer Gel System for Enhancing Oil Recovery Ashkan Jahanbani Ghahfarokhi, Jon Kleppe, and Ole Torsæter Dept. of Petroleum Engineering and Applied Geophysics, NTNUAshkan Jahanbani Ghahfarokhi ([email protected])
9. Fate and Effect of Produced Water Containing EOR Polymers E. Opsahl and R. KommedalThe National IOR Centre of NorwayCorresponding author: [email protected]
10. Solid-Phase Microextraction as Sample Preparation Technique in Tracer TechnologyMário Silva and Tor BjørnstadThe National IOR Centre of NorwayInstitute for Energy Technology (IFE) / Tracer DepartmentCorresponding author: [email protected]
11. Which processes are at play during wettability alteration and water induced compaction of chalks?Jaspreet Singh Sachdeva, Anders Nermoen, Reidar I. Korsnes and Merete Vadla MadlandDept. of Petroleum Technology, University of Stavanger The National IOR Centre of NorwayCorresponding author: [email protected]
12. Improved numerical schemes for transport processes in reservoirs Anna Kvashchuk and Robert Klöfkorn, IRIS Bergen The National IOR Centre of Norway Corresponding author: [email protected]
Abstracts IOR NORWAY 20161513. Synthesis and evaluation of monodispersed cobalt nanoparticles in the catalytic aquathermolysis of heavy crude oil
Kun Guo, Priscille Cuvillier, Vidar Folke Hansen, and Zhixin Yuab,Dept. of Petroleum Engineering, University of StavangerThe National IOR Centre of NorwayDept. of Mechanical and Structural Engineering and Materials Science, University of Stavanger Corresponding author: [email protected]
14. Plane Wave Semi-Continuous Galerkin method for seismic wave simulationAnders Matheson IRIS AS, International Research Institute of Stavanger Corresponding author: [email protected]
15. Micro- and Nano- Raman analyses of chalkLaura Borromeo, Nina Egeland, Mona Minde, Udo Zimmermann, Sergio Andò, Chiara Toccafondi, Razvigor OssikovskiDept. of Petroleum Engineering, University of StavangerThe National IOR Centre of Norway, StavangerDepartment of Earth and Environmental Sciences, University of Milano-Bicocca, Milano, ItalyLPICM, CNRS, Ecole Polytechnique, Université Paris Saclay, 91128, Palaiseau, France Corresponding author: [email protected]
16. A new method for locally adaptive earth model griddingErich Suter (IRIS/UiS), Terje Kårstad (UiS), Alejandro Escalona (UiS) and Erlend Vefring (IRIS)Dept. of Petroleum Engineering, University of Stavanger, NorwayIRIS AS – International Research Institute of StavangerDrillWell - Drilling and Well Centre for Improved RecoveryCorresponding author: [email protected]
17. Reservoir Management Workflow for Optimizing CO2 Injection to Enhance Oil Recovery in Mature Oil Fields: A Preliminary Study for a Field Pilot ProgramZachary P. Alcorn, Martin A. Fernø and Arne Graue Dept. of Physics and Technology, University of BergenCorresponding author: [email protected]
18. CO2 Injection for EOR in Tight ShalesArthur Uno Rognmo, Martha Lysne, Sunniva Brudvik Fredriksen, Martin A. Fernø and Arne GraueDept. of Physics and Technology, University of Bergen Corresponding author: [email protected]
19. The Effects of Brine and Oil Composition on Water Diffusion and Osmosis during Low Salinity WaterfloodingSunniva Fredriksen, Arthur Uno Rognmo and Martin A. Fernø Dept. of Physics and Technology, University of Bergen Corresponding author: [email protected]
20. Resistivity measurements and polymer flooding of sandpacks with dual-porosityIrene Ringen, Oddbjørn Nødland, Arne Stavland, Hjørdis Stiegler and Aksel HiorthDept. of Petroleum Engineering, University of Stavanger The National IOR Center of Norway IRIS AS – International Research Institute of Stavanger Statoil ASA, Stavanger, NorwayCorresponding author: [email protected]
21. Smart Water for EOR by MembranesRemya Ravindran Nair, Torleiv Bilstad, Skule StrandDept. of Petroleum Engineering, University of Stavanger The National IOR Centre of NorwayCorresponding author: [email protected]
22. A simulation study of a polymer flooding experiment in porous silica sandOddbjørn Nødland, Irene Ringen, Arild Lohne, Arne Stavland, Hjørdis Stiegler, Aksel HiorthDept. of Petroleum Engineering, University of StavangerThe National IOR Center of Norway IRIS AS – International Research Institute of StavangerStatoil ASA, Stavanger, NorwayCorresponding author: [email protected]
23. Experimental Investigation of the Influence of Nanoparticles Adsorption on Wettability Alteration for Berea SandstoneShidong Li and Ole TorsæterDept. of Petroleum Engineering and Applied Geophysics, NTNUCorresponding author: [email protected]
24. Using Capacitance-Resistance Model as Proxy for Fast Robust Production OptimizationAojie Hong, Reidar Bratvold and Geir Nævdal Dept. of Petroleum Engineering, University of Stavanger IRIS ASThe National IOR Centre of NorwayCorresponding author: [email protected]
Centre directorMerete V. Madland, professor, UiS,Phone: +47 51 83 22 53E-mail: [email protected]
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Communications advisorMari Løvås, UiSPhone: +47 479 033 28E-mail: [email protected]
Administrative coordinatorBente Dale, UiSPhone: +47 51 83 17 08E-mail: [email protected]
Website: uis.no/ior
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