Publications

  • Wettability Estimation by Oil Adsorption Using Quartz Crystal Microbalance with Dissipation QCM-D. SPE-190882-MS

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  • CO2 Laboratory experiments

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  • Reservoir Rock Wettability Characterization via surface complexation modelling

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  • Wettability Estimation via Oil Adhesion

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  • Challenges Associated with Quartz Crystal Microbalance with Dissipation (QCM-D) as a Wettability Screening Tool

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  • IMPROVED OIL RECOVERY AND CO2-STORAGE BY CARBONATED WATER INJECTION

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  • The trophic significance of EOR polymers to marine environment – A threat or “treat”?

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  • Surfactant Flooding

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  • Multiphase Flow Parameters

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  • Challenges Associated with Quartz Crystal Microbalance With Dissipation (QCM-D) as a Wettability Screening Tool

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  • Effects of Clay Wettability on the Flow Properties in Oil Reservoir Rocks

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  • Effects of Ferrous Ion (Fe2 ) on Wettability: Oxidation and Cation-Bridging. SPE-185816-MS

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  • Wettability Estimation by Surface Complexation Simulations. SPE-185767-MS

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  • Wettability Characterization Using the Flotation Technique Coupled with Geochemical Simulation

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  • When Size Matters - Polymer Injectivity in Chalk Matrix

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  • Effect of Mud Invasion on the Determined Low Salinity Water Flooding Potential

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  • Screening of the Potential for Different Injection Water Compositions to Alter Wettability to More Water-Wet, SPE-184918-MS

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  • Removal of mud components from reservoir sandstone rocks

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  • Effects of mud invasion on nanotechnology applications?

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  • Characterization of wettability

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  • Butch field: Evaluation of measured rock properties

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  • Surfactant flooding in fractured chalk reservoirs

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  • Wettability study Gohta PL 492 license

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  • Wettability study Alta PL 609 license

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  • Removal of mud components from reservoir sandstone rocks

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  • Critical Aspects in Surfactant Flooding Procedure at Mixed-wet Conditions. SPE-174393-MS

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  • Effect of Initial Sulfate in Reservoir Chalks on the Spontaneous Imbibition of Sea Water

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  • A MODEL FOR LOW SALINITY FLOODING EXPERIMENTS: DISSOLUTION AND ION EXCHANGE

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  • A probabilistic approach for pressure control evaluation in the well planning phase

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  • Sulphate in Ekofisk chalk: Viscous flooding

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  • Skarfjell: Evaluation of measured rock properties

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  • Sulphate in reservoir chalk

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  • Mature Oilfields Screening for CO2 EOR Utilization and Storage – A Case Study

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  • Low Salinity Water Flooding: Effect of Crude Oil Composition

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  • Spontaneous imbibition and viscous flooding of Valhall rock with and without initial sulphate

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  • Effect of Interfacial Tension on Water/Oil Relative Permeability Based on History Matching to Coreflood Data

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  • SPE-164920-MS: Secondary and Tertiary Low Salinity Water Floods: Experimenta and Modelling

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  • SPE 165500: Modeling of Interaction Between CO2 and Rock in Core Flooding Experiments.

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  • Low Salinity Water Flooding: Retention of Polar Oil Components in Sandstone Reservoirs. A24

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  • LSWF Evaluation of cation exchange

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  • TRANSPORT OF SURFACTANTS IN FRACTURED CHALK ROCK – LABORATORY EXPERIMENTS AND NUMERICAL SIMULATIONS

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  • DISPLACEMENT OF OIL BY SURFACTANT FLOODING IN MIXED-WET CONDITION

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  • Sulphate interactions in reservoir chalks.

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  • Gravity Segregated Flow in Surfactant Flooding (SPE 154495)

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  • CO2-flooding Phase 3

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  • Low salinity water flooding experiments and interpretation by simulations

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  • Modeling of Ion-Exchange and Solubility in Low Salinity Water flooding

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  • SPE 155626: Acceleration of oil production in mixed-wet reservoirs by alteration of relative permeability curves using surfactants,

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  • SPE 154178: Surfactant Flooding in Heterogeneous Formations

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  • SPE 160883: Dependency of Remaining Oil Saturation on Wettability and Capillary Number

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  • Effect of Interfacial Tension on Water/Oil Relative Permeability and Remaining Saturation with Consideration of Capillary Pressure

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  • Improved understanding of CO2/Foam EOR techniques by aid of Tracer Tecnology

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  • TOGEOS - TOWARDS GEOLOGICAL STORAGE OF CO2 IN THE CZECH REPUBLIC

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  • The Stability of Pre-formed Foam and the Effect of Gravity Forces on Oil Recovery during CO2-Foam Processes in Fractured Chalk Rock

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  • The stability of pre-formed foam and the effect of gravity forces on

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  • Improvement of Spontaneous Imbibition in Carbonate Rocks by CO2-

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  • Surfactant Flooding Mechanisms at Different Wetting Conditions

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  • Interaction between minerals and brines during low salinity water flooding: Experiments and simulations

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  • Transport of CO2-Foaming Agents During CO2-Foam Processes in Fractured Chalk Rock

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  • Wettability Alteration During Water Flooding and Carbon Dioxide Flooding of Reservoir Chalk Rocks

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  • Modeling of Transport of a CO2-Foaming agent during CO2-Foam Processes in Fractured Chalk Rock

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  • Experimental and Simulation of CO2-Foam Flooding in Fractured Chalk Rock at Reservoir Conditions: Effect of Mode of Injection on Oil Recovery

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  • Effekt av O2 i CO2 injeksjonsgass på undergrunnslagring av CO2

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  • SPE 121253 - Transport of CO2-Foaming Agents during CO2-Foam Processes in Fractured Chalk Rock

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  • Wettability alteration by spontaneous imbibition of sulphate-containing water into chalk cores with different boundary conditions

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  • Sulfate in rock samples from carbonate reservoirs

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  • Wettability alteration due to retention of CO2-foaming agents onto chalk rock

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  • Oil Recovery from Matrix during CO2-foam Flooding of Fractured Carbonate Oil Reservoirs (SPE-113880)

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  • Analysis of the Wettability Alteration Process during Seawater Imbibition into Preferentially Oil-Wet Chalk Cores

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  • Retention of CO2-foaming Agents onto Chalk: Effects of Surfactant Structure, Temperature and Residual Oil Saturation

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  • Modelling of wettability alteration processes in carbonate oil reservoirs

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  • SEM imaging of dry and saturated porous rocks for modelling fluid distribution on pore scale

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  • IOR screening project - Heidrun field

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  • IOR screening project - Snorre Field

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  • Wettability modification in Shell PDO reservoirs

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  • SPE 92412: Asphaltene Deposition During Drilling With Emulsified Drilling Fluids

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  • Injection of seawater and produced water into chalk impact on wettability

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  • Corrosion measurements on carbon steel electrodes in presence of oil, corrosion and scale inhibitors

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  • Hydrate test on KI3811

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  • Surface active compounds for enhanced oil recovery Phase 1

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  • Hydrate Inhibition 2003

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  • Wettability in chalk reservoir rock

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  • Carbon dioxide flooding in Ekofisk - Preliminary potential evaluation

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  • Mechanisms of formation damage for emulsion-based drilling fluids

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  • Criteria for designing and maintaining emulsion fluids for critical field cases

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  • Hydrate Inhibition 2002

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  • International Center for Improved Oil Recovery - Prestudy

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  • New Hydrate inhibitors 2001 - Industri

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  • Modification of Interfacial Tension in Rima Sandstone Reservoir

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  • Scale inhibitor injection in gas lift systems. Technical report 2000.;;

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  • Samlerapport 1998-1999 Scale

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  • Rechargeable scale inhibitor treatment for advanced wells. Technical report 2000.;

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  • SCB-applikasjonsrapporten

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  • Program Management

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  • SCB 2000-program management

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  • Scale control beyond 2000. Annual technical report summary 1999

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  • Scale inhibitor injection in gas lift systems/ Program Scale Control Beyond 2000/ Technical report 1999

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  • Samlerapport scale 1998-2000

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  • Rechargeable scale inhibitor treatment for advanced wells/ Program Scale Control Beyond 2000/ Technical report 1999

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  • Emulsions in oil-based muds technical report 1998

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  • Scale Inhibitor Injection in Gas Lift Systems. Technical report 1998

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  • Rechargeable scale inhibitor treatment for advanced wells. Technical report 1998

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  • Scale Control Beyond 2000 Annual Technical Report Summary 1998

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  • Wettability modifiers: Evaluations and recommendations

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  • Wettability modifiers: Imbibition studies using natural reservoir cores

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  • Emulsions in oil-based muds

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  • Scale inhibition for artificial lift. Preliminary study

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  • Wettability modifiers: Screening tests and fundamental studies

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  • Chemical flooding of oil reservoirs. Part 9: Dynamic adsorption of surfactant onto sandstone cores from injection water with and without polymer present

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International Research Institute of Stavanger
Mailing address:
Visiting address:
P.O. Box 8046, N-4068 Stavanger, Norway
Prof. Olav Hanssensvei 15, 4021 Stavanger


Phone:
Fax:

+47 51 87 50 00
+47 51 87 52 00

General email address: firmapost@iris.no
International Research Institute of Stavanger
Mailing address:
Visiting address:
P.O. Box 8046, N-4068 Stavanger, Norway
Prof. Olav Hanssensvei 15, 4021 Stavanger


Phone:
Fax:

+47 51 87 50 00
+47 51 87 52 00

General email address: firmapost@iris.no
International Research Institute of Stavanger
Mailing address:



Visiting address:
P.O. Box 8046
N-4068 Stavanger
Norway

Prof. Olav Hanssensvei 15 
4021 Stavanger

 
Phone:
Fax:
General email:
+47 51 87 50 00
+47 51 87 52 00
firmapost@iris.no