- E-mailMartin.Ferno@uib.no
- Phone+47 55 58 27 92+47 481 15 623
- Visitor AddressAllegt. 55
- Postal AddressPostboks 78035020 BERGEN
My research interests include
Multiphase flow in porous media, with focus on capillary heterogeneities including permeability contrasts, pore scale distribution and fractures. The influence of wettability of fluid flow and fluid distributions and multiphase functions in sandstone, chalk and carbonate rock types. In-situ imaging of dynamic displacement processes in porous media using MRI/NMR, NTI and CT. The impact of capillary forces and EOR/IOR in conventional and fractured reservoirs, including foam flow, polymer gels. Generating correct capillary curves and relative permeability curves from different SCAL techniques for input parameters in simulators. Additives to invading water in spontaneous imbibition tests to enhance oil recovery.
PhD students
Øyvind Eide
Jarand Gauteplass
MSc
2012/2013
Nicolai Ivar Majlaton
Ary Ahmed
Kamal Ahmed
Stuart Baird
Stig Langlo
Stig Lie
Tom Ydstebø
2011/2012
Christophersen, Anders
Økt oljeutvinning av injeksjon av CO2-skum i en oppsprukket karbonatbergart ved ulike fuktforhold
Fløysand Tveit, Jørn-Anders
An Experimental Study of Water Mixing in Carbonate Rocks Using Different Imaging Techniques
Nakken Follesø, Håvard
Fluid Displacements during Multiphase Flow Visualized at the Pore Scale Using Micromodels
Skibenes, Ane
Injeksjon av CO2-skum for økt oljeutvinning i en oppsprukket karbonatbergart under ulike fuktforhold
2010/2011
Eide, Øyvind
Integrated EOR and Waterflood Stability Criteria in Carbonate Rock
Børve, Bjarte
Økt oljeutvinning i kalk basert på vannkjemi og potensialbestemmende ioner for endring av fukt
Nybø, Sigurd
Skaleringskoeffisientens innvirkning på vannflømminger i sandstein og tertiær utvinnig ved bruk av CO2
Gauteplass, Jarand
Primærdreneringsprosesser ved bruk av gass målt med porøs plate, sentrifuge og under skum injeksjon
2009/2010
Grønsdal, Reidar
Økt oljeutvinning i kalk basert på vannkjemi og potensialbestemmende ioner for endring av fukt
Subjects
PTEK 211 - Fundamentals of Reservoir Physics
PTEK 212 - Reservoir Technology I
PTEK 214 - Experimental Reservoir Physcis
Books
- 2012. Enhanced Oil Recovery in Fractured Reservoirs. INTECH. 318 pages. ISBN: 978-953-51-0629-6.
Journal articles
- 2019. Core-scale sensitivity study of CO2 foam injection strategies for mobility control, enhanced oil recovery, and CO2 storage. E3S Web of Conferences.
- 2019. An Integrated Carbon-Dioxide-Foam Enhanced-Oil-Recovery Pilot Program With Combined Carbon Capture, Utilization, and Storage in an Onshore Texas Heterogeneous Carbonate Field. SPE Reservoir Evaluation and Engineering. 22: 1449-1466. doi: 10.2118/190204-PA
- 2019. An Experimental Investigation of Gas-Production Rates During Depressurization of Sedimentary Methane Hydrates. SPE Journal. 24: 522-530. doi: 10.2118/190811-PA
- 2019. Measurements of CH4 and CO2 relative permeability in hydrate-bearing sandstone. Journal of Petroleum Science and Engineering. 177: 880-888. doi: 10.1016/j.petrol.2019.02.091
- 2019. Foam Flow and Mobility Control in Natural Fracture Networks. Transport in Porous Media. 1-18. Published 2019-02-27. doi: 10.1007/s11242-019-01249-3
- 2019. Population-balance modeling of CO2 foam for CCUS using nanoparticles. Journal of Natural Gas Science and Engineering.
- 2019. Surfactant Prefloods During Carbon Dioxide Foam Injection for Integrated Enhanced Oil Recovery in Fractured Oil-Wet Carbonates. SPE Journal. 24: 1139-1153. doi: 10.2118/190168-PA
- 2019. The Effect of Non-Uniform Wettability and Heterogeneity on Induction Time and Onset of Spontaneous Imbibition. SPE Journal. doi: https://doi.org/10.2118/190311-PA
- 2019. Performance of Silica Nanoparticles in CO2-foam for EOR and CCUS at Tough Reservoir Conditions. SPE Journal. doi: 10.2118/191318-MS
- 2019. Pore-to-Core EOR Upscaling for CO2-foam for CCUS. SPE Journal. 11 pages. doi: 10.2118/190869-PA
- 2019. Model calibration for forecasting CO2-foam enhanced oil recovery field pilot performance in a carbonate reservoir. Petroleum Geoscience. 9 pages. Published 2019-11-15. doi: 10.1144/petgeo2019-093
- 2018. Pillars or Pancakes? Self-Cleaning Surfaces without Coating. Nano letters (Print). doi: 10.1021/acs.nanolett.8b02982
- 2018. Salinity Effects on Pore-Scale Methane Gas Hydrate Dissociation. Journal of Geophysical Research (JGR): Solid Earth. 123: 5599-5608. doi: 10.1029/2017JB015345
- 2018. Darcy-scale simulation of boundary-condition effects during capillary-dominated flow in high-permeability systems. SPE Reservoir Evaluation and Engineering. 22: 673-691. doi: 10.2118/188625-PA
- 2018. Silica Nanoparticles to Stabilize CO2-foam for Improved CO2 Utilization: Enhanced CO2 Storage and Oil Recovery from Mature Oil Reservoirs. Fuel. 216: 621-626. doi: 10.1016/j.fuel.2017.11.144
- 2018. Mechanisms of Multiphase Reactive Flow using Biogenically Calcite-Functionalized Micromodels. Lab on a Chip. 18: 3881-3891. doi: 10.1039/C8LC00793D
- 2017. Determination of Pore-Scale Hydrate Phase Equilibria in Sediments Using Lab-on-a-Chip Technology. Lab on a Chip. 17: 4070-4076. doi: 10.1039/c7lc00719a
- 2017. Vi kan ikke gamble med nordområdene. Bergens Tidende.
- 2017. Pore-scale mechanisms during low salinity waterflooding: Oil mobilization by diffusion and osmosis. Journal of Petroleum Science and Engineering. 163: 650-660. doi: 10.1016/j.petrol.2017.10.022
- 2017. Wettability effects on osmosis as an oil-mobilization mechanism during low-salinity waterflooding. Petrophysics. 58: 28-35. doi: SPWLA-2017-v58n1a3
- 2017. Nanotechnology for Improved CO2 Utilization in CCS: Laboratory Study of CO2-Foam Flow and Silica Nanoparticle Retention in Porous Media. International Journal of Greenhouse Gas Control. 64: 113-118. Published 2017-07-19. doi: 10.1016/j.ijggc.2017.07.010
- 2016. Multiscale laboratory verification of depressurization for production of sedimentary methane hydrates. SPE Journal. 22: 138-147. doi: 10.2118/180015-PA
- 2016. New insight into wormhole formation in polymer gel during water chase floods with positron emission tomography. SPE Journal. 22: 32-40. doi: 10.2118/180051-PA
- 2016. Visualization of carbon dioxide enhanced oil recovery by diffusion in fractured chalk. SPE Journal. 21: 112-120. doi: 10.2118/170920-PA
- 2016. Experimental study of foam generation, sweep efficiency, and flow in a fracture network. SPE Journal. 21: 1140-1150. doi: 10.2118/170840-PA
- 2016. Influence of wettability Study of Foam Generation, Sweep Efficiency and Flow in a Fracture Network. SPE Journal. 21.
- 2016. Pore-level hydrate formation mechanisms using realistic rock structures in high-pressure silicon micromodels. International Journal of Greenhouse Gas Control. 53: 178-186. doi: 10.1016/j.ijggc.2016.06.017
- 2016. Influence of wettability on residual gas trapping and enhanced oil recovery in three-phase flow: A pore-scale analysis by use of microcomputed tomography. SPE Journal. 21: 1916-1929. doi: 10.2118/179727-PA
- 2015. CO2 EOR by Diffusive Mixing in Fractured Reservoirs. Petrophysics. 56: 23-31.
- 2015. Mobility control during CO2 EOR in fractured carbonates using foam: Laboratory evaluation and numerical simulations. Journal of Petroleum Science and Engineering. 135: 442-451. doi: 10.1016/j.petrol.2015.10.005
- 2015. Combined positron emission tomography and computed tomography to visualize and quantify fluid flow in sedimentary rocks. Water Resources Research. 51: 7811-7819. doi: 10.1002/2015WR017130
- 2015. Flow visualization of CO2 in tight shale formations at reservoir conditions. Geophysical Research Letters. 42: 7414-7419. doi: 10.1002/2015GL065100
- 2015. Parametric study of oil recovery during CO2 injections in fractured chalk: Influence of fracture permeability, diffusion length and water saturation. Journal of Natural Gas Science and Engineering. 27: 1063-1073. doi: 10.1016/j.jngse.2015.09.052
- 2015. Pore-level foam generation and flow for mobility control in fractured systems. Colloids and Surfaces A: Physicochemical and Engineering Aspects. 468: 184-192. doi: 10.1016/j.colsurfa.2014.12.043
- 2015. Mobilization of immobile water: Connate-water mobility during waterfloods in heterogeneous reservoirs. SPE Journal. 20: 1-11. doi: 10.2118/170249-PA
- 2014. The effect of viscosity on relative permeabilities derived from spontaneous imbibition tests. Transport in Porous Media. 106: 383-404. doi: 10.1007/s11242-014-0406-4
- 2014. Capillary pressure and relative permeability estimated from a single spontaneous imbibition test. Journal of Petroleum Science and Engineering. 115: 66-77. doi: 10.1016/j.petrol.2014.02.001
- 2014. Miscible and immiscible foam injection for mobility control and EOR in fractured oil-wet carbonate rocks. Transport in Porous Media. 104: 109-131. doi: 10.1007/s11242-014-0323-6
- 2013. Magnetic resonance imaging of the development of fronts during spontaneous imbibition. Journal of Petroleum Science and Engineering. 101: 1-11. doi: 10.1016/j.petrol.2012.11.012
- 2012. Wettability effects on water mixing during waterflood oil recovery. Journal of Petroleum Science and Engineering. 94-95: 89-99. doi: 10.1016/j.petrol.2012.06.020
- 2012. Water Mixing During Waterflood Oil Recovery: The Effect of Initial Water Saturation. SPE Journal. 17: 43-52. doi: 10.2118/149577-PA
- 2012. Experimental study on foam in fractured oil-wet limestone for enhanced oil recovery. SPE Reservoir Evaluation and Engineering. 15: 218-228. doi: 10.2118/129763-PA
- 2012. Comparison of residual oil cluster size distribution, morphology and saturation in oil-wet and water-wet sandstone. Journal of Colloid and Interface Science. 375: 187-192. doi: 10.1016/j.jcis.2012.02.025
- 2012. Spontaneous counter-current imbibition outwards from a hemi-spherical depression. Journal of Petroleum Science and Engineering. 90-91: 131-138. Published 2012-04-25. doi: 10.1016/j.petrol.2012.04.017
- 2012. Modeling foam displacement in fractures. Journal of Petroleum Science and Engineering. 100: 50-58. doi: 10.1016/j.petrol.2012.11.018
- 2011. Use of sulfate for water based enhanced oil recovery during spontaneous imbibition in chalk. Energy & Fuels. 25: 1697-1706. doi: 10.1021/ef200136w
- 2011. Wettability effects on the matrix-fracture fluid transfer in fractured carbonate rocks. Journal of Petroleum Science and Engineering. 77: 146-153. doi: 10.1016/j.petrol.2011.02.015
- 2011. Water mixing during spontaneous imbibition at different boundary and wettability conditions. Journal of Petroleum Science and Engineering. 78: 586-595. doi: 10.1016/j.petrol.2011.07.013
- 2010. Complementary imaging of oil recovery mechanisms in fractured reservoirs. Chemical Engineering Journal. 158: 32-38. Published 2010-03-15. doi: 10.1016/j.cej.2008.11.049
- 2010. Dynamic laboratory wettability alteration. Energy & Fuels. 24: 3950-3958. doi: 10.1021/ef1001716
- 2010. Wettability Impacts on Oil Displacement in Large Fractured Carbonate Blocks. Energy & Fuels. 24: 3020-3027. doi: 10.1021/ef1000453
- 2010. Oil production by spontaneous imbibition from sandstone and chalk cylindrical cores with two ends open. Energy & Fuels. 24: 1164-1169. doi: 10.1021/ef901118n
- 2009. Capillary pressures obtained by dynamic in situ fluid saturation measurements during core plug centrifugation. Transport in Porous Media. 80: 253-267. doi: 10.1007/s11242-009-9355-8
Reports and theses
- 2008. A Study of Capillary Pressure and Capillary Continuity in Fractured Rocks. 150 pages.
Book sections
- 2018. Integrated CO2 Foam EOR Pilot Program with Combined CCUS in an Onshore Texas Heterogeneous Carbonate Field. kapittel. In:
- 2018. SPE Improved Oil Recovery Conference. Society of Petroleum Engineers. 3650 pages. ISBN: 978-1-61399-570-9.
- 2018. An experimental investigation of gas production rates during depressurization of sedimentary methane hydrates. kapittel. In:
- 2018. SPE Europec featured at 80th EAGE Conference and Exhibition, 11-14 June, Copenhagen, Denmark. Society of Petroleum Engineers. ISBN: 978-1-61399-606-5.
- 2018. The Onset of Spontaneous Imbibition: How Irregular Fronts Influence Imbibition Rate and Scaling Groups. KAPITTEL, pages . In:
- 2018. SPE Improved Oil Recovery Conference. Society of Petroleum Engineers. 3650 pages. ISBN: 978-1-61399-570-9.
- 2018. Pore-to Core EOR Upscaling for CO2-foam for CCUS. kapittel. In:
- 2018. SPE Europec featured at 80th EAGE Conference and Exhibition, 11-14 June, Copenhagen, Denmark. Society of Petroleum Engineers. ISBN: 978-1-61399-606-5.
- 2017. CO2 Foam EOR Field Pilot - Pilot Design, Geologic and Reservoir Modeling, and Laboratory Investigations. Kapittel. In:
- 2017. 19th European Symposium on Improved Oil Recovery/IOR Norway 2017. European Association of Geoscientists and Engineers. 2546 pages. ISBN: 978-94-6282-209-2.
- 2017. Numerical Interpretation of Laboratory Spontaneous Imbibition - Incorporation of the Capillary Back Pressure and How it Affects SCAL. KAPITTEL. In:
- 2017. SPE Abu Dhabi International Petroleum Exhibition & Conference. Society of Petroleum Engineers. ISBN: 978-1-61399-563-1.
- 2017. Numerical Modelling Study for Designing CO2-foam Field Pilot. 75, pages . In:
- 2017. 19th European Symposium on Improved Oil Recovery/IOR Norway 2017. European Association of Geoscientists and Engineers. 2546 pages. ISBN: 978-94-6282-209-2.
- 2016. New Insight from Visualization of Mobility Control for Enhanced Oil Recovery Using Polymer Gels and Foams. Chapter 3, pages 101-122. In:
- 2016. CHEMICAL ENHANCED OIL RECOVERY (CEOR)- A PRACTICAL OVERVIEW. INTECH. 191 pages. ISBN: 978-953-51-2700-0.
- 2007. Do’s and Don’ts When Developing a System to Investigate Spontaneous Imbibition in Unconsolidated Porous Media. kapittel. In:
- 2007. Conference Proceedings of the Symposium of the Society of Core Analysts. Society of Core Analysts. 6 pages.
- 2007. Dos and Don'ts when Developing a System to Investigate Spontaneous Imbibition in Unconsolidated Porous Media. KAPITTEL. In:
- 2007. Conference Proceedings of the Symposium of the Society of Core Analysts. Society of Core Analysts. 6 pages.
More information in national current research information system (CRIStin)
Integrated Enhanced Oil Recovery
Fields of competence