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Papers by Ingebret Fjelde
Journal of Natural Gas Science and Engineering
Energies
During CO2 storage, CO2 plume mixes with the water and oil present at the reservoir, initiated by... more During CO2 storage, CO2 plume mixes with the water and oil present at the reservoir, initiated by diffusion followed by a density gradient that leads to a convective flow. Studies are available where CO2 convective mixing have been studied in water phase but limited in oil phase. This study was conducted to reach this gap, and experiments were conducted in a vertically packed 3-dimensional column with oil-saturated unconsolidated porous media at 100 bar and 50 °C (representative of reservoir pressure and temperature conditions). N-Decane and crude oil were used as oils, and glass beads as porous media. A bromothymol blue water solution-filled sapphire cell connected at the bottom of the column was used to monitor the CO2 breakthrough. With the increase of the Rayleigh number, the CO2 transport rate in n-decane was found to increase as a function of a second order polynomial. Ra number vs. dimensionless time τ had a power relationship in the form of Ra = c×τ−n. The overall pressure d...
International Journal of Greenhouse Gas Control
Journal of Natural Gas Science and Engineering
SPE Reservoir Evaluation & Engineering
Summary Wettability controls the fluid-phase distribution and flow properties in the reservoir. T... more Summary Wettability controls the fluid-phase distribution and flow properties in the reservoir. The ionic compositions of brine, the oil chemistry, and the reservoir-rock mineralogy have profound effects on wettability. Wettability measurement can be obtained from special core analysis (SCAL), but those data are not readily available, and the cost and time of analyzing different possible injection waters can be excessive. There is thus a need for early evaluation of wettability because it is crucial for selecting optimal field-development options. Information about wettability can be indirectly obtained from logging of other rock properties, but the uncertainty in the estimated wettability range is often high. In addition, wettability alteration by injection brines cannot be analyzed by logging. This study seeks to estimate the wettability by assessing the electrostatic interactions existing between the mineral/brine and the oil/brine interfaces using a surface-complexation model (S...
SPE Europec featured at 79th EAGE Conference and Exhibition
Reservoir rock and crude oil samples are usually exposed to oxygen during storage and in laborato... more Reservoir rock and crude oil samples are usually exposed to oxygen during storage and in laboratory experiments. Ferrous ions (Fe2+) on mineral surfaces and in brines can be oxidized to ferric ions (Fe3+). Rock samples can also be contaminated with Fe3+, e.g. from muds. The objective for the study has been to investigate the effects of Fe2+ oxidation and cation bridging by Fe2+ and Fe3+ on wettability. Oxidation of Fe2+ to Fe3+ was first investigated by aging formation water (FW) solutions at reservoir temperature. The effect of Fe3+ on wettability was then studied for the clay mineral glauconite. The wettability was characterized using a flotation method that relies on the affinity of the minerals to either the brine or oil phase. Flooding experiments were carried out in native and restored reservoir cores using FW, sea water (SW) and low salinity water (LSW) as injection waters. The element composition of effluent samples was determined. Geochemical simulations were carried out to...
SPE Latin America and Caribbean Mature Fields Symposium
The water composition can affect the wettability of oil reservoir sandstone rocks. If several inj... more The water composition can affect the wettability of oil reservoir sandstone rocks. If several injection water compositions are available, the composition with highest oil recovery potential should be selected. Alteration of wettability to more water-wet conditions has the potential to accelerate the oil production and thereby reduce the water production. The main objective for the presented work was to develop a method for fast screening of the potential for available injection water compositions to alter wettability to more water-wet. The wettability of reservoir rock samples was characterized by using a flotation method which relies on the affinity of minerals to either the brine or crude oil phase. Crushed reservoir rock samples were aged at reservoir temperature using brine and crude oil of different compositions, and the amounts of oil-wet particles in the oil-phase were determined. The experimental results were compared with geochemical simulation of rock-brine interactions. I...
ABSTRACT Field studies and laboratory tests have shown that foam can reduce the mobility of CO2 a... more ABSTRACT Field studies and laboratory tests have shown that foam can reduce the mobility of CO2 and mitigate the effects of gravity override, viscous fingering and channelling. Thus, macroscopic sweep efficiency is improved and oil production is increased. However, very ...
Recent laboratory and mechanistic modeling studies have demonstrated that CO2-foam has the potent... more Recent laboratory and mechanistic modeling studies have demonstrated that CO2-foam has the potential to recover additional oil in fractured water flooded chalk rock with low matrix permeability. The CO2-foam processes were carried out in short core plugs by injecting pre-formed foam at 340 bar and 55°C. The fractured model was represented by core plug with a 0.3 cm diameter hole drilled though the centre, and packed with monodispersed glass beads. Calculated mobilities also indicated that CO2-foam is highly effective in decreasing the mobility of CO2 and increasing the apparent viscosity of CO2 in fractured chalk rock. In this work, mechanistic simulation studies based on history-matched foam models tuned to laboratory data are used to investigate the effect of the strength of pre-formed foam and the role of gravity forces on oil recovery in long fractured chalk models. Pre-formed foam was injected either horizontally or vertically (from the bottom) at 340 bar and 55°C. Pure CO2 injection was also injected in fractured chalk models and used as base cases. The foam qualities and water saturation were varied. Results indicate that decreasing the foam quality increases the rate of oil production with both horizontal and vertical injection of pre-formed foam. However, the oil recovery efficiency with horizontal injection of pre-foamed foam was higher than with vertical injection. The simulation results show that molecular diffusion is an important oil recovery mechanism in chalk fractured rock with low matrix permeability and should be taken into account, and that considerable gravity effect can affect the oil recovery in horizontal injection of pre-formed foam. The mechanistic models can be used to study CO2-foam processes in fractured chalk reservoirs with multiple fractures.
SPE 129575 Experimental and Simulation of CO2-Foam Flooding in Fractured Chalk Rock at Reservoir ... more SPE 129575 Experimental and Simulation of CO2-Foam Flooding in Fractured Chalk Rock at Reservoir Conditions: Effect of Mode of Injection on Oil Recovery Zuta John, SPE, Fjelde Ingebret, SPE and Berenblyum Roman, SPE, International Research Institute of Stavanger ...
Journal of Petroleum Science and Engineering, Nov 30, 1995
ABSTRACT
Reservoir rocks can undergo significant alterations in wettability upon retention of CO 2 -foamin... more Reservoir rocks can undergo significant alterations in wettability upon retention of CO 2 -foaming agents on them. This paper presents a wettability characterisation study based on the retention of CO 2 -foaming agents on outcrop Liege chalk core samples at 55 o C. Wettability characterisations were done using a sulphate wettability test which determines the water-wet fraction of a chalk rock. Two branched ethoxylated (EO) sulphonates with different ethoxylation degrees; S1 (EO=7) and S2 (EO=12) were used. The aim was to investigate the effect of foaming agent retention on wettability alterations of chalk core samples after aqueous CO 2 -foaming agent flooding. The wettability alterations were measured on chalk core samples saturated with 100% formation water and at residual oil saturation after waterflooding. Wettability indices were found to be altered from less water-wet to more water-wet with increasing ethoxylation degree of the CO 2 -foaming agents on core samples saturated wi...
Journal of Natural Gas Science and Engineering
Energies
During CO2 storage, CO2 plume mixes with the water and oil present at the reservoir, initiated by... more During CO2 storage, CO2 plume mixes with the water and oil present at the reservoir, initiated by diffusion followed by a density gradient that leads to a convective flow. Studies are available where CO2 convective mixing have been studied in water phase but limited in oil phase. This study was conducted to reach this gap, and experiments were conducted in a vertically packed 3-dimensional column with oil-saturated unconsolidated porous media at 100 bar and 50 °C (representative of reservoir pressure and temperature conditions). N-Decane and crude oil were used as oils, and glass beads as porous media. A bromothymol blue water solution-filled sapphire cell connected at the bottom of the column was used to monitor the CO2 breakthrough. With the increase of the Rayleigh number, the CO2 transport rate in n-decane was found to increase as a function of a second order polynomial. Ra number vs. dimensionless time τ had a power relationship in the form of Ra = c×τ−n. The overall pressure d...
International Journal of Greenhouse Gas Control
Journal of Natural Gas Science and Engineering
SPE Reservoir Evaluation & Engineering
Summary Wettability controls the fluid-phase distribution and flow properties in the reservoir. T... more Summary Wettability controls the fluid-phase distribution and flow properties in the reservoir. The ionic compositions of brine, the oil chemistry, and the reservoir-rock mineralogy have profound effects on wettability. Wettability measurement can be obtained from special core analysis (SCAL), but those data are not readily available, and the cost and time of analyzing different possible injection waters can be excessive. There is thus a need for early evaluation of wettability because it is crucial for selecting optimal field-development options. Information about wettability can be indirectly obtained from logging of other rock properties, but the uncertainty in the estimated wettability range is often high. In addition, wettability alteration by injection brines cannot be analyzed by logging. This study seeks to estimate the wettability by assessing the electrostatic interactions existing between the mineral/brine and the oil/brine interfaces using a surface-complexation model (S...
SPE Europec featured at 79th EAGE Conference and Exhibition
Reservoir rock and crude oil samples are usually exposed to oxygen during storage and in laborato... more Reservoir rock and crude oil samples are usually exposed to oxygen during storage and in laboratory experiments. Ferrous ions (Fe2+) on mineral surfaces and in brines can be oxidized to ferric ions (Fe3+). Rock samples can also be contaminated with Fe3+, e.g. from muds. The objective for the study has been to investigate the effects of Fe2+ oxidation and cation bridging by Fe2+ and Fe3+ on wettability. Oxidation of Fe2+ to Fe3+ was first investigated by aging formation water (FW) solutions at reservoir temperature. The effect of Fe3+ on wettability was then studied for the clay mineral glauconite. The wettability was characterized using a flotation method that relies on the affinity of the minerals to either the brine or oil phase. Flooding experiments were carried out in native and restored reservoir cores using FW, sea water (SW) and low salinity water (LSW) as injection waters. The element composition of effluent samples was determined. Geochemical simulations were carried out to...
SPE Latin America and Caribbean Mature Fields Symposium
The water composition can affect the wettability of oil reservoir sandstone rocks. If several inj... more The water composition can affect the wettability of oil reservoir sandstone rocks. If several injection water compositions are available, the composition with highest oil recovery potential should be selected. Alteration of wettability to more water-wet conditions has the potential to accelerate the oil production and thereby reduce the water production. The main objective for the presented work was to develop a method for fast screening of the potential for available injection water compositions to alter wettability to more water-wet. The wettability of reservoir rock samples was characterized by using a flotation method which relies on the affinity of minerals to either the brine or crude oil phase. Crushed reservoir rock samples were aged at reservoir temperature using brine and crude oil of different compositions, and the amounts of oil-wet particles in the oil-phase were determined. The experimental results were compared with geochemical simulation of rock-brine interactions. I...
ABSTRACT Field studies and laboratory tests have shown that foam can reduce the mobility of CO2 a... more ABSTRACT Field studies and laboratory tests have shown that foam can reduce the mobility of CO2 and mitigate the effects of gravity override, viscous fingering and channelling. Thus, macroscopic sweep efficiency is improved and oil production is increased. However, very ...
Recent laboratory and mechanistic modeling studies have demonstrated that CO2-foam has the potent... more Recent laboratory and mechanistic modeling studies have demonstrated that CO2-foam has the potential to recover additional oil in fractured water flooded chalk rock with low matrix permeability. The CO2-foam processes were carried out in short core plugs by injecting pre-formed foam at 340 bar and 55°C. The fractured model was represented by core plug with a 0.3 cm diameter hole drilled though the centre, and packed with monodispersed glass beads. Calculated mobilities also indicated that CO2-foam is highly effective in decreasing the mobility of CO2 and increasing the apparent viscosity of CO2 in fractured chalk rock. In this work, mechanistic simulation studies based on history-matched foam models tuned to laboratory data are used to investigate the effect of the strength of pre-formed foam and the role of gravity forces on oil recovery in long fractured chalk models. Pre-formed foam was injected either horizontally or vertically (from the bottom) at 340 bar and 55°C. Pure CO2 injection was also injected in fractured chalk models and used as base cases. The foam qualities and water saturation were varied. Results indicate that decreasing the foam quality increases the rate of oil production with both horizontal and vertical injection of pre-formed foam. However, the oil recovery efficiency with horizontal injection of pre-foamed foam was higher than with vertical injection. The simulation results show that molecular diffusion is an important oil recovery mechanism in chalk fractured rock with low matrix permeability and should be taken into account, and that considerable gravity effect can affect the oil recovery in horizontal injection of pre-formed foam. The mechanistic models can be used to study CO2-foam processes in fractured chalk reservoirs with multiple fractures.
SPE 129575 Experimental and Simulation of CO2-Foam Flooding in Fractured Chalk Rock at Reservoir ... more SPE 129575 Experimental and Simulation of CO2-Foam Flooding in Fractured Chalk Rock at Reservoir Conditions: Effect of Mode of Injection on Oil Recovery Zuta John, SPE, Fjelde Ingebret, SPE and Berenblyum Roman, SPE, International Research Institute of Stavanger ...
Journal of Petroleum Science and Engineering, Nov 30, 1995
ABSTRACT
Reservoir rocks can undergo significant alterations in wettability upon retention of CO 2 -foamin... more Reservoir rocks can undergo significant alterations in wettability upon retention of CO 2 -foaming agents on them. This paper presents a wettability characterisation study based on the retention of CO 2 -foaming agents on outcrop Liege chalk core samples at 55 o C. Wettability characterisations were done using a sulphate wettability test which determines the water-wet fraction of a chalk rock. Two branched ethoxylated (EO) sulphonates with different ethoxylation degrees; S1 (EO=7) and S2 (EO=12) were used. The aim was to investigate the effect of foaming agent retention on wettability alterations of chalk core samples after aqueous CO 2 -foaming agent flooding. The wettability alterations were measured on chalk core samples saturated with 100% formation water and at residual oil saturation after waterflooding. Wettability indices were found to be altered from less water-wet to more water-wet with increasing ethoxylation degree of the CO 2 -foaming agents on core samples saturated wi...