An integrated evaluation of enhanced oil recovery and geochemical processes for carbonated water injection in carbonate rocks

Mahzari, Pedram; Jones, Adrian P.; Oelkers, Eric H.

doi:10.1016/j.petrol.2019.106188

Cited by 32 publications

(25 citation statements)

References 32 publications

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“…Another implication of the results presented in this study concerns CO2 storage. The CO2 storage capacity of shale oil formations can be significant 40,[66][67][68][69] . Based on Figure 18, the amount of gas that remains in the shale matrix can be increased by more than 10% when live oil was used rather than dead oil, although the dead oil has much higher intrinsic capacity to store the gas in a dissolved form.…”

Section: Comparison Of Live and Dead Oil Experimentsmentioning

confidence: 99%

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Novel laboratory investigation of huff-n-puff gas injection for shale oils under realistic reservoir conditions

Mahzari

Mitchell

Jones

et al. 2021

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Enhanced oil recovery (EOR) from shale oil formations is recognized as the next frontier in the exploitation of unconventional resources. Current approaches for performing EOR experiments using fractured rocks can generate misleading results as the fractured cores cannot be saturated with live oils. In this work, a novel laboratory methodology is developed to quantify the efficiency of gas huff-n-puff in shale oil formations under realistic reservoir conditions, i.e. live oil and hydraulic fracturing reservoir conditions. This new approach involves first saturating the shale core with oil and then hydraulic fracturing the oil-saturated core by increasing pore pressure above the core confining pressure. To demonstrate the viability of this new methodology, shale cores from the Haynesville formation with a permeability of 0.0001 mD were tested.Two huff-n-puff experiments were performed by the injection of associated gas into cores saturated with either dead crude oil or live oil. 48% additional oil recovery was achieved from the shale core saturated with live oil whereas, the shale core saturated with dead oil yielded a 33% enhanced oil recovery, which is significantly lower than that of the live oil. Furthermore, the pressure decay profiles during the soaking periods indicate a comparatively higher gas penetration into the live oil system despite the higher gas solubility in the dead oil. The in-situ gas formation can have a strong influence on the efficiency of huffn-puff. The notable differences in the results obtained on live compared to dead oil experiments demonstrate the need to perform more realistic laboratory experiments to better optimize shale oil EORbased extractions in the field.

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Section: Comparison Of Live and Dead Oil Experimentsmentioning

confidence: 99%

“…Despite the lack of laboratory studies under full reservoir conditions, several numerical simulations demonstrate the importance of using realistic reservoir conditions [39][40][41] . Such numerical simulations, however, require input parameters obtained from experimental observations .…”

Section: Introductionmentioning

confidence: 99%

Novel laboratory investigation of huff-n-puff gas injection for shale oils under realistic reservoir conditions

Mahzari

Mitchell

Jones

et al. 2021

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“…The dissolution and deposition of carbonate can be observed, and the deposition largely depends on the composition of the brine. Mahzari et al (2019) injected CO 2 -rich carbonated water into carbonate rocks through visualization experiments and carried out a quantitative analysis of crude oil recovery and DP profiles. It was found that additional oil recovery can be obtained by injecting carbonated water, mainly because the interaction between CO 2 and water adjusts the oil composition and the relative permeability of the gas and oil, and the interfacial tension (IFT) between oil and gas shows a downward trend, which indicates that light oil components are extracted into the gas phase.…”

Section: Carbonated Water Floodingmentioning

confidence: 99%

A review of development methods and EOR technologies for carbonate reservoirs

et al. 2020

Pet. Sci.

175

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Carbonate reservoirs worldwide are complex in structure, diverse in form, and highly heterogeneous. Based on these characteristics, the reservoir stimulation technologies and fluid flow characteristics of carbonate reservoirs are briefly described in this study. The development methods and EOR technologies of carbonate reservoirs are systematically summarized, the relevant mechanisms are analyzed, and the application status of oil fields is catalogued. The challenges in the development of carbonate reservoirs are discussed, and future research directions are explored. In the current development processes of carbonate reservoirs, water flooding and gas flooding remain the primary means but are often prone to channeling problems. Chemical flooding is an effective method of tertiary oil recovery, but the harsh formation conditions require high-performance chemical agents. The application of emerging technologies can enhance the oil recovery efficiency and environmental friendliness to a certain extent, which is welcome in hard-to-recover areas such as heavy oil reservoirs, but the economic cost is often high. In future research on EOR technologies, flow field control and flow channel plugging will be the potential directions of traditional development methods, and the application of nanoparticles will revolutionize the chemical EOR methods. On the basis of diversified reservoir stimulation, combined with a variety of modern data processing schemes, multichannel EOR technologies are being developed to realize the systematic, intelligent, and cost-effective development of carbonate reservoirs.

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“…Water alternating gas (WAG) is the most popular method where premature breakthrough of CO 2 is controlled by the injection of water on regular intervals (Mahzari et al, 2019;Yu et al, 2019;Zhao et al, 2015). The water column gets sandwiched between two subsequent CO 2 injections and it helps to increase the residence time of CO 2 in porous media.…”

Section: Introductionmentioning

confidence: 99%

“…Thus, compared to sole CO 2 , WAG process is more promising to make CO 2 injection remarkable for miscibility with crude oil and geological storage (Chaturvedi et al, 2020;Dang et al, 2016;Kumar and Mandal, 2017;Mahzari et al, 2019;Seyyedsar et al, 2016).…”

Section: Introductionmentioning

confidence: 99%

Impact of Low Salinity Water Injection on CO2 Storage and Oil Recovery for Improved CO2 Utilization

Chaturved

Ravilla

Kaleem

et al. 2021

Chemical Engineering Science

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CO 2 utilization for oil recovery applications is often impacted by the challenges such as viscous fingering and its premature breakthrough. Injection of slugs of water-alternating-gas (WAG) generally aims to overcome these challenges though the control of CO 2 mobility. Moreover, the oil recovery potential of WAG is largely dependent on the injection water salinity and the subsequent CO 2 dissolution and storage. Therefore, the effect of varying salinity (0-4 wt% NaCl) on CO 2 loading capacity of water is investigated in this study, at two test temperatures of 323 K and 363 K and three confining pressures of 4, 8, and 12 bar, and subsequently, the flooding experiments were performed to find the low salinity (LS)-WAG process suitability in oil recovery applications from porous sandstone rocks. The inclusion of salt was found to significantly affect CO 2 loading capacity of water. At higher NaCl concentration (4 wt%), CO 2 loading decreased by 50% as demonstrated by absorption kinetic study. LS-WAG suggested maximum oil recovery 55-58% of original oil in place for water salinity of 2 wt% NaCl at both the test temperatures. Increment in pressure had a positive impact on CO 2 loading while increasing temperature showed reverse behavior. As a result of LS in WAG and kinetic adsorption study, it is anticipated that the reduction in water salinity is a favorable factor in the CO 2 storage and oil recovery performance of CO 2 injection. The instance of CO 2 injection was also varied for LS-WAG process and its effect on oil recovery from sand-packs was reported. Oil recovery results demonstrated that WAG was similarly effective in all the stages of the injection cycle as long as water salinity remained lower than 2 wt% NaCl. Based on the findings in this study, it is recommended to implement the WAG in conjunction with low salinity water (LSW) in moderate saline conditions, which is of key importance for various applications where water salinity differs on a large scale.

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An integrated evaluation of enhanced oil recovery and geochemical processes for carbonated water injection in carbonate rocks

Cited by 32 publications

References 32 publications

Novel laboratory investigation of huff-n-puff gas injection for shale oils under realistic reservoir conditions

Novel laboratory investigation of huff-n-puff gas injection for shale oils under realistic reservoir conditions

A review of development methods and EOR technologies for carbonate reservoirs

Impact of Low Salinity Water Injection on CO2 Storage and Oil Recovery for Improved CO2 Utilization

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