Influence of long-term stored oil on wettability and its recovery in depleted petroleum reservoirs

Elsayed, Mahmoud; Al-Abdrabalnabi, Ridha; Zhou, Xianmin; Wu, Yu‐Shu

doi:10.1016/j.egyr.2022.01.099

Cited by 6 publications

(4 citation statements)

References 23 publications

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“…32,33,36,37,46−48 On the contrary, it takes a longer duration ranging between 14 and 21 days at higher temperatures of 60−90 °C to change the rock sample wettability of sandstone. 33,40,42,45,49 As for shale samples, it took 30 days at 82 °C temperature to alter the wettability. 50 Furthermore, it was reported that it took shale samples about 56 days at reservoir temperature to alter their wettability.…”

Section: Discussionmentioning

confidence: 99%

“…Results indicated that carbonates in general require less aging time to alter their wettability condition to oil-wet, around 1–7 days, compared with sandstones, around 14–21 days, based on the temperature and oil used. It took 10–14 days to alter the wettability of carbonate rock samples with temperatures ranging between 25 and 90 °C. ,,,,− On the contrary, it takes a longer duration ranging between 14 and 21 days at higher temperatures of 60–90 °C to change the rock sample wettability of sandstone. ,,,, …”

Section: Discussionmentioning

confidence: 99%

“… 32 , 33 , 36 , 37 , 46 − 48 On the contrary, it takes a longer duration ranging between 14 and 21 days at higher temperatures of 60–90 °C to change the rock sample wettability of sandstone. 33 , 40 , 42 , 45 , 49 …”

Section: Discussionmentioning

confidence: 99%

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A Guide for Selection of Aging Time and Temperature for Wettability Alteration in Various Rock-Oil Systems

Al-Ameer,

Azad,

Al-Shehri

et al. 2023

ACS Omega

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Wettability alteration has been identified to be one of the important mechanisms to improve the microscopic recovery in many of the enhanced oil recovery (EOR) methods including polymer flood, surfactant flood, low salinity flood, microbial flood, alkaline flood, etc. Ensuring the oil-wet nature of the formation before flooding in the laboratory is necessary to study the efficiency of the EOR process, which targets microscopic recovery through wettability alteration. Nevertheless, altering the wettability depends on several parameters, such as aging time, aging temperature, core nature, oil properties, etc. Although several researchers investigated the effect of individual parameters on wettability alteration, the literature is scarce, and the question of what is the shortest and yet the most reliable aging time for ensuring wettability alteration for the specific rock-oil system at different temperatures remains unclear. This paper attempts to seek an answer to this question by compiling the relevant literature to find the effect of individual parameters such as different aging times, temperatures, oil compositions, and rock lithologies on wettability alteration. Results observed from data analysis showed different windows for aging conditions depending on the core sample lithology, initial wettability, and type of oil used. It was noticed that the higher the asphaltene content in the crude oil used, the lower the time and temperature that it takes to alter the sample wettability. Aging a sandstone core under 80 °C using crude oil with 11 wt % % asphaltene took 7 days to shift the core from strongly water-wet to neutral-wet. The same wettability alteration was achieved in 14 days when aging the sandstone sample at 90 °C using crude oil with 0.85 wt % asphaltene content. Generally, it was observed that the aging time decreased as the temperature increased. Moreover, as the sample has a lower initial water wettability condition, the time that it needs to be aged becomes higher. Results indicated that carbonates in general require less aging time to alter their wettability condition to oil-wet, around 1−7 days, compared with sandstones, around 14−21 days.

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Section: Discussionmentioning

confidence: 99%

Section: Discussionmentioning

confidence: 99%

See 1 more Smart Citation

A Guide for Selection of Aging Time and Temperature for Wettability Alteration in Various Rock-Oil Systems

Al-Ameer,

Azad,

Al-Shehri

et al. 2023

ACS Omega

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“…During oil production, reservoirs suffer a natural energy decline. To minimize this effect, two strategies can be implemented: (i) supplement energy through fluid injection and (ii) reducing the viscous and/or capillary resistances of the fluid–rock system by modifying the physicochemical characteristics to reduce the amount of oil retained in the reservoir. , In the case of energy injection, special recovery methods can be used, which are classified into thermal methods, miscible methods, chemical methods, and microbiological methods. − Such technologies are usually applied in mature fields, once conventional methods have been used. However, they may be used at the start of field production, as in the case of thermal methods.…”

Section: Introductionmentioning

confidence: 99%

Increasing Recovery Factor in Heavy Oil Fields Using Alternating Steam and Surfactant Injection

et al. 2023

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Fossil fuels, particularly oil, currently dominate the global energy matrix. With a projected 30% increase in demand by 2040 compared to 2010, it is crucial to maintain current oil production levels. To achieve this, it is necessary to increase the oil recovery factor through alternative methodologies that will improve oil extraction from reservoirs and exploration viability in mature fields. While previous studies have investigated thermal and chemical methods to increase the recovery factor, this study aims to explore the synergy between steam and non-ionic surfactants varying the surfactant degrees of ethoxylation and injection configurations. The experimental study investigated the application of solutions of ethoxylated nonylphenol surfactants (NP-10EO and NP-100EO) combined with steam injection into banks at different concentrations and injection configurations. The results showed that combining the NP-100EO surfactant (0.5% m/m) with steam demonstrated the highest oil recovery (64.88%) compared to conventional steam (45.19%). The most effective configurations were surfactant + steam + surfactant (65.06%) and surfactant + steam + water (65.88%). These findings suggest that the proposed technique of steam injection and surfactant solution could be a promising alternative. By revitalizing marginal fields, this technique could help extend production and stimulate local and regional development.

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A comprehensive evaluation of wind-PV-salt cavern-hydrogen energy storage and utilization system: A case study in Qianjiang salt cavern, China

Gao

et al. 2023

Energy Conversion and Management

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Influence of long-term stored oil on wettability and its recovery in depleted petroleum reservoirs

Cited by 6 publications

References 23 publications

A Guide for Selection of Aging Time and Temperature for Wettability Alteration in Various Rock-Oil Systems

A Guide for Selection of Aging Time and Temperature for Wettability Alteration in Various Rock-Oil Systems

Increasing Recovery Factor in Heavy Oil Fields Using Alternating Steam and Surfactant Injection

A comprehensive evaluation of wind-PV-salt cavern-hydrogen energy storage and utilization system: A case study in Qianjiang salt cavern, China

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