Tato studie je přehledovým článkem, který zkoumá, jak povrchově aktivní chemikálie (SAC) v surové ropě ovlivňují smáčivost rezervoárů. Aby byl určen vliv přirozeně se vyskytujících SACs, obvykle se nacházejících v surové ropě, na smáčivost pískovcových a vápenatých hornin při různých salinitách a teplotách, byla v této práci provedena revize literatury nejnovějšího stavu výzkumu. Smáčivost se vztahuje k relativní náchylnosti rezervoárových hornin k oleji nebo vodě. Smáčivost rezervoáru ovlivňuje jak účinnost postupů týkajících se obnovy oleje, tak rozložení tekutin v rezervoáru. Bohužel, ještě není známo, jak chemické látky regulují smáčivost některých rezervoárů. Teplota, chemie tekutin a mineralogie hornin ovlivňují smáčivost látky. Pro simulaci olejové fáze byl použit čistý dekan a SACs. Čtyři skupiny SACs, které byly zkoumány, jsou aromatické, kyslík obsahující, síru obsahující a dusík obsahující SACs. Tato studie odhaluje, že je nezbytné popsat surovou ropu, slanou vodu a rezervoárové horniny přesně, aby bylo možné pochopit, proč snížená salinita vody zvyšuje obnovu oleje v některých rezervoárech, ale ne v ostatních. Tím je umožněna účinná modifikace chemie vstřikované vody k zvýšení obnovy oleje a zlepšení smáčivosti. Celkový vliv na podmínky, buď olejově mokré nebo vodou mokré, byl ukázán jako více závislý na teplotě, než na salinitě vody. Při snižování salinity kvůli dusíkatým SACs, nekyselým sírovým SACs a krátkým kyslíkovým SACs se smáčivost vápenatých hornin přesunula směrem k podmínkám, kdy jsou mokré vodou. Při snižování salinity slané vody se SACs, kyselé sírové SACs a aromatické látky upravovaly smáčivost uhlíkatých hornin k olejově mokrým podmínkám.
Anotace v angličtině
This study is a review article that investigates how surface-active chemicals (SAC) in crude oil impact the wettability of reservoirs. in order to determine the impact of naturally occurring SACs usually found in crude oil on wettability of sandstone and carbonate rocks at a range of salinities and temperatures, a review of the state-of-the-art literature has been done in this thesis. Wettability refers to a reservoir rock's relative susceptibility for oil or water. Both the efficiency of oil recovery procedures and the distribution of fluids in a reservoir are affected by the wettability of the reservoir. Unfortunately, it is yet unknown how chemical agents regulate the wettability of certain reservoirs. Temperature, fluid chemistry, and rock mineralogy all influence the wettability of a substance. Pure decane and SACs were combined to simulate the oleic phase in order to identify the effects of certain SACs. The four SAC groups being studied are aromatic, oxygen-containing, sulfur-containing, and nitrogen-containing SACs. This study discovers that, it is essential to describe crude oil, brine, and reservoir rock exactly in order to comprehend why low salinity waterflooding boosts oil recovery in some reservoirs but not others. order to determine the impact of naturally occurring SACs usually found in crude oil on wettability of sandstone and carbonate rocks at a range of salinities and temperatures, a review of the state-of-the-art literature has been done in this thesis. This enables the efficient modification of injection water chemistry to increase oil recovery and improve wettability. Overall impacts toward either oil-wet or water-wet conditions were shown to be more reliant on temperature than brine salinity. As salinity decreased as a result of nitrogen SACs, non-acidic sulfur SACs, and short-chained oxygen SACs, the wettability of carbonate rocks moved toward circumstances where they were wet with water. As the salinity of the brine decreased, SACs, acidic sulfur SACs, and aromatics modified the wettability of carbonates to oil-wet conditions. It was postulated that differences in how SACs respond to salt are one of the reasons why low salinity waterflooding works in certain reservoirs but not in others.
Tato studie je přehledovým článkem, který zkoumá, jak povrchově aktivní chemikálie (SAC) v surové ropě ovlivňují smáčivost rezervoárů. Aby byl určen vliv přirozeně se vyskytujících SACs, obvykle se nacházejících v surové ropě, na smáčivost pískovcových a vápenatých hornin při různých salinitách a teplotách, byla v této práci provedena revize literatury nejnovějšího stavu výzkumu. Smáčivost se vztahuje k relativní náchylnosti rezervoárových hornin k oleji nebo vodě. Smáčivost rezervoáru ovlivňuje jak účinnost postupů týkajících se obnovy oleje, tak rozložení tekutin v rezervoáru. Bohužel, ještě není známo, jak chemické látky regulují smáčivost některých rezervoárů. Teplota, chemie tekutin a mineralogie hornin ovlivňují smáčivost látky. Pro simulaci olejové fáze byl použit čistý dekan a SACs. Čtyři skupiny SACs, které byly zkoumány, jsou aromatické, kyslík obsahující, síru obsahující a dusík obsahující SACs. Tato studie odhaluje, že je nezbytné popsat surovou ropu, slanou vodu a rezervoárové horniny přesně, aby bylo možné pochopit, proč snížená salinita vody zvyšuje obnovu oleje v některých rezervoárech, ale ne v ostatních. Tím je umožněna účinná modifikace chemie vstřikované vody k zvýšení obnovy oleje a zlepšení smáčivosti. Celkový vliv na podmínky, buď olejově mokré nebo vodou mokré, byl ukázán jako více závislý na teplotě, než na salinitě vody. Při snižování salinity kvůli dusíkatým SACs, nekyselým sírovým SACs a krátkým kyslíkovým SACs se smáčivost vápenatých hornin přesunula směrem k podmínkám, kdy jsou mokré vodou. Při snižování salinity slané vody se SACs, kyselé sírové SACs a aromatické látky upravovaly smáčivost uhlíkatých hornin k olejově mokrým podmínkám.
Anotace v angličtině
This study is a review article that investigates how surface-active chemicals (SAC) in crude oil impact the wettability of reservoirs. in order to determine the impact of naturally occurring SACs usually found in crude oil on wettability of sandstone and carbonate rocks at a range of salinities and temperatures, a review of the state-of-the-art literature has been done in this thesis. Wettability refers to a reservoir rock's relative susceptibility for oil or water. Both the efficiency of oil recovery procedures and the distribution of fluids in a reservoir are affected by the wettability of the reservoir. Unfortunately, it is yet unknown how chemical agents regulate the wettability of certain reservoirs. Temperature, fluid chemistry, and rock mineralogy all influence the wettability of a substance. Pure decane and SACs were combined to simulate the oleic phase in order to identify the effects of certain SACs. The four SAC groups being studied are aromatic, oxygen-containing, sulfur-containing, and nitrogen-containing SACs. This study discovers that, it is essential to describe crude oil, brine, and reservoir rock exactly in order to comprehend why low salinity waterflooding boosts oil recovery in some reservoirs but not others. order to determine the impact of naturally occurring SACs usually found in crude oil on wettability of sandstone and carbonate rocks at a range of salinities and temperatures, a review of the state-of-the-art literature has been done in this thesis. This enables the efficient modification of injection water chemistry to increase oil recovery and improve wettability. Overall impacts toward either oil-wet or water-wet conditions were shown to be more reliant on temperature than brine salinity. As salinity decreased as a result of nitrogen SACs, non-acidic sulfur SACs, and short-chained oxygen SACs, the wettability of carbonate rocks moved toward circumstances where they were wet with water. As the salinity of the brine decreased, SACs, acidic sulfur SACs, and aromatics modified the wettability of carbonates to oil-wet conditions. It was postulated that differences in how SACs respond to salt are one of the reasons why low salinity waterflooding works in certain reservoirs but not in others.
This study is a review article that investigates how surface-active chemicals (SAC) in crude oil impact the wettability of reservoirs. in order to determine the impact of naturally occurring SACs usually found in crude oil on wettability of sandstone and carbonate rocks at a range of salinities and temperatures, a review of the state-of-the-art literature has been done in this thesis. Wettability refers to a reservoir rock's relative susceptibility for oil or water. Both the efficiency of oil recovery procedures and the distribution of fluids in a reservoir are affected by the wettability of the reservoir. Unfortunately, it is yet unknown how chemical agents regulate the wettability of certain reservoirs. Temperature, fluid chemistry, and rock mineralogy all influence the wettability of a substance[O1] . Pure decane and SACs were combined to simulate the oleic phase in order to identify the effects of certain SACs. The four SAC groups being studied are aromatic, oxygen-containing, sulfur-containing, and nitrogen-containing SACs. This study discovers that, it is essential to describe crude oil, brine, and reservoir rock exactly in order to comprehend why low salinity waterflooding boosts oil recovery in some reservoirs but not others. order to determine the impact of naturally occurring SACs usually found in crude oil on wettability of sandstone and carbonate rocks at a range of salinities and temperatures, a review of the state-of-the-art literature has been done in this thesis. This enables the efficient modification of injection water chemistry to increase oil recovery and improve wettability. Overall impacts toward either oil-wet or water-wet conditions were shown to be more reliant on temperature than brine salinity. As salinity decreased as a result of nitrogen SACs, non-acidic sulfur SACs, and short-chained oxygen SACs, the wettability of carbonate rocks moved toward circumstances where they were wet with water. As the salinity of the brine decreased, SACs, acidic sulfur SACs, and aromatics modified the wettability of carbonates to oil-wet conditions. It was postulated that differences in how SACs respond to salt are one of the reasons why low salinity waterflooding works in certain reservoirs but not in others.
This Bachelor thesis contains the following chapters
1. Introduction
2. Backcground// Litrature
3. Methods
4. Case Study
5.Results
6.Discussion
7.References
Zásady pro vypracování
This study is a review article that investigates how surface-active chemicals (SAC) in crude oil impact the wettability of reservoirs. in order to determine the impact of naturally occurring SACs usually found in crude oil on wettability of sandstone and carbonate rocks at a range of salinities and temperatures, a review of the state-of-the-art literature has been done in this thesis. Wettability refers to a reservoir rock's relative susceptibility for oil or water. Both the efficiency of oil recovery procedures and the distribution of fluids in a reservoir are affected by the wettability of the reservoir. Unfortunately, it is yet unknown how chemical agents regulate the wettability of certain reservoirs. Temperature, fluid chemistry, and rock mineralogy all influence the wettability of a substance[O1] . Pure decane and SACs were combined to simulate the oleic phase in order to identify the effects of certain SACs. The four SAC groups being studied are aromatic, oxygen-containing, sulfur-containing, and nitrogen-containing SACs. This study discovers that, it is essential to describe crude oil, brine, and reservoir rock exactly in order to comprehend why low salinity waterflooding boosts oil recovery in some reservoirs but not others. order to determine the impact of naturally occurring SACs usually found in crude oil on wettability of sandstone and carbonate rocks at a range of salinities and temperatures, a review of the state-of-the-art literature has been done in this thesis. This enables the efficient modification of injection water chemistry to increase oil recovery and improve wettability. Overall impacts toward either oil-wet or water-wet conditions were shown to be more reliant on temperature than brine salinity. As salinity decreased as a result of nitrogen SACs, non-acidic sulfur SACs, and short-chained oxygen SACs, the wettability of carbonate rocks moved toward circumstances where they were wet with water. As the salinity of the brine decreased, SACs, acidic sulfur SACs, and aromatics modified the wettability of carbonates to oil-wet conditions. It was postulated that differences in how SACs respond to salt are one of the reasons why low salinity waterflooding works in certain reservoirs but not in others.
This Bachelor thesis contains the following chapters
1. Introduction
2. Backcground// Litrature
3. Methods
4. Case Study
5.Results
6.Discussion
7.References
Seznam doporučené literatury
1. Abdallah, W., J.S. Buckley, A. Carnegie, J. Edwards, B. Herold, E. Fordham, A. Graue, T. Habashy, N. Zeleznev, C. Signer, H. Hussien, B. Montaron, and M. Ziauddin, 2007, Fundamentals of wettability: Oilfield Review, v. 19/2, p. 44-61. 2. Agbalaka C, Abhijit Y. Dandekar, Shirish L. Patil, Khataniar S, Hemsath JR. (2008) "The effect of wettability on oil recovery: a review”, paper SPE 114496 presented at SPE Asia Pacific oil and gas conference and exhibition, Perth, Australia, 20–22 October 2008. 3. Al-Adasani Ahmad, Bai, B., & Wu, Y.-S. (2012) "Investigating Low-Salinity Waterflooding Recovery Mechanisms in Sandstone Reservoirs”. SPE 152997, 18th SPE Improved Oil Recovery Symposium. 4. Al-Attar, H. H., Mahmoud, M. Y., Zekri, A. Y., Almehaideb, R. A., and Ghannam, M. T., (2013) "Low salinity flooding in a selected carbonate reservoir: experimental approach,” in Proceedings of the EAGE Annual Conference & Exhibition incorporating SPE Europec, London, UK, June 2013. 5. Al Harrasi, A., Al-Maamari, R. S., and Masalmeh, S. K., (2012) "Laboratory investigation of smart waterflooding for carbonate reservoirs,” in Proceedings of the Abu Dhabi International Petroleum Conference and Exhibition, SPE-161468-MS, Abu Dhabi, UAE. 6. Al-Shalabi, E.W., Sepehrnoori, K., and Delshad, M. 2014 "Mechanisms behind low salinity water injection in carbonate reservoirs” Fuel, vol. 121, pp. 11–19 7. Al Quraishi, A. A., Al Hussinan, S. N., and Al Yami, H. Q. (2015) "Efficiency and recovery mechanisms of low salinity waterflooding in sandstone and carbonate reservoir,” in Proceedings of the Offshore Mediterranean Conference and Exhibition, OMC-2015-223, Ravenna, Italy. 8. Alotaibi, M.B., Nasralla, R.A., and Nasr-El-Din, H.A. (2011) "Wettability Studies Using Low- Salinity Water in Sandstone Reservoirs.” SPE Reservoir Evaluation & Engineering, 14, pp. 713–725. SPE-149942-PA 9. Anderson, William G., 1986. "Wettability Literature Survey-Part 1: Rock/Oil/Brine Interactions and the Effects of Core Handling on Wettability”, SPE 13932, Pages 1125 – 1127 10. Austad, T., Shariatpanahi, S.F., Strand, S., Black, C.J.J. and Webb, K.J., 2011. Condition for low salinity EOR-effect in carbonate oil reservoirs. 32nd Annual IEA EOR Symposium and Workshop, 17-19 October. 11. Austad, T., RezaeiDoust, A. and Puntervold, T., 2010. Chemical mechanism of low salinity water flooding in sandstone reservoirs. Paper SPE 129767 prepared for presentation at the 2010 SPE Improved Oil Recovery Symposium, 24-28 April. .
Seznam doporučené literatury
1. Abdallah, W., J.S. Buckley, A. Carnegie, J. Edwards, B. Herold, E. Fordham, A. Graue, T. Habashy, N. Zeleznev, C. Signer, H. Hussien, B. Montaron, and M. Ziauddin, 2007, Fundamentals of wettability: Oilfield Review, v. 19/2, p. 44-61. 2. Agbalaka C, Abhijit Y. Dandekar, Shirish L. Patil, Khataniar S, Hemsath JR. (2008) "The effect of wettability on oil recovery: a review”, paper SPE 114496 presented at SPE Asia Pacific oil and gas conference and exhibition, Perth, Australia, 20–22 October 2008. 3. Al-Adasani Ahmad, Bai, B., & Wu, Y.-S. (2012) "Investigating Low-Salinity Waterflooding Recovery Mechanisms in Sandstone Reservoirs”. SPE 152997, 18th SPE Improved Oil Recovery Symposium. 4. Al-Attar, H. H., Mahmoud, M. Y., Zekri, A. Y., Almehaideb, R. A., and Ghannam, M. T., (2013) "Low salinity flooding in a selected carbonate reservoir: experimental approach,” in Proceedings of the EAGE Annual Conference & Exhibition incorporating SPE Europec, London, UK, June 2013. 5. Al Harrasi, A., Al-Maamari, R. S., and Masalmeh, S. K., (2012) "Laboratory investigation of smart waterflooding for carbonate reservoirs,” in Proceedings of the Abu Dhabi International Petroleum Conference and Exhibition, SPE-161468-MS, Abu Dhabi, UAE. 6. Al-Shalabi, E.W., Sepehrnoori, K., and Delshad, M. 2014 "Mechanisms behind low salinity water injection in carbonate reservoirs” Fuel, vol. 121, pp. 11–19 7. Al Quraishi, A. A., Al Hussinan, S. N., and Al Yami, H. Q. (2015) "Efficiency and recovery mechanisms of low salinity waterflooding in sandstone and carbonate reservoir,” in Proceedings of the Offshore Mediterranean Conference and Exhibition, OMC-2015-223, Ravenna, Italy. 8. Alotaibi, M.B., Nasralla, R.A., and Nasr-El-Din, H.A. (2011) "Wettability Studies Using Low- Salinity Water in Sandstone Reservoirs.” SPE Reservoir Evaluation & Engineering, 14, pp. 713–725. SPE-149942-PA 9. Anderson, William G., 1986. "Wettability Literature Survey-Part 1: Rock/Oil/Brine Interactions and the Effects of Core Handling on Wettability”, SPE 13932, Pages 1125 – 1127 10. Austad, T., Shariatpanahi, S.F., Strand, S., Black, C.J.J. and Webb, K.J., 2011. Condition for low salinity EOR-effect in carbonate oil reservoirs. 32nd Annual IEA EOR Symposium and Workshop, 17-19 October. 11. Austad, T., RezaeiDoust, A. and Puntervold, T., 2010. Chemical mechanism of low salinity water flooding in sandstone reservoirs. Paper SPE 129767 prepared for presentation at the 2010 SPE Improved Oil Recovery Symposium, 24-28 April. .
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Záznam průběhu obhajoby
Yousif Al-Shaaya: The Effects of Surface-Active Chemicals on Wettability of Conventional
and Unconventional Formation
The student presented his bachelor's thesis in a PowerPoint presentation. It included introduction (oil formation adhesion dynamic, forces that influence oil-formation interactions, sandstone formation – wettablility dynamic, salinity and migration in sandstones formations carbonate formation- wettablility, dynamic and effects of rock dissolution and salinity), aims of study, methodology, results, and discussion.
The reviews of both substitute supervisor (prof. Bábek) and reviewer (Dr. Jagar Ali) were introduced
by their authors. The supervisor suggested a grade C, because of the formal and factual mistakes.
The reviewer pointed out insufficient lithological description and many formal mistakes, and suggested grade E.
In the discussion of the committee members, prof. Bábek explained that the case-study was his idea. Dr. Spirov asked about conventional and unconventional formation terminology. Dr. Mansurbeg asked what is the meaning of “formation water”. The student responded appropriately to most
of the questions.
In the public discussion, no question arose.
The committee agreed on an overall evaluation – grade C.