Tato studie zkoumá, jak povrchově aktivní chemikálie (SAC) v ropě ovlivňují smáčivost uložišť. Smáčivost se týká relativní náchylnosti horniny na ropu nebo vodu. Jak účinnost postupů získávání ropy, tak distribuce kapalin v nádrži jsou ovlivněny smáčivostí uložiště. Bohužel dosud není známo, jak chemické látky regulují smáčivost některých uložišť. Smáčivost látky ovlivňuje teplota, chemismus kapalin a minerální složení hornin. Byl proveden experiment s cílem určit, jak přirozeně se vyskytující SAC, které jsou obvykle přítomny v ropě, ovlivňují smáčivost pískovcových a karbonátových hornin za různých hodnot salinity a teploty. V tomto experimentu byl zkombinován čistý dekan a SAC, které simulují ropnou fázi, k identifikaci účinků určitých SAC. Čtyři studované skupiny jsou: aromatické SAC a SAC obsahující kyslík, síru a dusík. Podle této studie je nezbytné přesně popsat surovou ropu, solanku a okolní horninu, abychom pochopili, proč zaplavení nízkosalinitní vodou podporuje těžbu ropy na některých ložiscích a na jiných ne. To umožňuje účinnou modifikaci chemie vstřikované vody pro zvýšení regenerace ropy a zlepšení smáčivosti. Ukázalo se, že celkové dopady na podmínky smáčivého ropy nebo vody jsou více závislé na teplotě než na slanosti solanky. Pokud se slanost snížila v důsledku dusíkatých SAC, nekyselých sirných SAC a kyslíkatých SAC s krátkým řetězcem, smáčivost karbonátových hornin se posunula směrem ke stavu, kdy byly mokré vodou. Kyseliny s prodlouženým řetězcem SAC Jak slanost solanky klesala, SAC, kyselé sirné SAC a aromatické látky modifikovaly smáčivost uhličitanů na podmínky mokra olejem. Bylo zjištěno, že rozdíly v tom, jak SAC reagují na sůl, jsou jedním z důvodů, proč zaplavování s nízkou slaností funguje v některých nádržích, ale ne ve všech.
Anotace v angličtině
This study investigates how surface-active chemicals (SAC) in crude oil impact the wettability of reservoirs. 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. An experiment was done to determine the impact of naturally occurring SACs, usually found in crude oil, on the wettability of sandstone and carbonate rocks at a range of salinities and temperatures. In this experiment, 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. According to this study, 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. 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. extended-chain acids SAC 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.
Klíčová slova
SAC,Surface active chemicals
EOR,Enhanced Oil recovery
PPM,Part-Per-Million
Klíčová slova v angličtině
SAC,Surface active chemicals
EOR,Enhanced Oil recovery
PPM,Part-Per-Million
Rozsah průvodní práce
Bachelor Thesis
Jazyk
AN
Anotace
Tato studie zkoumá, jak povrchově aktivní chemikálie (SAC) v ropě ovlivňují smáčivost uložišť. Smáčivost se týká relativní náchylnosti horniny na ropu nebo vodu. Jak účinnost postupů získávání ropy, tak distribuce kapalin v nádrži jsou ovlivněny smáčivostí uložiště. Bohužel dosud není známo, jak chemické látky regulují smáčivost některých uložišť. Smáčivost látky ovlivňuje teplota, chemismus kapalin a minerální složení hornin. Byl proveden experiment s cílem určit, jak přirozeně se vyskytující SAC, které jsou obvykle přítomny v ropě, ovlivňují smáčivost pískovcových a karbonátových hornin za různých hodnot salinity a teploty. V tomto experimentu byl zkombinován čistý dekan a SAC, které simulují ropnou fázi, k identifikaci účinků určitých SAC. Čtyři studované skupiny jsou: aromatické SAC a SAC obsahující kyslík, síru a dusík. Podle této studie je nezbytné přesně popsat surovou ropu, solanku a okolní horninu, abychom pochopili, proč zaplavení nízkosalinitní vodou podporuje těžbu ropy na některých ložiscích a na jiných ne. To umožňuje účinnou modifikaci chemie vstřikované vody pro zvýšení regenerace ropy a zlepšení smáčivosti. Ukázalo se, že celkové dopady na podmínky smáčivého ropy nebo vody jsou více závislé na teplotě než na slanosti solanky. Pokud se slanost snížila v důsledku dusíkatých SAC, nekyselých sirných SAC a kyslíkatých SAC s krátkým řetězcem, smáčivost karbonátových hornin se posunula směrem ke stavu, kdy byly mokré vodou. Kyseliny s prodlouženým řetězcem SAC Jak slanost solanky klesala, SAC, kyselé sirné SAC a aromatické látky modifikovaly smáčivost uhličitanů na podmínky mokra olejem. Bylo zjištěno, že rozdíly v tom, jak SAC reagují na sůl, jsou jedním z důvodů, proč zaplavování s nízkou slaností funguje v některých nádržích, ale ne ve všech.
Anotace v angličtině
This study investigates how surface-active chemicals (SAC) in crude oil impact the wettability of reservoirs. 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. An experiment was done to determine the impact of naturally occurring SACs, usually found in crude oil, on the wettability of sandstone and carbonate rocks at a range of salinities and temperatures. In this experiment, 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. According to this study, 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. 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. extended-chain acids SAC 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.
Klíčová slova
SAC,Surface active chemicals
EOR,Enhanced Oil recovery
PPM,Part-Per-Million
Klíčová slova v angličtině
SAC,Surface active chemicals
EOR,Enhanced Oil recovery
PPM,Part-Per-Million
Zásady pro vypracování
We look at how surface active chemicals (SAC) in crude oil impact reservoir and wettability. Wetability refers to a reservoir rock's relative proclivity for oil or water. Wettability influences both the efficiency of oil recovery processes and the fluid distribution in a reservoir. Unfortunately, it is yet unknown how particular reservoirs' wettability is chemically regulated. Wetability is affected by temperature, fluid chemistry, and rock mineralogy. A complete experimental study was carried out to understand the effects of naturally occurring SACs, which are typically found in crude oil, on the wettability of sandstone and carbonate rocks over a wide range of salinities and temperatures. To isolate the effects of certain SACs, model oil blends of pure decane and SACs to simulate the oleic phase were used in this experiment. Aromatic, oxygen-, sulfur-, and nitrogen-containing SACs are the four SAC groups under research. Due to the high cost and time requirements for each experiment, standard wettability testing techniques could not be used in this study's large number of experiments. It was found that, it is necessary to characterize crude oil, brine, and reservoir rock exactly in order to understand why low salinity waterflooding boosts oil recovery in certain reservoirs but not others. This enables effective tailoring of injection water chemistry to improve oil recovery and modify wettability. Overall, the impacts on either oil-wet or water-wet conditions were found to be temperature-dependent rather than brine salinity-dependent. When salinity was lowered, nitrogen SACs, non-acidic sulfur SACs, and short chained oxygen SACs transformed the wettability of carbonate rocks from salt-wet to water-wet conditions. long-chain fatty acids SACs, acidic sulfur SACs, and aromatics changed the wettability of carbonates towards oil-wet conditions when brine salinity was lowered. It was proposed that differences in how SACs respond to salt are one of the reasons why low salinity waterflooding works in certain reservoirs but not others.
Zásady pro vypracování
We look at how surface active chemicals (SAC) in crude oil impact reservoir and wettability. Wetability refers to a reservoir rock's relative proclivity for oil or water. Wettability influences both the efficiency of oil recovery processes and the fluid distribution in a reservoir. Unfortunately, it is yet unknown how particular reservoirs' wettability is chemically regulated. Wetability is affected by temperature, fluid chemistry, and rock mineralogy. A complete experimental study was carried out to understand the effects of naturally occurring SACs, which are typically found in crude oil, on the wettability of sandstone and carbonate rocks over a wide range of salinities and temperatures. To isolate the effects of certain SACs, model oil blends of pure decane and SACs to simulate the oleic phase were used in this experiment. Aromatic, oxygen-, sulfur-, and nitrogen-containing SACs are the four SAC groups under research. Due to the high cost and time requirements for each experiment, standard wettability testing techniques could not be used in this study's large number of experiments. It was found that, it is necessary to characterize crude oil, brine, and reservoir rock exactly in order to understand why low salinity waterflooding boosts oil recovery in certain reservoirs but not others. This enables effective tailoring of injection water chemistry to improve oil recovery and modify wettability. Overall, the impacts on either oil-wet or water-wet conditions were found to be temperature-dependent rather than brine salinity-dependent. When salinity was lowered, nitrogen SACs, non-acidic sulfur SACs, and short chained oxygen SACs transformed the wettability of carbonate rocks from salt-wet to water-wet conditions. long-chain fatty acids SACs, acidic sulfur SACs, and aromatics changed the wettability of carbonates towards oil-wet conditions when brine salinity was lowered. It was proposed that differences in how SACs respond to salt are one of the reasons why low salinity waterflooding works in certain reservoirs but not others.
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. .