Multiphase flow challenges in drilling, completions, and injection: Part 2

Abstract

This review addresses the diverse applications of multiphase flows, focusing on drilling, completions, and injection activities in the oil and gas industry. Identifying contemporary challenges and suggesting future research directions, it comprehensively reviews evolving applications in these multidisciplinary topics. In drilling, challenges such as gas kicks, cutting transport, and hole cleaning are explored. The application of immersion cooling technology in surface facilities for gas fields utilized in integrated bitcoin mining is also discussed. Nanotechnology, particularly the use of nanoparticles and nanofluids, shows promise in mitigating particulate flow issues and controlling macroscopic fluid behavior. Nanofluids find applications in drilling for formation strengthening and mitigating formation damage in completions as highlighted in this work, as well as in subsurface injection for enhanced oil recovery (EOR), waterflooding, reservoir mapping, and sequestration tracking. The review emphasizes the need for techno-economic analyses using multiphase flow models, particularly in scenarios involving fluid injection for energy storage. Addressing these multiphase flow challenges is crucial for the future of energy diversity and transition initiatives, offering benefits such as financial stability, resilience, sustainability, and reliable supply chains. In the first part of this review, we presented the application of multiphase (typical gas, liquid, solid) flow models and technology for drilling, completion, and injection operations. This second part of this review presents the applications of multiphase particulate (nanofluid) flow technology for drilling, completion, and injection operations. It aims to identify technology development needs related to multiphase flows, enhancing research endeavors for better cognition and mitigation of the identified issues. The use of computational fluid dynamics (CFD), machine learning (ML), and system modeling for multiphase flow models is also discussed.

Keywords

Multiphase flow / Drilling / Completion / Injection / Nanoparticle

CRediT authorship contribution statement

C.E. Obi: Writing -original draft, Visualization, Validation, Project administration, Methodology, Investigation, Formal analysis, Data curation, Conceptualization. A.R. Hasan: Writing -review & editing, Validation, Supervision, Methodology, Formal analysis. A. Badejo: Writing -original draft, Visualization, Software, Investigation, Data curation. M.A. Rahman: Validation, Supervision, Resources, Investigation. D. Banerjee: Writing -review & editing, Visualization, Validation, Supervision, Project administration, Methodology, Investigation, Formal analysis.

Declaration of competing interest

The authors declare that they have no known competing financial interests or personal relationships that could have appeared to influence the work reported in this paper.

References

[1] R. Azarinezhad, A. Chapoy, R. Anderson, et al., A wet cold-flow technology for tackling offshore flow-assurance problems, SPE Proj. Facil. Constr. 5 (2) (2010) 58-64, https://doi.org/10.2118/132349-PA.

[2] X.F.F. Lv, J. Gong, W.Q.Q. Li, et al., Experimental study on natural-gashydrate-slurry flow, SPE J. 19 (2) (2013) 206-214, https://doi.org/10.2118/158597-PA.

[3] Ahmad A. Majid, Wonhee Lee, Vishal Srivastava, et al., Experimental investigation of gas-hydrate formation and particle transportability in fully and partially dispersed multiphase-flow systems using a high-pressure flow loop, SPE J. 23 (3) (2017) 937-951, https://doi.org/10.2118/187952-PA.

[4] Kaufui V. Wong, Omar De Leon, Applications of nanofluids: current and future, Adv. Mech. Eng. 2 (2010) 519659. https://journals.sagepub.com/doi/abs/10.1155/2010/519659.

[5] Debjyoti Banerjee, Nanofluids and Applications to Energy Systems, 2017, https://doi.org/10.1016/B978-0-12-409548-9.10144-7.

[6] Mehrdad Alfi, Debjyoti Banerjee, Hadi Nasrabadi, Effect of confinement on the dynamic contact angle of hydrocarbons, Energy Fuels 30 (11) (2016) 8962-8967, https://doi.org/10.1021/acs.energyfuels.6b01450.

[7] Mehrdad Alfi, Hadi Nasrabadi, Debjyoti Banerjee, Effect of confinement on bubble point temperature shift of hydrocarbon mixtures: experimental investigation using nanofluidic devices,in:Proc., SPE Annual Technical Conference and Exhibition, 2017, https://doi.org/10.2118/187057-MS.

[8] D. Banerjee, V.K. Dhir, Study of subcooled film boiling on a horizontal disc: part 2dexperiments, J. Heat Transf. 123 (2001).

[9] Muhammed A. Hassan, Debjyoti Banerjee, A soft computing approach for estimating the specific heat capacity of molten salt-based nanofluids, J. Mol. Liq. 281 (2019) 365-375. https://www.sciencedirect.com/science/article/pii/S0167732218347639.

[10] Byeongnam Jo, Debjyoti Banerjee, Effect of dispersion homogeneity on specific heat capacity enhancement of molten salt nanomaterials using carbon nanotubes, J. Sol. Energy Eng. 137 (1) (2014), https://doi.org/10.1115/1.4028144.

[11] Byeongnam Jo, Debjyoti Banerjee, Effect of solvent on specific heat capacity enhancement of binary molten salt-based carbon nanotube nanomaterials for thermal energy storage, Int. J. Therm. Sci. 98 (2015) 219-227. https://www.sciencedirect.com/science/article/pii/S1290072915002185.

[12] Aditya Kuchibhotla, Sanjukta Chakraborty, Debjyoti Banerjee, Experimental validation of numerical predictions for “Deviant” density enhancement of protein emulsions in oil (oleo-nanofluids), SN Appl. Sci. 2 (9) (2020) 1617, https://doi.org/10.1007/s42452-020-03422-6.

[13] Hyun-eun Kwak, Donghyun Shin, Debjyoti Banerjee, Enhanced sensible heat capacity of molten salt and conventional heat transfer fluid based nanofluid for solar thermal energy storage application, in: Proc., ASME 2010 4th International Conference on Energy Sustainability, 2010, pp. 735-739, https://doi.org/10.1115/ES2010-90295.

[14] Navdeep Singh, Debjyoti Banerjee,Nanofins, first ed., Nanofins, 2014.

[15] Donghyun Shin, Debjyoti Banerjee, Experimental investigation of molten salt nanofluid for solar thermal energy application, in: Proc., ASME/JSME 2011 8th Thermal Engineering Joint Conference, 2011, https://doi.org/10.1115/AJTEC2011-44375.

[16] Donghyun Shin, Byeongnam Jo, Hyun-eun Kwak, et al., Investigation of high temperature nanofluids for solar thermal power conversion and storage applications,in:Proc., 2010 14th International Heat Transfer Conference, 2010, pp. 583-591, https://doi.org/10.1115/IHTC14-23296.

[17] Qi Yang, Bikai Jin, Debjyoti Banerjee, et al., Direct visualization and molecular simulation of dewpoint pressure of a confined fluid in sub-10 nm slit pores, Fuel 235 (2019) 1216-1223. https://www.sciencedirect.com/science/article/pii/S0016236118314212.

[18] Jiwon Yu, Seok-Won Kang, Rag-Gyo Jeong, et al., Experimental validation of numerical predictions for forced convective heat transfer of nanofluids in a microchannel, Int. J. Heat Fluid Flow 62 (2016) 203-212. https://www. sciencedirect.com/science/article/pii/S0142727X16307378.

[19] Debjyoti Banerjee, Nanofluids and applications to energy systems, in:Martin A. Abraham (Ed.), Encyclopedia of sustainable technologies, Elsevier, Oxford, 2017, pp. 429-439.

[20] Binjian Ma, Debjoyti Banerjee, Numerical modeling of nanofluid thermal conductivity: the effect of nanonetwork on thermal transport behavior, J. Heat Transf. 141 (12) (2019), https://doi.org/10.1115/1.4044701.

[21] Binjian Ma, Donghyun Shin, Debjyoti Banerjee, One-step synthesis of molten salt nanofluid for thermal energy storage application e a comprehensive analysis on thermophysical property, corrosion behavior, and economic benefit, J. Energy Storage 35 (2021) 102278. https://www.sciencedirect.com/science/article/pii/S2352152X21000426.

[22] Jiwon Yu, Seok-Won Kang, Tae-Soon Kwon, et al., In situ characterization of enhanced thermal performance by periodic nanostructures on the surface of a microchannel, Int. J. Heat Mass Transf. 124 (2018) 414-422. https://www. sciencedirect.com/science/article/pii/S0017931017336323.

[23] Jihyung Lee, Aditya Kuchibhotla, Debjyoti Banerjee, et al., Silica nanoparticles as copper corrosion inhibitors, Mater. Res. Express 6 (8) (2019) 0850-3, https://doi.org/10.1088/2053-1591/ab2270.

[24] J.A. Rivero, S.W. Siddiqui, Use of nanotracers for imaging and/or monitoring fluid flow and improved oil recovery, 2014. Available at: https://patents. google.com/patent/CA2843625A1/en. (Accessed 25 September 2023).

[25] X.Z. Kong, et al., Tomographic reservoir imaging with DNA-labeled silica nanotracers: the first field validation, Environ. Sci. Technol. 52 (23) (2018) 13681-13689, https://doi.org/10.1021/acs.est.8b04367. Available at:.

[26] J.M. Felix Servin, H.A. Al-Sadeg, A. Abdel-Fattah, Photoacoustic nanotracers for subsurface applications: opportunities and challenges,in: SPE Annual Technical Conference and Exhibition, 2021, pp. 21-23, https://doi.org/10.2118/206316-MS. Available at:.

[27] Zisis Vryzas, Omar Mahmoud, Hisham A. Nasr-El-Din, et al., Development and testing of novel drilling fluids using Fe2O3 and SiO 2 nanoparticles for enhanced drilling operations,in:Proc., International Petroleum Technology Conference, 2015, https://doi.org/10.2523/IPTC-18381-MS.

[28] Omar Mahmoud, Hisham A. Nasr-El-Din, Zisis Vryzas, et al., Nanoparticlebased drilling fluids for minimizing formation damage in HP/HT applications,in:Proc., SPE International Conference and Exhibition on Formation Damage Control, 2016, https://doi.org/10.2118/178949-MS.

[29] Oscar Contreras, Geir Hareland, Maen Husein, et al., Experimental investigation on wellbore strengthening in shales by means of nanoparticle-based drilling fluids,in:Proc., SPE Annual Technical Conference and Exhibition, 2014, https://doi.org/10.2118/170589-MS.

[30] Oscar Contreras, Geir Hareland, Maen Husein, et al., Wellbore strengthening in sandstones by means of nanoparticle-based drilling fluids,in:Proc., SPE Deepwater Drilling and Completions Conference, 2014, https://doi.org/10.2118/170263-MS.

[31] A.E. Cedola, S. Akhtarmanesh, R. Qader, et al., Nanoparticles in weighted water based drilling fluids increase loss gradient,in:Proc., 50th US Rock Mechanics/Geomechanics Symposium, 2016.

[32] T.M. Bryant, D.S. Grosso, S.N. Wallace, Gas-influx detection with MWD technology, SPE Drill. Eng. 6 (4) (1991) 273-278, https://doi.org/10.2118/19973-PA.

[33] Gwen Wilcox, Jefferson W. Tester, The Future of Geothermal Energy, Idaho National Labs. (INL), 2006.

[34] C.A. Nieto de Castro, et al., Thermal properties of ionic liquids and IoNanofluids of imidazolium and pyrrolidinium liquids, J. Chem. Eng. Data 55 (2) (2010) 653-661, https://doi.org/10.1021/je900648p. Available at:.

[35] C.A. Nieto de Castro, et al., Enhanced thermal conductivity and specific heat capacity of carbon nanotubes ionanofluids, Int. J. Therm. Sci. 62 (2012) 34-39, https://doi.org/10.1016/j.ijthermalsci.2012.03.010. Available at:.

[36] E.B. Fox, et al., Thermophysical properties of nanoparticle-enhanced ionic liquids (NEILs) heat-transfer fluids, Energy Fuels 27 (6) (2013) 3385-3393, https://doi.org/10.1021/ef4002617. Available at:.

[37] S.J. Hoffman, A. Andrews, B.K. Joosten, et al., A water rich mars surface mission scenario,in:Proc., 2017 IEEE Aerospace Conference,4-11 March 2017, 2017, pp. 1-21.

[38] Stephen J. Hoffman, Alida D. Andrews, Kevin D. Watts, Simulated water well performance on Mars, in: 2018 AIAA SPACE and Astronautics Forum and Exposition, 2018.

[39] R.M. Haberle, Planetary atmospheres|Mars, in:James R. Holton (Ed.), Encyclopedia of Atmospheric Sciences, Academic Press, Oxford, 2003, pp. 1745-1755.

[40] NWS. The Planet Mars,National Oceanic and Atmospheric Administration, https://www.weather.gov/fsd/mars.

[41] Gerald Sanders,In situ resource utilization on Mars e update from DRA 5.0 study, in:48th AIAA Aerospace Sciences Meeting Including the New Horizons Forum and Aerospace Exposition, 2010.

[42] M. Ba Geri, A. Imqam, L. Shen, et al., Static proppant settling velocity characteristics in high viscosity friction reducers fluids for unconfined and confined fractures,in:Proc., 53rd US Rock Mechanics/Geomechanics Symposium, 2019.

[43] Sahil Malhotra, Mukul M. Sharma, A general correlation for proppant settling in VES fluids, in: Proc., SPE hydraulic fracturing technology conference, 2011, https://doi.org/10.2118/139581-MS.

[44] Shuang Zheng, Ripudaman Manchanda, Mukul M. Sharma, Modeling fracture closure with proppant settling and embedment during shut-in and production, SPE Drill. Complet. 35 (4) (2020) 668-683, https://doi.org/10.2118/201205-PA.

[45] Chinemerem E. Obi, Using 3D Printing to Improve Fracture Conductivity Experiments, Presented at the ARMA Sante Fe, New Mexico, USA, 2022.

[46] Leiming Li, Ghaithan A. Al-Muntasheri, Feng Liang, Nanomaterials-enhanced high-temperature fracturing fluids prepared with untreated seawater, in: Proc., SPE Annual Technical Conference and Exhibition, 2016, https://doi.org/10.2118/181283-MS.

[47] Gang Hui, Shengnan Chen, Fei Gu, Insights on trigger mechanisms of two large hydraulic fracturing-induced earthquakes and sensitivity analysis, in: Proc., SPE Canada Unconventional Resources Conference, 2020, https://doi.org/10.2118/199996-MS.

[48] Julie E. Shemeta,Colin Edward Brooks, Charles Clifford Lord, Well stimulation seismicity in Oklahoma: cataloging earthquakes related to hydraulic fracturing,in:Proc., SPE/AAPG/SEG Asia Pacific Unconventional Resources Technology Conference, 2019, https://doi.org/10.15530/AP-URTEC-2019-198283.

[49] Abhash Kumar, Hongru Hu, Alex Bear, et al., Seismic monitoring of hydraulic fracturing activity in the Wolfcamp Shale of Midland Basin, Texas, in: Proc., SPE/AAPG/SEG Unconventional Resources Technology Conference, 2019, https://doi.org/10.15530/urtec-2019-564.

[50] Chinemerem E. Obi, Investigation of Proppant Shear Behavior along Fracture/Fault Lines; a Gouge Analogy for Fracture Stability and Earthquake Potential, Presented at the ARMA Sante Fe, New Mexico, USA, 2022.

[51] John Yilin Wang, Stephen A. Holditch, Duane A. McVay, Modeling fracturefluid cleanup in tight-gas wells, SPE J. 15 (3) (2010) 783-793, https://doi.org/10.2118/119624-PA.

[52] Mark I. Dickins, Duane A. McVay,Stephen K. Schubarth, The impact of gravity segregation on multiphase non-darcy flow in hydraulically fractured gas wells, in: Proc., SPE Annual Technical Conference and Exhibition, 2008, https://doi.org/10.2118/116748-MS.

[53] Scott J. Wilson, Technology focus: gas production, J. Pet. Technol. 71 (11) (2019), https://doi.org/10.2118/1119-0070-JPT, pp. 70-70.

[54] Trent Jacobs, Innovators seek to transform flaring into money and power, J. Pet. Technol. 72 (3) (2020) 24-29, https://doi.org/10.2118/0320-0024-JPT.

[55] J. Vazquez, C. Donald Larry, Flared gas can reduce some risks in crypto mining as well as oil and gas operations, Risks 10 (6) (2022) 127. https://doi. org/10.3390/risks10060127.

[56] Yousef Kazemzadeh, Sanaz Shojaei, Masoud Riazi, et al., Review on application of nanoparticles for EOR purposes: a critical review of the opportunities and challenges, Chin. J. Chem. Eng. 27 (2) (2019) 237-246. https://www.sciencedirect.com/science/article/pii/S1004954118301745.

[57] Milton J. Rosen, Hongzhuang Wang, Pingping Shen, et al., Ultralow interfacial tension for enhanced oil recovery at very low surfactant concentrations, Langmuir 21 (9) (2005) 3749-3756, https://doi.org/10.1021/la0400959.

[58] Anirbid Sircar, Kamakshi Rayavarapu, Namrata Bist, et al., Applications of nanoparticles in enhanced oil recovery, Pet. Res. (2021). https://www. sciencedirect.com/science/article/pii/S2096249521000636.

[59] Nanjun Lai, Qingru Zhu, Dongyu Qiao, et al. Original research., CO2/N2-responsive nanoparticles for enhanced oil recovery during CO₂ flooding (in English), Front. Chem. 8 (2020), https://www.frontiersin.org/article/10.3389/fchem.2020.00393.

[60] Muhammad Shahzad Kamal, Ahmad A. Adewunmi, Abdullah S. Sultan, et al., Recent advances in nanoparticles enhanced oil recovery: rheology, interfacial tension, oil recovery, and wettability alteration, J. Nanomater. 2017 (2017) 2473175, https://doi.org/10.1155/2017/2473175.

[61] Marwan Y. Rezk, Nageh K. Allam, Impact of nanotechnology on enhanced oil recovery: a mini-review, Ind. Eng. Chem. Res. 58 (36) (2019) 16287-16295, https://doi.org/10.1021/acs.iecr.9b03693.

[62] Erika S. Ellis, Mohammad N. Askar, Muhammad Hotan, et al., Successful field test of real time inline sensing system for tracer detection at well head,in:Proc., SPE Kingdom of Saudi Arabia Annual Technical Symposium and Exhibition, 2017, https://doi.org/10.2118/188035-MS.

[63] Hsieh Chen, Sehoon Chang, Gawain Thomas, et al., Comparison of water and gas tracers field breakthrough,in:Proc., SPE Annual Technical Conference and Exhibition, 2021, https://doi.org/10.2118/205863-MS.

[64] Leah M. Johnson, Chasity A. Norton, Nicolas D. Huffman, et al., Nanocapsules for controlled release of waterflood agents for improved conformance,in:Proc., SPE Annual Technical Conference and Exhibition, 2016, https://doi.org/10.2118/181547-MS.

[65] Ahmed W. Alsmaeil, Apostolos Enotiadis, Mohammed A. Hammami, et al., Slow release of surfactant using silica nanosized capsules, SPE J. 25 (6) (2020) 3472-3480, https://doi.org/10.2118/202479-PA.

[66] K. Ng, H. Yu, H. Wang, et al., Geomechanical investigation of the carbon sequestration reservoir at Rock Springs Uplift, Wyoming, USA, in: Proc., 53rd US Rock Mechanics/Geomechanics Symposium, 2019.

[67] Lingyu Mu, Xinwei Liao, Jingtian Zhang, et al., Analytical solutions of leakage through the caprock in carbon sequestration in a closed boundary aquifer system,in:Proc., Carbon Management Technology Conference, 2019, https://doi.org/10.7122/CMTC-553897-MS.

[68] Ahmed Abdulhamid Mahmoud, Salaheldin Elkatatny, Mohamed Mahmoud, Improving class G cement carbonation resistance using nanoclay particles for geologic carbon sequestration applications, in: Proc., Abu Dhabi International Petroleum Exhibition & Conference, 2018, https://doi.org/10.2118/192901-MS.

[69] Wararit Toempromraj C.W. Graham Grant, Chakrit Chanpen, et al., Old field, new well: well design challenge for long-terms CO 2 storage in a depleted field,in:Proc., IADC/SPE Asia Pacific Drilling Technology Conference and Exhibition, 2022, https://doi.org/10.2118/209861-MS.

[70] Petrowiki, Horizontal Wells, 2023. Month Accessed: October.

[71] Piyush Pankaj, Haidan Lu,Katherine Escobar Patron, Artificial lift selection and its applications for deep horizontal wells in unconventional reservoirs, in: Proc., SPE/AAPG/SEG Unconventional Resources Technology Conference, 2018, https://doi.org/10.15530/URTEC-2018-2875180.

[72] R. Brito, E. Pereyra, C. Sarica, Effect of well trajectory on liquid removal in horizontal gas wells, in: Proc., SPE Annual Technical Conference and Exhibition, 2016, https://doi.org/10.2118/181423-MS.

[73] C.A. Shook, R.G. Gillies, B.J. Kristoff, et al., Sand transport mechanism in horizontal wells,in:Proc., Technical Meeting/Petroleum Conference of the South Saskatchewan Section, 1992, https://doi.org/10.2118/SS-92-15.

[74] Q. Dean, S.M. Farouq Ali, A. George, Flow of oil and sand in a horizontal well, in: Proc., Technical Meeting/Petroleum Conference of the South Saskatchewan Section, 1993, https://doi.org/10.2118/SS-93-34.

[75] Q. Doan, S.M. Farouq Ali, L. Doan, et al., Sand deposition inside a horizontal well e a simulation approach,in:Proc., Annual Technical Meeting, 1998, https://doi.org/10.2118/98-65.

[76] Nwoke Linus, James Arukhe, Uchendu Chike, Intelligent-thinking restored well productivity in horizontal completions plugged-off by sand-deposits: huge reward,in:Proc., SPE Production and Operations Symposium, 2003, https://doi.org/10.2118/80931-MS.

[77] Junko Hutahaean, Vasily Demyanov, Dan Arnold, et al., Optimization of well placement to minimize the risk of scale deposition in field development,in:Proc., Abu Dhabi International Petroleum Exhibition and Conference, 2014, https://doi.org/10.2118/171733-MS.

[78] Kai Wang, Haisheng Wang, Xiao Shu, et al., Super-large scale horizontal well position optimization method and infilling practice in high water-cut large complex fluvial reservoir based on multidisciplinary innovative techniques,in:Proc., SPE Annual Technical Conference and Exhibition, 2016, https://doi.org/10.2118/181889-MS.

[79] P. Chen, H. Montgomerie, T. Hagen, et al., Meeting the challenges in downhole scale control for high-water-production horizontal wells in an environmentally sensitive part of the Norwegian North Sea, SPE Prod. Oper. 27 (4) (2012) 382-389, https://doi.org/10.2118/135249-PA.

[80] P.D. Dholabhai, N. Kalogerakis, P.R. Bishnoi, Evaluation of gas hydrate formation and deposition in condensate pipelines: pilot plant studies, SPE Prod. Facil. 8 (3) (1993) 185-190, https://doi.org/10.2118/22829-PA.

[81] Ake Rittirong, Ekarit Panacharoensawad, Cem Sarica, An experimental study of paraffin deposition under two-phase gas-oil slug flow in horizontal pipes, in: Proc., Offshore Technology Conference, 2015, https://doi.org/10.4043/26047-MS.

[82] Kosta J. Leontaritis, Wax flow assurance issues in gas condensate multiphase flowlines, in: Proc., Offshore Technology Conference, 2007, https://doi.org/10.4043/18790-MS.

[83] Nura Makwashi, Kwame Sarkodie, Stephen Akubo, et al., Investigation of the severity of wax deposition in bend pipes under subcooled pipelines conditions,in:Proc., SPE Europec Featured at 81st EAGE Conference and Exhibition, 2019, https://doi.org/10.2118/195559-MS.

[84] Shaojun Wang, Faruk Civan, Productivity decline of vertical and horizontal wells by asphaltene deposition in petroleum reservoirs, in: Proc., SPE International Symposium on Oilfield Chemistry, 2001, https://doi.org/10.2118/64991-MS.

[85] J. Paddock, M.R. Islam, A new technique for cleaning horizontal wellbores, in: Proc., Technical Meeting/Petroleum Conference of the South Saskatchewan Section, 1999, https://doi.org/10.2118/99-98.

[86] Hugo Francisco Santos, Eduardo André Perondi, André Viegas Wentz, et al., Annelida, a robot for removing hydrate and paraffin plugs in offshore flexible lines: development and experimental trials, SPE Prod. Oper. 35 (3) (2020) 641-653, https://doi.org/10.2118/196015-PA.

[87] Glenn Gahr Lunde, Graham Rudrum, Pabs Angelo, et al., Ormen lange flow assurance system (FAS) e online flow assurance monitoring and advice,in:Proc., OTC Brasil, 2013, https://doi.org/10.4043/24297-MS.

[88] Matt Straw, Ravindra Aglave, Rodolfo Piccioli, Integrated approach to multiphase flow regime prediction through computational fluid dynamics CFD, in: Proc., Offshore Technology Conference, 2021, https://doi.org/10.4043/31096-MS.

[89] Madhusuden Agrawal, Ahmadreza Haghnegahdar, Rahul Bharadwaj, Improved prediction of sand erosion by accurate particle shape representation in CFD-DEM modelling, in: Proc., SPE annual technical conference and exhibition, 2021, https://doi.org/10.2118/206122-MS.

[90] Chinemerem Edmond Obi, Yusuf Falola, Kaushik Manikonda, et al., A machine learning analysis to relate flow pattern and pressure gradient during gas kicks under static conditions,in:Proc., SPE Western Regional Meeting, 2022, https://doi.org/10.2118/209333-MS.

[91] C.E. Obi, et al., A machine learning approach for gas kick identification, SPE Drill. Complet. (2023) 1-19, https://doi.org/10.2118/215831-PA. Available at:.

[92] M. Alhashem,Machine learning classification model for multiphase flow regimes in horizontal pipes, in:International Petroleum Technology Conference, 2020. Available at: http://onepetro.org/IPTCONF/proceedings-pdf/20IPTC/2-20IPTC/D023S042R001/1188779/iptc-20058-abstract.pdf/1.

[93] Kaushik Manikonda, Raka Islam, Chinemerem Edmond Obi, et al., Horizontal two-phase flow regime identification with machine learning classification models,in: Proc., IPTC 2022, Saudi Arabia, 2022.

[94] I. Isemin, K. Nkundu,Investigating the use of machine learning models for the prediction of pressure gradient and flow regimes in multiphase flow in horizontal pipes, in:Nigeria Annual International Conference and Exhibition, 2021. Available at: http://onepetro.org/SPENAIC/proceedings-pdf/21NAIC/2-21NAIC/D021S009R011/2459013/spe-208410-ms.pdf/1.

[95] A. Tyagi, A. Gupta, Machine learning based prediction of pressure drop, liquid-holdup and flow pattern in multiphase flows,in:SPE EuropEC e Europe Energy Conference, Society of Petroleum Engineers (SPE), 2023, https://doi.org/10.2118/214348-ms. Available at:.

[96] H. Qin, V. Srivastava,Machine learning models to predict gas hydrate plugging risks using flowloop and field data, in:Offshore Technology Conference, 2019. Available at: http://onepetro.org/OTCONF/proceedings-pdf/19OTC/1-19OTC/D011S010R003/1986392/otc-29411-ms.pdf/1.

[97] Z. Sun, et al., Current flow loop equipment and research in hydrateassociated flow assurance, J. Nat. Gas Sci. Eng. 96 (2021), https://doi.org/10.1016/j.jngse.2021.104276. Available at:.

[98] J. Chen, et al., An improved solution to flow assurance in natural gas pipeline enabled by a novel self-regulated bypass pig prototype: an experimental and numerical study, J. Nat. Gas Sci. Eng. 107 (2022), https://doi.org/10.1016/j.jngse.2022.104776. Available at:.

[99] S. Stokes, et al., Modelling of multiphase flow during transient operation of a carbon capture and storage system,in: Offshore Technology Conference, 2023, https://doi.org/10.4043/32446-MS. Available at:.

[100] K.A. Sangita, S. Srinivasan, An analytical model to experimentally emulate flow effects in multiphase CO2/H2S systems, in: NACE Corrosion, 2000. Available at: http://onepetro.org/NACECORR/proceedings-pdf/CORR00/All-CORR00/NACE-00058/1910616/nace-00058.pdf/1.