KaydedilenlerDerginizi ekleyin

Dergiler / El-Cezeri / 2025 / Cilt: 12 Sayı: 3

Karbondioksit (CO2) Depolamak İçin Kullanılan Petrol ve Gaz Rezervuarlarındaki Kuyularda Isı Transferi ve Joule-Thomson Etkisinin Araştırılması

Investigation Of Heat Transfer and Joule-Thomson Effect in Wells of Depleted Oil and Gas Reservoirs Used For Carbon Dioxide (CO2) Storage

Okan Kon(BALIKESIR UNIVERSITY)0000-0002-5166-0258
İsmail Caner(BALIKESİR ÜNİVERSİTESİ, MÜHENDİSLİK-MİMARLIK FAKÜLTESİ, MAKİNE MÜHENDİSLİĞİ BÖLÜMÜ)0000-0003-1232-649X
Sayfa
298–310
Yayın Tarihi
2025-09-30
🏛️Bu makalenin bibliyografik verileri ve tam metin bağlantısı DergiPark üzerinden sağlanmıştır.
DergiPark Kaydı ↗
✨

Yapay Zeka Hızlı Bakış & Çıkarımlar

AI Insight
⚡ TL;DR(1 Cümlede Hızlı Çıkarım)

Kuyu başı girişi ve çıkışı arasındaki iletim ve taşınım ısı kaybındaki hesaplanan farkın 23.918 ila 481.980 W arasında değiştiği tespit edilmiştir.

📌 3 Maddede Bu Makale

🎯
Amaç & Hipotez:Bu çalışmada, tükenmiş petrol, gaz ve kömür rezervuarlarında karbondioksit (CO₂) depolanırken kuyu başındaki ısı transfer mekanizmaları ve Joule-Thomson etkisi araştırılmıştır.
📊
Temel Bulgular & Veri:Ayrıca, Joule-Thomson etkisinin neden olduğu kuyu başındaki soğutma etkisi incelenmiştir.
💡
Sonuç & Katkı:Kuyu başı girişi ve çıkışı arasındaki iletim ve taşınım ısı kaybındaki hesaplanan farkın 23.918 ila 481.980 W arasında değiştiği tespit edilmiştir.
🔬Tür:Araştırma Makalesi
📍Kapsam:Genişletilmiş Akademik Örneklem
⚙️Değişkenler:Karbondioksit depolama · rezervuar · ısı transferi

Özet

Bu çalışmada, tükenmiş petrol, gaz ve kömür rezervuarlarında karbondioksit (CO₂) depolanırken kuyu başındaki ısı transfer mekanizmaları ve Joule-Thomson etkisi araştırılmıştır. Depolama amacıyla enjekte edilen CO₂'nin tek fazlı ve saf halde olduğu varsayılmıştır. Rezervuar kuyusunda, kuyu deliği boyunca konvektif ısı transferi ve çevredeki kaya toprağıyla iletken ısı transferi, CO₂'nin yüzeye üretimi sırasında analiz edilmiştir. Ayrıca, Joule-Thomson etkisinin neden olduğu kuyu başındaki soğutma etkisi incelenmiştir. Joule-Thomson katsayısının pozitif bir değere sahip olması, bir soğutma etkisinin varlığını göstermiştir. Bu çalışmada, üretim kuyusu için 30, 51 ve 78 °C sıcaklıkları; 3,8, 4,3 ve 6,1 MPa basınçları ile 1000, 1700 ve 2600 metrelik kuyu derinlikleri dikkate alınmıştır. Rezervuar başındaki üretim kuyusunu çevreleyen altı farklı kaya-toprak tipi değerlendirilmiş olup, termal gradyan 25 °C/km ve CO₂ akış hızı 1 m/s olarak belirlenmiştir. Kuyu başı girişi ve çıkışı arasındaki iletim ve taşınım ısı kaybındaki hesaplanan farkın 23.918 ila 481.980 W arasında değiştiği tespit edilmiştir. Joule-Thomson katsayısının, kuyunun derinliğine ve sıcaklığına bağlı olarak 6,797 ila 17,91 °C/MPa arasında değiştiği belirlenmiştir. Ayrıca, Joule-Thomson etkisinden (kısma ekserjisi) kaynaklanan ekserji verimliliğindeki değişimin 3,042 ila 10,766 arasında olduğu hesaplanmıştır.

Abstract

This study investigated the heat transfer mechanisms and the Joule-Thomson effect at the wellhead while storing carbon dioxide (CO₂) in depleted oil, gas, and coal reservoirs. It was assumed that the injected CO₂ for storage is in a single-phase pure state. In the reservoir well, convection heat transfer along the wellbore and conduction heat transfer with the surrounding rock soil were analysed during the production of CO₂ to the surface. Additionally, the cooling effect at the wellhead caused by the Joule-Thomson effect was examined. A positive value of the Joule-Thomson coefficient indicated the presence of a cooling effect. For the production well, the study considered temperatures of 30, 51, and 78 °C, pressures of 3.8, 4.3, and 6.1 MPa, and well depths of 1000, 1700, and 2600 meters. Six different rock-soil types surrounding the production well at the reservoir head were included, with a thermal gradient of 25 °C/km and a CO₂ flow velocity of 1 m/s. The calculated difference in conduction and convection heat loss between the wellhead entry and exit ranged from 23.918 to 481.980 W. The Joule-Thomson coefficient was found to vary between 6.797 and 17.91 0C/MPa, depending on the depth and temperature of the well. The change in exergy efficiency due to the Joule-Thomson effect (throttling exergy) was calculated to vary between 3.042 and 10.766.

🔖

Bu Makaleye Atıf Yap

Kon, O., Caner, İ. (2025). Karbondioksit (CO2) Depolamak İçin Kullanılan Petrol ve Gaz Rezervuarlarındaki Kuyularda Isı Transferi ve Joule-Thomson Etkisinin Araştırılması. El-Cezeri, Cilt: 12 Sayı: 3, 298–310. https://doi.org/10.31202/ecjse.1642591

📄 Tam Metin PDF Okuyucu

📄

PDF görüntüleyici hazırlanıyor...

Kaynakça (62)

  1. Metz, B., Davidson, O., De Coninck, H. C., Loos, M., & Meyer, L. (2005). IPCC special report on carbon dioxide capture and storage. Cambridge: Cambridge University Press.
  2. Rifat US, Cağlar S, Elif K, Turkiye’nin Karbon Yakalama, Kullanma ve Depolama Potansiyeli, Kaynak, Cevre ve İklim Derneği – REC, Mart 2024, Ankara
  3. Olajire, A. A. (2020). Flow assurance issues in deep-water gas well testing and mitigation strategies with respect to gas hydrates deposition in flowlines—A review. Journal of molecular liquids, 318, 114203. https://doi.org/10.1016/j.molliq.2020.114203
  4. Li, Z., Dong, M., Li, S., & Huang, S. (2006). CO2 sequestration in depleted oil and gas reservoirs—caprock characterization and storage capacity. Energy conversion and management, 47(11-12), 1372-1382. https://doi.org/10.1016/j.enconman.2005.08.023
  5. Aminu, M. D., Nabavi, S. A., Rochelle, C. A., & Manovic, V. (2017). A review of developments in carbon dioxide storage. Applied Energy, 208, 1389-1419. https://doi.org/10.1016/j.apenergy.2017.09.015
  6. Liu, X., Falcone, G., & Alimonti, C. (2018). A systematic study of harnessing low-temperature geothermal energy from oil and gas reservoirs. Energy, 142, 346-355. https://doi.org/10.1016/j.energy.2017.10.058
  7. Luo, Y., Xu, G., & Yan, T. (2020). Performance evaluation and optimization design of deep ground source heat pump with non-uniform internal insulation based on analytical solutions. Energy and Buildings, 229, 110495. https://doi.org/10.1016/j.enbuild.2020.110495
  8. Wang, Z., Fan, W., Sun, H., Yao, J., Zhu, G., Zhang, L., & Yang, Y. (2020). Multiscale flow simulation of shale oil considering hydro-thermal process. Applied Thermal Engineering, 177, 115428. https://doi.org/10.1016/j.applthermaleng.2020.115428
  9. Guo, Y., Zhao, J., & Liu, W. V. (2024). Effects of varying heat transfer rates for borehole heat exchangers in layered subsurface with groundwater flow. Applied Thermal Engineering, 247, 123007. https://doi.org/10.1016/j.applthermaleng.2024.123007
  10. Bai, M., Zhang, Z., & Fu, X. (2016). A review on well integrity issues for CO2 geological storage and enhanced gas recovery. Renewable and Sustainable Energy Reviews, 59, 920-926. https://doi.org/10.1016/j.rser.2016.01.043
  11. Amar, M. N., Ghahfarokhi, A. J., & Zeraibi, N. (2020). Predicting thermal conductivity of carbon dioxide using group of data-driven models. Journal of the Taiwan Institute of Chemical Engineers, 113, 165-177. https://doi.org/10.1016/j.jtice.2020.08.001
  12. Liu, Z., Yang, W., Xu, K., Zhang, Q., Yan, L., Li, B.,. & Yang, M. (2023). Research progress of technologies and numerical simulations in exploiting geothermal energy from abandoned wells: a review. Geoenergy Science and Engineering, 224, 211624. https://doi.org/10.1016/j.geoen.2023.211624
  13. Jia, M., Deng, S., Li, X., Jin, W., Yang, Z., & Rao, D. (2023). A numerical simulation study of the micro-mechanism of CO2 flow friction in fracturing pipe string. Gas Science and Engineering, 112, 204941. https://doi.org/10.1016/j.jgsce.2023.204941
  14. Zhou, Y., Liu, Z., & Xing, C. (2022). Application of abandoned wells integrated with renewables. In Utilization of Thermal Potential of Abandoned Wells (pp. 255-273). Academic Press. https://doi.org/10.1016/B978-0-323-90616- 6.00013-0
  15. Kengerli, T. S., & Agayeva, N. A. (2024). Influence of connecting a new gas pipeline to the operating gas pipeline on the flow rate of production wells. https://doi.org/10.53404/Sci.Petro.20240100053
  16. Apak, E. C. (2006). A study on heat transfer inside the wellbore during drilling operations. Master's thesis, Middle East Technical University.
  17. Sorgun, M. (2010). Modeling of Newtonian fluids and cuttings transport analysis in high inclination wellbores with pipe rotation.
  18. Ettehadi, A. (2016). Modelling Wellbore Hydraulics through Thermal Rheological Sepiolite Mud Properties. PhD thesis, Graduate School of Science, Engineering and Technology, Istanbul Technical University.
  19. Ahmed, N., Kabir, E., & Islam, M. A. (2024, April). The influence of borehole lengths on a numerical model of a double-tube vertical ground heat exchanger. In IOP Conference Series: Materials Science and Engineering (Vol. 1305, No. 1, p. 012002). IOP Publishing. https://doi.org/10.1088/1757-899X/1305/1/012002
  20. Holloway, S. (2007). Carbon dioxide capture and geological storage. Philosophical Transactions of the Royal Society A: Mathematical, Physical and Engineering Sciences, 365(1853), 1095-1107. https://doi.org/10.1098/rsta.2006.1953
  21. Bachu, S. (2003). Screening and ranking of sedimentary basins for sequestration of CO2 in geological media in response to climate change. Environmental Geology, 44(3), 277-289. https://doi.org/10.1007/s00254-003-0762-9
  22. Bahadori, A., & Vuthaluru, H. B. (2010). Predictive tool for an accurate estimation of carbon dioxide transport properties. International Journal of Greenhouse Gas Control, 4(3), 532-536. https://doi.org/10.1016/j.ijggc.2009.12.007
  23. Vesovic, V., Wakeham, W. A., Olchowy, G. A., Sengers, J. V., Watson, J. T. R., & Millat, J. (1990). The transport properties of carbon dioxide. Journal of physical and chemical reference data, 19(3), 763-808. https://doi.org/10.1063/1.555875
  24. Lim, O.S. Optimization of Gas Transmission Design. 2011. Available online: http://utpedia.utp.edu.my/id/eprint/10565/1/20 11%20-%20Optimizing%20of%20gas%20transmission%20design.pdf (accessed on 22 Jan 2025).
  25. Sagir, M., Mushtaq, M., Tahir, M. S., Tahir, M. B., Ullah, S., Abbas, N., & Pervaiz, M. (2018). CO2 capture, storage, and enhanced oil recovery applications. Encyclopedia of Renewable and Sustainable Materials. Elsevier, 52-58. https://doi.org/10.1016/B978-0-12-803581-8.10360-1
  26. Wu, Z., Xu, J., Wang, X., Chen, K., Li, X., & Zhao, X. (2011). Predicting temperature and pressure in high-temperature– high-pressure gas wells. Petroleum Science and Technology, 29(2), 132-148. https://doi.org/10.1080/10916460903330213
  27. Kurnia, J. C., Shatri, M. S., Putra, Z. A., Zaini, J., Caesarendra, W., & Sasmito, A. P. (2022). Geothermal energy extraction using abandoned oil and gas wells: Techno‐economic and policy review. International Journal of Energy Research, 46(1), 28-60. https://doi.org/10.1002/er.6386
  28. Shoghl, S. N., Naderifar, A., Farhadi, F., & Pazuki, G. (2020). Prediction of Joule-Thomson coefficient and inversion curve for natural gas and its components using CFD modeling. Journal of Natural Gas Science and Engineering, 83, 103570. https://doi.org/10.1016/j.jngse.2020.103570
  29. Chevarunotai, N. (2014). Analytical Models for Flowing-Fluid Temperature Distribution in Single-Phase Oil Reservoirs Accounting for Joule-Thomson Effect. PhD thesis.
  30. Islam, R. (2017). Analytical Model for Fluid Temperature Change During Expansion in the Reservoir. PhD thesis.
  31. Ding, L., Yang, Z., Chen, W., & Zhang, Q. (2023). Transient prediction method for flow temperature at wellbore bottom. Applied Thermal Engineering, 234, 121208. https://doi.org/10.1016/j.applthermaleng.2023.121208
  32. Randolph, J. B., Adams, B., Kuehn, T. H., & Saar, M. O. (2012). Wellbore heat transfer in CO2-based geothermal systems. Geothermal Resources Council Transactions, 36, 549-554.
  33. Van Der Meer, B. (2005). Carbon dioxide storage in natural gas reservoir. Oil & gas science and technology, 60(3), 527-536. https://doi.org/10.2516/ogst:2005035
  34. Kon, O. (2004). Termodinamik kısılma ve madde ozelliklerine etkisi. Master's thesis, Balıkesir Universitesi Fen Bilimleri Enstitusu.
  35. Kon, O. (2009). Termodinamik kısılma olayında Joule-Thomson katsayısı ve inversiyon eğrileri. Balıkesir Universitesi Fen Bilimleri Enstitusu Dergisi, 11(2), 81-93.
  36. Randolph, J. B., & Saar, M. O. (2011). Combining geothermal energy capture with geologic carbon dioxide sequestration. Geophysical Research Letters, 38(10). https://doi.org/10.1029/2011GL047265
  37. Phillip L. Swagel, Carbon Capture and Storage in the United State, December 2023.
  38. Energy, Technology, & Policy, Carbon Dioxide Enhanced Oil Recovery: A Great Environmental Choice, https://webberenergyblog.wordpress.com/2012/04/01/carbon-dioxide-enhanced-oil-recovery-a-great-environmentalchoice/ (access: 12.27.2024)
  39. Huang, Y., Zheng, Q. P., Fan, N., & Aminian, K. (2014). Optimal scheduling for enhanced coal bed methane production through CO2 injection. Applied energy, 113, 1475-1483. http://dx.doi.org/10.1016/j.apenergy.2013.08.074
  40. Samuel, R. J. (2019). Transient flow modelling of carbon dioxide (CO2) injection into depleted gas fields. PhD thesis. University College London.
  41. Gaurina-Međimurec, N., & Pašić, B. (2011). Design and mechanical integrity of CO2 injection wells. Rudarsko- Geolosko-Naftni Zbornik, 23.
  42. CO2 injection well in Mississippi, https://www.usgs.gov/media/images/co2-injection-well-mississippi, April 9, 2010 (access: 12.26.2024)
  43. Witkowski, A., Majkut, M., & Rulik, S. (2014). Analysis of pipeline transportation systems for carbon dioxide sequestration. Archives of thermodynamics, 35(1), 117-140. http://dx.doi.org/10.2478/aoter-2014-0008
  44. Lu, T., Li, Z., Fan, W., & Li, S. (2016). CO2 huff and puff for heavy oil recovery after primary production. Greenhouse Gases: Science and Technology, 6(2), 288-301. https://doi.org/10.1002/ghg.1566
  45. Longe, P. O., Danso, D. K., Gyamfi, G., Tsau, J. S., Alhajeri, M. M., Rasoulzadeh, M.,. & Barati, R. G. (2024). Predicting CO2 and H2 Solubility in Pure Water and Various Aqueous Systems: Implication for CO2–EOR, Carbon Capture and Sequestration, Natural Hydrogen Production and Underground Hydrogen Storage. Energies, 17(22), 5723. https:// doi.org/10.3390/en17225723
  46. Chow, Y. F., Maitland, G. C., & Trusler, J. M. (2016). Interfacial tensions of the (CO2+ N2+ H2O) system at temperatures of (298 to 448) K and pressures up to 40 MPa. The Journal of Chemical Thermodynamics, 93, 392- 403.http://dx.doi.org/10.1016/j.jct.2015.08.006
  47. Wang, R., Shi, M., Zhu, K., Yu, J., Ren, W., Yan, G.,. & Gao, S. (2024). Research on the heat transfer model of double U-pipe ground heat exchanger based on in-situ testing. Frontiers in Energy Research, 12, 1442185. https://doi.org/10.3389/fenrg.2024.1442185
  48. Fuchs, S., Balling, N., & Forster, A. (2015). Calculation of thermal conductivity, thermal diffusivity and specific heat capacity of sedimentary rocks using petrophysical well logs. Geophysical Journal International, 203(3), 1977-2000. https://doi.org/10.1093/gji/ggv403
  49. Mobaraki, H. (2024). The Cooling Effect of Joule Thomson on CO2 Storage during Start-Up Period: Integration of Reservoir and Wellbore. PhD thesis, Politecnico di Torino.
  50. Shoghl, S. N., Naderifar, A., Farhadi, F., & Pazuki, G. (2021). Thermodynamic analysis and process optimization of a natural gas liquid recovery unit based on the Joule–Thomson process. Journal of Natural Gas Science and Engineering, 96, 104265. https://doi.org/10.1016/j.jngse.2021.104265
  51. Cengel, Y. A., & Ghajar A.F. (2015). Isı ve Kutle Transferi, Palme Yayınevi.
  52. Kayansayan N., Thermodynamics Principle & Applications, Nobel Akademik Yayıncılık, 2013.
  53. Span, R., & Wagner, W. (1996). A new equation of state for carbon dioxide covering the fluid region from the triplepoint temperature to 1100 K at pressures up to 800 MPa. Journal of physical and chemical reference data, 25(6), 1509- 1596. https://doi.org/10.1063/1.555991
  54. Menon, E.S. (2005). Gas Pipeline Hydraulics (1st ed.). CRC Press. https://doi.org/10.1201/9781420038224
  55. Luo, Y., & Wang, X. (2010). Exergy analysis on throttle reduction efficiency based on real gas equations. Energy, 35(1), 181-187. https://doi.org/10.1016/j.energy.2009.09.008
  56. Kotas, T. J. (2012). The Exergy Method of Thermal Plant Analysis, 1985. Great Britain by Anchor Brendon Ltd, Tiptree, Essex.
  57. Li, J., Chen, Y., Ma, Y. B., Kwon, J., & Xu, H. (2023). Ji-Chao Li A study on the Joule-Thomson effect of during filling hydrogen in high pressure tank, Case Studies in Thermal Engineering, 41, 102678. https://doi.org/10.1016/j.csite.2022.102678
  58. Erdoğan, M., & Acar, M. Ş. (2024). Thermodynamic analysis of a tunnel biscuit oven and heat recovery system. WAPRIME, 1(1), 1-15.
  59. Unal, E. K. (2024). Analytical and numerical investigation of viscous heating in parallel-plate Couette flow. WAPRIME, 1(1), 57-69.
  60. Liu, Z., Yang, W., Xu, K., Zhang, Q., Yan, L., Li, B.,. & Yang, M. (2023). Research progress of technologies and numerical simulations in exploiting geothermal energy from abandoned wells: a review. Geoenergy Science and Engineering, 224, 211624. https://doi.org/10.1016/j.geoen.2023.211624
  61. Longe, P. O., Danso, D. K., Gyamfi, G., Tsau, J. S., Alhajeri, M. M., Rasoulzadeh, M.,. & Barati, R. G. (2024). Predicting CO2 and H2 Solubility in Pure Water and Various Aqueous Systems: Implication for CO2–EOR, Carbon Capture and Sequestration, Natural Hydrogen Production and Underground Hydrogen Storage. Energies, 17(22), 5723. https:// doi.org/10.3390/en17225723
  62. Wang, R., Shi, M., Zhu, K., Yu, J., Ren, W., Yan, G.,. & Gao, S. (2024). Research on the heat transfer model of double U-pipe ground heat exchanger based on in-situ testing. Frontiers in Energy Research, 12, 1442185. https://doi.org/10.3389/fenrg.2024.1442185