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G. Zhang et al.
conductivity, the lower annulus absorbs more heat from the formation, and the annulus temperature increases. The greater the heat transfer from the upper annulus to the
formation, the lower the annulus temperature.
4 Conclusions
(1) With the increase of cycle time, the lower annulus temperature of CML drilling
decreases gradually, while the upper annulus temperature increases gradually.
(2) The wellbore temperature of conventional drilling is about 3 °C higher on average
than that of CML drilling, and the temperature difference near the mud line can
reach about 8 °C.
(3) With the increase of drilling fluid density, specific heat and consistency coefficient,
the lower annulus temperature of CML drilling decreases gradually, while the upper
annulus temperature increases gradually. With the increase of thermal conductivity
of drilling fluid, the lower annulus temperature of CML drilling increases gradually,
while the upper annulus temperature decreases gradually.
References
1. Huai, Y., Pan, J., Lu, Q., et al.: Exploration status and methods of world offshore oil industry.
Petroleum Knowl. 5, 7–9 (2008)
2. Yang, J., Cao, S.: Current situation and development Trend of deepwater oil drilling
technology. Petroleum Drill. Prod. Technol. 30(2), 10–13 (2008)
3. Zhang, G., Qu, H., Zhang, F., et al.: Major new discoveries and implications of global
deepwater Oil and Gas. Acta Petroleum Sinica, 40(1), 1–34, 55 (2019)
4. Chen, G., Yin, Z., Xu, L., et al.: Advances in dual-gradient drilling technology in deep water.
Petroleum Exploration Dev. 034(002), 246–251 (2007)
5. Maurer, W.C., Medley, G.H., Mcdonald, W.J.: Multigradient drilling method and system.
United States Patent: 006530437 (2003)
6. Cayeux, E., Daireaux, B., Dvergsnes, E.W., et al.: Principles and sensitivity analysis of automatic calibration of mpd methods based on dual-gradient drilling solutions. In: Society of
Petroleum Engineers (2014)
7. Shelton, J., Smith, R.: Feasibility study of diluting a weighted drilling fluid with a low-density
liquid to create a riser fluid for a dual density drilling system. RPSEA 13(2), 26–29 (2004)
8. Yang, M., Meng, Y., Li, G., et al.: Transient wellbore - formation heat transfer model in the
whole drilling process. J. Petroleum Sci. 02, 170–175 (2013)
9. Song, X., Guan, Z.: Transient heat transfer characteristics of deep water drilling wellbore.
Acta Petroleum Sinica, 04, 158–162 (2011)
10. He, S., He, P., Yin, C., Xu, P.: Downhole circulating temperature model and its Sensitivity
Analysis. J. Southwest Petroleum Institute, 24(1), 57–60 (2002)
11. Li, M., Xu, L., Luo, H., et al.: Research on distribution and Control method of circulating
temperature of wellbore in deep water high-temperature Drilling. China Offshore Oil and
Gas, 30(04), 162–166 (2018)
12. Zhang, Z., Xiong, Y., Mao, L., et al.: Transient temperature prediction models of wellbore and
formation in well-kick condition during circulation stage. J. Petrol. Sci. Eng. 175, 266–279
(2019)
G. Zhang et al.
conductivity, the lower annulus absorbs more heat from the formation, and the annulus temperature increases. The greater the heat transfer from the upper annulus to the
formation, the lower the annulus temperature.
4 Conclusions
(1) With the increase of cycle time, the lower annulus temperature of CML drilling
decreases gradually, while the upper annulus temperature increases gradually.
(2) The wellbore temperature of conventional drilling is about 3 °C higher on average
than that of CML drilling, and the temperature difference near the mud line can
reach about 8 °C.
(3) With the increase of drilling fluid density, specific heat and consistency coefficient,
the lower annulus temperature of CML drilling decreases gradually, while the upper
annulus temperature increases gradually. With the increase of thermal conductivity
of drilling fluid, the lower annulus temperature of CML drilling increases gradually,
while the upper annulus temperature decreases gradually.
References
1. Huai, Y., Pan, J., Lu, Q., et al.: Exploration status and methods of world offshore oil industry.
Petroleum Knowl. 5, 7–9 (2008)
2. Yang, J., Cao, S.: Current situation and development Trend of deepwater oil drilling
technology. Petroleum Drill. Prod. Technol. 30(2), 10–13 (2008)
3. Zhang, G., Qu, H., Zhang, F., et al.: Major new discoveries and implications of global
deepwater Oil and Gas. Acta Petroleum Sinica, 40(1), 1–34, 55 (2019)
4. Chen, G., Yin, Z., Xu, L., et al.: Advances in dual-gradient drilling technology in deep water.
Petroleum Exploration Dev. 034(002), 246–251 (2007)
5. Maurer, W.C., Medley, G.H., Mcdonald, W.J.: Multigradient drilling method and system.
United States Patent: 006530437 (2003)
6. Cayeux, E., Daireaux, B., Dvergsnes, E.W., et al.: Principles and sensitivity analysis of automatic calibration of mpd methods based on dual-gradient drilling solutions. In: Society of
Petroleum Engineers (2014)
7. Shelton, J., Smith, R.: Feasibility study of diluting a weighted drilling fluid with a low-density
liquid to create a riser fluid for a dual density drilling system. RPSEA 13(2), 26–29 (2004)
8. Yang, M., Meng, Y., Li, G., et al.: Transient wellbore - formation heat transfer model in the
whole drilling process. J. Petroleum Sci. 02, 170–175 (2013)
9. Song, X., Guan, Z.: Transient heat transfer characteristics of deep water drilling wellbore.
Acta Petroleum Sinica, 04, 158–162 (2011)
10. He, S., He, P., Yin, C., Xu, P.: Downhole circulating temperature model and its Sensitivity
Analysis. J. Southwest Petroleum Institute, 24(1), 57–60 (2002)
11. Li, M., Xu, L., Luo, H., et al.: Research on distribution and Control method of circulating
temperature of wellbore in deep water high-temperature Drilling. China Offshore Oil and
Gas, 30(04), 162–166 (2018)
12. Zhang, Z., Xiong, Y., Mao, L., et al.: Transient temperature prediction models of wellbore and
formation in well-kick condition during circulation stage. J. Petrol. Sci. Eng. 175, 266–279
(2019)