This project is explaining a laboratory development of a solid free drilling fluid formula that could be potentially used in tight gas reservoirs. The configuration of the weak gel fluid WGL-1, which is resistant to high temperature and high salt, was tested, and concluded that its gelling properties, salt and temperature resistance, and environmental protection were all in line with industry requirements. The final drilling fluid formula was developed as: water + (0.3% - 0.5%) NaOH + 5% KCl + 2% WGL-1 + 5% NaCl + (1.0% - 2.0%) HBFR Anti-high temperature fluid loss agent + 2% Polyol + (1.5% - 2.0%) SDL-1 Lubricant + 0.4% A4O1. The performance of the liquid was tested for temperature resistance, inhibition, gas formation protection effect, plugging performance, and static settlement stability. It was concluded that the temperature resistance performance is satisfied at 150°C, and the cuttings recovery rate is as high as 96.78%. It has good performance in inhibiting water dispersion and swelling of cuttings. The permeability recovery value reaches 88.9%, which meets the requirements of gas formation protection. The SSSI value shows that its settlement stability is good; under high temperature and high pressure, its sealing performance is good. This drilling fluid system has achieved the expected results and laid a foundation for further promoting the development of solid-free drilling fluid systems. The future development direction of solid-free drilling fluids is pointed out, to the improvement of properties to be applied in high temperature environment and have high salt resistance capacity.
References
[1]
Sun, H.Y. and Liu, Y.Y. (2008) Drilling Fluid. Petroleum industry Press, Beijing, 1-150.
[2]
Yan, J.N. (2001) Drilling Fluid Technology. China University of Petroleum Press, Dongying, 1-75.
[3]
Wang, Z.H. (2001) Understanding of the Development of Drilling Fluid Additives and Drilling Fluid Systems in China. Drilling and Completion Fluids, 18, 32-35.
[4]
Wei, Y., Cheng, F. and Zheng, H. (2008) Synthesis and Flocculating Properties of Cationic Starch Derivatives. Carbohydrate Polymers, 74, 673-679. https://doi.org/10.1016/j.carbpol.2008.04.026
[5]
Pal, S., Mal, D. and Singh, R.P. (2005) Cationic Starch: An Effective Flocculating Agent. Carbohydrate Polymers, 59, 417-423. https://doi.org/10.1016/j.carbpol.2004.06.047
[6]
Fanta, G.F. and Shogren, R.L. (1997) Modification of Starchpoly(methyl acrylate) Graft Copolymers by Steam Jet Cooking. Journal of Applied Polymer Science, 65, 1021-1029. https://doi.org/10.1002/(SICI)1097-4628(19970801)65:5<1021::AID-APP20>3.0.CO;2-3
[7]
Qiao, Y., Li, S., Wei, P.Z., et al. (2014) Study on the Modification of High Temperature Salt-Tolerant Starch Filtration Reducer. Drilling Fluid & Completion Fluid, 31, 19-22.
[8]
Wang, D.L., Wang, J.M., Song, Z.J., et al. (2010) Preparation and Properties of a Novelinor Ganicsilicon Modified Sodium Carboxyl Methylstarch Filtrate Reducer. Petrochemical Technology, 39, 440-443.
[9]
Xiang, C.G. (2012) Research on Weak Gel Water-Based Drilling Fluid and Its Action Mechanism. Master’s Thesis of Southwest Petroleum University, Chengdu.
[10]
Jones, F.V. (1990) Alternate Environmental Testing of Drilling Fluids: An International Perspective. The European Petroleum Conference, The Hague, October 1990, SPE-20889-MS.
[11]
Yi, S.J. and Yu, Y.H. (2002) Petroleum and Environmental Microbial Technology. China University of Geosciences Press, Beijing.
[12]
Wan, L.P., Ji, X.X., Liu, Z.D., et al. (2020) Formulation of High Temperature Foaming Drilling Fluid and Performance Evaluation. Drilling Fluid & Completion Fluid, 37, 71-76.
[13]
Zhang, Q.G., Chen, F., Liu, Y., et al. (2007) Development Status of Foreign High-Performance Water-Based Drilling Fluids. Drilling Fluid & Completion Fluid, 24, 74-78.
[14]
Ding, T.W. and Yan, J.N. (2007) Laboratory Study on High Temperature and High Density Water-Based Drilling Fluid System. Journal of the University of Petroleum: Natural Science Edition, No. 2, 73-79.
[15]
Zhong, H.Y., Qiu, Z.S., Huang, W.A., et al. (2010) Experimental Evaluation of the Characteristics of Polyamine Water-Based Drilling Fluids. Oilfield Chemistry, 27, 119-123.
[16]
Zhong, H.Y., Huang, W.A., Lin, Y.X., et al. (2011) Performance Evaluation of a New Type of Polyamine Shale Inhibitor. Petroleum Drilling Technology, 39, 44-48.
[17]
Ye, C., Rong, K.S., Xiang, D.M., et al. (2017) Development and Performance Evaluation of Shale Amine Inhibitor PEDAS. Fault Block Oil and Gas Field, 24, 269-272, 288.
[18]
SY5336-88, Recommended Methods for Conventional Core Analysis.
[19]
SY/T5358-94, Recommended Experimental Method for Sensitivity Evaluation Experiment of Sandstone Reservoir.
[20]
Zeng, W. and Bouguetta, M. (2016) A Comparative Assessment of Barite SAG Evaluation Methods. SPE Deepwater Drilling and Completions Conference, Galveston, September 2016, SPE-180348-MS. https://doi.org/10.2118/180348-MS
[21]
Ye, Y., Yin, D., Liu, C.Q., et al. (2005) A Device and Method for Measuring Settlement Stability of High-Density Oil Test Working Fluid. CN102818881B.
[22]
Parvizinia, A., Ahmed, R.M. and Osisanya, S.O. (2011) Experimental Study on the Phenomenon of Barite Sag. International Petroleum Technology Conference, Bangkok, November 2011, IPTC-14944-MS. https://doi.org/10.2523/IPTC-14944-MS
