Study on Effects of Temperature and Pressure on Density of Oil Based Drilling Fluids and the Mathematical Model Thereof
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摘要: 油基钻井液的密度受温度和压力影响显著，掌握油基钻井液在不同温度和压力条件下密度的变化规律是钻井安全的重要保障。基于现场配方在室内配制了相同组分、不同密度的4种油基钻井液，使用Anton Paar公司的流体高温高压密度测试仪测定了4种油基钻井液的密度在温度范围60～220 ℃、压力范围20～120 MPa内的变化，探究了温度和压力对油基钻井液密度的影响规律，并建立了油基钻井液密度的温压二元数学模型。使用现场不同密度的油基钻井液对模型的准确性进行了验证，结果表明预测值与实测值之间具有较高的一致性，平均预测准确度达97.93%，能够满足现场使用的需要。另外对2种类似配方的油基钻井液进行了密度准确性验证，结果显示平均误差为9.24%，精度较高。Abstract: The density of oil based drilling fluids is significantly affected by temperature and pressure. Understanding the change of the density of oil based drilling fluids is of importance to the safety of the drilling operation. Oil based drilling fluids of 4 different densities with the same composition copied from the composition of a field drilling fluid were formulated in laboratory and were tested for the change of density with an HTHP density balance made by Anton Paar Company in temperature range of 60 – 220 ℃ and pressure range of 20 – 120 MPa. Using the teste results, the effects of temperature and pressure on the density of the oil based drilling fluids were investigated, and a temperature-pressure binary mathematical model about the density of oil based drilling fluid was established. The accuracy of the model was verified with field oil based drilling fluids of different densities, and it was found that the values predicted with the model and the values measured agreed closely with each other, the average prediction accuracy of the model is up to 97.93%, meaning that the model is able to satisfy the needs of field application. Verification of the model on another two oil based drilling fluids with similar composition showed an average error of 9.24%, indicating a high prediction accuracy.
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Key words:
- Oil based drilling fluid /
- Temperature /
- Pressure /
- Density /
- Prediction
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表 1 不同密度油基钻井液老化前后的基本性能
ρ /
g·cm−3老化
条件PV/
mPa·sYP/
Paφ6/φ3 Gel/
Pa/PaES/
V2.4 老化前 40.0 11.24 10/9 4/8.0 1561 220 ℃、16 h 59.0 6.64 5/3 3/7.0 1012 2.2 老化前 43.0 10.22 9/6 4/8.0 1443 220 ℃、16 h 58.5 5.11 4/3 3/7.0 992 1.8 老化前 39.0 10.22 6/5 3/4.0 1012 220 ℃、16 h 46.0 5.62 3/2 1/1.5 786 1.4 老化前 19.0 7.66 7/4 3/3.0 825 220 ℃、16 h 21.5 1.79 1.5/1 1/1.0 654 
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表 2 不同密度油基钻井液的密度数学模型参数及可决系数
ρ0/（g·cm−3） β0 β1 β2 β3 β4 R 2.4 1.078×10−3 −2.488×10−3 3.163×10−6 1.461×10−5 −3.255×10−8 0.99 2.2 8.374×10−4 −1.976×10−3 6.493×10−6 1.418×10−5 −5.198×10−8 0.99 1.8 1.309×10−3 −1.632×10−3 −1.053×10−6 7.169×10−6 1.093×10−8 0.97 1.4 6.870×10−4 −2.149×10−3 1.760×10−6 1.129×10−5 −2.383×10−8 0.99
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表 3 蓬深1井油基钻井液密度预测值与实测值的对比
T/℃ P/MPa ρ实测/（g·cm−3） ρ预测/（g·cm−3） 误差/% 89 20 1.372 1.308 4.64 89 45 1.388 1.329 4.23 89 65 1.393 1.346 3.36 120 20 1.369 1.291 5.66 120 45 1.382 1.314 4.93 120 65 1.391 1.332 4.25
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表 4 高石130井油基钻井液密度预测值与实测值的对比
T/℃ P/MPa ρ实测/（g·cm−3） ρ预测/（g·cm−3） 误差/% 75 20 1.792 1.777 0.83 75 70 1.875 1.839 1.94 75 92 1.888 1.866 1.18 141 20 1.777 1.796 −1.08 141 70 1.859 1.854 0.25 141 92 1.870 1.880 −0.52
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表 5 天府1井油基钻井液密度预测值与实测值的对比
T/℃ P/MPa ρ实测/（g·cm−3） ρ预测/（g·cm−3） 误差/% 119 20 2.222 2.140 3.68 119 70 2.269 2.221 2.12 119 100 2.290 2.269 0.91 150 20 2.183 2.113 3.19 150 70 2.265 2.204 2.69 150 100 2.297 2.258 1.68
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表 6 得胜1井油基钻井液密度预测值与实测值的对比
T/℃ P/MPa ρ实测/（g·cm−3） ρ预测/（g·cm−3） 误差/% 142 20 2.289 2.259 1.33 142 89 2.391 2.364 1.13 142 115 2.425 2.404 0.88 180 20 2.275 2.249 1.16 180 89 2.381 2.362 0.79 180 115 2.419 2.405 0.57
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表 7 不同温度压力下5#配方油基钻井液密度预测值与实际值的对比
P/
MPa140 ℃ 160 ℃ ρ实测/（g·cm−3） ρ预测/（g·cm−3） 误差/% ρ实测/（g·cm−3） ρ预测/（g·cm−3） 误差/% 10 1.5485 1.7324 11.87 1.5336 1.7178 12.01 30 1.5991 1.7555 9.78 1.5899 1.7407 9.48 50 1.6384 1.7789 8.57 1.6207 1.7639 8.84 70 1.6594 1.8026 8.63 1.6516 1.7875 8.23 90 1.7122 1.8267 6.69 1.7099 1.8113 5.93
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表 8 不同温度压力下6#配方油基钻井液密度预测值与实际值的对比
P/
MPa200 ℃ 220 ℃ ρ实测/（g·cm−3） ρ预测/（g·cm−3） 误差/% ρ实测/（g·cm−3） ρ预测/（g·cm−3） 误差/% 10 1.9135 2.1497 12.34 1.8943 2.1323 10.03 30 1.9723 2.1796 10.51 1.9648 2.1619 8.24 50 2.0332 2.2099 8.69 2.0251 2.1920 6.66 70 2.0961 2.2407 6.90 2.0860 2.2250 9.41 90 2.1765 2.2719 4.38 2.1596 2.2534 4.34
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