# Intelligent Stuck Pipe Type Recognition Using Digital Twins and Knowledge Graph Model
## 3 Results and Discussion  
### Results  
The trajectory data of well N in Moxi, Sichuan are shown in Table 7. The current bottom hole assembly (BHA) for the open hole are shown in Table 8 and the drilling fluid performance and drilling parameters are shown in Table 9.  
Drill log: the quiet lifting and lowering were normal after proactive reaming to well depth of 5040.03 m, the original hanging load was 1000 KN, the normal lifting friction was 300 KN, the normal lowering friction was 150 KN, and the reaming torque was 7-9 KN.m at 00:00-04:55, which at the time of pumping and lowering to the well depth of 5013.49 m at 04:55, the hanging load decreased from 850 KN to 800 KN, with blocking when lifting to the hanging load: 1350 KN as well as the top drive was rotated and the torque increased to 10 KN.m with standpipe pressure: 14.9-16.2 MPa and displacement: 752-780 L/min when lowering to the hanging load: 1000 KN. At 04:55-06:40, the drilling tool was moved at the hanging load: 1000-2100 KN, with intermittent torque: 15-18 KN.m, standpipe pressure: 15.9-16.3 MPa and displacement: 780-803 L/min and no free stick. At 06:40-08:00, the drilling tool was moved at the hanging load: 1000-1600 KN, with no free stick, but standpipe pressure: 16.4-16.9 MPa and displacement: 790-829 L/min. It is judged as key seat stuck-type. Figure 8: Recognition flow of stuck drill type using knowledge graph and digital twins. \begin{table}
\begin{tabular}{c c c} \hline \hline
**Depth (m)** & **Inclination (\({}^{\circ}\))** & **Azimuth (\({}^{\circ}\))** \\ \hline
140 & 0 & 137 \\ \hline
800 & 1 & 119.3 \\ \hline
1700 & 1 & 81 \\ \hline
3200 & 0.57 & 175.9 \\ \hline
4116 & 2 & 141 \\ \hline
4269 & 4.17 & 48 \\ \hline
4375 & 22 & 37 \\ \hline
4541.97 & 46.28 & 32.33 \\ \hline
4900 & 81.24 & 45.19 \\ \hline
5070 & 89.8 & 48 \\ \hline
5360 & 91 & 46.98 \\ \hline
5800 & 91.92 & 48.36 \\ \hline
5960 & 92.63 & 46.94 \\ \hline \hline \end{tabular}
\end{table} 
Table 7: Well trajectory data for well N. \begin{table}
\begin{tabular}{c c c c c} \hline \hline
**Tool** & **OD (mm)** & **ID (mm)** & **Length (m)** & **Cumulative** & **Linear Weight (N/m)** \\ \hline bit & 149.2 & 31.75 & 0.21 & 0.21 & 419.14 \\ \hline drill pipe & 88.9 & 70.2 & 1456.39 & 1456.60 & 197.97 \\ \hline heavy weight & 88.9 & 52.4 & 54 & 1510.60 & 363.54 \\ \hline drill pipe & 88.9 & 70.2 & 1526.4 & 3037 & 197.97 \\ \hline drill pipe & 101.6 & 84.84 & 2924 & 5961 & 208.39 \\ \hline \hline \end{tabular}
\end{table} 
Table 8: Current bottom hole assembly (BHA) for well N open hole. \begin{table}
\begin{tabular}{c c c c c} \hline \hline
**Mud Weight (g/cm\({}^{3}\))** & \(\varphi\)3 & \(\varphi\)100 & \(\varphi\)300 & \(\varphi\)600 & **Flow Rate (L/s)** \\ \hline
1.8 & 6 & 7 & 60 & 75 & 20 \\ \hline \hline \end{tabular}
\end{table} 
Table 9: Drilling fluid performance and drilling parameters for well N.  
Figure 10: The deviation of the measured POOH hookload value after stuck for well N.  
Figure 9: Stuck well logging data for well N.  
Combining Tables 7-9 and recorded data, the hookload data at the pulling out and drill-down before the stuck pipe and after the stuck pipe were extracted. According to the calculation method of the degree of stuck pipe and Figures 11-14, the degree of stuck pipe was calculated as 92.4%, the result is shown in Table 10 indicating that the drill stem was stuck during the pulling out, while the RIH hookload and torque behaved normally without abnormal changes after the stuck pipe. According to the drilling log, the stuck pipe time was identified as 4:55 to 5:05. The trend analysis of the stuck pipe data was performed by the SAX method, which showed that after the stuck pipe, the hookload and the torque at the pulling out gradually increased after the stuck pipe, the RIH hookload and the RIH torque were all normal, and the pump pressure was normal under the circulation conditions.