## 4 Results  
### Pore Pressure Prediction from Resistivity and Sonic Logs  
The Eaton [51] resistivity and sonic methods were employed to predict pore pressure gradient and pore pressure. The Mathews and Kelly and Eaton (resistivity and sonic) models were used to calculate fracture pressure and gradient. Similar techniques were applied to all three wells, and therefore, in this section, we present the detailed results for the E-BK1 and E-CB1 wells, and a summary of the results for the E-AJ1 well. The reservoir zone in E-BK1 (Figure 3) shows a compacted sandstone formation between 2942 m and 2983 m. Normal pressure formation was encountered from 2942 m to 2983 m, as indicated by NCT_Res and NCT_Sonic in tracks 4 and 5. With ResShale and SonShale values of 50.37 ohm/m and 67 us/f, respectively, the sonic shale deviates to the left of the Normal Compaction Trend (NCT) line, while the shale resistivity deviates to the right. The reservoir zone did not contain any overpressured zones. The overpressures were identified at the top and bottom of the reservoir intervals of the shale formation. InE-AJ1, normal and overpressured formations were observed within the studied interval. The reservoir zone shows an under-compacted sandstone formation and a sequence of intercalated shale intervals within the depths. Normal pressure formations were encountered at depths from 2690 m to 2714 m, and from 2678 m to 2685. The fracture pressures in E-BK1 (Figure 4) and E-AJ1 were estimated at 280.25 psi (FP_Res) and 17.949 psi (FP_Sonic), and 2110.24 psi (FP_Res) and 22,709.32 psi (FP_Sonic), respectively. Fracture pressure is necessary to fracture the formation at depth to induce mud loss into the fractured zone of the well. The estimated effective stress (ES) within the selected interval depth is \(-\)7.98 gm/cc for E-BK1 and \(-\)8.02 gm/cc for E-AJ1. These values imply that the ES's negative effects may result in an overpressure zone when drilling deeper than the selected intervals. The E-BK1 overburden gradient (OBG) and overburden pressure (OBP) were recorded as 15.35 Ibs/gal (1.84 gm/cc) and 4487.04 psi, respectively. Based on these readings, a low overburden pressure shows that E-BK1 penetrates a low-overburden water column. In E-AJ1, the overburden gradient (OBG) and overburden pressures were recorded at 17.3 Ibs/gal (1.88 gm/cc) and 7991.54 psi, respectively, suggesting that E-AJ1 penetrated under a column with excessive water overburden and thus an increased overburden pressure. Pore pressure gradient (PPG) values during well drilling determine how much mud weight is needed to mitigate the loss of circulation or kick. Pore pressure gradients (PPG) of 8.4 Ibs/gal (1.01 gm/cc) for PPG_Res and 8.3 Ibs/gal (0.99 gm/cc) for PPG_Sonic were determined for E-BK1, whereas E-AJ1 recorded 9.59 Ibs/gal (1.15 gm/cc) for PPG_Res and 8.28 Ibs/gal (0.99 gm/cc) for PPG_Sonic within the overpressured zone. Figure 3: Resistivity model, sonic model, pore pressure gradient, and fracture pressure gradient for E-BK1, estimated from the Eaton methods with a depth-dependent NCT. (Blue line= Pore pressure gradient from resistivity, Green=Pore pressure gradient from sonic, black= Overburden gradient, red dotted line=mid weight gradient, purple=pore pressure from sonic, yellow=pore pressure from resistivity). The sonic and resistivity fracture gradients (FG) were estimated to be 11.55 gm/cc and 7.40 gm/cc, respectively, in E-BK1 (Figure 5). FG serves as the maximum weight of mud needed to drill the formation. A mud weight (MW) of 2 gm/cc was determined to be the required weight to drill through the reservoir interval between 2942 m and 2983 m in E-BK1. The fracture gradients in E-AJ1 were estimated to be 15.52 lbs/gal (1.86 gm/cc) for FG_Res and 15.23 lbs/gal (1.86 gm/cc) for FG_Sonic. The mud weight (MW) calculated for this well was 2.02 lbs/gal (0.26 gm/cc). These values allow determination of the pressures needed to break the formation and cause mud loss. Figure 4: Pore and fracture pressure versus depth results for E-BK1.