Abstract:

This study applies an integrated multi-source data approach, including well logging data, formation pressure measurements (MDT), formation integrity/leak-off tests (FIT/LOT), and drilling incident records, to develop a high-confidence one-dimensional Mechanical Earth Model (1D MEM) for the KD field cluster, Block 46/13, Malay–Tho Chu Basin. Key geomechanical parameters, including pore pressure, in-situ stress regime, and rock mechanical properties, were quantified and rigorously calibrated using MDT, FIT/LOT, caliper logs, and actual drilling performance data. The results indicate that the KD area is characterized by a normal hydrostatic pressure regime and a normal faulting stress regime (Shmin ≈ Shmax < Sv). The calibrated geomechanical model established a safe mud weight window ranging from 8.6 to 9.6 ppg, helping to mitigate wellbore instability and lost circulation risks during drilling operations. Failure analysis and Critical Drawdown Pressure (CDDP) evaluation indicate that sand production risk is primarily concentrated within the Middle Miocene reservoirs (H) and Early Miocene (I) reservoir intervals), particularly under reservoir pressure depletion during production. In contrast, the deeper Early Miocene to Late Oligocene reservoirs (below I-115, including the J and K intervals) exhibit better mechanical stability and a lower likelihood of sand production. Based on these findings, a cased-hole perforated completion strategy, combined with appropriate production management, is recommended to minimize sand production risk and enhance long-term production performance.