Abstract
In order to safely access deep petroleum resources, pore pressure studies are an essential part of well design engineering and economics considerations. Predicting pore pressure may become problematic in deeper reservoirs because to extra geological processes that encourage secondary overpressure mechanisms. Petrophysical, stress, and pressure plots (e.g., depth-based velocity-density, porosity-effective vertical stress), field data (formation and temperature), and observations (stress and pressure measurements) are analyzed in conjunction with the conducted analyses. The findings indicate that temperatures between 80 and 140 degrees Celsius are frequently associated with the largest discrepancies between projections and actual observations. Because of likely intricate geological processes including hydrocarbon production, diagenesis, metagenesis, chemical compaction, and alteration, this temperature range is frequently linked to less predictable fluid characteristics and pressure. Based on field data, the estimation errors are shown and evaluated for each temperature range. The assessment of temperature-related uncertainty in pore pressure prediction as well as the discrepancies between estimated and measured pore pressure at various temperatures are highlighted in the research. For a complete and enhanced understanding of the effects of temperature and pore pressure forecast reliability, it is crucial to understand the origins of overpressure and related geological processes. To provide more insights for prompt decision making, the research proposes an enhanced technique and workflow in pore pressure prediction combined with petrophysical analysis for a range of temperatures. In addition, it hopes to stimulate industry and society to think about replication and maybe enhance the process for identifying ambiguity and boosting comprehension of pore pressure prediction at high temperatures.