Parameter Optimization Study for Improving Success Rates in Formation Testing and Pressure Measurement

Formation pressure testing can obtain formation pressure and fluid mobility within minutes through milliliter (mL)-scale fluid withdrawal (drawdown) and pressure recovery. However, inaccurate operational parameters will compromise data quality. Key parameters including pumping rate, pumped volume, and pressure recovery waiting time significantly impact test results, particularly in low-permeability reservoirs where parameter optimization proves crucial. Conventional analytical methods fail to conduct multi-parameter sensitivity analysis. This study establishes a large-scale rock property model integrating petrophysical attributes, fluid characteristics, and relative permeability relationships through reservoir modeling. A well model with completion design was constructed and validated through reservoir numerical simulation using second-level timesteps. Sensitivity analysis schemes were designed to investigate pumping volume (V) and rate (Q). Results demonstrate: (1) Pumping rate shows no correlation with pressure stabilization time, while pumped volume directly affects recovery duration; (2) Multiple pressure drawdown/recovery cycles reveal that early recovery phases require no full stabilization, with no impact on final stabilization time. The reservoir modeling approach effectively simulates formation tester responses, providing critical guidance for pressure testing theory advancement and operational optimization. This methodology proves particularly valuable for improving success rates in low-permeability formation pressure prediction tests.