Improving carbonate reservoir characterization by applying rock typing methods: a case study from the Nam Con Son Basin, offshore Vietnam

Understanding the permeability-porosity relationships is key to improving reservoir prediction and exploitation especially in carbonate reservoirs, which are known for their complex textural diagenetic variation. Rock type classifications have long been proven be an effective technique establishing permeability- porosity relationships, enhance capability capture various flow behavior uncored zones. This study highlights some of those practical theoretically-correct methods, such as Hydraulic Flow Unit (HFU); Global hydraulic element (GHE), Winland’s R35 method, Pittman Lucia method. They proposed tested identification characterization rock types using a database 555 core plugs from Miocene Nam Con Son basin. It large isolated build-up structure were deposited within shallow marine platform interior dominated by coral, red algal foraminiferal packstones, wackestones grainstones. Hydrocarbons this found upper most part late formation. Conventional data first used define display cross plot permeability porosity. Different charts cutoff thresholds classified, defined number linear non-linear equations established. The predicted was calculated different methods compared with actual each type. predictions HFU method recognized give better matching measured coefficient more than 89%.