Estimation of Capillary Pressure and Relative Permeability from Downhole Advanced Wireline Measurements for Waterflooding Design
- Mona Al-Rushaid (Kuwait Oil Company) | Hamad Al-Rashidi (Kuwait Oil Company) | Munir Ahmad (Kuwait Oil Company) | Mehdi Azari (Halliburton) | Hamid Hadibeik (Halliburton) | Mahmoud Kalawina (Halliburton) | Gibran Hashmi (Halliburton) | Farrukh Hamza (Halliburton) | Sandeep Ramakrishna (Halliburton)
- Document ID
- Society of Petroleum Engineers
- SPE Improved Oil Recovery Conference, 14-18 April, Tulsa, Oklahoma, USA
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 5.2 Reservoir Fluid Dynamics, 5.6.2 Core Analysis, 5.4 Improved and Enhanced Recovery, 5.5 Reservoir Simulation, 2.2 Installation and Completion Operations, 5.2 Reservoir Fluid Dynamics, 5 Reservoir Desciption & Dynamics, 5.4.1 Waterflooding, 5.6.1 Open hole/cased hole log analysis, 5.6.3 Pressure Transient Testing, 5.5.2 Core Analysis, 1.6 Drilling Operations, 5.4 Improved and Enhanced Recovery, 5.6.4 Drillstem/Well Testing, 5.6.9 Production Forecasting, 5.6 Formation Evaluation & Management, 2 Well completion
- wireline log, downhole estimation, relative permeability, capillary pressure, water flooding
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Reservoir relative permeability and capillary pressure, as a function of saturation, is important for assessing reservoir hydrocarbon recovery, selecting the well completion method, and determining the production strategy because they are fundamental inputs to reservoir simulation for predicting lifetime production of a well. Estimation of relative permeability and capillary pressure curves at reservoir conditions is also an important task for successful planning of waterflooding and enhanced oil recovery. The relative permeability and capillary pressure data estimated from core analysis might cause concern regarding representativeness, and adjustments are typically necessary for successful production forecasting. This paper proposes a new method to obtain relative permeability and capillary pressure curves with downhole pressure-transient analysis (PTA) of mini-drillstem tests (miniDSTs) and well log-derived saturations.
The new approach was based on performing miniDSTs in the free water, oil, and oil-water transition zones. Analyses of the miniDST buildup tests provided absolute formation permeability, endpoints of relative permeability to both oil and water, and curvature of the relative permeability data. Additionally, resistivity, dielectric, and nuclear magnetic resonance (NMR) logs were used to determine irreducible water, residual oil, and transition zone saturations. Combining these downhole measurements provided the relative permeability and capillary pressure curves.
|File Size||1 MB||Number of Pages||16|
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