‘Log-Soak-Log’ Experiment in Tengiz Field: Novel Technology for In-Situ Imbibition Measurements To Support an Improved Oil Recovery Project
- Yegor Se (Chevron Energy Technology Company) | Mauricio Villegas (Chevron) | Elrad Iskakov (Chevron) | Ted Playton (Tengizchevroil) | Karl Lindsell | Ernesto Cordova | Aizhan Turmanbekova (Tengizchevroil) | Haijing Wang (Chevron Energy Technology Company)
- Document ID
- Society of Petrophysicists and Well-Log Analysts
- Publication Date
- October 2019
- Document Type
- Journal Paper
- 605 - 619
- 2019. Society of Petrophysicists & Well Log Analysts
- 6 in the last 30 days
- 91 since 2007
- Show more detail
Secondary oil recovery projects in naturally fractured carbonate reservoirs (NFR) often introduce uncertainties and challenges that are not common to conventional waterfloods. The recovery mechanism in NFRs relies on ability of the fracture network to deliver enough injected fluid to the matrix, as well as rate and magnitude of capillary interactions within the matrix rock, during which hydrocarbon displacement occurs. The imbibition measurements can be performed in the laboratory using core samples, but due to reservoir heterogeneity, certain limitations of the lab equipment and the quality of the core material, scalability of the core results to a reservoir model can be challenging.
This paper describes the design, execution and evaluation of the’ log-soak-log’ (LSL) pilot test conducted in a giant naturally fractured carbonate reservoir with a low-permeability matrix in Western Kazakhstan, where repeatable and reliable measurements of changes in water saturation were achieved across large intervals (tens of meters) using a time-lapse pulsed-neutron logging technique. Periodic measurements provided valuable observations of dynamic change in saturation and fluid level over time and allowed estimation of the rate and magnitude of imbibition in the slope margins, depositional settings and rock types of interest. Incorporation of the LSL results into reservoir models validated the ranges of water-oil relative permeability curves, residual oil saturation to water, irreducible water saturation, and capillary pressure assumptions. This validation constrained key subsurface uncertainty and updated the oil recovery forecast in several improved oil recovery (IOR) waterflood projects.
|File Size||22 MB||Number of Pages||15|