EOR Performance and Modeling

Efforts for increasing recovery factors in all reservoir types continued with increasing momentum during the past year. Maturing fields combined with limited exploration forced operators to focus on recovering more from existing fields. Implementing enhanced oil recovery (EOR) in a depressed-oil-price environment is accepted as a challenge by our resilient industry, and, therefore, all aspects of EOR, including EOR agents, EOR physics, and EOR modeling and monitoring, improved further.

We saw progress in all EOR schemes in the past year, from expanding-solvent steam-assisted gravity drainage (SAGD) to increasing recovery factors in unconventional fields in the US. While carbon-dioxide EOR continues to be used in conventional reservoirs, it is also becoming a desired EOR agent for unconventionals. EOR implementations in high-viscosity-oil reservoirs continued to see improvements with more chemistry, with heat, with improved reservoir characterization, and with advancements in SAGD implementation.

Progress in chemical EOR, from polymer to alkaline/surfactant/polymer, has been significant. Not only are there new chemicals with improved recovery capabilities, but also the cost of the chemicals is being reduced continuously. All those factors led to more operators using chemical EOR. It is worth reiterating that increasing recovery factors in unconventionals will remain the top priority for many years to come. The next chapter of the exciting unconventionals journey will be more about EOR. 

EOR momentum on all fronts is reflected in the technical papers reviewed this year. This is the first time I have seen that all EOR schemes were covered. Half the technical papers were about fundamentals, and the other half were about field implementation. I found that to be the best indicator that EOR is becoming an integral part of managing oil fields. The selected papers provide a summary of some of the noteworthy advancements in EOR performance and modeling.

This Month's Technical Papers

A New Three-Phase Microemulsion Relative Permeability Model

A Review of Improved-Oil-Recovery Methods in North American Unconventional Reservoirs

Estimation of Flow and Hysteresis Parameters Applicable to WAG Experiments

Recommended Additional Reading

SPE 187032 Nanoscale-Flow-Chip Platform for Laboratory Evaluation of Enhanced-Oil-Recovery Materials by Michael Engel, IBM Research, et al.

SPE 185526 Surveillance and Initial Results of an Existing Polymer Flood: A Case History From the Rayoso Formation by L.A. Martino, YPF, et al.

SPE 183165 Borehole Controlled-Source Electromagnetics for Hydrocarbon-Saturation Monitoring in the Bockstedt Oil Field, Onshore Northwest Germany by K. Tietze, GFZ Potsdam, et al.

SPE 182669 Uncertainty Quantification for Foam Flooding in Fractured Carbonate Reservoirs by A. Almaqbali, Heriot-Watt University, et al.

SPE 185002 ES-SAGD Relative Permeability as a Function of Temperature and Solvent Concentrations by M. Zeidani, University of Calgary, et al.

Omer Gurpinar, SPE, is the technical director of enhanced oil recovery for Schlumberger. He leads Schlumberger in development of technologies and services to help improve recovery factors in oil fields. Gurpinar has more than 35 years of industry experience in various aspects of numerical reservoir modeling, with specific focus on naturally fractured reservoirs, reservoir optimization, and EOR. He has contributed to recovery optimization for numerous oil and gas fields globally. Since joining Schlumberger in 1998, Gurpinar has served as the vice president or technical director in various segments. He holds BS and MS degrees in petroleum engineering. Gurpinar is a member of the JPT Editorial Committee and can be reached at ogurpinar@slb.com.

EOR Performance and Modeling

Omer Gurpinar, SPE, Technical Director of Enhanced Oil Recovery, Schlumberger

01 January 2018

Volume: 70 | Issue: 1


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