The goal of this project is to develop cost-effective chemical formulations that will recover incremental oil beyond a waterflood operation from carbonate reservoirs. The target for this improved technology is large: domestic carbonate reservoirs under mature waterflood operations, and most especially those with a significant fracture system.
California Institute of Technology, Pasadena, CA
This 3-year project began in October 2004 as an effort to identify cost-effective surfactant formulations for EOR in fractured carbonate reservoirs. The motivation for this study is that, with the high oil price environment and tight supplies, there is a strong incentive to deploy new EOR methods such as chemical treatments in carbonate reservoirs, provided research can demonstrate the feasibility of such processes. Fractured carbonate reservoirs generally have poor oil recovery due to poor sweep of the water into the oil-rich matrix blocks. Adding the right surfactants to the injection water will change the wettability of the carbonate reservoir surfaces and alter the interfacial tension so as to increase the aqueous phase penetration into the rock matrix with trapped oil. The oil then released enters the fracture system and is recovered.
The project has developed rapid screening methods to evaluate surfactant formulations for their potential as enhanced oil recovery (EOR) agents for carbonate reservoirs. Expected results are an improved understanding of chemical mechanisms associated with this process and the development of more cost-effective formulations to apply this process in the field.
Researchers performed additional tests, including oil displacement/imbibition tests associated with the study of fundamental mechanisms for oil-wetting on a carbonate surface and then reversing that with a surfactant solution.
The first theoretical studies indicate that the more hydrophobic naphthenic acids (NA) have a greater effect on inducing oil-wet conditions. This work also suggests the wetting effect is independent of the binding energy of a NA on a carbonate surface.
Tests are in progress for designing this process for a typical West Texas fractured carbonate reservoir. Laboratory results demonstrate that some surfactants can recover by imbibition (simple soaking treatments) more than 50 percent of this crude oil initially saturating a 20 milidarcy limestone cores. These same successful surfactants are shown to be compatible with a synthetic field brine (approximately 3 wt percent salinity) at reservoir temperature.
This project benefits the industry by identifying a spectrum of surfactant products that may be useful for EOR in fractured carbonate reservoirs. Developing effective, low-cost chemical formulations will allow the commercial application of this technology.
The State and the public benefit of this research is that it provides further impetus for the industry to practice chemical EOR and thereby increase domestic oil supply. This should have a moderating effect on oil prices, plus help improve the U.S. balance of payments.
Significant accomplishments for this project so far are that the researchers have:
Remaining major tasks/future work with the identified better chemical formulations are additional oil recovery tests for the subject crude oil.
The first accomplishment, under Task 1, relates to the challenge of rapidly selecting those surfactants that have the best potential for an EOR process from fractured carbonate reservoirs. There are thousands of surfactants one could evaluate. The screening methods done for Task 1 identifies chemicals best suited to make carbonate surfaces water-wet. This approach allows one to quickly go from hundreds of formulation ideas to a few surfactant types worthy of more detailed study.
The item under Task 2 entails selecting simple “model” chemical systems that probe the chemical mechanisms responsible for good oil recovery performance. Insights from Task 2 narrow further which surfactants received more detailed study. The latter items encompass Tasks 3, 4, and 5, where detailed studies examine the performance of only those surfactants that look promising based on the simple screening tests. These later tasks also involve phase-behavior/IFT measurements to select only the chemicals with good fluid properties when exposed to the reservoir brine and oil. These results, coupled with the previous wetting data, have provided a selected suite of surfactants tested for their ability to recover model and crude oil via imbibition from limestone cores. The final test work with those best surfactants would seek to verify their high efficiency as waterflood additives to improve oil displacement from the matrix portion of carbonate reservoirs.
The project has just completed the first quarter of Year 3. The total project is scheduled to be completed in 3 years. The project is on schedule, with the most recent activity to test the performance of surfactants to improve oil recovery of a crude oil. Planned work will focus on additional oil recovery experiments and some further theoretical study of surface wetting and oil recovery mechanisms.
This project was selected in response to DOE’s Oil Exploration and Production solicitation DE- PS26-04NT15450-3A, November 2003. Due to reductions to the DOE Oil Program budget, this project was not fully funded and the scope of work was revised. This project ended on June 30, 2007 and a Final Report has been submitted.
$191,773 (20 percent of total)
Wu, Yongfu, and Shuler, P., Screening Methods for Selection of Surfactant Formulations for IOR from Fractured Carbonate Reservoirs, DOE Topical Report, DE-FC26-04NT15521, 2005.
Wu, Yongfu, Shuler, Patrick, Blanco, Mario, Tang, Yongchun, Goddard, William A. III, A Study of Wetting Behavior and Surfactant EOR in Carbonates with Model Compounds, SPE 99612 , SPE/IOR, Tulsa, OK, April 2006.
A first-quarter and first semi-annual reports to DOE have been completed. A third-quarter report was to be submitted, as well as a topical report to DOE, in July 2005. Reports are available from NETL by calling 918-699-2000.