Optimizing wettability in your waterflood project with ESal™ can increase oil recovery by up to 50% for less than $4 per barrel without new equipment or downtime.
Oil reservoirs have an optimum wettability that maximizes oil production, but this rarely occurs in the natural state. Reservoirs can be oil wet to the point that oil is not mobile even under waterflood. When the rock is water wet, pore throats shrink in effective diameter, as the capillary force of water clinging to the rock resists oil movement through the throat and snaps off the oil phase stranding mobile oil.
This optimum state is neutral wettability or the condition where oil and water move equally well through the porous medium.
The ESal process improves reservoir wettability and increases recovery by optimizing the injection water salinity to increase recovery without adding chemicals. This is achieved by blending the produced water with surface or other ground water in EOR projects without adding chemicals.
Employ separately or as part of your existing EOR strategy
Can be employed with chemical, thermal and CO2 flooding to further improve results!
You are already using water. Why not use the right water to get more oil?
Tertiary Benefit Forecast
The change in injected water chemistry may improve injectivity, eliminate souring, reduce corrosion and scale formation and may even dissolve scales – all improving your wells’ performance. No expensive searching for sweet spots or development of new methodology.
Increase oil production, and boost recoveries by up to 50%.
Typically costs less than $4 per incremental barrel.
No new equipment or change in normal operations.
Increased production in as little as 6 months after deployment.
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Learn how the ESal solution can increase oil recovery by up to 50% for less than $4 per barrel.
Frequently Asked Questions
Do we understand the mechanism for increasing recovery and how it works?
There is much debate even today about the mechanisms, but the emerging consensus is changing salinity alters the wettability of the reservoir system to increase recovery (see our reference page for more information). At ESal our question is do we have enough practical understanding to make it work in the field. The answer is yes, we do. This knowledge is incorporated into our screening tool and our design process to provide you with the best chance of success. Our step-wise process of screening, lab testing, design and field deployment allows the client to de-risk the process saving time and money.
Will it work in shale?
While there is limited field experience in this area, we know you can alter wettability in shale wells through our laboratory research and is currently being done with limited success with surfactants. In fact, many companies currently use surfactants in their fracking fluid which can be expensive ($250K/well). However, the basic conditions that allow us to alter wettability with salinity are present in shale. While it is early days, there is some published work that shows that wettability alteration by salinity modification works in shale (see our reference page for more information). Finally, the prospect of re-using produced water instead of disposing it is very attractive especially in basins where produced water volumes are high.
How do I find out if this will work in my field?
Traditionally, the answer is several years and millions of dollars of lab work and reservoir modeling. At ESal we have developed a screening tool to use your data on the rock, water and oil composition together with basic data on your field that gives you a numerical score within a few weeks (see our reference page for more information). This procedure provides a fast and reliable answer and identifies which factors are the most sensitive for your field. We can screen one or more fields quickly and provided you with the critical information at the speed of business.
How much extra oil can I expect to recover?
Our screening tool and lab tests provide our clients with good estimates of potential benefits. Depending on the type of reservoir (shale, carbonate, clastic) and the stage of deployment the benefit will vary. However, in general both field and lab testing has shown the benefits are from 5-15% OOIP (original oil in place) in both carbonate and sandstone reservoirs and 2-5% in shale (see our reference page for more information). Avoiding expensive projects that provide little or no return is why you want ESal in your corner.