Efficiently Produce More Oil at Lower Cost
SuperEORTM has a much lower cost of development and operation, less than half the breakeven cost of drilling and completing a new shale oil well, based on data presented by the Dallas Fed, March, 2021
source: Dallas Fed, March, 2021
Recover More Oil and Increase Reserves
SuperEORTM can increase oil production and reserves from shale oil wells, while lowering the cost of development. In the Midland Wolfcamp, implementation of SuperEORTM in a well can produce 4X more oil, at about 10% the cost.
Reduce GHG Emissions
SuperEORTM application in your wells can reduce your greenhouse gas emissions by 40-70%, eliminating the need for artificial lift and recovering far more oil from each well per day of production.
Emissions reductions will vary, depending on shale basin and project configuration.
Reduce Water Handling
SuperEOR application in your wells can reduce water handling - consumption for well completion and production and disposal - by about 80% on a per barrel of oil produced basis
We have invented, developed and patented novel, innovative methods for shale oil EOR.
Our shale oil EOR processes, SuperEORTM and UltraEORTM provide:
high oil recovery - as much as five times primary oil recovery.
less than half the cost of primary, e.g., less than $14/bbl.
efficient at lower maximum BHP, isolating the process to each well
uses a liquid solvent solution, injected with a pump
short injection periods, less production downtime
mitigates the need for artificial lift
applicable to undersaturated, saturated oil and gas condensate shale reservoirs
significantly reduces the environmental impact of shale oil production
Solving The Problem of Interwell Pressure Communication
As shale oil development has progressed using horizontal wellbores completed at increasingly closer lateral spacing, multistage fracture stimulation treatments often propagate fractures that extend to offset wells and cause these wells to be in hydraulic or pressure communication. And, in some areas, natural fractures may extend between these wellbores, that are in hydraulic or pressure communication.
As a result, implementation of cyclic natural gas or CO2 EOR processes in these wells may result in poor incremental oil recovery, as pressure buildup during injection cannot be achieved sufficient to drive the injectant gas into the matrix oil, and injected gas may move away from the well to offset wells and/or be unrecoverable.
This problem has been observed in several of the Eagle Ford shale, Permian Wolfcamp shale, Williston Basin Bakken and SCOOP Springer shale natural gas EOR projects. Efforts to mitigate this problem have included methods such as pressuring up wells offset the injector with water, shutting offset wells in, or pressuring up offset wells with natural gas. These efforts may work to some extent, but EOR oil recoveries are usually much lower than needed for good project economics.
The SuperEORTM process can operate very effectively to recover far more oil than natural gas or COE cyclic EOR, at much lower bottomhole pressures.
The graph below shows the recovery of oil via SuperEORTM in an Eagle Ford shale well at varying maximum buttonhole pressures. As shown, cumulative oil recovery at just 1500 psig maximum BHP is just 13% lower than cumulative oil recovery when the maximum injection BHP is 4500 psig.
The degree of interwell hydraulic or pressure communication will vary from well to well and across areas of a shale basin, as well completions determine hydraulic fracture lengths, fracture permeabilities, fracture spacing and fracture orientation, and geologic conditions provide for natural fracturing and in-situ stress conditions.
In many cases of interwell communication, the degree of pressure and hydraulic (gas or fluid movement) communication is limited to the duration of high pressure injection events. Therefore, injection into a well at pressures well below the initial reservoir pressure in most cases will limit interwell hydraulic or pressure communication.
The SuperEORTM process should be therefore applicable in wells that have exhibited interwell hydraulic or pressure communication, and reservoir simulation model matching of this appears to confirm this.
SuperEORTM Project Development Process
Development of a shale oil EOR project begins with the development of an accurate compositional reservoir simulation model. The compositional reservoir simulation model incorporates as much geological, geophysical, petrophysical, reservoir fluids and well completion and production data as possible, in order to develop an accurate mathematical representation of the reservoir and wells.
Of particular importance is the acquisition of accurate, detailed reservoir PVT data, collected from wells just following completion and flowback of frac fluids, as this data is used to develop an Equation of State for use in the compositional reservoir simulation model. The Computer Modeling Group GEM compositional reservoir simulation software is the most advanced and accurate in the oil industry. CMG software is used by more than 600 companies in 60 countries.
Once the compositional reservoir simulation model is developed, including the well completion, and historical production and pressure data, the simulation model is run and key model variables are adjusted in order to obtain an accurate history match of production and pressure data.
Once the match is obtained, the model may be used to forecast oil production under a variety of EOR operational scenarios, with a goal of determining the EOR operating conditions that will yield the greatest NPV.
Once optimum EOR operating parameters are determined from simulation modeling, an EOR field test or pilot project may be designed, in order to validate the model forecast.
The field test is then conducted, and the results compared to the simulation model forecast, with adjustments made to the model based on actual field results.
Once the field test results can be modeled with accuracy, a multi-well EOR project may be designed and implemented using the simulation model.