Cyclic Injection Optimization for Shale Oil Recovery
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Solution Overview
Problem
Current methods for enhanced oil recovery in shale reservoirs, such as cyclic gas injection, do not optimize the composition of injection gases to maximize oil recovery, leading to suboptimal recovery rates.
Innovation Solution
A cyclic injection process that determines the optimal composition of hydrocarbon-containing injection fluids, including gases like propane, butane, and carbon dioxide, to maximize oil recovery, along with adjusting injection and production parameters based on reservoir conditions and simulation models.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If cyclic gas injection is used to enhance oil recovery in shale reservoirs, then oil recovery is improved, but the composition of injection gases is not optimized leading to suboptimal recovery rates
Solution Approach 1:
The patent applies parameter changes by systematically varying the composition parameters of injection gases (propane, butane, carbon dioxide ratios) and injection parameters (pressure, rate, duration) to optimize oil recovery. The method uses compositional reservoir simulation to determine optimal gas mixtures and injection parameters, transforming the process from fixed protocols to dynamic parameter optimization based on reservoir conditions.
Solution Approach 2:
The patent implements feedback mechanisms through compositional reservoir simulation models that continuously assess produced fluid composition and reservoir conditions. The system uses this feedback to recalibrate injection gas composition and parameters for each cycle, creating a closed-loop optimization process that adapts to changing reservoir states and maximizes recovery efficiency.
2Productivity
If high-pressure natural gas compression equipment is used to enable cyclic injection, then injection capability is improved, but equipment complexity and cost increase
Solution Approach 1:
The patent employs disposable or easily replaceable liquid hydrocarbon storage tanks and pumping systems instead of expensive, complex high-pressure compression equipment. The method uses liquid-phase injection of hydrocarbons (propane, butane) that can be stored in conventional tanks and pumped through standard infrastructure, eliminating the need for costly compression facilities while maintaining effective injection capability.
Solution Approach 2:
The patent utilizes pneumatic and hydraulic principles by injecting liquids and gases in liquid phase through pressure-driven flow rather than mechanical compression. The system employs natural pressure gradients, gas lift, and hydraulic pumping to deliver injection materials to the reservoir, replacing complex mechanical compression systems with simpler fluid-dynamic approaches.
3Ease of operation
If existing wellbores are used for cyclic injection, then operational ease is improved, but recovery optimization is limited without compositional adjustment
Solution Approach 1:
The patent applies dynamics by making the injection process adaptive and variable rather than static. The system dynamically adjusts gas composition, injection rate, pressure, and cycle duration based on real-time reservoir conditions and produced fluid analysis. This dynamic optimization allows existing wellbores to achieve maximum recovery potential by continuously adapting injection parameters to changing reservoir states.
Solution Approach 2:
The patent uses parameter changes to optimize recovery from existing wellbores by systematically varying injection gas composition (propane, butane, carbon dioxide ratios) and injection parameters. The method recalibrates these parameters based on compositional analysis of produced fluids and reservoir conditions, transforming standard wellbores into optimized production systems without requiring new infrastructure.
Applied Scientific Principles
This section explains which scientific principles are used to turn an abstract innovation direction into a practical engineering solution.
Function Achieved in This Case
The process achieves an increase in oil recovery of at least 75% to 90% compared to primary recovery, optimizing the use of existing wellbores and reducing the need for high-pressure natural gas compression equipment.
Implementation Method 1
Carbon dioxide is used in the process due to its high miscibility in crude oil
Implementation Method 2
thermal injection, gas injection, liquid injection and chemical injection to extract crude oil from the reservoir
Implementation Method 3
The advent of oil production from shale oil and gas reservoirs around 2008 was brought about by efficient horizontal drilling and multiple stage hydraulic fracture stimulation technology development
Implementation Method 4
cyclic injection of natural gas can cause significant increased oil recovery
Implementation Method 5
high initial flow rates of oil and gas, and a rapid decline in production over the first year
Data Source
AI summary
System and method for the optimized production of hydrocarbons from shale oil reservoirs via cyclic injection to achieve an improved and optimal recovery of oil. The method can determine and optimize the composition of injected fluids to be injected, the rate, pressure and duration of injection, the production rate and pressure of produced fluids; can determine and utilize the optimum number of injection and production cycles; can determine the amount of soaking time (if any); and can determine the equipment design and operating characteristics to provide for the optimized injection of injection fluids, and the separation of produced fluids for both reinjection and delivery to sales or storage.