Wellbore Stimulation Method for Selective Hydrocarbon Recovery
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Solution Overview
Problem
Current well stimulation techniques, such as hydraulic fracturing, often apply indiscriminate pressure along a wellbore, leading to wasteful fluid injection and reduced hydrocarbon recovery due to lack of knowledge about the in-situ geology and porosity of the formation, particularly where water is scarce and hydrocarbon reservoirs have varying water content regions.
Innovation Solution
A method that involves applying pressurized fluid at discrete intervals along a wellbore at pressures below formation dilation pressure to determine the ease of fluid penetration, allowing for customized stimulation by identifying regions that benefit from higher pressure injection and avoiding unnecessary stimulation in regions with high water content or low porosity.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If pressurized fluid injection is applied along the entire length of a wellbore, then hydrocarbon recovery is improved through stimulation of tight regions, but fluid waste increases in regions with high porosity or low hydrocarbon content
Solution Approach 1:
The wellbore is divided into multiple discrete intervals, and each interval is evaluated independently for stimulation needs based on formation characteristics such as porosity and hydrocarbon content. This allows selective application of pressurized fluid injection only to intervals that require stimulation, rather than treating the entire wellbore uniformly.
Solution Approach 2:
Different treatment strategies are applied to different intervals along the wellbore based on local formation characteristics. Intervals with tight rock formations and high hydrocarbon content receive pressurized fluid injection, while intervals with high porosity or low hydrocarbon content are excluded from treatment, optimizing resource allocation and reducing fluid waste.
2Productivity
If pressurized fluid injection is applied along the entire length of a wellbore, then stimulation of tight formation regions is achieved, but water ingress increases from high water content regions
Solution Approach 1:
The wellbore is segmented into multiple intervals, each evaluated for water content and hydrocarbon content. This segmentation allows identification and exclusion of high water content regions from pressurized fluid injection treatment, preventing water ingress while maintaining treatment of beneficial intervals.
Solution Approach 2:
Local formation characteristics including water content and hydrocarbon content are assessed for each interval. Intervals with high water content are identified and excluded from treatment, while intervals with favorable characteristics are treated, thereby preventing water ingress while maintaining hydrocarbon recovery benefits.
3Area of stationary object
If indiscriminate fracturing is performed without knowledge of in-situ geology, then coverage of the entire wellbore is achieved, but recovery efficiency decreases due to incorrect treatment decisions
Solution Approach 1:
Formation characteristics such as porosity and hydrocarbon content are evaluated at each interval before applying pressurized fluid injection. This preliminary assessment allows identification of intervals that will benefit from stimulation, enabling informed treatment decisions that improve recovery efficiency while maintaining comprehensive coverage of the wellbore.
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
This approach optimizes fluid injection by determining the most beneficial locations for stimulation, reducing water ingress and enhancing hydrocarbon recovery while conserving scarce water resources.
Implementation Method 1
downhole tools have been developed which provide high pressure cyclic pressure surges, instead of a single high pressure, which is more effective in providing stimulation as it avoids constant high pressure application to the formation which might otherwise displace oil from the region of the wellbore and/or negatively affect the created fissures
Implementation Method 2
injection of pressurized fluids in hydrocarbon formations at pressures above formation dilation pressures has been used in the past to provide fractures and fissures in rock surrounding a wellbore
Data Source
AI summary
A method for determining along a length of a wellbore situated in an underground hydrocarbon-containing formation, regions within the formation to inject a fluid at a pressure above formation dilation pressure, to stimulate production of oil into the wellbore. An initial information-gathering procedure is conducted prior to formation dilation/fracturing, wherein fluid is supplied under a pressure less than formation dilation or fracture pressure, to discrete intervals along the wellbore, and sensors measure and data is recorded regarding the ease of penetration of such fluid into the various regions of the formation. Regions of the formation exhibiting poor ease of fluid penetration or regions of higher oil saturation, are thereafter selected for subsequent stimulation or dilation, at pressures above formation dilation pressures. Where initial fluid pressures and/or formation dilation pressures are provided in cyclic pulses, a downhole tool is disclosed for such purpose.