Parallel Wellbore Stimulation via Pre-Test Pressure Pulses
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Solution Overview
Problem
Current fracturing methods in hydrocarbon recovery are inefficient due to indiscriminate application of pressurized fluids along wellbores, leading to wasteful fluid injection and reduced oil recovery, especially in formations with unknown geology and porosity, and can cause water influx into wellbores, negatively affecting hydrocarbon recovery.
Innovation Solution
A method that involves pre-stimulation information gathering to determine relative reservoir properties by applying pressurized fluids below formation dilation pressure to identify regions requiring stimulation, allowing for targeted injection of high-pressure fluids only where beneficial, using downhole tools to apply cyclic pressure pulses and sensors to assess fluid penetration ease along the wellbore.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If pressurized fluids are injected along the entire length of a wellbore to stimulate the formation, then fracturing and fissures are created throughout the wellbore, but fluid is wasted in regions where porosity is already sufficient or hydrocarbon content is low
Solution Approach 1:
The wellbore is divided into multiple discrete intervals, and each interval is evaluated individually for stimulation needs based on formation characteristics such as porosity and hydrocarbon content. This allows selective application of fracturing treatments only to intervals that require stimulation, rather than treating the entire wellbore uniformly.
Solution Approach 2:
Formation evaluation is performed before the fracturing treatment to identify which specific intervals require stimulation. This preliminary assessment allows planners to determine the optimal locations for fracturing based on formation properties, ensuring that fluid injection is targeted only where it will be effective.
2Productivity
If pressurized fluids are injected along the entire length of a wellbore, then all regions are stimulated, but water flows out of high water content regions into the wellbore, reducing hydrocarbon recovery
Solution Approach 1:
Different regions of the formation are treated differently based on their specific characteristics. High water content regions are identified and excluded from fracturing treatment, while only regions with adequate porosity and hydrocarbon content are stimulated. This localized approach prevents water influx into the wellbore while maintaining effective hydrocarbon recovery.
3Productivity
If indiscriminate fracturing is performed without knowledge of formation porosity, then stimulation is applied throughout the wellbore, but recovery is reduced compared to targeted stimulation
Solution Approach 1:
Formation evaluation is conducted before fracturing to gather information about porosity, permeability, and hydrocarbon content at different intervals. This preliminary action provides the necessary geological knowledge to make informed decisions about where to apply stimulation, preventing waste and optimizing recovery.
Solution Approach 2:
Formation characteristics are assessed and used to provide feedback that guides the fracturing treatment design. This feedback loop ensures that stimulation is applied only where formation properties indicate it will be effective, rather than applying treatment uniformly without consideration of actual formation conditions.
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 stimulation by identifying 'tight' regions for targeted fracturing, reducing water influx and enhancing oil recovery by ensuring that fluids are injected only where necessary, thereby improving the efficiency of hydrocarbon extraction processes.
Implementation Method 1
applying, via fluid pressurization means, a fluid at a first pressure below formation dilation pressure... sensing... a value or values indicative of ease of penetration of said fluid or magnitude of a pressure pulse
Data Source
AI summary
A method for determining along relatively uniformly spaced apart parallel first and second wellbores situated in an underground hydrocarbon-containing formation, regions within the formation, including in particular regions between such wellbores, to inject a fluid at a pressure above formation dilation pressure, to stimulate production of oil into the second of the two wellbores, and subsequently injecting fluid at pressures above formation dilation pressures at the discrete regions along such wellbores determined to be in need. An initial information-gathering procedure is conducted, wherein fluid is supplied under a pressure less than formation dilation or fracture pressure, to discrete intervals along a first wellbore, and sensors in the second wellbore measure and data is recorded regarding the ease of penetration of such fluid into the various regions of the formation intermediate the two wellbores. Regions of the formation exhibiting poor ease of fluid penetration are thereafter selected for subsequent 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.