Well Pad Solvent Gradient Delocalization for Hydrocarbon Recovery
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Solution Overview
Problem
Current hydrocarbon production methods using solvent processes often focus on individual well or well pair operations, neglecting inter-well dynamics that could enhance recovery across a well pad, leading to suboptimal production metrics.
Innovation Solution
Deploying a strategic plurality of SAGD, SAP, SDP, and SO processes across an array of well pairs to induce and delocalize solvent-concentration and temperature gradients, leveraging inter-well pressure differentials to distribute gradients and improve cumulative steam-oil and solvent-oil ratios.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Ease of operation
If solvent processes are employed at a single well or well pair, then operational simplicity is maintained, but inter-well dynamics and gradient delocalization opportunities are neglected
Solution Approach 1:
The well pad is segmented into multiple well pairs, each operated under different conditions (SAGD, SAP, SDP, or SO processes). This segmentation allows each well pair to contribute differently to creating solvent-concentration and temperature gradients, which then delocalize across the array to improve overall recovery efficiency without requiring complex operation at any single well
Solution Approach 2:
The approach transitions from considering single well operations (0D) to well pair operations (1D) to array-wide inter-well dynamics (2D/3D). By operating well pairs at different locations and conditions across the pad, the system creates spatial gradients that delocalize across the entire array, adding a dimensional aspect to gradient management that improves productivity
2Productivity
If multiple solvent processes are deployed across a well pad array, then gradient delocalization and inter-well dynamics are leveraged, but device complexity increases
Solution Approach 1:
Different well pairs within the array are assigned different process types (SAGD, SAP, SDP, or SO) based on local conditions and objectives. Peripheral well pairs may use SAGD/SAP while medial well pairs use SDP/SO, creating localized quality differences that generate gradients. These local variations collectively contribute to delocalized gradient effects across the entire array, improving productivity while managing complexity through localized optimization
3Stability of the object's composition
If uniform solvent injection is applied across all well pairs, then operational consistency is maintained, but solvent-concentration and temperature gradients cannot be induced
Solution Approach 1:
Rather than uniform injection, the system applies different injection fluid compositions to different well pairs. Peripheral well pairs receive steam-dominated fluids (SAGD/SAP) while medial well pairs receive solvent-rich fluids (SDP/SO). This local quality variation creates the necessary solvent-concentration and temperature gradients that drive hydrocarbon mobilization and improve recovery productivity
Solution Approach 2:
The system deliberately changes injection parameters (solvent concentration, steam content, injection temperature) across different well pairs to create gradients. By varying these parameters spatially across the array, the system induces solvent-concentration and temperature gradients that enhance hydrocarbon mobilization and delocalize across the well pad, improving overall productivity
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 enhances hydrocarbon recovery by offsetting weaknesses of individual technologies with strengths of others, achieving improved production metrics and efficiency compared to conventional methods.
Implementation Method 1
heat energy is introduced to a reservoir to lower the viscosity of hydrocarbons in situ
Implementation Method 2
lower the viscosity of hydrocarbons in situ such that they can be recovered
Implementation Method 3
the solvent component of the injection fluid is primarily in the gas phase as it passes from the injection well into the reservoir
Implementation Method 4
injected solvent facilitates further chamber growth and hydrocarbon mobilization
Implementation Method 5
inter-well pressure differentials can be used to drive the delocalization of at least one such gradient
Data Source
AI summary
Disclosed are methods for producing hydrocarbons from a subterranean reservoir. The methods comprise penetrating the subterranean reservoir with a plurality of well pairs that are laterally displaced across a well pad in an array. The methods further comprise operating the plurality of well pairs under a first set of conditions that induce a solvent-concentration gradient, a temperature gradient, or a combination thereof within the subterranean reservoir by: (i) injecting varying concentrations of steam, solvent, or combinations thereof across the array, and (ii) producing hydrocarbons from the reservoir via the plurality of well pairs. The methods further comprise operating the plurality of well pairs under a second set of conditions that delocalize the solvent-concentration gradient, the temperature gradient, or the combination thereof across the array to enhance hydrocarbon production.