Gas-phase solvent management in-situ hydrocarbon production
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Solution Overview
Problem
Conventional in-situ hydrocarbon production methods face challenges in controlling the production of gas-phase solvent during solvent-aided and solvent-driven processes, leading to inefficiencies and suboptimal recovery metrics due to solvent short-circuiting and imbalanced gas-to-liquid phase ratios.
Innovation Solution
The method involves configuring production wells with spaced fluid-inlet components to segment drainage fluids into semi-localized zones, prioritizing hydraulic communication with low gas-content zones and modulating pump speeds to manage flow rates, thereby controlling the liquid-to-gas phase ratio and retaining gas-phase solvent within the reservoir.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Ease of operation
If conventional production-well completions are used, then gas-phase solvent can be produced, but control over the gas phase:liquid phase ratio is lost and solvent short-circuiting occurs
Solution Approach 1:
The production well is segmented into multiple discrete in-flow zones using spaced fluid-inlet components, allowing independent control of gas and liquid phase flow from different reservoir zones. This segmentation enables selective prioritization of low gas-content zones while managing overall gas:liquid phase ratio.
Solution Approach 2:
The system employs dynamic pump speed modulation to actively manage the gas:liquid phase ratio in produced fluids. By varying pump operating conditions in response to measured phase ratios, the system maintains optimal production characteristics while adapting to changing reservoir conditions.
2Productivity
If gas-phase solvent is produced, then production fluid volume increases, but gas processing bottlenecks occur and recovery metrics deteriorate
Solution Approach 1:
The invention extracts and removes gas-phase solvent from the produced fluid stream through phase separation processes. By separating the gas phase from liquid hydrocarbons at the production well or surface facilities, the system prevents gas processing bottlenecks and retains solvent for potential re-injection, while maintaining high oil production rates.
Solution Approach 2:
The system introduces an intermediary phase separation process between reservoir production and surface processing. This intermediary step manages the gas:liquid phase ratio by separating phases and allowing selective handling, preventing gas-phase solvent from creating bottlenecks in downstream processing while maintaining productivity.
3Manufacturing precision
If fluid-inlet components are spaced to segment drainage fluids, then control over gas:liquid phase ratio improves, but well completion complexity increases
Solution Approach 1:
The production well is divided into multiple discrete in-flow zones using spaced fluid-inlet components positioned at specific intervals along the horizontal section. This segmentation creates distinct zones that can be selectively activated or deactivated, enabling precise control over which reservoir regions contribute to production and thereby managing gas:liquid phase ratio.
Solution Approach 2:
Different sections of the production well are given different functional characteristics through selective activation of fluid-inlet zones. Zones with high gas-content are deprioritized or deactivated, while zones with low gas-content are prioritized for active production, creating local quality variations that optimize overall production fluid composition.
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 maintains or enhances oil production rates while reducing gas production and improving recovery metrics, such as steam-oil ratios and oil recovery factors, by effectively managing the phase ratios and reducing solvent bottlenecks.
Implementation Method 1
producing a production fluid at a production-flow rate via a pump running at a pump speed
Data Source
AI summary
Methods for producing hydrocarbons from subterranean reservoirs utilizing a production well having a plurality of fluid-inlet components spaced apart to define a plurality of production-well fluid-inlet zones. An injection fluid comprising a solvent is injected into the reservoir, resulting in a drainage fluid with a liquid phase and a gas phase occupying one or more of the production-well fluid-inflow zones. The production fluid is produced at a production-flow rate via a pump, and the gas phase:liquid phase ratio of the production fluid is modulated by orchestrating variations in the pump speed and one or more of the plurality of fluid-inlet components to prioritize hydraulic communication with a subset of the plurality of production-well fluid-inlet zones.