Gas Lift Control Using Optical Bubble Sensing in Producing Wells
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Solution Overview
Problem
Challenges in transporting coiled tubing (CT) in horizontal wellbores due to friction forces, determining optimal start time and pump rate for friction reducer fluids, and efficiently managing wellbore cleanouts and gas lift operations to optimize production efficiency and reduce operator burden.
Innovation Solution
Implementing a controller with a processor that monitors wellbore conditions, predicts future lock-ups of CT using forward and generative models, automatically pumps friction reducer fluids to prevent lock-ups, optimizes wellbore cleanouts by identifying specific locations for treatment, and controls gas lift operations based on real-time production fluid analysis.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Force
If the diameter of CT is increased to overcome friction forces, then CT can be transported in horizontal wellbores, but logistical challenges with road transport and crane-lifting/loading limitations occur
Solution Approach 1:
A friction reducer fluid is introduced as an intermediary substance between the coiled tubing and the wellbore wall. The fluid reduces the coefficient of friction at the CT-wellbore interface, enabling transportation of standard-diameter CT in horizontal wellbores without increasing CT diameter or requiring complex handling equipment
Solution Approach 2:
The friction characteristics of the CT-wellbore interface are changed by introducing friction reducer fluid. This chemical parameter change allows the same CT to be transported in horizontal wellbores that would otherwise be inaccessible, avoiding the need for larger diameter CT
2Reliability
If friction reducer fluid is pumped to prevent CT lock-up, then CT transportation is improved, but determining optimal start time and pump rate becomes complex
Solution Approach 1:
The system performs preliminary calculations of friction forces and lock-up risks before CT injection begins. Based on these pre-calculations, the optimal start time and pump rate for friction reducer fluid are determined in advance, simplifying the control process while ensuring reliable lock-up prevention
Solution Approach 2:
The system continuously monitors CT injection parameters and friction forces during the operation. Real-time feedback allows dynamic adjustment of friction reducer fluid pump rate to maintain optimal conditions, automatically adapting to changing wellbore conditions without requiring complex manual control
3Productivity
If wellbore cleanout operation is performed to remove solids or debris, then production flowrate is improved, but time and cost of operation increase
Solution Approach 1:
Instead of performing cleanout operations uniformly throughout the entire wellbore, the system identifies specific locations where solids or debris accumulation is most severe. Cleanout resources are concentrated at these critical locations, removing blockages efficiently while minimizing overall operation time and cost
4Productivity
If gas is injected into annulus to lift production fluid, then production efficiency is improved, but unnecessary gas injection increases costs
Solution Approach 1:
The system continuously monitors production fluid characteristics and wellbore conditions to determine when gas lift is actually needed. Real-time feedback control adjusts gas injection rates dynamically, injecting gas only when production efficiency benefits are achieved, thereby eliminating unnecessary gas consumption and associated costs
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
Automated systems minimize operator intervention, optimize CT transportation, reduce costs and time in wellbore cleanouts, and enhance gas lift efficiency by minimizing unnecessary gas injection, thereby improving overall wellbore operation efficiency.
Implementation Method 1
technologies such as friction reducer fluids are traditionally used to extend the CT reach
Data Source
AI summary
Systems and methods for performing a gas lift operation using gas to increase production of production fluid through a production tubing in a wellbore. Included is an optical bubble sensor usable to detect bubbles per unit volume of the production fluid in the production tubing. Also included is a pump operable to pump gas into an annulus in the wellbore outside the production tubing, a valve operable to control whether gas from the pump enters the annulus, and a controller comprising a processor. The controller is operable to automatically convert the detected bubbles per unit volume into a gas/liquid saturation index (GLSI) using a transformation function; automatically execute, at designated intervals, a decision function based on the GLSI to either pump or not pump gas into the wellbore; and automatically control the pump and the valve to pump gas into the annulus when indicated by the decision function.