In modern oil and gas reservoir management, accurate wellbore flow profiling is critical for optimizing injection efficiency and production performance. Distributed fiber optic sensing technology, especially DTS (Distributed Temperature Sensing) and DAS (Distributed Acoustic Sensing), has become a key solution for real-time well monitoring.
By continuously measuring temperature and acoustic signals along the entire wellbore, fiber optic logging provides valuable insights into fluid movement, injection distribution, and production contribution from different zones.
Injection Profile Interpretation with DTS and DAS
For injection profile monitoring, DTS data is mainly used to identify localized temperature anomalies caused by injected fluids entering the formation.
When fluid passes through perforations or specific reservoir intervals, clear temperature changes appear on the temperature curve. These thermal responses allow engineers to accurately locate injection entry points and evaluate zonal injectivity.
At the same time, DAS captures flow-induced acoustic noise generated by fluid movement, helping further confirm the exact formation entry locations.
For example, during multi-rate step injection testing, flow rates can be gradually reduced from 37 m³/d to 30, 20, and 10 m³/d.
The interpretation results typically show:
clear temperature anomalies near packer release positions
linear attenuation of DAS signal intensity as injection rate decreases
accurate identification of contribution from each injection zone
This method demonstrates high sensitivity even under low injection rates, making it highly valuable for layered water injection wells and zonal optimization projects.
Production Profile Monitoring and Two-Phase Flow Analysis
In production wells, distributed fiber optic sensing helps operators determine:
fluid producing intervals
gas and water phase identification
relative production contribution from each fractured stage
DTS temperature field distribution can clearly indicate active production zones, while DAS frequency-domain analysis helps distinguish gas-water two-phase flow characteristics.
In one horizontal coalbed methane well case, interpretation results showed that fracture stages 5, 8, and 10 contributed 46.81% of total cumulative gas production, confirming them as the primary production intervals.
Among all zones, the block coal section delivered the highest gas production intensity.
These quantitative results provide strong technical support for:
refracturing design
production optimization
stage selection in future completions
reservoir performance evaluation
Why This Matters for Operators and Service Companies
For B2B buyers such as:
oilfield service companies
reservoir engineering teams
national oil companies
logging service providers
distributed fiber optic monitoring offers clear commercial value.
Key Benefits
Real-time full-wellbore monitoring
Continuous data acquisition throughout the well lifecycle.
Higher interpretation accuracy
Combining thermal and acoustic signals significantly improves profiling precision.
Reduced intervention costs
No repeated wireline operations required.
Better production decisions
Supports data-driven reservoir management and completion optimization.
From Experience-Driven to Data-Driven Well Interpretation
Advanced data processing platforms now integrate automatic download and interpretation of:
temperature
pressure
acoustic signals
profile calculation results
This centralized workflow improves data sharing and eliminates information silos across teams.
As the industry moves toward intelligent oilfield operations, distributed fiber optic logging is rapidly transforming well interpretation from traditional experience-based analysis into a fully data-driven decision system.
For companies seeking reliable injection and production profiling solutions, DTS and DAS technologies are becoming essential tools for improving well performance and maximizing reservoir value.