Well Integrity Leak Diagnostic Using Fiber-Optic Distributed Temperature Sensing and Production Logging

2021 ◽  
Author(s):  
Joerg Abeling ◽  
Ulrich Bartels ◽  
Kamaljeet Singh ◽  
Shaktim Dutta ◽  
Gaurav Agrawal ◽  
...  
Keyword(s):  
Fiber Optics ◽  
Production System ◽  
Fiber Optic ◽  
Operation Time ◽  
Temperature Sensing ◽  
The Novel ◽  
Distributed Temperature Sensing ◽  
Operational Approach ◽  
Well Completion ◽  
Well Integrity

Abstract Fiber optics has many applications in the oil and gas industry. In recent years, fiber optics has found usefulness in leak detection. The leaks can be efficiently identified using fiber-optic distributed temperature sensing measurement, thereby mitigating the health, safety, and environmental (HSE) risk associated with well integrity. Further, a production log can be used to gain more insight and finalize a way ahead to resolve well integrity issues. An innovative solution-driven approach was defined, with fiber-optic distributed measurement playing a key role. Multiple leaks were suspected in the well completion, and a fiber-optic cable was run to identify possible areas of the leak path. After the fiber-optic data acquisition, a production log was recorded across selective depths to provide an insight on leak paths. After identifying leak depths, a definitive decision between tubular patching and production system overhaul was decided based on combined outputs of the fiber-optic acquisition and production log. Results are presented for a well where multiple leaks were successfully identified using the novel operational approach. Further, operational time was reduced from 3 days (conventional slickline memory or e-line logging performed during daylight operation) to 1 day (a combination of fiber-optic distributed temperature sensing and production log in a single run). The diagnosis of production system issues was completed in one shut-in and one flowing condition, thereby reducing the risk of HSE exposure with multiple flowing conditions (to simulate the leak while the conventional production logging tool is moved to different depths in the well). Additional insight on leak quantification was confirmed from the production log data, where one leak was noted at the tubing collar while the other leak was noted a few meters above the tubing collar. This observation was substantial in deciding whether to proceed with tubing patch or replace the entire production tubing. The novel operational approach affirms fiber-optic distributed temperature measurement's versatility in solving critical issues of operation time and reducing HSE exposure while delivering decisive information on production system issues. The paper serves as a staging area for other applications of similar nature to unlock even wider horizons for distributed temperature sensing measurement.

Unlocking the Potential of Fiber-Optic Distributed Temperature Sensing in Resolving Well Integrity Issues

2021 ◽  
Author(s):  
Shaktim Dutta ◽  
Kamaljeet Singh ◽  
Gaurav Agrawal ◽  
Apoorva Kumar
Keyword(s):  
Production System ◽  
Fiber Optic ◽  
Operation Time ◽  
Temperature Sensing ◽  
The Novel ◽  
Distributed Temperature Sensing ◽  
Well Integrity ◽  
Deep Wells ◽  
Conventional Production ◽  
Production Tubing

Abstract Multiple leaks in production tubing of deep wells can be efficiently identified using fiber-optic distributed temperature measurement and thereby mitigating the health, safety and environment (HSE) risk associated with a potential well barrier failure. Further, a production log can be used to gain more insight and finalize a way ahead to resolve the issues of the well integrity. An innovative solution-driven approach was identified with fiber-optic distributed measurement playing a key role. Multiple leaks were suspected in the production system and a fiber-optic cable was run to identify possible areas of leak path. In these deep wells, after the fiber-optic data acquisition, a production log was recorded across selective depths to provide more insights on leak paths. Post identification of leak depths, a definitive decision between tubular patching and production system overhaul was decided based on combined outputs of fiber-optic, production log and tubular patch technology. Results are presented for a two-well operation. Taking an example of Well A, leaks were successfully identified at three depths using the novel operational approach. Further, operation time was reduced from three days (conventional production log measurement performed during daylight operation) to one day (combination of fiber-optic distributed temperature sensing and production log in a single run). Diagnosis of production system issues were completed in one flowing and one shut-in survey condition, thereby reducing the risk of HSE exposure with multiple flowing conditions (conventional production log measurement). Additional insight and confirmation on leaks were observed from production log data which helped identify the presence of a leak across the tubing body. This observation was substantial in deciding whether to proceed with tubing patch or replace the entire production tubing. Tubing patch technology was not satisfactorily recognized to provide well integrity across leak depths. Hence, the decision was made to replace the entire production tubing. The novel operational approach affirms the versatility of fiber-optic distributed temperature measurement in solving critical issues of operation time and reducing HSE exposure while delivering decisive information on production system issues. The paper serves as a staging area for other applications of similar nature to unlock even wider horizons for distributed temperature sensing.

Horizontal-Steam-Injection-Flow Profiling Using Fiber Optics

SPE Journal ◽  
2019 ◽  
Vol 24 (02) ◽  
pp. 431-451 ◽  
Author(s):  
M.. Shirdel ◽  
R. S. Buell ◽  
M. J. Wells ◽  
C.. Muharam ◽  
J. C. Sims
Keyword(s):  
Fiber Optics ◽  
Fiber Optic ◽  
Steam Injection ◽  
Flow Profile ◽  
Distributed Temperature Sensing ◽  
Flow Loop ◽  
Conformance Control ◽  
Well Completion ◽  
Injection Flow ◽  
Optic Systems

Summary Steam-conformance control in horizontal injectors is important for efficient reservoir-heat management in heavy-oil fields. Suboptimal conformance and nonuniform heating of the reservoir can substantially affect the economics of the field development and oil-production response and result in nonuniform steam breakthrough. To achieve the required control, it is essential to have an appropriate well-completion architecture and robust surveillance. Five fiber-optic systems, each with a unique steam-conformance-control-completion configuration, have been installed in two horizontal steam injectors to help mature steam-injection-flow profiling and conformance-control solutions. These fiber-optic systems have used custom-designed fiber-optic bundles of multimode and single-mode fibers for distributed-temperature sensing (DTS) and distributed-acoustic sensing (DAS), respectively. Fiber-optic systems were also installed in a steam-injection-test-flow loop. All the optical fibers successfully acquired data in the wells and flow loop, measuring temperature and acoustic energy. A portfolio of algorithms and signal-processing techniques was developed to interpret the DTS and DAS data for quantitative steam-injection-flow profiling. The heavily instrumented flow-loop environment was used to characterize DTS and DAS response in a design-of-experiment (DOE) matrix to improve the flow-profiling algorithms. These algorithms are dependent on independent physical principles derived from multiphase flow, thermal hydraulic models, acoustic effects, large-data-array processing, and combinations of these methods for both transient and steady-state steam flow. A high-confidence flow profile is computed using the convergence of the algorithms. The flow-profiling-algorithm results were further validated using 11 short-offset injector observation wells wells in the reservoir that confirmed steam movement near the injectors.

scholarly journals Thermodynamics of a fast-moving Greenlandic outlet glacier revealed by fiber-optic distributed temperature sensing

2021 ◽  
Vol 7 (20) ◽  
pp. eabe7136
Author(s):  
Robert Law ◽  
Poul Christoffersen ◽  
Bryn Hubbard ◽  
Samuel H. Doyle ◽  
Thomas R. Chudley ◽  
...  
Keyword(s):  
Fiber Optic ◽  
Basal Layer ◽  
Temperature Sensing ◽  
Distributed Temperature Sensing ◽  
Catchment Scale ◽  
Outlet Glacier ◽  
Coarse Spatial Resolution ◽  
High Vertical Resolution ◽  
Fast Motion ◽  
Strain Heating

Measurements of ice temperature provide crucial constraints on ice viscosity and the thermodynamic processes occurring within a glacier. However, such measurements are presently limited by a small number of relatively coarse-spatial-resolution borehole records, especially for ice sheets. Here, we advance our understanding of glacier thermodynamics with an exceptionally high-vertical-resolution (~0.65 m), distributed-fiber-optic temperature-sensing profile from a 1043-m borehole drilled to the base of Sermeq Kujalleq (Store Glacier), Greenland. We report substantial but isolated strain heating within interglacial-phase ice at 208 to 242 m depth together with strongly heterogeneous ice deformation in glacial-phase ice below 889 m. We also observe a high-strain interface between glacial- and interglacial-phase ice and a 73-m-thick temperate basal layer, interpreted as locally formed and important for the glacier’s fast motion. These findings demonstrate notable spatial heterogeneity, both vertically and at the catchment scale, in the conditions facilitating the fast motion of marine-terminating glaciers in Greenland.

Measuring Artificial Recharge with Fiber Optic Distributed Temperature Sensing

Ground Water ◽  
2012 ◽  
Vol 51 (5) ◽  
pp. 670-678 ◽  
Author(s):  
Matthew W. Becker ◽  
Brian Bauer ◽  
Adam Hutchinson
Keyword(s):  
Fiber Optic ◽  
Artificial Recharge ◽  
Temperature Sensing ◽  
Distributed Temperature Sensing

Expanding the Envelope of Fiber-Optic Sensing for Reservoir Description and Dynamics

2021 ◽  
Author(s):  
Abdulaziz Al-Qasim ◽  
Sharidah Alabduh ◽  
Muhannad Alabdullateef ◽  
Mutaz Alsubhi
Keyword(s):  
Performance Optimization ◽  
Fiber Optic ◽  
Thermal Recovery ◽  
Production Performance ◽  
Flow Profile ◽  
Distributed Temperature Sensing ◽  
Integrity Monitoring ◽  
Well Integrity ◽  
Fiber Optic Sensing ◽  
Reservoir Description

Abstract Fiber-optic sensing (FOS) technology is gradually becoming a pervasive tool in the monitoring and surveillance toolkit for reservoir engineers. Traditionally, sensing with fiber optic technology in the form of distributed temperature sensing (DTS) or distributed acoustic sensing (DAS), and most recently distributed strain sensing (DSS), distributed flow sensing (DFS) and distributed pressure sensing (DPS) were done with the fiber being permanently clamped either behind the casing or production tubing. Distributed chemical sensing (DCS) is still in the development phase. The emergence of the composite carbon-rod (CCR) system that can be easily deployed in and out of a well, similar to wireline logging, has opened up a vista of possibilities to obtain many FOS measurements in any well without prior fiber-optic installation. Currently, combinations of distributed FOS data are being used for injection management, well integrity monitoring, well stimulation and production performance optimization, thermal recovery management, etc. Is it possible to integrate many of the distributed FOS measurements in the CCR or a hybrid combination with wireline to obtain multiple measurements with one FOS cable? Each one of FOS has its own use to get certain data, or combination of FOS can be used to make a further interpretation. This paper reviews the state of the art of the FOS technology and the gamut of current different applications of FOS data in the oil and gas (upstream) industry. We present some results of traditional FOS measurements for well integrity monitoring, assessing production and injection flow profile, cross flow behind casing, etc. We propose some nontraditional applications of the technology and suggest a few ways through. Which the technology can be deployed for obtaining some key reservoir description and dynamics data for reservoir performance optimization.

scholarly journals Distributed Temperature Sensing Monitoring of Well Completion Processes in a CO2 Geological Storage Demonstration Site

Sensors ◽  
2018 ◽  
Vol 18 (12) ◽  
pp. 4239 ◽  
Author(s):  
Dasom Lee ◽  
Kwon Park ◽  
Changhyun Lee ◽  
Sang-Jin Choi
Keyword(s):  
Conventional Method ◽  
Exothermic Reaction ◽  
Thermal Response ◽  
Temperature Sensing ◽  
Temperature Calibration ◽  
Distributed Temperature Sensing ◽  
Cement Slurry ◽  
Well Completion ◽  
Calibration Methods ◽  
Gravel Packing

The Distributed Temperature Sensing (DTS) profiles obtained during well completion of a CO2 monitoring well were analyzed to characterize each well completion process in terms of temperature anomalies. Before analysis, we corrected the depth by redistributing the discrepancy, and then explored three temperature calibration methods. Consequently, we confirmed the depth discrepancy could be well corrected with conventional error redistribution techniques. Among three temperature calibration methods, the conventional method shows the best results. However, pointwise methods using heat coil or in-well divers also showed reliable accuracy, which allows them to be alternatives when the conventional method is not affordable. The DTS data revealed that each well completion processes can be characterized by their own distinctive temperature anomaly patterns. During gravel packing, the sand progression was monitorable with clear step-like temperature change due to the thermal bridge effect of sand. The DTS data during the cementing operation, also, clearly showed the progression up of the cement slurry and the exothermic reaction associated with curing of cement. During gas lift operations, we could observe the effect of casing transition as well as typical highly oscillating thermal response to gas lifting.

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