Flow Monitoring and Production Profiling Using DAS

Panhuis, Peter in ‘t; Boer, H.; Horst, Juun van der; Paleja, Rakesh; Randell, David; Joinson, Daniel; McIvor, Philip; Green, Kevyn; Bartlett, Richard

doi:10.2118/170917-ms

Cited by 44 publications

(5 citation statements)

References 13 publications

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“…Since a well-protected sensing fiber can endure harsh environments, DAS is desirable in wellbore diagnostics to examine several aspects. It can serve as a noise log to detect leakage or estimate injection rate—e.g., [ 9 , 10 ], supporting the differentiation between the channeling, borehole flow, matrix flow, and fracture flow [ 11 ]. It can also be used for hydraulic fracture monitoring [ 12 ] and seismic acquisition [ 13 ].…”

Section: Introductionmentioning

confidence: 85%

Characterization of Gas–Liquid Two-Phase Slug Flow Using Distributed Acoustic Sensing in Horizontal Pipes

Ali,

Jin,

Fan

2024

Sensors

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This article discusses the use of distributed acoustic sensing (DAS) for monitoring gas–liquid two-phase slug flow in horizontal pipes, using standard telecommunication fiber optics connected to a DAS integrator for data acquisition. The experiments were performed in a 14 m long, 5 cm diameter transparent PVC pipe with a fiber cable helically wrapped around the pipe. Using mineral oil and compressed air, the system captured various flow rates and gas–oil ratios. New algorithms were developed to characterize slug flow using DAS data, including slug frequency, translational velocity, and the lengths of slug body, slug unit, and the liquid film region that had never been discussed previously. This study employed a high-speed camera next to the fiber cable sensing section for validation purposes and achieved a good correlation among the measurements under all conditions tested. Compared to traditional multiphase flow sensors, this technology is non-intrusive and offers continuous, real-time measurement across long distances and in harsh environments, such as subsurface or downhole conditions. It is cost-effective, particularly where multiple measurement points are required. Characterizing slug flow in real time is crucial to many industries that suffer slug-flow-related issues. This research demonstrated the DAS’s potential to characterize slug flow quantitively. It will offer the industry a more optimal solution for facility design and operation and ensure safer operational practices.

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Section: Introductionmentioning

confidence: 85%

Characterization of Gas–Liquid Two-Phase Slug Flow Using Distributed Acoustic Sensing in Horizontal Pipes

Ali,

Jin,

Fan

2024

Sensors

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“…These and other workflows for the evaluation of DAS data can now be applied relatively easily by using a specially developed user program (for example [17][18] ) with powerful visualization capabilities, as shown in Figure 2 for an onshore oil producer. , the middle graph the DAS 'waterfall' plot with noise amplitudes (blue is quiet, red is loud) for a selected frequency interval as function of depth (vertical) and time (horizontal)across selected producing zones.…”

Section: Production Profilingmentioning

confidence: 99%

“…DAS has proven its utility for monitoring of Hydraulic Fracturing (HF) stimulation operations [8][9] , where it is used to determine the volumes of injected fluid and proppant in real time to better understand and optimize treatment design in conjunction with DTS; and for acquisition of Vertical Seismic Profile (VSP) surveys [10][11] and Micro-Seismic 12-13 where a string of conventional geophones can now be replaced by the FO cable. A third application of DAS is for measuring downhole production or injection flow performance [14][15][16][17][18][19][20] replacing conventional Production Logging Tool (PLT) surveys for a number of flow regimes and well types while the application for more complex situations is under development.…”

Section: Introductionmentioning

confidence: 99%

Recent Advances in Fiber Optic Technology for In-Well Production and Injection Profiling

Horst

2015

Day 3 Tue, December 08, 2015

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In the past decade, Fiber-Optic (FO) based sensing has opened up opportunities for in-well reservoir surveillance in the oil and gas industry. Distributed Temperature Sensing (DTS) has been used in applications such as steam front monitoring in thermal development projects and injection conformance monitoring in waterflood development projects using warmback analysis and FO-based pressure gauges are deployed commonly. In recent years significant progress has also been made to mature other, new FO-based surveillance methods such as the application of Distributed Strain Sensing (DSS) for monitoring reservoir compaction and well deformation, multidrop Distributed Pressure Sensing (DPS) for fluid level determination, and Distributed Acoustic Sensing (DAS) for geophysical and production/injection profiling. For the latter application, numerous field surveys were conducted to develop evaluation algorithms to convert the DAS noise recordings into flow rates from individual zones.In this paper we present an overview of recent advances in FO-based methods such as DAS, DTS, and DSS for the application of production and injection surveillance. From field examples acquired by Shell and its affiliates it is clear that FO-based flow monitoring provides a powerful addition to the standard surveillance toolkit and in some cases is even the preferred way of surveillance because of its unique advantages.

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“…In the past few years we have conducted several field surveys [16][17][18] showing that applicability of DAS for flow monitoring in different well types resulting in workflows for converting the acoustic response as measured by the DAS fiber into a production profile across the different producing (or injecting) intervals. Since the DAS interrogator has the ability to read out the different channels in the FO cable at a very high sample rate it can identify the dynamics of both low-frequency and high-frequency acoustic events ranging from less than 1 Hz up to several kHz.…”

Section: Fiber-optic Based Injection Monitoringmentioning

confidence: 99%

Latest Developments using Fiber Optic Based Well Surveillance such as Distributed Acoustic Sensing (DAS) for Downhole Production and Injection Profiling

et al. 2015

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In the past decade, Fiber-Optic (FO) based sensing has opened up opportunities for in-well reservoir surveillance in the oil and gas industry. Distributed Temperature Sensing (DTS) has been used in applications such as steam front monitoring in thermal EOR and injection conformance monitoring in waterflood projects using (improved) warmback analysis and FO based pressure gauges are deployed commonly. In recent years 1 significant progress has also been made to mature other, new FO based surveillance methods such as the application of Distributed Strain Sensing (DSS) for monitoring reservoir compaction and well deformation, multidrop Distributed Pressure Sensing (DPS) for fluid level determination, and Distributed Acoustic Sensing (DAS) for geophysical and production/injection profiling. For the latter application, numerous field surveys were conducted to develop the evaluation algorithms or workflows which convert the DAS noise recordings into flow rates from individual zones. The applicability of a new graphical user-interface has been expanded to include smart producers and injectors that allows the user to visualize (in real time), QC and evaluate the DAS data. Also, the evaluation methods for the use of DTS for warmback analysis have been significantly improved.There are still improvements to be made in enabling Distributed Sensing infrastructure, such as handling and evaluation of very large data volumes, seamless FO data transfer, the robustness & cost of the FO system installation in subsea installations, and the overall integration of FO surveillance into traditional workflows. It will take some time before all these issues are addressed but we believe that FO based applications will play a key role in future well and reservoir surveillance.In this paper we present a recent example of single-phase flow profiling using DAS. The example is from a long horizontal, smart polymer injector operated by Petroleum Development Oman (PDO).

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Flow Monitoring and Production Profiling Using DAS

Cited by 44 publications

References 13 publications

Characterization of Gas–Liquid Two-Phase Slug Flow Using Distributed Acoustic Sensing in Horizontal Pipes

Characterization of Gas–Liquid Two-Phase Slug Flow Using Distributed Acoustic Sensing in Horizontal Pipes

Recent Advances in Fiber Optic Technology for In-Well Production and Injection Profiling

Latest Developments using Fiber Optic Based Well Surveillance such as Distributed Acoustic Sensing (DAS) for Downhole Production and Injection Profiling

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