Well Surveillance with a Permanent Downhole Multiphase Flowmeter

Webster, Michael; Richardson, S.; Gabard-Cuoq, C.; Fitzgerald, John; Stephenson, K.E.

doi:10.2118/90024-pa

Cited by 17 publications

(8 citation statements)

References 9 publications

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“…Webster et al (2006) report on the use of sophisticated downhole multiphase rate monitoring which requires the application of both specialized metering devices and complex analytical techniques. Depending on the complexity of the well and its associated reservoir, it can be a full-time job for a reservoir engineer to monitor just one of these wells.…”

Section: High-rate Offshore Wells -Completion and Reserves Monitoringmentioning

confidence: 99%

Intelligent Continual Right-Time Analysis of Field Data as a Service

Mezzatesta

Shaw

Webb³

2008

All Days

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This paper describes one application of Right-Time analysis of continual field measurements as used in a high-rate HPHT field in the North Sea. Many sensors and devices in the field are available for constant monitoring at the reservoir manager's desk, yet, we are still faced with the challenge of transforming all this raw streaming data into useful information. Data is regularly used to identify anomalies in the classical Field Automation sense. At medium-long term, however, it ought to be used to identify well and reservoir signatures that help in Formation Evaluation, and for reservoir management and planning. This rarely happens because the analysis involved -which includes highly technical disciplines -simply cannot be automated by computer. This makes it vital to be able to streamline these activities and to deliver the associated analysis as a turnkey service to the Field Operator.

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Section: High-rate Offshore Wells -Completion and Reserves Monitoringmentioning

confidence: 99%

Intelligent Continual Right-Time Analysis of Field Data as a Service

Mezzatesta

Shaw

Webb³

2008

All Days

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“…Further information regarding the theory of measurement can be found in SPE 90024. 2 A master calibration of the tool is performed prior to installation and in-situ calibration can be carried out as and when required to compensate for any changes of flow regimes, etc. Performance of the tool is dependent upon such factors as the specifications of the pressure gauges together with the correct selection of the Venturi size for expected flow characteristics.…”

Section: Engineered Solution and Field Installationmentioning

confidence: 99%

Permanent Real-Time Downhole Flowrate Measurements in Multilateral Wells Improve Reservoir Monitoring and Control

Захаров

Eriksen

Raw

et al. 2007

Proceedings of EUROPEC/EAGE Conference and Exhibition

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fax 01-972-952-9435. AbstractDuring the last decade, intelligent well completions have evolved to become engineered solutions widely used for both monobore and multilateral horizontal wells. However, a clear understanding of zonal or lateral branch flow contributions still remains an issue. Several SPE papers covering the issue have been published recently.This paper presents the engineered solution for a TAML level 5 dual-lateral horizontal well that was drilled and completed in the Oseberg Sør field in December 2005. The solution combines hydraulic flow control valves with advanced downhole two-phase flow and density measurement provided by a Venturi-based flowmeter with a gamma ray source and detector. Real-time data were used to optimize the settings of the downhole chokes to obtain a balanced production from the two horizontal wellbores. The completion provides the capability to control and measure, in real time, flow contributions from both laterals and is the first installation of its type. This capability is critical for production and reservoir optimization.Additional value of the technology is demonstrated by the analysis of acquired downhole data. Productivity Indices are obtained for each of the two laterals without any production loss associated with shutting down the other lateral branch. Data analysis indicated a decrease of the Productivity Index for one of the two horizontal wellbores.The successful installation of the two-phase flowmeter in an intelligent completion is a significant milestone corresponding to the general trend in the industry to improve inflow control and the understanding of flow contributions in multilateral wells. This solution for flow control and measurement can be applied effectively in both multilateral wells and monobore wells designed for commingled production from different reservoirs where accurate production allocation is a critical issue.

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“…In-well sensors are currently technologically mature and have been installed in realistic smart wells (Dilib et al, 2015). Examples of successfully applied in-well monitoring techniques include pressure gauges, temperature sensors, and multiphase flow meters based on fiber optics (Kragas et al, 2003;Webster et al, 2006;Aggrey et al, 2007). These tools can only monitor fluid changes inside or closely adjacent to the well.…”

Section: Introductionmentioning

confidence: 99%

Reservoir monitoring using borehole radars to improve oil recovery: Suggestions from 3D electromagnetic and fluid modeling

et al. 2018

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The recently developed smart well technology allows for sectionalized production control by means of downhole inflow control valves and monitoring devices. We consider borehole radars as permanently installed downhole sensors to monitor fluid evolution in reservoirs, and it provides the possibility to support a proactive control for smart well production. To investigate the potential of borehole radar on monitoring reservoirs, we establish a 3D numerical model by coupling electromagnetic propagation and multiphase flow modeling in a bottom-water drive reservoir environment. Simulation results indicate that time-lapse downhole radar measurements can capture the evolution of water and oil distributions in the proximity (order of meters) of a production well, and reservoir imaging with an array of downhole radars successfully reconstructs the profile of a flowing water front. With the information of reservoir dynamics, a proactive control procedure with smart well production is conducted. This method observably delays the water breakthrough and extends the water-free recovery period. To assess the potential benefits that borehole radar brings to hydrocarbon recovery, three production strategies are simulated in a thin oil rim reservoir scenario, i.e., a conventional well production, a reactive production, and a combined production supported by borehole radar monitoring. Relative to the reactive strategy, the combined strategy further reduces cumulative water production by 66.89%, 1.75%, and 0.45% whereas it increases cumulative oil production by 4.76%, 0.57%, and 0.31%, in the production periods of 1 year, 5 years, and 10 years, respectively. The quantitative comparisons reflect that the combined production strategy has the capability of accelerating oil production and suppressing water production, especially in the early stage of production. We suggest that borehole radar is a promising reservoir monitoring technology, and it has the potential to improve oil recovery efficiency.

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Well Surveillance with a Permanent Downhole Multiphase Flowmeter

Cited by 17 publications

References 9 publications

Intelligent Continual Right-Time Analysis of Field Data as a Service

Intelligent Continual Right-Time Analysis of Field Data as a Service

Permanent Real-Time Downhole Flowrate Measurements in Multilateral Wells Improve Reservoir Monitoring and Control

Reservoir monitoring using borehole radars to improve oil recovery: Suggestions from 3D electromagnetic and fluid modeling

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