How 24/7 Real-Time Surveillance Increases ESP Run Life and Uptime

Camilleri, Lawrence; MacDonald, J. W.

doi:10.2118/134702-ms

Cited by 50 publications

(9 citation statements)

References 16 publications

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“…The fully operational Artificial Lift Surveillance Centre (ALSC) based in Inverurie, UK has also demonstrated the value of 24/7 ESP surveillance and monitoring in terms of extended ESP run life and reduction in downtime. The ALSC provides coverage for over 150 wells equipped with ESPs across Europe and Africa (Camilleri and MacDonald, 2010). However, ESP-DST well testing requires seamless integration of both acquisition and data delivery systems, optimized for monitoring of each particular operation to deliver data from the ESP and the surface well test package in different formats to dedicated operation support centers.…”

Section: Figure 9 -Wellhead Conditions Superposed On Hydrate Curves Fmentioning

confidence: 99%

Real Time Well Testing: A Game Changer – Experience and Lessons Learned Over 100 Well Tests Performed In the North Sea

Hollaender

Shumakov

Sarac

et al. 2015

Day 1 Tue, September 15, 2015

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Obtaining accurate and representative well testing information is critical for the proper characterization of a reservoir, with confidence and quality of data being of paramount importance during a well test. Over the last few years, well testing has become real-time enabled, following in the footsteps of drilling, wireline logging and production operations. However, making a better well test is not just about enabling the technology. It is also about ensuring that the right people have access to the right data and that adequate decision-making processes are available. This requires that reservoir engineers are trained in operational aspects, rig crew are able to communicate and implement remotely taken decisions, and the "end-users" of the well test are fully engaged in the real time monitoring, analysis and execution processes.The real-time well testing approach presented in this paper is the result of the evolution from basic real-time data transmission to a reliable real-time data delivery and analysis infrastructure that has taken place over the last five years. Throughout the 100 real-time well tests completed in the North Sea, the workflows used to process and analyze the data have evolved significantly, enabling the processed information to be leveraged for decision-making and to update test programs. Recently developed downhole tools and components controlled remotely via a wireless acoustic telemetry system, and providing real-time access to downhole pressure data, have enhanced and broadened the applicable workflows and capabilities. This paper also presents the evolution of remote connectivity systems and the exploitation of their technical capabilities to their full potential so that off-site experts can witness, collaborate and support operations on a 24/7 basis. By these means, the right expertise can be utilized regardless of location. In addition, we present several case studies where real time data delivery, remote monitoring and support were crucial for continuous quality assurance and for successful pressure transient analysis which led to better reservoir characterization. The change in the mindset of management in both operating companies and service suppliers is essential to ensure that the power of real-time enabled well testing is fully leveraged.

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Section: Figure 9 -Wellhead Conditions Superposed On Hydrate Curves Fmentioning

confidence: 99%

Real Time Well Testing: A Game Changer – Experience and Lessons Learned Over 100 Well Tests Performed In the North Sea

Hollaender

Shumakov

Sarac

et al. 2015

Day 1 Tue, September 15, 2015

View full text Add to dashboard Cite

show abstract

“…The fully operational Artificial Lift Surveillance Centre (ALSC) based in Inverurie, UK has also demonstrated the value of 24/7 ESP surveillance and monitoring in terms of extended ESP run life and reduction in ESP downtime. The ALSC provides coverage for over 150 wells equipped with ESPs across the Europe and Africa (Camilleri and MacDonald 2010). However, ESP-DST well testing requires seamless integration of both acquisition and data delivery systems, optimized for monitoring of each particular operation to deliver data from ESP and surface well test package in different formats to dedicated operation support centers.…”

Section: Real-time Servicesmentioning

confidence: 99%

Methodologies, Solutions, and Lessons Learned from Heavy Oil Well Testing with an ESP, Offshore UK in the Bentley Field, Block 9/3b

et al. 2011

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Due to increased hydrocarbon demand and technological advances, production from heavy oil fields in the United Kingdom Continental Shelf (UKCS) has become possible over the past 10 years. Despite substantial reserves in the UKCS with crudes less than 20° API, most of the activity has been confined to exploration and appraisal drilling. The main reason for the restricted activity has been the high uncertainty of the reservoir and fluid properties. Operational complexities inherent to heavy oil also limit the use of conventional appraisal-well testing technology.A method was developed to determine the most suitable technology for testing wells with heavy oil using an electrical submersible pump (ESP). The solution was applied in the Bentley field located in the UK sector of the North Sea in block 9/3b, on which final appraisal well 9/3b-6Z was flow tested in December 2010.The technical challenges included a short weather window, maintaining fluid mobility through the surface-testing equipment, oil and gas separation for metering, obtaining accurate flow measurements, and designing the most appropriate ESP system. A combination of technologies-dual-energy gamma ray venturi multiphase flowmeter, real-time monitoring, and a novel ESP completion-provided a solution that enabled successful well test execution. A multirate test reaching a final stabilized rate of 2900 bpd, with a subsequent period of pressure buildup was accomplished in less than 2.5 days with 10 to 12° API crude. A key lesson was how to obtain the quality of data that would enable reservoir engineers to extract with confidence a productivity index and perform pressure transient analysis for reservoir characterization. This success paves the way for development drilling to commence on the Bentley field at the end of 2011, but also demonstrates potential that can enable new heavy oil field developments.

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“…To improve the chances these projects have of success, operating companies must make allowances for run-life improvement options to take priority over production requirements (Camilleri and MacDonald, 2010), including the installation of additional equipment to help characterise the operating conditions and their effect on the subsurface. To improve the chances these projects have of success, operating companies must make allowances for run-life improvement options to take priority over production requirements (Camilleri and MacDonald, 2010), including the installation of additional equipment to help characterise the operating conditions and their effect on the subsurface.…”

Section: Introductionmentioning

confidence: 99%

Diagnosing PCP Failure Characteristics using Exception Based Surveillance in CSG

et al. 2013

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The coal seam gas (CSG) industry is challenged to maximise gas recoverability while minimising the operational and maintenance costs of subsurface artificial lift technologies. Data acquisition is critical in both optimising assets and characterising early failure. Large data flows must be analysed for variations from normal operation to identify problems when and before they occur; automated processes are essential.Exception based surveillance (EBS) utilises a systematic approach for automatically monitoring asset data (particularly continuous time-series data) for violations of acceptable operating conditions, or for trends that show deviations from expectations. EBS also provides diagnostics that assist in identifying the root cause of exceptions and providing suggestions for remediation.Root cause analysis (RCA)-derived failure mechanisms aid in accurately identifying the source of repeatable failures in wells. Key performance indicators, measured or calculated from continuous data sources allow operators to observe operational trends, notice variations to long-term averages and begin investigatory procedures before failures occur. The information can be used to avoid failure or develop prevention strategies.Progressive Cavity Pumps (PCP) are one of the preferred artificial lift methods for CSG production in both the Bowen and Surat basins in Australia. This paper discusses the innovative use of algorithms and software, in an automated exception based system to diagnose and detect PCP failure in a CSG environment. Using only four different parameters, this paper aims to maximise the value of information to monitor the operating conditions in each well and minimise operational costs by deciphering an in-situ volumetric efficiency variable and a frictional coefficient in parallel to the exisiting parameters without the need for additional monitoring sensors.

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How 24/7 Real-Time Surveillance Increases ESP Run Life and Uptime

Cited by 50 publications

References 16 publications

Real Time Well Testing: A Game Changer – Experience and Lessons Learned Over 100 Well Tests Performed In the North Sea

Real Time Well Testing: A Game Changer – Experience and Lessons Learned Over 100 Well Tests Performed In the North Sea

Methodologies, Solutions, and Lessons Learned from Heavy Oil Well Testing with an ESP, Offshore UK in the Bentley Field, Block 9/3b

Diagnosing PCP Failure Characteristics using Exception Based Surveillance in CSG

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