ESP Monitoring and Diagnosis System Enables Operational Efficiency (Russian)

Molotkov, Roman; Stephenson, Greg; Seale, S.R.

doi:10.2118/115340-ru

SPE Russian Oil and Gas Technical Conference and Exhibition 2008

DOI: 10.2118/115340-ru

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ESP Monitoring and Diagnosis System Enables Operational Efficiency (Russian)

Roman Molotkov¹,

Greg Stephenson²,

S.R. Seale³

Abstract: Авторское право 2008 г., Общество инженеров-нефтяников Этот доклад был приготавливан предьявления в 2008 Российской нефтьегазовой технической конференции и выставке состоится в Москве 28-30 октабря 2008.Данный доклад был выбран для проведения презентации Программным комитетом SPE по результатам экспертизы информации, содержащейся в представленном авторами резюме. Экспертиза содержания доклада Обществом инженеров-нефтяников не выполнялась, и доклад подлежит внесению исправлений и корректировок авторами. Материа… Show more

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Cited by 10 publications

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“…(Coudeville and Watt, 2002) showed how minimising the stress on the electrical insulation and motor pressure compensation systems could extend the run-life of an ESP by minimizing the number of pump shut-downs and start-ups. A modern monitoring and diagnostics systems that measures pressures, temperature, voltages and currents at several locations was shown to increase the ESP's operational efficiency (Molotkov et al, 2008). They recommended tracking both the ESP's performance, the reservoir conditions and comparing the pump's actual operating conditions with the design up-and down-thrust limits.…”

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confidence: 99%

Role of Artificial Lift in Wells With a Downhole, Flow Control Completion

Gasbarri

Muradov²,

Davies³

2013

SPE Offshore Europe Oil and Gas Conference and Exhibition

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Several hundred of Intelligent wells well that combine downhole flow control and monitoring have been installed over the last decade in a wide range of reservoir production scenarios. Numerous publications have reported the successful use of the technology to reduce the number of well interventions, improve sweep efficiency, reduce risk, mitigate production problems, etc. A number of zonal inflow and outflow control methodologies have been proposed to meet a wide range of different well objectives as well as different production or injection conditions. Research still continues in the areas of simple reactive or predefined passive control methods employed by Intelligent wells. This is even more true if it is planned to use proactive control which requires optimisation of a complex multivariable problem.Efficient downhole flow control comes at the cost of adding an additional pressure loss. Such losses can be significant, jeopardizing the well productivity and sometimes carrying the risk of a reduced well performance of the intelligent well when compared to the corresponding conventional well. Installing artificial lift can compensate for this reduced well performance; not only extending the well life, but also adding additional well control flexibility. However, it also poses two extra problems: how to (a) optimally design the artificial lift equipment and (b) avoid interference between the I-well's control of the zonal inflow and control of the artificial lift.This paper sets out how to(1) Add control flexibility to downhole flow control by artificial lift and (2) Design an electric submersible pump that operates flexibly with down hole, multi-zone inflow control actions.Improved active and passive downhole flow control will be discussed in a rigorous, mathematical manner that allows the conclusion that the combination of artificial lift and downhole flow control provides greater zonal flow control flexibility and reduces the inflow imbalance. Also, two conceptual, electric submersible pump design options, employing (1) a variable wellhead choke and (2) a variable pump operating frequency, are proposed and illustrated. Both of these proposed pump design options could cope with the changing well inflow performance created by downhole flow control devices in situations where the standard pump design workflow was ineffective.

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confidence: 99%

Role of Artificial Lift in Wells With a Downhole, Flow Control Completion

Gasbarri

Muradov²,

Davies³

2013

SPE Offshore Europe Oil and Gas Conference and Exhibition

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From Operations to Desktop Analysis to Field Implementation: Well and ESP Optimization for Production Enhancement in the Cliff Head Field

Dholkawala¹,

Billingsley

2010

All Days

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Understanding the integrated performance of complex artificially lifted wells on ‘not normally manned’ (NNM), offshore platforms, without invasive techniques represents a challenge not only to minimizing operating costs, but also optimizing production and thereby maximizing value. Often the analysis of such problems is hindered by the complex interactions between identified production constraints and a lack of operating data. The Cliff Head oilfield (offshore Western Australia) is developed with an innovative Coiled Tubing deployed Electrical Submersible Pump (CT-ESP) artificial lift system. This paper describes the process by which ESP and well data, in conjunction with a well performance modeling software, have been used as a powerful tool to diagnose well performance issues and optimize production. Production trends were created based on real time production data to understand ESP performance. Individual well models were created to identify potential causes of declining performance; in this case, the utilization of an ESP "performance limiting factor (PLF)" indicating deteriorating ESP performance due to solids build-up. Based on the model results, chemical soaks were implemented on two production wells to remove flow restrictions within and around the ESPs. The treatments increased the oil production rates by 17% to 48% Following a de-bottlenecking study, reservoir simulation in combination with detailed ESP performance analysis concluded that total field production improvements of up to 50% were possible. Consequently, the next phase of field development will install larger capacity ESP's. This paper outlines how field data and desktop tools were combined successfully to monitor and diagnose well performance issues to deliver material production enhancements.

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Improving ESP LifeTime Performance Evaluation by Deploying an ESP Tracking and Inventory Management System

Bougherara

ahmed

Algdamsi

2011

SPE Asia Pacific Oil and Gas Conference and Exhibition

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One of the most popular and efficient artificial lift mechanisms is the electrical submersible pump (ESP). According to recent statistics, there are more than 100,000 ESPs worldwide. With the increasing number of wells equipped with ESPs, operators are making substantial efforts to improve ESP performance and achieve longer runlife. The primary focus has been on tracking ESPs sensors real-time data, along with failures prediction as proactive measures. It is however, still difficult to keep track of historical ESP pull and run jobs, ESP equipments, and benchmark pump runlife. Typically there are no structured datastores for ESP movements. ESP runlife statistics are stored in multiple individual spreadsheets and are resource-intensive to compile. This paper presents a solution that enables to track within database software ESP operations, equipments movements and failures along with classical production data to enable better ESP lifetime evaluation and equipments management. The solution encompassed ESP operations and equipment tracking within a next-generation production volumes management system. The software and database were expanded to ensure that data was generated through a single point of reference, so that operators could capture and store downhole and surface equipments tracked via serial-number along with operations details and failures. ESP runlife, failure and equipment statistics were also calculated and reported graphically. More accurate ESP lifetime was calculated using well production uptime, installation and pull dates. Using these key statistics, the asset team was able to benchmark equipments and vendors. Each time the team needed to design or redesign an ESP, the solution enabled them to browse current and historical production, ESP operations, and both installed and warehoused equipments data. Used equipments historical installations can be tracked to make informed decisions before any reinstallation in other wells. In addition, the solution allows through reports to track wells with longer pull operations time providing input to improve rig workover planning. In summary, the proper capture, validation, data browsing, and accurate performance evaluation enabled by the pilot solution reduced routine work time, positively impacting the asset team. More time could thus be dedicated to recurrent problems identification, in-depth investigations for remedial actions for underperforming ESP wells.

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ESP Monitoring and Diagnosis System Enables Operational Efficiency (Russian)

Cited by 10 publications

References 0 publications

Role of Artificial Lift in Wells With a Downhole, Flow Control Completion

Role of Artificial Lift in Wells With a Downhole, Flow Control Completion

From Operations to Desktop Analysis to Field Implementation: Well and ESP Optimization for Production Enhancement in the Cliff Head Field

Improving ESP LifeTime Performance Evaluation by Deploying an ESP Tracking and Inventory Management System

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