Production Surveillance And Optimization With Data Driven Models

Goh, Keat-Choon; Moncur, Charlie; Overschee, Peter Van; Briers, Jan

doi:10.2523/11647-ms

Cited by 13 publications

(4 citation statements)

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“…The daily report consists of individual well daily gas flows and the flare gas flow as estimated by subtracting sales gas, inection gas and utility gas from the total well gas flow estimates. 3,4,5,6,7,8). For all of this large installed base FW PU is already automatically and continuously estimating gas flows for all of the wells.…”

Section: Case Study 4 -Continuously Estimating Gas Emissions To the Amentioning

confidence: 99%

Continuous Energy Efficiency and Green House Gas Emission Surveillance and Control

et al. 2011

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The purpose of this paper is to document Shell's experiences and learnings in the effort to better track and reduce Green House Gases (GHG) and improve Energy Efficiency in our downstream manufacturing and upstream production operations. The paper is based on Case Studies from various Operating Units in Shell upstream and downstream operations, as well as outlining further development plans.In Shell operations we seek to minimize GHG emissions by continuously monitoring, displaying and reporting associated Key Performance Indicators (KPI's) and quickly alerting operators of changes to trigger remedial intervention. Reduction of GHG emission is also achieved by improving cross validated and mass balanced tracking of our process streams. This ensures that manufacturing and production processes are operated efficiently and transparently.Continuous GHG monitoring also allows automatic compilation of emissions by source which can then be automatically reported as part of the normal daily reporting cycle. The resulting emissions figures and associated KPI's are then prominently displayed in the Daily Production Report. The daily emissions totals are also stored and trended to flag more subtle and/or gradual changes. In this way GHG emissions data and performance information are made available to operations staff and management to facilitate awareness and corrective actions when appropriate.

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Section: Case Study 4 -Continuously Estimating Gas Emissions To the Amentioning

confidence: 99%

Continuous Energy Efficiency and Green House Gas Emission Surveillance and Control

et al. 2011

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“…The use of virtual multiphase metering, for example [1], has lead to significant improvements in the availability of production information as continuous well oil, water, and gas production estimates can be generated in real time in between well tests. For example, the remoteness of onshore wells may make it difficult to justify automatic choke valves, as utilities and infrastructure at such remote locations are too expensive.…”

Section: Current Situationmentioning

confidence: 99%

“…In references [1,5,6,7] the Production Universe data driven modelling system for real-time virtual metering and real-time optimization is described. The Production Universe technology is developed from identification techniques applied to the specific oil and gas production environment.…”

Section: Base Technology For Closed-loop Real Time Production Surveilmentioning

confidence: 99%

Closing the Loop for Improved Oil and Gas Production Management

Dijk

Goh

Lienden³

2008

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Well and Facility Operations make operating decisions based on processing huge amounts of data. However, there is a practical limit to the number of optimization moves an operator can make (due to: changing operating constraints, plant disturbances or interactions, fundamental process delays and dynamics, and the remoteness of wells). Automatic Process Control enhances the speed and accuracy with which decisions can be made and is essential for optimization. However, the advantages of automatic process control are often underestimated; hence the discipline is under-staffed and under-utilized.Process Control also plays a crucial role in plant safety and availability as stable wells or facilities are operated more frequently within the design window. Stable operation results in fewer shutdowns, less breakdown maintenance, less deferment, less flaring, lower operational cost, and sometimes even higher ultimate recovery. The impact of process instabilities on overall well or facility performance are often not recognized; a single trip may wipe out months of optimization benefits.To achieve the full potential of process control in Oil and Gas Production requires change management; Process Control technology skills need to be used throughout the whole projects lifecycle and integrated with the various processes from field development planning to surveillance and optimization. This paper will provide the following examples:1. automatic control of producer wells to prevent coning and/or gas breakthrough, 2. automatic control of injection wells to control water flooding and prevent fracturing, 3. capacity and surge controls for compressor networks, 4. control applications for the suppression of slugs, and, 5. higher level process control applications, where the application of automated control technology has improved production surveillance, management, and optimization. The role of Process Control in Exploration and ProductionHistorical perspective Most engineers and managers confuse Process Control with Instrumentation; i.e. they think Process Control is only about the video screens in the control room and the associated computers. However, Process Control is the rationale behind the visible systems (instruments and valves) and the strategy about realizing process objectives. Design decisions are made when devising the control strategy; if the level in a vessel is higher than the desired level, the control strategy is either to open the valve of the liquid outlet stream or to throttle a valve in the incoming stream. The right choice will depend on the process itself and the process objectives of the integrated facility (i.e. the consequences of the strategy upstream or downstream of the unit must be considered). Certain control objectives will be conflicting or have different priorities. It is also important to consider the dynamics of the process, the drifts and changes in the underlying equipment and processes, the measurement noise, and the possible disturbances that can occur.

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“…The above has been achieved using the Shell developed commercially available FieldWare TM Production Universe TM (FW PU) software package (references [11], [12], [13]). Combined with the Metering Atlas production flow measurement information portal reported in [14], the work reported here also provides an integrated view of the status of production metering in an Asset.…”

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confidence: 99%

Asset-Wide Reconciled Production Monitoring—A Key Enabler to Successful Real-Time Field Management

et al. 2010

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This paper describes how Brunei Shell Petroleum Co Sdn Bhd (BSP) uses cross validated and reconciled real time production data across large offshore and onshore production networks to support more proactive day-to-day oil and gas production surveillance and management. Examples are presented of the gathering network surveillance systems for the extensive BSP East and Darat Production Assets.In modern oil fields, there is an abundance of instrumentation distributed over often large geographical areas. The production network ranges from the individual wellheads, to production manifolds, test and bulk separators, past surge vessels and export pumps, to crude dehydration tanks at a central crude terminal or to the gas compressors and gas export points. At least the initial parts of the production gathering network at the wells will have multiphase flow with uncertain and variable oil, water and gas proportions. Normally the most downstream flow meters are well calibrated with good calibration records, but the actual accuracy of the majority of the flow meters upstream will be uncertain, and they will not be nominally designed to handle multiphase fluids or mixtures of fluids with varying densities. Conventionally, it is regarded to be problematic to track production variations in real time across the network back to the source wells. This is due to issues with metering multiphase flows and assumed uncertain transport delays.It is shown here that it is now practical to track in real time production rates across large production networks, working back from the most downstream, well metered, points to the individual bulk separator units or production platforms or the wells themselves. Indeed, it is possible to obtain a consistent, real-time reconciled view of the current production rates across these larger production networks. This allows more accurate surveillance of production from the wells, early detection of measurement issues and quicker responses to system upsets. Various common blockers to real time network wide production flow surveillance are addressed, including noisy meters, storage tanks, on-off pumps and hard-to-measure multiphase flows from the wells. The work reported may be seen as a "top-down" approach that complements the existing metering systems, integrating the data to "make the best of" all available metering and instrumentation. An example shows how better metering and instrumentation, virtual metering and real time data analysis are combined to detect and correct significant discrepancies.Raw ultrasonic flow meter signal in black, filtered signal is in red, reconciled filtered signal is in blue.

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Production Surveillance And Optimization With Data Driven Models

Cited by 13 publications

References 0 publications

Continuous Energy Efficiency and Green House Gas Emission Surveillance and Control

Continuous Energy Efficiency and Green House Gas Emission Surveillance and Control

Closing the Loop for Improved Oil and Gas Production Management

Asset-Wide Reconciled Production Monitoring—A Key Enabler to Successful Real-Time Field Management

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