Greater Plutonio - Real Time Reservoir Management in a High Cost, Deepwater Environment

Booth, David Anthony; Sebastiao, Pedro Morais

doi:10.2118/128542-ms

Cited by 5 publications

(1 citation statement)

References 4 publications

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“…Greater Plutonio in Angola is a field that from start up has been able to benefit from real time capabilities, intelligent wells, and is applying repeat seismic. This has resulted in fast ramp up of production, effective management of operational issues, and is expected to lead through to improved ultimate recovery (Booth & Sebastiao, 2009).…”

Section: Examples: Capability Developments and Deployments (Need To Cmentioning

confidence: 99%

The BP Field of the Future Programme: The Continuing Mission To Deliver Value

Dickens¹,

Latin²,

Verra³

et al. 2010

Proceedings of SPE Intelligent Energy Conference and Exhibition

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BP's digital oilfield initiative, the Field of the Future Technology Flagship, has been developing and deploying distinctive operational capabilities since it's inception in 2005. This paper describes the growing track record of value delivery, achieved through pace and scale deployment. These capabilities, which continue to be developed, support a relentless drive for continuous improvement in our asset operations, aiming at delivery of significant production (100mboed BPnet) and reserve (1bnbbl) targets by 2017. We report significant progress toward meeting these targets and highlight new key lessons from our growing body of experience.The Field of the Future concept is now a routine part of how BP builds projects and operates fields across much of our portfolio. It impacts a significant and growing proportion of net production and routinely supports >80% of our top 100 wells. A range of monitoring, analytical, optimization and collaborative solutions are applied according to asset needs and value opportunities.The in-house solutions have delivered over a third of the production target so far -ahead of plan. When integrated with general bought-in solutions, base infrastructure and collaboration benefits, we are routinely adding more than 50mboed gross production per annum.The Paper presents examples of the variety of capability, technology and solution applications that have underpinned this continuing successful value delivery.Key to this success has been:• Establishing an effective, balanced approach to R&D, deployment and value realization;• Developing clear linkage to business needs and functional priorities as a basis for effectively engaging the customer.Areas of continuing challenge include:• Sustaining uptake and usage when faced with issues and barriers arising from technical, business and organizational diversity in the asset portfolio; • Competing or aligning with other business priorities and initiatives, especially in a cost challenged environment.Looking forward, the common challenge all operators face is firmly on making it an industry-wide reality, and to fully embed "intelligent energy" in all that we build and operate.

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Section: Examples: Capability Developments and Deployments (Need To Cmentioning

confidence: 99%

The BP Field of the Future Programme: The Continuing Mission To Deliver Value

Dickens¹,

Latin²,

Verra³

et al. 2010

Proceedings of SPE Intelligent Energy Conference and Exhibition

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Intelligent Oilfield Considerations for New Developments Offshore Abu Dhabi

Cobb¹,

Forster

Kirkman³

2010

Abu Dhabi International Petroleum Exhibition and Conference

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ADMA-OPCO is currently pursuing the development of several undeveloped structures offshore Abu Dhabi. These fields, some of which have been appraised over the last 30 years, are currently being evaluated and moved forward for full field development. As part of this development we are actively incorporating Intelligent Oilfield concepts into these development plans and this paper seeks to highlight some of the key considerations and assumptions being integrated into ADMA-OPCO’s philosophy for these developments. The next generation of oilfields is looking at these concepts to apply this advanced technology to: Enhance hydrocarbon recovery;Improve the safety for our Offshore Installations (by investigating new ways of working and opportunities to reduce the manning of these Operations);Reduce the Operating Costs (by improving the overall operating efficiency); It has been documented (Dickens et al. 2010) that by improving the down hole surveillance and control we may significantly enhance our ability to improve recovery in these large offshore fields. The challenges ADMA-OPCO faces offshore Abu Dhabi is that we are dealing with a high number of complex wells, to ensure adequate drainage and optimum flux rates, to enhance overall recoveries, from these difficult reservoir intervals. The optimal utilization of technology (for the applications of down hole monitoring and control) is complex as the number of wells and increasing complexity in well construction, is driving the drilling Capex higher. Current development plans in these fields show that a significant component of the field development capex is associated with the well construction costs, a significantly greater proportion of Capex than in conventional offshore developments. This is, due to the relatively lower facility costs associated with shallow water development in the Gulf. Hence optimization of well construction costs is a key component of successful delivery of the new fields. The rationalization of well complexity and organizational capability is an additional component in actively managing the increased risk associated with these non-traditional wells. Additionally we screened the systems, processes and infrastructure required to ensure optimal delivery of the real time monitoring capability and decision making capability that this technology can unlock. This paper will seek to share how ADMA-OPCO plans to move the field development concepts forward in the project life cycle and how we look to leverage world-wide learning in bringing this technology into offshore Abu Dhabi and details some of the challenges and opportunities that occur as we move forward with these concepts.

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Multiphase Flowmeter Performance: A Critical Piece of an Offshore Well Management Toolkit

Okotie¹,

Hollaender

Younes

et al. 2016

Day 2 Tue, November 08, 2016

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The accurate metering of flow rates across the production chain, from sandface to sales point or custody transfer point is of vital importance. With the use of multiphase flowmeters (MPFMs), measurement of multiphase flow under dynamic conditions is possible. In well tests, the assurance of optimal flowmeter performance is of great importance because test results can significantly impact long-term field development planning and well management. We highlight the integrated approach implemented to improve flowmetering performance for a new oilfield offshore UAE In offshore fields, MPFMs have been installed on production towers to measure production of individual wells. In the first phase of field development, commingled flow from all wells is also metered at the outlet of the manifold tower (MFT) before entering the subsea line to the processing facility. The installed MPFMs eliminate the need for traditional test separators or dedicated test vessels. However, since multiphase flow is complex, turbulent, and chaotic, the acquisition of accurate, reliable, and repeatable rate measurements can be a challenge. Fiscal measurements must also meet statutory requirements for accuracy in hydrocarbon accounting and production allocation. We present the case study of a new field, the initial challenges encountered in achieving quality test data, and the systematic approach established to streamline flowmeter performance. This approach comprises representative fluids description, results validation, and calculation model optimization, which has resulted in improved performance of wellhead and MFT flowmeters. The process of streamlining flowmeter performance verification and optimizing flowmeter utilization to track individual well performance has resulted in cost savings and improved production optimization. Well-specific pressure-volume-temperature (PVT) models have provided optimal conversion of line conditions to standard conditions, with reduced uncertainties introduced by pressure, temperature, and effluent variations. As a consequence, ideal production allocation factors were achieved, yielding confidence in the use of well test data for production and reservoir management purposes. An added benefit is the increased confidence in the data quality for history matching of the dynamic model. Effective production monitoring as new production streams from different reservoirs come on line has enhanced production reconciliation due to reduced uncertainty from commingled flow and improved production forecasting. The principles employed in multiphase flow measurement technology are not new. However, real-time, accurate flow rate measurements are essential for good decision-making, sound engineering analysis, and effective life-of-well management. The application of a case-by-case approach to flowmeter configuration, combined with an efficient monitoring approach, has proved very valuable to achievement of effective reservoir monitoring and well management.

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Greater Plutonio - Real Time Reservoir Management in a High Cost, Deepwater Environment

Cited by 5 publications

References 4 publications

The BP Field of the Future Programme: The Continuing Mission To Deliver Value

The BP Field of the Future Programme: The Continuing Mission To Deliver Value

Intelligent Oilfield Considerations for New Developments Offshore Abu Dhabi

Multiphase Flowmeter Performance: A Critical Piece of an Offshore Well Management Toolkit

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