Reservoir management

It is important to realise that knowledge of depositional processes and features in a given reservoir will be vital for the correct siting of the optimum number of appraisal and development wells, the sizing of facilities and the definition of a reservoir management policy. 

Introduction and Commercial Application The reservoir and well behaviour under dynamic conditions are key parameters in determining what fraction of the hydrocarbons initially in place will be produced to surface over the lifetime of the field, at what rates they will be produced, and which unwanted fluids such as water are also produced. This behaviour will therefore dictate the revenue stream which the development will generate through sales of the hydrocarbons. The reservoir and well performance are linked to the surface development plan, and cannot be considered in isolation different subsurface development plans will demand different surface facilities. The prediction of reservoir and well behaviour are therefore crucial components of field development planning, as well as playing a major role in reservoir management during production. 

It Is important to know how much each well produces or injects in order to identify productivity or injectivity changes in the wells, the cause of which may then be investigated. Also, for reservoir management purposes (Section 14.0) it is necessary to understand the distribution of volumes of fluids produced from and injected into the field. This data is input to the reservoir simulation model, and is used to check whether the actual performance agrees with the prediction, and to update the historical data in the model. Where actual and predicted results do not agree, an explanation is sought, and may lead to an adjustment of the model (e.g. re-defining pressure boundaries, or volumes of fluid in place). 

Mark Cook is a Reservoir Engineer and Petroleum Economist. He has worked on international assignments mainly in Tanzania, Oman, the Netherlands and the UK. His main focus is in economic evaluation of field development projects, risk analysis, reservoir management and simulation. After 11 years with a multinational company he co-founded TRACS International of which he is Technical Director. 

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Algal pigments Lake/reservoir management Water treatment 55 ... 

Wiiest A (2010) Downstream Relevance of Reservoir Management. In Bundi U (ed.) Alpine Waters. Handbook of Environmental Chemistry, vol. 6. Springer, Heidelberg... 

The Conroe Field was unitized on Jan. 1, 1978 and Exxon Co. U.S.A., as the unit operator, assumed the producing responsibilities of 26 operators in the field. This paper describes the operator s approach to consolidation and automation of the facilities of all operators to provide more efficient field operations and surveillance to meet reservoir management objectives. 

Since the operation is in an arctic environment, achieving the above objectives presents particular problems and would be difficult and Inefficient using the more conventional approaches. Therefore, as part of the original facilities a "supervisory control and data acquisition" (SCADA) system was Installed in the VfOA. The operational philosophy is one where, by means of the SCADA system, the functions necessary for reservoir management and production control could be monitored and controlled from a central location called the Main Operations Center [Pg.57]

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A proper understanding of the above items, including maturation and filling history, formation pressure distributions, intra-reservoir communications, fault and top seal potentials, and leakage mechanisms, is considered essential for resource assessment, safe drilling of further explora-tion/delineation and production wells, and for reservoir management and production planning of the Njord Field. 

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