Using Integrated Production Modeling (IPM) as an Optimization Tool for Field Development Planning and Management

Ageh, Ebenezer; Adegoke, Adekola Felix; Uzoh, O.J.

doi:10.2118/140625-ms

Cited by 18 publications

(2 citation statements)

References 2 publications

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“…Furthermore, the applying such a system in a developed onshore gas lift fields in the western parts of the United States of American and their findings were extensively discussed. Ageh et al (2010) carried out an integrated method of production modelling for optimising field development planning as well as management. The Petroleum experts (PETEX) modelling tool was used for evaluating the Bonga North deep-water subsea tie-back development, the software allowed the incorporation of flow assurance into subsurface deliverability and this also includes considering the effect of both existing and envisaged topside constraints.…”

Section: Introductionmentioning

confidence: 99%

Optimisation of Artificial Lifts Using Prosper Nodal Analysis for BARBRA-1 Well in Niger Delta

Odjugo¹,

Baba²,

Aliyu³

et al. 2020

Nig. J. Technol. Dev.

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Hydrocarbon exploration basically requires effective drilling and efficient overpowering of frictional and viscosity forces. Normally, frictional power losses occur in deep well systems and it is essential to analyse each component of any well system to determine where exactly pressure is lost, and this can be done using Nodal Analysis. In this study, nodal analysis has been carried out with the use of PROSPER, a software for well performance, design and optimisation. Artificial lifts can then be used to solve the problem of frictional power losses. To increase the production of Barbra 1 well in the Niger Delta and hence extend its functional life, we have applied nodal analysis. Modelling results for three artificial lift methods; continuous gas lift, intermittent gas lift and electrical submersible pump were found to be 1734.93 bbl/day, 451.50 bbl/day and 2869 bbl/day respectively. The output from the well performance without artificial lift was 1370.99 bbl/day by applying Darcy’s model. Meanwhile, the output from the well without artificial lift is 89.90 bbl/day when aided with productivity index (PI) entry, the normal model for intermittent gas lift. Hence, from the comparative analysis of the results obtained from this study, it was deduced that when artificial lifts are employed, the well output increases significantly from 1370.99bbl/day to 2869 bbl/day (electrical submersible pump). This study concludes that wells such as Barbra 1 are good candidates for artificial lift, and this is evidenced by increasing productivity. Keywords: Production optimisation, nodal analysis, prosper simulator and barbra well.

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Section: Introductionmentioning

confidence: 99%

Optimisation of Artificial Lifts Using Prosper Nodal Analysis for BARBRA-1 Well in Niger Delta

Odjugo¹,

Baba²,

Aliyu³

et al. 2020

Nig. J. Technol. Dev.

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“…Alguns trabalhos vêm sendo desenvolvidos na área para fazer a simulação integrada de reservatório/sistema de produção utilizando diversos softwares de simulação de superfície e reservatório, como em Hayder (2006), Ursini (2010), Rodríguez (2007), Ageh (2010) e Hayder (2011.…”

Section: Motivaçõesunclassified

Redes Neurais Aplicadas À Construção De Aproximadores Para Simulação Integrada Entre Reservatório E Sistema De Produção

KOHLER¹

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À Deus.À minha orientadora Professora Marley, pelo apoio e parceria para a realização deste trabalho.Ao meu co-orientador Eugênio, pela confiança, estímulo e importantes contribuições.Aos meus pais, Zita e Helio, pela educação, atenção e carinho.Aos meus irmãos amigos e amigos irmãos Marcella, Dedé, Roberta, JP, Davi, Leonardo, Mariana, Marco, Sarah, Marina, Mateus, por todo apoio, paciência e compreensão.À todos os amigos da PUC-Rio.À todos os amigos e familiares que de uma forma ou de outra me estimularam e me ajudaram.Aos colegas da Petrobràs pela disponibilidade e interesse em contribuir.Aos professores que participaram da Comissão examinadora.Ao CNPq, à PUC-Rio, à Petrobrás e à Pretroleum Experts, pelos auxílios concedidos, sem os quais este trabalho não poderia ter sido realizado. o cálculo do VPL é diretamente dependente dos dados de produção de óleo, gás e água durante a vida produtiva do reservatório, bem como de seus custos de desenvolvimento. Determinar a localização, os tipos (produtor ou injetor) e a trajetória de poços em um reservatório é um problema de otimização complexo que depende de uma grande quantidade de variáveis, dentre elas as propriedades do reservatório (tais como porosidade e permeabilidade) e os critérios econômicos. Os processos de otimização aplicados a este tipo de problema têm um alto custo computacional devido ao uso contínuo de simuladores que reproduzem as condições do reservatório e do sistema de superfície. O uso dos simuladores pode ser substituído por um aproximador, que neste trabalho, é um modelo que utiliza Redes Neurais Artificiais. Os aproximadores aqui apresentados são feitos para substituir a simulação integrada do reservatório, do poço e da superfície (linhas de produção e riser). As amostras para a construção do aproximador é feita utilizando os simuladores de reservatório e de superfície e para reduzir o número de amostras necessárias e tornar sua construção mais rápida, utiliza-se Hipercubo Latino e Análise de Componentes Principais. Os aproximadores foram testados em dois reservatórios petrolíferos: um reservatório sintético, e baseado em um caso real. Os resultados encontrados indicam que estes aproximadores conseguem bom desempenho na substituição dos simuladores no processo de otimização devido aos baixos erros encontrados e à substancial PUC-Rio -Certificação Digital Nº 1121522/CA diminuição do custo computacional. The development of an oil reservoir consists in finding an alternative of wells that contributes to maximizing the revenue to be obtained from the recovered reservoir oil. The pursuit for this alternative is often based on optimization processes using the net present value (NPV) of the project as the evaluation function of the alternatives found during this pursuit. Among other variables, the NPV calculation is directly dependent on the oil, gas and water production data during the productive life of the reservoir, as well as their development costs. Determine the number, location, type (producer or injector) and the trajectory of wells in a res...

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Application of IPM Modeling for Production Surveillance, Allocation and Optimization

Orioha¹,

Gruba²,

Muoneke

et al. 2012

All Days

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In order to make effective decisions for oil field management, well and reservoir surveillance data needs to be utilized to better understand how the subsurface and surface systems in a field interact. This can be done at the reservoir, well and surface facility level, but is most effective when considering the entire production or injection system. IPM (Integrated Production Modeling) is now being used more often and, has demonstrated its usefulness in many oil and gas field applications. The use of integrated production modeling methodologies for improving production, identifying and eliminating bottlenecks and improving production allocation for wells from multiple reservoirs from both onshore and offshore oil fields are presented. Methods for coupling the surface and subsurface are reviewed and its usefulness for identifying bottlenecks at both the well and surface facility level are demonstrated. Field examples are presented where issues were identified and overcome by operational means and, found to increase production. Prioritization of wells and production intervals can also be incorporated to improve production/system uptime and field life. The use of artificial lift for oil wells and additional compression for gas wells can be effectively modeled by reasonably calibrated IPM models. Without proper calibration, these models can yield results that lead to inadequate decisions that have a significant impact on project economics. The use of IPM models as a tool to better allocate field production data has proved to be very reliable and has resulted in better field management. This approach requires both reservoir and surface facility information gathered on a regular basis in order to be reliable and accurate. Reservoir, well and surface models require occasional calibration or updates of inflow type curves. Application of these methods are discussed and presented for some field cases for oil reservoirs some under waterflood and others with active water drive.

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Using Integrated Production Modeling (IPM) as an Optimization Tool for Field Development Planning and Management

Cited by 18 publications

References 2 publications

Optimisation of Artificial Lifts Using Prosper Nodal Analysis for BARBRA-1 Well in Niger Delta

Optimisation of Artificial Lifts Using Prosper Nodal Analysis for BARBRA-1 Well in Niger Delta

Redes Neurais Aplicadas À Construção De Aproximadores Para Simulação Integrada Entre Reservatório E Sistema De Produção

Application of IPM Modeling for Production Surveillance, Allocation and Optimization

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