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

2010 ◽  
Author(s):  
E.A. Ageh ◽  
A. Adegoke ◽  
O.J. Uzoh
Keyword(s):  
Development Planning ◽  
Integrated Production ◽  
Field Development ◽  
Planning And Management ◽  
Production Modeling

Use of Integrated Production Modeling to Estimate the Influence of Subsea Manifolds in Reservoir Production Management

2018 ◽  
Author(s):  
Igor Ricardo de Souza Victorino ◽  
João Carlos von Hohendorff Filho ◽  
Marcelo Souza de Castro ◽  
Denis José Schiozer
Keyword(s):  
Production System ◽  
Production Management ◽  
Integrated Analysis ◽  
Financial Return ◽  
Integrated Production ◽  
Optimization Of Parameters ◽  
Field Development ◽  
Improve Production ◽  
Field Management ◽  
Production Modeling

Integrated analysis of reservoir and production system models for field development can improve production forecasts. This integration allows the evaluation and optimization of parameters of both systems for both financial return and accurate production prediction. This work evaluates the presence and position of manifolds and their influence on production. We use a Brazilian benchmark case to perform an integrated analysis of oilfield production evaluating the influence of various aspects of manifold systems to increase financial return. The results showed that integrated analysis of optimized manifold locations and the number of connected wells improved financial return. Thus, we recommend the inclusion of this integrated production modeling in field management.

scholarly journals Incremental and acceleration production estimation and their effect on optimization of well infill locations in tight gas reservoirs

2021 ◽  
Author(s):  
Atheer Dheyauldeen ◽  
Omar Al-Fatlawi ◽  
Md Mofazzal Hossain
Keyword(s):  
Transient Flow ◽  
Development Planning ◽  
Main Role ◽  
Gas Reservoirs ◽  
Type Curves ◽  
Field Development ◽  
Drilling Performance ◽  
Well Location ◽  
Infill Drilling ◽  
Tight Formations

AbstractThe main role of infill drilling is either adding incremental reserves to the already existing one by intersecting newly undrained (virgin) regions or accelerating the production from currently depleted areas. Accelerating reserves from increasing drainage in tight formations can be beneficial considering the time value of money and the cost of additional wells. However, the maximum benefit can be realized when infill wells produce mostly incremental recoveries (recoveries from virgin formations). Therefore, the prediction of incremental and accelerated recovery is crucial in field development planning as it helps in the optimization of infill wells with the assurance of long-term economic sustainability of the project. Several approaches are presented in literatures to determine incremental and acceleration recovery and areas for infill drilling. However, the majority of these methods require huge and expensive data; and very time-consuming simulation studies. In this study, two qualitative techniques are proposed for the estimation of incremental and accelerated recovery based upon readily available production data. In the first technique, acceleration and incremental recovery, and thus infill drilling, are predicted from the trend of the cumulative production (Gp) versus square root time function. This approach is more applicable for tight formations considering the long period of transient linear flow. The second technique is based on multi-well Blasingame type curves analysis. This technique appears to best be applied when the production of parent wells reaches the boundary dominated flow (BDF) region before the production start of the successive infill wells. These techniques are important in field development planning as the flow regimes in tight formations change gradually from transient flow (early times) to BDF (late times) as the production continues. Despite different approaches/methods, the field case studies demonstrate that the accurate framework for strategic well planning including prediction of optimum well location is very critical, especially for the realization of the commercial benefit (i.e., increasing and accelerating of reserve or assets) from infilled drilling campaign. Also, the proposed framework and findings of this study provide new insight into infilled drilling campaigns including the importance of better evaluation of infill drilling performance in tight formations, which eventually assist on informed decisions process regarding future development plans.

Integrated Production Model as a Tool for Optimization the Development Strategy of the Sakhalin Oil and Gas Condensate Field

2021 ◽  
Author(s):  
Oleksandr Doroshenko ◽  
Miljenko Cimic ◽  
Nicholas Singh ◽  
Yevhen Machuzhak
Keyword(s):  
History Matching ◽  
Effective Field ◽  
Production Optimization ◽  
Production Model ◽  
Production Forecast ◽  
Hydrocarbon Production ◽  
Integrated Production ◽  
Wellhead Pressure ◽  
Field Development ◽  
The Impact

Abstract A fully integrated production model (IPM) has been implemented in the Sakhalin field to optimize hydrocarbons production and carried out effective field development. To achieve our goal in optimizing production, a strategy has been accurately executed to align the surface facilities upgrade with the production forecast. The main challenges to achieving the goal, that we have faced were:All facilities were designed for early production stage in late 1980's, and as the asset outdated the pipeline sizes, routing and compression strategies needs review.Detecting, predicting and reducing liquid loading is required so that the operator can proactively control the hydrocarbon production process.No integrated asset model exists to date. The most significant engineering tasks were solved by creating models of reservoirs, wells and surface network facility, and after history matching and connecting all the elements of the model into a single environment, it has been used for the different production forecast scenarios, taking into account the impact of infrastructure bottlenecks on production of each well. This paper describes in detail methodology applied to calculate optimal well control, wellhead pressure, pressure at the inlet of the booster compressor, as well as for improving surface flowlines capacity. Using the model, we determined the compressor capacity required for the next more than ten years and assessed the impact of pipeline upgrades on oil gas and condensate production. Using optimization algorithms, a realistic scenario was set and used as a basis for maximizing hydrocarbon production. Integrated production model (IPM) and production optimization provided to us several development scenarios to achieve target production at the lowest cost by eliminating infrastructure constraints.

Gas Lift Optimization Using Artificial Neural Network and Integrated Production Modeling

2017 ◽  
Vol 31 (9) ◽  
pp. 9302-9307 ◽  
Author(s):  
Eissa Mohamed El-M. Shokir ◽  
Mazen M. B. Hamed ◽  
Azza El-S. B. Ibrahim ◽  
Ismail Mahgoub
Keyword(s):  
Neural Network ◽  
Artificial Neural Network ◽  
Integrated Production ◽  
Artificial Neural ◽  
Production Modeling ◽  
Gas Lift

Artificial Lift Strategy Selection Within Field Development Planning (Russian)

2015 ◽  
Author(s):  
A. V. Alferov ◽  
A. G. Lutfurakhmanov ◽  
K. V. Litvinenko ◽  
S. E. Zdolnik
Keyword(s):  
Development Planning ◽  
Strategy Selection ◽  
Field Development ◽  
Artificial Lift
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