Coupled Completion and Reservoir Simulation Technology for Well Performance Optimization

2009 ◽  
Author(s):  
Marcel A. Grubert ◽  
Jing Wan ◽  
Sarta S. Ghai ◽  
Silviu Livescu ◽  
William B. Brown ◽  
...  
Keyword(s):  
Reservoir Simulation ◽  
Performance Optimization ◽  
Well Performance ◽  
Simulation Technology

Coupled Completion and Reservoir Simulation Technology for Well Performance Optimization

2009 ◽  
Author(s):  
Marcel A. Grubert ◽  
Jing Wan ◽  
Sartaj S. Ghai ◽  
Silviu Livescu ◽  
William P. Brown ◽  
...  
Keyword(s):  
Reservoir Simulation ◽  
Performance Optimization ◽  
Well Performance ◽  
Simulation Technology

Advances in Parallel Reservoir Simulation Technology, Using Multi-Threaded Algorithms

2018 ◽  
Author(s):  
Sina Mohajeri ◽  
Reza Eslahi ◽  
Maryam Bakhtiari ◽  
Mostafa Zeinali ◽  
Hamed Rajabi ◽  
...  
Keyword(s):  
Reservoir Simulation ◽  
Simulation Technology

Linear Solver Performance Optimization in Reservoir Simulation Studies

2009 ◽  
Author(s):  
Ilya D. Mishev ◽  
Bret Loneil Beckner ◽  
Serge A. Terekhov ◽  
Nelli Fedorova
Keyword(s):  
Reservoir Simulation ◽  
Performance Optimization ◽  
Simulation Studies ◽  
Linear Solver ◽  
Solver Performance

Improvement of the well performance optimization methodology based on integrated modeling (Russian)

2015 ◽  
Author(s):  
S. M. Bikbulatov ◽  
D. S. Vorobyev ◽  
A. Y. Smirnov ◽  
I. R. Mukminiov ◽  
S. V. Romashkin
Keyword(s):  
Performance Optimization ◽  
Integrated Modeling ◽  
Well Performance ◽  
Optimization Methodology

scholarly journals Assessing the Needs to Incorporate Completion Details in a Petroleum Reservoir Simulation Model

2015 ◽  
Vol 8 (1) ◽  
pp. 16-28 ◽  
Author(s):  
Liang-Biao Ouyang
Keyword(s):  
Fluid Flow ◽  
Simulation Model ◽  
Simulation Study ◽  
Reservoir Simulation ◽  
High Rate ◽  
Petroleum Reservoir ◽  
Well Performance ◽  
Well Completion ◽  
Reservoir Permeability ◽  
Reservoir Simulation Model

Most of the current research and commercial reservoir simulators lack the capability to handle complex completion details like perforation tunnels in a simulation study. In most common applications, the simplified handling of completion complexity in reservoir simulations is not expected to introduce significant error in simulation results. However, it has been found that under certain circumstances, especially in high rate wells that have become more and more common in deepwater oil and profilic gas development, exclusion of the complex completion details in a reservoir simulation model would lead to nontrivial errors. New equations have been proposed to assess the needs to incorporate completion details in a reservoir simulation study based on the understanding of the fluid flow in a formation, the fluid flow along a wellbore and the fluid flow through perforation tunnels if exist. A series of sensitivity studies with different completion options under different flow and reservoir environments has been conducted to provide some guidance to improve well performance prediction through reservoir simulation. Impacts of key parameters like perforation density, perforation diameter, perforation length, wellbore length, borehole diameter, well completion configuration, well placement, reservoir permeability, reservoir heterogeneity, pressure drawdown, etc, have also been investigated.

scholarly journals A Study of Pressure Gradient in Multiphase Flow in Vertical Pipes

2019 ◽  
Vol 4 (1) ◽  
pp. 54-59
Author(s):  
David Nwobisi Wordu ◽  
Felix J. K. Ideriah ◽  
Barinyima Nkoi
Keyword(s):  
Pressure Drop ◽  
Multiphase Flow ◽  
Pressure Gradient ◽  
Performance Optimization ◽  
Field Data ◽  
Oil And Gas ◽  
Liquid Velocity ◽  
Petroleum Industry ◽  
Well Performance ◽  
Flowing Fluid

The study of multiphase flow in vertical pipes is aimed at effective and accurate design of tubing, surface facilities and well performance optimization for the production of oil and gas in the petroleum industry by developing a better approach for predicting pressure gradient. In this study, field data was analyzed using mathematical model, multiphase flow correlations, statistical model, and computer programming to predict accurately the flow regime, liquid holdup and pressure drop gradient which are important in the optimization of well. A Computer programme was used to prediction pressure drop gradient. Four dimensionless parameters liquid velocity number (Nlv), gas velocity number (Ngv), pipe diameter number (Nd), liquid viscosity number (Nl), were chosen because they represent an integration of the two dominant components that influence pressure drop in pipes. These dominant component are flow channel/media and the flowing fluid. The model was found to give a fit of 100% to the selected data points. Hagedorn & Brown, Griffith &Wallis correlations and model were compared with field data and the overall pressure gradient for a total depth of 10000ft was predicted. The predicted pressure gradient measured was found to be 0.320778psi/ft, Graffith& Wallis gave 0.382649Psi/ft, Hagedorn & Brown gave 0.382649Psi/ft; whereas generated model gave 0.271514Psi/ft. These results indicate that the model equation generated is better and leads to a reasonably accurate prediction of pressure drop gradient according to measured pressure gradient.

Maximizing Asset Value & Field Recovery with Advanced Completion Solutions – A Digital Twin Field Case Study with Multilateral, Intelligent Completion, and AICD Completion Technologies

2021 ◽  
Author(s):  
Noman Shahreyar ◽  
Ben Butler ◽  
Georgina Corona
Keyword(s):  
Reservoir Simulation ◽  
Simulation Software ◽  
Well Performance ◽  
Reservoir Model ◽  
Additional Information ◽  
Well Completion ◽  
Asset Value ◽  
Reservoir Conditions ◽  
Control Devices

Abstract The drilling and completion of multilateral wells continues to expand and advance within the oil industry after three decades of accelerating adoption. The performance of these wells can be increased when integrated with advanced well completion techniques. The addition of intelligent completions (IC) and inflow control devices (ICD/AICD) enhances well performance and improves field recovery. This paper discusses a reservoir simulation case study that evaluates the productive impact these technologies provide when combined with multilateral technology (MLT), and the mechanism by which they achieve it. A reservoir model is devised and simulates under dynamic reservoir conditions the field production of dual lateral and single bore horizontal wells. The simulation is conducted for three separate scenarios where AICD and IC are incrementally implemented. The results are compared across the scenarios and their value quantified. The mechanisms by which estimated ultimate recovery (EUR) is increased will be discussed, including the increase of reservoir contact, drawdown distribution optimization, and the control and delay of water production. The study will provide an overview on the theory behind the technologies. It will also review the workflow used to conduct the study, utilizing a combination of steady state nodal analysis software and dynamic reservoir simulation software. Additional information about the reservoir model, initial and boundary conditions are detailed, to provide insight into reservoir simulation methodology.

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