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.

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.

Challenges from Well Shut-in Amid the Oil Downturn: Long Term Impacts on Near Wellbore Skin Buildup and Sand Control

2021 ◽  
Author(s):  
Mohammad Soroush ◽  
Mahdi Mahmoudi ◽  
Morteza Roostaei ◽  
Hossein Izadi ◽  
Seyed Abolhassan Hosseini ◽  
...  
Keyword(s):  
Hot Spot ◽  
Oil Production ◽  
Well Performance ◽  
Well Completion ◽  
Flow Control Devices ◽  
Sand Control ◽  
Control Devices ◽  
Inflow Problem ◽  
The Impact

Abstract In wake of the biggest oil crash in history triggered by the COVID-19 pandemic; Western Canada in- situ production is under tremendous price pressure. Therefore, the operators may consider shut in the wells. Current investigation offers an insight into the effect of near-wellbore skin buildup because of such shut-in. A series of simulation studies was performed to quantitatively address the impact of well shut-in on the long-term performance of well, in particular on key performance indicators of the well including cumulative steam to oil ratio and cumulative oil production. The long-term shut-in contributes to three main modes of plugging: (1) near-wellbore pore plugging by clays and fines, (2) scaling, and (3) chemical consolidation induced by corrosion. A series of carefully designed simulations was also utilized to understand the potential of skin buildup in the near-wellbore region and within different sand control devices. The simulation results showed a higher sensitivity of well performance to shut-in for the wells in the initial stage of SAGD production. If the well is shut in during the first years, the total reduction in cumulative oil production is much higher compared to a well which is shut-in during late SAGD production life. As the induced skin due to shut-in increases, the ultimate cumulative oil production drops whose magnitude depends on well completion designs. The highest effect on the cumulative oil production is in the case of completion designs with flow control devices (liner deployed and tubing deployed completions). Therefore, wellbore hydraulics and completion design play key roles in the maintenance of uniform inflow profile, and the skin buildup due to shut-in poses a high risk of inflow problem and increases the risk of hot-spot development and steam breakthrough. This investigation offers a new understanding concerning the effect of shut-in and wellbore skin buildup on SAGD operation. It helps production and completion engineers to better understand and select candidate wells for shut-in and subsequently to minimize the skin buildup in wells.

Improving reservoir performance using intelligent well completion sensors combined with surface wet-gas flow measurement

2012 ◽  
Vol 52 (1) ◽  
pp. 181
Author(s):  
Nematollah Tarom ◽  
Mofazzal Hossain
Keyword(s):  
Data Acquisition ◽  
Gas Flow ◽  
Reservoir Management ◽  
Production Performance ◽  
Well Performance ◽  
Reservoir Performance ◽  
Well Completion ◽  
Wet Gas ◽  
Wellbore Pressure ◽  
Reservoir Conditions

Reservoir performance, in addition to day-to-day well performance, needs to be evaluated during the life of a well. The production logging tool (PLT) is conventionally designed to provide a full set of data measurements in producing wells to evaluate well and reservoir performance. Depending on the well conditions and location, running conventional PLTs may be difficult, impossible or expensive. Therefore, an alternative approach that can be applied in lieu of PLT operations—to obtain information similar to PLTs for better reservoir management—and that can optimise reservoir production performance is desireable. Data acquisition techniques such as downhole pressure/temperature gauges, fibre optic sensors at reservoir conditions and wet-gas flow meters at the surface have been considered as a viable alternative. Such data acquisition techniques help to increase flexibility in the field development and reservoir management of problematic wells with well completion technologies such as multi-lateral, horizontal and artificial lift. This study focused on the development of an alternative method of analysing problem well data on the basis of downhole pressure and temperature data collected at reservoir conditions. The proposed model has been based on the Joule-Thomson effect and radial heat and fluid flow equations to solve the transient wellbore pressure and temperature equations. It is expected this model can be used to analyse intelligent wells completed with downhole pressure and temperature sensors, and facilitate the monitoring of wells and reservoir performance without any PLT operation, especially for complex fields.

NEAR-WELLBORE SIMULATION OF AUTONOMOUS INFLOW CONTROL DEVICES COMPLETION: COMPARING COMPUTATIONAL FLUID DYNAMICS WITH CONVENTIONAL RESERVOIR SIMULATION

2020 ◽  
Vol 32 (2) ◽  
pp. 93-112
Author(s):  
Rodrigo Peralta Muniz Moreira ◽  
Vinicius Girardi ◽  
Karolline Ropelato ◽  
Lars Kollbotn ◽  
Ying Guo ◽  
...  
Keyword(s):  
Fluid Dynamics ◽  
Computational Fluid Dynamics ◽  
Reservoir Simulation ◽  
Control Devices

A Mid-Jurassic Carbonate Reservoir Case Study, Offshore Qatar: How to Capture High Permeable Streaks in a 3D Reservoir Model

2009 ◽  
Author(s):  
Agus Sudarsana ◽  
Mariem Abdelouahab ◽  
Robert Chanpong ◽  
Vance I. Fryer ◽  
Jonathan Hall ◽  
...  
Keyword(s):  
Carbonate Reservoir ◽  
Reservoir Model

scholarly journals Scoping Review of Thermal Comfort Research in Colombia

Buildings ◽  
2021 ◽  
Vol 11 (6) ◽  
pp. 232
Author(s):  
Juan Manuel Medina ◽  
Carolina M. Rodriguez ◽  
Maria Camila Coronado ◽  
Lina Maria Garcia
Keyword(s):  
Thermal Comfort ◽  
Scoping Review ◽  
Architectural Design ◽  
Urban Climate ◽  
Academic Community ◽  
Additional Information ◽  
The Future ◽  
Art Research ◽  
Occupant Satisfaction

The analysis of thermal comfort in buildings, energy consumption, and occupant satisfaction is crucial to influencing the architectural design methodologies of the future. However, research in these fields in developing countries is sectorised. Most times, the standards to study and assess thermal comfort such as ASHRAE Standard 55, EN 15251, and ISO 7730 are insufficient and not appropriate for the geographical areas of application. This article presents a scoping review of published work in Colombia, as a representative case study, to highlight the state-of-the-art, research trends, gaps, and potential areas for further development. It examines the amount, origin, extent, and content of research and peer-reviewed documentation over the last decades. The findings allow new insights regarding the preferred models and the evaluation tools that have been used to date and that are recommended to use in the future. It also includes additional information regarding the most and least studied regions, cities, and climates in the country. This work could be of interest for the academic community and policymakers in the areas related to indoor and urban climate management and energy efficiency.

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