An Innovative Modelling Approach in Characterization of Autonomous Inflow Control Valve Performance to Maximizing Oil Recovery in Heavy Oil-SAGD Application

2021 ◽  
Author(s):  
Ismarullizam Mohd Ismail ◽  
Vidar Mathiesen ◽  
Anson Abraham ◽  
Ehsan Ranjbar ◽  
Faraj Zarei ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Reservoir Simulation ◽  
Computer Modelling ◽  
Control Valve ◽  
Thermal Recovery ◽  
Hydrocarbon Production ◽  
Pressure Drops ◽  
Simulation Tools ◽  
Flow Control Devices ◽  
Production Wells

Abstract Flow control devices (FCDs) have demonstrated significant potential in improving recovery from Steam Assisted Gravity Drainage (SAGD) production wells. Passive FCDs will allow the SAGD producer well to create additional pressure drop to balance the production influx, improving overall conformance and promoting accelerated hydrocarbon production. However, passive FCDs cannot effectively restrict steam effluents once steam breakthrough at the production well occurs. The Autonomous Inflow Control Valve (AICV) actively delivers a dynamic flow restriction with the ability to choke and/or ‘shut-off’ in response to the associated viscosity and density of the fluids flowing through the AICV. This novel AICV design behaves truly autonomously based on the Hagen-Poiseuille equation and Bernoulli’s principle. The AICV utilizes the differences in flow behaviour between the laminar and turbulent flow restrictions to differentiate the pressure-drops between oil, water, gas, and steam phases. A collaborative effort has been initiated between the AICV vendor and the Computer Modelling Group to develop reservoir simulation workflows with the AICV that will allow the user to enter characteristic performance curves for a variety of SAGD and thermal fields. The development of mechanistic wellbore modelling and developed methodology to incorporate the associated complexities of AICV behaviour has shown to be an improvement to the way FCDs are currently modelled, providing insight into the potential for AICV application in SAGD and other thermal recovery operations. Such techniques allow the reservoir simulation tools to perform realistic predictions of the AICV behaviour at downhole conditions and evaluate scenarios and relative impacts of completion designs. The development of a new characterization method of AICV performance in SAGD applications, and its implementation in reservoir simulation tools, has helped to unveil the benefits of implementing AICVs in improving recovery from SAGD operations.

scholarly journals A semi-implicit approach for the modeling of wells with inflow control completions

2020 ◽  
Vol 75 ◽  
pp. 39
Author(s):  
Eric Flauraud ◽  
Didier Yu Ding
Keyword(s):  
Oil Recovery ◽  
Reservoir Simulation ◽  
Flow Model ◽  
New Technologies ◽  
Control Valve ◽  
Simulation Models ◽  
Control Device ◽  
Fully Implicit ◽  
Implicit Approach ◽  
Reservoir Simulator

In the last two decades, new technologies have been introduced to equip wells with intelligent completions such as Inflow Control Device (ICD) or Inflow Control Valve (ICV) in order to optimize the oil recovery by reducing the undesirable production of gas and water. To optimally define the locations of the packers and the characteristics of the valves, efficient reservoir simulation models are required. This paper is aimed at presenting the specific developments introduced in a multipurpose industrial reservoir simulator to simulate such wells equipped with intelligent completions taking into account the pressure drop and multiphase flow. An explicit coupling or decoupling of a reservoir model and a well flow model with intelligent completion makes usually unstable and non-convergent results, and a fully implicit coupling is CPU time consuming and difficult to be implemented. This paper presents therefore a semi-implicit approach, which links on one side to the reservoir simulation model and on the other side to the well flow model, to integrate ICD and ICV.

Reservoir and Wellbore Flow Coupling Model for Fishbone Multilateral Wells in Bottom Water Drive Reservoirs

2021 ◽  
pp. 1-27
Author(s):  
ping Yue ◽  
Jiantang Zhou ◽  
Li Xia Kang ◽  
Ping Liu ◽  
Jia Chunsheng ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Bottom Water ◽  
Water Reservoir ◽  
Pressure Profile ◽  
Coupling Model ◽  
New Model ◽  
Flow Coupling ◽  
Field Situation ◽  
Production Wells ◽  
Actual Field

Abstract Nowadays, different types of complex production wells are applied in challenging reservoirs in order to maximize oil recovery. A representative application is the fishbone multilateral horizontal wells, which have advantages of expanding the drainage area information and reducing the pressure loss in the long single lateral wellbore. This paper investigated the performance of fishbone wells and derived a wellbore and reservoir flow coupling model for fishbone multilateral wells in the bottom water reservoirs. The new model considered plenty of parameters that may have significant impacts on productivity and pressure drop in the well, including the fishbone structure, the main and branch wellbores' length, the spacing distance of the branch wellbores, wellbore radius, and preformation parameters. Furthermore, a sensitivity analysis example by the numerical method presented in this paper. Compared with other models, our coupling model, when it is degraded to horizontal well, is more consistent with the results of actual field situation. In another comparative analysis, the results of the new model with branches show a good match with the numerical simulation results by software. The proposed method in this paper can be used as a valuable tool to analyze the productivity, wellbore inflow profile, and pressure profile of the fishbone multilateral wells in the bottom water reservoir.

A Superior Shale Oil EOR Method for the Permian Basin

2021 ◽  
Author(s):  
Robert Downey ◽  
Kiran Venepalli ◽  
Jim Erdle ◽  
Morgan Whitelock
Keyword(s):  
Oil Recovery ◽  
Reservoir Simulation ◽  
Simulation Modeling ◽  
Lower Cost ◽  
Oil Production ◽  
Oil Wells ◽  
Oil Well ◽  
Shale Oil ◽  
Permian Basin ◽  
Artificial Lift

Abstract The Permian Basin of west Texas is the largest and most prolific shale oil producing basin in the United States. Oil production from horizontal shale oil wells in the Permian Basin has grown from 5,000 BOPD in February, 2009 to 3.5 Million BOPD as of October, 2020, with 29,000 horizontal shale oil wells in production. The primary target for this horizontal shale oil development is the Wolfcamp shale. Oil production from these wells is characterized by high initial rates and steep declines. A few producers have begun testing EOR processes, specifically natural gas cyclic injection, or "Huff and Puff", with little information provided to date. Our objective is to introduce a novel EOR process that can greatly increase the production and recovery of oil from shale oil reservoirs, while reducing the cost per barrel of recovered oil. A superior shale oil EOR method is proposed that utilizes a triplex pump to inject a solvent liquid into the shale oil reservoir, and an efficient method to recover the injectant at the surface, for storage and reinjection. The process is designed and integrated during operation using compositional reservoir simulation in order to optimize oil recovery. Compositional simulation modeling of a Wolfcamp D horizontal producing oil well was conducted to obtain a history match on oil, gas, and water production. The matched model was then utilized to evaluate the shale oil EOR method under a variety of operating conditions. The modeling indicates that for this particular well, incremental oil production of 500% over primary EUR may be achieved in the first five years of EOR operation, and more than 700% over primary EUR after 10 years. The method, which is patented, has numerous advantages over cyclic gas injection, such as much greater oil recovery, much better economics/lower cost per barrel, lower risk of interwell communication, use of far less horsepower and fuel, shorter injection time, longer production time, smaller injection volumes, scalability, faster implementation, precludes the need for artificial lift, elimination of the need to buy and sell injectant during each cycle, ability to optimize each cycle by integration with compositional reservoir simulation modeling, and lower emissions. This superior shale oil EOR method has been modeled in the five major US shale oil plays, indicating large incremental oil recovery potential. The method is now being field tested to confirm reservoir simulation modeling projections. If implemented early in the life of a shale oil well, its application can slow the production decline rate, recover far more oil earlier and at lower cost, and extend the life of the well by several years, while precluding the need for artificial lift.

scholarly journals THE DEVICE WELLHEAD CONTROL VALVE FOR GAS PRODUCTION WELLS

2019 ◽  
pp. 119-123
Author(s):  
S. V. Marfitsyn ◽  
А. V. Marfitsyn ◽  
V. P. Marfitsyn
Keyword(s):  
Control Valve ◽  
Gas Production ◽  
Production Wells

scholarly journals Skenario Pengembangan Untuk Meningkatkan Recovery Factor Pada Lapangan TR Lapisan X Dengan Menggunakan Simulasi Reservoir

PETRO ◽  
2018 ◽  
Vol 4 (4) ◽  
Author(s):  
Muhamad Taufan Azhari
Keyword(s):  
Reservoir Simulation ◽  
History Matching ◽  
Control Volume ◽  
Base Case ◽  
Case Scenario ◽  
Injection Wells ◽  
Base Case Scenario ◽  
Development Scenarios ◽  
Production Wells ◽  
Grid Construction

<p>Reservoir simulation is an area of reservoir engineering in which computer models are used to predict the flow of fluids through porous media. Reservoir simulation process starts with several steps; data preparation, model and grid construction, initialization, history matching and prediction. Initialization process is done for matching OOIP or total initial hydrocarbon which fill reservoir with hydrocarbon control volume with volumetric method.</p><p>To aim the best encouraging optimum data, these development scenarios of TR Field Layer X will be predicted for 30 years (from 2014 until January 2044). Development scenarios in this study consist of 4 scenarios : Scenario 1 (Base Case), Scenario 2 (Base Case + Reopening non-active wells), Scenario 3 (scenario 2 + infill production wells), Scenario 4 (Scenario 2 + 5 spot pattern of infill injection wells).</p>

Influence of Pipeline Inclination on Hydraulic Conveying of Sand Particles

2012 ◽  
Author(s):  
Ahmed Mohamed Nossair ◽  
Peter Rodgers ◽  
Afshin Goharzadeh
Keyword(s):  
Particle Transport ◽  
High Speed ◽  
Sand Dune ◽  
Sand Particle ◽  
Hydrocarbon Production ◽  
Production Wells ◽  
Load Transport ◽  
Bed Load Transport ◽  
Sand Particles ◽  
Dune Dynamics

The understanding of sand particle transport by fluids in pipelines is of importance for the drilling of horizontal and inclined hydrocarbon production wells, topside process facilities, infield pipelines, and trunk lines. Previous studies on hydraulic conveying of sand particles in pipelines have made significant contributions to the understanding of multiphase flow patterns, pressure drop and particle transport rate in horizontal pipelines. However, due to the complexity of the flow structure resulting from liquid-sand interactions, the mechanisms responsible for bed-load transport flow for hydraulic conveying of sand particles have not been extensively studied in inclined pipelines. This paper presents an experimental investigation of hydraulic conveying of sand particles resulting from a stationary flat bed in both horizontal and +3.6 degree upward inclined pipelines. The characteristics of sand transportation by saltation from an initial sand bed are experimentally visualized using a transparent Plexiglas pipeline and high-speed digital photography. The dune formation process is assessed as a function of pipeline orientation. Based on the visualized dune morphology, pipeline inclination is found to have a significant influence on hydraulic conveying of sand dune dynamics (i.e., dune velocity), as well as sand dune geometry (i.e., dune pitch and characteristic dune angles).

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