Application of the Multiphase Flow Simulator to Evaluate Power Allocation Management for ESPs

2016 ◽  
Author(s):  
M. Ali ◽  
L. C. Enriquez Cisneros ◽  
R. A. Fraga Figueroa ◽  
T. Graham Tonkin ◽  
E. Hasanov ◽  
...  
Keyword(s):  
Multiphase Flow ◽  
Power Allocation ◽  
Flow Simulator

Assessment of Chemical Injection to Mitigate Wax Deposition in Unconventional Wells

2021 ◽  
Author(s):  
Rafael M. D. Rosa ◽  
Arthur B. Soprana ◽  
Vinicius Girardi ◽  
Fernando M. Villagra
Keyword(s):  
Boundary Conditions ◽  
Multiphase Flow ◽  
Cfd Simulation ◽  
Simulated Data ◽  
Wax Deposition ◽  
Operational Conditions ◽  
Numerical Assessment ◽  
Minimum Depth ◽  
Flow Simulator ◽  
Environmental Temperatures

Abstract This work presents a numerical assessment of chemical inhibitor injection to mitigate wax deposition in unconventional wells. The goal of this study is to simulate the deposition of wax under several operational conditions and later optimize the chemical inhibitor injection position, using two different types of numerical simulations. A transient one-dimensional multiphase flow simulator - ALFAsim, with a dedicated wax model, was used to predict flow conditions such pressure, temperature, holdup and flow pattern profiles, as well the position and rates that wax accumulates. The results from the 1D simulation were then used as boundary conditions in a 3D CFD simulator, which aimed to assess how long it would take to a satisfactory homogenization of the inhibitor with the flow and what would be the minimum depth for the injector should be installed. In this work, a 1D multiphase flow simulator with wax deposition model was used to identify on which operational conditions (flow rates and environmental temperatures) an unconventional well would start to present wax deposition on its tubing walls. After defining the susceptible region where the paraffin could deposit, it was important to verify if the inhibitor would be well homogenized with the stream when reaching this region. For that, a 3D CFD simulation was performed, using information obtained directly from the 1D simulator as boundary conditions. The CFD model was capable to show the mixing evolution of the inhibitor with the stream and it was possible to determine the minimum distance where the injector should be placed to guarantee such homogeneity. A real well was selected to provide comparisons between field observations and simulated data, in order to validate the model assumptions and accuracy.

Modelling Complex Well Behaviour in the Field Using a Transient Multiphase Flow Simulator (Russian)

2018 ◽  
Author(s):  
Kanat Karatayev ◽  
Beibit Bissakayev ◽  
Tamer Saada ◽  
Benjamin Madeley ◽  
Alberto Brancolini ◽  
...  
Keyword(s):  
Multiphase Flow ◽  
Flow Simulator ◽  
Transient Multiphase Flow ◽  
Complex Well

Modelling Complex Well Behaviour in the Field Using a Transient Multiphase Flow Simulator

2018 ◽  
Author(s):  
Kanat Karatayev ◽  
Beibit Bissakayev ◽  
Tamer Saada ◽  
Benjamin Madeley ◽  
Alberto Brancolini ◽  
...  
Keyword(s):  
Multiphase Flow ◽  
Flow Simulator ◽  
Transient Multiphase Flow ◽  
Complex Well

Derivative-free parameter tuning for a well multiphase flow simulator

2020 ◽  
Vol 192 ◽  
pp. 107288 ◽  
Author(s):  
Laio Oriel Seman ◽  
Luis Kin Miyatake ◽  
Eduardo Camponogara ◽  
Caio Merlini Giuliani ◽  
Bruno Ferreira Vieira
Keyword(s):  
Multiphase Flow ◽  
Free Parameter ◽  
Parameter Tuning ◽  
Derivative Free ◽  
Flow Simulator

Optimizing Production Facilities Using a Transient Multiphase Flow Simulator

2019 ◽  
Author(s):  
Abdulaziz S. Al-Qasim ◽  
Fahad Almudairis ◽  
Abdulrahman Bin Omar ◽  
Abdullatif Omair
Keyword(s):  
Multiphase Flow ◽  
Oil And Gas ◽  
Gas Production ◽  
Oil Field ◽  
Flow Assurance ◽  
Field Development ◽  
Wide Range ◽  
Flow Simulator ◽  
Transient Multiphase Flow ◽  
Production Facilities

Abstract This paper discusses a method for optimizing production facilities design for onshore/offshore wells during new field development. Optimizing the development of new oil and gas fields necessitates the use of accurate predication techniques to minimize uncertainties associated with day-to-day operational challenges related to wells, pipelines and surface facilities. It involves the use of a transient multiphase flow simulator (TMFS) for designing new oil and gas production systems to determine the feasibility of its economic development. A synthetic offshore oil field that covers a wide range of subsurface and surface facility data is considered in this paper. 32 wells and two reservoirs are considered to evaluate the effect of varying sizes of tubing, wellhead choke, flowline, riser, and transport line. A detailed investigation of the scenario of emergency shutdowns to study its effect on the system is performed using TMFS. Other scenarios are also evaluated such as startup, depressurization, pigging, wax deposition, and hydrate formation. This paper provides a method to minimize the cost by selecting the optimum pipelines sizes and diameters, and investigating the requirements of insulation, risk of pipeline corrosions and other related flow assurance parameters. Different facility design scenarios are considered using TMFS tool to achieve operational flexibility and eliminate associated risks. Pressure and temperature conditions are evaluated under several parametric scenarios to determine the best dimensions of the production system. This paper will also provide insight into factors affecting the flow assurance of oil and gas reservoirs.

Significance of Geochemistry in Single-Well Chemical-Tracer Tests by Coupling a Multiphase-Flow Simulator to the Geochemical Package

SPE Journal ◽  
2018 ◽  
Vol 23 (04) ◽  
pp. 1126-1144 ◽  
Author(s):  
Rasoul Khaledialidusti ◽  
Jon Kleppe
Keyword(s):  
Multiphase Flow ◽  
Test Data ◽  
Reaction Rate ◽  
Hydrolysis Reaction ◽  
Hydrolysis Rate ◽  
Ph Variation ◽  
Chemical Tracer ◽  
Ph Dependency ◽  
Single Well ◽  
Flow Simulator

Summary Single-well chemical tracer (SWCT) is the most commonly used field method to determine oil or water saturation in one-well enhanced-oil-recovery (EOR) pilots. Because hydrolysis of an ester, which is the main part of the method, leads to forming acid as well as alcohol, the equilibrium state of the reservoir is disturbed, and thus the pH changes. It is generally accepted that the hydrolysis-reaction rate is mainly dependent on the pH and temperature. Therefore, it is required to know the extent to which this dependency might affect the shape of the product-tracer profiles and the numerical interpretation of the field-test data for computing residual oil saturation (Sor). In this study, this notion has been investigated by coupling a multiphase-flow simulator to the geochemistry package PHREEQC (Parkhust and Appelo 2013). In this study, the PHREEQC geochemical simulator has been used to illustrate the extent to which different parameters might affect the pH variation during the test. The PHREEQC database has been modified to take the ester-hydrolysis reaction into account by adding the ester, alcohol, and acid-product species. The hydrolysis-reaction mechanisms of ester have also been programmed to account for the dependency of the hydrolysis reaction on the pH. Also, because ester partitions into the oil phase and travels behind the water phase (i.e., Darcy velocity), performing two-phase flow would be necessary to highlight the significance of the pH dependency of the hydrolysis-reaction rate on the tracer profiles. For doing that, a multiphase Buckley-Leverett (BL) flow simulation is coupled with IPhreeqc, which is an open-source module of the PHREEQC geochemical package. Then, a California Turbidite SWCT test has been re-evaluated to verify the approach. At the end, the geochemistry of a reservoir with an almost weak resistance (high temperature and weak buffer capacity) against pH variation in the SWCT test has been studied using the geochemical-based approach. The results show that the variation of the hydrolysis rate with pH could affect mainly the tail edge of the predicted tracer profiles, and it could marginally affect the apex of the profiles; however, it might affect the interpreted value of the Sor measurement as the resistance against pH variation becomes weaker. In these conditions, adapting the SWCT-test designs (i.e., shut-in time and injecting lower concentration of ester) could diminish the pH variation. The pH dependency of the hydrolysis-reaction rate is recommended for the numerical interpretation of the field SWCT-test data. The results of this study can be used to minimize the uncertainties of the SWCT tests and to improve the reliability of the Sor measurements.

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