Application of Genetic-Algorithm-Based Data Reconciliation on Offshore Virtual Flow Metering of Gas-Condensate Field Production

2018 ◽  
Author(s):  
Dan Wang ◽  
Jing Gong ◽  
Di Fan ◽  
Guoyun Shi ◽  
Juheng Yang
Keyword(s):  
Genetic Algorithm ◽  
Flow Rate ◽  
Engineering Application ◽  
Gas Condensate ◽  
Physical Models ◽  
Data Reconciliation ◽  
Production Flow ◽  
Two Phase ◽  
Flow Metering ◽  
Single Well

During present offshore gas-condensate production, flow meters, due to its exceedingly high cost, are being substituted by Virtual Flow Metering (VFM) Technology for monitoring total and single-well flow rates through sensor measurements and physical models. In this work, the inverse problem is solved by Data Reconciliation (DR), minimizing weighted sum of errors with constraints integrating multiple two-phase flow models. The DR problem is solved by Parallel Genetic Algorithm, without complex calculations required by conventional optimization. The newly developed VFM method is tested by data from a realistic gas-condensate production system. The results show good accuracy for the total mass flow rate with model calibration. Meanwhile, recommended single-well flow rate can be provided without physical meters. The method is proved of good robustness with individual pressure sensor invalid, even total flow rate measurements unavailable. The time cost of each reconciliation process can meet the demand of engineering application.

Soft Sensing for Gas-Condensate Field Production Using Parallel-Genetic-Algorithm-Based Data Reconciliation

2019 ◽  
Vol 19 (4) ◽  
Author(s):  
Dan Wang ◽  
Jing Gong ◽  
Qi Kang ◽  
Di Fan ◽  
Juheng Yang
Keyword(s):  
Genetic Algorithm ◽  
Engineering Application ◽  
Gas Condensate ◽  
Physical Models ◽  
Data Reconciliation ◽  
Parallel Genetic Algorithm ◽  
Two Phase ◽  
Soft Sensing ◽  
Flow Models ◽  
Conventional Optimization

During present offshore gas-condensate production, multiphase flow-meters, due to its exceedingly high cost, are being substituted by a soft sensing (SS) technique for estimating total and single-well flowrates through sensor measurements and physical models. In this work, the inverse problem is solved by data reconciliation (DR), minimizing weighted sum of errors with constraints integrating multiple two-phase flow models. The DR problem is solved by parallel genetic algorithm (PGA) without complex calculations required by conventional optimization. The newly developed SS method is tested by data from a realistic gas-condensate production system. The method is proved of good accuracy and robustness with invalid individual pressure sensor or unavailable total flowrate measurements. Meanwhile, the proposed method shows good parallel performance and the time cost of each DR process can meet the demand of engineering application.

Wet Gas Flow Metering Based on Differential Pressure and BSS Techniques

2011 ◽  
Vol 383-390 ◽  
pp. 4922-4927
Author(s):  
Peng Xia Xu ◽  
Yan Feng Geng
Keyword(s):  
Flow Rate ◽  
Liquid Flow ◽  
Gas Flow ◽  
Two Phase Flow ◽  
Liquid Flow Rate ◽  
Differential Pressure ◽  
Phase Flow ◽  
Two Phase ◽  
Flow Metering ◽  
Wet Gas

Wet gas flow is a typical two-phase flow with low liquid fractions. As differential pressure signal contains rich information of flow parameters in two-phase flow metering, a new method is proposed for wet gas flow metering based on differential pressure (DP) and blind source separation (BSS) techniques. DP signals are from a couple of slotted orifices and the BSS method is based on time-frequency analysis. A good relationship between the liquid flow rate and the characteristic quantity of the separated signal is established, and a differential pressure correlation for slotted orifice is applied to calculate the gas flow rate. The calculation results are good with 90% relative errors less than ±10%. The results also show that BSS is an effective method to extract liquid flow rate from DP signals of wet gas flow, and to analysis different interactions among the total DP readings.

Virtual flow metering of production flow rates of individual wells in oil and gas platforms through data reconciliation

2021 ◽  
pp. 109772
Author(s):  
Gabriel M.P. Andrade ◽  
Diego Q.F. de Menezes ◽  
Rafael M. Soares ◽  
Tiago S.M. Lemos ◽  
Alex F. Teixeira ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Data Reconciliation ◽  
Production Flow ◽  
Flow Rates ◽  
Flow Metering

Prediction of Transient Behaviors of Gas-Condensate Two-Phase Flow in Pipelines With Low Liquid Loading

2006 ◽  
Author(s):  
Daoming Deng ◽  
Jing Gong
Keyword(s):  
Flow Rate ◽  
Transient Flow ◽  
Two Phase Flow ◽  
Flow Behavior ◽  
Flow Simulation ◽  
Gas Condensate ◽  
Phase Flow ◽  
Liquid Loading ◽  
Long Distance ◽  
Two Phase

Transporting natural gas and gas condensate in a long distance pipeline occurs frequently during the development of offshore or desert gas condensate and/or oil fields. However, the thermohydraulic calculation of gas-condensate pipeline, especially transient flow simulation, is hitherto a challenging issue in the pipeline industry on account of a maze of complexities of pipeline undulation, changeable properties of fluid, and transfer of momentum, mass and heat. This study is intended to predict the transient flow behavior in gas-condensate pipelines. In the paper, a hydraulic and thermodynamic (such as phase behavior and properties) model for the analysis of transient gas-condensate two-phase flow in pipelines with low liquid loading is outlined. The hydraulic model is based on simplified “No Pressure Wave” model where the constitutive relation results from the Ottens et al (2001) correlation. An implicit method, the convergence and stability of which have been verified by example calculations, is utilized to solve the transient flow model equations of gas-condensate pipelines. In the end, the transient performances of low-liquid-loading gas-condensate two-phase non-isothermal flow in undulating pipelines, which are subjected to boundary conditions of increasing or decreasing inlet flow rate and specified outlet pressure with time, are numerically investigated. The results, such as pressure and liquid holdup profiles vs. time, and time evolutions of outlet condensate flow rate and accumulated liquid content etc., show that the presented model and numerical method for analyzing gas-condensate transient flow behaviors in pipelines looks reasonable.

THE MECHANISM OF RAISING AND QUANTIFICATION OF SPECIFIC HEAT FLUX AT BOILING OF NANOFLUIDS IN FREE CONVECTION CONDITIONS

2017 ◽  
pp. 25-34
Author(s):  
V.N. Moraru
Keyword(s):  
Heat Transfer ◽  
Heat Flux ◽  
Heat Capacity ◽  
Specific Heat ◽  
Chemical Properties ◽  
Heating Surface ◽  
Physical Models ◽  
Superheated Liquid ◽  
Two Phase ◽  
Boiling Process

The results of our work and a number of foreign studies indicate that the sharp increase in the heat transfer parameters (specific heat flux q and heat transfer coefficient _) at the boiling of nanofluids as compared to the base liquid (water) is due not only and not so much to the increase of the thermal conductivity of the nanofluids, but an intensification of the boiling process caused by a change in the state of the heating surface, its topological and chemical properties (porosity, roughness, wettability). The latter leads to a change in the internal characteristics of the boiling process and the average temperature of the superheated liquid layer. This circumstance makes it possible, on the basis of physical models of the liquids boiling and taking into account the parameters of the surface state (temperature, pressure) and properties of the coolant (the density and heat capacity of the liquid, the specific heat of vaporization and the heat capacity of the vapor), and also the internal characteristics of the boiling of liquids, to calculate the value of specific heat flux q. In this paper, the difference in the mechanisms of heat transfer during the boiling of single-phase (water) and two-phase nanofluids has been studied and a quantitative estimate of the q values for the boiling of the nanofluid is carried out based on the internal characteristics of the boiling process. The satisfactory agreement of the calculated values with the experimental data is a confirmation that the key factor in the growth of the heat transfer intensity at the boiling of nanofluids is indeed a change in the nature and microrelief of the heating surface. Bibl. 20, Fig. 9, Tab. 2.

Gas-Water Flow Behaviour During Mutual Displacement in Porous Media

2017 ◽  
Vol 10 (1) ◽  
pp. 13-22
Author(s):  
Renyi Cao ◽  
Junjie Xu ◽  
Xiaoping Yang ◽  
Renkai Jiang ◽  
Changchao Chen
Keyword(s):  
Porous Media ◽  
Relative Permeability ◽  
Gas Storage ◽  
Fluid Distribution ◽  
Water Displacement ◽  
Phase Zone ◽  
Two Phase ◽  
Flow Process ◽  
Single Well ◽  
Mutual Displacement

During oilfield development, there exist multi-cycle gas–water mutual displacement processes. This means that a cycling process such as water driving gas–gas driving water–water driving gas is used for the operation of injection and production in a single well (such as foam huff and puff in single well or water-bearing gas storage). In this paper, by using core- and micro-pore scales model, we study the distribution of gas and water and the flow process of gas-water mutual displacement. We find that gas and water are easier to disperse in the porous media and do not flow in continuous gas and water phases. The Jamin effect of the gas or bubble becomes more severe and makes the flow mechanism of multi-cycle gas–water displacement different from the conventional water driving gas or gas driving water processes. Based on experiments of gas–water mutual displacement, the changing mechanism of gas–water displacement is determined. The results indicate that (1) after gas–water mutual displacement, the residual gas saturation of a gas–water coexistence zone becomes larger and the two-phase zone becomes narrower, (2) increasing the number of injection and production cycles causes the relative permeability of gas to increase and relative permeability for water to decrease, (3) it becomes easier for gas to intrude and the invaded water becomes more difficult to drive out and (4) the microcosmic fluid distribution of each stage have a great difference, which caused the two-phase region becomes narrower and effective volume of gas storage becomes narrower.

scholarly journals Correction to Flow Rate Profile Interpretation for a Two-Phase Flow in Multistage Fractured Horizontal Wells by Inversion of DTS Data

ACS Omega ◽  
2020 ◽  
Vol 5 (41) ◽  
pp. 26955-26955
Author(s):  
Hongwen Luo ◽  
Beibei Jiang ◽  
Haitao Li ◽  
Ying Li ◽  
Zhangxin Chen
Keyword(s):  
Flow Rate ◽  
Two Phase Flow ◽  
Horizontal Wells ◽  
Phase Flow ◽  
Two Phase ◽  
Fractured Horizontal Wells ◽  
Rate Profile
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