Comparison Study of Asphaltene Precipitation Models Using UTCOMP, CMG/GEM and ECLIPSE Simulators

Al-Qasim, Abdulaziz; Aldawsari, Mudhish

doi:10.2118/185370-ms

Cited by 4 publications

(1 citation statement)

References 14 publications

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“…Heavy crude oils have, in their composition, a considerable fraction of high molecular weight asphaltenes and paraffin molecules (Al-Qasim & Al-Dawsari, 2017;Ilyin et al, 2016;Kumar, Kumar & Singh, 2017;Sama, Barrère-Mangote, Bouyssière, Giusti & Lobinski, 2017). These molecules interact with each other to form aggregates making a dispersed phase that, among other effects, manifests itself in high viscosity (Barnes, 2000;Berg, 2010;Cerbelaud, Laganapan, Ala-Nissila, Ferrando & Videcoq, 2017;Kontogeorgis & Kiil, 2016).…”

Section: Introductionmentioning

confidence: 99%

Flow enhancer influence on non-isothermal systems for heavy crude oil production

et al. 2020

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Production of heavy and extra-heavy crude oils generally entails high costs, especially in the winter season, due to heat losses. This work studies the effect of a flow enhancer (a chemical formulation based on biodiesel and oxidized biodiesel of soy oil) on the viscosity of heavy crude oil from different wells in Northern Mexico. The observed results indicate a non-linear decreasing behavior of viscosity concerning temperature and volume fraction of the viscosity reducer. It is also presented a theoretical model that predicts the flow increase that can be achieved using the enhancer in systems in which crude oil temperature is higher than the temperature of the environment. Results showed adequate correspondence between experimental and predicted data. It was found that the enhancer increases the volume of crude oil that can be processed without varying pressure gradient.

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Section: Introductionmentioning

confidence: 99%

Flow enhancer influence on non-isothermal systems for heavy crude oil production

et al. 2020

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Formation Damage Control, Modeling, Analysis and Remediation Techniques

Al-Qasim

Almudairis

2020

Day 1 Wed, February 19, 2020

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Formation damage can occur in the vicinity of the wellbore or far field in the reservoir. Organic and inorganic deposition such as asphaltene, paraffin, iron sulfide, barium sulfate and calcium carbonate are the most commonly encountered scale types of damage. Accidental interactions between the completion kill fluid after the perforation or the drilling fluid while drilling through the target zone are also major causes. The decline of well productivity is the first indication of formation damage and can be used as a determining factor of its severity. Therefore, the type of damage, the mechanisms, and controls need to be analyzed and predicted. This paper presents a detailed and comprehensive review of formation damage including both the external and internal types and the far field and near-wellbore damage. Damage can be identified by observing changes mainly in the well productivity; however, it can be also observed using retrieved equipment such as logging tools and downhole pumps or due to the restricted entry of completion equipment such as inflow control devices (ICDs). The impact of well configuration on the formation damage and the remedy afterwards is also discussed in details. The present study provides a solution and control criteria for the formation damage and a comprehensive mechanistic modeling is proposed. The model is applied by coupling reservoir modeling with the wellbore conservation equations through the pressure. The effect of horizontal laterals is included by developing three-phase transient equations to account for the flow rate change from toe to heel in the drain hole.

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Optimization of Fracturing Parameters by Modified Variable-Length Particle-Swarm Optimization in Shale-Gas Reservoir

Liu

et al. 2021

SPE Journal

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Summary Horizontal drilling and hydraulic fracturing are recognized as the most efficient techniques to enhance recovery in shale-gas reservoirs. Because of the exploitation difficulties and complex flow mechanism in shale gas, it is imperative to focus on the optimization of fracturing parameters. However, most of the current heuristic algorithms follow the principle that the variable dimension is constant during iteration, which leads to poor performance when dealing with dimension-varying problems. The optimization of fracturing parameters can be regarded as a typical dimension-varying problem when considering the difference among fracture properties such as half-length and conductivity. Thus an improved algorithm named modified variable-lengthparticle-swarm optimization (PSO) (VPSO) (MVPSO) was proposed to automatically select the optimal fracturing parameters: the number of fractures as well as the corresponding fracture properties. Then, MVPSO was verified and compared with VPSO by several benchmarks. In addition, a gas/water two-phase model considering gas-adsorption and Knudsen-diffusion effects was used to describe the shale-gas flow in matrix and fracture domains. An embedded discrete-fracture model (EDFM) was applied to model the hydraulic-fracture geometries and fractal methods were adopted to generate the fracture networks. The results indicated that MVPSO showed better performance in both convergence speed and accuracy than that of VPSO, which also provided a new perspective for the optimization of fracturing parameters. Besides, the multispindle-shapedfracture-distribution pattern reached a higher net-present-value (NPV) contrast to that of homogeneous fracture distribution. The decrease of gas price leads to smaller and more nonuniform half-lengthdistribution.

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Comparison Study of Asphaltene Precipitation Models Using UTCOMP, CMG/GEM and ECLIPSE Simulators

Cited by 4 publications

References 14 publications

Flow enhancer influence on non-isothermal systems for heavy crude oil production

Flow enhancer influence on non-isothermal systems for heavy crude oil production

Formation Damage Control, Modeling, Analysis and Remediation Techniques

Optimization of Fracturing Parameters by Modified Variable-Length Particle-Swarm Optimization in Shale-Gas Reservoir

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