scholarly journals Application of Implicit Pressure-Explicit Saturation Method to Predict Filtrated Mud Saturation Impact on the Hydrocarbon Reservoirs Formation Damage

Mathematics ◽  
2020 ◽  
Vol 8 (7) ◽  
pp. 1057 ◽  
Author(s):  
Mingxuan Zhu ◽  
Li Yu ◽  
Xiong Zhang ◽  
Afshin Davarpanah
Keyword(s):  
Porous Media ◽  
Water Saturation ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Drilling Mud ◽  
Oil Viscosity ◽  
The Core ◽  
Oil Flow ◽  
Lower Porosity ◽  
Saturation Method

Hydrocarbon reservoirs’ formation damage is one of the essential issues in petroleum industries that is caused by drilling and production operations and completion procedures. Ineffective implementation of drilling fluid during the drilling operations led to large volumes of filtrated mud penetrating into the reservoir formation. Therefore, pore throats and spaces would be filled, and hydrocarbon mobilization reduced due to the porosity and permeability reduction. In this paper, a developed model was proposed to predict the filtrated mud saturation impact on the formation damage. First, the physics of the fluids were examined, and the governing equations were defined by the combination of general mass transfer equations. The drilling mud penetration in the core on the one direction and the removal of oil from the core, in the other direction, requires the simultaneous dissolution of water and oil flow. As both fluids enter and exit from the same core, it is necessary to derive the equations of drilling mud and oil flow in a one-dimensional process. Finally, due to the complexity of mass balance and fluid flow equations in porous media, the implicit pressure-explicit saturation method was used to solve the equations simultaneously. Four crucial parameters of oil viscosity, water saturation, permeability, and porosity were sensitivity-analyzed in this model to predict the filtrated mud saturation. According to the results of the sensitivity analysis for the crucial parameters, at a lower porosity (porosity = 0.2), permeability (permeability = 2 mD), and water saturation (saturation = 0.1), the filtrated mud saturation had decreased. This resulted in the lower capillary forces, which were induced to penetrate the drilling fluid to the formation. Therefore, formation damage reduced at lower porosity, permeability and water saturation. Furthermore, at higher oil viscosities, due to the increased mobilization of oil through the porous media, filtrated mud saturation penetration through the core length would be increased slightly. Consequently, at the oil viscosity of 3 cP, the decrease rate of filtrated mud saturation is slower than other oil viscosities which indicated increased invasion of filtrated mud into the formation.

scholarly journals A parametric study to numerically analyze the formation damage effect

2019 ◽  
Vol 38 (2) ◽  
pp. 555-568 ◽  
Author(s):  
Afshin Davarpanah ◽  
Behnam Mirshekari ◽  
Armin Razmjoo
Keyword(s):  
Ct Scan ◽  
Water Saturation ◽  
Drilling Fluid ◽  
Laboratory Data ◽  
Damage Effect ◽  
Formation Damage ◽  
Oil Viscosity ◽  
Proposed Model ◽  
Scan Data ◽  
Good Agreement

Spontaneous countercurrent imbibition is one of the essential parameters in the study of formation damage effect in hydrocarbon reservoirs when the drilling fluid is contacted with the drilled formation. Formation damage is considered as one of the harmful phenomena which would seriously affect the efficiency of drilling performances. In this paper, a numerical model was proposed to analyze the main parameters which have profoundly impacted the formation damage. Based on the following parameters of porosity, permeability, water saturation, oil viscosity, pressure drop, contact time, and capillary pressure which were performed in the proposed model, the dominant influence of each parameter was evaluated in more detail. Regarding the high expenditures of scanning electron microscopy and CT scan in petroleum industries, the proposed analytical model would be beneficial instead of spending vast expenditures of experimental evaluation. Subsequently, to provide the accuracy of the model, a set of experimental CT scan data were used to validate the proposed model, and according to the results of this study, it is evident that the proposed model results are in a good agreement with the laboratory data.

Dynamic Evaluation of Invasion and Backflow in Carbonate and Sandstone Reservoirs

2012 ◽  
Author(s):  
Bruno O. Silveira ◽  
Rosangela B. Z. L. Moreno
Keyword(s):  
Multiphase Flow ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Dynamic Flow ◽  
Dynamic Evaluation ◽  
The Core ◽  
Advancing Front ◽  
Sandstone Reservoirs ◽  
Flow Drilling ◽  
Protocol Test

This work aims to compare the drilling fluid invasion and oil backflow in sandstone and carbonate samples in order to evaluate the influence of kind of rock in the formation damage and its interaction with the drilling tested fluid. The tests were performed in sandstone and carbonate samples with similar gas absolute permeabilities and under a protocol test in steps that included preparation, characterization, multiphase flow, drilling fluid invasion and oil backflow. During the work it was observed that carbonate samples were less water wet than sandstone samples. From the obtained results for longer samples was possible to follow the advancing front of the invading fluid with pressure observations along the core. The dynamic flow permitted to conclude that invasion in carbonate samples was faster than in sandstone. It was also observed that in carbonate samples the backflow presented a higher and faster productivity return when compared with sandstone results.

scholarly journals Modification of DS-01 Drilling Fluid to Reduce Formation Damage

2020 ◽  
Vol 2 (3) ◽  
Author(s):  
Winarto S. ◽  
Sugiatmo Kasmungin
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Laboratory Research ◽  
Formation Damage ◽  
Drilling Fluids ◽  
Drilling Mud ◽  
Initial Flow ◽  
Lost Circulation ◽  
Negative Impacts ◽  
Drilling Muds

<em>In the process of drilling for oil and gas wells the use of appropriate drilling mud can reduce the negative impacts during ongoing drilling and post-drilling operations (production). In general, one of the drilling muds that are often used is conventional mud type with weighting agent barite, but the use of this type of mud often results in skin that is difficult to clean. Therefore in this laboratory research an experiment was carried out using a CaCO3 weigting agent called Mud DS-01. CaCO3 is widely used as a material for Lost Circulation Material so that it is expected that using CaCO3 mud will have little effect on formation damage or at least easily cleaned by acidizing. The aim of this research is to obtain a formula of mud with CaCO3 which at least gives formation damage. Laboratory experiments on this drilling mud using several mud samples adjusted to the property specifications of the mud program. Mud sample consists of 4, namely using super fine, fine, medium, and conventional CaCO3. First measuring mud properties in each sample then testing the filter cake breaker, testing the initial flow rate using 200 ml of distilled water and a 20 micron filter disk inserted in a 500 ml HPHT cell then assembled in a PPA jacket and injecting a pressure of 100 psi. The acidification test was then performed using 15% HCL and then pressured 100 psi for 3 hours to let the acid work to remove the cake attached to the filter disk (acidizing). Laboratory studies are expected which of these samples will minimize the formation damage caused by drilling fluids.</em>

Experimental Study of Temperature Effect on Oil Relative Permeability in Porous Media

2013 ◽  
Vol 336 ◽  
pp. 19-27 ◽  
Author(s):  
Mohammad Afkhami Karaei ◽  
Ali Ahmadi ◽  
Hooman Fallah ◽  
Abdolreza Dabiri
Keyword(s):  
Porous Media ◽  
Relative Permeability ◽  
Water Saturation ◽  
Water Injection ◽  
Thermal Recovery ◽  
Engine Oil ◽  
Absolute Permeability ◽  
Scale Model ◽  
Oil Viscosity ◽  
Different Diameters

In the modeling of thermal recovery processes of heavy oil, it is important to know the oil primary relative permeability in the reservoir; moreover we have to be aware of effects of the temperature on oil relative permeability as well. In this study, a sand pack of quartz (SiO2) has been used to simulate and make a porous medium. Quartz is naturally water wet. During experiments there was no change in the pore volume of the media at different temperatures because of the low expansion coefficient of quartz. The fluid used in experiments is engine oil 50. Glass pipes with length of 91cm and diameter of 2.6cm have been used in the experiments. At first, columns have been filled with sand, which sand grains had different diameters, then carbon dioxide was injected to the columns to deplete the air in the pores , then the porous media have been saturated with water to calculate the porosity using the scale model. In addition according to Darcys law in steady state, the absolute permeability was calculated. In the next step, oil was injected to columns until the water saturation reached connate water saturation and finally, water injection was begun to get residual oil saturation (Sor). Experiments results showed that increase of temperature increases the oil relative permeability, note that wetability was constant. Increasing the temperature decreases the oil viscosity then this reduction causes the fluid to move easier and its velocity increases as well.

Evaluating drilling fluid infiltration in porous media – Comparing NMR, gravimetric, and X-ray CT scan methods

2021 ◽  
Vol 198 ◽  
pp. 108242
Author(s):  
Badr S. Bageri ◽  
Abdulrauf R. Adebayo ◽  
Jaber Al Jaberi ◽  
Shirish Patil ◽  
Rahul B. Salin
Keyword(s):  
Porous Media ◽  
Ct Scan ◽  
Drilling Fluid ◽  
X Ray ◽  
Fluid Infiltration

DEVELOPMENT OF RADIAL MODELS FOR FORMATION DAMAGE IN POROUS MEDIA

1991 ◽  
Vol 108 (1) ◽  
pp. 67-83 ◽  
Author(s):  
SUNIL D. REGE ◽  
H. SCOTT FOGLER
Keyword(s):  
Porous Media ◽  
Formation Damage

Imaging and Resistivity Studies of Saturation Gradients in Two-Phase Flow in 3-D Porous Media

1996 ◽  
Vol 464 ◽  
Author(s):  
E. H. Kawamoto ◽  
Po-Zen Wong
Keyword(s):  
Computed Tomography ◽  
Porous Media ◽  
Two Phase Flow ◽  
Water Saturation ◽  
Glass Beads ◽  
Water Phase ◽  
Phase Flow ◽  
Two Phase ◽  
Vertical Column ◽  
X Ray

ABSTRACTWe have carried out x-ray radiography and computed tomography (CT) to study two-phase flow in 3-D porous media. Air-brine displacement was imaged for drainage and imbibition experiments in a vertical column of glass beads. By correlating water saturation Sw with resistance R, we find that there is a threshold saturation S* ≈ 0.2, above which R(SW) ∼ Sw−2, in agreement with the empirical Archie relation. This holds true for both drainage and imbibition with littlehysteresis, provided that Sw remains above S*. Should Sw drop below S* during drainage, R(Sw) rises above the Archie prediction, exhibiting strong hysteresis upon reimbibition. This behavior suggests a transition in the connectivity of the water phase near S*, possibly due to percolation effects.

A FRACTAL MODEL FOR PREDICTING OXYGEN EFFECTIVE DIFFUSIVITY OF POROUS MEDIA WITH ROUGH SURFACES UNDER DRY AND WET CONDITIONS

Fractals ◽  
2021 ◽  
pp. 2150076
Author(s):  
BOQI XIAO ◽  
QIWEN HUANG ◽  
BOMING YU ◽  
GONGBO LONG ◽  
HANXIN CHEN
Keyword(s):  
Porous Media ◽  
Fractal Dimension ◽  
Oxygen Diffusion ◽  
Water Saturation ◽  
Rough Surfaces ◽  
Effective Diffusivity ◽  
Fractal Model ◽  
Relative Roughness ◽  
Oxygen Diffusivity ◽  
Dry And Wet Conditions

Oxygen diffusion in porous media (ODPM) with rough surfaces (RS) under dry and wet conditions is of great interest. In this work, a novel fractal model for the oxygen effective diffusivity of porous media with RS under dry and wet conditions is proposed. The proposed fractal model is expressed in terms of relative roughness, the water saturation, fractal dimension for tortuosity of tortuous capillaries, fractal dimension for pores, and porosity. It is observed that the normalized oxygen diffusivity decreases with increasing relative roughness and fractal dimension for capillary tortuosity. It is found that the normalized oxygen diffusivity increases with porosity and fractal dimension for pore area. Besides, it is seen that that the normalized oxygen diffusivity under wet condition decreases with increasing water saturation. The determined normalized oxygen diffusivity is in good agreement with experimental data and existing models reported in the literature. With the proposed analytical fractal model, the physical mechanisms of oxygen diffusion through porous media with RS under dry and wet conditions are better elucidated. Every parameter in the proposed fractal model has clear physical meaning, with no empirical constant.

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