Deformable Micro-Gel for EOR in High-Temperature and Ultra-High-Salinity Reservoirs: How to Design the Particle Size of Micro-Gel to Achieve its Optimal Match with Pore Throat of Porous Media

2019 ◽  
Author(s):  
Chengdong Yuan ◽  
Wanfen Pu ◽  
Mikhail A. Varfolomeev ◽  
Junnan Wei ◽  
Shuai Zhao ◽  
...  
Keyword(s):  
Particle Size ◽  
Porous Media ◽  
High Temperature ◽  
High Salinity ◽  
Pore Throat ◽  
Optimal Match

Deformable Microgel for Enhanced Oil Recovery in High-Temperature and Ultrahigh-Salinity Reservoirs: How to Design the Particle Size of Microgel to Achieve Its Optimal Match with Pore Throat of Porous Media

SPE Journal ◽  
2020 ◽  
pp. 1-15
Author(s):  
Chengdong Yuan ◽  
Wanfen Pu ◽  
Mikhail A. Varfolomeev ◽  
Junnan Wei ◽  
Shuai Zhao ◽  
...  
Keyword(s):  
Particle Size ◽  
High Temperature ◽  
Particle Size Distribution ◽  
Size Distribution ◽  
Pore Throat ◽  
Conformance Control ◽  
Average Pore ◽  
Optimal Match ◽  
Throat Diameter ◽  
Matching Relation

Summary Conformance control treatment in high-temperature and ultrahigh-salinity reservoirs for easing water/gas channeling through high-permeability zones has been a great challenge. In this work, we propose a deformable microgel that can be used at more than 373.15 K and ultrahigh-salinity conditions (total dissolved solids > 200 kg/m3, Ca2+ + Mg2+ > 10 kg/m3) and present a method for choosing the suitable particle size of the microgel to achieve an optimal match with the pore throat of the core. First, the particle size distribution of the microgel was analyzed to decide d50, d10, and d90 (diameter when cumulative frequency is 50, 10, and 90%, respectively). Coreflooding experiments were conducted under different permeability conditions from 20 to 900 md to investigate the migration and plugging patterns of the microgel by analyzing and fitting injection pressure curves together with the change in the morphology of the produced microgel analyzed by a microscope. The migration and plugging patterns were divided into three patterns: complete plugging; plugging—passing through in a deformation or broken state—deep migration; and inefficient plugging—smoothly passing through—stable flow. The second pattern can be further divided into three subpatterns as strong plugging, general plugging, and weak plugging. Finally, on the basis of five patterns, we build a quantitative matching relation between the particle size distribution of microgel and the pore-throat size of cores by defining three matching coefficients a = d10/d, ß = d50/d, γ = d90/d (d is the average pore-throat diameter). The effectiveness of this quantitative matching relation was verified by evaluating the plugging ability (residual resistance factor) in a post-waterflooding process after the injection of 1.5 pore volume (PV) of microgel. For a strong permeability heterogeneity, the strong plugging is believed to be the expected pattern. The particles size and the pore-throat size should meet the following relationship: 1 < a < 2, 2 < ß < 4, 4 < γ < 6. In this scenario, the deformable microgel particles could achieve both an effective plugging and a deep migration. The quantitative matching relation with multiple matching coefficients determined based on the particle size distribution might help to choose suitable particles more precisely in comparison to the method based on one matching coefficient (mostly, the ratio of the average diameter of particles to the average pore-throat diameter). In addition, the method itself to build a quantitative matching relation according to particle size distribution can be used for designing different particle-type conformance control agents for profile control and water shutoff treatment in field applications.

scholarly journals Methodology for Concurrent Multi-Parametric Physical Modeling of a Target Natural Unfractured Homogeneous Sandstone

Processes ◽  
2020 ◽  
Vol 8 (11) ◽  
pp. 1448
Author(s):  
Joseph Y. Fu ◽  
Xiang’an Yue ◽  
Bo Zhang
Keyword(s):  
Particle Size ◽  
Numerical Modeling ◽  
Porous Media ◽  
Particle Size Distribution ◽  
Capillary Pressure ◽  
Size Distribution ◽  
Physical Modeling ◽  
Pore Throat ◽  
Fundamental Parameters ◽  
Modeling Simulation

In petroleum, geological and environmental science, flow through porous media is conventionally studied complementarily with numerical modeling/simulation and experimental corefloods. Despite advances in numerical modeling/simulation, experimental corefloods with actual samples are still desired for higher-specificity testing or more complex mechanistic studies. In these applications, the lack of advances in physical modeling is very apparent with the available options mostly unchanged for decades (e.g., sandpacks of unconsolidated packing materials, industry-accepted substitutes with fixed/mismatching petrophysical properties such as Berea sandstone). Renewable synthetic porous media with adjustable parameters are the most promising but have not advanced adequately. To address this, a methodology of advanced physical modeling of the fundamental parameters of dominant mineralogy, particle size distribution, packing, and cementation of a target natural porous media is introduced. Based upon the tight physical modeling of these four fundamental parameters, the other derived parameters of interests including wettability, porosity, pore throat size distribution, permeability, and capillary pressure can be concurrently modeled very close as well by further fine-tuning one of the fundamental parameters while holding the rest constant. Through this process, concurrent multi-parametric physical modeling of the primary petrophysical parameters including particle size distribution, wettability, porosity, pore throat size distribution, permeability, capillary pressure behavior in a target sandstone becomes possible.

scholarly journals Analysis and Simulation of Polymer Injectivity Test in a High Temperature High Salinity Carbonate Reservoir

Polymers ◽  
2021 ◽  
Vol 13 (11) ◽  
pp. 1765
Author(s):  
Mohamed Adel Alzaabi ◽  
Juan Manuel Leon ◽  
Arne Skauge ◽  
Shehadeh Masalmeh
Keyword(s):  
Porous Media ◽  
High Temperature ◽  
Polymer Solutions ◽  
High Salinity ◽  
Shear Thickening ◽  
Shear Thinning ◽  
Polymer Flooding ◽  
Carbonate Reservoir ◽  
Polymer Injection ◽  
The Impact

Polymer flooding has gained much interest within the oil industry in the past few decades as one of the most successful chemical enhanced oil recovery (CEOR) methods. The injectivity of polymer solutions in porous media is a key factor in polymer flooding projects. The main challenge that faces prediction of polymer injectivity in field applications is the inherent non-Newtonian behavior of polymer solutions. Polymer in situ rheology in porous media may exhibit complex behavior that encompasses shear thickening at high flow rates in addition to the typical shear thinning at low rates. This shear-dependent behavior is usually measured in lab core flood experiments. However, data from field applications are usually limited to the well bottom-hole pressure (BHP) as the sole source of information. In this paper, we analyze BHP data from field polymer injectivity test conducted in a Middle Eastern heterogeneous carbonate reservoir characterized by high-temperature and high-salinity (HTHS) conditions. The analysis involved incorporating available data to build a single-well model to simulate the injectivity test. Several generic sensitivities were tested to investigate the impact of stepwise variation in injection flow rate and polymer concentration. Polymer injection was reflected in a non-linear increase in pressure with injection, and longer transient behavior toward steady state. The results differ from water injection which have linear pressure response to rate variation, and quick stabilization of pressure after rate change. The best match of the polymer injection was obtained with complex rheology, that means the combined shear thickening at high rate near the well and moving through apparent Newtonian and shear thinning at low rate.

Study of Characterization Methods on the Particle Size of SMG

2014 ◽  
Vol 1015 ◽  
pp. 268-271
Author(s):  
Yin Zhu Ye ◽  
Xing Cai Wu ◽  
Zheng Bo Wang ◽  
Li Ming Shao ◽  
Zhi Hui Zeng
Keyword(s):  
Particle Size ◽  
High Temperature ◽  
High Salinity ◽  
New Method ◽  
Control Technique ◽  
Scattering Method ◽  
Laser Scattering ◽  
Displacement Effect ◽  
Profile Control ◽  
Deep Profile

Soft moveable gel (SMG) is a new kind of deep profile control microgels used in many oilfields. SMG has many advantages of high temperature, salt tolerance, shear resistance, controllable grain size, good control and oil displacement effect. The SMG deep profile control technique can remarkably improve oil recovery of the high temperature and high salinity oilfields. While the successful applications of SMG deep profile control technique are greatly decided by the size matching ability between SMG microgels micelle particles and reservoir pore throat. Therefore, three different experimental methods such as microscope, SEM analysis, and laser scattering method are used for particle characterization at first. Based on that, the new method utilizing near-infrared spectroscopy is innovated and developed. The method has the advantages of non-destructive measurement of original state, convenient, accurate and reliable results etc.. Finally, three levels of SMG particle size entitled by nanometer, micron, and sub-millimeter are systematically evaluated. The results show the sizes are 0.06, 21.37, about 39.24 μm respectively in the new method. Different particle size of SMG can be applied in deep profile control of high, medium or low permeability reservoirs correspondingly with high temperature and high salinity.

Polymer Flooding in North Sea Reservoirs

1982 ◽  
Vol 22 (03) ◽  
pp. 353-362 ◽  
Author(s):  
Paul Davison ◽  
Eric Mentzer
Keyword(s):  
Porous Media ◽  
High Temperature ◽  
North Sea ◽  
High Salinity ◽  
Oil Reservoirs ◽  
Water Contact ◽  
Oil Reserves ◽  
The North ◽  
The North Sea ◽  
Oil Water

Abstract The use of polymer solutions to enhance oil-displacement efficiency by seawater injection in North Sea oil reservoirs has been investigated. We have evaluated over 140 polymers for viscosity retention and porous media flow performance under high temperature (90 deg. C), high salinity, and high pressure. Scleroglucan polymers give the best performance in our tests. Polyacrylamides (PAAm's) are particularly unsuitable for mobility control. Using polymers to enhance seawater injection and waterflooding processes is not practical in North Sea reservoirs, but selective injection may improve local sweep efficiencies. Introduction North Sea Waterflooding With 95% of Ne crude oil reserves of Western Europe and 90% of the current crude oil production coming from deposits lying under the North Sea bed, oil producers have been prepared to exploit them by making the high capital investment in the new technology of deepwater production platforms. Seawater injection schemes have been introduced early in the life of many/ North Sea fields, and are featuring in Middle East and North and South American offshore field development programs. Most North Sea oils are fairly light, and many can be produced at high rates from thick oil zones in good permeability sandstone reservoirs. The principal aim of the injection schemes has been to maintain reservoir pressure with peripheral injectors positioned mainly below the oil/water contact. Until now, the main problem has been to keep the seawater injection rates high enough. With the incentive of producing more of the North Sea oil reserves, research is being done to ameliorate some other foreseeable problems. One major problem is the severe channeling of injection water, leading to seawater breakthrough into production wells, and the likelihood of barium sulfate scale formation. Channeling resulting from mobility ration effects may be through high-permeability layers (most North Sea reservoirs are very heterogeneous), fractures, or viscous oils. Another factor reducing efficiency is the general rise of the oil/water contact, causing the producing wells to cut excessive quantities of water. Selectively placed polymer injection treatments may reduce channeling, and polymer squeeze treatments may restrict water production. Polymers and other chemical additives need to have adequate chemical stability in the high-salinity, high-temperature environment of North Sea oil reservoirs. Accurate prediction of reservoir performance of enhanced oil recovery (EOR) techniques requires precise data on the behavior of crude oils and relevant aqueous systems in porous media at reservoir conditions. This paper reports thermal stability and porous media test results for a range of polymer types and discusses their possible use to augment North Sea waterflooding. Experimental Polymers Tested. We screened more than 140 polymers, which we classify as polyacrylamides (PAAm's), polyvinylpyrrolidones (PVP's), hydroxyethylcelluloses (HEC's), cellulose sulfate esters (CSE's), guar gums, xanthans, and scleroglucans. Solution Preparation. Solutions were made up in the manner of Hill et al. in seawater (0.45 um filtered) obtained from Chesil beach on the English southwest coast. The seawater contained residual (less than 0.2 ppm) hypochlorite biocide, from a treatment added on collection. Polymer solutions were characterized by filtration profiles through 5-um Millipore filters (at 0.069-MPa driving pressure, and following prefiltration) and by Brookfield ultralow viscometer measurements at 25 and 55 deg. C, with parameters to represent the solution viscosity at high and low shear rates. SPEJ P. 353^

A Novel Hydroxylpropyl Sulfobetaine Surfactant for High Temperature and High Salinity Reservoirs

2013 ◽  
Author(s):  
Fan Zhang ◽  
Desheng Ma ◽  
Qiang Wang ◽  
Youyi Zhu ◽  
Wenli Luo
Keyword(s):  
High Temperature ◽  
High Salinity

scholarly journals Waterfall Algorithm as a tool of investigation the geometrical features of granular porous media

2021 ◽  
Author(s):  
Wojciech Sobieski
Keyword(s):  
Particle Size ◽  
Porous Media ◽  
Lattice Boltzmann ◽  
Granular Media ◽  
Density Ratio ◽  
Geometrical Features ◽  
Granular Porous Media ◽  
Collision Density ◽  
Boltzmann Method ◽  
The Impact

AbstractThe paper describes the so-called Waterfall Algorithm, which may be used to calculate a set of parameters characterising the spatial structure of granular porous media, such as shift ratio, collision density ratio, consolidation ratio, path length and minimum tortuosity. The study is performed for 1800 different two-dimensional random pore structures. In each geometry, 100 individual paths are calculated. The impact of porosity and the particle size on the above-mentioned parameters is investigated. It was stated in the paper, that the minimum tortuosity calculated by the Waterfall Algorithm cannot be used directly as a representative tortuosity of pore channels in the Kozeny or the Carman meaning. However, it may be used indirect by making the assumption that a unambiguous relationship between the representative tortuosity and the minimum tortuosity exists. It was also stated, that the new parameters defined in the present study are sensitive on the porosity and the particle size and may be therefore applied as indicators of the geometry structure of granular media. The Waterfall Algorithm is compared with other methods of determining the tortuosity: A-Star Algorithm, Path Searching Algorithm, Random Walk technique, Path Tracking Method and the methodology of calculating the hydraulic tortuosity based on the Lattice Boltzmann Method. A very short calculation time is the main advantage of the Waterfall Algorithm, what meant, that it may be applied in a very large granular porous media.

scholarly journals Investigation of the kinetics of spontaneous combustion of the major coal seam in Dahuangshan mining area of the Southern Junggar coalfield, Xinjiang, China

2021 ◽  
Vol 11 (1) ◽  
Author(s):  
Li Shen ◽  
Qiang Zeng
Keyword(s):  
Particle Size ◽  
High Temperature ◽  
Coal Seam ◽  
Spontaneous Combustion ◽  
Heating Temperature ◽  
Characteristic Temperature ◽  
Mining Area ◽  
Particle Sizes ◽  
Coal Oxidation ◽  
Increasing Temperature

AbstractIn the present paper, with using diverse methods (including the SEM, the XRD, the TPO, the FTIR, and the TGA) , the authors analysed samples of the major coal seam in Dahuangshan Mining area with different particle sizes and with different heated temperatures (from 50 to 800 °C at regular intervals of 50 °C). The results from SEM and XRD showed that high temperature and high number of pores, fissures, and hierarchical structures in the coal samples could facilitate oxidation reactions and spontaneous combustion. A higher degree of graphitization and much greater number of aromatic microcrystalline structures facilitated spontaneous combustion. The results from TPO showed that the oxygen consumption rate of the coal samples increased exponentially with increasing temperature. The generation rates of different gases indicated that temperatures of 90 °C or 130 °C could accelerate coal oxidation. With increasing temperature, the coal oxidation rate increased, and the release of gaseous products was accelerated. The FTIR results showed that the amount of hydroxide radicals and oxygen-containing functional groups increased with the decline in particle size, indicating that a smaller particle size may facilitate the oxidation reaction and spontaneous combustion of coal. The absorbance and the functional group areas at different particle sizes were consistent with those of the heated coal samples, which decreased as the temperature rose. The results from TGA showed that the characteristic temperature T3 declined with decreasing particle size. After the sample with 0.15–0.18 mm particle size was heated, its carbon content decreased, and its mineral content increased, inhibiting coal oxidation. This result also shows that the activation energy of the heated samples tended to increase at the stage of high-temperature combustion with increasing heating temperature.

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