Flooding mechanism of biolithite based on progressive ion exchange model: an example of the Wangxuzhuang biolithite reservoir in the Dagang oilfield

Abstract The biolithite reservoir has a strong heterogeneity and complex pore structure, and the changing trend of formation resistivity is complicated during the waterflood development process. In the logging interpretation of a water-flooded layer, mixed-formation water resistivity is a critical parameter and its accurate calculation heavily influences the evaluation of logging water saturation. The commonly used mixed liquid resistivity models have not taken into account the contribution of irreducible clay water and, thus, they are not suitable for biolithite reservoirs with high shale contents. In this paper, a new 3D digital core was constructed based on CT scanning, and a progressive ion exchange model of the mixed-formation water compatible with the biolithite reservoir put forward. Compared with experimental data from core water flooding, the progressive ion exchange model conforms to the resistivity change law of biolithite reservoirs. Through numerical simulation and analysis of the resistivity of biolithite reservoir, it is concluded that the salinity of injected water and the formation water saturation are the main factors affecting the resistivity characteristics of water-flooded layer. In terms of the interpretation of the water-flooded layer, the water saturation was calculated using the progressive ion exchange model through finite element modelling of formation resistivity. The particular mechanism of water flooding and changing law of rock electrical properties during reservoir water injection development are presented, which provide a new reliable basis for optimization of the biolithite reservoir development plan.

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Experimental Investigation on Oil Enhancement Mechanism of Hot Water Injection in tight reservoirs

Open Physics ◽

10.1515/phys-2016-0079 ◽

2016 ◽

Vol 14 (1) ◽

pp. 703-713 ◽

Cited By ~ 1

Author(s):

Hao Yongmao ◽

Lu Mingjing ◽

Dong Chengshun ◽

Jia Jianpeng ◽

Su Yuliang ◽

...

Keyword(s):

Oil Recovery ◽

Water Saturation ◽

Water Injection ◽

Hot Water ◽

Water Flooding ◽

Water Displacement ◽

Pore Characteristics ◽

Irreducible Water Saturation ◽

Tight Reservoirs ◽

Oil Water

AbstractAimed at enhancing the oil recovery of tight reservoirs, the mechanism of hot water flooding was studied in this paper. Experiments were conducted to investigate the influence of hot water injection on oil properties, and the interaction between rock and fluid, petrophysical property of the reservoirs. Results show that with the injected water temperature increasing, the oil/water viscosity ratio falls slightly in a tight reservoir which has little effect on oil recovery. Further it shows that the volume factor of oil increases significantly which can increase the formation energy and thus raise the formation pressure. At the same time, oil/water interfacial tension decreases slightly which has a positive effect on production though the reduction is not obvious. Meanwhile, the irreducible water saturation and the residual oil saturation are both reduced, the common percolation area of two phases is widened and the general shape of the curve improves. The threshold pressure gradient that crude oil starts to flow also decreases. It relates the power function to the temperature, which means it will be easier for oil production and water injection. Further the pore characteristics of reservoir rocks improves which leads to better water displacement. Based on the experimental results and influence of temperature on different aspects of hot water injection, the flow velocity expression of two-phase of oil and water after hot water injection in tight reservoirs is obtained.

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A New Methodology for the Multilayer Tight Oil Reservoir Water Injection Efficiency Evaluation and Real-Time Optimization

Geofluids ◽

10.1155/2020/8854545 ◽

2020 ◽

Vol 2020 ◽

pp. 1-17

Author(s):

Lin Cao ◽

Jianlong Xiu ◽

Hongjie Cheng ◽

Hui Wang ◽

Shujian Xie ◽

...

Keyword(s):

Water Injection ◽

Sedimentary Facies ◽

Production Performance ◽

Water Flooding ◽

Tight Oil ◽

Oil Reservoir ◽

Reservoir Water ◽

Injection Efficiency ◽

Tight Oil Reservoir ◽

Channel Bar

It is important to determine the reasonable injection and production rates in the development of multilayer tight oil reservoir with water flooding treatment. Based on the INSIM (interconnection-based numeric simulation model), a connected network model, a new method is designed to evaluate the water injection efficiency of different layers in water flooding reservoirs and to optimize the injection-production system to produce more oil. Based on the types of sedimentary facies and corresponding injection-production data, the interwell connections are divided into four major categories (middle channel, channel edge, middle channel bar, and channel bar edge) and twelve subclasses. This classification standard of interwell connections could help to significantly improve the accuracy of judging the dominant flow path without constructing a complicated geological model. The interaction of interwells such as injection-production correlation and water injection efficiency could be revealed by simulating the production performance and computing the layer dividing coefficient and well dividing coefficient. A numerical example is used to validate this method by comparing results from FrontSim and this method, and the computational efficiency of this method is several dozen times faster than that of the traditional numerical simulation. This method is applied to quickly optimize the production schedule of a tight oil reservoir with the water flooding treatment, that is, the water injection rate of multilayer reservoirs could be optimized subtly by the injection efficiency of different layers, and the target of producing more oil with lower water cut could be achieved.

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Enhanced Oil Recovery using Smart Water Injection

Journal of Engineering ◽

10.31026/j.eng.2018.08.04 ◽

2018 ◽

Vol 24 (8) ◽

pp. 40

Author(s):

Hussain Ali Baker ◽

Kareem A. Alwan ◽

Saher Faris Fadhil

Keyword(s):

Oil Recovery ◽

Water Injection ◽

Deionized Water ◽

Water Flooding ◽

Wettability Alteration ◽

Formation Water ◽

Low Salinity ◽

Smart Water ◽

Low Salinity Water ◽

Salinity Water

Smart water flooding (low salinity water flooding) was mainly invested in a sandstone reservoir. The main reasons for using low salinity water flooding are; to improve oil recovery and to give a support for the reservoir pressure. In this study, two core plugs of sandstone were used with different permeability from south of Iraq to explain the effect of water injection with different ions concentration on the oil recovery. Water types that have been used are formation water, seawater, modified low salinity water, and deionized water. The effects of water salinity, the flow rate of water injected, and the permeability of core plugs have been studied in order to summarize the best conditions of low salinity water flooding. The result of this experimental work shows that the water without any free ions (deionized water) and modified low salinity water have improved better oil recovery than the formation water and seawater as a secondary oil process. The increase in oil recovery factor related to the wettability alteration during low salinity water flooding which causes a decrease in the interfacial tension between the crude oil in porous media and the surface of reservoir rocks. As well as the dissolution of minerals such as calcite Ca+2 was observed in this work, which causes an increase in the pH value. All these factors led to change the wettability of rock to be more water-wet, so the oil recovery can be increased.

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A Novel Nanodrag Reducer for Low Permeability Reservoir Water Flooding: Long-Chain Alkylamines Modified Graphene Oxide

Journal of Nanomaterials ◽

10.1155/2016/8716257 ◽

2016 ◽

Vol 2016 ◽

pp. 1-9 ◽

Cited By ~ 2

Author(s):

Hong Chen ◽

Lin Xiao ◽

Yuan Xu ◽

Xiang Zeng ◽

Zhong-Bin Ye

Keyword(s):

Graphene Oxide ◽

Water Injection ◽

Injection Pressure ◽

Water Flooding ◽

Oxide Surface ◽

Low Permeability ◽

Reservoir Water ◽

Water Contact ◽

Low Permeability Reservoir ◽

Modified Graphene Oxide

Chemical modification of graphene oxide (GO) by grafting hydrophobic chains on the surface has drawn much attention nowadays in the academic world, and it was suggested that modified GO could lead to new functionalized materials with specific structure and different properties. In this paper, modified GO (M-GO) were synthesized by chemically grafting alkylamines with varying chain lengths on the graphene oxide surface. Successful grafting of alkylamines was confirmed using Fourier transform infrared (FTIR) spectra, X-ray diffraction (XRD), thermogravimetric analysis (TGA), scanning electron microscope (SEM), and Raman spectroscopy measurements. In addition, we investigated the properties of M-GO as nanodrag reducer in low permeability reservoir water flooding. Water contact angle (CA) measurements revealed that the hydrophobic nature of GO depended on the chain length of the grafted alkylamines. And flooding experiments showed that the hexadecylamine- and octadecylamine-modified GO had an ability to reduce water injection pressure and improve water-phase permeability of the low permeability reservoirs during water flooding. So the M-GO would have potential applications in oilfield exploitation.

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Chemical and biological compatibility of different injection waters with Zubair Formation Water of Upper Sand Member in Zubair Oil Field, South of Iraq

IOP Conference Series Earth and Environmental Science ◽

10.1088/1755-1315/877/1/012013 ◽

2021 ◽

Vol 877 (1) ◽

pp. 012013

Author(s):

Inass Abdal Razaq Almallah ◽

Fahad Al Najm ◽

Zainb Ali Husain

Keyword(s):

Water Samples ◽

Water Injection ◽

Oil Field ◽

Water Flooding ◽

Formation Damage ◽

Formation Water ◽

Chemical Compatibility ◽

Weakly Alkaline ◽

Weakly Acid ◽

Biological Compatibility

Abstract Water injection by water flooding was used to enhance and increase oil production in Zubair oil field, southern Iraq. Physical-chemical and biological analysis of five water samples from different sources were collected to evaluate its compatibility with formation water using biological experiments and chemical compatibility simulation. The results show that injection water is classified weakly acidic-weakly alkaline and saline water, whereas surface water samples are considered weakly acid-weakly alkaline. The total dissolved solids results show brackish types accept for Formation water which classified weakly acid and Brine water. All the studied water samples contain bacteria colonies of Escherichia coli and Coliform expect for one sample, while Sulfate Reducing Bacteria was founded in all studied samples. Mathematical model of chemical compatibility between studied water samples and Zubair Formation water of the scale prediction model show that there are no needs for any inhibition treatments of all scales except for Geothite and Dolomite that should be treated before water injection. The biological compatibility experiments results show Formation damage about (61%) and (69%) in the studied core samples, while Bactria in water injection caused formation damage about (20%) and (51%).

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A New Methodology of Production Performance Prediction for Strong Edge-Water Reservoir

Journal of Energy Resources Technology ◽

10.1115/1.4049020 ◽

2020 ◽

Vol 143 (8) ◽

Author(s):

Angang Zhang ◽

Zifei Fan ◽

Lun Zhao ◽

Jincai Wang ◽

Heng Song

Keyword(s):

Performance Prediction ◽

Water Saturation ◽

Water Injection ◽

Material Balance ◽

Water Reservoir ◽

Production Performance ◽

Water Flooding ◽

Gas Oil ◽

Permeability Model ◽

Water Influx

Abstract Material balance is a basic principle in reservoir engineering, which is still used as a quick and easy analytical tool for reservoir evaluation. In this article, a new methodology of production performance prediction for water-flooding reservoir was proposed based on the material balance principle, which considers the water saturation change caused by water injection and natural water influx, and its effect on transient gas–oil ratio. Among them, the cumulative water production was calculated based on Tong’s water-driver performance curve; the cumulative water influx was obtained by the Fetkovitch method; the transient gas–oil ratio can be acquired by Darcy’s law and Baker’s relative permeability model. Comparisons have been made between the new methodology and commercial reservoir simulator for two different reservoirs. The results show that there is good similarity between these two tools, which verifies the correctness of the new methodology.

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A justification of the application of low-mineralized flooding at the later stage of offshore oil field development

MORSKIE INTELLEKTUAL`NYE TEHNOLOGII ◽

10.37220/mit.2021.54.4.082 ◽

2021 ◽

pp. 265-270

Author(s):

Д.С. Тананыхин ◽

А.Д. Селимов ◽

Л.А. Сайченко

Keyword(s):

Water Injection ◽

Oil Field ◽

Water Flooding ◽

Reservoir Pressure ◽

Reservoir Water ◽

Field Development ◽

Stage Of Development ◽

Oil Field Development ◽

Mineralized Water ◽

Offshore Oil

Известно, что для поддержания пластового давления используется вода совместимая по своему химическому составу с пластовой. В этом случае обеспечивается возможность сохранить присущую эксплуатируемому объекту поровую структуру. Данная работа посвящена обоснованию применения низкоминерализованного заводнения нефтяных месторождений на поздней стадии разработки. На основе изученного материала разработаны методические рекомендации для повышения эффективности системы поддержания пластового давления за счет закачки низкоминерализованной воды. Результаты теоретического анализа (литературная и патентная проработки) дополнительно были подтверждены проведенным гидродинамическим моделированием низкоминерализованного заводнения на примере нефтяного месторождения. It Has been known that the water used for reservoir pressure maintenance has to be compatible in its chemical composition with the reservoir water. In this case, it is possible to preserve the pore structure inherent in the exploited object. This article is devoted to the justification of applying low-mineralized water flooding at the later stage of offshore oil field development. Authors developed a method to improve the efficiency of reservoir pressure maintenance system with applying low-mineralized water injection. The novelty of this article is the mathematical determination of the optimal period for the start of the application of low-mineralized water flooding. Theoretical analysis results were also confirmed by hydrodynamic modeling of low-mineralized water flooding in an offshore oil field at a late stage of development. Based on the analysis results, authors identified requirements and recommendations for the low-mineralized water flooding.

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Low Permeability Reservoir Water Displacing Oil and Water Flooding Characteristic Curve Theory

Applied Mechanics and Materials ◽

10.4028/www.scientific.net/amm.556-562.4701 ◽

2014 ◽

Vol 556-562 ◽

pp. 4701-4704

Author(s):

Chun Sen Zhao ◽

Qing Lin Ren ◽

Pei Jing Li

Keyword(s):

Characteristic Curve ◽

Water Injection ◽

Oil Field ◽

Water Flooding ◽

Practical Significance ◽

Low Permeability ◽

Reservoir Water ◽

Field Development ◽

Recoverable Reserves ◽

The Impact

The so-called water flooding characteristic curve refers to the oilfield water injection (or natural water drive) development process, a relationship between curve cumulative oil production, cumulative water production and accumulation of fluid production. These curves have been widely used for water injection development of dynamic and recoverable reserves forecast. After many years of practical application, summed up the four kinds of water drive characteristic curve, they have a good practical significance. Recoverable reserves are important indicators of field development is the main basis for planning and design, the application of waterflooding characteristic curve can be predicted oil recoverable reserves. Four water flooding characteristics discussed above curve is mainly applied in high-permeability oil field, which did not consider starting pressure, but should consider the impact of low permeability oilfield actuating pressure gradient on the moisture content.

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ELECTRICAL PARAMETERS OF THE UPPER CARBON ROCKS (RUNOVSHCHYNSKA AREA OF THE DNIEPER-DONETSK BASIN)

Visnyk of Taras Shevchenko National University of Kyiv Geology ◽

10.17721/1728-2713.85.05 ◽

2019 ◽

pp. 37-45

Author(s):

S. Vyzhva ◽

V. Onyshchuk ◽

I. Onyshchuk ◽

M. Reva ◽

O. Shabatura

Keyword(s):

Electrical Resistivity ◽

Water Saturation ◽

Pore Space ◽

Donets Basin ◽

Electrical Parameters ◽

Reservoir Water ◽

Reservoir Conditions ◽

Porosity Coefficient ◽

Specific Electrical Resistivity ◽

Formation Resistivity

The main objective of this article is to study electrical parameters of sandstones and argillites of the Upper Carbon rocks in the Runovshchynska area of the Dnieper-Donets basin. It has been determined that specific electrical resistivity of dry rock samples (specific electrical resistivity of rock matrix) varies from 44,802 kΩ·m to 6,115 МΩ·m (average 751,328 kΩ·m). Specific electrical resistivity of sandstones is 3,45 times more than argillitesdue to different shaliness of studied rocks. Specific electrical resistivity of saturated rocks samples varies from 0,54 Ω·m to 10,46 Ω·m (average 1,23 Ω·m). Specific electrical resistivity of argillites is 2,46 times more than sandstones because the latter had high content of reservoir water in their pores (sandstones had better conductivity). It has been determined that formation resistivity factor of sandstones in atmospheric conditions varies from 6,05 to 33,71 (argillites 11,8), and argillites – from 4,76 to 51,47 (average 17,4). Physical modelling of reservoir conditions (temperature t = 78,5°С, pressure p = 31–31,9 MPa, mineralization M= 170 g/l) showed that specific electrical resistivity varies from 0,3 Ω·m to 3,0 Ω·m (average 0,75 Ω·m). Sandstones in reservoir conditions had the range from 0,3 Ω·m to 2,3 Ω·m (average 0,7 Ω·m), and argillites – from 0,5 Ω·m to 3,0 Ω·m (average 1,2 Ω·m). In this case, specific electrical resistivity of argillites is 1,6 times more than sandstones. Due to the closure of microcracks and the deformation of the pore space, the electrical resistance of rocks increases with increasing pressure. The dependence of formation resistivity enlargement factor on pressure for the studied rocks is expressed by 2-order polynomials. The formation resistivity factor of the studied rocks in reservoir conditions has been determined. It was defined that sandstones in reservoir conditions had the range of the formation resistivity factor from 5,4 to 63,3 (average 20,3), and porosity coefficient – from 0,038 to 0,175 (average 0,113). The range of the formation resistivity factor for argillites was from 13,4 to 88,7 (average 34,3), and porosity coefficient – from 0,043 to 0,115 (average 0,086). Analysis of data of laboratory electrometric investigations has allowed establishing correlations between the porosity coefficient and formation resistivity factor. In addition, the correlation of electrical parameters of rocks in atmospheric and reservoir conditions and the formation resistivity enlargement factor from the water saturation coefficient, taking into account the lithological varieties of the studied rocks, was established.

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