The Impact of the Fracturing Fluid Spontaneous Imbibition on the Petrophysical Properties of Low Permeability Reservoirs

2018 ◽  
Author(s):  
Aymen Al-Ameri ◽  
Talal Gamadi ◽  
Marshall Watson
Keyword(s):  
Spontaneous Imbibition ◽  
Low Permeability ◽  
Petrophysical Properties ◽  
Fracturing Fluid ◽  
Low Permeability Reservoirs ◽  
The Impact

scholarly journals Analysis of Controlling Factors at Separate Imbibition Stages for Ultra-Low-Permeability Reservoirs

Energies ◽  
2021 ◽  
Vol 14 (21) ◽  
pp. 7093
Author(s):  
Hailong Dang ◽  
Hanqiao Jiang ◽  
Binchi Hou ◽  
Xiaofeng Wang ◽  
Tao Gao ◽  
...  
Keyword(s):  
Fractured Reservoirs ◽  
Influential Factors ◽  
Controlling Factors ◽  
Spontaneous Imbibition ◽  
Low Permeability ◽  
Relative Importance ◽  
Oil Viscosity ◽  
Oil Saturation ◽  
Low Permeability Reservoirs ◽  
Interfacial Characteristics

Spontaneous imbibition is an important mechanism in naturally fractured reservoirs. In our previous studies on the effect of imbibition efficiency of ultra-low permeability reservoirs, we mostly focused on the relationship between macroscopic core recovery rate and influential factors. Additionally, we also mainly focused on the factors that control the final imbibition recovery for ultra-low permeability reservoirs. Through a large number of experiments, it was found that the factors affecting imbibition are different in separate stages. However, the relative importance of those factors in different imbibition stages was hardly studied. In this work, we tested six key factors, i.e., the core length, RQI, salinity, interfacial characteristics, initial oil saturation, and oil viscosity, in natural sandstone samples from Chang 6 in the Zichang area. Based on experimental results, we divided the imbibition process into three stages (i.e., the early stage, the middle stage, and the late stage) to quantify the effects of the controlling factors. The results show that the relative importance of the controlling factors is changing during the imbibition process. The weight of importance is obtained for those factors at each stage. In addition, a comparative model is established for the dual-porosity media from Chang 6 formation. The results show that the increase of the rock size can extend the imbibition period for the early and middle stages. Moreover, the weight of importance for the initial oil saturation, interfacial characteristics, and salinity are also analyzed in three imbibition stages. This study provides theoretical support to guide water injection in ultra-low-permeability reservoirs and to understand the formation of energy supplements and oil recovery during the imbibition process.

scholarly journals Experimental Study of Imbibition with Normal Fracturing Fluid in Low-permeability Reservoirs

2020 ◽  
Vol 440 ◽  
pp. 052018
Author(s):  
Feifei Huang ◽  
Chunsheng Pu ◽  
Leichao Lu ◽  
Huanfeng Yan ◽  
Xiaolong He ◽  
...  
Keyword(s):  
Experimental Study ◽  
Low Permeability ◽  
Fracturing Fluid ◽  
Low Permeability Reservoirs

scholarly journals FORMATION HYDRAULIC FRACTURING FLUID BASED ON CARBOXYMETHYL CELLULOSE: ITS ADVANTAGES AND LIMITATIONS, APPLICATION PROSPECTS

2016 ◽  
pp. 49-57
Author(s):  
V. R. Kalinin
Keyword(s):  
Hydraulic Fracturing ◽  
Carboxymethyl Cellulose ◽  
Low Cost ◽  
Low Permeability ◽  
Laboratory Studies ◽  
Fracturing Fluid ◽  
Fracturing Fluids ◽  
Low Permeability Reservoirs ◽  
Manufacturing Features ◽  
Hydraulic Fracturing Fluid

The article considers the advantages and limitations of hydraulic fracturing fluid based on carboxymethyl cellulose determined as a result of laboratory studies. As a result of testing the studied fluid manufacturing features compared with similar fracturing fluids it was determined that the fluid of interest can be effectively used as a fluid for formation hydraulic fracturing especially in low permeability reservoirs. This fluid is widely available and has a low cost. It can easily replace the foreign analogues.

Experimental Investigation of Fracturing-Fluid Migration Caused by Spontaneous Imbibition in Fractured Low-Permeability Sands

2014 ◽  
Vol 17 (01) ◽  
pp. 74-81 ◽  
Author(s):  
R.. Dutta ◽  
C.-H.. -H. Lee ◽  
S.. Odumabo ◽  
P.. Ye ◽  
S.C.. C. Walker ◽  
...  
Keyword(s):  
Capillary Forces ◽  
Spontaneous Imbibition ◽  
Low Permeability ◽  
Driving Mechanism ◽  
Fluid Migration ◽  
High Permeability ◽  
Fracturing Fluid ◽  
X Ray ◽  
Fracturing Fluids ◽  
Water Based

Summary During hydraulic-fracturing operations in low-permeability formations, spontaneous imbibition of fracturing fluid into the rock matrix is believed to have a significant impact on the retention of water-based fracturing fluids in the neighborhood of the induced fracture. This may affect the post-fracturing productivity of the well. However, there is lack of direct experimental and visual evidence of the extent of fluid retention, evolution of the resulting imbibing-fluid front, and how they relate to potential productivity hindrance. In this paper, laboratory experiments have been carefully designed to represent the vicinity of a hydraulic fracture. The evolution of fracturing fluid leakoff is monitored as a function of space and time by use of X-ray computed tomography (CT). The X-ray CT imaging technique allows us to map saturations at controlled time intervals to monitor the migration of fracturing fluid into the reservoir formation. It is generally expected for low-permeability formations (5 to 10 md) to show strong capillary forces because of their small characteristic pore radii, but this driving mechanism is in competition with the low permeability and spatial heterogeneities found in low-permeability sands. The relevance of capillarity as a driver of fluid migration and retention in a low-permeability sand sample is interpreted visually and quantified and compared with high-permeability Berea sandstone in our experiments. It is seen that although low-permeability sands are subject to strong capillary forces, the effect can be suppressed by the low permeability of the formation and the heterogeneous nature of the sample. Nevertheless, saturation values attained as a result of spontaneous imbibition are comparable with those obtained for high-permeability samples. Leakoff of fracturing fluids during the shut-in period of a well can result in delayed gas flowback and can hinder gas production. Results from this investigation are expected to provide fundamental insight regarding critical variables affecting the retention and migration of water-based fracturing fluids in the neighborhood of hydraulic fractures, and consequently affecting the post-fracturing productivity of the well.

Evaluation of liquid nanofluid as fracturing fluid additive on enhanced oil recovery from low-permeability reservoirs

2018 ◽  
Vol 168 ◽  
pp. 390-399 ◽  
Author(s):  
Tianbo Liang ◽  
Qingguang Li ◽  
Xingyuan Liang ◽  
Erdong Yao ◽  
Yanqing Wang ◽  
...  
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Low Permeability ◽  
Fracturing Fluid ◽  
Low Permeability Reservoirs

Analysis of the channeling of water injection in low permeability reservoirs with interlayer considering the seepage–stress coupling

2020 ◽  
Vol ahead-of-print (ahead-of-print) ◽  
Author(s):  
Ji Youjun ◽  
K. Vafai ◽  
Huijin Xu ◽  
Liu Jianjun
Keyword(s):  
Water Injection ◽  
Simulation Method ◽  
Stress Sensitivity ◽  
Injection Rate ◽  
Water Flooding ◽  
Low Permeability ◽  
Content Type ◽  
Main Injection ◽  
Low Permeability Reservoirs ◽  
The Impact

Purpose This paper aims to establish a mathematical model for water-flooding considering the impact of fluid–solid coupling to describe the process of development for a low-permeability reservoir. The numerical simulation method was used to analyze the process of injected water channeling into the interlayer. Design/methodology/approach Some typical cores including the sandstone and the mudstone were selected to test the permeability and the stress sensitivity, and some curves of the permeability varying with the stress for the cores were obtained to demonstrate the sensitivity of the formation. Based on the experimental results and the software Eclipse and Abaqus, the main injection parameters to reduce the amount of the injected water in flowing into the interlayer were simulated. Findings The results indicate that the permeability of the mudstone is more sensitive to the stress than sandstone. The injection rate can be as high as possible on the condition that no crack is activated or a new fracture is created in the development. For the B82 block of Daqing oilfield, the suggested pressure of the production pressure should be around 1–3MPa, this pressure must be gradually reached to get a higher efficiency of water injection and avoid damaging the casing. Originality/value This work is beneficial to ensure stable production and provide technical support to the production of low permeability reservoirs containing an interlayer.

ASSESSMENT OF OIL WELL PRODUCTIVITY IN LOW-PERMEABILITY RESERVOIRS IN THE FIELDS OF EASTERN SIBERIA

2017 ◽  
pp. 30-36
Author(s):  
R. V. Urvantsev ◽  
S. E. Cheban
Keyword(s):  
Oil Recovery ◽  
Large Scale ◽  
Oil And Gas ◽  
Oil Extraction ◽  
Low Permeability ◽  
Oil Well ◽  
Eastern Siberia ◽  
Development Costs ◽  
Traditional Fields ◽  
Low Permeability Reservoirs

The 21st century witnessed the development of the oil extraction industry in Russia due to the intensifica- tion of its production at the existing traditional fields of Western Siberia, the Volga region and other oil-extracting regions, and due discovering new oil and gas provinces. At that time the path to the development of fields in Eastern Siberia was already paved. The large-scale discoveries of a number of fields made here in the 70s-80s of the 20th century are only being developed now. The process of development itself is rather slow in view of a number of reasons. Create a problem of high cost value of oil extraction in the region. One of the major tasks is obtaining the maximum oil recovery factor while reducing the development costs. The carbonate layer lying within the Katangsky suite is low-permeability, and its inventories are categorised as hard to recover. Now, the object is at a stage of trial development,which foregrounds researches on selecting the effective methods of oil extraction.

scholarly journals Mechanism of active silica nanofluids based on interface-regulated effect during spontaneous imbibition

2021 ◽  
Author(s):  
Xu-Guang Song ◽  
Ming-Wei Zhao ◽  
Cai-Li Dai ◽  
Xin-Ke Wang ◽  
Wen-Jiao Lv
Keyword(s):  
Contact Angle ◽  
Interfacial Tension ◽  
Oil Recovery ◽  
Dynamic Contact Angle ◽  
Liquid Interface ◽  
Spontaneous Imbibition ◽  
Wettability Alteration ◽  
Low Permeability ◽  
Oil Water ◽  
Solid Liquid

AbstractThe ultra-low permeability reservoir is regarded as an important energy source for oil and gas resource development and is attracting more and more attention. In this work, the active silica nanofluids were prepared by modified active silica nanoparticles and surfactant BSSB-12. The dispersion stability tests showed that the hydraulic radius of nanofluids was 58.59 nm and the zeta potential was − 48.39 mV. The active nanofluids can simultaneously regulate liquid–liquid interface and solid–liquid interface. The nanofluids can reduce the oil/water interfacial tension (IFT) from 23.5 to 6.7 mN/m, and the oil/water/solid contact angle was altered from 42° to 145°. The spontaneous imbibition tests showed that the oil recovery of 0.1 wt% active nanofluids was 20.5% and 8.5% higher than that of 3 wt% NaCl solution and 0.1 wt% BSSB-12 solution. Finally, the effects of nanofluids on dynamic contact angle, dynamic interfacial tension and moduli were studied from the adsorption behavior of nanofluids at solid–liquid and liquid–liquid interface. The oil detaching and transporting are completed by synergistic effect of wettability alteration and interfacial tension reduction. The findings of this study can help in better understanding of active nanofluids for EOR in ultra-low permeability reservoirs.

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