Journal of Petroleum Science and Engineering最新文献

{"title":"Evaluating the rock wettability using multi-frequency dielectric measurements: A review on the fundamental concept and experimental approach","authors":"Ali Oshaish ,&nbsp;Amjed Hassan ,&nbsp;Mohamed Mahmoud ,&nbsp;Ammar El-Husseiny ,&nbsp;Salah Al-Ofi ,&nbsp;Ahmed Al-Yaseri","doi":"10.1016/j.petrol.2022.111177","DOIUrl":"10.1016/j.petrol.2022.111177","url":null,"abstract":"<div><p><span>The dielectric approach is considered as one of the measurements that have potential in characterizing dissipative mediums which have an electrical contrast in their comprising elements. Recently, there have been remarkable research and development activities aiming to link dielectric responses to different petrophysical properties. Wettability is considered a key parameter in many </span>reservoir engineering<span> aspects including evaluating reservoir performance and designing enhanced oil recovery processes. The rock wettability controls the majority of the electrochemical interactions between the solid grain and the ionically-dissipative fluid. These interactions provide an excellent environment for dielectric measurements to display some dispersion mechanisms under the influence of alternating frequency. This paper presents a comprehensive review on the use of the dielectric approach for wettability evaluation. The majority of the reviewed studies were either a qualitative investigation of this relationship or empirical prediction models for the dielectric measurements based on many inputs which are not available most of the time. Even though significant work has been done in this area, there are still gaps that can be improved and fulfilled. Wettability was still not explored quantitatively through a measurable indicator from the dielectric measurements, for example, no wettability index was developed based on the dielectric approach. Therefore, dielectric could provide an efficient, accurate, and economical wettability index that can be implemented in the industry. Overall, this work aims to review the literature and pave the road for quantifying the wettability index via dielectric measurements.</span></p></div>","PeriodicalId":16717,"journal":{"name":"Journal of Petroleum Science and Engineering","volume":"220 ","pages":"Article 111177"},"PeriodicalIF":0.0,"publicationDate":"2023-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47956894","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Laboratory experiments of in situ combustion in core samples with simulated fractures","authors":"Murat Cinar,&nbsp;Melek Deniz-Paker","doi":"10.1016/j.petrol.2022.111153","DOIUrl":"10.1016/j.petrol.2022.111153","url":null,"abstract":"<div><p><span><span>In situ combustion is one of the oldest </span>enhanced oil recovery methods usually applied to heavy oil fields to improve recovery. In this process, air or oxygen-enriched gas is injected into a reservoir, burning some of the </span>oil in place<span> and generating heat and combustion gases. A considerable fraction of heavy oil resources resides in naturally fractured systems. There is no reported successful application of in situ combustion in a field with fractured systems in the literature to date. There is a limited number of studies regarding the subject in the literature. Thus, fundamental understanding of the process in fractured systems is limited.</span></p><p>In this study, laboratory experiments of in situ combustion in core samples with the presence of fractures were conducted. A total of 12 combustion tube experiments were conducted with 12° API heavy oil from the Bati Raman field in Turkey. These experiments differ in their configuration of fractures and oxygen concentration in the injected gas. Based on our experimental observations three distinct behaviors were observed regarding front propagation through fractured systems. The first type is strictly diffusion-limited, the second type is characterized by a thick combustion front and the last is homogenous behavior. These observations could provide a fundamental basis for possible field applications of in situ combustion in fractured systems.</p></div>","PeriodicalId":16717,"journal":{"name":"Journal of Petroleum Science and Engineering","volume":"220 ","pages":"Article 111153"},"PeriodicalIF":0.0,"publicationDate":"2023-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"41318276","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Effect of lignin source and initiation conditions on graft copolymerization of lignin with acrylamide and performance of graft copolymer as additive in water- based drilling fluid","authors":"Maryam Pourmahdi ,&nbsp;Mahdi Abdollahi ,&nbsp;Alireza Nasiri","doi":"10.1016/j.petrol.2022.111253","DOIUrl":"10.1016/j.petrol.2022.111253","url":null,"abstract":"<div><p><span><span><span>In our previous study, as effective and eco-friendly polymer additive in the water-based drilling fluids (WBDFs), lignosulfonate-g-polyacrylamide (LS-g-PAAm) graft copolymers<span> were successfully synthesized and characterized [J. Petroleum Science and Engineering, 171(2018) 484–494]. The aim of this study was to investigate effect of the functional groups (sources) of lignin as well as initiation condition on the chemical modification of lignin via graft copolymerization method. </span></span>Kraft lignin (KL) extracted from </span>black liquor<span> (as a waste of paper mills) and sulfonated lignin (SL) were used as lignins with the different source and chemical structure. KL and SL were then modified by graft radical copolymerization of acrylamide initiated with thermal or redox initiator. The aliphatic hydroxyl groups were identified as the active sites in the graft copolymerization, where the number of these functional groups in the lignin chain had a significant effect on the progress of the graft copolymerization reaction. Structure of the copolymers was investigated qualitatively and quantitatively using Fourier transform infrared (FTIR) and proton nuclear magnetic resonance (</span></span>¹<span>HNMR) spectroscopies. The performance of lignin and lignin-based graft copolymers (with different grafting percentage) as an additive in the water-based drilling fluids (WBDFs) was studied. Before and after hot rolling, rheological properties including apparent viscosity<span>, plastic viscosity, yield point as well as fluid loss were measured in the absence and presence of the salt contamination. In all fluids, except fluids containing unmodified lignin, an increase in apparent and plastic viscosities was observed. Also, thermal stability and resistance to the salt contamination were observed in fluids formulated with the graft copolymers. Best performance was observed for a fluid containing of kraft lignin graft copolymer 1 (KLGC1) where grafting percentage was as high as 452.9 wt%. Also, results showed that higher amounts of the aliphatic hydroxyl functional groups in the KL in comparison with the SL provides higher rate of the reaction progress, leading to a superior performance for use of corresponding graft copolymer as an additive in the WBDFs. The KL-based graft copolymers were able to maintain rheological and fluid loss properties during drilling operations under the hot rolling and salt contamination.</span></span></p></div>","PeriodicalId":16717,"journal":{"name":"Journal of Petroleum Science and Engineering","volume":"220 ","pages":"Article 111253"},"PeriodicalIF":0.0,"publicationDate":"2023-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48553128","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Experimental study of oil recovery mechanisms during imbibition in tight sandstone with different fluid displacing agents under ambient and reservoir pressure","authors":"Yinghe Chen ,&nbsp;Jianguang Wei ,&nbsp;Fahimeh Hadavimoghaddam ,&nbsp;Xiaofeng Zhou ,&nbsp;Mehdi Ostadhassan ,&nbsp;Xiaoqing Zhao ,&nbsp;Abdumalik Gayubov ,&nbsp;Jiangtao Li ,&nbsp;Anlun Wang ,&nbsp;Ying Yang ,&nbsp;Xuedong Shi","doi":"10.1016/j.petrol.2022.111181","DOIUrl":"10.1016/j.petrol.2022.111181","url":null,"abstract":"<div><p><span>This study explores oil recovery mechanisms of static imbibition<span> in a tight sandstone under different imbibition pressures, simultaneously optimizing imbibition agents. To this end, the static imbibition experiments of two common agents, polyacrylamide (PAM) slick water and anion–nonionic surfactants, are conducted under atmospheric and reservoir pressure (20 MPa). The interfacial tension and contact angle of these two imbibition fluids are also measured. Herein, the entire recovery period and imbibition equilibrium time vs. pressure are determined. Based on NMR and high-pressure mercury injection measurements, the contributions of pores with different sizes to the displacement recovery during imbibition are quantified. Under atmospheric pressure, the recovery rate with the surfactant was measured higher than that of the PAM slick water. The main reason was that the former has a lower interfacial tension (0.0961 mN/m), stronger </span></span>hydrophilicity<span> (average contact angle 27.7°), and stronger oil-displacing effect. Under a reservoir pressure of 20 MPa, the surfactant had lower recovery rate than the PAM slick water, while the latter enhanced the recovery further. Under atmospheric pressure, both agents recovered the crude oil in the medium-sized and larger pores whereas, under reservoir pressure (20 MPa), they mainly recovered oil from the smaller and medium-sized pores. At higher imbibition pressures, both agents recovered more oil from the smaller and medium-sized pores, and less from micropores and larger pores. This indicated that higher pressures can further improve the driving force of fluid replacement, to improve oil production from finer and medium-sized pores significantly. Under atmospheric pressure, both agents reached imbibition equilibrium in approximately 20 days while this period was reduced for the surfactant and slick water to 16 and 12 days, respectively. Based on the results PAM slick water is recommended for EOR purposes in tight sandstone which can be generalized to similar formations around the globe.</span></p></div>","PeriodicalId":16717,"journal":{"name":"Journal of Petroleum Science and Engineering","volume":"220 ","pages":"Article 111181"},"PeriodicalIF":0.0,"publicationDate":"2023-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"42675045","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Modeling transient cavitating flow in large drop crude oil pipelines","authors":"Changjun Li,&nbsp;Jie He,&nbsp;Wenlong Jia,&nbsp;Fan Yang,&nbsp;Jiuqing Ban,&nbsp;Bolin Qiu","doi":"10.1016/j.petrol.2022.111241","DOIUrl":"10.1016/j.petrol.2022.111241","url":null,"abstract":"<div><p><span>Transient cavitating flow is a dangerous condition in the operation of large drop crude oil pipelines. Accurately predicting the high pressure generated by cavity collapse is the premise of analyzing and formulating pipeline safety management and control strategies. A new numerical simulation method for one dimension cavitating flow in crude oil pipelines considering the effect of unsteady friction was proposed. The unsteady friction (UF) term is coupled to the classical discrete gas cavity model (DGCM) for modeling the cavitating flow, and the proposed model is called UF-DGCM. The </span>method of characteristics<span> (MOC) is used to solve the UF-DGCM. The validity of the model has been verified with experimental data. The pipeline length of the two test cases is 37.23 m and 15.22 m, respectively, and the pipeline diameter is 22.1 mm and 20.0 mm, respectively. For the two test cases, the accuracy of the prediction results is improved by 6.7% and 4.4%, respectively. A case study of cavitating flow caused by pump shutdown in a pipeline with a length of 35 km and a diameter of 738 mm was performed using UF-DGCM, and the effects of water hammer wave speed, crude oil vapor pressure, and pump shutdown time on cavitating flow were analyzed. The results show that the maximum pressure peak is dependent on the water hammer wave speed. About the increase in the wave speed value of 200 m/s will lead to an increase in the maximum pressure head value of 10.1 m. The increase of pump shutdown time will inhibit the growth of cavities, and increasing the pump shutdown time by 4 s will shorten the existence time of cavities by about 3 s. The extension of the pump shutdown time will prevent cavitating flow. The proposed improved model is more suitable for transient cavitating flow analysis, and the results of flow parameters research will be helpful to prevent cavitating flow in crude oil pipelines.</span></p></div>","PeriodicalId":16717,"journal":{"name":"Journal of Petroleum Science and Engineering","volume":"220 ","pages":"Article 111241"},"PeriodicalIF":0.0,"publicationDate":"2023-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46704504","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Paleoenvironment-driven organic matter accumulation in lacustrine shale mixed with shell bioclasts: A case study from the Jurassic Da'anzhai member, Sichuan Basin (China)","authors":"Wenzhi Lei ,&nbsp;Dongxia Chen ,&nbsp;Ziyi Liu ,&nbsp;Ming Cheng","doi":"10.1016/j.petrol.2022.111178","DOIUrl":"10.1016/j.petrol.2022.111178","url":null,"abstract":"<div><p>The sedimentary environment<span> governs the depositional processes<span><span><span>, ecological environments, and hydrodynamics, which affect the accumulation of organic-rich sediments. Some particular issues are unsolved about the organic matter accumulations of lacustrine shale mixed with shell bioclasts due to their alternating deposition. Freshwater bivalve remains are a familiar constituent of the Da'anzhai lacustrine calcareous shale, which indicates enhanced activities of benthic organisms. Under this background, favorable environmental conditions for the deposition and preservation of abundant organic matter may be different from classical models. </span>Total organic carbon and elemental concentration analyses of lacustrine calcareous shale samples from the Jurassic Da'anzhai Member in the Sichuan Basin were carried out to reconstruct the </span>paleoenvironment<span> and reveal the organic enrichment mechanism. Results show that the samples are notably enriched in strontium<span><span><span>, phosphorus and biogenic calcium (indicated by excess calcium concentrations) and reveal the mass death event of benthic organisms (including freshwater mussels and gastropods) in paleolakes under the control of climatic transformation. Such enrichment strongly supports the hypothesis that CaO is considered to be a paleoproductivity proxy to some extent. The paleolake was dominated by a warm and humid climate and rapid </span>sedimentation rates and experienced intense chemical weathering, which are characteristic of </span>freshwater input<span> and a high flux of detrital fractions. The variations in the redox state and paleoproductivity are due to climatic shifts, hydrographic restrictions and biological behavior. Furthermore, the organic matter was enriched during both oxygenated and oxygen-deficient conditions. The combination of high sedimentation rates and high sinking influxes of particulate organic carbon reduced the chances of decomposition and thereby facilitated the efficiency of organic matter accumulation in an oxic environment. The low degree of organic matter degradation, moderate sedimentation rates and enhanced phosphorus recycling were responsible for the organic carbon accumulation and preservation in sediments for dysoxic bottom conditions.</span></span></span></span></span></p></div>","PeriodicalId":16717,"journal":{"name":"Journal of Petroleum Science and Engineering","volume":"220 ","pages":"Article 111178"},"PeriodicalIF":0.0,"publicationDate":"2023-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"41890433","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The effect of climbing film on molybdenum disulfide nanosheets flooding in the tertiary oil recovery","authors":"Erdong Yao ,&nbsp;Yuechun Wang ,&nbsp;Hao Bai ,&nbsp;Lianqi Sheng ,&nbsp;Jianhua Guo ,&nbsp;Junjian Li ,&nbsp;Kun Zhang ,&nbsp;Guolin Yu ,&nbsp;Fujian Zhou","doi":"10.1016/j.petrol.2022.111184","DOIUrl":"10.1016/j.petrol.2022.111184","url":null,"abstract":"<div><p><span>With the development of nanotechnology, nanomaterials<span> have shown good potential for enhanced oil recovery<span>, which is of great significance for oil and gas production. Compared with nanoparticles and </span></span></span>nanoemulsions<span>, nanosheets have higher interfacial activity due to their two-dimensional structure, which can form a climbing film on the interface of oil-water and efficiently improve oil recovery. However, the influencing factors of the film-climbing effect and the relationship between the film-climbing effect and enhanced oil recovery are still not clear.</span></p><p><span>In this paper, small-sized water-soluble nanosheets which were molybdenum disulfide (MoS</span>₂<span>) nanosheets (30–50 nm) were synthesized using a one-step hydrothermal method<span>, which have strong stability during the flooding test. And then, modifiers with different carbon chain lengths were used to modify the hydrophile-lipophile balance (HLB) of nanosheets.</span></span></p><p>Next, the influencing factors of nanosheets' climbing film were discussed, and the two-phase height index was innovatively used to characterize the strength of the nanosheets climbing film in the oil-water system. The results show that the longer the carbon chain length of the modifier, the closer the nanosheets are to neutral wet with stronger interfacial activity. In addition, molybdenum disulfide nanosheets can produce a climbing film at the oil-water interface, which is related to salinity, concentration, and diameter of test jar. In a word, the oil displacement efficiency can be characterized by the two-phase height index, and the higher the index, the higher the oil displacement efficiency. This makes us fully realize the importance of climbing film in tertiary oil recovery, and provides a new method for the effective development of oil and gas resources.</p></div>","PeriodicalId":16717,"journal":{"name":"Journal of Petroleum Science and Engineering","volume":"220 ","pages":"Article 111184"},"PeriodicalIF":0.0,"publicationDate":"2023-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46069459","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Synchronous vertical propagation mechanism of multiple hydraulic fractures in shale oil formations interlayered with thin sandstone","authors":"Jun Zhang ,&nbsp;Zengguang Xie ,&nbsp;Yishan Pan ,&nbsp;Jizhou Tang ,&nbsp;Yuwei Li","doi":"10.1016/j.petrol.2022.111229","DOIUrl":"10.1016/j.petrol.2022.111229","url":null,"abstract":"<div><p><span><span><span>To investigate the synchronous vertical propagation mechanism of multiple hydraulic fractures in shale oil formations interlayered with thin sandstone (SIS), we conduct a series of accurate, triaxial, </span>hydraulic fracturing experiments using artificial SIS samples and analyze the effects of the formation dip angle and vertical stress difference on the penetration behavior of a single hydraulic fracture. Further, we develop a numerical model for the synchronous propagation of multiple fractures in SIS formations on a field scale using a three-dimensional lattice algorithm and investigate the controlling effects of the critical fracturing operation parameters on the penetration behavior of multiple hydraulic fractures. Increasing the formation dip angle inhibits the ability of the hydraulic fractures to penetrate the </span>interlayer<span> in the longitudinal direction<span> significantly, while increasing the vertical, in-situ stress difference can improve this penetration ability. When the length of the segment to be fractured remains fixed, too many or few fractures are unfavorable to the longitudinal extension of the hydraulic fractures. When the segment to be fractured includes five perforation clusters, multiple hydraulic fractures on the outside can better penetrate the sandstone interlayer and enter the adjacent shale layers. Appropriately increasing the injection rate and viscosity of the fracturing fluid can enhance the penetration and extension ability of the outer hydraulic fractures; however, massive injections enhance the communication between the intermediate fractures and weaken the penetration and expansion ability of the outer fractures. An injection rate of the fracturing fluid equal to 12 m</span></span></span>³/min can produce a better layer-penetration hydraulic-fracturing effect. When the method of intermittent pumping at a decreased injection rate of the fracturing fluid is used for fracturing under cyclic loading of first high and then low loads, the ability of multiple fractures to penetrate the interlayer in the longitudinal direction can improve further. The obtained results can provide a deeper understanding of the synchronous longitudinal propagation mechanism of multiple fractures in SIS formations, thereby providing more accurate guidance on optimizing layer-penetration fracturing parameters.</p></div>","PeriodicalId":16717,"journal":{"name":"Journal of Petroleum Science and Engineering","volume":"220 ","pages":"Article 111229"},"PeriodicalIF":0.0,"publicationDate":"2023-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"43927929","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Design and performance study of a two-stage inline gas-liquid cyclone separator with large range of inlet gas volume fraction","authors":"Qiang-qiang Wang ,&nbsp;Jia-qing Chen ,&nbsp;Chun-sheng Wang ,&nbsp;Yi-peng Ji ,&nbsp;Chao Shang ,&nbsp;Ming Zhang ,&nbsp;Yi Shi ,&nbsp;Guo-dong Ding","doi":"10.1016/j.petrol.2022.111218","DOIUrl":"https://doi.org/10.1016/j.petrol.2022.111218","url":null,"abstract":"<div><p><span>With the advantages of high separation efficiency and less footprint, the inline gas-liquid cyclone separator has gained wide attention in the fields of petroleum, chemical industry, nuclear energy and aerospace. However, single-stage gas-liquid cyclone separator usually cannot accommodate a large range of </span>inlet gas<span> volume fractions<span>. For gas-liquid cyclone separator operating in series with the same structure, it is difficult to operate the second stage efficiently. Therefore, a new two-stage inline gas-liquid cyclone separator is designed in this study considering the bubble size and the variation of inlet gas volume fraction. It integrates the advantages of horizontal and vertical inline gas-liquid cyclone separator, so as to meet the separation requirement for both gas and liquid. The tangential velocity, gas volume fraction and pressure distribution inside the separator are studied by numerical simulation using Computational Fluid Dynamics. The experimental results show that the optimal standardized flow split is about 1.0. When the inlet gas volume fraction varies from 10% to 90%, the degassing efficiency gradually increased with a maximum value of 8.88%. Meanwhile, the dehydration efficiency gradually decreases, with a maximum value of 4.24%. In addition, the maximum pressure drop of the two-stage inline gas-liquid cyclone separator is only 140 kPa during the process of experimental test. This research can provide efficient solution to the working condition with wide range of inlet gas volume fraction and to meet the requirement of high compactness as well.</span></span></p></div>","PeriodicalId":16717,"journal":{"name":"Journal of Petroleum Science and Engineering","volume":"220 ","pages":"Article 111218"},"PeriodicalIF":0.0,"publicationDate":"2023-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"50185600","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Reasons for low flowback behaviors of water-based fluids in tight sandstone gas reservoirs","authors":"Jian Tian ,&nbsp;Chaozhong Qin ,&nbsp;Yili Kang ,&nbsp;Lijun You ,&nbsp;Na Jia ,&nbsp;Jinghan Song","doi":"10.1016/j.petrol.2022.111152","DOIUrl":"https://doi.org/10.1016/j.petrol.2022.111152","url":null,"abstract":"<div><p><span>Water-based working fluids are widely applied in the development of tight gas formations. However, these fluids’ flowback rate is generally low than 50%, resulting in a large amount of water retention to dramatically decline the gas delivery. Typical tight sandstone core samples are selected in this study to perform the gas-driven water displacement experiment to investigate the underlying mechanisms for the low water flowback behaviors in tight gas reservoirs. Results show that the average water flowback rate for 15 tight sandstone samples by gas-driven water displacement is obtained to be only 31.31%, which in turn causes an average gas permeability damage rate of 58.94%. Analysis suggests that multiscale pore structures, ultra-low connate water saturation phenomenon, filling of </span>hydrophilic clay minerals, and insufficient pressure drop contribute to the congenitally unfavorable geological factors of low water flowback capacity. On the other hand, irreversible formation damages like water phase trapping, salting out issues, and residual water film effect caused by water retention are the main elements that restrict water removal during a gas-flow drying process. The findings of this study provide useful insights into the control mechanisms of low water flowback behaviors and the formation damages induced by water invasion in tight sandstone gas reservoirs.</p></div>","PeriodicalId":16717,"journal":{"name":"Journal of Petroleum Science and Engineering","volume":"220 ","pages":"Article 111152"},"PeriodicalIF":0.0,"publicationDate":"2023-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49873379","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}