Petroleum最新文献

{"title":"Experimental investigation of the impact of sugarcane molasses on the properties of colloidal gas aphron (CGA) drilling fluid","authors":"Amir Hossein Saeedi Dehaghani,&nbsp;Seyed Masoud Ghalamizade Elyaderani","doi":"10.1016/j.petlm.2021.07.004","DOIUrl":"https://doi.org/10.1016/j.petlm.2021.07.004","url":null,"abstract":"<div><p>Colloidal gas aphron (CGA) based fluid has become very popular in drilling in the last two decades, as it reduces formation damages significantly. In this study, sugarcane molasses (Mls) was used for the first time as a polymer in CGA-based to investigate its ability to improve the role of aphronized fluid as a drilling fluid. The results showed that increasing the concentration of Mls to 12% (v/v) in CGA-based fluid reduces the drainage rate and increases half-life to 10.6 min, resulting in enhanced stability of the aphronized fluid. Also, because of increasing Mls concentration from 1% to 12% (v/v), the yield and the initial gas hold-up decrease to 74% and 299.4 mL, respectively, indicating that the presence of Mls allows less air into the aphron system. Although the rheological properties were improved in this study, the gel strength did not change considerably. Furthermore, the results showed that by increasing the concentration of Mls, the average size of the bubbles decreases, and the particle-size distribution becomes more uniform. Finally, the API filtration test revealed that the higher the Mls concentration in the aphronized fluid, the lower the fluid loss, and at the Mls concentration of 12% (v/v), the fluid loss was estimated at 19.54 mL. A natural polysaccharide with high molecular weight, Mls can be used as a polymer in CGA-based fluid and, thus, improve its performance.</p></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1016/j.petlm.2021.07.004","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49868371","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Optimization design of multi-gathering mode for the surface system in coalbed methane field","authors":"Jun Zhou ,&nbsp;Tiantian Fu ,&nbsp;Kunyi Wu ,&nbsp;Yunxiang Zhao ,&nbsp;Lanting Feng","doi":"10.1016/j.petlm.2022.01.001","DOIUrl":"https://doi.org/10.1016/j.petlm.2022.01.001","url":null,"abstract":"<div><p>As a potential resource for emerging clean energy with abundant reserves, coalbed methane (CBM) has risen rapidly in recent years, and the construction of rational and economical CBM gathering system plays a vital role in the development of the oil and gas industry. At present, there is no literature that considers the optimization of the multi-gathering mode of coalbed methane pipe network system. Due to the complexity and high investment, this paper establishes a unified mixed-integer nonlinear programming model to determine the gathering modes (including liquified natural gas, compressed natural gas, and gas gathering station) of gathering system to reduce the cost of coalbed methane collection and export. The objective function is the maximization of total profit during the period of the whole project, and such constraints, like network structure, facility number, location, node flow balance, capacity and variable value, are taken into consideration. The solution strategy and heuristic algorithm is proposed and verified by the field data from Shanxi province (China). The results show that the model can solve the problem for optimization design of the surface system in complicated CBM fields.</p></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49868374","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Application of thermotolerant petroleum microbes at reservoir conditions for enhanced oil recovery","authors":"Emmanuel E. Okoro ,&nbsp;Ewarezi A. Efajemue ,&nbsp;Samuel E. Sanni ,&nbsp;Oluwasanmi A. Olabode ,&nbsp;Oyinkepreye D. Orodu ,&nbsp;Temiloluwa Ojo","doi":"10.1016/j.petlm.2022.01.008","DOIUrl":"https://doi.org/10.1016/j.petlm.2022.01.008","url":null,"abstract":"<div><p>Primary oil recovery is the first stage of hydrocarbon production in which a reservoir uses its natural energy to force hydrocarbon to its wellbore. Secondary oil recovery comes to play when hydrocarbons can no longer be further produced by natural means. The purpose of secondary recovery is to maintain reservoir pressure so as to displace hydrocarbons toward the wellbore. Both primary and secondary recovery processes cannot displace more than 50% of the available hydrocarbons in a reservoir. The remaining hydrocarbons are further recovered through Tertiary/Enhanced Oil Recovery techniques. According to literature, microbial enhanced oil recovery has been identified as a tertiary method used to improve the efficiency of hydrocarbon production from reservoirs. Microbial enhanced oil recovery is a feasible reservoir technology, which has not been widely used in the oil and gas industry owing to the attainment of the requisite reservoir conditions such as temperature within which microbes can thrive. Literature has shown that thermotolerant microbes can withstand optimum temperatures of 50–90°C, while deep and ultra-deep hydrocarbon reservoir temperatures are often above 100°C. This study identifies some isolated thermotolerant microbes from a sandstone reservoir that can withstand temperatures as high as 110°C via conventional methods and molecular analysis. The identified thermotolerant petroleum microbes: Bacillus amyloliquefaciens (A) and Bacillus nealsonii (B) were used to enhance oil recovery from a reservoir. The results showed that the microbial species A and B at a confined pressure of 3.0 MPa and temperature of 27°C, gave 46.4% and 48.6% oil recoveries, respectively, which is comparably higher than the value (26.9%) obtained for the water flooded samples. At temperatures of 80, 90, 100, 110 and 120°C, the oil recovery results show that the recovery factor (55.2%–64.1%) of species B were higher compared to the range (46.7–57.5%) recorded for species A. At the onset of the core flooding experiments, there was an initial increment in oil recovery factor as the temperature increased from 80 to 110°C, whereas, it remained constant within 110–120°C. This trend coincides with the drop in the thermal resistance exhibited by the microbes when exposed to such conditions. The cumulative oil production from the commercial Eclipse simulation closely matched those of the experiment results, whereas, the slight difference can be attributed to the adjustment of the simulation input parameters. The experimental results show that species B can be used to enhance oil recovery at reservoir temperature conditions above 100°C.</p></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49868375","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Predicting total organic carbon from few well logs aided by well-log attributes","authors":"David A. Wood","doi":"10.1016/j.petlm.2022.10.004","DOIUrl":"https://doi.org/10.1016/j.petlm.2022.10.004","url":null,"abstract":"<div><p>Derivative/volatility well-log attributes from very few commonly recorded well logs can assist in the prediction of total organic carbon (TOC) in shales and tight formations. This is of value where only limited suites of well logs are recorded, and few laboratory measurements of TOC are conducted on rock samples. Data from two Lower-Barnett-Shale (LBS) wells (USA), including well logs and core analysis is considered. It demonstrates how well-log attributes can be exploited with machine learning (ML) to generate accurate TOC predictions. Six attributes are calculated for gamma-ray (GR), bulk-density (PB) and compressional-sonic (DT) logs. Used in combination with just one of those recorded logs, those attributes deliver more accurate TOC predictions with ML models than using all three recorded logs. When used in combination with two or three of the recorded logs, the attributes generate TOC prediction accuracy comparable with ML models using five recorded well logs. Multi-K-fold-cross-validation analysis reveals that the K-nearest-neighbour algorithm yields the most accurate TOC predictions for the LBS dataset. The extreme-gradient-boosting (XGB) algorithm also performs well. XGB is able to provide information about the relative importance of each well-log attribute used as an input variable. This facilitates feature selection making it possible to reduce the number of attributes required to generate accurate TOC predictions from just two or three recorded well logs.</p></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49868812","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Experimental study on the sandstone abrasiveness via mineral composition and microstructure analysis","authors":"","doi":"10.1016/j.petlm.2023.05.002","DOIUrl":"10.1016/j.petlm.2023.05.002","url":null,"abstract":"<div><p>Rock abrasiveness is an important factor affecting the tool's lifetime and efficiency in breaking a rock. Characterizing rock abrasiveness helps in the design, optimization, and mean-life prediction of tools. X-ray diffraction, cast thin section analysis, and CERCHAR abrasiveness tests were performed on 18 different sandstones to characterize rock abrasiveness and explore new methods for characterization. The relationship between the mineral composition and microstructure of sandstone and abrasiveness was investigated. The results show that different structural maturities have varying effects on abrasiveness. In addition, the higher the structural maturity, the more the abrasiveness. Furthermore, in sandstones of the same structural maturity, the abrasiveness increases with equivalent quartz content (EQC). The texture coefficient (TC) and CERCHAR abrasiveness index (CAI) of sandstones with the same structural maturity showed a good linear relationship. Moreover, the correlation coefficients considering the combined parameters are above 0.85. Therefore, obtaining the microstructure and mineral composition of sandstone can effectively characterize rock abrasiveness. It also provides a new method for predicting the abrasiveness of the rock in the well.</p></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":null,"pages":null},"PeriodicalIF":4.2,"publicationDate":"2023-05-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2405656123000329/pdfft?md5=7389fe90af179f3b988f790794a9d1c8&pid=1-s2.0-S2405656123000329-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87663608","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Axial-torsional nonlinear vibration of bottom hole assembly in the air drilling technology","authors":"","doi":"10.1016/j.petlm.2023.05.001","DOIUrl":"10.1016/j.petlm.2023.05.001","url":null,"abstract":"<div><p>The safety and efficiency of drilling engineering are greatly impeded by destructive vibrations of drill string in air drilling, such as stick-slip, bit-bounce and their coupled vibrations. To avoid or suppress these vibrations improving the stability of drilling operations, revealing the occurrence mechanisms of abovementioned harmful vibrations are indispensable by investigating dynamics characteristics of drill string system. In this paper, an axial-torsional coupled dynamics model that can capture the motion behaviors of bottom hole assembly (BHA) is established adopting the lumped parameter method. Subsequently, a rate of penetration (ROP) model appropriating for air drilling is obtained firstly by linear fitting means. Meanwhile, a novel discontinuous support model is established to describe the bit-formation interactions. Then, BHA dynamics are discussed using numerical simulations under different vibration scenarios: normal operation; stick-slip; bit-bounce; bit-bounce and stick-slip combination. Subsequently, in two drilling modes: the continuous and intermittent drilling, the vibration mitigation strategies and dynamics sensibility study of BHA are carried out based on the parametric analysis. The results show that increasing torsional stiffness of drill-pipes, appropriately adjusting rotation speed of top driven system and dynamic weight on bit (WOB) are deemed as an effective strategy suppressing or eliminating stick-slip and bit-bounce vibrations of BHA. Suggest that the rotation speed of top driven system and dynamic WOB are 5 rad/s and 3.5 kN, respectively. Finally, the constructed probability maps allow to driller to choose reasonable mechanical parameters, thereby realizing smooth drilling operation in the air drilling.</p></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":null,"pages":null},"PeriodicalIF":4.2,"publicationDate":"2023-05-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2405656123000317/pdfft?md5=4b1ac94bc4e6d01b29e4229647ecdc56&pid=1-s2.0-S2405656123000317-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79286897","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The rock cutting simulation of heterogeneous granite using FDEM method","authors":"Weiji Liu, Hongxing Deng, X. Zhu, Yanxin Lv, Yunxu Luo","doi":"10.1016/j.petlm.2023.04.002","DOIUrl":"https://doi.org/10.1016/j.petlm.2023.04.002","url":null,"abstract":"","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86101089","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Experimental study on sand production and coupling response of silty hydrate reservoir with different contents of fine clay during depressurization","authors":"Xiangyu Fang ,&nbsp;Dianheng Yang ,&nbsp;Fulong Ning ,&nbsp;Linjie Wang ,&nbsp;Zhichao Liu ,&nbsp;Yanjiang Yu ,&nbsp;Wenwei Xie ,&nbsp;Hongfeng Lu ,&nbsp;Yanlong Li ,&nbsp;Meng Xu","doi":"10.1016/j.petlm.2021.11.008","DOIUrl":"https://doi.org/10.1016/j.petlm.2021.11.008","url":null,"abstract":"<div><p>To further understand the characteristics of clay and sand production (hereafter collectively referred to as sand production) and to provide optimization designs of sand control schemes are critical for gas production from clayey silt natural gas hydrate reservoirs in the South China Sea. Thus, gas-water-sand production behavoirs and coupling reservoir subsidence characteristics before, during, and after hydrate dissociation of the clayey silt hydrate reservoirs with different clay contents (5%, 10%, 15%, 20%, 25%, and 30%) have been studied through a self-developed experimental system. The results show that with the increase of clay content, the total mass of sand production first increases and then decreases, and it reaches maximum when the clayey content is 20%. The sand production is the lowest before hydrate dissociation and increases significantly during hydrate dissociation, which mainly occurs in the high-speed gas and water production stage at the beginning of hydrate dissociation. After hydrate dissociation, the sand production decreases significantly. During the whole depressurization process, the clay and free sand particles generally move to the sand outlet due to the fluid driving force and overlying stress extrusion. However, for conditions of high clay contents, those particles fail to pass through the sand control screen and gradually accumulate and block the screen by forming a mud cake, which greatly reduce the permeability of the screen and limite sand production as well as gas and water production. Our research lays a foundation for sand production prediction and sand control scheme selection during gas recovery from clayey silty hydrate reservoirs that greatly need to consider a balance between sand control and gas productivity.</p></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49702614","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Development and performance evaluation of a high temperature resistant, internal rigid, and external flexible plugging agent for water-based drilling fluids","authors":"Zhe Xu ,&nbsp;Jinsheng Sun ,&nbsp;Li Li ,&nbsp;Kaihe Lv ,&nbsp;Jingping Liu ,&nbsp;Zhiwen Dai ,&nbsp;Xianfa Zhang ,&nbsp;Zonglun Wang","doi":"10.1016/j.petlm.2022.07.004","DOIUrl":"https://doi.org/10.1016/j.petlm.2022.07.004","url":null,"abstract":"<div><p>During the drilling process for oil and gas production, a larger number of drilling fluids invade the formation, causing severe formation damage and wellbore collapsing, which seriously hinders the efficient production of deep oil and gas. Although several plugging agents have been developed for efficient fracture sealing in recent years, the development of high-performance plugging agents with self-adaptive ability and high-temperature resistance remain a challenge. Herein, we report the synthesis of an internal rigid and external flexible plugging agent PANS by reversed-phase emulsion polymerization with nano-silica as the rigid core and poly (acrylamide-co-N-vinylpyrrolidone) as a flexible shell. The plugging agent has a median particle size of 10.5 μm and can self-adapt to seal the microfractures and fractures in the formation, leading to an effective reduction in the filtration loss of bentonite water-based drilling fluid under both low temperature and low pressure (LTLP) and high temperature and high pressure (HTHP) conditions. In addition, compared with the neat nano-silica (500 nm), the sealing efficiency of PANS toward 100–120 mesh sand bed was increased by 71.4% after hot rolling at 180°C.</p></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49702399","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Production optimization under waterflooding with long short-term memory and metaheuristic algorithm","authors":"Cuthbert Shang Wui Ng ,&nbsp;Ashkan Jahanbani Ghahfarokhi ,&nbsp;Menad Nait Amar","doi":"10.1016/j.petlm.2021.12.008","DOIUrl":"https://doi.org/10.1016/j.petlm.2021.12.008","url":null,"abstract":"<div><p>In petroleum domain, optimizing hydrocarbon production is essential because it does not only ensure the economic prospects of the petroleum companies, but also fulfills the increasing global demand of energy. However, applying numerical reservoir simulation (NRS) to optimize production can induce high computational footprint. Proxy models are suggested to alleviate this challenge because they are computationally less demanding and able to yield reasonably accurate results. In this paper, we demonstrated how a machine learning technique, namely long short-term memory (LSTM), was applied to develop proxies of a 3D reservoir model. Sampling techniques were employed to create numerous simulation cases which served as the training database to establish the proxies. Upon blind validating the trained proxies, we coupled these proxies with particle swarm optimization to conduct production optimization. Both training and blind validation results illustrated that the proxies had been excellently developed with coefficient of determination, R² of 0.99. We also compared the optimization results produced by NRS and the proxies. The comparison recorded a good level of accuracy that was within 3% error. The proxies were also computationally 3 times faster than NRS. Hence, the proxies have served their practical purposes in this study.</p></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49702684","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}