Journal of Petroleum Exploration and Production Technology最新文献

{"title":"Anomaly detection in oil-producing wells: a comparative study of one-class classifiers in a multivariate time series dataset","authors":"Wander Fernandes, Karin Satie Komati, Kelly Assis de Souza Gazolli","doi":"10.1007/s13202-023-01710-6","DOIUrl":"https://doi.org/10.1007/s13202-023-01710-6","url":null,"abstract":"Abstract Anomalies in oil-producing wells can have detrimental financial implications, leading to production disruptions and increased maintenance costs. Machine learning techniques offer a promising solution for detecting and preventing such anomalies, minimizing these disruptions and expenses. In this study, we focused on detecting faults in naturally flowing offshore oil and subsea gas-producing wells, utilizing the publicly available 3W dataset comprising multivariate time series data. We conducted a comparison of different anomaly detection methods, specifically one-class classifiers, including Isolation Forest, One-class Support Vector Machine (OCSVM), Local Outlier Factor (LOF), Elliptical Envelope, and Autoencoder with feedforward and LSTM architectures. Our evaluation encompassed two variations: one with feature extraction and the other without, each assessed in both simulated and real data scenarios. Across all scenarios, the LOF classifier consistently outperformed its counterparts. In real instances, the LOF classifier achieved an F1-measure of 87.0% with feature extraction and 85.9% without. In simulated instances, the LOF classifier demonstrated superior performance, attaining F1 measures of 91.5% with feature extraction and 92.0% without. These results show an improvement over the benchmark established by the 3W dataset. Considering the more challenging nature of real data, the inclusion of feature extraction is recommended to improve the effectiveness of anomaly detection in offshore wells. The superior performance of the LOF classifier suggests that the boundaries of normal cases as a single class may be ill-defined, with normal cases better represented by multiple clusters. The statistical analysis conducted further reinforces the reliability and robustness of these findings, instilling confidence in their generalizability to a larger population. The utilization of individual classifiers per instance allows for tailored hyperparameter configurations, accommodating the specific characteristics of each offshore well.","PeriodicalId":16723,"journal":{"name":"Journal of Petroleum Exploration and Production Technology","volume":"102 4","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-11-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135390050","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Treatment of paraffin deposition behavior in gas-condensate wells with chemical inhibitors","authors":"Bowen Shi, Jiajun Hong, Zhihua Wang, Zhenbo Chang, Feng Li","doi":"10.1007/s13202-023-01716-0","DOIUrl":"https://doi.org/10.1007/s13202-023-01716-0","url":null,"abstract":"Abstract As deep gas-condensate reservoirs are explored, the problem of paraffin deposition is becoming more prominent. Therefore, this paper collects condensate samples from representative paraffin deposition gas-condensate wells and analyzes basic physical properties. The cold plate deposition device is employed to study paraffin deposition behavior under well conditions and to divide the critical regions for paraffin deposition in gas-condensate wells. The experimental apparatus, such as the crude oil dynamic paraffin deposition rate tester, is utilized to investigate the preventive effect of paraffin dispersants and paraffin crystal modifier. The results show that there is significant phase change behavior in gas-condensate wells and gas phase is dominant form, but there is also phase evolution. It can be identified from the experiments that paraffin deposition is mainly located in the 1000 ~ 1500 m region, and a paraffin deposition identification chart has been established. The maximum deposition rate could reach 15.50 mm/year, which matched the temperature and pressure conditions of 45 ℃ and 70 MPa. The preventive effect of paraffin crystal modifiers greatly exceeds that of paraffin dispersants, with paraffin prevention rates of 85–95% at the optimal concentrations of 0.25–0.50 wt.%. The dissolving paraffin rate can reach 0.0169 g/min. It decreases the paraffin appearance temperature approximately 40% and significantly changes the paraffin crystal morphology. Increased deposition surface area of the cold plate structural design describes the paraffin deposition. This diagram facilitates the reliable identification of paraffin deposition areas and the deposition rates in the wellbore during production. The optimum amounts of BZ and PI paraffin inhibitors are quantified. This study provides a comprehensive understanding of the paraffin deposition behavior, and scientific basis and guidance for the selection of paraffin inhibitors in gas-condensate wells.","PeriodicalId":16723,"journal":{"name":"Journal of Petroleum Exploration and Production Technology","volume":"19 11","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-11-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135935816","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Study on rock brittleness characteristics of deep volcanic reservoir under different confining pressures","authors":"Guozhou Qiu, Xin Chang, Jing Li, Yintong Guo, Lei Wang, Hongling Ma, Wuhao Guo, Zhenhui Bi","doi":"10.1007/s13202-023-01717-z","DOIUrl":"https://doi.org/10.1007/s13202-023-01717-z","url":null,"abstract":"Abstract The mechanical properties of deep volcanic reservoir rocks are complex and the brittleness characteristics are not clear. In order to study the brittleness characteristics of deep volcanic rocks, triaxial compression tests and XRD tests under different confining pressures were carried out to study the brittleness characteristics of deep volcanic rocks. Three methods were used to evaluate the brittleness of volcanic rocks from different sides: the brittleness evaluation method based on stress–strain curve characteristics (BI 1 ), the brittleness evaluation method based on energy dissipation (BI 2 ) and the brittleness evaluation method based on mineral composition (BI 3 ). The three methods showed that the brittleness index of volcanic rocks decreases with the increase in confining pressure, and the higher the depth of volcanic rocks, the lower the brittleness. On the basis of previous studies, an improved brittleness evaluation method based on internal friction Angle was proposed, and the obtained evaluation results were almost consistent with the results obtained by the brittleness evaluation method based on stress–strain curve characteristics (BI 1 ) and the brittleness evaluation method based on energy dissipation (BI 2 ), indicating the feasibility of the improved brittleness evaluation method. The brittleness characteristics of deep volcanic rocks are clearly defined to provide reference for the exploration and development of deep volcanic rocks reservoir.","PeriodicalId":16723,"journal":{"name":"Journal of Petroleum Exploration and Production Technology","volume":"67 6","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135221805","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Reactive transport modeling of scale precipitation and deposition during incompatible water injection in carbonate reservoirs","authors":"A. Shojaee, S. Kord, R. Miri, O. Mohammadzadeh","doi":"10.1007/s13202-023-01715-1","DOIUrl":"https://doi.org/10.1007/s13202-023-01715-1","url":null,"abstract":"Abstract Seawater injection is an efficient enhanced oil recovery (EOR) method that capitalizes on the chemical composition differences between the injecting seawater and in-situ formation water, which leads to physicochemical interactions between the rock and fluids. These rock and fluid interactions result in changes of rock wettability and subsequent improved microscopic sweep efficiency. However, the ion imbalance resulting from seawater injection and its incompatibility with the in-situ formation water may interfere with the rock and fluids equilibrium state, causing scale precipitation and subsequent deposition which can negatively impact rock quality, well productivity and reservoir performance. In this study, an accurate, robust, and general approach is presented by coupling a geochemical module with a compositional two-phase fluid flow model to handle reactive transport in porous media. The proposed coupled model, so-called ad-scale model, is capable of simulating carbonate rock dissolution and sulfate scale formation/deposition for evaluating reservoir performance under incompatible water injection. The model predictions were validated using experimental data. This model was also utilized to predict water injection rate into a carbonate formation. It was obtained that both the reacting and non-reacting component profiles were accurately predicted using the proposed coupled model. The water injection rate prediction was also validated and showed high accuracy with absolute error and coefficient of determination values of 9.02% and 0.99, respectively. In addition, a sensitivity analysis was performed on water composition, which showed a strong dependence of reservoir and well performance on water composition. Graphical abstract This diagram elucidates what exactly happens during incompatible water injection in the mixing zones near the injection well (right half of the figure) or production well (left half of the figure) where most of the geochemical phenomena occur.","PeriodicalId":16723,"journal":{"name":"Journal of Petroleum Exploration and Production Technology","volume":"58 1-2","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-10-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134971808","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Optimal path planning for directional wells across flow units’ many-targets","authors":"C. P. B. Fernandes, W. P. Coutinho, J. W. L. Silva, M. D. Santos, G. P. Oliveira","doi":"10.1007/s13202-023-01709-z","DOIUrl":"https://doi.org/10.1007/s13202-023-01709-z","url":null,"abstract":"Abstract Over the past decades, directional drilling has continuously advanced to increase hydrocarbon recovery by effectively targeting high-productivity reservoirs. However, many existing approaches primarily focus on heuristic optimization algorithms. Moreover, existing models often neglect the incorporation of petrophysical attributes that can significantly impact the selection of production targets, such as the reservoir quality indicator. This article introduces a novel application of mixed-integer programming to define directional drilling paths, considering practical aspects of interest. The paths are subject to drift angle constraints and reference coordinates that align with the optimal reservoir targets. Such targets are identified using the authors’ proposed technique of maximum closeness centrality and the geologic model of hydraulic flow units. In order to evaluate the effectiveness of this approach, a realistic model of the Campos Basin in Brazil is studied. The results reveal that the highest recovery factors obtained with the proposed methodology (17%) exceed the historical average recovery factor of the studied reservoir (15.66%). We believe this study can contribute to the ongoing efforts to enhance directional drilling and maximize the production potential of offshore oil and gas reservoirs.","PeriodicalId":16723,"journal":{"name":"Journal of Petroleum Exploration and Production Technology","volume":"39 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-10-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135219609","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"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 investigation of the rock cutting process and derivation of the 3D spatial distribution of the formation strength using in-cutter sensing","authors":"Alexis Koulidis, Gilles Pelfrene, Shehab Ahmed","doi":"10.1007/s13202-023-01712-4","DOIUrl":"https://doi.org/10.1007/s13202-023-01712-4","url":null,"abstract":"Abstract Recent advances in downhole measurements allow to accurately measure drilling forces at the drill bit, and estimate the evolution of the rock strength along the well profile. This paper presents an experimental methodology that allows to measure drilling forces, at the cutter scale, with a sensor embedded behind a polycrystalline diamond compact (PDC) cutter, and to infer the 3D spatial distribution of the rock strength. Two experimental campaigns have been performed on a laboratory-scaled drilling rig and complemented with standard mechanical tests to validate rock strength estimations. In the first campaign, homogeneous synthetic rock samples have been prepared. The average rock strength of each sample derived from cutter force measurements and a cutter–rock interaction model, compares well with the one derived from mechanical tests. In the second campaign, heterogeneous synthetic rock samples have been prepared. They are made of two layers of gypsum mixtures of different strengths, separated by a slanted bedding plane. Based on the instrumented cutter measurements, the 3D spatial distribution of the rock strength has been reconstructed along its path. Rock strength estimations are consistent with results obtained from mechanical tests, and the reconstructed geometry of the bedding plane matches well its actual geometry. The experimental methodology and technology presented in this paper lay the foundations for estimating rock properties in 3D, at the drilling stage. It has the potential to provide geoscientists information about complex lithological structures at an early stage, reducing the need for expensive and time-consuming coring and logging operations.","PeriodicalId":16723,"journal":{"name":"Journal of Petroleum Exploration and Production Technology","volume":"72 9","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135511374","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"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 investigation and prediction of saturation exponent in carbonate rocks: the significance of rock-fluid properties","authors":"Kazem Saadat, Hossain Rahimpour-Bonab, Vahid Tavakoli, Jebraeel Gholinezhad","doi":"10.1007/s13202-023-01714-2","DOIUrl":"https://doi.org/10.1007/s13202-023-01714-2","url":null,"abstract":"Abstract Hydrocarbon reserves are commonly estimated from electrical logs based on the Archie’s law. Therefore, understanding the concepts and precise determination of Archie’s parameters play an essential role in reservoir studies. The electrical properties of carbonates are affected by both microstructures and wetting characteristics of these heterogeneous rocks. Understanding of these effects and prediction of Archie’s parameters are significant theoretical and experimental challenges. In this paper, these effects were analyzed separately using rocks with various lithologies including limestone, dolomitic limestone and dolostones. Samples with different sedimentary textures (grainstones and packstones), porosities and pore types were also considered under different laboratory conditions. For microstructure effects analysis, 16 heterogeneous carbonate samples having a wide range of microstructures were selected. To decrease wetting effect, the washed samples were tested in air–brine injection system at ambient conditions to measure saturation exponent. Subsequently, in order to investigate the influence of the wetting characteristics on this exponent, 25 homogeneous limestone samples were employed for water–oil injection under reservoir conditions. The porous plate was used as a standard technique to determine the saturation exponent as an electrical index. The results showed that pore connectivity and wettability are the main factors affecting the saturation exponent. Heterogeneity, including the presence of large pores and bimodal texture, is another effective factor that complicates the relationship between saturation exponent and wettability. Furthermore, results indicate variation of the saturation exponent with fluid saturation. Finally, equations were obtained to interpret and calculate the saturation exponent using capillary pressure data by mercury injection method. The derived equations clearly demonstrate the significant impact of the studied parameters on the saturation exponent in carbonate rocks.","PeriodicalId":16723,"journal":{"name":"Journal of Petroleum Exploration and Production Technology","volume":"20 3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-10-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135617143","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"New approach of evaluating fracturing interference based on wellhead pressure monitoring data: a case study from the well group-A of Fuling shale gas field","authors":"Liu Li, Tang YaWan, Zheng Aiwei, Zhang Qian, Wang Yimin, Cai Jin","doi":"10.1007/s13202-023-01713-3","DOIUrl":"https://doi.org/10.1007/s13202-023-01713-3","url":null,"abstract":"Abstract Well pattern infilling has become an effective means for improving the development effect of gas reservoirs in unconventional gas reservoirs. The hydraulic fracturing of infill wells causes widespread fracturing interference between new and old wells. Because fracturing interference has a significant influence on the production of old wells, it is urgent to evaluate the degree of fracturing interference. This paper proposes a new approach to evaluating fracturing interference between new and old wells, which is based on a systematic analysis of the variation pattern of old well wellhead fracturing during the fracturing process of new wells. This new approach not only provides a semi-quantitative evaluation for the degree of fracturing interference between fracture sections of new and old wells but also achieves inter-well connectivity evaluation between new and old wells. This new approach is applied in well group A of the Fuling gas field to demonstrate its analysis process. The results show the different types of fracturing interference result in different levels of pressure response between each fracturing section and the old wells. For example, The pressure rise of old well A7-1 is more obvious in the fracturing process of the 2nd, 14th, and 13th sections of new well A68-5, and the old well A7-2 has significant fracturing interference with the 1st, 2nd, 3rd, 4th, and 6th sections. This achieves a semi-quantitative characterization of fracturing interference between new and old wells. The degree of fracturing interference between the old well A7-2 and the new well A68-5 is the strongest in well group A, which is the effect of compression fracture interference. The old wells A7-3 and A15-3 are the least impacted by fracturing interference, and follow the old wells A15-2 and A7-1. This result has implications for assessing the degree of fracturing interference and inter-well connectivity in unconventional gas reservoirs.","PeriodicalId":16723,"journal":{"name":"Journal of Petroleum Exploration and Production Technology","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135732295","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Estimation of tensile and uniaxial compressive strength of carbonate rocks from well-logging data: artificial intelligence approach","authors":"Ahmed Farid Ibrahim, Moaz Hiba, Salaheldin Elkatatny, Abdulwahab Ali","doi":"10.1007/s13202-023-01707-1","DOIUrl":"https://doi.org/10.1007/s13202-023-01707-1","url":null,"abstract":"Abstract The uniaxial compressive strength (UCS) and tensile strength (T0) are crucial parameters in field development and excavation projects. Traditional lab-based methods for directly measuring these properties face practical challenges. Therefore, non-destructive techniques like machine learning have gained traction as innovative tools for predicting these parameters. This study leverages machine learning methods, specifically random forest (RF) and decision tree (DT), to forecast UCS and T0 using real well-logging data sourced from a Middle East reservoir. The dataset comprises 2600 data points for model development and over 600 points for validation. Sensitivity analysis identified gamma-ray, compressional time (DTC), and bulk density (ROHB) as key factors influencing the prediction. Model accuracy was assessed using the correlation coefficient ( R ) and the absolute average percentage error (AAPE) against actual parameter profiles. For UCS prediction, both RF and DT achieved R values of 0.97, with AAPE values at 0.65% for RF and 0.78% for DT. In T0 prediction, RF yielded R values of 0.99, outperforming DT's 0.93, while AAPE stood at 0.28% for RF and 1.4% for DT. These outcomes underscore the effectiveness of both models in predicting strength parameters from well-logging data, with RF demonstrating superior performance. These models offer the industry an economical and rapid tool for accurately and reliably estimating strength parameters from well-logging data.","PeriodicalId":16723,"journal":{"name":"Journal of Petroleum Exploration and Production Technology","volume":"26 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-10-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135993619","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"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 evaluation of corrosion inhibitors for completion fluids in the petroleum production systems","authors":"Albertus Retnanto, Rommel Yrac, Afsha Shaikh, Rand Alagha, Fay Alsulaiti, Tariq Chagouri","doi":"10.1007/s13202-023-01708-0","DOIUrl":"https://doi.org/10.1007/s13202-023-01708-0","url":null,"abstract":"Abstract Corrosion is the natural and continuous degradation of materials caused by either chemical, mechanical, or electrochemical reactions. Corrosion inhibitors may be added to the completion fluids to address corrosion problems efficiently. It is critical to add corrosion inhibitors in completion fluids, specifically under high-temperature conditions, since the corrosion rate is higher when the temperature is high. This corrosion process limits the life of the drill tools or the oil and gas well and causes formation damage. This research studied corrosion and corrosion inhibition treatments for five completion fluids, namely potassium chloride, sodium chloride, sodium bromide, calcium chloride, and calcium bromide. Phosphate and sulfite-based corrosion inhibitors were individually added to the completion fluids, and their corrosion properties were studied to tackle the corrosion issue. In addition, a mixture of phosphate-based and sulfite-based corrosion inhibitors in completion fluids was studied. Additionally, the experimental results recommend using divalent brines as they were identified as a better medium for lowering corrosion rate and conditions than the monovalent brines. A novel aspect of this study is that the materials leveraged for conducting experiments are also used in actual petroleum production field operations. The experiments demonstrate that the corrosion rate can be efficiently controlled at high temperatures in deeper wells.","PeriodicalId":16723,"journal":{"name":"Journal of Petroleum Exploration and Production Technology","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-10-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"136209928","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}