Petroleum Research最新文献

{"title":"Nanoparticles stabilized foam fluid for hydraulic fracturing application of unconventional gas reservoirs: A review of the properties, progress and future prospects","authors":"Amit Verma ,&nbsp;Nilanjan Pal ,&nbsp;Narendra Kumar ,&nbsp;Ahmed Al-Yaseri ,&nbsp;Muhammad Ali ,&nbsp;Keka Ojha","doi":"10.1016/j.ptlrs.2024.08.004","DOIUrl":"10.1016/j.ptlrs.2024.08.004","url":null,"abstract":"<div><div>Nanoparticles stabilized foam fracturing fluid is an emerging technology in the field of hydraulic fracturing for the unconventional reservoirs. Hydraulic fracturing, commonly known as fracking, is a process used to extract oil and gas from the unconventional reservoirs, such as shale formations. This study has reviewed contiguous improvement in the properties of foam fracturing fluid by the effective formulation of surfactant, polymer, and nanoparticles. Compared to conventional fracturing fluids (slick water and polymer), nanoparticles stabilized foam fracturing fluids exhibit superior proppant-carrying capabilities, ensuring better penetration into micro-fractures and enhanced contact with the reservoir matrix, reduce water usage, and minimize formation damage. Foam structures at different scales, i.e., the interface between air-water and liquid film has been discussed in depth to elaborate on the mechanisms that maintain the stability of foam film. The effects of nanoparticles for improving the foam stability and liquid drainage are deliberated to throw light on the strength and limitations of the current review work for better knowledge of foam structure. This review work is on the advancement of nanoparticles foam fluid focuses on significant analyses, problems, future scope, and applications. The various knowledge gaps and conflicting observations have been identified that give the range of our studies. The technical challenges of using foam-based fracturing fluids were also explored. Maintaining foam stability at the high pressures and temperatures experienced in unconventional reservoirs is a critical challenge. The potential for foam collapse or degradation could undermine its effectiveness in delivering proppants and stimulating fractures.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 149-165"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143684814","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":"Electrofacies-driven 3D-static reservoir modeling of the Late Cenomanian AbuRoash’G Member (Abu-Gharadig Basin, Egypt): Sequence stratigraphic and geomodel constraints for a gas-bearing estuarine system","authors":"Mohammad A. Abdelwahhab ,&nbsp;Emad H. Ali ,&nbsp;Nabil A. Abdelhafez","doi":"10.1016/j.ptlrs.2024.07.004","DOIUrl":"10.1016/j.ptlrs.2024.07.004","url":null,"abstract":"<div><div>Estuarine-systems, developed upon transgressive-phases, feature high-quality reservoir-facies, e.g. tidal-bars, that are important stratigraphic-plays critical for hydrocarbon exploration-development. However, capturing their intricate architectural elements (heterogeneity and quality) is still challenging due to the complex stacking-nature and limited-examples. Moreover, defining reservoir-boundaries upon static-modeling of reservoirs cannot be efficient unless it is controlled by stratal-geometries and established depositional-models. To this end, in this study, we performed 3D-static geocellular reservoir-modeling process for the Late-Cenomanian AbuRoash“G” Member (Abu-Gharadig Basin, Egypt) with sequence-stratigraphic and geomodel, relative-geological-time (RGT) model and horizon-stacks, constraints. In this investigation, as an effective-workflow, not only facies-analysis, integrating seismic-stratigraphy and GR-log motifs, was applied for paleo-environment reconstruction, but also machine learning-based electrofacies were applied, through self-organized-maps (SOM), to accurately recognize complex facies-assemblages present. Object-based and pixel-based stochastic-simulation processes were applied upon geocellularly modeling rock and fluid properties, utilizing key-information scales of seismic and well-log data. The results show that three third-order depositional sequences dominate the succession, resting on the Late-Cretaceous unconformity, of which sequence-1 encloses the lowstand and transgressive systems-tracts of the fluvio-estuarine Bahariya and Abu Roash“G” units, respectively. The transgressive phase built AbuRoash“G” lithounit features an estuarine depositional-system encompassing four facies-associations, of which tidal-sand-bars represent significant gas-bearing reservoir-quality facies. The tidal-bar facies’ efficient reservoir quality calls for attention and testing in future development plans and investigation in similar settings. Furthermore, the facies-constrained workflow established in this study, for reservoir modeling, can effectively help identify the ultimate reservoir-configuration worldwide, as long as the 3D-static modeling process is controlled by the stratal and geomodel restraints.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 79-104"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141849504","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":"Three systems of the oil and gas formation in the world","authors":"Yunhua Deng,&nbsp;Yongcai Yang,&nbsp;Ting Yang","doi":"10.1016/j.ptlrs.2024.06.008","DOIUrl":"10.1016/j.ptlrs.2024.06.008","url":null,"abstract":"<div><div>Crude oil and natural gas are generated by organic matters in rocks in sedimentary basins. After incisive and systematic research on global petroliferous basins, it is realized that the distribution of oil and gas fields is highly heterogeneous, and most of oil and gas are enriched in a few sedimentary strata. Source rocks are the most significant factor that governs the distribution of crude oil and natural gas in sedimentary basins. The prerequisite to finding out a petroliferous basin is to search for source rocks. The abundance of organic matters determines the quality of source rocks and the quantity of generated hydrocarbons. In a sedimentary basin, the biological nutrients come from rivers. The biological nutrition is the key factor that controls the degree of reproduction and organic matter abundance in source rocks, which is a governing factor for the amount of oil and gas generated and the degree of petroleum resource enrichment in the sedimentary basin. Oil and gas are mainly distributed in three systems in the world: river-lake system, river-gulf system and river-delta system. The river-lake system is the main location of continental oil distribution. Lacustrine oil is mainly produced by organic matters originating from dead algae in lakes preserved in sedimentary rocks. Algae growth mainly depends on the nutrients that come from rivers, especially those with a long history, flowing through a wide area. The nutrients have a large amount of phosphorus, potassium and other minerals dissolved in water, providing a prerequisite to the growth of algae and a guarantee of the formation of high-quality source rocks. The river-gulf system is the main location of marine oil distribution. The gulf is the estuary of the river, which brings abundant minerals to promote the growth and proliferation of aquatic organisms such as algae. Gulfs are relatively closed and their exchange with the ocean is restricted, therefore the gulf is also conducive to the preservation of organic matters. The coaliferous gas has the world's most widely distributed and biggest reserves; many giant coaliferous gas fields are located in the river-delta system. The sediments brought by the river are fertile soil for the growth of higher plants, and the native higher plants on the river-delta plain are the solid material basis for the formation of coal-measure gas source rocks. Well-developed delta reservoirs with good reservoir-caprock configuration are beneficial for natural gas enrichment and accumulation.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 1-27"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143684774","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":"Generating extremely low-dimensional representation of subsurface earth models using vector quantization and deep Autoencoder","authors":"Yusuf Falola ,&nbsp;Polina Churilova ,&nbsp;Rui Liu ,&nbsp;Chung-Kan Huang ,&nbsp;Jose F. Delgado ,&nbsp;Siddharth Misra","doi":"10.1016/j.ptlrs.2024.07.001","DOIUrl":"10.1016/j.ptlrs.2024.07.001","url":null,"abstract":"<div><div>Geological model compression is crucial for making large and complex models more manageable. By reducing the size of these models, compression techniques enable efficient storage, enhance computational efficiency, making it feasible to perform complex simulations and analyses in a shorter time. This is particularly important in applications such as reservoir management, groundwater hydrology, and geological carbon storage, where large geomodels with millions of grid cells are common. This study presents a comprehensive overview of previous work on geomodel compression and introduces several autoencoder-based deep-learning architectures for low-dimensional representation of modified Brugge-field geomodels. The compression and reconstruction efficiencies of autoencoders (AE), variational autoencoders (VAE), vector-quantized variational autoencoders (VQ-VAE), and vector-quantized variational autoencoders 2 (VQ-VAE2) were tested and compared to the traditional singular value decomposition (SVD) method. Results show that the deep-learning-based approaches significantly outperform SVD, achieving higher compression ratios while maintaining or even exceeding the reconstruction quality. Notably, VQ-VAE2 achieves the highest compression ratio of 667:1 with a structural similarity index metric (SSIM) of 0.92, far surpassing the 10:1 compression ratio of SVD with a SSIM of 0.9. The result of this work shows that, unlike traditional approaches, which often rely on linear transformations and can struggle to capture complex, non-linear relationships within geological data, VQ-VAE's use of vector quantization helps in preserving high-resolution details and enhances the model's ability to generalize across varying geological complexities.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 28-44"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141696236","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":"Research on physical explosion crater model of high-pressure natural gas pipeline","authors":"","doi":"10.1016/j.ptlrs.2024.03.002","DOIUrl":"10.1016/j.ptlrs.2024.03.002","url":null,"abstract":"<div><p>In this study, Hypermesh and LS-DYNA numerical simulation software are used to build a multi domain coupling model of natural gas pipeline, including soil, pipeline, TNT explosive and air domain, and the non-reflection boundary conditions are set for the model. The TNT equivalent method is used to convert the physical explosion amount of natural gas pipeline into 1387.38 kg TNT explosive amount. The simulation results show that the physical explosion of pipeline forms an approximate elliptical crater with a width of 12.68 m and a depth of 4.12 m; the TNT equivalent of the model is corrected by comparing the crater simulation value and the size value of the crater calculated by the PRCI empirical formula under the same laying condition, and the correction coefficient is selected as 0.9, and the corrected TNT equivalent is 1248.64 kg; the modified model crater size is 3.72 m deep and 12.66 m wide, compared with the crater size obtained from the field test, the error of crater depth and width calculated by the modified model simulation is 5.7% and 15.5% respectively.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 3","pages":"Pages 432-438"},"PeriodicalIF":0.0,"publicationDate":"2024-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000279/pdfft?md5=3e92fe2993143a2ce8dbb0baabd94cba&pid=1-s2.0-S2096249524000279-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140269777","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":"Petrophysical insights into pore structure in complex carbonate reservoirs using NMR data","authors":"","doi":"10.1016/j.ptlrs.2024.03.004","DOIUrl":"10.1016/j.ptlrs.2024.03.004","url":null,"abstract":"<div><p>The study delves into pore structure attributes within the complex Eocene carbonate of an Indian offshore field, encompassing pore throat, radius and their characteristics. Nuclear Magnetic Resonance (NMR) experimental data reveals crucial insights into pore structures and fluid states. This study compares the NMR T₂ distribution curve with capillary pressure data from the Mercury Injection Capillary Pressure (MICP) technique, deriving linear and nonlinear conversion coefficients to transform NMR T₂ spectra into equivalent pore radius distribution. Pore radius-dependent porosity partitioning, linked to permeability and the distribution of irreducible water, is conducted utilizing NMR-derived data. Following the T₂ cut-off analysis, a two-segment fractal analysis of NMR T₂ distribution is also carried out. This analysis unveils associations between fractal dimensions and various petrophysical parameters, including permeability, porosity, T₂LM, irreducible water saturation and R₅₀. The NMR-derived pore radius distribution is mostly unimodal, occasionally slightly bimodal. Six different pore size classes (less than 0.05 μm to more than 5 μm) are analysed in relation to permeability, porosity and irreducible water. Small pores (&lt;1 μm) contribute more to irreducible water with low porosity and permeability. The fractal dimension of large pores correlates strongly with porosity, permeability, T₂LM, irreducible water and R₅₀ suggesting significant impact on reservoir seepage capacity. In addition to porosity partitioning, the current study demonstrates effectiveness in modelling modified permeability and correlating it with in situ permeability when applied to field NMR log data from the study area. While numerous studies focus on sandstone, our study marks the pioneering attempt at a comprehensive analysis on complex carbonate reservoirs.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 3","pages":"Pages 439-450"},"PeriodicalIF":0.0,"publicationDate":"2024-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000309/pdfft?md5=89fdeaf81c1cf9b9c7dde6ec46a3c5b1&pid=1-s2.0-S2096249524000309-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140274423","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":"Reliability of permanent downhole systems: Minimum sample and quality index","authors":"","doi":"10.1016/j.ptlrs.2024.03.005","DOIUrl":"10.1016/j.ptlrs.2024.03.005","url":null,"abstract":"<div><p>Permanent downhole monitoring systems are responsible for measuring pressure and temperature time series and enable uninterrupted reservoir characterization during the oil field production period, playing a key role in the oil and gas industry. Located in hostile pressure and temperature environments (i) close to the reservoir, in the case of the PDG (Permanent Downhole Gauge) sensor, and (ii) at the wellhead, in the case of the TPT (Pressure and Temperature Transducer) and PT (Pressure Transducer), its data are transmitted from the subsea environment to the Floating Production Storage and Offloading (FPSO), where the Master Control System (MCS) provides the information in engineering format. This information fulfills its function in the FPSO plant and finally is stored in an onshore data historian. Such complexity, importance, and maintenance difficulty of this system make it necessary to control and manage its reliability. Therefore, the objective of this work is to increase the availability and maximize the useful life of the downhole permanent monitoring system through the reliability calculation, using the Weibull estimate with 2 parameters, and the application of an index quality of statistical inferences. The proposed method for estimating reliability uses a database containing information from permanent downhole monitoring systems of the PDG, TPT, and PT type, from January 1st, 2008 to January 9th, 2014, and considers only the failures that occur until the arrival of the data in the MCS. From the reliability results, it can be observed that stratifications of this database could generate samples with a smaller number of observations, thus inferring reliability even with a small number of samples. The deepening of this method results in the definition of the minimum sample that allows removing reliability inferences without statistical significance and a quality index that allows classifying the reliability estimates of stratified sets of the largest sample of a database. It is worth mentioning here that both methodologies developed in this work are inserted in a well monitoring system that intends to contribute to increasing the availability of pressure and temperature data for the management of well operations.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 3","pages":"Pages 472-480"},"PeriodicalIF":0.0,"publicationDate":"2024-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000310/pdfft?md5=37e28ac73a42d702ca4292dd89e8ffb0&pid=1-s2.0-S2096249524000310-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140403230","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":"Investigation of a solid particle deposition velocity in drag reducing fluids with salinity","authors":"","doi":"10.1016/j.ptlrs.2024.01.010","DOIUrl":"10.1016/j.ptlrs.2024.01.010","url":null,"abstract":"<div><p>Optimal and cost-effective drilling operations in extended-reach horizontal wells depend on efficient solid cuttings removal from the borehole. Several solids-suspended multiphase processes such as crude petroleum transportation, separation, and processing of oil and gas streams also require the efficient removal of these solids. The terminal settling velocity (V_ts) of the solid particle is a vital parameter that controls the removal efficiency of these solids. In a drilling scenario when there is a hold on fluid circulation such as connection time, the accurate estimation of V_s provides the driller with time available to prevent solid deposition. In severe conditions, this can result in a stuck pipe, especially for extended-reach horizontal wells. In this work, both spherical and non-spherical particle deposition were experimentally investigated in several fluid rheology and salinity. Two concentrations (<span><math><mrow><mn>0.1</mn><mspace></mspace><mi>v</mi><mi>o</mi><mi>l</mi><mo>%</mo></mrow></math></span> and <span><math><mrow><mn>0.05</mn><mspace></mspace><mi>v</mi><mi>o</mi><mi>l</mi><mo>%</mo></mrow></math></span>.) of partially-hydrolyzed polyacrylamide (PHPA) were used as a drag-reducing additive for water-based drilling mud. The PHPA drag-reducing fluid (reduced pressure loss) acts as a turbulence inhibitor. The PHPA polymer chain suppresses any turbulence in the flow, reducing the turbulent eddy viscosity. The effects of salinity (<span><math><mrow><mn>3</mn><mspace></mspace><mi>w</mi><mi>t</mi><mo>.</mo><mspace></mspace><mo>%</mo><mspace></mspace><mi>N</mi><mi>a</mi><mi>C</mi><mi>l</mi></mrow></math></span> and <span><math><mrow><mn>3</mn><mspace></mspace><mi>w</mi><mi>t</mi><mo>.</mo><mspace></mspace><mo>%</mo><mspace></mspace><mi>C</mi><mi>a</mi><mi>C</mi><msub><mi>l</mi><mn>2</mn></msub></mrow></math></span> contamination) on solid particle settling velocity (V_s) in drag-reducing fluids were also investigated. Terminal velocity was achieved for all experiments and seemed to increase with increased diameter/sphericity. However, cases when this trend was not consistent were observed and therefore a new parameter of Φ (sphericity index × diameter) was proposed. V_s increases with Φ value for all cases. During drilling, PHPA also aids in sealing the fracture in the formation. With and without salt in the fluid, how lowering drag affected the settling velocity of solid particles (drill cuttings) could be observed. The settling velocity tests will be improved in drag-reducing PHPA solutions with the knowledge from this study.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 3","pages":"Pages 347-358"},"PeriodicalIF":0.0,"publicationDate":"2024-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000103/pdfft?md5=cdbf4e8870c6307243ff0b8f7a97952a&pid=1-s2.0-S2096249524000103-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139879785","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":"Influence of mantle plume on continental rift evolution: A case study of the East African rift system","authors":"","doi":"10.1016/j.ptlrs.2024.02.001","DOIUrl":"10.1016/j.ptlrs.2024.02.001","url":null,"abstract":"<div><p>Mantle plume is an essential component of the mantle convection system, and its influence on the geodynamics of continental rifts is of great significance for understanding the crust–mantle interaction. The East African Rift System, as the largest continental rift in the Cenozoic and in the initial stage, provides an excellent option for studying the interaction between the mantle plume and the continental crust. Based on the data such as GPS, seismic tomography, and global crustal model, a viscoelastic-plastic 2D thermodynamic numerical model is established to reconstruct the evolution of the Afar depression, Ethiopian Rift, and Kenyan Rift. By comparing the differences between the models of the Afar depression, Ethiopian Rift, and Kenyan Rift, the relationship between the mantle plume and pre-existing structures and their influence on the evolution of continental rifts are discussed. The results show that the mantle plume can increase the depth of the rift faults, concentrate the distribution of the faults, and strengthen the control of main faults on the rifts, allowing the possibility of narrow rifts. Pre-existing structures control the fault styles and symmetry of the rifts and also the morphology of the mantle plume.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 3","pages":"Pages 409-417"},"PeriodicalIF":0.0,"publicationDate":"2024-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000152/pdfft?md5=d656bf7d10c5f5327904d0ed0584fc57&pid=1-s2.0-S2096249524000152-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140469542","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":"Fast production and water-breakthrough analysis methods demonstrated using Volve Field data","authors":"Ruud Weijermars","doi":"10.1016/j.ptlrs.2024.03.001","DOIUrl":"10.1016/j.ptlrs.2024.03.001","url":null,"abstract":"<div><p>When producing from conventional fields, the well rates are primarily constrained by the production-system in the early years of the field-life, while later in the field-life the production rates are primarily constrained by the reservoir deliverability. For the post-plateau production period, the reservoir deliverability will no longer potentially exceed the production-system well-rate constraints. Traditionally, analytical equations are used in a nodal analysis method that balances the pressure at the well inflow point from the reservoir (inflow performance relationship; IPR) with the pressure required for the vertical lift performance (VLP; or vertical flow performance; VFP) from the same point upward. A faster and simpler approach is proposed in the present study. Whereas, the classical IPR solutions are based on a constant well-rate solution of the diffusivity equation, use of a constant bottomhole pressure assumption can bypass the need for nodal analysis type pressure matching solutions to obtain the well rate. Instead, the well rate can be directly computed from the pressure decline in the reservoir and any production system capacity constraint can be imposed on the theoretical well rate due to the reservoir quality. The merits of the new approach are explained and illustrated by way of a detailed production analysis case study using open-access data from the Volve Field (Norwegian Continental Shelf). In addition, the case study of the Volve Field wells demonstrates a new water-breakthrough analysis method.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 3","pages":"Pages 327-346"},"PeriodicalIF":0.0,"publicationDate":"2024-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000267/pdfft?md5=23717bd0560c98bc03299be69702ada5&pid=1-s2.0-S2096249524000267-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142173090","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}