Day 1 Tue, October 22, 2019最新文献

{"title":"Applying Machine Learning Methods to Search for Missing Net Pay Zones in Mature Oilfields Wells","authors":"D. Egorov, A. Sabirov, O. Osmonalieva, B. Belozerov, A. A. Reshytko, A. Klenitskiy, A. Shchepetnov, A. Semenikhin","doi":"10.2118/196869-ms","DOIUrl":"https://doi.org/10.2118/196869-ms","url":null,"abstract":"\u0000 The main aim of this work is to develop new approaches for processes of searching previously missed potential net pay intervals within wells from well log data of brownfields with machine learning algorithms. The practical interest for such a solution is an extraction of additional oil potential recovery from field data in order to prolongate development and production life of mature fields through development of system capable to automatically make recommendations on previously misinterpreted intervals.\u0000 Besides application of cognitive technologies the developed methodology includes also a workflow of cross-functional interaction of experts from different disciplines (geologist, petrophysicists) between each other and digital system. The system is based on modern deep learning architectures including convolutional and recurrent artificial neural networks. It utilizes well log data and corresponding interpretation of many specialists in order to accumulate or digitize a vast amount of previous experience. It can be used for the following robust re-interpretation of data in those parts of wells which were not previously considered in terms of net pay intervals but have high potential for new oil saturated thicknesses according to geological conditions and previous experience of manual investigation of such intervals.\u0000 The field test on a basis of described methodology was conducted on assets of Gazpromneft PJSC in Yamanlo-Nenets Autonomous Region, Western Siberia. The comprehensive volume of geological and geophysical information from oilfield was collected including well log data and corresponding results of expert interpretation. This information is used for model training and then predictions about previously uninterpreted intervals are made, providing business user a new interpretation of target geological objects. New interpretation produced by model was compared with current manual interpretation and new net pay intervals were considered as previously missed and potentially oil saturated. At the next step those intervals were examined by petrophysicists, geologists and reservoir engineers in order to estimate probability of oil saturation. Intervals with highest expert marks were proposed for field work and tested by perforation of the target zone. As a result of described process new net pay intervals were found and well, which was suspended, started a new production life. Obtained results confirm high potential of machine learning models application for search of new potential net pay intervals by helping an expert in daily geological and petrophysical tasks.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130202812","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":"Modeling of a Gas-Lift Well Operation with an Automated Gas-Lift Gas Supply Control System","authors":"E. Yudin, R. Khabibullin, I. Galyautdinov, A. Andrianova, K. Goridko, N. Smirnov, V. Babin, G. Chigarev, I. Lomukhin, Y. Murzaev","doi":"10.2118/196816-ms","DOIUrl":"https://doi.org/10.2118/196816-ms","url":null,"abstract":"\u0000 Gaslift operation faces several challenges - optimizing the amount of gas pumped, ensuring that the gas is pumped to the maximum possible depth, combating salt and hydrate formation and, finally, the instability of the flow. The timely detection of these problems and the optimisation of the system requires information on the dynamics of the main parameters (flow rates, pressure measurements at each unit and the amount of gas pumped). In the conditions of high cost of multiphase flowmeters at the Orenburg field well flow rates are not measured often enough, and the task of identification of the most unstable wells in real time by auxiliary parameters measured with greater discreteness becomes urgent.\u0000 Often important production decisions based on monthly data, and less often on daily measurements. In the paper the necessity to go down to the level of analysis of highly discrete information (dozens of measurements per day) is proved by the example of the Orenburg field, because in conditions of unstable operation the averaging inside the day can lead to distortion of the general view of the operating mode. Within the framework of the analysis of dynamic parameters of gas-lift wells operation in unstable conditions, the notion of well operation quality index was introduced, i.e. a normalized metrics reflecting the general state of stability of a gas-lift well operation. This metric considers uncoordinated changes in the main parameters of the system. The wells with the lowest index are the first candidates to search for hidden production losses (not achieving the regime flow rate).\u0000 Modelling of well performance, adaptation of models to historical data - a typical approach to production management in the field. But in the conditions of unstable gas-lift wells modeling of their work is much more complicated. In this regard, the authors of the article developed an approach to modeling wells through the approximation relationship between the flow rate of wells and the flow rate of gas-lift gas and linear pressure with further integration of well models with the collection system.\u0000 To solve well operation modes optimization problem, an integrated Proxy-model of the asset was created, which consists of a simplified reservoir model, developed well models and infrastructure model. The Proxy model was adapted and verified to the actual operating data. The task of finding the optimal distribution of gas injection between the wells from the point of view of oil production was solved.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"270 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126834348","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":"Pre-FEED CAPEX Evaluation: Speed Through Complexity?","authors":"S. Chizhikov, E. Dubovitskaya, M. Tkachenko","doi":"10.2118/196907-ms","DOIUrl":"https://doi.org/10.2118/196907-ms","url":null,"abstract":"\u0000 This paper gives riteria for developing successful expenditure estimation models for development of hydrocarbon deposits, as well as tools available to improve the estimation accuracy. The paper describes practical cases supporting efficiency of the proposed approaches.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"22 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116639072","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":"Wag Design: Miscibility Challenge, Tools and Techniques for Analysis, Efficiency Assessment","authors":"K. Fedorov, T. Pospelova, A. Kobyashev, Pavel Guzhikov, A. Vasiliev, A. Shevelev, Igor Dmitriev","doi":"10.2118/196758-ms","DOIUrl":"https://doi.org/10.2118/196758-ms","url":null,"abstract":"\u0000 WAG injection combines advantages of gas drive efficiency with mobility control and sweep enlargement due to simultaneous water-gas flow. A complex preliminary investigation is the basis of successful application of gases. Such investigation determines appropriate and available type of gas, attainability of miscible flood, technology of gas injection.\u0000 This paper combines modern achievements in theory and practice of gas application for EOR with new approaches for ternary phase and saturation diagram analysis, comparison of different gas injection technologies on saturation triangle and mobility control during WAG process. The proposed investigation workflow is presented on the example of real field in East Siberia.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114993279","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":"NMR Study of Reservoirs Containing Fluids with Anomalous Physical and Chemical Properties","authors":"A. Potapov, M. Zagidullin","doi":"10.2118/196930-ms","DOIUrl":"https://doi.org/10.2118/196930-ms","url":null,"abstract":"\u0000 The main goal of laboratory nuclear magnetic resonance (NMR) measurements is to verify the accuracy of the interpretation of nuclear magnetic logging (NML) data and to adjust this data to a petro physical model. To set up NML data for a petro physical model, it is necessary to perform laboratory NMR measurements, where the accuracy in studied samples depends on simulated saturation with one or other fluids.\u0000 In most cases, laboratory research comes down to fraction porosity definition on hydrocarbon-cleaned, desalted, dried and saturated with reservoir water samples.\u0000 Such formations as Bazhenov suite deposits and bituminous sands cannot be studied by NMR using the standard method. Carrying out the extraction leads to change of mechanical properties of samples: cavities appear in samples, they slough, storage capacity changes. Thus, storage capacity and mechanical properties will not correspond to their original properties. It is required to study these formations in naturally occurring saturated state.\u0000 If the hydrogen index of the saturating fluid is different from unity, then for reliable estimate of storage capacity, a correction for hydrogen index of studied fluid is applied. It is possible to determine hydrogen index of studied fluid in the volume with current methods (oil in the volume, oil-field water in the volume, or their mixture in a certain ratio also in the volume). It is not always possible to determine the hydrogen index of the fluids that saturate the studied rock in the laboratory directly for a number of reasons.\u0000 Kerogen, bitumen, heavy and light hydrocarbons and water are contained in the pore volume of the Bazhenov suite. (Manuilova, 2017) Bituminous sandstone formations contain extremely-high viscosity index oil with non-uniform viscosity and irreducible water. (Musin, 2015) In both of these cases, the average hydrogen index of the formation fluids is less than unity, therefore, the porosity determined by NMR will be underestimated. It is not possible to obtain fluid influx in the same ration like in a reservoir in these cases, so there is no chance to measure average HI of these fluids. Therefore, very important development stage of NMR technology is to determine the average HI of all fluids in the pore volume.\u0000 Authors proposed fluid hydrogen index (HI) determination method on naturally saturated core within this work.\u0000 The proposed method of hydrogen index determination is based on the registration of changes in the volume of the pore fluid by two methods before and after extraction. On one hand, the change in pore fluid volume before and after cleaning is determined by nuclear magnetic resonance. Due to the hydrogen index that is different from the unity, the apparent change in the pore volume fluid will be recorded. Apparent change of pore fluid volume in studied fluid will be recorded because of differing unity. On the other hand, the change in the same volume is determined by the gas volumetric method as the differ","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115471790","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":"Rapid Rock Nanoporosity Analysis Using Small Angle Scattering Fused with Imaging Data Based on Stochastic Reconstructions","authors":"M. Karsanina, V. Volkov, P. Konarev, V. Belokhin, I. Bayuk, D. Korost, K. Gerke","doi":"10.2118/196932-ms","DOIUrl":"https://doi.org/10.2118/196932-ms","url":null,"abstract":"\u0000 Through recent decade pore-scale modelling techniques matured enough to establish their robustness for relatively simple porous rocks, in particular porous media with a narrow pore-size distribution within the resolution window of the X-ray microtomography devices. But modelling of flow properties for rocks with significant amount of nano-scale porosity requires additional multi-scale structure studies. Current imaging techniques are too limited or time-consuming to cover necessary volumes of porous media. Thus, we are in search of a fast, yet robust methodology to assess nan-scale pore structure which can be used to inform pore-scale models and improve the accuracy of flow and transport predictions. In this work we report some preliminary results on the usage of the small angle scattering techniques to access the nano-scale structural properties for two complex rocks: chalk and Bazhenov formation siliceous rock (shale). The pore-size interpretation of X-ray small angle scattering results is compared against mercury porosimetry results and scanning electron microscopy. We argue that obtained results show qualitative agreement which provides an alley for future technology to combine small angle scattering with stochastic reconstructions. To further elucidate the power of such approach we perform 3D stochastic reconstructions based on 2D SEM images and simulate apparent gas permeability using pore-network model accounting for slip and (Knudsen) diffusion effects. Compared to laboratory measurements of gas permeability our results show surprisingly good agreement. We discuss obtained results and future developments of such a novel technology.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123910968","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":"Channel Fracturing Extension to Low-Temperature Formations. Field Case Studies in Russia.","authors":"A. Yudin, I. Glaznev, K. Lyapunov, O. Loznyuk, A. Korolev, Timur Khamidov, A. Prokhorov, M. Rylance","doi":"10.2118/196754-ms","DOIUrl":"https://doi.org/10.2118/196754-ms","url":null,"abstract":"\u0000 Channel fracturing technology has been a key enabler to unlocking hydrocarbon production from low-permeability formations in Russia for 10 years, by minimizing treatment costs and improving operational efficiency. However, an intrinsic limitation existed for candidate selection because the technique requires post-job dissolution of the fiber that is a principal component of the success of achieving efficient channel fracturing behavior. This set a lower temperature limitation of 60°C, such that formations with temperatures below this value were not recognized as potential candidates. This project was aimed at eliminating the temperature limitation and thereby enhancing the potential candidate pool for application.\u0000 The channel fracturing technique creates infinite-conductivity channels within a fracture, using a proppant-pulsing technique delivered by the surface equipment. Proppant structures are consolidated and transported along the fracture by means of fibrous material, which then degrades in the channels and proppant pillars within days after the treatment, conventionally because of the high formation temperature. Expanding hydraulic fracturing into new low-temperature oil provinces such as Eastern Siberia and the Turonian formation in the Yamal region called for adjustment in the channel fracturing technique. Specifically, surface equipment was used in a modified mode to alter the pumping schedule of the fiber additive to add fiber in pulses that are synchronized with proppant pulses.\u0000 The new channel fracturing methodology was designed and tested under laboratory conditions initially and then subsequently applied in several low-temperature (20 to 30°C) oil and gas fields/wells in Russia. The first campaign yielded positive results. New software and equipment adjustments allowed for precise and accurate synchronization that resulted in fiber-free channels. The first productivity results also illustrated the potential of the technology to match or exceed the planned hydrocarbon production. The main advantages of the channel fracturing technique remained unchanged—improved barrels/dollar ratio by up to 10% compared with conventional methods and fracturing cycle operational efficiency reduction of up to 25% as compared with standard techniques. Thus, the temperature limitation was removed, leaving one major criterion for channel fracturing applicability: rock competency to hold channels open and stable throughout the life of the fracture.\u0000 The study breaks new ground in the stimulation of low-temperature formations by extending the channel fracturing technique, well-recognized in the traditional basins of Russia. The project includes laboratory testing and real field examples from two regions of Russia—the first campaigns.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"48 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130002862","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":"Advanced LWD Technology Application at the Caspian Offshore Oilfields","authors":"M. Golenkin, M. Rakitin, D. Shtepin, A. Mityagin, L. Urmantseva, R. Golubtsov, V. Kuzakov, N. Shaymardanov, A. Cheprasov","doi":"10.2118/196959-ms","DOIUrl":"https://doi.org/10.2118/196959-ms","url":null,"abstract":"\u0000 Offshore oilfields are characterized by complex geological structure, such as presence of fault blocks, significant lateral changes of the rock properties. These features require accurate technology selection used during horizontal production wells drilling. Offshore drilling is fundamentally different from that on land, that requires a special selection of logging-while-drilling (LWD) technologies. The number of exploration wells is limited, therefore LWD tools and data interpretation should solve the problem of additional field exploration, that is impossible without advanced LWD technology application. Currently, LWD allows perform measurements similar to wireline logging – nuclear magnetic resonance logging (NMR), formation testing and obtain azimuthal density data. In addition, it is possible to perform measurements using reservoir-mapping-while-drilling service to solve geosteering tasks.\u0000 This paper discusses examples of optimal well placement within the target zone, considering integrated interpretation of advanced LWD data for reservoir properties estimation, reservoir pressure behavior understanding, and choosing completion strategy. According to reservoir-mapping-while-drilling service data interpretation, density azimuthal data the geological model was updated. To clarify the petrophysical properties LWD-NMR data were used. These data allow to obtain porosity estimation, permeability, residual water saturation coefficient, evaluate bottomhole formation zone damage. Formation testing data were used to estimate reservoir pressure and hydrodynamic parameters of the target zone. Integrated interpretation of LWD data has been used to select the most optimal design of lower completion scheme and to control the development of reservoir.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"34 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128829866","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":"Geology Driven History Matching","authors":"I. Matveev, G. Shishaev, G. Eremyan, V. Demyanov, O. Popova, S. Kaygorodov, B. Belozerov, I. Uzhegova, D. Konoshonkin, M. Korovin","doi":"10.2118/196881-ms","DOIUrl":"https://doi.org/10.2118/196881-ms","url":null,"abstract":"\u0000 This paper proposes the method of an automatic history matching (HM) with the ability to preserve geological realism and an example of its application in one of the fields in Western Siberia. The method assumes takes into account all identified uncertainties at the early stages of geological model construction and their synchronized variation within realistic limits during HM.\u0000 There are interrelations between petrophysical and geological uncertainties, which significantly affect on the reservoir dynamics. Hence, changes in one of the parameters during HM should influence the synchronous change of the others in order to preserve the geological consistency of the simulation model within the given geological concept. As a result, engineer gets a set of history matched models providing a range of predictions, which can be used for investment decisions.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"63 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125918049","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 Hybrid DPDP-DFN Modeling of Fractured Carbonate Reservoirs","authors":"Nikolay Shevko, Vil Shaislamov, O. Savelev","doi":"10.2118/196885-ms","DOIUrl":"https://doi.org/10.2118/196885-ms","url":null,"abstract":"\u0000 Predicting naturally fractured carbonate reservoir behavior is associated with fluid flow modeling of two and more mediums. Presence of highly conductive faults and fractures complicates the process. These complications are generally addressed by common approaches using DPDP models and modern techniques of explicit discrete fracture networks (DFN) modeling.\u0000 Dual porosity-dual permeability (DPDP) models do not provide proper results without significant modifications and improvements. Flow simulation of the whole fracture set in discrete format on full-scale models is computationally intensive and time-consuming task thus not applicable for practical purposes.\u0000 Alternative hybrid modeling approach based on combination of individual DFN objects (faults and long fractures) with traditional DPDP modeling was created based on detailed geological static model. Full scope of available geological, geophysical and production data was used to provide background for flow simulations.\u0000 Numeric algorithms were optimized for three mediums including single porosity medium (SPM), fracture medium (DFN) and discrete objects representing irregular fault and long fracture systems.\u0000 Generalized workflows for creating static model, defining fractured zones and explicit discrete objects, followed by DPDP-DFN hybrid modeling are described in this paper.\u0000 The proposed approach was utilized to perform full-scale model history matching, optimize well locations, estimate risks and uncertainties of gas injection efficiency.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126737361","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}