Day 1 Tue, November 15, 2022最新文献

{"title":"Gas-Steam Composite Stimulation: A Strategy for a Heavy Oil Reservoir with High Water Cut in Kazakhstan","authors":"Leihao Yi, E. Guo, X. Hua, Aijun Zhu, Chunxi Wang, Wenlong Guan, Yuexiong Wang, Xiantao Zheng, Yu E Zhao","doi":"10.2118/212100-ms","DOIUrl":"https://doi.org/10.2118/212100-ms","url":null,"abstract":"\u0000 North Buzachi field is structurally located in the western part of Ustyurt Basin on the edge of Caspian Sea in Kazakhstan. It's a heavy oil reservoir with viscosity nearly 400 mPa·s at 33°C. After nearly 20 years of cold-water flooding, the oil production has fallen sharply. Low sweep efficiency and high water cut come to be the main severe challenges at this stage. Ways to improve efficiency and productivity need to be tried and evaluated.\u0000 Water shut off tests, polymer flooding and adjusting perforations have been tried, but with little success. Thermal enhanced oil recovery (EOR) methods generally are effective options and cyclic steam stimulation (CSS) was considered. But the high-water saturation and water cut make CSS get rapid economic decline after 1 or 2 cycle. Therefore, the feasibility of Gas-Steam Composite Stimulation (GSCS) on this field is studied and evaluated. This paper shows the prospect of GSCS in this reservoir by studying flow mechanisms and numerical simulation analysis.\u0000 Gas-Steam Composite is a mixture of steam, carbon dioxide and nitrogen, which is produced based on a high-pressure jet combustion mechanism. The mixed components are simultaneously injected into the formation at the same pressure and temperature. GSCS has been tried in other similar oil fields (Mortuk oil field in Kazakhstan) before, and the actual production results are better than predicted. The application prediction of North Buzachi field was based on the previous theory and experience. During the GSCS progress, gas overlap occurs underground, resulting in secondary gas cap drive and higher reservoir pressure. Along with other synergistic effects, the oil rate can theoretically increase to 4-5 times of water flooding in North Buzachi field. By the results of numerical simulation, the upper residual oil was swept and the sweep efficiency increase from 14% to 40%. The daily oil production per well grows from the initial 3.5 t/d to 15 t/d. Compared with the final recovery of 12% by water flooding, the recovery may reach 33.4% after 7 cycles of GSCS. Meanwhile, the water cut declines from 97% to 50% and the average cyclic oil-steam ratio reaches 4.24.\u0000 Economical evaluation shows that cost per ton of oil can be reduced by 24%. With the remarkable increase in production, more economic benefits can be achieved with GSCS technology. This study not only lays the groundwork for future pilot of GSCS in this field, but also provides a significant reference for the development of similar heavy oil reservoirs.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"99 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125515033","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":"The Concept of Large-Scale Blue Hydrogen Production in West Kazakhstan","authors":"Y. Abuov, Didar Dauletbakov, Daulet Zhakupov, B. Suleimenova, Saule Zholdayakova","doi":"10.2118/212111-ms","DOIUrl":"https://doi.org/10.2118/212111-ms","url":null,"abstract":"\u0000 The challenge of meeting ever-pressing energy demand and reducing GHG emissions presents a significant challenge. One of the recent trends in the energy transition is hydrogen, which is experiencing unseen support from various stakeholders. Hydrogen roadmaps and net-zero strategies announced by governments and companies indicate that demand for low-carbon hydrogen will increase significantly. Therefore, it is essential to establish a reliable supply of low-carbon hydrogen. In our previous work, we have shown that Kazakhstan is located between the two largest hydrogen markets - China and Europe. Natural gas can be a feedstock material for low-carbon hydrogen, which is also known as blue hydrogen.\u0000 Kazakhstan holds the 16th largest natural gas reserves in the world. Nevertheless, finding feedstock natural gas for hydrogen in Kazakhstan can be challenging. In 2020, the gross natural gas production in Kazakhstan reached 55.1 bcm of natural gas of which 34.8 bcm and 20.3 bcm are commercial and reinjected volumes, respectively. Commercial volumes are tightly used for rising domestic market and export. Reinjection volumes are also tightly used to maintain the production of oil in the largest hydrogen reservoirs of the country - Tengiz, Kashagan and Karachaganak.\u0000 In our work, we propose an approach to use reinjected gas volumes for large-scale hydrogen production while keeping the oil production targets in the largest fields as before. CO2 emissions resulting from the hydrogen production would be used to replace currently reinjected natural gas in maintaining reservoir pressure. CO2 can decrease the viscosity of the reservoir fluid, thus enhancing oil recovery (EOR). This work presents the viability of the concept in the example of the Kashagan field by showing the material balance of both surface and subsurface processes. Several development scenarios were which also involved coproduction of elemental sulfur and methanol. Blue hydrogen production was modeled in Aspen Hysys v12.1.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116840702","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":"Improving the Approach to Assessing the Production Potential from Well Interventions for Mature Fields with a Large Well Stock","authors":"Darya Sun, E. Yudin, Andrey Slabetsky, D. Vorobyev, R.N. Studinskiy, Roman Martynyuk, A.Yu. Chervyak","doi":"10.2118/212065-ms","DOIUrl":"https://doi.org/10.2118/212065-ms","url":null,"abstract":"\u0000 This paper describes a comprehensive solution for the management of technological and economic potential, implemented using a digital information system (IS) - SPecTR, which includes a section of the Unified Register of geological and technical measures with automatic selection and multi-user expertise of geological and technical measures in the production and injection stocks, as well as Well Intervention Efficiency Monitoring section.\u0000 A significant advantage of the information system under development is the maximum automation of the entire selection process and subsequent monitoring of success: from the input data needed to calculate, i.e. technological modes of operation of wells, isobar maps, porosity and permeability, initial and residual oil saturated layers, well logging data interpretation results, well coordinates, charts, PVT data, etc., - to to determination of the risks to the performance of light and heavy well interventions for each specific well, calculating incremental oil flow rates and economic viability for the selected well intervention candidates, conducting factor analysis of achieving the planned effect of well interventions, etc.\u0000 The described system provides for a unified approach to determining the technological (production) potential for various Gazprom Neft's assets. At the same time, the system can be called flexible since it enables users from various Subsidiaries to \"customize\" the candidate selection process with account of specifics of their assets: by including additional selection criteria in the selection process, adjusting thresholds, setting well intervention design parameters for calculating the target conditions, etc.\u0000 The SPecTR system is currently implemented and has been undergoing commercial operation at 9 Subsidiaries of Gazpromneft.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131416642","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":"World's Longest DTS Cable Run for Permanent Monitoring Below ESP - A Successful Solution for West Siberian Wells Surveillance with ESP Systems - Case Study","authors":"N. Nifontov, A. Maltsev, N. Vikulin, P. Ten, Nikolay Torsunov","doi":"10.2118/212094-ms","DOIUrl":"https://doi.org/10.2118/212094-ms","url":null,"abstract":"\u0000 This article describes evolution of well design concept for Vikulovskaya oil rim reservoir development with no possibility for fracking and first World's longest application of permanent monitoring solution for appraisal multilateral well with the access to the wellbore restricted by presence of ESP pump in West Siberia inside 7″ casing and 4.5″ production liner Horizontal Multilateral well.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"32 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117094220","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":"Simulation-Based Evaluation of Concurrent CH4 Storage Potentials During CO2-ECBM in Karaganda Coal Basin","authors":"Yernar Tiyntayev, Omirzhan Tursymat, Galymzhan Serikov, Mohammad Asif, Lei Wang, R. Hazlett","doi":"10.2118/212076-ms","DOIUrl":"https://doi.org/10.2118/212076-ms","url":null,"abstract":"\u0000 Karaganda Basin contains the largest coalbed methane (CBM) reserve in Kazakhstan. We previously modelled the enhanced coalbed methane (ECBM) process by injecting CO2 into a typical well group which showed high production potential. With the global agreement on carbon neutrality, it is advantageous to explore the CO2 storage potential during CO2-ECBM in Karaganda Coal Basin. The CO2 storage potential of a given coal seam volume in the Karaganda Coal Basin is evaluated by setting up an extended 5-well pattern in a compositional reservoir simulator. The CO2-ECBM process is simulated by incorporating the reservoir parameters reported for the Karaganda Coal Basin, with variable CO2 injection rate and well pressures to optimize the injection strategy, such as the necessity of well stimulation. Simulation results showed that primary depletion followed by CO2 injection is a promising win-win strategy. Based on parameter sensitivity analysis, the CO2 injection rate should have an optimal value under pressure constraint, since higher injection rate does not contribute remarkably to the recovery. With the aid of CO2 injection, the methane recovery could be enhanced from 35.1×106 kg to 40.2×106 kg by 14.5% during the 4-year CO2 injection at constant rate of 60,000 m3/day with constraint pressure of 15,000 psi. Correspondingly over 99.98% of injected CO2 can be concurrently stored in the form of adsorbed and free gas in these case scenarios. Simulation results suggest that commercial CBM production could be established in the Karaganda Coal Basin, if properly implemented; meanwhile, the process entails enormous potential for CO2storage and represents a new opportunity for the Karaganda coal industry.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"146 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130929839","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":"Field Development Optimization Under Uncertainty and Risk Assessment of Carbonate Massive Reservoir in West Kazakhstan","authors":"Asfandiyar Bigeldiyev, Samat Ramatullayev, D. Kovyazin, D. Sidorov, V. Malyshev, Gernort Vogtlander, G. Wall, D. Lungershausen, Talgat Nauruzov","doi":"10.2118/212062-ms","DOIUrl":"https://doi.org/10.2118/212062-ms","url":null,"abstract":"\u0000 Reservoir modeling has become an indispensable tool in the oil and gas industry to measure risk associated with alternative production scenarios. It is no secret that nowadays more and more operators use deterministic approach for history matching but even so, the task remains technically challenging. Given a large number of uncertainties associated with subsurface models, it has become critical to produce a set of history-matched models and use them for risk assessment in predicting the future performance of the reservoir.\u0000 Quantification of uncertainties is a vital process in complex fields to ensure a proper field development plan (FDP) is in place. In this paper, we present a comprehensive workflow that incorporates all processes from building static and dynamic models to producing ensemble of history matched models. To assess the mismatch with historical production data, a number of geological realizations were created and simulated using a variety of uncertainty parameters. Based on the obtained mismatch value, the posterior probability distribution for uncertain parameters updated. Different optimization methods are used to find candidates with improved match quality, and this loop is repeated until a set of diverse history-matched models are generated. These calibrated reservoir models are then used to estimate prediction uncertainties for further FDP optimization.\u0000 This study is focused on automating workflows and generating multiple geological realizations that produce a set of history-matched models to probabilistically estimate prediction uncertainties and optimize FDP. We also show how these models are critical in the process of decision making and risk evaluation.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124486519","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":"Uncertainty Analysis Using Multi-Scenario Modeling Approach: Kashagan Field Case Study","authors":"Ilyas Saurbayev, P. Nurafza, S. Price, C. Tueckmantel, A. Jamankulov, Gadilbek Uxukbayev, Liviu Ionescu, B. Haynes, Dachang Li, R. Saifutdinov","doi":"10.2118/212060-ms","DOIUrl":"https://doi.org/10.2118/212060-ms","url":null,"abstract":"\u0000 This paper will present a case study of an Uncertainty Analysis recently performed for the Kashagan Field. This is the first full scale uncertainty work performed on the field since it came online in September 2016. The paper will describe unique challenges given Kashagan peculiarities and describe methods and approaches taken to address those.\u0000 A multi-scenario modeling workflow has been utilized to fully explore subsurface uncertainties in the decision space. First, uncertainties that were believed to have an impact on field performance based on the available data and learnings from previous studies were identified and ranked. Then, so-called categorical parameters were combined by grouping geologically relatable parameters into several scenarios with differentiating behaviors which were checked by performing screening simulation runs. This was followed by Design of Experiment (DoE) runs (Placket-Burman and Latin Hypercube), proxy modeling and Monte-Carlo analysis to aid selection of high, mid, and low models.\u0000 More than 400 simulation runs were generated resulting in a wide range of outcomes for key performance indicators, enabling the selection of high, mid, and low model realizations to evaluate future field development decisions. The approach of combining categorical parameters into multiple scenarios followed by DoE runs offered several advantages including full sampling of the uncertainty space and clearer link between geologic input and dynamic output. It also allowed to get maximum information using the lowest number of simulation runs. Communication techniques such as plumbing diagrams representing geologic scenarios were effective in discussion of study results amongst experts.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"68 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124246267","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 of a Semi-Analytical Model of Gas Breakthrough to Horizontal Wells in Gas Cap Zones of Oil Rims Considering Heterogeneity of Reservoir Distribution","authors":"A. V. Elesin, D. A. Samolovov, R. Apasov","doi":"10.2118/212101-ms","DOIUrl":"https://doi.org/10.2118/212101-ms","url":null,"abstract":"\u0000 The paper describes the experience of creating a semi-analytical model of gas breakthrough to a horizontal oil well located in the subgas zone of an oil rim. A physical-mathematical model is described, examples of using the model to predict the displacement characteristics of actual wells and using the model in the process of reservoir history matching are considered.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"98 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124078831","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":"Sand Production in Two-Phase Gas-Water Flow","authors":"Ainash Shabdirova, F. Khamitov, A. Kozhagulova, Minh Nguyen, Yong Zhao","doi":"10.2118/212054-ms","DOIUrl":"https://doi.org/10.2118/212054-ms","url":null,"abstract":"\u0000 Sanding phenomenon is a severe problem in the oil and gas fields found in weak unconsolidated formations. While previous experimental researches mostly studied single-phase fluid flow, it rarely happened in real reservoirs. This study presents a novel approach to investigating sand production mechanism from multiphase fluid production through experiment of large specimen size, and a coupled Computation Fluid Dynamics – Discrete Element Method (CFD-DEM) modelling for two-phase flow. The sand production experiments on a weak artificial sandstone were conducted under one-phase and two-phase flow conditions: water flow in water-saturated and gas flow in water-saturated samples using a customized High-Pressure Consolidation System (HPCS). The coupled CFD-DEM numerical simulations of similar conditions were conducted to capture the salient features of sanding behaviour at micro-levels. The discontinuous nature of sand particles and the bonds between them were modelled using DEM, whereas the continuous fluid flow was described by CFD. The experimental results showed that more sand was produced by the two-phase flow of gas through an initially water-saturated sample as compared to the single-phase water flow. The numerical results on the other hand showed different internal void fraction distributions between the two cases, which led to a faster fluid outflow and a slightly higher sand production for the multiphase flow case. The experimental and numerical results were however limited by the experiment duration and the simulation time of an otherwise on-going sand production process.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128830944","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":"Geothermal Energy in Caspian Region: Study of Heat Extraction Methods from Deep Wells","authors":"D. Abdrazakov","doi":"10.2118/212075-ms","DOIUrl":"https://doi.org/10.2118/212075-ms","url":null,"abstract":"\u0000 Geothermal energy currently occupies an insignificant role in the renewable energy balance. This is explained by its low heat flow rate and the significant investments associated with heat mining. However, the geothermal heat flow is continuous and non-interruptible and occurs everywhere in the lithosphere. Existing oil and gas fields’ subsurface and surface infrastructure and expertise can significantly decrease capital expenditures for geothermal heat extraction. Taking this idea as a basis, the study of geothermal heat production from existing oil and gas fields of the pre-Caspian region of Kazakhstan was performed.\u0000 Since this work is one of the first attempts to estimate the geothermal heat potential of the existing oil and gas industry infrastructure in Kazakhstan, the study consists of two big parts. First part is the detailed theoretical review of the geothermal heat extraction methods which may be potentially applied in Kazakhstan. Special attention in the literature review section was given to enhanced geothermal systems and closed loop systems, because they have many technologies in common with the oil and gas industry (completion concepts, hydraulic fracturing etc.). Second part is the quantitative estimation of the geothermal potential based on twenty oil fields, with several wells in each field as trial sites. Quantitative estimation considers pragmatic and optimistic scenario of future investments.\u0000 The study showed that even in the pragmatic scenario in which the water-producing wells are turned into hydrothermal producers, the recoverable effective heat reaches 420 TJ in total for all wells in the selected fields. However, the demand for the geothermal heating of the industrial and household objects near the selected fields was estimated to be three times higher. Thus, a more proactive geothermal strategy was considered. This strategy yields ~9800 TJ of recoverable effective heat, which covers the demand and provides excess for the growth. Based on the reservoir properties and economic perspective estimations, it was defined that enhanced geothermal systems and closed loop systems will be less abundant in the given region in a short term. However, with development of the geothermal technologies and increase of investments, these systems may have increased importance. On the other hand, direct hydrothermal producers and well doublets (injector connected to producer through the permeable reservoir), most probably, will be a prevailing method of the geothermal heat mining in the pre-Caspian region of Kazakhstan in the short and medium terms.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123544345","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}