Day 2 Tue, October 16, 2018最新文献

{"title":"On the Mechanisms of the Formation of Zones with Abnormally High Rock Pressure and Methods for Predicting them in Undeveloped Rock Systems","authors":"A. Islamov, D. Kolupaev, R. Faskhutdinov, S. Vereschagin","doi":"10.2118/191501-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191501-18RPTC-MS","url":null,"abstract":"\u0000 To the list of the most serious and uncontrolled geological complications arising during the drilling of wells, it is well known the Oil, Gas and Water Shows (OGWS) which often happens in areas with formed waterflooding zones. Risks result from the lack of the ability to predict the location of Abnormally High Reservoir Pressures zones (AHRPZ) due to high uncertainties in the movement of the injected fluid in formation.\u0000 Oversight of the meeting of reservoir zones with high reservoir pressure is conducted on the basis of a number of analytical tasks: making water-oil factor maps, ping the front of the injection water in formation, pressure (isobar) maps, drilling history, special field geophysical tests for formation cross-flows, CO-logs across not perforated productive intervals.\u0000 However, by using the classical development tools, it is possible to solve the issues with predicting the potential high pressure zones in the flooded reservoirs, but how we can predict the abnormal pressure systems in reservoirs that are not under development and carry exclusively technogenic genesis?! In this paper we will talk about the forecasting possibility of the abnormal pressures in the transit reservoir systems using the example of the Priobskoye oilfield. Those systems are not involved in the development process either because of the lack of hydrocarbon reserves or because of the absence of the reservoir at all. The authors hope that this materials allow to describe the tools that will protect other colleagues from complications related with well drilling and their re-drilling with associated material costs.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124679750","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 Integrated Approach to Permeability Adjustment Based on the Simultaneous Well Log and Well Test Interpretation","authors":"E. Maksimova, N. A. Parfenov, B. Belozerov","doi":"10.2118/191690-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191690-18RPTC-MS","url":null,"abstract":"\u0000 Nowadays, efficient field development cannot be imagined without the integrated interpretation of field data with different scale – core, well logs, and formation testers. The above mentioned methods allow definition of permeability values, which can be used during the geological and simulation modeling. However, it should be highlighted that there is no unified approach to permeability adjustment which may lead to unclear connections between absolute gas permeability (core, log) and effective permeability (well test) in reservoir models. As a result correct quantitative description of field development parameters could be questioned.\u0000 The present work considers the creation of the workflow for adjustment of core and therefore logs absolute permeability on field values, estimated from formation testing operations. It can be expected that the adjusted permeability values will describe the filtration process more correctly.\u0000 During the workflow creation the field with clastic deposits and special logging complex was analyzed. The permeability adjustment workflow, which consisted of several steps, was developed. First of all, absolute log permeability values were obtained taking types/facies into account. Then continuous log effective permeability curves were estimated based on the equations, derived during the analysis of PVT-properties and SCAL data. Finally, the comparison between log and well test permeability was performed.\u0000 It has been discovered that the developed methodology can be valid for clastic field with unconsolidated deposits. The transformation from average well test permeability to continuous log effective permeability was mathematically validated. Furthermore, it was shown that estimation of continuous fractional flow values can be performed for several intervals. Besides, calculated log mobility can be used for prediction of layers for which water filtration process can be faster.\u0000 The results, which were obtained during the workflow application, are planned to use during further simulation modeling. This can provide the improvement of development process prediction during the simulation modeling and future field development.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122384315","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":"Study in Efficiency of Acid Compositions Application in the Clastic Reservoirs of Perm Region Based on Experimental Studies of Core Sample","authors":"V. Plotnikov, P. Rekhachev, N. Barkovsky, A. Amirov, N. Mikhaylov, S. Popov","doi":"10.2118/191667-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191667-18RPTC-MS","url":null,"abstract":"\u0000 The paper considers results of laboratory experiments on the effect of an acid composition consisting of hydrochloric and hydrofluoric acids on core samples taken from clastic reservoirs in Perm Region. The research included determination of porosity and permeability properties of the samples before and after treatment with the composition, taking anisotropy of rock properties into account. The paper presents the research program and the experimental results obtained that showed a significant change in permeability after filtration of the acid composition and the influence of anisotropy on this parameter. The specific feature of the research carried out is the study of the combined effect of the acid reagent and varying effective stresses on permeability of core samples.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114155017","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":"Forecast of Well Drilling Events in Salt Bodies Based on Geomechanical Modeling for Eastern Part of the Orenburg Oil and Gas-Condensate Field","authors":"Dilia Galliamova, O. Kalinin, P. Lukyanov","doi":"10.2118/191633-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191633-18RPTC-MS","url":null,"abstract":"\u0000 The paper is dedicated to problem of forecast of well events drilling through nonproductive reservoirs at shallow depths: mud losses, wellbore instability due to salt tectonics, mud and reservoir temperatures difference and drilling time. Problem of forecast in those zones is complicated because of insufficient amount or complete lack of core tests, well loggings and noisy of seismic data.\u0000 There is three-dimensional geomechanical modeling was showed with taking into account thermal stresses and time factor in the clay and salt zones on the example of the Eastern part of the Orenburg oil and gas condensate field. Also geological features were analyzed for prediction of mud losses zones.\u0000 As a result of modeling, a relationship was found between the drilling mud losses and the wells location with respect to the sides of the salt folds and domes, which are accompanied by the development of natural fracturing. While well is drilling in overbalanced conditions in these zones, fractures and faults become critical stressed, which leads to their reactivation and mud infiltration. The trajectory can not be significantly corrected in the 300-800m depths so well schematic recommendations are reduced to a warning about the zones of possible losses.\u0000 Wellbore stability calculation with taking into account the temperature effect shows an increase or decrease (depending on the drilling season) of the stresses, acting on the wall of the borehole up to 10 MPa; the influence in salts is greater than in clays. Taking into account time factor showed that long-term drilling with high mud density can lead to numerous stuck pipes and tight pulles.\u0000 The obtained results make it possible to clarify wellbore stability calculations and, accordingly, the intervals of borehole failures. The prediction of critical stressed zones allows to warn the intervals of drilling mud losses. Thus, due to the combination of these approaches, it is possible to reduce the nonproductive time of well drilling and choose candidate wells for an optimized well design.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"26 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132811997","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":"Prospects for the Spectral Noise Logging Application in the Analysis of Stimulated Reservoir Volume in Horizontal Wells with Multistage Fracturing","authors":"V. Nagimov, A. Alekseev, E. Tolmachev, Yu. V. Maslennikova, I. Shigapov","doi":"10.2118/191488-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191488-18RPTC-MS","url":null,"abstract":"\u0000 The most effective technique of low-permeability reservoir development is multistage hydraulic fracturing (hydrofrac) in horizontal wells. One of the specific features in operating such wells is that in the vast majority of cases flow rates from the created fractures are insignificant and remain below the sensitivity threshold of most tools that are part of the conventional production logging suite. In addition, development of unconventional reservoirs, such as Bazhenov formation, requires application of special hydraulic fracturing techniques. Therefore, estimation of the contribution from each frac stage into the total production and diagnostics of active fracs are essential and challenging tasks. To solve these tasks, the production logging suite that was run in a horizontal well to Bazhenov formation included Spectral Noise Logging tool which can not only locate the flow zones but is also suitable for identification of the flow zone type. This paper discusses the approaches to Spectral Nose Logging data analysis focused on the problem mentioned above and provides several case studies dealing with application of the production logging suite supplemented with SNL in a horizontal well drilled in Palyanovo area of Kranoleninsk field where multistage fracs had been carried out in the Bazhenov Deposits.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"8 12","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114028539","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":"Experience and Optimization of Essential Multistage Fracturing Technology with Coiled Tubing at the Well for the Vinogradova Oilfield","authors":"N. Parshin, K. Burdin, K. Starodubtseva, M. Novikov, M. Demkovich","doi":"10.2118/191720-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191720-18RPTC-MS","url":null,"abstract":"\u0000 In the article presented 2 years of experience gained during multi-stage hydraulic fracturing (MSF) on 17 wells, by means of coiled tubing (CT) without lifting it to the surface, performed in years 2017 – 2018 on Vinogradova oilfield, KhMAO, Russia. In 2017 it was successfully implemented innovative technology, where fracturing operations are combined with coiled tubing (CT) operations and are run together with CT inside the well. Current method is based on operating reusable fracturing ports, where opening and closing is carried out using coiled tubing with subsequent performace of MSF along the CT/Tubing annulus. During these jobs, considerable experience was gained, the technologies were optimized and raised issues solved, including excessive abrasive wear of the coiled tubing pipe, leaks, etc.\u0000 Vinogradova oilfield is a unique oil-saturated low-permeable reservoir with a small effective thickness, characterized by considerable stratification and gas-saturated porous layers.\u0000 MSF technology demonstrated high efficiency and proved its reliability. Starting from February 2017 till June 2018 it was 17 wells accomplished, where 246 fracturings were carried out. All the wells were successfully commissioned. The implementation of innovative approaches to multi-stage hydraulic fracturing while coiled tubing remains in the well, resulted in 2-fold work time reduction, while the amount of frac ports doubled per well. The time frame of CT work between fracturing stages was minimized from 4 to 1.5 hours. During the job on one of the wells, it was encountered a leak in the completion (liner) in the shoe area, in order to continue MSF job, the isolation packer was run and temporary installed, which allowed to accomplish the operation.\u0000 The performance of MSF technology without lifting coiled tubing to the surface proved its efficiency and economic feasibility, becoming more and more popular among operating companies, it has great potential for future implementation both in Russia and in the rest of the world. The area of distribution and application of MSF using CT is growing every year, the most relevant technology found in oil fringe with a gas cap or bottom water. The accumulated experience in this project creates the basis for the wide introduction and application of technology on other projects","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121892655","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":"Assessment of Reactivated Natural Fractures Influence on Overall SRV During Multi-Stage Hydraulic Fracturing","authors":"A. Gula, A. Bochkarev, A. Vishnivetskiy, R. Nikitin, Y. Ovcharenko, D. Alchibaev","doi":"10.2118/191629-18rptc-ms","DOIUrl":"https://doi.org/10.2118/191629-18rptc-ms","url":null,"abstract":"\u0000 This work is devoted to the development of methods for determining the stimulated reservoir volume (SRV) taking into account the contribution of natural fractures hydrodynamically not connected with technogenic one with the example of Western Siberia reservoir. At present, more and more fields with a complex geological structure, including low-permeability reservoirs, require effective technologies for exploitation, which in turn has led to the massive applying of horizontal wellbores and technologies of multistage fracturing. Modeling of multistage fracturing is a complex process that requires an understanding of the mechanical behavior of the formation, cracks and faults. The cracks formed during the hydraulic fracturing change the stress field around it, this effect is called the shadow stress effect. Natural fracturing can have a significant effect on production rates, in particular, on the hydrodynamic connection of the reservoir and the migration path of fluids. If stress shadow effect of the technogenic fracturing is taken into account, then can be additionally taken into account the reactivated natural fractures with induced stresses as well.\u0000 In the process of the work, mechanisms of formation of natural fracturing were determined on the basis of seismic attributes and reconstruction of paleostresses, a natural fracture network model was constructed using geomechanical information. The results obtained during the construction of a NFN play one of the key roles for the modeling of the multistage fracturing in fractured reservoirs allows to take into account information on the intensity and direction of development of natural fracturing in addition to mechanical properties: elastic and strength characteristics of rocks.\u0000 In this paper, we demonstrate the results of a numerical evaluation of multistage fracturing influence in the change of the stress field. The stress field, modified during the stimulation, was used to assess the critical stress fractures, which allows increasing the stimulated reservoir volume due to reactivated natural fractures. Such cracks do not need to be fixed, since they are formed by sliding along the plane of failure with small changes in the stress field and give an additional contribution to the total area induced fractures.\u0000 The demonstrated technique allows to maximize the area of induced fractures and increase the stimulated reservoir volume by taking into account the critically-stressed one.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114064187","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":"A Comprehensive Approach to Achieve Record Performance on the field named after V. N. Vinogradova","authors":"S. Yakunin, E. Kashin, A. Shtyfel","doi":"10.2118/191519-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191519-18RPTC-MS","url":null,"abstract":"\u0000 JS \"RITEK\" since 2008 engaged in the development of deposits named after V. N. Vinogradova. Geological oil reserves are more than 100 million tons of oil and are hard to recover reserves. Target horizon is AS3. Development of the field. V. N. Vinogradov was carried out in several stages. The first stage took place at the end of 2008 and involved the well re-entry and re-testing of exploration wells of the field. The next stage was the drilling of horizontal wells with multi-stage hydraulic fracturing. The horizontal wells have the standard design: direction Ø324 mm – 50 m, conductor Ø245 mm – 800 m, production casing Ø178 – 2000 m and a liner with a long horizontal section Ø114 mm – 500 m. Over the past few years the development of the field, the length of the horizontal section increased from 500 m to 1600 m. For the successful drilling of wells with horizontal section of 1600 metres was conducted the work on optimization of equipment, technologies and parameters of drilling a conductor casing string and the shank. The article presents technical and technological solutions for drilling optimization.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129322604","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 Formation Pressure While Drilling FPWD Technology in Challenging Low Mobility Environment – Case Study from Western Kazakhstan","authors":"Samat Ramatullayev, A. Makhmotov, M. Zhabagenov, Dastan Ospanov, Yura Markelov, A. Navrotsky, Yerlan Gabdyzhamalov, Ruslan Nurgaliyev, G. Maletti, T. Assanova","doi":"10.2118/191696-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191696-18RPTC-MS","url":null,"abstract":"\u0000 Historically, pressure measurements have been performed with wireline formation tester (WFT) tools. In highly deviated and horizontal wells, wireline tools are drill-pipe conveyed and this operation can be complex and adds significant expenses and operational risks. On the other hand, formation pressure while drilling (FPWD) technology minimizes operational risks at reduced overall cost and results in increased operational efficiency. This is particularly true for highly deviated and horizontal wells.\u0000 FPWD technology has its own application envelope. Low permeability reservoirs are traditionally considered to be \"no-go zone\" for FPWD. Reason being nearly all FPWD tools on the market are equipped with a single probe that has a modest flow area. Whenever formation exhibits extremely low mobility, in the order of 0.1 mD/cP or lower, operators prefer to opt for configurations that increase the flow area such as dual packer conveyed on wireline, despite the added cost and conveyance risk. However, proper job planning and real-time data transmission allows to acquire critical reservoir dynamic data with FPWD tool in challenging low-permeability environment in horizontal wells with reduced operational risks.\u0000 The following paper discusses the first successful application of FPWD technology in horizontal wells drilled in low permeability giant carbonate reservoir located in Western Kazakhstan. It focuses on the approaches taken during job planning and execution, dwells upon the acquired results and offers a methodology on how to optimize the acquisition. It is worth noting that fluid mobility in some stations was below 0.1 mD/cP, making it an extremely challenging environment. Nevertheless, the results acquired in eight wells has proven that FPWD can perform effectively and provide crucial reservoir dynamic data in separate clinoforms and gain insights about reservoir depletion mechanism, which was previously inaccessible due to operational risks related to formation tester tools conveyance in horizontal wells.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129604542","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":"Expanding Boundaries of Multistage Hydraulic Fracturing with Coiled Tubing in Novoportovskoe Field","authors":"A. Belov, S. Tishkevich, S. Simakov, A. Kichigin, K. Burdin, Movsar Maskhadov, A. Ishangaliev","doi":"10.2118/191719-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191719-18RPTC-MS","url":null,"abstract":"\u0000 Today, when most reservoirs have low productivity, the question of whether hydraulic fracturing can be applied to the oil rims becomes very important. It was revealed that the efficient way to compensate the fractures and formation contact area under conditions of a necessary hydraulic fracturing reduction was the implementation of a special well completion technology, during which renewable frac sleeves were installed in the fullbore diameter of a liner, with sleeve density being increased for a reliable coverage of the well horizontal spacing with longitudinal fractures (Ishangaliev et al., 2017).\u0000 In the complex geological conditions of the Novoportovskoye field, a fundamentally new solution was proposed for horizontal well completion – full bore MSF system with sliding sleeves, operated by hydraulic shifting key with coiled tubing (CT). This completion system allows to perform MSF without pulling CT out of the well to the surface and instantly use CT for well clenout in the case of screenout (SO). This decision is aimed to increas production and achive economic efficiency of the field development by increasing the formation coverage by means of larger number of MSF stages per well, and optimizing costs by reducing the time for the entire range of work at the well, that was detailed described by Kazakov et al., 2017.\u0000 An outstanding example of oil rim stimulation and application of new technology was a project in Novoportovskoye field where 30- and 27- stage mulstistage fracturing operations were successfully performed with shifting ports comopletion operated by coiled tubing.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"32 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121964164","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}