|Theme||Visible||Selectable||Appearance||Zoom Range (now: 0)|
Golenkin, Mikhail Yurievich (LUKOIL-Nizhnevolzhskneft) | Eliseev, Denis Vladimirovich (LUKOIL-Nizhnevolzhskneft) | Zemchikhin, Alexander Anatolyevich (LUKOIL-Nizhnevolzhskneft) | Borisenko, Alexey Alexandrovich (LUKOIL-Engineering) | Atabiyev, Akhmat Sakhadinovich (LUKOIL-Engineering) | Sorokin, Eduard Viktorovich (LUKOIL-Engineering) | Mikitin, Yevgeniy Orestovich (LUKOIL-Engineering) | Khusainov, Aidar Biktimirovich (Baker Hughes) | Liplyanin, Andrey Valeryevich (Baker Hughes) | Sidorov, Andrey Valeryevich (Baker Hughes) | Bashirov, Rustem Talgatovich (Baker Hughes) | Goryachev, Sergey Anatolyevich (Baker Hughes)
Abstract The paper describes the results of the first multistage hydraulic fracturing operations in Russia on the Caspian Sea shelf in the gas condensate and oil deposits of the Aptian formation of V. Filanovsky field. In addition to the small productive formation depth, long horizontal sections with a complex trajectory and high collapse gradients due to large zenith angles when passing the Albian and Aptian deposits of poorly consolidated sandstones are an additional challenge for choosing a multistage hydraulic fracturing assembly. The above features require the use of modern sand control screens with enhanced frac sleeves. A design was developed which includes frac sleeves and sand control screens that can withstand multiple cycles of hydraulic impact during hydraulic fracturing, as well as many opening/closing cycles. A seawater-based frac fluid system was applied. The frac fleet was located on a pontoon, the coiled tubing – on a platform. For the first time in Russia, a 2-5/8 inch coiled tubing with a complex-type friction reducing system was used to switch coupling/sleeves in conditions of very long horizontal sections, complex trajectories, and high friction coefficients. The minimum distances between the screen's sliding sleeves and frac sleeves did not prevent from performing manipulations in complex environment. For well cleaning, the frac assemblies of reverse rotary-pulse and rotary-directional types were used. At the first stage of the project, the development of an optimal method of well completion was successfully implemented. Due to the close interaction of the operating company, service company, and science & engineering team of the operator, for the first time in Russia the design of downhole equipment with the use of advanced technologies of sand control screens, frac sleeves was presented. This solution has proved its effectiveness – the downhole equipment has retained its operational properties after a long period of well operation and further in the process of hydraulic fracturing. At the second stage of the project, 32 MSHF operations were performed at four wells. To reduce nonproductive time and operational risks, a satellite communication complex was additionally deployed on the pontoon to join the engineering centers of Astrakhan, Moscow, and Houston. After finishing the well development, the design indicators for formation fluid rates were achieved, which proved the effectiveness of the stimulation of the field's target objects – this opens great prospects for further development of low-permeability reservoirs at offshore sites in the Caspian Sea. The successful project implementation and the achievement of the design values of oil flow rates has expanded the possibilities of commercial operation of the low-permeable Aptian formation, complicated by the presence of a gas cap and underlying water. A solution was presented for working in extended horizontal well sections with 2-5/8 inch coiled tubing together with a complex-type mechanical friction reducing system. The economic effect was achieved when solving tasks of manipulating mechanical screen couplings and frac port sleeves without the involvement of downhole tractors. The use of new solutions in the completion assembly made it possible to eliminate additional sand ingress problems.
Alekperov, V. Yu. (LUKOIL PJSC, RF, Moscow) | Lyashko, N. N. (LUKOIL PJSC, RF, Moscow) | Gavura, A. V. (LUKOIL-Engineering LLC, RF, Moscow) | Fedotov, I. B. (LUKOIL-Engineering LLC, RF, Moscow) | Kibalenko, I. A. (LUKOIL-Engineering LLC, RF, Moscow)
The PDF file of this paper is in Russian. Based on oil and gas fields discovered by LUKOIL PJSC, a new oil-producing region of the Russian Federation is being formed in the northern part of the Caspian Sea. To increase the technical and economic efficiency of field development under the conditions of technical, technological and environmental restrictions at sea, and to overcome adverse mining and geological conditions of occurrence of petroleum reserves, a proposal of a large-scale application of field development systems with horizontal wells was put forward. The article describes the main results of the development of the Kravtsovskoye (D-6) oil field discovered in 1983 and set by the Company in 2004 into the operation and located in the Baltic Sea. The entire production well stock, implemented at the field, consists of wells with horizontal wellbores. At the Neocomian and Volgian deposit of Yu. Korchagin (Northern Caspian) field, set into operation in 2010, all production wells have a horizontal completion as well. The length of several wellbores along the reservoir reaches 4,900 m. The operational experience obtained from these development targets became the basis for project solutions for new fields in the Northern Caspian. At the largest production target of this region - the Neocomian deposit of V. Filanovsky field - production drilling was started in August 2016. All project production wells and injection wells (except for one) of this deposit are horizontal ones. To develop other production targets of the V. Filanovsky field (Aptian and Albian), all exploitation targets of the satellite deposits (Rakushochnoye field, S. Kuvykin field, 170 km field), the development strategy with horizontal wells has also been planned. Their feasibility and efficiency are demonstrated by detailed simulation using modern methods and tools and confirmed by the conclusions of the state expertise.
Abstract This paper demonstrates the approach to field development that involves geomechanical expert analysis at early stages of planning and development. One of the most important problems raised today by geomechanics experts is late involvement of geomechanical analysis and review in the field lifecycle and its usual occurrence only at the development stage. Such approach might lead to a significant reduction in the spectrum of solutions and opportunities to be used in drilling and subsequent production. The need for geomechanics was identified early at the stage of the field development plan preparation for the V. Filanovsky Field, the largest in the North Caspian Region. Mindful of the complexity of the geological and drilling conditions of the field area, geomechanical modelling was conducted a 3D geomechanical model was built that made it possible to estimate the borehole stability of the designed wells. The 3D geomechanical model served as a "foundation" for preparation of a field Basis of Design. It helped to identify the key elements: well design, optimized well paths taking into account the geology and unstable intervals, potential risks, multilateral well sidetracking points, drilling mud type and mud weight, etc. As a result of an extensive multi-year study, the drilling was performed based on pre-selected and pre-computed parameters along the optimized trajectories planned as per the 3D geomechanical model. To additionally reduce potential risks, the drilling process is accompanied by real-time geomechanical calculations, the purpose of which is not limited to update of safe mud weight window model on the basis of real time data but also includes control of borehole stability, hole cleaning, differential sticking risk, cavings morphology, controlling of equivalent circulation and static density within the safe window, well path update for drillability in case of adjustments. Logging while drilling provides of critical information for permanent update of the geomechanical model and improvement of functions, which allows further optimization of well paths and the most accurate parameters of the "safe mud weigh window". Geomechanics involvement at the Basis of Design project preparation allowed early exclusion of instability risks and identification of well drilling features that would be impossible to implement at the development drilling stage. The result currently achieved by the above effort is the possibility of drilling absolutely all wells, including extended reach (ERD) wells, without any wellbore instability-related problems. Further changes in the modelling approach will be associated to improvement of related functions to ensure still safer and faster drilling. A reservoir optimization group has currently been formed to support the field development. The next step in the development of the geomechanical model of the V. Filanovsky field will be coupled geomechanical and reservoir modelling to make it possible to assess the impact of production on the strain-stress state of the formation and, therefore, on the reservoir properties. Updated model will also be used for planning multi-stage hydraulic fracturing in relevant wells.
Shtun, S. Yu. (OOO LUKOIL-Nizhnevolzhskneft) | Golenkin, M. Yu. (OOO LUKOIL-Nizhnevolzhskneft) | Shtun, A. S. (OOO LUKOIL-Nizhnevolzhskneft) | Shabalinskaya, D. D. (Schlumberger) | Cheprasov, A. V. (Schlumberger) | Kuzakov, V. R. (Schlumberger) | Brichikova, M. P. (Schlumberger) | Zolotoi, N. V. (Schlumberger)
Abstract In this paper we describe a new approach to the development of oil and gas fields in Russia and CIS countries, which consists of integrated use of well log data while drilling and deep directional electromagnetic measurements (EM) for geosteering applications with subsequent update of the geological static model. This approach was implemented in 2016 on the offshore Filanovsky field to reduce drilling risks in the first production wells, and to refine and update the 3D static model. At the initial stage of drilling estimated structural uncertainty in the field was ± 15 m (vertical depth). The use of deep directional resistivity technology (DDR) while drilling allowed to determine bed boundaries remotely based on resistivities at vertical distance of up to 24 m (vertical depth). Based on inversion of deep electromagnetic measurements (inversion), the first wells were successfully drilled with all the geological and technical tasks completed. The obtained well log data together with inversion allowed refining of the correlation of the target beds with seismic data, and updating the velocity-depth model as well as structural surfaces of the deposit. New surfaces, together with the petrophysical interpretation of the data from the horizontal and production intervals obtained during drilling, were used to update the stochastic 3D model for subsequent reserves estimation and planning of future wells.
Skobeev, Andrey (LUKOIL-Nizhnevolzhskneft LLC) | Senkov, Alexander (LUKOIL-Nizhnevolzhskneft LLC) | Danilko, Alexey (LUKOIL-Nizhnevolzhskneft LLC) | Volkov, Vladimir (LUKOIL-Engineering) | Akhmadiev, Ruslan (Lukoil Upstream West)
Summary The requirement of the use of models in the of oil and gas condensate fields development is determined by the legislation of the Russian Federation with regard to application of hydrodynamic models. Thus, an absolute majority of oil and gas companies create and use topical hydrodynamic models within the existing legislation. However, if we talk about the practical application of models for solving the applied problems of developing oil and gas condensate fields, the use in calculations only hydrodynamic models will not allow taking into account the characteristics of used downhole equipment, gathering and processing system Application of integrated approach permits to link "reservoir-well-gathering facilities" as a single whole. An integrated model is a model that combines all the key components of field development, such as a productive formation, wells and a collection network. The decision to create an integrated model was the need for an operative change in the operating practices of the well stock operation in the conditions of technological limits during operation of technological complex. It is expected that the integrated model will allow to calculate the production of liquid, oil, gas, taking into account all the constraints in the existing production system, and also to estimate design capacity of newly developed fields. Additional requirements have been introduced for the integrated model: it must be expandable (for further use of the model of target reservoir), the time of full modeling and forecasting for a month should not exceed more than 24 hours. This article is an example of the construction and application of an integrated offshore field model. Within the example, the field includes two production targets that have a hydrodynamic relationship between themselves. The following functional areas were identified for which it is planned to use integrated modeling as applied problems:Production plan optimization; Development of operating practice for production wells; Development of 24-hour forecast for a month in respect of production wells; Modeling of the current and newly commissioned fields; Evaluation and updating parameters of well performance; Engineering of downhole equipment and process equipment and etc.; The article describes the main problems encountered by specialists of LUKOIL-Nizhnevolzhskneft LLC in integrated modeling development/actualization, as well as examples of its use for solving applied problems. In the course of the project, a common methodology was developed for the making/updating a single integrated modeling, uniting a reservoir model, well models, collection systems and reservoir pressure maintenance. Application of PVT Black Oil was reasoned both for the reservoir and wells. Results of PVT-modeling were applied in multiphase flowmeter as well. A consolidated reservoir model was made consisting of two production targets. This model was successfully adjusted for the production history and adequate forecast for reservoir pressure were demonstrated. Well models were calibrated based actual data of multiphase flowmeter, borehole and surface transmitters (oil production, liquid rate, gas rate; wellhead pressure, line pressure, bottom hole pressure; line and BHT), well test results (reservoir pressure, production ratio). Well bore fluid in the gathering network was modeled with Black Oil. Elaborated integrated model demonstrated consistency in description of PVT reservoir fluid properties. Integrated model was used to complete the following process tasks: Production plan optimization; Development of operating practice for production wells; Modeling of ICD completions and optimization; Gas lift system engineering; Optimization of well connection to separation stages.
Kovalenko, Yu. F. (Institute for Problems in Mechanics RAS, RF, Moscow) | Karev, V. I. (Institute for Problems in Mechanics RAS, RF, Moscow) | Gavura, A. V. (LUKOIL-Engineering LLC, RF, Moscow) | Shafikov, R. R. (LUKOIL-Engineering LLC, RF, Moscow)
The pdf file of this paper is in Russian. A geomechanical approach to solving the horizontal wells stability problem and increasing well productivity based on the physical modeling of deformation and filtration processes in the vicinity of the well is presented. The modeling was performed on a unique experimental facility Triaxial Independent Load Test System (TILTS) created at the Institute for Problems in Mechanics of the RAS. The importance of taking into account of the strength and filtration rock properties anisotropy is demonstrated on the example of Filanovsky field reservoir rock. The tests of rock specimens showed that rocks having the isotropic elastic properties and outward appearance can have significant anisotropy of strength and filtration properties. In this regard, fracture conditions of horizontal well vary for different circuit points, the fracture of a horizontal borehole begins in the areas near the intersection of well contour with the vertical plane. The rock permeability in the horizontal plane was significantly higher than in the vertical direction. Modeling of decompression process in horizontal downhole using TILTS revealed that the occurrence of non-uniform stress conditions in the vicinity of the well when creating a depression in its bottom may result to a substantial change in permeability in this zone – both to a decrease or an increase. The very significant permeability increase mainly observed in the test specimens corresponding to their location in the points of intersection of the contour of a horizontal well and a vertical plane. The studies lead to the important conclusions regarding the selection of the prioritized strength and filtration properties of reservoir rocks to be determined experimentally under creating and filling in the geomechanical model of the deposit. Currently used traditional set of data is based on the assumption of an isotropic elastic and strength properties of rocks (Young's modulus, Poisson's ratio, the Mohr-Coulomb or Drucker-Prager strength constants, etc.). The facilities which based on the Karman principle mainly used to determine these characteristics, but they do not allow to create real stress conditions arising in the formations in the vicinity of the well. At the same time, deformation, strength and filtration properties of rocks depend intrinsically on the level and type of stresses created in the formation. Conclusions and forward recommendations to ensure the stability of rocks in the bottomhole zone of reservoir, find the maximum of allowable depression and well production can be quite remote from reality if the strength rock properties anisotropy, as well as the dependence of the filtration properties on stresses, will not be taken into account. And the central objectives to reduce risk and enhance efficiency in well production will not be achieved.
Abstract 4D seismic monitoring appears to be quite an expensive and pinpoint tool to increase the efficiency of oil and gas fields' exploitation. To reach the desired profit results, it is necessary to select candidate-fields very accurately and provide individual monitoring parameters on every stage. In this work, the opportunity of a 4D marine seismic survey on the Filanovsky field, which is prepared for development, is being examined. The questions of technique's efficiency in these particular geological and geographical conditions are discussed. To conduct a feasibility study, 4D seismic modelling of possible reservoir development effects was performed and the most suitable design of marine 4D seismic survey was proposed considering international experience of such projects. A full package of interdisciplinary information was utilized as initial data: 3D seismic interpretation results, AVA seismic inversion results, well log data interpretation, core data laboratory testing results, results of reservoir simulation and geomechanical modeling. 4D modeling was performed by calculating 3D elastic parameter models for various periods of field development according to flow simulation and geomechanical modeling results. Then these petro-elastic models were used to generate synthetic seismic volumes. The possibility of 4D seismic effects appearance was proved based on the modeling outcome. After analyzing the latest field survey techniques of 4D seismic monitoring, the most effective scenario of their realization on the Filanovsky field was suggested taking into account all the specific aspects of geology and the local area. The 4D marine survey was completely designed according to all efficient parameters calculation.