- Home
- Conferences
- Conference Proceedings
- Conferences
Horizontal Wells 2021
- Conference date: May 24-28, 2021
- Location: Online
- Published: 24 May 2021
1 - 50 of 68 results
-
-
3D modeling of multilateral well (fishbone) junction stability in development conditions of the Yamal-Nenets Autonomous District oil field
Authors A.V. Seryakov and M.Yu. PodberezhnySummaryThe results of 3D poroelastic finite element modeling of the fishbone well junction located in the north of the Yamal-Nenets Autonomous District oilfield are presented. The reservoir being studied is characterized by a thin productive pay bounded by a larger gas cap and a water-bearing layer. The oil-bearing rocks are brittle sandstones saturated with viscous oil. The 3D poroelastic modeling of the fishbone located at 1 km depth was carried out for the situations when main wellbore is oriented along maximum and along minimum horizontal stress. The safe wellbore pressure ranges were determined both for drilling and for production regimes of the junction passed through the sandstone with normal and reduced strength.
-
-
-
Peculiarities of ground microseismic monitoring of HF with partial deepening of sensors under the low velocity zone and assessment of the reliability of the results obtained for the well of LUKOIL-PERM LTD
Authors I.R. Sharapov, V.A. Ryzhov, S.A. Feofilov, A.Y. Milin, I.A. Chernykh, A.V. Rastegaev and I.N. PonomarevaSummaryThe deepening of the sensors of the surface locating system under the low-velocity zone compensates for the influence of inaccuracy in the knowledge of the velocity model in the upper part of the section, reduces the level of registered surface noise and expands the upper limit of the operating frequency range. All this increases the sensitivity to weak events and the accuracy of event location in general. The formation of a hydraulic fracture leads to a change in filtration flows in the reservoir in the well area, which in general should affect the change in flow rate not only in the well with hydraulic fracturing, but also in the adjacent wells. Correlation analysis between daily fluid flow rates in wells before and after hydraulic fracturing, in the presence of statistical relationships, allows to establish a change in the direction of fluid movement in the considered element of the development system and to give a qualitative assessment of the fracture azimuth obtained from the results of microseismic monitoring.
-
-
-
Integrated approach to well test and production log analysis interpretation of multiple hydraulically fractured horizontal wells in low permeability heterogeneous formation
Authors E.I. Grishina and M.I. KremenetskySummaryThe Paper presented usage of Well Testing and Production logging in Horizontal wells in low permeability reservoirs. The obtained test results were reviewed in order to estimate parameters of each individual fracture and reservoir permeability using production contribution of each fracture by PLT and bottom-hole pressure and surface liquid rate of tested wells. Optimal testing technology and interpretation methodology is justified by numerical modeling.
-
-
-
Experience in drilling multilateral wells at the fields of JSC Tomskneft
Authors V.V. Stotsky, A.S. Aleshkin, A.V. Kuznetsov and P.V. MolodykhSummaryJSC TomskNIPIneft has accumulated significant experience in geological support for drilling horizontal wells at the fields of JSC Tomskneft. The authors have consolidated the existing experience of drilling multilateral wells at the fields of JSC Tomskneft. Was formed a list of cases and "lessons learned" in order to increase the efficiency of drilling and further replicate such wells.
-
-
-
Seismic Facies Analysis of the Neocomian Sediments of the Rakushechno-Shirotnaya Uplift Zone Oil Field (Caspian) as a Tool to Improve the Efficiency of Horizontal Wells Geosteering
Authors A.V. Gorban, I. N. Kerusov and I.S. TimofeevaSummaryLateral changes of lithology can reduce the reliability and efficiency of geosteering when using only reference wells. Using 3D seismic data in addition to reference vertical wells can improve the efficiency of horizontal wells planning and geosteering. The oil field considered in this study is covered by 3D seismic survey and 6 exploration wells. The Neocomian terrigenous reservoir is being developed with horizontal wells Seismic-well-tie show that lithology changes within Neocomian reservoir can lead to time shift between stratigraphic well top and seismic reflection. Seismic facies mapping was performed using seismic attributes and verified by horizontal wells data. Result seismic facies map can be used for optimal well placement
-
-
-
Investigation of state of the gas pipeline part under the Vym River
Authors V.V. Noskevich and V.Y. GorshkovSummaryThe article presents the results of ground penetrating radar (GPR) researches of the gas subway pipeline, which was passed under the river by horizontal drilling. GPR method allowed to distinguish the layers boundaries in more detail than drilling data, and also found an anomalous zone with a high-frequency "ringing", corresponding to a metal object that damaged the upper part of the gas pipeline.
-
-
-
The approach for anomalous permeable zones detection in the sedimentary cover based on geomorphological analysis and gravimetric data
Authors D.I. Khasanov, J.V. Gubaidullina, K.V. Rodionov, I.I. Bagmanov, D.K. Nurgaliev and A.A. LutfullinSummaryComplex of methods, presented in this work, allows to identify active fluid migration zones of natural or technogenic characters. Application of this complex is especially relevant due to existing areas, which underexplored or not explored by seismic methods. The proposed method allows to promptly predict the existence and spatial position of sedimentary cover active fluid migration zones at minimum cost. In such zones, the fluid migration can occur laterally (along faults, blocks boundaries, etc) and vertically. The information, which obtained using this technique, can be applied for planning of horizontal wells and network of injection wells, interpreting hydrodynamic modeling data etc.
-
-
-
Geochemical monitoring of oil molecular composition during field development for geological model updating and optimization of horizontal wells performance
SummaryApplying geochemical techniques to complex of geological exploration opens wide opportunities for controlling the field development and operation. For example, molecular studies make it possible to understand complex oil reservoirs, find vertical and lateral connectivity, trace oil migration, determine the proportions of commingled production from multiple zones. This paper presents an example of geochemical monitoring of oil from the wells of the Caspian Sea water area. Geochemical survey were based on study of molecular composition of paraffins in gasoline fractions of oil. The molecular composition of oil samples obtained from different wells in period from 2016 to 2020 has been compared. The possibility of identification whether hydrocarbon fluid belonged to the working formation is shown.
-
-
-
The accumulated experience of planning and geological monitoring the drilling process of horizontal wells into the Cenomanian strata of the Kharampurskoe field
Authors R.S. Shekhonin, A.A. Orlov, I.A. Kunakkuzhin, V.S. Abdullin and A.P. PopruzhukSummaryThe results of comprehensive work that led into an increase in drilling efficiency, an improvement in the starting flow rates of drilled wells, and a decrease in estimated economic losses are reflected.
-
-
-
Taking Parameters of Horizontal Wells Into Account During Reserve Estimation
More LessSummaryIn this presentation we're taking a look at possibility of taking parameters of horizontal wells into account when estimating reserves of Srednebotuobinsky field. Interpretation of horizontal wells has been done, as well as coefficients of porosity and hydrocarbon saturation have been calculated. We've compared the parameters with the core and the pilot borehole, and given recommendations for use of the parameters when estimating reserves.
-
-
-
Quantitative interpretation of data from flowmetric studies of horizontal wells: problems and opportunities
SummaryRecently, in connection with the expansion of the hardware and methodological complex in field-geophysical studies (PGI) of horizontal wells, more and more attention, along with the traditional qualitative interpretation of PGI data, is paid to the quantitative determination of parameters, such as the inflow profile, interval flow rate, etc. One of the main approaches in this case is the use of mathematical models and the solution of inverse problems for the quantitative assessment of the relevant parameters based on the processing of the initial data of field-geophysical studies at different operating modes of the well. The most complete information is obtained when using multi-sensor devices with distributed moisture meters and temperature sensors, as well as systems with length-distributed temperature and pressure sensors, as well as fiber-optic technologies. Some approaches for quantifying phase flow rates and the inflow/uptake profile from flowmetric studies are discussed below.
-
-
-
Real-time LWD interpretation
Authors A.S. Romantsov, A.M. Galechyan, V.E. Kovalchuk and V.V. KapsenkovSummaryDrilling process geological monitoring becomes more critical due to horizontal drilling percentage increase over the last two decades. That results in a growth of LWD operative interpretation demand and makes necessary to provide the formation evaluation data as soon as possible. This paper represents the automation of LWD interpretation process with automatic data import and export via the remote server. Decreasing the process life of operative interpretation we manage to increase the geosteering efficiency. This work examines formation evaluation and calculation of the mineral volumetric fractions. Collector, lithology and formation fluid type are determined by the cut-off values method. Data transmission (both import and export) is performed via the classified remote server WITSML. The represented approach has shown its efficiency on practice. It makes log quality control more effective and optimizes the workflow by cutting down unproductive routine operations.
-
-
-
Improving Development Efficiency of Hard-to-Recover Reserves of Tyumen Formation (JK2-9) at Krasnoleninsky Field
Authors S.A. Moiseev, Yu.A. Plitkina, D.P. Patrakov and A.S. GlebovSummaryThe challenges of developing the Tyumen Formation reserves are associated with the following features: thick oil column, high heterogeneity, abnormally low permeability, and a low degree of knowledge. Historically, the development of the Tyumen Formation has been uneconomic due to low startup oil rates and high decline rates. The first active phase of development began in 2009, due to recompletions at the Talinsky license block and drilling of directional wells with hydraulic fracturing at the Em-Yegovsky license block. Those measures resulted in recoveries of less than 2% of the initial recoverable reserves. The next stage started in 2013–2015, when a pilot project of “horizontal wells with hydraulic fracturing” was successfully implemented at the Em-Egovsky license block. Together with the tax incentives to the MET rate, this made it possible to significantly expand the zones of economic drilling and ensure an increase in oil production. Based on successful practices at the Em-Egovsky license block, since 2017, the HzW + MSHF technology has been replicated at the Kamenny and Talinsky license blocks. In the next 20 years, it is planned to drill about 5,000 wells in the Tyumen Formation which will increase production by more than five times. In 2020, a pilot project was implemented to increase the length of a horizontal well (up to 1,200 m) and the number of hydraulic fracturing stages (up to 12). Note that the current tax incentives will not allow the full involvement of the Tyumen Formation reserves into development - when moving into zones of poorer quality, the development economics decreases. By the time the tax benefit expires (2030–2035), 40% of planned wells will be drilled, the recoveries from initial recoverable reserves will not exceed 20%. Further growth and maintenance of oil production will require additional tax incentives.
-
-
-
Estimation of the number of stages of hydraulic fracturing in horizontal wells in various geological conditions
Authors E.O. Sazonov, A.A. Suleimanov, A.I. Ganeev and A.N. NugaevaSummaryThe report considers the problem of fluid flow to a well with multistage hydraulic fracturing (MSHF) in an infinite and bounded homogeneous isotropic formation. An approximating dependence of the skin factor in a horizontal well with multistage fracturing on its parameters has been obtained. Calculation formulas for expressing the skin factor was derived. Based on the solution of the diffusivity equation for a bounded formation with a boundary condition of the first kind, rates and cumulative production for the well were obtained with good accuracy. An economic estimation of the optimal number of hydraulic fracturing stages was presented. To evaluate this values specialized script is written by means of Python programming language.
-
-
-
Geochemical Approach for Identification of Hydraulic Fracture Vertical Distribution in Reservoir Simulation Model Basing on Microcomponent Study of Oil Produced
Authors M. Shipaeva, D. Nurgaliev, V. Sudakov, S. Usmanov, R. Safina and R. SalimovaSummaryHydraulic fracturing in horizontal wells is one of the effective stimulation techniques. Despite the widespread use of this technology, determining the vertical distribution of fractures and adjusting its parameters in the geological and reservoir simulation models remains challenging. That is due to the lack of borehole and areal geophysical surveys data on fractures distribution. Vertical distribution of hydraulic fractures has a strong influence on fluid flow in carbonate reservoir. The correct simulation of their geometry in the hydrodynamic models greatly affects the nature of reserve recovery, the well performance, water breakthrough and the efficiency of reservoir development as a whole. The paper shows an approach based on geochemical survey of oil produced allowing identification of formation produced by a well with fracture and calibration fracture vertical distribution in reservoir simulation model on the data of oil inflow from each formation.
-
-
-
Forecast of productivity in the design of the field development scheme with horizontal wells based on the use of new methods of seismic data processing
Authors E. Anokhina and G. ErokhinSummaryThe use of new methods for processing seismic data makes it possible to refine the tectonic model of the field, to forecast zones of increased and decreased productivity in the production horizons. This is necessary for a reasonable choice of directions and lengths of horizontal and directional wellbores in the most fractured zones in order to maximize production rates. The fracture zone map serves as the basis for the design of the field development scheme. Initially, it is recommended to lay wells in zones of increased fracturing of the productive horizon, while avoiding or taking into account the zones of possible complications during drilling, which are present in the overlying horizons. If the location of the well pad has already been determined, the resulting map will help to adjust the azimuth and length of the horizontal sections of the wellbores to undercut the zones of increased productivity.
-
-
-
Integration of geomechanical and seismic data for losses predictions while drilling horizontal wells
Authors D. V. Malyutin, O. V. Grachev, A. V. Bekmachev, A. S. Puchkov, Ya. N. Smyshlyaev and I. A. OparinSummaryThis thesis presents the technology for assessing the risks of mud losses during drilling using 1D geomechanical modeling in conjunction with the seismic interpretation data MOGT-3D. Based on a combination of seismic and geomechanical data, a methodology has been developed for estimating the equivalent circulating density values, above which the mud losses will appear during drilling, which makes it possible to predict drilling risks and provide measures to prevent them without increasing the cost of drilling. In the examples considered, the forecast of mud losses by this method has a 72% confirmation (21 out of 29 wells). In order to further improve the technique, a number of measures have been proposed, including, conducting special methods of geophysical well logging to determine the nature of zones with increased mud loss risks and clarifying the direction of maximum horizontal stress, as well as performing leak-off tests (LOT and XLOT) for estimations of mud loss and hydraulic fracture pressures. The seismic-geomechanical model constructed according to the proposed method can be used to solve other equally important tasks: search for zones of increased reservoir properties, the location of the ports of multistage hydraulic fracturing, risk assessment of increased wear of bits and others.
-
-
-
An automate approach of optimal pad arrangement for horizontal wells in bitumen deposits
Authors T.A. Murtazin, A.D. Yarullin, V.A. Sudakov and V.K. GataullinSummaryThis paper discusses an approach to automate the process of optimal pad arrangement for horizontal wells in bitumen deposits, to reduce the total costs of surface infrastructure. The authors proposed methods for determining the positions of horizontal wellheads, combining them into well pads and design the well profiles. When combining wells into groups, surface and technological limitations are taken into account.
-
-
-
Elaboration of criteria for laying wells of the operating stock of the Riphean carbonate reservoir in the central part of the Kamovsky arch of the Baikit anteclise based on 3D seismic data
Authors S.S. Soshnikov and E.N. CherepanovSummaryThe object of this work was a large oil and gas condensate carbonate field in Eastern Siberia. The target interval at the field is the riphean reservoirs, which are represented by an impermeable carbonate matrix permeated by a dense network of micro-macro cracks of various orientations, caverns and leaching intervals. The affected area was subjected to an active and multi-stage tectonic impact, which led to the widespread development of numerous low-amplitude, sub-vertical faults and fracture zones of a predominantly shear nature. The main intervals of the section are represented by the Archean basement, Proterozoic (Riphean-Vend), Paleozoic (Cambrian, Ordovician, etc.) and Upper (HCR) parts of the section. The Paleozoic part of the section consists mainly of Cambrian carbonate-halogen-sulfate rocks and traps, presumably of Triassic age. The wave pattern of the Cambrian rocks is characterized by relatively laterally sustained seismic reflections with a small number of interpreted faults. The shape of the wave pattern, or in other words, the seismic images/seismophations, are mainly high-amplitude, laterally sustained with increased reflection and impedance coefficients. Potential reservoirs in this part of the section are most often represented by relatively dense carbonates, which are characterized by a small number of secondary changes in carbonate rocks. The main risks when drilling GS are the presence of abnormally high absorption of drilling fluid (up to loss of circulation), the presence of tool failures, frequent wear of bits, the presence of silicification. More than half of the current fund of producing wells have a high gas factor or significant water cut. To solve the described problems, it was decided to create a number of criteria for laying horizontal wells, taking into account the seismogeological conditions of the section.
-
-
-
New Prospects of SAP Investigation using Multisensory Passive Spectral Acoustics
Authors A.A. Senkov, O.I. Abramenko, V.M. Nagimov and A.V. TrusovSummarySustained Annulus Pressure (SAP) monitoring on offshore stationary platforms plays an important role in the development of oilfields with the massive gas cap. Conventional SAP diagnostic techniques is significantly limited primarily by the complexity of unwanted flowpaths in annular space and the presence of multiple pipe barriers. Multisensory passive acoustics is the novel approach evaluating SAP. Several accurately synchronized high-definition acoustic sensors measuring acoustics wave time arrival shift of the signal generating by active flow source. To take into account acoustic wave reflections in multiple strings of well construction 3D modelling of acoustic propagation is applied. The logging campaign of five wells was surveyed using slickline. Both conventional single sensor and multisensory spectral acoustics were used in the same toolstring. The multisensory acoustic data indicated active SAP sources and estimated the distance to the SAP source and flowpath separately, differentiation of that is impossible using single sensor spectral acoustics data. As a result of the campaign multisensory passive spectral acoustic instrument demonstrated additional important features on SAP source identification over conventional single sensor spectral acoustics. The most important feature is the differentiation of SAP source and flowpaths behind multiple casings. This significantly improves workover planning on SAP source isolation
-
-
-
An Integrated Approach for Application and Operation evaluation of Autonomous Inflow Control Devices in Horizontal and Multilateral wells
By T. SolovyevSummaryThe article also describes general information about the inflow control devices technology, their characteristics and problems that the operators user may encounter when using one or another element of high-tech completion, gives reasons for the use of autonomous inflow control devices at the considered development object. Analysis of field data and PLT and well logs results revealed that the devices actually work and help to limit water and gas compared to wells that are equipped only with wire filters without inflow control, and also begin to form a unified strategy and concept of well completion based on the data The results of the work show that currently the use of AFCD for the project is favorable, and the completion of wells without flow control in these conditions is impractical.
-
-
-
Key Performance Indicators of Geomechanical Modelling
Authors P.V. Iastrebov and A.I. ArhipovSummaryGeomechanical modeling with regard to well construction process acts as a service and solves a set of issues related to the rock mechanics. Such tasks can be, for example, ensuring the borehole stability, multi-stage hydraulic fracturing, forecasting sand production, or reducing the risk of lost circulation and kick events. The process of a geomechanical model development implies the processing of a large amount of data, such as well logs, core studies, LOTs and XLOTs, hydraulic fracturing events in offset wells, etc. The effectiveness of geomechanical modeling depends largely on the quantity and quality of the input data. In this behalf, it is required to formalize and quantify the key performance indicators (KPIs) of geomechanical modeling, which will further regulate this process.
-
-
-
Laboratory studies application for mineral-geochemical characteristics of the Bazhenov formation of horizontal wells
Authors E.A. Vtorushina, E.S. Pivovarova, I.V. Afonin, A.E. Gavrilov and M.N. VtorushinSummaryMineralogical heterogeneity of rocks of the Bazhenov formation and lateral distribution of pyrolysis parameters are investigated along the horizontal wellbore in the territory of Krasnoleninsky upland. The highest content of clay minerals and pyrite corresponds to the interval V. There is a positive correlation between the amount of clay minerals, plagioclase and the zirconium and titanium content, the oxide forms of which should be interpreted as circon and rutile accessory minerals. At the intervals V-II oil saturation (the average oil hydrocarbon content is 6.5 mg/g rock) is fixed with the maximum oil saturation (16 mg/g rock) in the interval III. Total organic carbon content ranges from 3 to 11%. The comparison of pyrolysis characteristics with mineralogical composition allowed us to identify two types of organic matter within the well, which were assumed to differ in chemical composition and physical properties.
-
-
-
Multilateral wells as the way to increase profitability of Vikulskaya formation development
Authors A.V. Iakovenko, D.S. Lachugin, A.K Maltsev, T.Y Dolgushin, N.V. Kudlaeva and J.J. PolushinaSummaryWell 2 is 4 branches fishbone with total reservoir exposure 3100 m The drillability of final design decisions is proven and wells are brought into operations. The better result is shown by Well 1: the productivity index is more, then expected from numerical simulation. Extended well test is in progress. Build up test show, that 64% of well is in production"
-
-
-
Modeling the sedimentation rate of mechanical impurities in the horizontal wellbore
Authors M.F. Zakirov, R.F. Sharafutdinov, R.A. Valiullin and I.G. NizaevaSummaryThis work is devoted to the determination of the sedimentation rate of mechanical impurities depending on the particle diameter, as well as the assessment of such a process from the watering of the well production.
-
-
-
True stratigraphic thicknesses calculation and fault throw evaluation based on image log interpretation during geosteering on horizontal well of Y.Korchagin field (Caspian Sea)
Authors S.Y. Shtun, M.Y. Golenkin, M.V. Rakitin, D.V. Shtepin, A.F. Islamov, N.R. Shaymardanov, N.V. Ivanova and V.R. KuzakovSummaryHorizontal wells bring a lot of new practices in way of working with well data. For example, in the petrophysical interpretation of reservoir properties, 3D approach is used that allows us to take into account the effect of several layers simultaneously affecting on LWD measurement [ 3 ]. Geosteering team always shifts from measuring thicknesses (MT) to true stratigraphic ones (TST) by adjusting trajectories based on formation dips. During interpretation wellplacement engineers uses relable stratigraphic well tops to adjust formation dips for achieving better correlation with surrounding wells [ 1 , 4 ] (Figure 1). For understanding of formation dips LWD borehole images or deep-reading electromagnetic measurements are used. A new method of using borehole images interpretation for TST calculation, which allows to build more accurate geosteering model described in this article.
-
-
-
The importance of pinpoint horizontal well landing
More LessSummaryThe development of geologically complex fields with horizontal wells often requires the use of special technologies not only directly for drilling a well within the target interval, but also for well landing. This paper considers an example of the well landing special requirements with the aim of further successful drilling in the target zone in the conditions of the Filanovsky field edge area (North Caspian Offshore). The development target is the Lower Cretaceous sediments (Neocomian superstage), represented by interlayering of sandy reservoirs and clay-siltstones, changing their thickness and properties both in the northeastern and southwestern directions. The oilfield is characterized also by presence of fault zones (with amplitudes from 1 to 65 m). In addition to these geological and structural uncertainties during horizontal wells drilling on the edge parts of the structure (fold wings), significant structural angles cause additional complexity. One more important condition for the successful well landing is the fluid contacts crossing in definite parts of the section. Ultra-Deep Electromagnetic Logging While Drilling Mapping Technology was used to solve successfully all uncertainties and tasks.
-
-
-
Evaluation of Multilateral Wells Efficiency in the Fields of Vankorsky Cluster in Different Geological Environments
By A.A. ZerninSummaryThe purpose of the work is to assess the efficiency of difficult wells having different geometries (sidetrack/multilateral wells) under similar subsurface conditions. The work includes the following: formation of principles for selecting analogues to evaluate efficiency; selecting well sections in reservoirs of continental and marine genesis, comparing porosity and permeability; comparing productivity factors of producing horizontal section at the start of operation; evaluating the oil production decline rate and growth in cumulative oil production; and presentation of promising trends of multilateral well technology development. In order to evaluate the multilateral well efficiency as compared to the other types of completion, principles of site selection are developed based on close position of wells and similar porosity and permeability, energy condition of reservoir and development settings. The following stages were included in evaluation of site efficiency: 1) selection of sites for comparison in accordance with similar porosity and permeability; 2) comparison of well completion technologies and energy conditions of reservoir in the area of sites; 3) estimation of productivity factor and oil rates at the start of well operation; 4) analysis of oil production decline rate and cumulative oil production. In accordance with well commissioning data, the trend of productivity factor growth from the producing horizontal section is observed for horizontal holes; at the same time, based upon the trend lines, there is a limit of productivity factor growth because of draining the same volume of reserves. For the areas with representative operational statistics, the sites were broken down in accordance with continental (2 sites) and marine (4 sites) genesis; 5 more sites in the Vankorsky field were assigned to a separate block because of the lower energy conditions in multilateral wells compared to sidetracks (reservoir pressure by 15% lower on average). As a result of the assessment, efficiency of multilateral wells with respect to sidetracks was proved; the average increment of cumulative oil production per well for 6 months amounted to 5 thousand tons compared to sidetracks (+14%), while the predicted effect for 20 years makes 63.2 thousand tons (+75%). The best results in multilateral wells are obtained in reservoirs of continental genesis having better reservoir quality.
-
-
-
Combination of strat-based modeling & distance to boundary (inversion) methods implementation in geologically complex formation K1ne-2 of Balgimbaev oil field, Kazakhstan
SummaryYear by year drilling of horizontal wells becomes more and more popular way of the field exploration. For instance, at the beginning of XXI century the quantity of drilled horizontal wells from the whole amount was just about few percentages, if to say that nowadays this number is getting closer to 60%. Despite on that fact, that designing and exploration of oil & gas fields are such laborious processes, the main problem is still lies on the low level of EOR. Nowadays geosteering becomes an essential part of well drilling and increases the level of well targeting, therefore it enhances the level of extracted hydrocarbon fluid. Analyzing drilling datas, received in a real time from the wellbore, geosteering provides an opportunity to correct the planned trajectory of the well instantly and therefore make sure that the well stays in a target zone.
-
-
-
Marker-Based Long-Term Production Profiling Surveillance in Horizontal Wells in The Northern Capsian Sea
Authors E.A. Malyavko, S.Y. Shtun, A.A. Senkov, O.I. Abramenko, А.V. Buyanov, D.А. Lysova and E.V. PotapovaSummaryFundamentally new control tools for reservoir management are required in modern field tests for productivity estimation with high efficiency. One such tool is marker-based production logging enabling long-term production profiling surveillance. This research represents the case study of multi-phase flow profile estimation (oil, water and gas) in horizontal offshore oil wells in the North Caspian Sea. This method assumes that marker systems (marker cassettes) with unique codes are placed in the well as part of the lower completion. During further monitoring immediately after the well is put into production, formation fluid sampling is performed with a certain frequency according to a pre-formed schedule. The fluid and gas samples are analysed in the laboratory using specialised equipment. Based on the processing results, the distribution of each marker code was obtained. It shows the intensity of fluid flow from the formation into the wellbore. The results of production logging for each interval made it possible to determine the zones with low productivity, to identify how they correlate with the geological features of the area and the porosity and permeability distribution throughout the reservoir, and also to reveal the dependence of the production profile on well operation parameters. This information allows optimising the well operation and selecting the most promising development scenario to maximise hydrocarbon recovery.
-
-
-
Separate Production Metering From Each Formation When Integrating Taml-1 Well Construction Technology with Quantum Plt at The Novoportovskoye Field
SummaryThere are the remaining undeveloped hydrocarbon reserves at Novoportovskoye field occurring immediately under massive gas caps. To make field development economical in such geological settings, new technologies are required. This article describes the experience of constructing a multilateral well according to the new TAML Level 1 completion scheme, utilizing rock characteristics of the impermeable roof of the underlying bed and the dynamic Quantum PLT to arrange for separate production metering from each formation. Multilateral wells have been extensively drilled in the Novoportovskoye field in order to expand the drainage area. The dynamic production logging technology based on the use of quantum dot marker-reporters was chosen to arrange for separate production metering. The CAPEX and construction period have decreased by about 38%. The design enables separate production metering from each reservoir without stopping production. In addition, the costs associated with the regular interpretation of data obtained by analyzing the samples containing quantum-dot markers are offset by a reduction in operating costs for the pumping unit and service of well workover teams. The operator company has resolved to replicate the technology. However, the potential for this scale-up is limited by the requirements for the geological structure of the section.
-
-
-
Seeing fractures under a Microscope - the first application of the new microimager while drilling in WBM in Russia
Authors S.A. Nazarov, V.V. Slyusarev and A.F. IslamovSummaryNDP «Chepakovskoe» uses advanced logging while drilling technologies for studying the fracturing of Paleogene reservoirs of Chepakovskoye oil field (Stavrovol region). High-resolution microimager while drilling in horizontal well provide new information of complex structure of the Paleogene deposits which cannot be unambiguously characterized by standard logging methods. For example, wide development of natural fracturing according to core data cannot be taken into account according to the standard logging complex. At the same time, the data of high-resolution images made it possible to significantly detail the structural elements of the reservoir, to characterize the natural and drilling-induced fracturing of the rock. Main attention in this article is given to the analysis of fracturing of reservoir horizons, estimating of fracture density (frequency) along the wellbore and the determination of fracture aperture.
-
-
-
Verification of the polygonal approximation of an induction source in electromagnetic logging of horizontal wells
Authors P.A. Domnikov, Y.I. Koshkina and M.V. IvanovSummaryIn this paper, we study the magnetic field sensitivity from the sources of various configurations and check the adequacy of replacing the circular loop with a square vertical frame. The performed computational experiments showed that for the approximation of a current loop, the plane of which is perpendicular to the boundaries of layers with different resistivities, the choice of a vertical frame of four sides is sufficient in terms of the accuracy of the obtained components of the magnetic field in the receiver. The result is retained when the electromagnetic field frequency and the resistivity of the medium vary for situations typical for induction logging problems in horizontal wells.
-
-
-
Losses risk minimization while predrill stage and realtime drilling geomechanics support on the north part of Caspian sea
Authors M.U. Topolyan, G.A. Chikhanov, P.S. Bak, A.S. Kuznetsov, R.V. Golubtsov and V.R. KuzakovSummaryOil field development in the northern Caspian Sea involves the drilling of horizontal wells in terrigenous Lower Cretaceous sediments with low hydraulic fracture pressure, where both geological and technical conditions increase the risk of fluid loss. The main geological factors that cause losses on the Filanovsky and Korchagin fields are wells with direction to maximum horizontal stress azimuth, fractures and faults, and depletion of producing formations. Technical reasons include high mud density, use of standard (without increased diameter) casing, poor borehole cleaning, which leads to unacceptable growth of equivalent circulating mud density during drilling. Separately, the high probability of losses during the cementing phase of the well is considered. One of the proactive tools for managing drilling fluid loss risk is building a geomechanical model that includes calculation of losses and hydraulic fracturing gradients, which allows determining safe limits of equivalent circulating density during drilling and performing trajectory optimization at the initial planning stage to expand the safe drilling fluid density window.
-
-
-
The assessment of the prospects for sub-horizontal wells based on the experience of the Achimov deposits development in the Urengoy oil and gas complex.
Authors I. O. Maltseva and V.A. GuznenkoSummaryA comparative analysis of horizontal well No. 1 and adjacent S-shaped wells with hydraulic fracturing was carried out in this work so as to assess the prospects of using a sub-horizontal structure with multi-stage hydraulic fracturing. In order to assess the effectiveness of horizontal opening with multi-stage hydraulic fracturing, a comparative analysis of field combined gas dynamic and gas condensate studies was carried out. Based on the results of the work, a conclusion was made about the effectiveness of using sub-horizontal wells with penetration through the Achimov formations and carrying out several stages of hydraulic fracturing for each formation separately.
-
-
-
Drilling and well placement of uprising horizontal wells in multizone reservoirs of Turonian formation in Western Siberia
SummaryThe developed methodology is based on the reducing of geological uncertainty, the optimal positioning of the horizontal uprising wells in the target interval, an increase of Net to Gross ratio and, therefore, an increase in well productivity. The proposed integrated engineering solutions was successfully implemented in 50 horizontal wells.
-
-
-
Machine learning methods for geological support in geosteering
Authors M.S. Pospelkov, E.V. Shkunov, A.V. Belousov, D.P. Proshutinsky, N.K. Kayurov and V.U. UlyanovSummaryIn order to more accurately predict lithology and the nature of saturation, as well as minimize the time to perform interpretation, it was decided to test machine learning algorithms. For solving such problems, the gradient boosting algorithm (GBoosting) showed the best efficiency.
-
-
-
Multistage hydraulic fracturing's tailpipe with additional elements for the possibility of re-fracturing operations in horizontal wells
Authors A.R. Gayfullin, A.V. Ivshin, A.G. Kudiiarov, A.V. Churakov and I.G. FayzullinSummaryThere are no optimal solutions for re-fracturing in horizontal wells in JSC «Gazpromneft-Noyabrsneftegaz» this time because exist certain factors that complicate process repeated hydraulic fracturing. The authors proposed the idea of creating multistage hydraulic fracturing's tailpipe with additional elements on new horizontal wells. This configuration has next additional element: movable elements with a saddle, soluble balls, hydraulic fracturing sleeves, packer. The idea is to close existing sleeves and open new ones without additional impact on the formation and attracting expensive equipment. Advantages of such simple type of tailpipe: 1. There is no need to prepare the well for repeated multi-stage hydraulic fracturing. 2. Minimization of manipulations for drilling ports in a horizontal wellbore prior to hydraulic fracturing. 3. It eliminates the need to run additional two-packer systems to separate each interval during re-fracturing. 4. It solves the issue of targeted repeated hydraulic fracturing in the selected zones. 5. It can be used not only for re-fracturing purposes, but also for isolating water-cut intervals according to the research results. 6. Reducing the cost of the re-fracturing process due to the elimination of the lease of attracting a contractor with two-packer assemblies, lengthy workover well preparation to achieve equal bore diameter in the horizontal part of the well.
-
-
-
Construction of Extended-Reach Wells (Bottomhole More Than 6000 m) in the North of the Perm Region
Authors K.A. Meshcheryakov, Yu.V. Fefelov and A.V. ShirokovSummaryThe results of drilling extended reach wells at one of the fields in the north of the Perm region are presented. The substantiation of the choice of the well design and the extended profile taking into account the peculiarities of the geological structure of the field is given. The problems that arose during the construction of the well and their solutions are described. The relevance of individual design of construction of extended reach wells is noted.
-
-
-
Systematic Approach to Selecting Candidates for Multistage Repeated Hydraulic Fracturing in Horizontal Wells of RN-Uvatneftegaz
Authors R.A. Gatiyatullin, R.R. Baisov and V.T. KirshinSummaryThe share of horizontal wells with multistage hydraulic fracturing in the well stock of RN-Uvatneftegaz is increasing every year and this trend will continue for the next 5 years. At the same time, the well productivity significantly decreases, which leads to declining oil production. The most promising method for restoring oil production in horizontal wells with multi-stage hydraulic fracturing is repeated multi-stage hydraulic fracturing. An analysis was carried out and the criteria for the selection of well-candidates were determined.
-
-
-
Key for Turon: an example of petrophysical modeling taking into account field development with horizontal wells
Authors A.Y. Bokarev and D.M. EzerskySummaryThe Turon is known for its complex reservoir rock structures. Evaluation of reservoir properties is greatly complicated not only by its structure, but also by the lack of high-quality core material. In such conditions, building a high-quality petrophysical model is complicated. The authors presented the work on the development of a petrophysical model based on the data of modern special logging methods, which make it possible to approach the core data in terms of the amount of information received while conducting measurements in downhole conditions. A key feature of the model is the fact that the field will be drilled with horizontal wells using logging while drilling technologies. The obtained universal model is capable to assess the reservoir properties of complex rocks of the Turonian age, taking into account the influence of gas, lithology and laminated structure of the formation.
-
-
-
Gas-dynamic methods of well research as a tool for complex improvement of the efficiency of gas re-injection into the gas cap of the Novoportovskoe Oil and Gas Condensate Field
Authors Y.A. Podchuvalova, I.L. Chameev, E.A. Sherstoboev, E.P. Borisov and V.N. GrischukSummaryThe article presents an approach that allows to evaluate the efficiency of gas re-injection into the layers of the Novoportovskoe Field, detect the reasons of injection rate decrease, and analyze the impact of gas injection on the development of the oil layers. The method is based on gas-dynamic tests of wells. The development of the field began in the absence of outside gas infrastructure. For the purpose of rational utilization of associated gas, until the outside gas infrastructure is ready, it was decided to re-inject gas into the main reservoirs. The reservoirs are represented by fringes of the marginal and underlying type. There is a risk of a gas breakthrough to the producing wells. It is necessary to optimize the re-injection of gas in order to equalize the reservoir pressure profile and increase oil production. The current task is to monitor the re-injection of gas, targeted management of gas injection wells, which will allow to inject the necessary volumes and get additional oil production. Based on the assessment, measures are proposed to recover injection coefficients. Timely diagnosis of the causes ensures the rational use of associated gas by the planned gas injection well stock.
-
-
-
Improving The Development Efficiency of Low-Permeability Reservoirs and Hard-To-Recover Reserves with The Introduction of Recoverable Liners Technology in Horizontal Wells with Multi-Stage Hydraulic Fracturing
Authors A.M. Ishkinov, I.N. Esipenok and A.F. MingazovSummaryObjective of the project is to introduce a new type of uncemented liner «Smart-liner» in wells with multistage hydraulic fracturing using the extraction of a part of the liner from the T1 zone to the adapter, in order to implement the 2nd horizontal wellbore with drilling from T1 with deviation in azimuth of the wellbore. This technology will increase the efficiency of the development of low-permeability reservoirs. The method assumes adaptation and revision of existing liners with multistage hydraulic fracturing assemblies with division of a single assembly into 2 parts. The first part with hydraulic fracturing sleeves is lowered into the horizontal wellbore, while it has a connecting unit for docking with the second part of the liner at T1. The second part is lowered on the next trip, while it has a connecting unit with the first part in the zone T1 of the well and has a removable liner hanger packer on the adapter head, which in the future will be possible to extract by the workover team. In the process of developing reserves, a moment comes after which the question of the implementation of the second horizontal wellbore is considered.
-