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Today it is trendy to pursuit of the development of hard-to-recover reserves, companies often do not pay due attention to the huge reserves at conventional reservoirs that has become difficult to recover due to ineffective field development. At the same time, the fields have a well-developed infrastructure, as well as favorable reservoir properties. The reason for stopping thousands of producing wells at such fields, as usual, is early time injected water breakthrough because non-optimal development, casing of high production at the early stage of reservoir development and ignoring reservoir surveillance and well diagnostics. Using the example of the analysis of reservoir surveillance results during development of one of the large oil fields, the authors show how the problems grew and led to the actual loss of half of the initially recoverable reserves. For this reservoir and its analogues production enhancement operations are developed for field productivity reactivation with the justification of their effectiveness. The information basis for current reserves localization is reservoir dynamic model calibration on the results of historical and additionally conducted production logging, well-testing and cross-well tests. Accounting for the injection and production vertical profile, clarifying areal displacement coverage of the reservoir, accounting for cross-flows, reservoir properties distribution and the current reservoir pressure made it possible to identify the most promising areas for production enhancement. Logs in transit wells confirmed dynamic model reliability. Drilling of horizontal wells and optimization of the production and injection targets are planned.
Digital solutions for field development surveillance based on permanent distributed fiber-optic systems (Russian)
Ipatov, A. I. (Gazpromneft STC LLC) | Kremenetsky, M. I. (Gazpromneft STC LLC) | Andrianovsky, A. A. (OptoMonitoring LLC) | Trusov, A. V. (OptoMonitoring LLC) | Gulyaev, D. N. (Gubkin University) | Solovyova, V. V. (Gubkin University)
The paper is focused on innovative technologies of well and reservoir real-time surveillance for both data recording, and further study of the thermo-dynamic processes around the well and the reservoir. In particular, a special role is given to temperature field, the most promising method of cased-hole production logging. Today, such a tool as distributed fiber-optic downhole temperature and acoustic sensors record an enormous amount of information at a high speed, and this is possible in real time. In this regard, there is a need for the development of specialized software that allows for primary processing and interpretation of distributed temperature records by fiber-optic. This need contributed to the activation of the creation of software and methodological support (SMS) of DTS - software aimed at solving the mentioned above tasks: a portal for data documentation and analytical module for interpretation of a distributed temperature records. This paper discusses approaches to the software concept. In addition, some requirements for the composition, structure and principles of operation of such software-analytical products are substantiated and outlined, recommendations are given for their practical use when working with the results of fiber-optic temperature records. Implementation of the presented approaches to increasing the efficiency of oil and gas fields development, namely: clarification and adaptation of the current dynamic model of the field, assess the degree and reasons for the decrease in well productivity, identify the places of water breakthroughs, as well as which hydraulic fracturing ports or wellbore intervals are not flowing. A clear advantage of the proposed concept of data interpretation lies in the fact that the presented fiber-optic technologies are simultaneously elements of instrumental digital control and a digital processing system for geomonitoring processes, capable of providing optimal well control during long-term production.
The PDF file of this paper is in Russian. Last years there has been a trend in Russia to develop hard-to-recover oil reserves with low-permeability (less than (1–2)⋅10–3 mkm2) and hyper-low-permeable ((0.1–0.001)⋅10–3 mkm2) fields. The latter primarily include Bazhenov, Domanic and Achimov fields. As a result of the extremely low natural filtration properties of these reservoirs, their development at the present stage of technological development provides for the mandatory completion with multiple-fractured horizontal wells (MFHW). Experience in the development of layers of the specified type for Gazprom Neft PJSC shows that the highest oil production rate is achieved if the MFHW system reveals not only the low-permeability rock matrix, but also captures the highly conductive (typically fractured) streaks, that take place in some cases. The difference in the permeability of such highly conductive layers and the hyper-low-permeable matrix of the host rocks can be very significant, for example, up to 105–106. Highly conductive layers in the section associated with the achievement of high initial oil flow rates in new wells, in the process of further development, negative consequences may arise as a result of premature (and even worse – unpredictable) gas and water breakthroughs through narrow fractured layers. The authors dissertate upon how to take into account the risks of loss of well productivity as a consequence of the pronounced geological heterogeneity of these fields, even if the scale of the impact of this heterogeneity is still difficult to assess by modern research methods. In this regard, this paper analyzes some of the results of core, logging, well-testing and indicator studies with the allocation of characteristic features indicating the presence of local highly conductive layers in the section of the oil complex. In addition, the authors proposed some control solutions to minimize the negative consequences of the development of such heterogeneous fields.
- Asia > Russia > West Siberian Basin > Bazhenov Formation (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District > West Siberian Basin > Vostochno Messoyakhskoye Field (0.94)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Central Basin > Tazovskoye Field (0.94)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (0.86)
Evolution of production logging in low permeability reservoirs at horizontal wells, multiple-fractured horizontal wells and multilateral wells. Gazprom Neft experience (Russian)
Bilinchuk, A. V. (Gazpromneft NTC LLC) | Ipatov, A. I. (Gazpromneft NTC LLC) | Kremenetskiy, M. I. (Gazpromneft NTC LLC) | Sitnikov, A. N. (Gazpromneft NTC LLC) | Yakovlev, A. A. (Gazpromneft NTC LLC) | Shurunov, A. V. (Gazpromneft NTC LLC) | Galeev, R. R. (Gazpromneft NTC LLC) | Kolesnikov, M. V. (Gazpromneft NTC LLC)
The PDF file of this paper is in Russian. The rapid development of drilling and completion of horizontal wells (HW), as well as the need for successful selective well interventions requires the growth of informativeness of field geophysics to meet the needs of production. The greatest difficulty in conducting geophysical logging in the area of development control is caused by the non-uniform flow pattern in the HW and the lack of effective methods for delivering equipment to the bottom hole of the HW. Currently, the standard short-term field geophysical logging technology in horizontal wells has been successfully applied to the assets of Gazprom Neft. The technology has been modified for different types of wells both in terms of the research tool, and in terms of delivery technologies and feed-in inducing methods. A further increase in the effectiveness of the geophysical logging in HW, including multilateral HW and multi-fractured HW (MFHW), is associated with the transition from the usual methods of standard one-time logging to stationary distributed or point-distributed monitoring of the inflow / intake profile of horizontal wells. The main stationary monitoring systems, such as fiber optic systems for temperature (DTS) and acoustics (DAS) and point-distributed indicator studies, have already been tested in the first wells of the Company. In order to be able to use these systems on a wide range of wells, the methodological and technological component of research by these systems is currently being developed. The article presents recommendations of Gazprom Neft experts to increase the informativeness of research of HW and MFHW and minimize the risk of an accident during the downhole operations, as well as conclusions regarding the informativeness and effectiveness of new methods for remote monitoring of low permeability formation in wells with complex completion based on the results of testing and implementation of stationary monitoring systems in the Company.
Development of technologies and tools for field research of the Gazprom Neft Exploration and Production Unit (Russian)
Kotezhekov, V. S. (Gazpromneft NTC LLC, RF, Saint-Petersburg) | Margarit, A. S. (Gazpromneft NTC LLC, RF, Saint-Petersburg) | Ipatov, A. I. (Gazpromneft NTC LLC, RF, Saint-Petersburg) | Pustovskih, A. A. (Gazpromneft NTC LLC, RF, Saint-Petersburg)
The PDF file of this paper is in Russian. Production logging and well testing are a source of key information for the design and control of field development. The relevance, reliability and completeness of these researches depend on how effective decisions are made at all stages of field development. Reliable results of field researches: production logging and well testing are important source of information on well and reservoir characteristics, bottom-hole area, inter-well interaction etc. Within the framework of continuous improvement of the efficiency of process control and optimization, Gazprom Neft develops a number of projects in the field of production logging and well testing to develop tools and technologies aimed at solving the number of challenges. Increasing the complexity of the resource base, the development of low-permeability reservoirs, oil rims and fractured reservoirs requires the development of new approaches in the planning and processing of field researches. An increase in the number of oil assets and an increase in the number of wells with high-precision downhole telemetry lead to an increase in the number of field researches. This circumstance, coupled with the current preservation of the volume of labor resources at the current level, leads to the need to create automated systems for preparing and processing data. High resource consumption of well operations and complex geological structure of new assets of the Company raises the price of a possible error, which is associated with incorrect decisions, based on incomplete or unreliable results of field research. In this regard, comprehensive measures are needed to increase the reliability of the results of processing production logging and well testing, as well as assessing the reliability of all estimated parameters. The article briefly describes completed and ongoing projects aimed at developing technologies and tools for production logging and well testing researches in the following areas: centralization and verification of field research data, automation of well-testing interpretation, development of a methodological and software system for optimal well testing planning, optimal well planning based on the value of information (VOI), generating of reservoir pressure maps based on proxy modeling, implemented of new production logging technologies and the development of a temperature simulator.
Horizontal well production monitoring with distributed temperature sensor (Russian)
Ipatov, A. I. (Gazpromneft NTC LLC, RF, Saint-Petersburg) | Kremenetsky, I. M. (Gazpromneft NTC LLC, RF, Saint-Petersburg) | Kaeshkov, I. S. (Gazpromneft NTC LLC, RF, Saint-Petersburg) | Buyanov, A. V. (Gazpromneft NTC LLC, RF, Saint-Petersburg)
The pdf file of this paper is in Russian. The authors sum up Gazprom Neft field experience in the area of longterm distributed temperature sensor (DTS) studies in horizontal wells. First steps in information capacity analysis were made on vertical multilayer well studies. Obtained results approved thermosimulator calculations and allowed to determine future conditions of representative studies in horizontal wells. The following periodical DTS measurements during multi-fracturing and 6 months stationary monitoring showed high information capacity of both stable and dynamic temperature field. The next steps in method effectivity enhancement are two be done in three directions:DTS optimization, its components and price; forming the best well run and stop conditions for easurements; usage of advanced methods of interpretation and software. Most urgent field task is DTS installation in horizontal well with ESP. Exact technology is not provided yet (ESP housing, Y-tool or composite fiber rod). Anyway for tie-in and reliable interpretation basic production logging studies will be conducted before DTS installation. In its turn obtained results of distributed acoustic sensing are still to be comprehended and may also find its place in production monitoring system.
Field-geophysical research of horizontal wells in low unstable inflow. Problems and solutions (Russian)
Kolesnikova, A. A. (Gazpromneft NTC LLC, RF, Saint-Petersburg) | Kremenetskiy, M. I. (Gazpromneft NTC LLC, RF, Saint-Petersburg) | Ipatov, A. I. (Gazpromneft NTC LLC, RF, Saint-Petersburg) | Kovalenko, I. V. (Gazpromneft NTC LLC, RF, Saint-Petersburg) | Komarov, V. S. (Messoyakhaneftegaz JSC, RF, Tyumen) | Nemirovich, G. M. (Messoyakhaneftegaz JSC, RF, Tyumen)
The pdf file of this paper is in Russian. Today Horizontal and deviated wells found strong using in the field development schedule, because of their high efficiency in the extraction of hydrocarbons. Using such wells related with significant complication works, both in drilling and the planning and conduct geophysical research and interpretation of the getting results. The article discusses the possibility of informative geophysical studies (PLT) in determining the inflow profile of horizontal wellbore under unstable flow rate and low draw down pressure. It has been shown that the addition of a standard set of PLT and water-cut log with gauges distributed over the cross section of the wellbore, and spectral noise logging allows to successfully identify contrasting inflow rates (in case with the oil reservoir with high specific yield, breaking water and gas). The control the dynamics of filling the wellbore on the unstable state start-up or change of draw down pressure is necessary condition for the effectiveness of research. Methods of geophysical investigations at this stage of knowledge of the field needs to be considered not only in the "traditional" context, as a development control tool, but also as a method of further exploration of the deposit and the possibility of obtaining additional information regarding the mining characteristics of the exposed geological bodies, the study based production potential of the effective length horizontal wells drilled in cyclites different genesis.