Aksenov M.,CJSC Rospan International |
Lachugin D.,CJSC Rospan International |
Nukhaev M.,Gubkin Russian State University of Oil and Gas |
Rymarenko K.,Gubkin Russian State University of Oil and Gas |
And 4 more authors.
Society of Petroleum Engineers - SPE Heavy Oil Conference Canada 2013 | Year: 2013
Russkoye heavy oil field is located in the northern part of Siberia. The field was discovered in 1968. It is characterized by the huge reserves: more than 1.3 billion tonn of oil in place and remote location (the field is located to the north from the polar circle). Main challenges for the field development are: unconsolidated formation, gas cap, high heterogeneity of formation, permafrost zone and heavy oil. This paper covers latest experience (2007-2012) obtained during field development pilot project implementation at the representative part of the Russkoye field. Pilot stage results will be used for the further field development strategy building. Effectiveness of different approaches has to be estimated, considering specifics of the field. Traditional field instrumentation did not provided reliable data for the analysis. New technologies (such as fiber optic distributed temperature sensors, specifically adopted multiphase metering etc.) were implemented for the building of the proper data acquisition system. During the pilot stage specific injection schedules, cold and hot water injection, various well completion applications were implemented. Depletion rate estimation based on real production data, determination of critical drawdown and numerous well testing activities including conventional buildup/drawdown pressure transient analysis and interference testing were made. Special attention is paid to the comparison of the cold and hot water injection and to the methods of control/monitoring of the well production. Monitoring and effectiveness estimation of the tested technology should be based on flow rate measurements data (MPFM), distributed pressure and temperature sensors (DP/TS) in horizontal production wells. Numerous new technologies were used for the pilot project. Paper describes approaches for integrated data acquisition implementation; development techniques comparison and new technologies adaptation workflow to the specific field conditions. New technologies application allowed to see specific field behavior and to estimate effect of various field development and management approaches tested. The results obtained during the pilot project will be used for the Russkoye field development planning, technical solutions will be implemented for the field monitoring and managing. Successful development of the first biggest heavy oil field should lead to initiation of development of other numerous challenging heavy oil fields in Russia. Copyright © 2013 by the Society of Petroleum Engineers.
Ignatyev A.,Rosneft |
Bikbulatov S.,CJSC Rospan International |
Mukminov I.,CJSC Rospan International |
Romashkin S.,CJSC Rospan International |
And 2 more authors.
Society of Petroleum Engineers - SPE Arctic and Extreme Environments Conference and Exhibition, AEE 2013 | Year: 2013
Most of oil and gas companies are building simulation models for its assets to planning reservoir development. However, even in those cases when the models are reliable and well calibrated to the production history, they do not always reflect the interaction between the different parts of a single system "reservoir-well-gathering system-processing facilities". In other cases when hydrodynamic models are the parts of an integrated model (IM), the models become too complex and require a long time of simulation, what mostly is not very convenient. This article provides an example of the IM building for the two formations of one of the largest oil-gas-condensate field in the world. Two large gas-condensate reservoirs are in the pilot stage. Full-field development of these reservoirs will increase hydrocarbon production by 5 times (Figure 1). To develop and optimize production plans and the development of the asset, it was decided to use the integrated model. There were considered different methodologies for constructing the unified model, which combines the reservoir models, models for wells and gathering systems and for processing facilities. Finally the best approach for this project has been selected. The initial compositional hydrodynamic models, which was matched to the production history, have been successfully converted to the Black-Oil models, while giving identical forecasts for gas and condensate and significantly reducing the simulation time. Well models were calibrated to historical data. The formation fluid in the gas gathering network was modelled using a simplified description, while in the models of processing facilities the fluid was modelling with the detailed composition. Despite of the differences in the approaches to the description of PVT properties of gas condensate in different simulators (Eclipse, Gap, Hysys), the developed Integrated Model has demonstrated consistency in the description of fluid PVT-properties. A significant reduction in time of simulation was obtained during the forecast calculations. The results of the Integrated Model were very important for the field development plan optimization, the development of which was previously limited to disparate models of reservoirs and ground infrastructure. Copyright 2013, Society of Petroleum Engineers.
Bikbulatov S.M.,Cjsc Rospan International |
Buleiko V.V.,Cjsc Rospan International |
Mukminov I.R.,Cjsc Rospan International |
Bikbulatov R.V.,LLC RN UfaNIPIneft |
Vinokurov V.N.,LLC RN UfaNIPIneft
Society of Petroleum Engineers - SPE Russian Petroleum Technology Conference | Year: 2015
The last 18 years CJSC "Rospan International" is producing gas and condensate from the two formations of The Urengoyskoye Gas-Condensate Field located in the Yamalo-Nenets Autonomous District. By 2016, the company expects a significant increase in production capacity, with an annual production of hydrocarbons more than 18 billions of cubic meters. About 250 wells are planned to drill at both formations. Gas transport is carried out based on the collector-beam pattern onto the GTU (gas treatment unit), which at this stage operates on the subcooling separation scheme. In the long term it is expected to complete modernization of the GTU. Multiphase flow transported through collectors is seen as a dynamic phenomenon and is subject for dynamic modeling. Non-stationary processes can often be observed in the gas-gathering networks. Moreover, a stable (close to steady state) stage often is not achieved, and thus the use of stationary calculation methods may not correctly model the real situation. In order to provide current and future control of production processes that occur during the operation of gas-gathering networks, and to provide the necessary engineering support, models of gas-gathering networks in the OLGA software have established. In this article authors present an analysis of calculations and offer recommendations based on results of dynamic modeling of transport processes in the production system using OLGA software. Analysis of stability of flow in gas-gathering system has been performed for an abnormality in the piping due to the formation of hydraulic slugs. Problem areas were examined, and recommendations for elimination of the negative phenomena thus regimes of transport products have been excluded in which the violation of a stable flow regime in the pipeline will be observed. The reasons of wells self-killing were investigated. Copyright 2015, Society of Petroleum Engineers.
Edelman I.,OJSC TNK BP Management |
Ivantsov N.,LLC TNNC |
Shandrygin A.,OJSC TNK BP Management |
Makarov E.,OJSC TNK BP Management |
Zakirov I.,CJSC Rospan International
Society of Petroleum Engineers - Arctic and Extreme Environments Conference and Exhibition 2011 | Year: 2011
The article discusses approaches to developing the Russkoe gas and oil field and results of pilot operations. The field is unique in terms of both hydrocarbon reserves and problems associated with its development. It is located above the Polar Circle and is characterized with a complex geological structure of highly permeable poorly cemented reservoirs saturated with high-viscosity oil (250-300 mPa*s). Significant factors making field development difficult include presence of tectonic faults, extensive gas cap, and underlying water. Field development was started with pilot operations whose results lay the foundation for the full field development strategy. The article describes technological solutions used and development scenarios considered. Copyright 2011, Society of Petroleum Engineers.
Edelman I.,TNK BP |
Shandrygin A.,TNK BP |
Severinov E.,CJSC Rospan International |
Gaidukov L.,LLC TPRC |
Dubrovskiy D.,TNK BP
Saint Petersburg Russia - From Fundamental Science to Deployment: 17th European Symposium on Improved Oil Recovery, IOR | Year: 2013
The paper presents an approach and the results of laboratory tests of the EOR methods on core samples of Russkoe gas and oil field, and the results of pilot works to the implementation of the recommended method The field is unique in terms of both its huge hydrocarbon reserves and problems associated with its development It is located above the Polar Circle and is characterized with a complex geological structure of highly permeable poorly cemented reservoirs saturated with high-viscosity oil Significant factors making field development difficult include presence of tectonic faults, extensive gas cap, and underlying water At the first stage of the research the following main EOR methods have been analyzed injection of hot water, steam injection, injection of polymer solutions and thermo-alkali flooding Experimental studies have been conducted on natural cores and bulk models The complexity of the preparation and conduct of experiments was attributed to work with weakly consolidated core At the initial stage of the pilot project one of the most effective methods, which performance has been proven by both experiments and simulations, has been recommended for implementation, - the displacement of viscous oil with hot water Test injection of hot water in one of the pilot areas commenced in August 2010 and, in general, confirms the effectiveness of oil displacement observed in laboratory experiments The results of field tests of EOR methods m the Russkoe field by injecting hot water are described in detail in the report In the next stage of the pilot project, which is aimed at finding appropriate technologies for the development of this extremely complicated field, the continuation of laboratory testing of the EOR methods is planned using new core samples Along with this, further laboratory testing of WAG and surfactants applicability is envisaged To achieve this objective, a special program of laboratory and analytical studies is planned.
Bolychev E.A.,CJSC ROSPAN International |
Konstantinova N.V.,OJSC TNK BP Management |
Muslimov E.Ya.,OJSC TNK BP Management |
Shayhutdinov I.K.,OJSC TNK BP Management |
Makarov E.M.,OJSC TNK BP Management
Society of Petroleum Engineers - SPE Russian Oil and Gas Exploration and Production Technical Conference and Exhibition 2012 | Year: 2012
Regardless of their size, slotted filters with the slot size over 0.5 mm do not have the containing function for average statistical types of Russkoe field reservoirs; in other words, well completion with liners with the slot size over 0.5 mm will not help solve problems caused by solids production in the course of operation. It is highly probable that using slotted filters with the slot size of 0.5 mm will help reach the goals posed, such as containment of coarse grained fraction that will not reach the surface with the well production flow and will settle in the horizontal borehole; forming a natural additional filtration layer made of the course fraction of reservoir rock produced; passage of the fine-grained fraction produced in the course of operation. It is not recommended that Premium type filters with the mesh size below 175 mμ should be used under Russkoe field conditions due to quick permeability loss. All Premium filters assure containment of the solid phase with the size of particles making their settling in the borehole highly probable when water cut rises in the course of operation. Mesh with netting according to GOST 3187-76 has high clogging resistance. Filter based on fabric plaiting meshes are inapplicable under conditions of Russkoe field reservoirs with poorly consolidated sandstone since it is prone to quick clogging despite their high initial permeability. The tests conducted cannot model all processes taking place under reservoir conditions and are applicable within the framework of model limitations. The reliable applicability assessment can be assured under field conditions only. The pilot program in the Russkoe field, which includes testing completion systems described in this paper, in underway in 2012. Copyright 2012, Society of Petroleum Engineers, Inc.
Bikbulatov S.M.,CJSC Rospan International |
Vorobyev D.S.,CJSC Rospan International |
Smirnov A.Y.,CJSC Rospan International |
Mukminiov I.R.,CJSC Rospan International |
Romashkin S.V.,CJSC Rospan International
Society of Petroleum Engineers - SPE Russian Petroleum Technology Conference | Year: 2015
CJSC "Rospan International" developing the Achimov deposits on the two license areas. These reservoirs have the gas condensate saturation, low permeability at the level of 0.8-1.6 md, abnormally high formation pressure by a factor of -1.7 abnormalities. Reservoir Engineering conducted using large volume fracturing with proppant loading of 150-400 tonns. Geological formations heterogeneity, nonsimultaneous entering wells and as a result, the uneven development of reservoirs necessitate of regulation of technological modes of operation wells. The task is to select the well operating mode, maximizes the production of liquid hydrocarbons at a constant level of gas production. The results presented in this paper, represent a further development of approaches to solving the problems previously described in two papers , . The model is presented as a single complex network model collecting the two license areas and merged with reservoir model and the model of the GTU. The type of reservoir models as part of the integrated model is a matter of finding the most suitable to the conditions of the problem being solved tool and is considered in detail in the article. This paper describes the approaches to setting up model to the actual data, including the use of automated tools. The concept has been used to set up an equal uncertainty in the evidence. So, to build a table of pressure losses along the wellbore, the work carried out at the choice of a single correlation flow in the wellbore without the individual correction factors. It was chosen the single choke model, which does not provide for individual tuning coefficients of variation, as a way of setting pressure drop across the each well. It was justified choice of options in the calculation of temperature performance and thermal conductivity of selected wells. As a result of the work is considered an upgraded integrated model, which allows to carry out work on the automated setup to the actual data and to optimize technological operating mode wells. The optimizer takes into account the dependence of the condensate-gas factor on the selected operating mode of the well, and can thus be used for the oil fields, where the limiting factor may be the high GOR and for gas condensate fields to improve the current condensate recovery. Developed in the course of the project methodology reduces uncertainty of the model set up procedure to the actual data and carry out optimization calculations for choosing the best wells operation mode. Copyright 2015, Society of Petroleum Engineers.
Bikbulatov S.,CJSC Rospan International |
Smirnov A.,CJSC Rospan International |
Buleiko V.,CJSC Rospan International |
Mukminov I.,CJSC Rospan International |
Romashkin S.,CJSC Rospan International
Society of Petroleum Engineers - SPE Russian Oil and Gas Exploration and Production Technical Conference and Exhibition 2014, RO and G 2014 - Sustaining and Optimising Production: Challenging the Limits with Technology | Year: 2014
In this paper, the authors address the issue of optimization of gas production system reservoir-wellpipeline-GCTU (gas & condensate treatment unit) using integrated modeling. Authors describe the method of calculation, the setup process and modeling of each element of the system and the various methods of optimization. Special attention is paid to the automatization of the engineer interaction with models, modeling of the GCTU and optimizing the mode of operation in conjunction with other elements of the system. Copyright © 2014, Society of Petroleum Engineers.