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.
Edelman I.,OJSC TNK BP Management |
Ivantsov N.,TNNC Ltd. |
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.
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.
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.
Bikbulatov S.M.,Cjsc Rospan International |
Buleiko V.V.,Cjsc Rospan International |
Mukminov I.R.,Cjsc Rospan International |
Bikbulatov R.V.,RN Ufa NIP Ineft LLC |
Vinokurov V.N.,RN Ufa NIP Ineft LLC
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.