Integrated modeling is a tool of managing a process of hydrocarbon production from an asset, which consists of downstream and upstream elements. Integrated model subsequently covers complex relationships between reservoirs, wells, pipelines and elements of subsurface infrastructure. In many ways, efficiency of oil and gas field development depends on these relationships [1]. For this reason, modeling of a hydrocarbon production process should embrace a whole chain (from upstream to downstream) and integrated modeling is best suited for this task [2]. The main purpose of this work was to evaluate the possibility of well operation condition optimization with account of subsurface infrastructure using integrated modeling tools. The paper gives a review of a modern approach to modeling a large Sakhalin offshore oil and gas condensate field, the X Field. Oil producers have been drilled from the shore into oil rims of reservoirs with record-breaking horizontal offset in the oil and gas industry. Initial oil rates exceed 3000 ton/day. However, the field development is complicated at the moment, due to gas breakthrough from the gas cap which leads to a critical decline in well performance. An integrated model includes simulation models of two oil/gas reservoirs, well models, and a model of single gathering system. The paper briefly describes the approach to building and matching the integrated model. After building and history matching of the integrated model, sensitivity of oil production to a change in well operation condition was analyzed. Also, mutual well influence on the gathering system level was evaluated. As a possible scenario for well operation condition improvement an intermittent well operation was considered. The results of model runs demonstrate that a change in well operation conditions won't positively affect oil production in short period.

No abstract

No abstract

The operation of gas condensate fields under natural recovery drive is accompanied by retrograde condensation in the well bottomhole zone, which inhibits the movement of hydrocarbons in this area. One of the main methods of maintaining reservoir pressure under these complications is the injection of dry gas into injection wells, which is limited by economic factors. The problem of the development of gas condensate fields with oil rims is that the traditional reservoir pressure maintenance system does not provide a high oil recovery factor. Thus, the effective production of hydrocarbons requires new technologies and technical means. The paper considers a complex strategy for the development of such reservoirs, based on integrated modeling and the use of smart-well solutions. The paper presents PVT-analysis, special core analysis, geophysical studies and well test results. An integrated field model has been created that allows to identify effective technologies for the development of gas condensate formations and the oil rim, as well as to account for the operational capabilities of surface facilities, while maximizing hydrocarbon recovery. The assessment and recommendations for the long-term development of a gas condensate field with an oil rim are suggested. Multivariate calculations are performed to assess the productivity of wells and reach the field's maximum potential. The proposed field development strategy involves optimization of the surface infrastructure and hydrocarbon transportation system.