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AbstractSteam chamber (SC) control during steam-assisted gravity drainage (SAGD) has a great impact on the efficiency of heavy oil and natural bitumen recovery. An optimal production rate and corresponding bottomhole temperature and pressure should be maintained to improve SAGD cumulative oil recovery and the steam-oil ratio.SAGD optimization work includes simulation results and real-time data monitoring. Existing analytical models 1,2 are mainly dedicated to describing the ability of a reservoir to drain heated oil and do not depict all details of real SAGD processes.In the present work a new analytical model of the SAGD production regime is described. The initial stage of oil production is considered before SC reaches the production well. The model accounts for mass and heat transfer during the process of heavy oil recovery and establishes a significant correlation between production rate and the dynamic of SC evolution. The model that was developed was compared with simulation done by commercial reservoir simulation software.
Gravity Drainage RateAccording to Butler's original model 1 , the drainage volumetric rate per one meter of the well length ( d
Summary
The gas-lift operation is widely internationally used in the oil production. At present, this production method is used at the Orenburg oil and gas condensate field as one of its options—a natural-pressure gas-lift well operation method. The advantage of the natural-pressure gas-lift well operation method is a significant reduction in operating costs (electricity, electric submersible pump rent). At that both, new wells drilled into the gas cap and production wells where a breakthrough of gas has occurred can be used as a donor well. A feature that defines this operation method is a need for continuous control over pumping down each borehole. This is due to the fact that a donor well provides several producing oil wells with active gas, the operational parameters of these may significantly differ from each other. A system with automatic lock shield valves was adopted to automate the injection of gas in the Orenburg oil and gas condensate field, it allowed tuning up the injection, constantly monitoring and metering consumption of gas for each well.
This paper outlines the Gazpromneft-Orenburg experience in adopting an intelligent system for gas injection monitoring. It is described as a stage of a technical task preparation, conducting pilot runs at several wells, adjusting requirements to the equipment based on the results of pilot runs, full-scale implementation of the project at all wells of the deposit, optimization of gas-lift wells throughout the well stock.
The automated gas-lift process control system adopted at the Orenburg oil and gas condensate field allowed: collecting and processing information coming from primary transducer-converters;managing the actuators ensuring optimal well performance;operatively ensuring well operation mode alternations;accumulating the information received to gather statistical data and monitor the oil wells status.
The purpose of this paper is to compare the permanent monitoring systems based on optical fiber systems and intelligent chemical tracers. This analysis was carried out based on an operational assessment of similar systems for permanent monitoring of horizontal wells in the Yuri Korchagin oilfield for 3 years in various regimes of operation.
The paper discusses the main advantages and limitations of these systems and provides their comparison to conventional production logging tools (PLTs).
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