The first installation of intelligent tracers system in extended reach horizontal well was deployed by LUKOIL-Nizhnevolzhskneft LLC in a thin oil rim reservoir with a large gas cap located in the North region of the Caspian sea. Putting in operation of the Yu. Korchagin field is challenging serious tasks during development:relative zone inflow estimation;identifying intervals of water breakthrough;long-term monitoring of oil extraction and water level;monitoring of completion equipment functionality. Traditional technologies of production logging, considering complex well trajectory, are highly risky and expensive. Fiber-optic system of monitoring of Distributed Temperature Sensors (DTS) would be an ideal instrument identifying the source of gas breakthrough, but such technology is not always feasible due to necessity of rotation of the completion during its running in extended reach horizontal well. Performance of periodic field research via cable is limited due to drilling operations on the platform. In addition to perform such survey it is required to use downhole tractors to transport logging tool. Practice of tractors usage in extended horizontal wells in the field has a negative statistics to reach the toe of the well, as for a project operator it's important to verify remote flow contribution (e.g. 7000 m) in total well flow rate. To solve the above problem a relatively new monitoring technology has been applied. At stage of equipment fabrication downhole intelligent chemical sensors were installed in sand screens. Sensors are placed in the drainage area in different intervals along the well to meet objectives by the engineers of LUKOIL Nizhnevolzhskneft LLC to provide flow profiles, identify the location of gas breakthrough and confirmation of the functional work of AICD in the course of time. After selection of surface samples of hydrocarbons at the wellhead, a laboratory analysis is conducted for chemical tracers in the sample and interpretation of tracer signals during unsteady and steady state production is performed. Some period has passed related to operation of the well after its start. The first well equipped with intelligent chemical indicators has its history of production; the well performance can be evaluated both in whole, and for each zone equipped with chemical indicators. This paper will review the experience of wireless monitoring for extend horizontal well on the shelf of the Caspian sea.
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).
This paper presents a comprehensive example of wireline formation tester and drillstem tester data that offers insight to compare and contrast the information that can be delivered by these two similar but different technologies. The dataset presented here consists of logs, WFT and DST data from two North Caspian wells penetrating Cretaceous and Jurassic layers. The log data is used to initially predict fluid types and contacts. This is later verified with WFT data. This combined answer is then used to design a well test program to extract maximum data for development planning. Data is also used to defend the booking of reserves before state committees. Difficult reservoir conditions including complex mineralogy and varying and unknown water salinity can make fluid typing and contact determination from wireline logs alone to be problematic. By incorporating WFT downhole fluid analysis data ambiguities in the petrophysical interpretation can be resolved and the results from the continuous log measurements can be calibrated by the sparser WFT dataset. Mobility information from WFT data is also used to calibrate log-derived permeabilities and this is used appropriately plan the DST program. Finally data from the DST program, including rates, fluid types and fluid properties are reconciled with the corresponding WFT data.
In this paper we describe a new approach to the development of oil and gas fields in Russia and CIS countries, which consists of integrated use of well log data while drilling and deep directional electromagnetic measurements (EM) for geosteering applications with subsequent update of the geological static model. This approach was implemented in 2016 on the offshore Filanovsky field to reduce drilling risks in the first production wells, and to refine and update the 3D static model. At the initial stage of drilling estimated structural uncertainty in the field was ± 15 m (vertical depth). The use of deep directional resistivity technology (DDR) while drilling allowed to determine bed boundaries remotely based on resistivities at vertical distance of up to 24 m (vertical depth). Based on inversion of deep electromagnetic measurements (inversion), the first wells were successfully drilled with all the geological and technical tasks completed. The obtained well log data together with inversion allowed refining of the correlation of the target beds with seismic data, and updating the velocity-depth model as well as structural surfaces of the deposit. New surfaces, together with the petrophysical interpretation of the data from the horizontal and production intervals obtained during drilling, were used to update the stochastic 3D model for subsequent reserves estimation and planning of future wells.
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