Rosneft has oil fields in Western Siberia producing fluids from a number of wells via Electric Submersible Pumps (ESP's). While production rates are increased using ESP's, run time can be compromised by the formation of scale within the inner workings of the pump. The deposition of scale can be detected by the pumps requiring increasing amounts of current to maintain the flow rates. Eventually the pumps fail (either mechanically or electrically) and have to be replaced. Typically examination of these pumps indicated the main failure mechanism to be the deposition of Calcium Carbonate scale within the pump. The actual run times achieved tend to be dependant on the severity of the scaling produced water, but were typically in the order of weeks. However in some extreme cases, pump failures had occurred in a matter of days from replacement and start up. It was proposed that one treatment strategy to increase the pump run time by inhibiting scale formation was via a Scale Inhibitor Squeeze application treatment. The Squeeze process and inhibitor application is very well understood, but to get successful squeeze treatment you need to perform adequate laboratory selection tests, including inhibition efficiency testing and core flood evaluations. This data, together with the Heriot Watt University Squeeze VI modeling can get an approximation to the potential squeeze life. This paper presents the testwork performed to identify and develop successful Scale Inhibitor Squeeze Chemistries suitable for application in Western Siberia. It details the laboratory testing, the coreflood evaluation and Squeeze VI modeling. The Squeeze application and performance of the first well squeezed is reviewed together with a summary of the current status of the wells squeezed. An economic evaluation of the squeeze is also performed together with a summary of all the wells treated which demonstrates that the squeeze application provided a very cost effective method of scale control to maximize pump run time and increase the net well value. Introduction Yuganskneftegaz is Rosneft's largest oil-producing enterprise. It holds licenses to develop 26 oilfields located in the Khanty-Mansiysk Autonomous District of Western Siberia. Yuganskneftegaz was established in 1977, and in early 2005, it was fully integrated into Rosneft's core production base. Yuganskneftegaz is responsible for fields that contain approximately 16% of Western Siberia's recoverable oil reserves. Nearly 80% of them are concentrated in the Priobskoye, Mamontovskoye, Malobalykskoye and Prirazlomnoye fields. Production of oil and associated gas at Yuganskneftegaz in 2006 amounted to 56 million tonnes, and 1.5 billion cubic meters, respectively, which is 70.1% and 11% of Rosneft's total production. Yuganskneftygaz Primary fields are: Priobskoye, Prirazlomnoye, Mamontovskoye, Malobalykskoye The number of wells in production in 2006 was 7,707. The average production per well is 21.3 t/day (2006).

In Rosneft Oil Company 90% of production is provided by 15 000 ESP wells. That is why monitoring and efficiency increasing of those wells are of current importance. Up to recent time, analysis and optimisation were done regularly on monthly basis, while real time monitoring systems were oriented mainly to keep books of oil production. In our opinion implementation of real time monitoring and control systems and reducing analysis and optimisation cycle to days may increase production by the means of rate increase and downtime reduction. Research in this area started in Rosneft in late 2006 in the framework of New Technologies System. Currently there are solutions for data gathering and proceeding, worked out information use in business processes, has practice in production increase and well downtime reduction, started company-wide application of system. Paper includes cases of well regime analysis done with the described system. An important question of quantative evaluation of system applicability for certain conditions was examined. This paper may help to take decision on application of this type of systems for other companies. Introduction In Rosneft Oil Company 90% of oil production is provided by 15 000 ESP wells. That is why monitoring and efficiency increasing of those wells are of current importance. Up to recent time, analysis and optimisation were done regularly on monthly basis, while real time monitoring systems were oriented mainly to keep books of oil production. Monthly efficiency calculations include estimation of production potential - maximum possible oil rate for that well that could be provided by lowering down bottomhole pressure (frequency increase or bigger pump installation) or increasing well productivity (fracturing) and comparing it with the current oil rate. This "simple» comparison is based on large amount of data collected (liquid rate, water cut, annulus pressure, fluid level, GOR, …) and engineering calculations for bottomhole pressure calculation, estimation of current well productivity, etc. [1] Analysis of current wells' regime efficiency shows that there is a potential of increasing oil production (in terms of oil rate increase and well downtime reduction) by the means of introducing monitoring and control systems and processes and shortening up analysis loop to days (see example - "Figure 1. Monthly based analysis"). Experience of real time ESP monitoring and control systems application in other companies shows that there might be an effect of production increase by 2–10% and cost reduction by 5–25% [2]. Research in this area started in Rosneft in late 2006 in the framework of New Technologies System to define the value of those systems application, to check its applicability and plan company-wide application.

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