Squeezing Scale Inhibitors to Protect Electric Submersible Pumps in Highly Fractured, Calcium Carbonate Scaling Reservoirs.
- Neil Poynton (Baker Petrolite) | Dmitry Markelov (Rosneft) | Alexandr Voloshin (Rosneft) | Alan Thomas Miller (Baker Petrolite) | Dmitry konyukhov (Baker Petrolite) | Ilgiz Ganiev (Rosneft) | Alexander Mikhailov (Purneftegaz) | Victor Ragulin (Rosneft) | Leontieff Andre (Baker Petrolite)
- Document ID
- Society of Petroleum Engineers
- SPE Russian Oil and Gas Technical Conference and Exhibition, 28-30 October, Moscow, Russia
- Publication Date
- Document Type
- Conference Paper
- 2008. Society of Petroleum Engineers
- 5.7.5 Economic Evaluations, 5.2.1 Phase Behavior and PVT Measurements, 4.6 Natural Gas, 3.1.2 Electric Submersible Pumps, 4.1.5 Processing Equipment, 3 Production and Well Operations, 1.8 Formation Damage, 5.1 Reservoir Characterisation, 5.6.5 Tracers, 1.2.3 Rock properties, 4.1.2 Separation and Treating, 3.1 Artificial Lift Systems, 5.2 Reservoir Fluid Dynamics, 4.3.4 Scale, 4.2.3 Materials and Corrosion, 1.6.9 Coring, Fishing, 2.2.2 Perforating
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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.
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).
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