A 3-Year Results of Application a Combined Scale Inhibition and Hydraulic Fracturing Treatments using a Novel Hydraulic Fracturing Fluid, Russia
- Olesya Vladimirovna Levanyuk (Schlumberger) | Alexander M. Overin (Schlumberger) | Almaz Sadykov (Schlumberger) | Sergey Parkhonyuk (Schlumberger) | Bernhard R. Lungwitz (Schlumberger) | Philippe Enkababian (Schlumberger) | Alexander Vladimirovich Klimov (Nord Imperial LLC) | Sergey Legeza
- Document ID
- Society of Petroleum Engineers
- SPE International Conference on Oilfield Scale, 30-31 May, Aberdeen, UK
- Publication Date
- Document Type
- Conference Paper
- 2012. Society of Petroleum Engineers
- 3 Production and Well Operations, 3.1 Artificial Lift Systems, 5.4.1 Waterflooding, 3.1.2 Electric Submersible Pumps, 2.2.2 Perforating, 5.2 Reservoir Fluid Dynamics, 4.1.2 Separation and Treating, 3.2.3 Hydraulic Fracturing Design, Implementation and Optimisation, 1.8 Formation Damage, 4.1.5 Processing Equipment, 4.3.4 Scale, 4.2.3 Materials and Corrosion, 2.5.2 Fracturing Materials (Fluids, Proppant), 5.2.1 Phase Behavior and PVT Measurements
- 0 in the last 30 days
- 320 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 8.50|
|SPE Non-Member Price:||USD 25.00|
Scale deposits are a common problem in oil and gas wells and can have detrimental effects on well production. Depending on the severity, scaling can stop production entirely as scale forms anywhere in the well production system, including the formation, perforations, casing or tubular, and in or on the artificial lift equipment. There are several chemical and mechanical methods for removing scale deposits. However, to prevent scale deposition, the only solution is chemical inhibitors injected into the formation. The typical production system includes artificially lifted, stimulated wells (propped hydraulic fractures) placed in reservoirs where pressure maintenance is achieved by water flooding. The artificial lifting is typically accomplished through use of electric submersible pumps (ESPs). In reservoirs where produced fluids exhibit scaling tendencies, ESP run life is significantly shortened by scale formation on the pump elements restricting rotation. By treating the formation with chemical inhibitors, the life of the ESP can be extended.
In this paper we provide approaches for improving a compatibility of a novel hydraulic fracturing fluid (used in Russia) and scale inhibitor. A 3-year campaign to combine scale inhibition with the hydraulic propped fracture effectively increased the average run life of ESPs in the Mayskoe and Snezhnoe oil fields.
Scaling is a persistent problem in the Russian oilfield industry (Voloshin et al. 2003; Ragulin et al. 2006; Yakimov et al. 2010). In Western Siberia, this problem is more pronounced because most oil wells are lifted by electric submersible pumps (ESPs). For Imperial Energy, oilfield damage due to scale buildup accounted for 20% of all ESP failures. Most of wells are hydraulically fractured. Thus, the objective of scale control is protection of the entire length of the propped fracture as well as the downhole equipment. Since 2007, conventional hydraulic fracturing treatments with a phosphino-polyacrylate scale inhibitor (PPASI) pumped simultaneously as an fracturing fluid additive have been introduced to Western Siberia (Cheremisov et al. 2008). It should be noted, that a so-called glazing agent is used to facilitate the glazing process of inhibitor on the matrix surface and proppant particles.
Over the past several years in Russia, the selection of hydraulic fracturing fluid selection has emphasized reducing polymer loadings. In 2009, a novel fracturing fluid based on guar with a solid borate-based crosslinker was introduced in Russia (Fu at al. 2010). This fluid allowed decreasing the amount of polymer in fracturing fluid to 3.0 kg/m3. Cowan et al. (2000) reported that PPASI had little effect on fluid viscosity for a crosslinked borate fracturing fluid with guar loading of 3.6 kg/m3 or more. To eliminate the impact of scale inhibitor and glazing agent on fracturing fluid properties, we proposed the approach described in this paper.
This paper discusses field results following fracturing treatments that incorporated a PPASI with the novel borate crosslinked fracturing fluids at Imperial Energy oil fields.
Imperial Energy operates in the Tomsk region of Western Siberia. Western Siberia is the most prolific oil-producing region in Russia with some of the world largest oil fields. Oil production from West Siberia currently accounts for 71% of Russia's total. Snezhnoe, Festivalnoe, and Mayskoe fields are small, mature oil fields located in the West Siberian basin. Because of low to medium permeability, their economical development is mostly possible only through utilization of fracturing.
|File Size||1 MB||Number of Pages||13|