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Foam Acid Treatment - The Key to Stimulation of Carbonate Reservoirs in Depleted Oil Fields of the Samara Region
Letichevskiy, Alexander (JSC Samaraneftegaz Rosneft) | Nikitin, Alexey (JSC Samaraneftegaz Rosneft) | Parfenov, Alexey (JSC Samaraneftegaz Rosneft) | Makarenko, Vitaliy (JSC Samaraneftegaz Rosneft) | Lavrov, Ilya (JSC Samaraneftegaz Rosneft) | Rukan, Gleb (Schlumberger) | Ovsyannikov, Dmitry (Schlumberger) | Nuriakhmetov, Ruslan (Schlumberger) | Gromovenko, Alexander (Schlumberger)
Abstract Oil fields of the Samara region are at a late stage of development, which is reflected in declining of their production level and rapid growth of watercut. About 30% of the region's industrial hydrocarbon reserves are concentrated in carbonate reservoirs, which require stimulation. Low reservoir pressure, heterogeneity of the formation and the proximity of water-saturated interlayers significantly complicate the task of efficient field development and exploitation. In such conditions, the use of traditional methods for treating the bottomhole zone of carbonate rocks does not bring the expected results, and the worsening stock of exploited objects makes it necessary to look for new promising methods for increasing oil recovery. Carbonate reservoirs stimulation in the Samara region is carried out using a spectrum of various technologies of hydrochloric acid treatments, both to extend the life of old wells and to efficiently start new wells after drilling. In order to increase the effect from the performed hydrochloric acid treatments in 2016, the foam diverting technology was applied in the framework of pilot projects. This technology uses a stable non-damaging agent to form a nitrogen foam of 65% quality at the bottom hole. After the treatment, the foam breaks down into liquid and nitrogen, which in turn improves well flow back and helps to restore the natural flow. Despite the high degree of field development, the use of foam made it possible to achieve a 69% greater initial well productivity index than other methods. At the same time, the starting production rate of wells increased almost 2 times. The technology also allowed to reduce the specific volume of injected acid per meter of oil saturation by 25% without compromising the efficiency of the treatment, what has key importance from the point of view of economic feasibility. Based on the results of the performed pilot operations, nitrogen-foam acid treatments were included in the regular program of wells stimulation.
- North America > United States (0.94)
- Asia (0.69)
- Europe > Russia > Volga Federal District > Orenburg Oblast (0.29)
- Europe > Russia > Volga Federal District > Samara Oblast (0.28)
- Europe > Russia > Volga Federal District > Samara Oblast > Volga Urals Basin > Kuleshovskoye Field (0.99)
- Europe > Russia > Volga Federal District > Orenburg Oblast > Precaspian Basin > Orenburg Field (0.99)
- Europe > Russia > Volga Federal District > Samara Oblast > Volga Urals Basin > Zhigulev-Orenburg Arch > Dmitriyevskoye Field (0.96)
New Opportunities for Brownfields: Channel Fracturing Offers a Significant Increase of Well Productivity in Complex Geological Conditions in the Samara Region
Letichevskiy, Alexander (JSC-Samaraneftegaz Rosneft) | Nikitin, Alexey (JSC-Samaraneftegaz Rosneft) | Parfenov, Alexey (JSC-Samaraneftegaz Rosneft) | Makarenko, Vitaliy (JSC-Samaraneftegaz Rosneft) | Lavrov, Ilya (JSC-Samaraneftegaz Rosneft) | Rukan, Gleb (Schlumberger) | Yudin, Alexey (Schlumberger) | Ovsyannikov, Dmitry (Schlumberger) | Nuriakhmetov, Ruslan (Schlumberger) | Gromovenko, Alexander (Schlumberger)
Abstract A characteristic feature of oil fields in the Samara region which main oil reserves are concentrated in terrigenous formations is considered to be a high level of exploration and depletion. One of the main challenges the solution of which will allow to maintain the current level of production is the systematic application of modern technologies for the oil inflow stimulation of small and hard-to-reach reservoirs with unfavorable geological and physical conditions. Under these circumstances the classical fracturing method with regular proppant injection has no the proper effect, what forces the oil producing companies to recourse to more efficient technologies. Gradually deteriorating geological conditions limit both the size of the proppant pumped and the tonnage of the whole hydraulic fracturing operation, not allowing to achieve the optimal "formation-well" connection. To optimize the fields development process in 2015-2016 four pilot operations were performed with a new technology for the region - the cluster fracturing. When it is performed, the proppant is being pumped with "pulses" alternating with self-dissolving fibers, thus achieving a highly conductive fracture structure that removes the restrictions for hydrocarbons inflow occurring during conventional fracturing. The development objects, treated with channel hydraulic fracturing, were sandstones of the Devonian system (D1, D3, Dk) of the Kuleshovskoye oil field, which was discovered as far back as 1959 and being the second largest in the Samara region. These formations are characterized by low reservoir properties and located at a much greater depth in comparison with the main oil reservoirs. The obtained results showed that the wells after the cluster fracturing demonstrated a productivity coefficient higher by 47%, the oil production rate increased by 1.56 times as compared to the wells with the conventional fracturing. Good production results were obtained due to the pad stage percent decreasing, a reduction of the fluid volume (when converted to the equivalent mass of standard fracturing), and the use of higher proppant concentrations.
- Europe > Russia > Volga Federal District > Samara Oblast > Volga Urals Basin > Kuleshovskoye Field (0.99)
- Europe > Russia > Volga Federal District > Orenburg Oblast > Volga Urals Basin > Tsarichanskoye Field (0.99)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Central Basin > Taylakovskoye Field (0.99)
- Europe > Russia > Volga Federal District > Samara Oblast > Volga Urals Basin > Zhigulev-Orenburg Arch > Dmitriyevskoye Field (0.97)
Proppant Flow Back Control for Fracturing Low Temperature Formations of Russia Methodology and Case Studies
Letichevskiy, Alexander (Rosneft Samaraneftegaz) | Parfenov, Alexey (Rosneft Samaraneftegaz) | Belyakova, Lyudmila (Schlumberger) | Konchenko, Andrey (Schlumberger) | Borisenko, Alexey (Schlumberger) | Parkhonyuk, Sergey (Schlumberger) | Olennikova, Olesya (Schlumberger) | Klyubin, Artem (Schlumberger)
Abstract Formations with a bottomhole static temperature below 70 degC are very common for quite a number of Russian oil provences such as Komi, Samara Area, Orenburg, Tatarstan Bashkiria, and Eastern Siberia. Many of these formations are now being developed with proppant fracturing which incorporates a lot of flow back issues due to the various reasons including high viscosity oil, aggressive TSO designs and cycle loads on a proppant pack due to ESP change regime. There are a number of solutions to prevent proppant flow back and the most common one is usage of resin- coated proppants. At temperatures below 70degC RCP needs chemical activation in order to achieve a solid proppant pack consolidation. Depending on temperature range and coating structure various types of activators can be used. Traditionally commercial activators were used at very high concentrations that may compromise proppant pack conductivity and performance fracturing fluid. Alternative techniques are based on using fiber technologies and unconventionally shaped proppants. The majority of flowback control techniques have been tested in Volga-Urals region of Russia, Orenburg, Samara and Bashkiria areas. Novel additives that accelerate curing, RCP was successfully implemented and pumped during hydraulic fracturing on the most oil fields of Samara area. Flow back problems were observed only at extremely low temperature reservoir (<30 degrees Celcius) with high- viscous (∼100+ cP) oil. Paper uncovers the details of activation process with detailed laboratory investigation for several RCPs and activators, proposes decision matrix for low temperature flow back control techniques, its applicability and design.
- Europe > Russia > Volga Federal District > Orenburg Oblast > Orenburg (0.45)
- Europe > Russia > Volga Federal District > Republic of Tatarstan (0.24)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.46)
- Europe > Russia > Volga Federal District > Volga Urals Basin (0.99)
- Europe > Russia > Northwestern Federal District > Volga Urals Basin (0.99)
- Asia > Middle East > Iraq > Salah al-Din Governorate > Samara Field > Zubair Formation (0.97)
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