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Results
Application of Open Hole Gravel Pack OHGP among the Technical Solutions for Successful Drilling and Completion of Horizontal Wells, North-Komsomolskoye Field, PK1 Formation
Salyaev, Vadim V. (Rosneft) | Sitdikov, Suleyman S. (Rosneft) | Nuykin, Andrey M. (Rosneft) | Arzamastsev, Georgiy G. (Rosneft) | Pilgun, Pavel S. (Rosneft) | Safin, Ayrat F. (Rosneft) | Gashimov, Roman R. (Rosneft) | Susoev, Anton S. (Rosneft) | Gruzdov, Dmitry (Schlumberger) | Gromovenko, Alexander (Schlumberger) | Kapkaev, Alexander (Schlumberger) | Rezanov, Ivan (Schlumberger)
Abstract Well completion using technology enabling to improve performance and life time is an important objective in the development of PK1 productive reservoir of North Komsomolskoye field. The main challenge of the development of this productive horizon lies in the fact that the reservoir is shallow (1,120 m TVD) and consist of poorly consolidated sandstone, which results in massive production of solids during operation. In addition to that, proximity of GOC and WOC together with high oil viscosity in reservoir conditions results in early gas and water breakthroughs when using standard completion technology. Basic PK1 formation characteristics could be found in Table 1. Remote location of the field and impossibility to use all-year-round road transport of materials, equipment and personnel are additional operating problems which had to be resolved to ensure that the project is delivered successfully and without extra costs. Main questions which the project team had to deal with: What is the long-term solution to limit solids production at target drawdown to a level that would be safe for pumps and surface facilities? How to prevent early water and gas breakthroughs? How to drill a long horizontal section in poorly consolidate rock without any incidents knowing that previously several wells were lost in this zone due to well caving during drilling? To tackle these problems, we chose a completion technology for the open horizontal section using screens equipped with autonomous inflow control devices (AICD) and inflow tracers. To ensure sand control, we injected gravel packing in the annular space between the screens and the open well bore. In addition to that, we built a 1D rock mechanic model to calculate well bore stability. During the project execution we drilled 2 long horizontal sections without any incidents; tested completion technology with gravel packing (well A) and without gravel packing (well B); obtained the planned oil inflows; confirmed that the approaches adopted can be successfully used in the Full Field Development. Given all the particular features of the field and the well design, this operation can be rightly considered one of the most complex onshore operations that have been performed in the Russian Federation.
Advanced Technologies of Acid Fracturing - a Great Advantage in the Development of Carbonate Reservoirs of the Timan-Pechora Region
Ponomarenko, Denis (Rusvietpetro) | Kubrak, Mikhail (Rusvietpetro) | Karimov, Albert (Zarubezhneft) | Rukan, Gleb (Schlumberger) | Konchenko, Andrey (Schlumberger) | Nuriakhmetov, Ruslan (Schlumberger) | Gromovenko, Alexander (Schlumberger)
Abstract About 70% of the reserves of the Timan-Pechora oil province are classified as hard-to-recovery. Most of the production comes from large reservoirs during the late stage of development, which makes us look for reliable methods to increase production while reducing capital expenditures. Traditionally carbonate reservoir acidizing is considered to be an effective method to increase oil recovery. However, this is not always true for the Devonian carbonate formations of Timan-Pechora region. In conditions of low reservoir temperature (60-70 C), dissection cut, high tectonic stress and the tendency to water cut increasing classic acidizing and acid fracturing are ineffective without the use of advanced technologies. Acid Fracturing has been selected by JC RUSVIETPETRO as a basic method for the pilot stimulation campaign in 2015. 15% HCl was used as the main fluid for reservoir with a temperature of 65C. Heavy oil tendency to deposit paraffins and create sludge promoted the use of an acid emulsion with the solvent. Low permeability and dismembered reservoir structure required formations merging into a single system of fractures and leveling inflow profile. Viscoelastic surfactant was applied to this end, having the properties of both the classic diverter in matrix acidizing and as a "buffer stage" for acid fracturing, helping to increase the fracture half-length. Also in 2016 in addition to the described systems, fiber diverter was applied for acid fracturing the first time in Russia in the fields of the Timan-Pechora. It allows to achieve even greater results in stimulation by natural fractures plugging in reservoir and redirecting acid fractures flows. The oil fields are located in the Nenets Autonomous District, which automatically imposes a large number of restrictions on the methods of stimulation because of complex logistics and low temperatures. In 2015 winter season, when winter roads were availble from February to April, the first stimulation campaign was performed. Most of the wells produce from two clusters of Famennian stage at a depth of 3200 m. The main inflow of the hydrocarbons comes from the lower, more permeable interval, while the top remains untapped. Thus, after water cut increasing of the lower cluster, wells keep sufficient production capacity at the top cluster if stimulated by selective acid fracturing. Hydraulic acid fracturing was performed after mechanical isolation of the lower cluster and with application of new modern technologies, which increased the productivity of wells on average 4.3 times, with an average increase in production by 20.4 tonnes of oil/day. Taking into account the results of the first stimulation campaign in 2016 stimulation jobs continued with using of fiber diverter, the uniqueness of which is the ability to temporarily block fractures and redirect their development in heterogeneous reservoir. Whereby a multi-fractures structure is created and increases the contact area of the fracture and the formation, and as a result the efficiency of acid fracturing increases. According to the results of the second winter stimulation project the average increase of production rate was 21.9 tons/day/well.
- Geology > Structural Geology > Tectonics (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock (0.93)