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Results
Development of Microbial Enhanced Oil Recovery Technology for Carbonate Formations: Stage 1
Khisametdinov, Marat (NTC Tatneft) | Sokolova, Diyana (NTC Tatneft) | Fedorov, Alexey (NTC Tatneft) | Khisamov, Rais S. (Tatneft) | Ibragimov, Nail G. (Tatneft) | Nazina, Tamara (Vinogradsky Institute of Microbiology) | Babich, Tamara (Vinogradsky Institute of Microbiology)
Abstract Initial stage of development of microbial enhanced oil recovery technology for carbonate petroleum reservoirs is presented. OAO TATNEFT has been successfully employing microbial technology in terrigenous formations for a long time. Results of carbonate reservoir characterization and microbial community analysis show prospectivity of microbial technology development for carbonate reservoirs as well. It has been found that microorganisms isolated from formation water can produce metabolites with high oil displacing potential when growing on carbohydrates. The main features of microbial method under development are formulated.
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.31)
Injection Test of Carbonate Reservoir with Complex Porosity Types Including Porous Matrix, Fractures, Vuggy Zones
Abdullin, R.. (LLC RN-UfaNIPIneft) | Davletbaev, A.. (LLC RN-UfaNIPIneft) | Bikbulatova, G.. (LLC RN-UfaNIPIneft) | Ignatev, A.. (LLC RN-Severnaya neft) | Yamalov, I.. (Rosneft Oil Company)
Summary Water flooding of carbonate reservoirs with complex porosity, fracture system and high vugginess is complicated by water breakthrough and quick waterflooding of the producers. At that, reservoir pressure maintenance is essential means as due to reduced reservoir energy state resulting from formation and bottom hole pressure decrease at elasto-plastic drive, well production rate decreases. Analyses of well test study show that pressure drop fracture healing takes place and leads to production loss of the producers. High vertical permeability leads to technogenic formation of gas caps at reservoir pressure drawdown below bubble point pressure and to necessity of shutting off some producers drilled under the field arch. To reduce water flooding in producers and involve non-draining uninvaded areas to injection high-elastic solutions are injected. This helps to distribute the fluid injected to uninvaded intervals. As a rule, fracture system and secondary porosity are less developed in these intervals. For that reason the reservoir are of less permeability. Liduid injection to the wells is carried out at high pressures. According to transient well test results which were undertaken before and after injection of high-elastic solutions large โ spontaneous growth of vertical fracture in injection wells are observed. Thus, according to log-log plot after the undertakings logarithmic derivative view (flow pattern for single vertical fractures) is fundamentally changed. Field research results show that after the injection of high-elastic solutions and further injection at high pressure rates in reservoirs with bad flow properties artificial hydrofracs are forming which helps to involve earlier non-draining intervals.
- Europe (0.71)
- North America > United States > Texas > Matagorda County (0.24)
Abstract This article is devoted to carrying out and interpreting well tests that reveal carbonate reservoirs with a developed system of conducting macrofractures. Relevance of the issue is due to not only the increase the number of such reservoirs in the structure of hydrocarbon reserves, but generally by domestic companiesโ low experience in production from such reservoirs. It was found out that in the presence of rare and extended natural fractures the traditional model of ยซdual porosityยป is ineffective. The authors studied more complex numerical model, which assumes the existence of a few fractures of different length in the formation as well as fracture systems that are uniformly distributed in reservoir. The cases where the well was at different distances from the fractures or penetrate fracture system were also considered. The numerical model parameters were adjusted to the results of core analysis, geophysical studies, logging and the history of the wells production history. The simulation results revealed that the hypothesis of fractured block structure of carbonate reservoirs correlates well with the results of well tests. The technique of determining the parameters of the fracture system according to the well test is validated. The distance to the nearest fractures and the average size of blocks are determined. It is shown that by the well tests in several wells the direction of extended natural fractures can be determined. This gives an indication of the spatial orientation of fractures and their areal distribution. The obtained results allow to approach the development of new carbonate deposits more rationally, to plan future wells spacing reasonably, to predict well rates and production profile, to consider the consequences of the well interference by the main fractures.
- North America > United States > Arkansas > Smart Field (0.99)
- Europe > Russia > Volga Federal District > Orenburg Oblast > Precaspian Basin > Orenburg Field (0.99)
- Asia > Russia > West Siberian Basin > Bazhenov Formation (0.99)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Central Basin > Priobskoye (Northern Part) Field (0.99)
Abstract Research and development in the area of complex trajectory well drilling technologies, including combined with hydraulic fracturing treatment, is one of the first priorities for national and international oil producers, OAO TATNEFT is no exception. As of 1 January, 2014, in TATNEFT oil fields, 587 horizontal wells and 104 multilateral wells have been drilled, including 421 horizontal wells and 83 multilateral wells drilled in carbonate reservoirs. On the average, initial oil production rates of horizontal and multilateral wells are higher vs. vertical wells, 1.8 times and 2.4 times, respectively. The worst production parameters are characteristic of horizontal and multilateral wells, 77 and 32 wells, respectively, draining the Bashkirian-Serpukhovian formations, which testifies to poor efficiency of horizontal technologies in this type of reservoirs. Of the total number of wells targeting carbonate formations, 11 multilateral and 15 horizontal completions showed good well performance. The paper presents a number of technologies aimed at improved carbonate reservoir performance through complex trajectory wells. Optimization of development of the carbonate reservoirs in the Pionerskoye, Novo-Elkhovskoye, and Shegurchinskoye fields will allow reducing vertical drilling metreage, thus, saving on well construction and infrastructure cost. It will also result in improved reservoir flow behavior, connectivity, and enhanced oil production. It is deemed that oil production of complex trajectory wells will increase 1.5-fold vs. vertical wells. The offered horizontal technologies will help to achieve uniform oil drainage of heterogeneous formations with different reservoir properties and, increase water-free production of wells through use of expandable well completion systems involving packers and ICVs or water-swellable packers. Calculation made in reservoir models show ultimate oil recovery increase by 8-15%. The Company is planning to commercialize the technologies in the nearest future.
- Phanerozoic > Paleozoic > Carboniferous > Pennsylvanian (0.50)
- Phanerozoic > Paleozoic > Carboniferous > Mississippian (0.35)
Theory and Practice of Acidizing High Temperature Carbonate Reservoirs of R. Trebs Oil Field, Timan-Pechora Basin
Folomeev, A. E. (LLC BashNIPIneft) | Sharifullin, A. R. (LLC BashNIPIneft) | Vakhrushev, S. A. (LLC BashNIPIneft) | Murinov, K. Yu. (LLC BashNIPIneft) | Akimkin, A. V. (JSOC Bashneft) | Lenchenkova, L. E. (Ufa State Petroleum Technological University) | Nabiullin, R. M. (LLC Bashneft-Polus) | Federov, A. I. (LLC Bashneft-Polus)
The oil reservoirs of R. Trebs field are predominately heterogeneous carbonates with a well developed network of natural fractures, high formation temperature and high concentration of resins and asphaltenes in the produced crude. Such complicated reservoir conditions entail integrated acid treatment engineering and design to include physical and chemical analysis of acid compositions, formation fluids and reservoir rock; physical simulation of acidizing on core from target intervals and numerical modeling of the optimum acid job design. The conducted research supported the selection of the optimum acids for the geological and engineering conditions of R.Trebs oil field to secure better compatibility with the formation fluids from the target intervals, lower corrosion activity and retarded reaction rate. The findings also identified the range of critical values for permeability and mineralogy of the rock whereby acid flows through a reservoir rock in a growing dominant wormhole. Based on the literature survey a semi-empirical model was chosen which describes the growth of a wormhole. The model was calibrated against the actual reservoir conditions of R.Trebs field using flow test results and reaction kinetics studies on the rock samples from the given pay zones. The integrated approach introduced for acid job design can be applied to achieve the following: - select application or usability criteria of an acid job for a given field; - select optimum acids to secure minimum risks of primary and secondary formation damage and optimum reaction rate; - implement engineering optimization of acid job design by the identification of its most efficient parameters; - forecast post-acid production and other field performance indicators. 2 SPE-171242-MS
- Europe > Russia > Northwestern Federal District > Nenets Autonomous Okrug (1.00)
- Europe > Russia > Northwestern Federal District > Komi Republic (1.00)
- Geology > Geological Subdiscipline (0.86)
- Geology > Mineral > Silicate > Phyllosilicate (0.46)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.30)
Abstract This paper presents the results of research programs performed by OAO TATNEFT aimed at additions to reserves and increased production from non-conventional reservoirs found in Tatarstan. It is worth mentioning that TATNEFT has been studying non-conventional reservoirs since 1950s. To date, most of Tatarstan's oil fields have entered their closing stage of development with 86% cumulative production of OOIP and increase of hard-to-recover reserves share from 33% to 80%. A considerable part (36%) of TATNEFT hard-to-recover reserves falls on carbonate low-permeability sediments with low-thickness fractured reservoirs. Aiming at study of shale, or tight, oil in the territory of Tatarstan, TATNEFT has concentrated its efforts on the search for oil accumulations and study of low-permeability reservoirs and source rocks in the Tournaisian-Sargaevian formations. Prospecting of nonconventional hydrocarbon reserves and nonconventional reservoir study is a challenging, still, a very promising line of activity associated that can add value and yield good returns, considering that the Tournaisian-Sargaevian formations are widespread in Tatarstan, the domanikites are source rocks with high organic matter content, and proved oil potential of these deposits. A certain tight oil potential is also associated with the Samara, Ulyanovsk, Orenburg, Nenets Autonomous District, and Kalmykia leases. It is worth mentioning that evaluation of shale plays is not based on conventional methods involving seismic survey, logging etc., but rather on analysis of chemical-mineralogical and mechanical rock properties. Analysis of available well data has been performed; underway are large-scale core recovery projects, including oriented core and quick capture. Considering geologic environment of the domanikites and the domanikoids in the Volga-Ural oil-and-gas province, petrophysical properties of these rocks, fluid composition and properties, G&G information is analyzed to design hydraulic fracturing treatment in wells targeting the domanikites and the domanikoids. Candidates for hydrofrac jobs have been selected. Dedicated drilling and reservoir management technologies are developed.
- Europe > Russia > Volga Federal District > Republic of Tatarstan (1.00)
- Europe > Russia > Volga Federal District > Ulyanovsk Oblast > Ulyanovsk (0.25)
- Europe > Russia > Volga Federal District > Orenburg Oblast > Orenburg (0.25)
- Phanerozoic > Paleozoic > Devonian > Upper Devonian (0.69)
- Phanerozoic > Paleozoic > Carboniferous > Mississippian > Lower Mississippian > Tournaisian (0.56)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.73)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.52)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Marcellus Shale Formation (0.99)
- (7 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- (2 more...)