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Results
Gas factor control of the Yurubcheno-Tokhomskoye gas and oilfield based on pressure and temperature measurements by permanent downhole gauges (Russian)
Fatikhov, S. Z. (Bashneft-PETROTEST LLC) | Fedorov, V. N. (Bashneft-PETROTEST LLC) | Izmailova, G. R. (Oktyabrsky Branch of Ufa State Petroleum Technological University) | Kashapov, V. F. (Vostsibneftegas JSC) | Markov, M. A. (Vostsibneftegas JSC) | Popov, A. V. (Vostsibneftegas JSC)
Over the past 20 years, many results of scientific research have been published aimed at studying thermohydrodynamic effects in producing and injection wells in steady and unsteady filtration modes. These works present the technological features of performing thermohydrodynamic well tests and the methodological basis for processing the results of field studies, which reduce uncertainty in determining the filtration properties of the reservoir and productive parameters of wells, including wells with a complex architecture of shanks. However, the information potential of permanent downhole gauges (PDG) is not limited only to the study of these parameters but allows monitoring of such physical and technological parameters of the oil recovery and production process that are not directly measured by PDG. In particular, when monitoring the development of complex oil fields with contact gas reserves and underlying water, it is important to measure not so much the downhole pressure as to determine its optimal value, preventing the formation of gas and water cones. Obviously, the pressure parameter alone does not provide a solution to this problem. It is necessary to control the integral parameter such as gas factor for determining the required downhole pressure value. The article considers an algorithm for field development control by an indirect parameter - the gas factor, the value of which is calculated on the basis of measured physical and technological quantities such as pressure, temperature and their change over time. The relevance of this approach results from the complexity of instrumental measurement of GF in field conditions associated with the gas separation pressure above atmospheric pressure and the lack of measurement tools for gas flows with droplet liquid.
The PDF file of this paper is in Russian. The development of multi-layer objects by a single filter leads to the impossibility of regulating the created depression on each layer independently of each other, which necessitates the use of special methods for monitoring energy, production and filtration properties. One of such methods is the use of permanent downhole gauges (PDG), which measure parameters such as pressure, temperature, flow, moisture content in front of each stratum with a string of complex geophysical instruments. High values of water cut and differentiation of reservoir pressures of a multi-layer development facility, which is a characteristic feature of the middle and late stages of development of the Republic of Bashkortostan, lead to a distortion of the recorded parameters. Therefore, special well tests are required to control reservoir pressure, productivity and reservoir development. To determine the individual values of reservoir pressure and the reservoir productivity index of a multi-layered object, an analysis was performed using methods proposed by a number of authors in the middle of the 20th century. To refine the composition of the inflow, a method based on the Joule โ Thomson effect is proposed. Similar to the analysis of steady-state studies using an indicator diagram, the Joule โ Thomson coefficient was determined from the pressure-temperature plot, constructed from the points obtained when stabilizing the bottomhole pressure and temperature at several steady-state regimes. Application of thermo-hydrodynamic methods of well tests allowed to determine individual values of reservoir pressure, productivity index, hydroconductivity, permeability and skin factor of each of the investigated layers of a multi-layered object.
A comprehensive analysis of bottomhole pressure and productivity measurements of the multilayer object in wells equipped with permanent downhole gauge systems (Russian)
Gimaev, A. F. (BashNIPIneft LLC, RF, Ufa) | Fatikhov, S. Z. (BashNIPIneft LLC, RF, Ufa) | Fedorov, V. N. (Ufa State Petroleum Technological University, RF, Ufa) | Malov, A. G. (Bashneft-Dobycha LLC, RF, Ufa)
The PDF file of this paper is in Russian. In fields with a large number of oil-saturated layers it is not uncommon to combine several layers into a single object of development. In most cases, they are developed by a single filter, it is leads to the need for special methods to control energy, productive and filtration parameters of multilayer objects. On the example of the use of permanent downhole gauge systems hardware and software complex SPRUT at the fields of the Republic of Bashkortostan the features of control of energy and filtration properties of multilayer objects by a single filter are considered. The method inflow performance relationship is used to estimate reservoir pressures and coefficients of productivity of each object. It is shown that to control the change in reservoir pressure build-up test method should be supplemented with information on the productivity index of each formation and the magnitude of the steady flow between the layers. In the absence of special studies, reservoir productivity indexes can be obtained only using inflow performance relationship. And reliable information about the flow is available only on the flow meter sensor, i.e. the conditions for the reliability of flow measurements for mechanical flow meters must be fulfilled. It is shown that at different reservoir pressures, the cessation of production from the well will correspond to the well test by the method of pressure stabilization curve (productivity analysis). Therefore, to determine the filtration properties of layers in the interpretation of such well tests, the values of reservoir pressures and the flow between the layers are the input parameters. On the real example of such well test two approaches of data interpretation are demonstrated: the first one, in case of availability of reliable data on the amount of flow and formation pressures using the method of pressure stabilization curve; the second โ in the absence of these data using modeling. The article also specifies the limitations and conditions of permanent downhole gauge systems of multi-layer objects by a single filter, and offers recommendations for increasing the information content of such systems.
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Well performance, inflow performance (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
Justification of key wells network for controlling formation pressure dynamics at R. Trebs oil field (Russian)
Nabiullin, R. M. (Bashneft-Polus LLC, RF, Ufa) | Gizatullin, D. R. (Bashneft-Polus LLC, RF, Ufa) | Fedorov, V. N. (Ufa State Petroleum Technological University, RF, Ufa) | Salimgareeva, E. M. (Ufa SciTechCenter LLC, RF, Ufa) | Akberova, A. Sh. (BashNIPIneft LLC, RF, Ufa)
The PDF file of this paper is in Russian. The article considers the principles of key well network development at R.Trebsa oil field for controlling the reservoir pressure profile, which is characterized by of filtration and productive properties heterogeneity. For that type of reservoirs development of key well network faces a problem caused by lateral heterogeneity and block structure of reservoir. Actual-to-date regulatory documents and procedures, which are dedicated to well tests, don't take into account aspects mentioned above. It is shown that these failures lead to loss of information and unability of effective reservoir development. The authors propose an algorithm of key well network development taking into account lateral heterogeneity. One of the principles is based on the identification of hydrodynamically connected parts of oil reservoir on the basis of reservoir pressure profile and field data. It is shown that in case of intensive reservoir pressure decline the frequency of pressure measurement is crucial. Proposed frequency of well tests (once a year quarter) within one hydrodynamically connected zone showed its effectiveness in monitoring the oil reservoir development, in particular, when determining the effect of reservoir pressure maintenance and fault's conductivity. The article presents calculations of minimum required number of key wells based on heterogeneity coefficient. The recommended number of well tests in order to determine current reservoir pressure is 25% of producing well stock. A block diagram of the algorithm for development of key well network is given taking into consideration the input of new wells.
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
The PDF file of this paper is in Russian. Development of oilfields characterized by low permeability and porosity, and a low rate of fluid filtration in the reservoir results in an increase in the well test duration (over 1000 hours) to determine reservoir pressure, productivity index and hydraulic conductivity of the layer. In such cases, there is the problem of providing the necessary comprehensive exploration while minimizing losses of oil production. The authors considered model examples of well tests of reservoirs of low-permeability, lateral heterogeneity and for different boundary conditions. Simulation of the lateral inhomogeneous layer showed that for the formation pressure control under the reservoir development it is sufficient to define the reservoir pressure at the boundary of the change of filtration properties. Analysis of simulation results revealed that the Horner method has higher accuracy in the case of homogeneous infinite reservoir. In the case of laterally inhomogeneous layer, the presence of impermeable boundaries or limits of the constant pressure differential method allows to estimate the formation pressure with minimal error and with less duration build up. Obtained in the course of numerical experiments the results are recommended to be used for the rapid assessment of the duration of the build up at the research planning stage and in monitoring the recovery process the bottom-hole pressure in real-time to predict the duration of the stop producing well.
The PDF file of this paper is in Russian. The aim of the work was the solution to the problem of evaluating the representativeness of core network of wells for field monitoring of gas factor with predetermined maximum allowable error of measurement. The question of the justification of the minimum required number of wells for core network is associated with the fact that a number of objective reasons do not allow monitoring gas-oil ratio in all wells. The proposed approach to the evaluating the representativeness of core network is based on statistical methods that can be applied to solve other control problems of field development, for example, the monitoring reservoir pressure profile, because it is general in nature. We considered the evaluation of the representativeness of core network for measurement of the gas-oil ratio on the example of one of the fields in the western part of the Republic of Bashkortostan. For this field, it is shown that the core network of wells should be at least 70% of the all producing wells on the examined object of development. It is noted that the value of the coverage of the core network of wells 70% applies to this particular case. At lower magnitude of the range of gas factor values for individual wells minimum required core network of wells can be much smaller.
The pdf file of this paper is in Russian. Based on the field research of Arlanskoye field it is shown that current gas factors of the main development objects are less than initial reservoir gas-oil ratios. With reference to the field and laboratory investigations of other authors, we adduced the main causes of gas factor loss in process of Arlanskoye field development. The main causes of gas factor loss at Arlanskoye field are the maintenance of production wells with bottomhole pressure below the bubble-point pressure and move some of gas oil component to download and bottom water at their contact. For example, total producing water oil ratio of the one development object amounts to 9.1 t/t. Today we cannot definitely say which of the above reasons have the most value in the process of reducing the reservoir gasoil ratio. The systematic monitoring of the gas factor on the basis of instrumental measurements in wells throughout the period of Arlanskoye field development was not made. Therefore, we don't know in time gasoil ratio dynamics. Also, we note that it necessary to conduct the control of the gas factor on the core network of wells for indirect estimation of current oil reservoir gas content, as on date, the Arlanskoye field has no conditions for the selection of representative samples of deep oil. The reasons for the lack of conditions for the selection of deep oil samples are high water cut wells production, operation of wells with bottomhole pressure below the bubble point pressure.
Determination of reservoir filtration system model of R. Trebs field using dynamic well tests (Russian)
Fedorov, A. I. (Bashneft-Polus LLC, RF, Ufa) | Nabiullin, R. M. (Bashneft-Polus LLC, RF, Ufa) | Fedorov, V. N. (BashNIPIneft LLC, RF, Ufa) | Salimgareeva, E. M. (BashNIPIneft LLC, RF, Ufa) | Akberova, A. Sh. (BashNIPIneft LLC, RF, Ufa)
The pdf file of this paper is in Russian. The paper presents features in determination of reservoir filtration system model of carbonate oil fields using dynamic well tests analysis. It is shown that pressure build-up is characterized by long-term wellbore storage covering over informative part of log-log plot. Authors suggest using drillstem test results to determine filtration model, for R.Trebs field it has determined as dual porosity model. Based on the drillstem test analysis storativity ratio and interporosity ratio for the Lower Devonian Ovinparma formation (D1op1) were calculated. Drillstem tests showed high informativity for reservoir filtration system model determination.
- Europe > Russia > Northwestern Federal District > Nenets Autonomous Okrug (0.71)
- North America > United States (0.70)
The pdf file of this paper is in Russian. The article presents the results of experimental field research of permanent downhole gauges (PDG) system SPRUT at Mancharovskoe oilfield. The analysis of well test is conducted. The advantages of using the PDG system in the field development control are presented.