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Collaborating Authors
SPE Russian Petroleum Technology Conference
Comprehensive Approach to Optimization of Macrooperations in Oil and Gas Production Based on Integrated Planning
Ermolovich, Igor Mikhailovich (NV-ASUproject) | Shamkov, Alexander Viktorovich (NV-ASUproject) | Seleznev, Igor Viktorovich (NV-ASUproject) | Yelin, Nikolay Nikolayevich (NV-ASUproject) | Duryagin, Andrey Vladimirovich (NV-ASUproject)
Abstract The task of integrated planning, as one of the main tools to improve the operational efficiency of production activities of oil and gas production operators, is the most relevant. Due to the high intensity, today all operators emphasize the importance of automating the integrated planning process. An integrated plan means combining, ranking and possible combination, as well as timely updating the order of implementation of activities presented in separate functional plans, for which various services are responsible. At the same time, a functional plan is a group of activities united in its specificity. Examples of functional plans are well intervention (TR), well workover (KR), PP (routine maintenance), Research, OTM (organizational -technical measures), PPR (scheduled preventive work), VNS (commissioning of new wells). The goal of integrated planning is to execute the mining company's business plan in the most efficient way in terms of economic performance within the existing constraints. The constraints can be various aspects, such as the limited number of crews of the required specialization and special equipment for the activities, the need to move resources to the location of the activity taking into account the seasonality and types of transport, a strict sequence of operations within one activity, technological constraints associated with the inability to simultaneously conduct various activities at one cluster site, restrictions on the utilization of associated petroleum gas. Integrated planning distinguishes between planning horizons. As a rule, the horizon does not exceed one year and is designed to assess the feasibility of the company's business plan and justify capital and operating costs. Annual planning must take into account both targeted (named, assigned to a specific well or field site) and unaddressed (called "virtual") activities based on past year statistics. Monthly and 90-day plans are updated on a monthly basis and are more detailed and accurate than the annual plan, containing only targeted activities. Monthly planning clarifies the feasibility of the business plan in terms of production, budget and other criteria. In addition to the approved annual, monthly and 90-day plan, an operational (working) plan is formed, which is updated on a daily basis or upon request. As a rule, the operational plan is formed for a two-week planning horizon. The traditional integrated planning approach has its drawbacks and opportunities for improvement. The essence of the traditional approach of integrated planning is that different operational services, such as Geological Service, Well Intervention Service, Pipeline Maintenance Service, Chief Power Engineer, Chief Engineer, etc., annually and monthly submit a list of activities for inclusion in the annual, monthly (90-day) production program, after which the integrated planner combines all activities, combining them if possible, trying to achieve the targets as closely as possible, such as The main drawbacks of the traditional approach are the high intensity of forming an integrated plan, as well as its static nature. In fact, the approved integrated plan is actual no more than two days, as the life of oil and gas field is usually very dynamic - there are always unscheduled activities, there are always emergencies during crews, shifts in the start and end dates of already started crews, etc. All of the above aspects indicate that the integrated plan must be dynamic and must be constantly updated (Repin et al., 2018). The OIS UFAM integrated scheduling solution presented in this article provides extensive automation capabilities for the integrated scheduling process.
Abstract This work presents the approaches used for the optimal placement and determination of parameters of hydraulic fractures in horizontal and multilateral wells in a low-permeability reservoir using various methods, including 3D modeling. The results of the production rate of a multilateral dualwellbore well are analyzed after the actual hydraulic fracturing performed on the basis of calculations. The advantages and disadvantages of modeling methods are evaluated, recommendations are given to improve the reliability of calculations for models with hydraulic fracturing (HF)/ multistage hydraulic fracturing (MHF).
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > P’nyang Field (0.97)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Elk-Antelope Field (0.97)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Angore Field (0.97)
- (9 more...)
The Choice of the Optimal Strategy for the Use of Solvents of High-Molecular Organic Deposits, Considering their Complex Composition and the Effect on the Oil Dispersion System
Guskova, Irina Alekseevna (Almetyevsk State Oil Institutes) | Khayarova, Dinara Rafaelevna (Almetyevsk State Oil Institutes) | Abzyapparova, Elvira Rafaelevna (Almetyevsk State Oil Institutes)
Abstract The long-term practice of operating wells producing oil rich in paraffins and asphaltenes has shown that the optimization of technologies for the removal of solid high-molecular organic deposits (asphaltene-resin-paraffin deposits) in oilfield equipment, lifting pipes and flow lines makes it possible to effectively solve the issues of improving the environmental friendliness and energy efficiency of oil production. The use of composite hydrocarbon solvents is one of the most well-known methods used to remove asphaltene-resin-paraffin deposits. Thus, to date, there is no systemic solution to this issue. This paper is aimed at discussing the provisions that determine the possible prospects for the development of an optimal strategy for the use of solvents for the removal of asphaltene-resin-paraffin deposits.
- Europe > Russia (0.46)
- North America > United States > Texas (0.28)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Inhibition and remediation of hydrates, scale, paraffin / wax and asphaltene (1.00)
- Facilities Design, Construction and Operation > Flow Assurance > Precipitates (paraffin, asphaltenes, etc.) (1.00)
Efficiency of Using a Proxy Model for Modeling of Reservoir Pressure
Yudin, Evgeniy Viktorovich (LLC, Gazpromneft STC) | Markov, Nikolay Sergeevich (Peter the Great St.Petersburg Polytechnic University SPbPU) | Kotezhekov, Viktor Sergeevich (LLC, Gazpromneft STC) | Kraeva, Svetlana Olegovna (Peter the Great St.Petersburg Polytechnic University SPbPU) | Makhnov, Andrei Vasilyevich (Peter the Great St.Petersburg Polytechnic University SPbPU) | Trubnikov, Nikita Pavlovich (Peter the Great St.Petersburg Polytechnic University SPbPU) | Gorbushin, Leonid Arkadevich (Peter the Great St.Petersburg Polytechnic University SPbPU)
Abstract The presented paper is devoted to the development and testing of a computational tool for assessment of the reservoir pressure and prompt generation of the pressure maps of collectors. The tool is based on a proxy model that allows to solve the two-dimensional diffusion equation for unsteady liquid filtration using the boundary element method. To expand the applicability of the proxy model, an algorithm for automated parameter adaptation was developed. This algorithm allows to exclude knowingly unreliable data or low-quality data from modeling. This is achieved due to analyzing the correlation between the injection, production and bottom-hole pressures for the entire well stock over the history of the reservoir development. In addition, this paper describes an approach to modeling two-phase oil and gas filtration based on the use of pseudofunctions. This approach considers the influence of gas on the oil filtration process. The use of pseudofunctions allows us to linearize the diffusion equation for two-phase filtration and to solve it using the boundary element method in the same manner as for the case of oil filtration without gas. To demonstrate the results of the proxy model validation, examples of its use for generating the pore pressure maps for two real collectors are given. The average values of the reservoir pressure at the wells calculated using the proxy model are compared with the results of the corresponding well tests and with the traditional isobar maps. The analysis showed that the average deviation of the proxy model from the real reservoir pressures is less than 10%.
- Reservoir Description and Dynamics > Reservoir Characterization (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)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
Application of Integrated Asset Modeling Approaches for Reservoir Management of a Large Oil Field in Western Siberia
Koshkin, Timur Aleksandrovich (LUKOIL-West Siberia LLC) | Sayfutdinov, Azat Firdavisovich (LUKOIL-Engineering LLC) | Kukushkin, Viktor Aleksandrovich (PITC Geofizika LLC, Perm Engineering and Technical Centre) | Markov, Pavel Vladimirovich (PITC Geofizika LLC, Perm Engineering and Technical Centre)
Summary The article reviews the development and implementation of a digital twin for one of the large fields of LUKOIL-West Siberia LLC. The project team has developed an integrated asset model (IAM) of an oil field at a late stage of its development, which is used both for making managerial decisions and in the operational work of the engineering and technical service. The IAM includes simplified models of reservoirs, models of wells and gathering systems, as well as simplified models of plants. The resulting model can produce short-term assumptions regarding production levels (up to 1 year) and is highly sustainable, which is confirmed by the examples given in this article as to the application of IAM for various production tasks. The developed automated tools allow making prompt decisions to optimize well stock operation, as well as to reveal deviations in the process parameters of downhole pumping equipment and metering facilities. The use of IAM tools enable production functions to perform many application tasks related to forecasting well operation modes and evaluating the existing production capacities of the field. The cases presented in this paper serve as a good practice for application of the IM by assets in their activities and can be implemented for similar brownfields.
- North America > United States > Arkansas > Smart Field (0.99)
- Europe > Russia > Southern Federal District > Kalmykia > Caspian Sea > Middle Caspian Basin > Mangyshlak-Ustyurt Basin > Severny Licensed Area > Vladimir Filanovsky Field (0.99)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > P’nyang Field (0.97)
- (11 more...)
- Information Technology > Data Science (1.00)
- Information Technology > Modeling & Simulation (0.93)
Abstract An innovative technology for determining the water cut in well products (without preliminary separation into liquid and gas fractions) uses the results of electrical impedance measurements and its dependence on the alternating current frequency. Water cut meter's sensor includes measuring and current electrodes, between which there is a well's multiphase flow. Imaginary and real components of the impedance quantitatively describe the component composition of the studied oil and gas-water mixtures. In this process, machine learning methods and developed algorithms for features extraction are used. Depending on the type of emulsion, two independent sensors are used in the oil pipeline, one of which measures in a direct emulsion, the other in an inverse emulsion. Tests of the described water cut meter on flow loops in the Russian Federation and in the Netherlands, as well as studies of well flows in oil production facilities in the Russian Federation and the Kingdom of Saudi Arabia, have shown high measurement accuracy in the full range of water cut, with high gas content, as well as at high salinity and in a wide range of flow rates. To do so, modern methods of data classification based on neural networks and regression modeling implemented using machine learning are employed. It was found that the flow rates of liquid and gas do not affect the results of measuring the water cut due to the high frequency of the impedance measurements - up to 100 thousand measurements per second. Use of in-line multiphase water cut meter makes it possible to apply intelligent methods of processing field information and accumulate statistical data for each well, as a big data element for predicting and modeling in-situ processes. It will also allow to introduce promising production processes aimed at increasing oil production and monitoring the baseline indicators of the well. Novelty of the presented technology: Solution of the problem of high-speed determination of water cut in a multiphase flow without preliminary separation using impedance metering. Creation of mathematical models of multiphase flow and methods for determining the type of flow and the type of emulsion. Machine learning methods and neural networks employment for high-speed analysis of flow changes. Development, successful testing and implementation of an affordable multiphase water cut meter of our own design, which has no analogs in industrial applications.
- Europe > Russia (0.68)
- Asia > Russia (0.68)
- Asia > Middle East > Saudi Arabia (0.24)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Conformance improvement (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)
Comprehensive Analysis of the Geological and Geophysical Data in the Study of the Upper Miocene Turbidite Systems of the Nam Con Son Basin, Vietnam
Kurianova, Mariia (Branch Office of Gazprom International in Saint Petersburg) | Birkle, Ekaterina (Branch Office of Gazprom International in Saint Petersburg) | Egorkina, Tatiana (Branch Office of Gazprom International in Saint Petersburg) | Koltsov, Sergey (Branch Office of Gazprom International in Saint Petersburg)
Abstract The article considers the approaches to the G&G data interpretation used in the Branch Office of Gazprom International in Saint Petersburg (hereinafter referred to as "GPEPI") when studying the geology aspects of turbidite deposits. This approach is showcased on one of the Upper Miocene deposits of the Nam Con Son Basin in Vietnam, and a conclusion is drawn about the possibility of using this complex technique in the study of sand bodies of any genesis.
Abstract Recently, more and more reservoir flow models are being extended to integrated ones to consider the influence of the surface network on the field development. A serious numerical problem is the handling of constraints in the form of inequalities. It is especially difficult in combination with optimization and automatic control of well and surface equipment. Traditional numerical methods solve the problem iteratively, choosing the operation modes for network elements. Sometimes solution may violate constraints or not be an optimal. The paper proposes a new flexible and relatively efficient method that allows to reliably handle constraints. The idea is to work with entire set of all possible operation modes according to constraints and control capabilities. Let's call this set an operation modes domain (OMD). The problem is solved in two stages. On the first stage (direct course) the OMD are calculated for all network elements from wells to terminal. Constraints are handled by narrowing the OMD. On the second stage (backward course) the optimal solution is chosen from OMD.
Digital Slot: A Tool for Optimization and Development of New Hydraulic Fracturing Technologies
Idimeshev, Semen Vasilievich (Schlumberger) | Isaev, Vadim Ismailovich (Schlumberger) | Tikhonov, Alexey Alexandrovich (Schlumberger) | Semin, Leonid Georgievich (Schlumberger) | Bannikov, Denis Viktorovich (Schlumberger) | Velikanov, Ivan Vladimirovich (Schlumberger) | Ivanov, Maxim Grigorievich (Schlumberger) | Kuznetsov, Dmitry Sergeevich (Schlumberger) | Belyakova, Ludmila Sergeevna (Schlumberger)
Abstract We present the digital slot — a tool for the development of new hydraulic fracturing technologies via digitization of slurry flow in narrow channels. We consider slurry containing fluid, proppant, and fiber components. The flow is described by a continuum mathematical model based on the lubrication theory. The numerical algorithm utilizes Lagrangian approach with finite volume pressure solver. We present the results of laboratory validation and simulation examples showing the key effects affecting solids transport in hydraulic fracturing: settling, bridging, gravity slumping, materials degradation, viscosity contrast, and bank formation.
Hierarchy of Integrated Models of Varying Detail to Solve Problems at Different Stages of Gas Condensate Projects Development
Varavva, Artem Igorevich (Gazpromneft STC) | Apasov, Renat Timergaleevich (Gazpromneft STC) | Badgutdinov, Ruslan Rustamovich (Gazpromneft STC) | Yamaletdinov, Ayrat Flyurovich (Gazpromneft STC) | Koryakin, Fedor Andreevich (Gazpromneft STC) | Sandalova, Ekaterina Evgenevna (Gazpromneft STC) | Samolovov, Dmitriy Alekseevich (Gazpromneft STC) | Bikbulatov, Salavat Miniahmetovich (PJSC Gazpromneft) | Nekhaev, Sergey Sergey (Gazpromneft-Razvitie)
Abstract This study makes an attempt to generalize the integrated modeling tools used by the authors in practice on the basis of the following criteria: the volume of the initial data, the integration mechanism, constraints and assumptions. Various types of integrated models are compared with each other, the need for their application is analyzed, they are connected at various stages of the project development and by the tasks solved at this stage. It also describes the challenges that the authors encountered when working with integrated models of various levels of detail, approaches to their solution, and the lessons learned.