The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
- Data Science & Engineering Analytics
The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
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Yanin, A. N. (Design Bureau TERM LLC) | Bikkulov, M. M. (Gazpromneft-Khantos LLC) | Yanin, K. E. (Design Bureau TERM LLC) | Kolupaev, D. Yu. (Gazpromneft-Khantos LLC)
The authors identified the evolution stages of development system for the central section of the Priobskoye field (southern part) and evaluated the effectiveness of the implemented solutions. The object of study is the low-permeable horizons AC10 and AC12, identified at the beginning as a single development object. Joint exploitation of different-permeable formations AС10 (6.9•10 mkm) and AС12 (2•10 mkm) led to a twofold lag in the production of oil reserves from the worst formation. The authors explored key issues in the development of low-permeability reservoirs: if it is it possible to obtain relatively high rates of oil recovery under the indicated conditions and by what means can they be ensured; what will be the characteristic of the water-flooding of the area developed with the massive and repeated use of large-volume hydraulic fracturing; are there any prospects to ensure oil recovery at such facilities - more than 0.3. The study of the 20-year history of the development of the central section of the AC10-12 reservoir allowed to answer positively the above questions. The factors for a rapid increase in oil production in the area at stages I-II are high drilling rates, repeated large-volume hydraulic fracturing in wells, creation of low bottomhole pressures (less than 5 MPa) in production wells and high wellhead injection pressures (more than 20 MPa) , correct consideration of the probable direction of development of hydraulic fractures in the reservoirs. The factors for maintaining oil production at the III stage of the development of the site were quick commissioning of infill production wells; mass drilling of horizontal wells with multi-stage hydraulic fracturing into separate layers in order to locally subdivide the AС10-12 object; selective sidetracking from idle wells; reduction of bottomhole pressure in high-watered wells − up to 3 MPa; regulation of water injection volumes by area zones, reduction of the current withdrawal compensation by injection. Due to these effective measures, it was possible to ensure a favorable characteristic of oil displacement by water. As a result, the final recovery factor expected for the area will be 20% higher than the oil recovery approved in general for the AC10-12 facility in the southern part of the Priobskoye field.
Korkina, E. A. (Branch of the FSBI Center for Laboratory Analysis and Technical Measurements in the Urals Federal District for the Khanty-Mansiysk Autonomous District – Yugra) | Malgina, S. P. (Nizhnevartovsk State University) | Shtogrina, A. V. (Nizhnevartovsk State University) | Nikolaeva, A. V. (Caspian Pipeline Consortium-R JSC) | Ryakhin, M. S. (Zarubezhneft JSC)
The article describes the results of a model experiment on restoration soil fertility on natural substrates. The experiment was carried out on the territory of the Samotlorskoye field. Typically, these natural substrates are used in land reclamation measures. The study area has humid conditions with frozen rocks occurrence. The experiment investigated natural substrates in the form of peat or sand, or mixtures thereof, which are the most commonly used during reclamation. The analysis of the humus qualitative characteristics shows effective humus recovery on reclaimed lands. During the ten-year observation, the carbon deposition by the studied young soils was assessed. These data can be used in the development of carbon projects for green house gas sequestration. Due to the lack of information in the study area about car bon deposition in the phytomass and in the soil in the conditions of oil producing, the relevance of this topic is obvious. In particular, the study of the qualitative characteristics of carbon in soils and substrates, sufficient for reclamation measures, allows us to forma conception of ‘effective soil’. This will reduce the difference in balance between phytomass and carbon dioxide emission in to the atmosphere. The results of the model experiment can become the basis for planning reclamation measures of the Samotlorskoye field lands, which are disturbed by the oil industry, as well as other territories located in humid conditions with frozen rocks occurrence.
Karpan, Volodimir (Shell Development Oman LLC) | Al Farsi, Samya (Petroleum Development Oman) | Al Sulaimani, Hanaa (Petroleum Development Oman) | Al Mahrouqi, Dawood (Petroleum Development Oman) | Al Mjeni, Rifaat (Petroleum Development Oman) | van Batenburg, Diederik (Shell International Exploration and Production)
Abstract Polymer-based chemical flooding is a mature enhanced oil recovery technology that has proven to result in significant incremental oil recovery that is both cost and GHG emission-competitive compared to the oil recovered by conventional waterflooding. For such chemical flooding projects, controlling the viscosity of injected polymer solution is critical because the polymer cost is one of the most significant cost elements in the project economics. The polymer viscosity is routinely measured in the laboratory using fluid samples taken manually at different sampling points (i.e., polymer preparation facilities, injecting lines, and well heads). However, in the case of large-scale projects, such viscosity monitoring becomes time-consuming and requires dedicated field staff. Moreover, the quality of laboratory-measured viscosity is questionable due to the potential viscosity degradation caused by the oxygen ingress or polymer shearing during sampling, storage, and measurement. The inline viscometers were introduced to improve the reliability of viscosity measurements and have a better quality of viscosity monitoring. Such viscometers are relatively simple devices readily available on the market from several vendors. However, the device comes at additional costs and requires modifications at the tie-in point (bypass line, drainage, and (sometimes) communication and power lines). On top of it, operational costs include regular maintenance that the inline viscometer requires to ensure good data quality. This study introduces a data-driven Virtual Viscosity Meter (VVM) as a tool to augment the inline and laboratory viscosity measurements. Standard injector wells in a field are equipped with gauges that report injection rate, well/tubing head pressure, and temperature of the injected fluid. With such well data and viscosity measurements, calculating the viscosity becomes a machine learning regression problem. Training the machine learning regression methods on the actual inline and laboratory-measured polymer viscosity has demonstrated that VVM is a promising, high-accuracy solution with a low computational cost. The possibility of further implementing this approach to calculate the viscosity of an injected fluid was investigated using the data from several projects. Finally, the application of the VVM tool for viscosity monitoring and the limitations of VVM were discussed.
Babaev, M. L. (Tyumen Petroleum Research Center LLC) | Savchenko, I. V. (Tyumen Petroleum Research Center LLC) | Shkitin, A. A. (Tyumen Petroleum Research Center LLC) | Pisarev, A. A. (Tyumen Petroleum Research Center LLC) | Smirnov, D. S. (Tyumen Petroleum Research Center LLC) | Pisarev, D. Yu. (Samotlorneftegas JSC)
The article describes an experience and technologies of heterogeneous Ryabchik formation AV1 development. Nine zones specified by the character of layers composing reservoir, depositional environment and involvement of areas into development. Permeability of zones modifies from 0,005 to 0,081 μm. Main volume (over 90%) of remaining oil in place concentrated in medium and low-permeable zones (permeability coefficient is 0,005–0,007 μm). For the purpose of development efficiency improvement, multistage hydraulic fracturing and drilling of horizontal wells up to 2000 m realized. Performance of hydrofrac is complicated by the presence of underlying high-productive water-saturated АВ1 formation. Hydrofracturing AV1 rises probability of fractures penetration into АВ1 formation. Reduction of fracture height realizes by low-volume hydrofracturing with non-crosslinked gel. This technology allows to cut fracture height in 30-60% in comparison with hydrofrac on crosslinked gel at similar proppant loading. Small-volume hydraulic fracturing on non-cross-linked gel is used to reduce the fracture height. Advanced technology of drilling in the reservoir with multilateral wells was tested in areas with contact reserves. In the zone of highly productive reservoirs, tertiary methods of enhanced oil recovery are successfully applied. Water-cut in production wells in these zones is 96-98%. To rise formation productivity sludge-forming, gel-forming and fiber-dispersed compositions are pumped into injection holes.
Vysotskikh, A. M. (Izhevsk Petroleum Research Center JSC) | Ivashov, Ya. D. (Izhevsk Petroleum Research Center JSC) | Tyukavkin, D. G. (RN-Nyaganneftegas JSC) | Puzanov, I. S. (RN-Nyaganneftegas JSC)
In June – December 2020 Izhevsk Petroleum Research Centre JSC carried out large-scale research aimed at assessment of influence of oil reservoirs microbiological contamination on accidents rate of oilfield pipeline system used at of the Krasnoleninsky arch oil fields (Talinskoye, Em-Egovskoye and Kamennoye) in Western Siberia. Several hypotheses were tested and a review was made of the results of observations, data of laboratory and field tests earlier performed by specialists in microbiological corrosion in oil fields. Data on exploitation targets, oilfield infrastructure of RN-Nyaganneftegas JSC and pipeline accident statistics were analyzed, scope of work and research objects were determined at the initial stage. Further, the specialists Izhevsk Petroleum Research Centre deployed a chemical analysis laboratory directly at the industrial estate of RN-Nyaganneftegas JSC and took samples of liquid and hard deposits for research. The special biosondes had manufactured to determine a concentration of adhered forms of bacteria especially for this project. A high degree influence of sulfate-reducing bacteria (SRB) on normalized frequency of oil leaks has been confirmed after consolidation of data on transported fluids corrosiveness through mathematical analysis. Favorable for SRB reproduction environment conditions, ranges and sources of microbiological contamination of the oil field system, and SRB lifecycle was determined. The dependence of insufficient effectiveness of pipeline corrosion protection on SRB presence had verified. As a result of the research, guidelines were formed available as a strategy for reducing accidents and extending the service life of the oil fields pipeline infrastructure.
Ryazantsev, M. V. (RN-BashNIPIneft LLC) | Mironenko, A. A. (RN-BashNIPIneft LLC) | Kuzin, I. G. (RN-BashNIPIneft LLC) | Nigmatullina, R. G. (RN-BashNIPIneft LLC) | Fedorov, A. E. (RN-BashNIPIneft LLC) | Kravets, D. A. (RN-Yuganskneftegas LLC) | Miroshnichenko, V. P. (RN-Yuganskneftegas LLC) | Guryanov, A. N. (RN-Yuganskneftegas LLC) | Kudashov, K. V. (Rosneft Oil Company) | Sergeychev, A. V. (Rosneft Oil Company)
The article is dedicated to the fortieth anniversary of Priobskoye oil field discovery, one of the most unique fields in the Russian Federation. The Priobskoye field belongs to the category of unique not only in terms of reserves, but also in terms of its most interesting development history. 40 years ago, the field was discovered based on the results of testing the exploration well No. 151P, which proved the presence of commercial hydrocarbon reserves. Despite this, this field could not be approached for a very long time due to the inaccessibility of the area, where it was necessary to build infrastructure from scratch, lay roads, pipeline networks and much more, and also, taking into account the fact that most of the reserves belong to the category difficult to recover, the reservoirs are characterized by a very complex geological structure and are characterized by low permeability values. Today it is a whole industrial area with several production and preparation shops, bases of process management and contracting organizations, the largest industrial infrastructure has been created. The development of this field has come a long way, on which, with the acquisition of new knowledge and the development of technologies, the fundamental design solutions and approaches to its development have repeatedly changed. Today, the Priobskoye field is one of the most key fields in our country and Rosneft, providing 13% of its annual Company’s oil production. And besides all this, it is an advanced testing ground and implementation of technologies for the development of ultra-low-permeability reservoirs, the positive results of the pilot work are broadcast to similar areas of the Rosneft Oil Company's fields. The authors provide a brief history and description of the main stages of development, an overview of the reasons that led to fundamental changes and the evolution of project decisions.
Ziatdinova, E. Yu. (RN-BashNIPIneft LLC) | Egorov, E. L. (RN-BashNIPIneft LLC) | Osorgin, P. A. (RN-BashNIPIneft LLC) | Mironenko, A. A. (RN-BashNIPIneft LLC) | Kuzin, I. G. (RN-BashNIPIneft LLC) | Serdyuk, A. N. (RN-Yuganskneftegas LLC) | Sergeichev, A. V. (Rosneft Oil Company)
The Priobskoye field is currently one of the largest unconventional reservoirs in the West Siberia. That field is characterized by low permeability and complex reservoir structure. In order to increase the recovery factor and raise the level of oil production in the Priobskoye tight formation the amount of wellworks constantly increases. Reservoir fracturing is the main of the variety of different wellworks is applied in this oilfield. The first operation of hydraulic fracturing at the Priobskoe field was made in 1992. RN-Yuganskneftegas LLC is one of the leaders in the field of hydraulic fracturing. Petroleum engineers, who develop this oil reservoir, have a great practical experience in reservoir fracturing. Nowadays formation fracturing is used in all well completing operations at the Priobskoye field. This article represents the main stages of evolution of hydraulic fracturing technology at the Priobskoye field. Historical data of the number of performed well operation of hydraulic fracturing at the Priobskoye field are presented. The relation between a volume of injection proppant and performance wells (vertical, horizontal) after hydraulic fracturing was discovered and the analysis of refracturing treatment effectiveness was made additionally. The ideas for further optimization of hydraulic fracturing technologies and development of digital hydraulic fracturing modeling are presented.
Karpan, Volodimir (Salym Petroleum Development B.V.) | de Reus, Jasper (Shell Global Solutions International B.V.) | van Batenburg, Diederik (Shell Global Solutions International B.V.) | Mikhaylenko, Egor (Salym Petroleum Development B.V.)
Abstract An Alkaline-Surfactant-Polymer (ASP) pilot was executed in the West Salym oil field in the Russian West-Siberian oil province. To successfully interpret the project outcome an extensive surveillance plan was put in place. A tracer program formed an important, stand-alone part of the plan. Tracers injection was designed and executed to evaluate the incremental oil production due to ASP injection by using A) change in volume swept between the pilot wells and B) change in oil saturations due to ASP flooding. This paper focusses on the practical aspects of the tracer program execution and how the tracer program results were used for the interpretation of the pilot. The West Salym reservoir is a sandstone formation with 83°C temperature, 2 cP crude oil viscosity, permeabilities ranging from 10 to 250 mD and porosity ranging from 18 to 22%. The field is operated as a mature waterflood, with oil production having peaked in 2011. To increase the recovery factor, a tertiary oil recovery technique (ASP) was selected. A confined five spot well pattern was chosen for conducting the ASP field trial. Due to low remaining oil saturation after the waterflood (executed also as a pre-flush for the ASP flood) the production watercut reverse due to the ASP injection changed only from 98% to 88-90%. Hence, it was important to evaluate the efficiency of ASP flooding using several independent approaches. In addition to field injection/production data, analytical and modelling techniques, the tracer data interpretation became a valuable source of information. Four tracer injection stages were conducted during West Salym ASP pilot. Passive and partitioning tracer injection/production data were analyzed using Shook's analytical method and supported by the reservoir modelling. Analytical analysis of field data was complicated by the production and injection upsets, as well as the changes in injected viscosities. Even though the requirement for steady state conditions were not fully met, the passive tracer recovery data provided an important input to the history matching of pilot dynamic model helping to determine the sweep increase due to injection of viscous chemical solutions. The partitioning tracer recovery data in the water post-flush were used to confirm the low residual oil saturation after ASP flooding.
Gazprom's oil-focused subsidiary Gazprom Neft has signed a memorandum of understanding with AIQ, a joint venture between the Abu Dhabi National Oil Company (ADNOC) and the UAE-based cloud computing firm Group 42. The firms seek to jointly develop and commercialize digital solutions for the upstream oil and gas industry in Russia and the Middle East. The partners pledged to develop tools for oil and gas exploration and production using cognitive technologies that cross the spectrum of algorithms, robotic process automation, machine learning, natural language processing and generation, and artificial intelligence. This is according to Gazprom Neft's Science & Technology Center, the company's research and development arm. ADNOC and Group 42 created the AIQ joint venture in 2019 to commercialize advanced programming solutions specifically for the oil and gas industry.
Temnikova, E. Yu. (A.A. Trofimuk Institute of Petroleum Geology and Geophysics, Siberian Branch of the RAS) | Grubas, S. I. (A.A. Trofimuk Institute of Petroleum Geology and Geophysics, Siberian Branch of the RAS) | Glinskikh, V. N. (A.A. Trofimuk Institute of Petroleum Geology and Geophysics, Siberian Branch of the RAS)
A computational algorithm based on an artificial neural network has been developed and implemented for lithological interpretation of well logging data for the Bazhenov Formation. The algorithm estimates the mineral-component composition of rocks. Our studies employ the classification of the Bazhenov Formation lithological types, which is centered on the modern concept of rock-forming mineral and mineraloid components distribution (clay, siliceous, carbonate minerals, and organic matter). Using the developed algorithm for a set of well logging data and taking into account the results of laboratory lithological and geochemical core studies, we constructed models of the content of rock-forming components of the Bazhenov Formation for the central part of the Salym field. The main lithological types of Bazhenov Formation rocks were distinguished: silicites, mudstones, carbonates, and mixtites (mixed siliceous-clay-carbonate rocks), including those enriched in organic matter. The contents of rock-forming components that were calculated with usage of an artificial neural network have a good correlation with the results of detailed lithological and geochemical core studies. Based on the obtained lithological models, we constructed correlation schemes of the Bazhenov Formation, which made it possible to trace the vertical and lateral variability of its mineral-component composition. The average contents of clay, siliceous, carbonate minerals, pyrite, albite, and organic matter have been determined. Significant spatial heterogeneity of the Bazhenov Formation is observed due to the multicomponent composition and complex distribution of various types of rocks that affect its main characteristic features within the local area of the examined field. The obtained results of the performed studies can be useful in research of the structure of the Bazhenov Formation when core materials are unavailable.