scholarly journals MONITORING AND CONTROL OF NEW TECHNOLOGIES FOR ENHANCED OIL RECOVERY AT THE PRODUCTION FIELDS IN WESTERN KAZAKHSTAN

2021 ◽  
pp. 1-9
Author(s):  
Gulnaz Zh. Moldabayeva ◽  
Raikhan T. Suleimenova ◽  
Sairanbek M. Akhmetov ◽  
Zhanar B. Shayakhmetova ◽  
Gabit E. Suyungariyev
Keyword(s):  
Factor Analysis ◽  
Oil Recovery ◽  
Statistical Models ◽  
New Technologies ◽  
Oil Field ◽  
Oil Fields ◽  
Water Production ◽  
Western Kazakhstan ◽  
Wide Range ◽  
Technical Measures

This paper discusses topical problems of further effective development of depleted oil fields (DOF) to increase their final oil recovery on the example of the oil field in Western Kazakhstan. Further exploitation of fields using waterflooding becomes unprofitable. At the same time, on average at these facilities, at least 50% of the reserves will remain unrecovered. Most of the oil fields in the Republic of Kazakhstan are at the late and final stages of development, which is characterised by an increase in the share of hard-to-recover oil reserves, a decrease in annual oil withdrawals, and a high water cut of the produced oil. Therefore, the problems of improving the technology aimed at reducing the volume of associated water production and increasing oil recovery from partially flooded deposits is very urgent. With an increase in the well density, the degree of field drilling and aging of the well stock, the work with the current declining well stock remains a very topical issue. Improving the efficiency of diagnostics and the systematic selection of wells for repair and isolation works is an important element for rationalising field development in the current conditions of profit variance in the oil and gas industry. The methods of bottomhole zone treatment also implement a deflecting effect on filtration flows. Therefore, this method includes a wide range of geological and technical measures: down-spacing; water production restraining; conformance control of injectivity profiles; forced production; all types of mechanical, thermochemical and thermal technologies. Consider a number of geological and technical measures that perform the tasks of occupational safety rules. Geological and statistical models are proposed for diagnosing wells for a premature increase of water production using factor analysis calculations for base production and Hall plots. Results. The degree of temperature influence of the primary components of the compounds on the rheology, filtration characteristics, and stability of inverted emulsions was determined. The classification of oil loss factors was carried out based on the results of downhole analysis and oil production losses were determined. Geological and statistical models for well diagnostics for premature increase in water production were built using factor analysis calculations for base production and Hall plots.

Laboratory studies of oil-washing characteristics of surfactants in the pore space of reservoir rocks

2021 ◽  
pp. 86-98
Author(s):  
V. Yu. Ogoreltsev ◽  
S. A. Leontiev ◽  
A. S. Drozdov
Keyword(s):  
Oil Recovery ◽  
Pore Space ◽  
Oil Field ◽  
Oil Fields ◽  
Molecular Surface ◽  
Laboratory Studies ◽  
Reservoir Rocks ◽  
Technological Efficiency ◽  
Chemical Eor ◽  
Physical And Chemical

When developing hard-to-recover reserves of oil fields, methods of enhanced oil recovery, used from chemical ones, are massively used. To establish the actual oil-washing characteristics of surfactant grades accepted for testing in the pore space of oil-containing reservoir rocks, a set of laboratory studies was carried out, including the study of molecular-surface properties upon contact of oil from the BS10 formation of the West Surgutskoye field and model water types with the addition of surfactants of various concentrations, as well as filtration tests of surfactant technology compositions on core models of the VK1 reservoir of the Rogozhnikovskoye oil field. On the basis of the performed laboratory studies of rocks, it has been established that conducting pilot operations with the use of Neonol RHP-20 will lead to higher technological efficiency than from the currently used at the company's fields in the compositions of the technologies of physical and chemical EOR Neonol BS-1 and proposed for application of Neftenol VKS, Aldinol-50 and Betanol.

scholarly journals RESEARCH OF THE MECHANISM OF OIL RECOVERY FROM HYDROCARBON DEPOSITS WITH LOW PERMEABILITY RESERVOIRS

2020 ◽  
Vol 17 (34) ◽  
pp. 892-904
Author(s):  
Zinon A KUANGALIEV ◽  
Gulsin S DOSKASIYEVA ◽  
Altynbek S MARDANOV
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
New Technologies ◽  
High Viscosity ◽  
Economic Feasibility ◽  
Oil Field ◽  
Low Permeability ◽  
Low Grade ◽  
Oil Reserves ◽  
Low Permeability Reservoirs

The main part of Russia's hard-to-recover reserves is 73% for low-grade and carbonate reservoirs, 12% for high-viscosity oil, about 15% of extensive sub-gas zones of oil and gas deposits and 7% of reservoirs lying at great depths. The development of such stocks with the usage of traditional technologies is economically inefficient. It requires the application of new technologies for their development and fundamentally new approaches to design, taking into account the features of extraction of hard-to-extract reserves (HtER). The purpose of this research is to find ways to improve the performance of low-permeability reservoirs. To accomplish this task, the Novobogatinsk South-Eastern Oil Field has been taken as an example and described. The necessary properties of production facilities in the field are highlighted, along with economic feasibility and technological efficiency. The reserves involved in the development are determined and, thanks to the knowledge of the geological oil reserves of the deposits, the potential oil recovery factor is calculated with the existing development technology. As a result of the research, development options were worked out with the results of the calculation of design indicators for the field as a whole. The comparison of oil recovery schedules and ORI, as well as the layout of wells, have been presented. As a result of the study, a description of 3 options for the development of design indicators for the field as a whole is given. The figures show oil production graphs, as well as location patterns. The authors of the study conclude which of the recommended development options can help extract maximum oil reserves.

scholarly journals Review of Oilfield Chemicals Used in Oil and Gas Industry

2021 ◽  
pp. 8-24
Author(s):  
M. Chukunedum Onojake ◽  
T. Angela Waka
Keyword(s):  
Natural Gas ◽  
Crude Oil ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Petroleum Industry ◽  
Oil And Gas Industry ◽  
Oil Field ◽  
Wide Range ◽  
Oilfield Chemicals

The petroleum industry includes the global processes of exploration, extraction, refining, transportation and marketing of natural gas, crude oil and refined petroleum products. The oil industry demands more sophisticated methods for the exploitation of petroleum. As a result, the use of oil field chemicals is becoming increasingly important and has received much attention in recent years due to the vast role they play in the recovery of hydrocarbons which has enormous  commercial benefits. The three main sectors of the petroleum industry are Upstream, Midstream and Downstream. The Upstream deals with exploration and the subsequent production (drilling of exploration wells to recover oil and gas). In the Midstream sector, petroleum produced is transported through pipelines as natural gas, crude oil, and natural gas liquids. Downstream sector is basically involved in the processing of the raw materials obtained from the Upstream sector. The operations comprises of refining of crude oil, processing and purifying of natural gas. Oil field chemicals offers exceptional applications in these sectors with wide range of applications in operations such as improved oil recovery, drilling optimization, corrosion protection, mud loss prevention, drilling fluid stabilization in high pressure and high temperature environment, and many others. Application of a wide range of oilfield chemicals is therefore essential to rectify issues and concerns which may arise from oil and gas operational activities. This review intends to highlight some of the oil field chemicals and  their positive applications in the oil and gas Industries.

Features and measures to improve the efficiency of development of a perspective small oil field

2020 ◽  
pp. 31-43
Author(s):  
T. K. Apasov ◽  
G. T. Apasov ◽  
E. E. Levitina ◽  
E. I. Mamchistova ◽  
N. V. Nazarova ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Oil Field ◽  
Oil Fields ◽  
Transport Infrastructure ◽  
Field Analysis ◽  
Field Development ◽  
Oil Reserves ◽  
Second Stage ◽  
Recoverable Reserves ◽  
Two Stages

Despite the current political and economic situation in Russia, mining in small oil fields is important and topical issue. We have conducted a geological and field analysis of the development of one of such small oil fields from setting into operation to shut down and have identified the reasons for the low production of oil reserves and the failure to achieve the design oil recovery factor. At the same time, the field has sufficient reserves of recoverable reserves, and there is an available transport infrastructure, which proves the necessity to consider rerun it for the development. For this purpose, geological and technical actions have been developed and are being proposed for implementation to improve the efficiency of field development. These actions envisage implementation in two stages: the first with minimal costs and the second with higher costs. At the first stage, at the existing reservoir pressure, we recommend to perform forced fluid withdrawals with an increase in depression on the reservoir. At the second stage, we offer actions at a higher cost, such as hydraulic fracturing, sidetracking. As a result of the analysis, actions have been developed to increase selection from initial recoverable reserves and increase the economic efficiency when the field is rerun.

Challenges, Opportunities and Threats of Deep Bottoms-Up Water Injection in Heavy Oil Reservoir: Lessons Learnt from the G Field, South Oman

2021 ◽  
Author(s):  
Chaitanya Behera ◽  
Sandip Mahajan ◽  
Carlos Annia ◽  
Mahmood Harthi ◽  
Jane-Frances Obilaja ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Water Injection ◽  
Field Performance ◽  
Oil Field ◽  
Oil Fields ◽  
Reservoir Pressure ◽  
Light Oil ◽  
Alternative Water ◽  
Variable Water

Abstract This paper presents the results of a comprehensive study carried out to improve the understanding of deep bottom-up water injection, which enabled optimizing the recovery of a heavy oil field in South Oman. Understanding the variable water injection response and the scale of impact on oil recovery due to reservoir heterogeneity, operating reservoir pressure and liquid offtake management are the main challenges of deep bottoms-up water injection in heavy oil fields. The offtake and throughput management philosophy for heavy oil waterflood is not same as classical light oil. Due to unclear understanding of water injection response, sometimes the operators are tempted to implement alternative water injection trials leading to increase in the risk of losing reserves and unwarranted CAPEX sink. There are several examples of waterflood in heavy oil fields; however, very few examples of deep bottom water injection cases are available globally. The field G is one of the large heavy oil fields in South Oman; the oil viscosity varies between 250cp to 1500cp. The field came on-stream in 1989, but bottoms-up water-injection started in 2015, mainly to supplement the aquifer influx after 40% decline of reservoir pressure. After three years of water injection, the field liquid production was substantially lower than predicted, which implied risk on the incremental reserves. Alternative water injection concepts were tested by implementing multiple water injection trials apprehending the effectiveness of the bottoms-up water injection concept. A comprehensive integrated study including update of geocellular model, full field dynamic simulation, produced water re-injection (PWRI) model and conventional field performance analysis was undertaken for optimizing the field recovery. The Root Cause Analysis (RCA) revealed many reasons for suboptimal field performance including water injection management, productivity impairment due to near wellbore damage, well completion issues, and more importantly the variable water injection response in the field. The dynamic simulation study indicated negligible oil bank development due to frontal displacement and no water cut reversal as initial response to the water injection. Nevertheless, the significance of operating reservoir pressure, liquid offtake and throughput management impact on oil recovery cann't be precluded. The work concludes that the well reservoir management (WRM) strategy for heavy oil field is not same as the classical light oil waterflood. Nevertheless, the reservoir heterogeneity, oil column thickness and saturation history are also important influencing factors for variable water injection response in heavy oil field.

New Technologies for Asset Management Applied to Oil Fields

2013 ◽  
Vol 746 ◽  
pp. 581-587
Author(s):  
Eduardo Cardoso Moraes ◽  
Ana Paula Tanajura ◽  
Herman Augusto Lepikson
Keyword(s):  
Asset Management ◽  
New Technologies ◽  
Oil Field ◽  
Oil Fields ◽  
Integrated Analysis ◽  
Rational Decision ◽  
Level Data ◽  
Corporate Goals ◽  
Comprehensive Manner ◽  
Oilfield Operations

Asset management is an integrated process that aims to achieve the alignment of corporate goals, information systems capable of making rigorous and consistent spending decisions based on asset-level data and cross-functional expertise between the various business process skills. In oil fields, managing the asset requires the decision-making from an integrated analysis of data that enables the understanding of interventions in the field in a comprehensive manner. For this, we propose an approach that by building a database of technical and economic variables, procedures and engineering methods to structure the information, and alignment with organizational strategy, more rational decision and better performances will be possible. These decisions can affect daily oilfield operations, direct investments or even disable an oil field facility.

scholarly journals The novel technology for reservoir stimulation: in situ generation of carbon dioxide for the residual oil recovery

2021 ◽  
Vol 11 (4) ◽  
pp. 2009-2026
Author(s):  
Geylani M. Panahov ◽  
Eldar M. Abbasov ◽  
Renqi Jiang
Keyword(s):  
Carbon Dioxide ◽  
Oil Recovery ◽  
Laboratory Tests ◽  
Oil Field ◽  
Chemical Compositions ◽  
Residual Oil ◽  
Reservoir Stimulation ◽  
Wide Range ◽  
Offshore Oil

AbstractThe gas and chemical flooding for reservoir stimulation with residual hydrocarbons reserves are highly relevant problem of current oil and gas recovery strategy. The objective of this paper is laboratory study and field implementation of new gas-EOR technology—in situ carbon dioxide generation technique for CO2-liquid slug formation under oil displacement, increasing the reservoir sweep efficiency and residual oil recovery. This paper presents a summary of a wide range of laboratory tests conducted on different core samples and chemical compositions. Several physical and hydrodynamic phenomena of in situ CO2 generation in highly permeable zones of a porous medium have been investigated as a part of complex study, which involved laboratory tests on the field-scale industrial technology applications, determination of optimal concentrations of foaming agents and inhibiting additives in gas-releasing solutions, etc. The results of laboratory experiments showed that the incremental recovery ranged between 30 and 35% oil original in place. The unique results of the field implementation provide developing an optimal technological scheme of reservoir stimulation with residual oil reserves both onshore and offshore oil fields. Technology of in situ CO2 generation was applied on the group of wells on Penglai offshore oil field (Bohai Bay). Incremental oil production for field operation was 37,740 bbl of crude oil. Theoretical and laboratory studies, as well as the outcomes of industrial implementation of a new method of residual oil recovery, using a CO2-slug confirm technology and economic profitability of the proposed solution.

scholarly journals Vankor oil field development experience

2019 ◽  
pp. 47-51
Author(s):  
Evgeny V. Panikarovskii ◽  
Valentin V. Panikarovskii ◽  
Alexandra E. Anashkina
Keyword(s):  
Oil Recovery ◽  
New Technologies ◽  
Development Rate ◽  
Oil Field ◽  
Water Flooding ◽  
Energy Potential ◽  
Field Development ◽  
Oil Field Development ◽  
Third Stage ◽  
Recovery Technique

The Vankor oil field is in the third stage of the development. Well stock mostly includes horizontal and directional wells. Analysis of the field development showed that actual development rate is much higher than planned. Energy potential of the field is drained out due to formation pressure decline and water flooding. New technologies for restoring well productivity, such as acid treatment and hydraulic fracturing should be introduced to maintain planned development rate. Drilling multilateral wells should be used as main enhanced oil recovery technique.

Managing limited subsurface data in a mature oil field case study: extending the production lifetime of a 50-year-old oil field in Indonesia: Rantau oil field Waterflood Pilot Project

2013 ◽  
Vol 53 (2) ◽  
pp. 489
Author(s):  
Reza Ardianto
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Oil Production ◽  
Pilot Project ◽  
Oil Field ◽  
Oil Fields ◽  
Water Flooding ◽  
Peak Oil ◽  
Screening Criteria ◽  
The Government

Business management of oil and gas in Pertamina State Oil enterprises was handed to one of its subsidiaries: Pertamina EP (PEP). With a vast working area of 140,000 km2, it consists of 214 fields where 80% is an old field (mature field or brown field). Most of these oil fields were discovered during Dutch colonialism. One of these fields was Rantau oil field, discovered in 1928; it is considered one of potential structure at the time. Peak oil production was achieved at 31,711 barrels of oil per day (BOPD) (wc 17.2%) in 1969, and it is still producing 2,500 BOPD from primary stage.To get better recovery from the Rantau oil field, it is necessary to identify the potential of secondary recovery water-flooding. Some screening criteria had been completed to select an appropriate method that could be applied in the Rantau field. PEP is preparing an Enhanced Oil Recovery (EOR) program to be applied in some oil fields with subsurface and surface potential consideration. The implementation was initiated by the EOR Department at PEP. The issue of the national oil production increasing program from the government has to be realised by the EOR Department at Pertamina EP. Following the national oil increasing program, management of PEP urged to increase oil production in a rapid and realistic way. As a result, the program of secondary and tertiary recovery pilot project should be conducted simultaneously by the EOR Department on some of the fields that have passed their peak. On the other hand, PEP has only limited geology, geophysics, reservoir, and production (GGRP) data, and most of the oil fields have been producing since 1930s. The conditions that have to be dealt with are as follows: production from the existing field is declining, data is collected and interpreted during a long period, huge amounts of production data, and reservoir model and simulation do not exist and are not frequently updated. Based on this, the planning of EOR struggled due to length of time needed versus the need for quick development. It has become much more of a challenge for the team consisting of integrated geophysics, geology, reservoir, production, process facility, project management and economic evaluation. This extended abstract presents the term of managing limited GGRP data that contributes to the successful pilot waterflood project in the Rantau field. It also explains the uses of limited subsurface GGRP data to overcome the uncertainty for planning of the waterflood pilot project in the Rantau field, as a part of planning using limited data.

Laboratory studies of oil-displacing characteristics of emulsion solutions in the pore space of reservoir rocks

2021 ◽  
pp. 53-65
Author(s):  
V. Yu. Ogoreltsev ◽  
S. A. Leontiev ◽  
V. F. Diaghilev ◽  
V. M. Spasibov
Keyword(s):  
Oil Recovery ◽  
High Efficiency ◽  
Pore Space ◽  
Laboratory Data ◽  
Oil Field ◽  
Laboratory Studies ◽  
High Permeability ◽  
Field Development ◽  
Reservoir Rocks ◽  
Technical Measures

Chemical enhanced oil recovery methods are widely used in field development. One of the methods for leveling injectivity is emulsion-based technologies. The mechanism of this technology is to create an increased filtration resistance of the most depleted reservoir intervals. To establish the actual oil-displacing characteristics of the emulsifier grades accepted for testing in the pore space of oil-containing reservoir rocks, a set of laboratory filtration studies was carried out on high-permeability core models at the AS12 horizon of the Nizhne-Sortymskoye oil field.Processing laboratory data after filtration of ready-to-use emulsions through core samples gives an increase in the oil displacement coefficient by water from 1.31 to 10.79 %. When constructing their correlation dependence, it is possible to identify the range of the final dynamic viscosity (from 5 to 9 mPa∙s) of the compositions of the emulsion-based technology, which is optimal for the most effective application on groups of AS formation.Based on the laboratory studies of rocks, it was established that carrying out geological and technical measures using the emulsifier Neftenol-NZ, which has proven itself in high efficiency from well treatments, will give a large volume of additional oil production, in comparison with the currently emulsifier Sinol-EM.

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