scholarly journals Oil Field Development Scenario With Geological Characterization In "Alpha" Field Of South Sumatra Basin

Khazanah ◽  
2020 ◽  
Vol 12 (2) ◽  
Author(s):  
Cahyadi Julianto ◽  
◽  
Dimas Ramadhan ◽  
Hidayat Tulloh ◽  
Aji Dharma Maulana ◽  
...  
Keyword(s):  
Oil Production ◽  
Oil Field ◽  
It Use ◽  
Field Development ◽  
High Productivity ◽  
Development Scenarios ◽  
Decline Curve ◽  
Calculation Results ◽  
Cumulative Production ◽  
Curve Method

The Structure of Alpha Field located in South Sumatra Basin, Geographically located around Musi Banyu Asin, Sub-district Sungai Lilin. The target reservoir to be developed is Baturaja Formation, domination with sandstone, and consisting of 9 layers. To forecast the production of the field, it use decline curve analysis. From the existing oil production data, exponential and hyperbole charts can be created. So, the analysis of decline curve method can forecast how much hydrocarbon can be produce from the reservoir. To get the maximal recovery of oil production, field development can be done. In making a geological model or geological characterization of the Alpha field using the Oasis Montaj software. Based on the calculation results, scenario 1 which is the basecase, is unable to produce for 20 years. The cumulative value of production is 76,243.8 with an RF of 9.67%. Scenario 2 is basecase/scenario 1 plus several workover wells (WO) capable of producing for 20 years with a cumulative production value of 484,748.7 STB with an Recovery Factor (RF) value of 10.47%. Whereas scenario 3 is scenario 2 plus several workover wells with the addition of infill wells capable of producing for 20 years with a cumulative production of 2,036,907.1 STB with an RF value of 13.50%. Of the three scenarios, the best scenario is scenario 3 because it has the highest cumulative value of production and RF and is certainly capable of producing for 20 years after a simulation using the DeclineCurve Analysis method. There is a relationship between geological characterization and field development scenarios where to provide information about Alpha Field, especially which parts and wells have high productivity so that it can be used as a reference in field development, especially when determining drill points for infill wells and well workovers.

Biotechnology of oil production. Principles and application

2017 ◽  
Author(s):  
Nariman Ismailov
Keyword(s):  
Human Activity ◽  
Oil Production ◽  
Oil Field ◽  
General Idea ◽  
Field Development ◽  
Main Research ◽  
Research Areas ◽  
Oil Field Development ◽  
Wide Range

The importance of biotechnology in various areas of human activity has become increasingly obvious in recent years. This determines the interest that, in our opinion, this book represents. It is aimed primarily at specialists engaged in the development of biotechnologies, as well as oil practitioners. The purpose of this book is to give the most complete, in — depth understanding of what oil production biotechnology is. However, it would be frivolous to say that this book exhaustively covers this topic. It is intended to arouse the interest of researchers and practitioners to this problem and give a General idea about it. This is essentially only the basis of some of the main research areas that can be attributed to the field of oil production biotechnologies, as well as an assessment of the principles that are the basis for the development of such technologies. At the same time, we believe that this book can be a good introduction to most of the main problems of oil production biotechnology. The book is intended not only for oil practitioners and specialists in the field of microbial biotechnologies, but also for a wide range of readers. It will be very useful for a student, an engineer specializing in the field of biotechnology of oil field development, as well as scientists to read this book.

Improvement of the Working Conditions of Oil Miners during the Transition from the Thermoshaft Method of High-Viscosity Oil Production to the Modular Mine Method of the Yaregskoye Field Development

2020 ◽  
pp. 58-65
Author(s):  
A.I. Fomin ◽  
◽  
T.V. Grunskoy ◽  
◽  
Keyword(s):  
Working Conditions ◽  
Occupational Diseases ◽  
Injury Rate ◽  
Oil Production ◽  
High Viscosity ◽  
Oil Field ◽  
Mining Operations ◽  
Field Development ◽  
Mine Workings ◽  
High Viscosity Oil

The need for high-viscosity oil production in the fields of the Russian Federation is substantiated. The technology of high-viscosity oil production by the thermoshaft method is considered, harmful and hazardous factors at the workplaces of the underground group workers are identified, first of all, the microclimate parameters (increased air temperature of the working area), which effect on the formation of occupational diseases and an increase in the risk of injury to the personnel. The main problems associated with the imperfection of the technology of the thermoshaft method for the extraction of high-viscosity oil, which effect on the safety of conducting operations for the extraction of heavy oil, are investigated, and presented. The options of opening up a high-viscosity oil field with a modular mine, which allows to normalize the thermal regime in mine workings, improve working conditions of the oil miners, reduce the level of occupational diseases and injury rate, reduce the volume of work and the costs of mining operations and maintenance of the mine workings, are considered. The system for the development of the Yaregskoye field of high-viscosity oil with the division of the mine field into separate production blocks using a sectional ventilation scheme, which provides for independent ventilation of each module due to the construction of an air supply and air exhaust shafts in each block-module of the mine is proposed in the article. The surface and underground complex of shafts for the construction of a modular mine is presented. The calculation is carried out and the results of technical solutions for airing various modifications of mini — mines are given. The drilling gallery was designed, which is typical for all the options of opening. In the designed modular mines, a closed oil gathering system is proposed. Comparative economic analysis showed the efficiency of the development of new areas of the Yaregskoye high-viscosity oil field using the construction of modular mines.

scholarly journals SOLUTIONS FOR THE SYSTEM RELIABILITY OF FIELD FACILITIES OF WEST SIBERIAN OIL FIELDS

2017 ◽  
pp. 73-77 ◽  
Author(s):  
V. A. Ivanov ◽  
S. M. Sokolov
Keyword(s):  
Crude Oil ◽  
System Reliability ◽  
Oil Production ◽  
High Water ◽  
Negative Influence ◽  
Climatic Conditions ◽  
Oil Field ◽  
Oil Fields ◽  
Field Development ◽  
Crude Oil Production

The issue of reliability assurance while constructing the oil field facilities by the example of West Siberian oil fields is considered. In particular, attention is paid to the problems that arise during the stage of mechanized crude oil production in case of high water cut of well produce, in severe natural and climatic conditions areas. The whole field development technological chain from the stage of crude oil production to the stage of crude-oil gathering and transportation was analyzed. For every stage the major factors, decreasing the system reliability, were determined and the suggestions for the elimination of these factors or reducing their negative influence were made. A number of possible measures for improvement field facilities construction reliability and profitability are indicated.

scholarly journals Approaches to forecast oil field performance at the well pads level and beta testing on oilfields of RN-Nyaganneftegaz (ROSNEFT)

2021 ◽  
Vol 6 (4) ◽  
pp. 123-130
Author(s):  
Aleksandr V. Korytov ◽  
Oleg A. Botkin ◽  
Aleksandr V. Knyazev ◽  
Petr V. Zimin ◽  
Dmitriy P. Patrakov ◽  
...  
Keyword(s):  
Analytical Methods ◽  
Field Performance ◽  
Oil Production ◽  
Curve Analysis ◽  
Oil Field ◽  
Oil Fields ◽  
Decline Curve ◽  
Long Term Performance ◽  
Term Performance

Background. The study performed by Rosneft employees shown in this paper demonstrates approach and analytical methods that allows to forecast oil production at the level of minimal infrastructure units. These approaches are used to forecast long-term oil production and predict infrastructure blockage. The approach was partially automated by the authors. This made it possible to testing at giant Krasnoleninskoye oilfield. Aim. The study was performed in order to develop and test an approaches to forecast oil production of large oil fields with high detail levels. Materials and methods. Common methods of decline curve analysis and water-into-oil curve analysis were used in this work to analyze the precondition. The main feature of the approach is the analysis of precondition at the level of large well clusters and transfer it to the level of wells. Some of the actions were automated by new proprietary software and were tested at the giant brown field. The software was integrated with the corporate database. Results. An author’s approach has been developed. The approach allows to forecast oil production at the level of infrastructure units using analytical methods. Oil production of the giant brown field with high detail levels were forecasted using the proposed approaches and developed software. Conclusions. The results show that the developed approaches and software can be used to forecast mediumand long-term performance of producing oil fields in the conditions of existing external and infrastructural constraints.

OFFSHORE GIPPSLAND BASIN FIELDS

1971 ◽  
Vol 11 (1) ◽  
pp. 85 ◽  
Author(s):  
B. R. Griffith ◽  
E. A. Hodgson
Keyword(s):  
Lower Cretaceous ◽  
Oil And Gas ◽  
Oil Field ◽  
Gas Field ◽  
Field Development ◽  
Oil And Gas Field ◽  
Cumulative Production ◽  
Gippsland Basin ◽  
Offshore Field ◽  
Unconformity Surface

The offshore Gippsland Basin, underlies the continental shelf and slope between eastern Victoria and Tasmania.The basin is filled with up to 25,000' of sediment, varying in age from Lower Cretaceous to Recent. The Lower Cretaceous section is represented by at least 10,000' of nonmarine greywackes of the Strzelecki Group. The overlying sediments of Upper Cretaceous to Eocene age comprise the interbedded sandstones, siltstones, shales and coals of the Latrobe Group, with a cumulative thickness of about 15,000'. Offshore, the Latrobe Group is overlain unconformably by up to 1500' of calcareous mudstones of the Lakes Entrance Formation and up to 5000' of Gippsland Limestone carbonates. Pliocene to Recent carbonates, reaching a maximum thickness of about 1000', complete the sedimentary section of the basin.Australia's first commercial offshore field, the Barracouta oil and gas field, was discovered in the Gippsland Basin in February 1965. Further exploratory drilling over the following two and a half years led to the discovery of the Marlin gas field and the Kingfish and Halibut oil fields.The principal hydrocarbon accumulations are reservoired by sediments of the Latrobe Group within closed structural highs on the Latrobe unconformity surface. Seal is provided by the mudstones and marls of the Lakes Entrance Formation and Gippsland Limestone.A field development programme was initiated immediately after Barracouta had been confirmed as a commercial gas reservoir. By the end of 1967, the Barracouta 'A' platform had been erected. Construction and positioning of the Marlin, Halibut and the two Kingfish platforms followed.To date development drilling has been completed on the Barracouta and Halibut fields, while development of the Marlin field has been temporarily suspended following completion of four wells. Development of the Kingfish oil field which commenced in March 1970, is still in a relatively early stage.The Barracouta field has been producing gas and oil since March and October, 1969 respectively. The Marlin gas field was put on stream in November, 1969 and the Halibut oil field in March 1970. As yet no wells drilled in the Kingfish oil field have been completed for production.The four fields provide a major source of hydrocarbons for the Australian market. By the end of September, 1970 cumulative production of sales quality gas from the Barracouta and Marlin fields was almost 23 BCF. Cumulative production of stabilised oil from Barracouta was 2 million barrels and over 26 million barrels from Halibut.

WANDOO: THE DEVELOPMENT OF A MARGINAL FIELD

1999 ◽  
Vol 39 (1) ◽  
pp. 523
Author(s):  
M.R. Fabian
Keyword(s):  
Oil Field ◽  
Production Test ◽  
Oil Viscosity ◽  
Commercial Development ◽  
Full Field ◽  
Field Development ◽  
Unconsolidated Sands ◽  
Reservoir Performance ◽  
Development Scenarios ◽  
Marginal Field

The combination of characteristics of the Wandoo Oil Field is unusual and presented significant challenges for commercial development of this field. These characteristics are a shallow reservoir, high oil viscosity, thin oil column, unconsolidated sands and very high permeability.A staged development of this field was adopted to enable evaluation of these characteristics, commencing with a 120-day extended production test (EPT). The EPT was further extended to address aquifer support and horizontal well length issues and for commercial reasons. The information gained from the EPT was used to calibrate the full field simulation model, which was used to quantify the benefits of various development scenarios. To date, the reservoir performance has been in accordance with pre-full field development expectations.

Low-Cost Development Plan Optimization for a Polish Oil Field

2021 ◽  
Author(s):  
Daniel Podsobinski ◽  
Roman Madatov ◽  
Bartlomiej Kawecki ◽  
Grzegorz Paliborek ◽  
Piotr Wójcik ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Capital Expenditure ◽  
Oil Production ◽  
Oil Field ◽  
Oil Fields ◽  
Development Plan ◽  
Recovery Factor ◽  
Co2 Injection ◽  
Development Scenarios ◽  
Injection Water

Abstract In Poland there are approximately 60 oil fields located in different geological structures. Most of these fields have been producing for several years to several dozen years, and now require redefining of the development plan by utilizing an improved oil recovery (IOR) or enhanced oil recovery (EOR) method to achieve a higher oil recovery factor. Here we present the redevelopment plan for the Polish Main Dolomite oil field, that aimed to optimize and maximize the oil recovery factor. Considering all available geological and reservoir data, both a static and dynamic model were built and calibrated for three separate reservoirs connected to the same production facility. Then the comprehensive study was performed where different development scenarios was considered and tested using reservoir numerical simulation. The proposed redevelopment scenarios included excessive gas reinjection to the main reservoir, additional high-nitrogen (N2) gas injection from a nearby gas reservoir (87% of N2), carbon dioxide (CO2) injection, water injection, polymer injection, water-alternating-gas (WAG), well stimulation, and a combination of these methods. Development plans assumes also drilling new injection and production wells and converting existing producers to gas or water injectors. The key component in development scenarios was to arrest the pressure decline from the main field and decrease the gas/oil ratio (GOR). An additional challenge was to implement in the simulation model all key assumptions behind various development scenarios, while also taking into account specific facility constraints and simultaneously handling separate reservoirs that are connected to the same facility, and hence affecting each other. From numerous scenarios, the scenario that requires the least number of new wells was selected and further optimized. It considers the drilling of only one new producer, one new water injector, and conversion of some currently producing wells to gas and water injectors. The location of the proposed well and the amount of injection fluids was optimized to achieve the highest oil recovery factor and to postpone gas and water breakthrough as much as possible. The optimized case that assumes low investments is expected to improve incremental oil production by 90% over No Further Actions Scenario. However, the study suggests the potential of more than tripling incremental oil production under a scenario with considerably higher expenditures. The improved case assumes drilling one more producer, four new water injectors, and injection of three times more water. The presented field optimization example highlights that in many existing Polish oil fields there is still a potential to reach higher oil recovery without considerable expenditures. However, to obtain more significant oil recovery improvement, higher capital expenditure is necessary. To facilitate the selection of the best development scenario, a detailed economic and risk analysis needs to be conducted.

Research of Optical Fiber Fluid Flow Monitoring System Using Flow-Induced Pipe Vibration in the Oil Production

2012 ◽  
Vol 616-618 ◽  
pp. 996-999
Author(s):  
Ying Shang ◽  
Xiao Hui Liu ◽  
Chang Wang ◽  
Bao Quan Sun ◽  
Gan Li ◽  
...  
Keyword(s):  
Fluid Flow ◽  
Oil And Gas ◽  
Oil Production ◽  
Scientific Basis ◽  
Oil Field ◽  
Mean Flow ◽  
Field Development ◽  
Flow Monitoring ◽  
Developed Turbulence ◽  
Pipe Vibration

In the oil field development and production, fluid flow is an extremely important parameter which determines the transmission characteristics of the oil production, real-time monitoring of fluid flow parameter provides a scientific basis for oil and gas optimization exploration and increase of reservoir recovery. A method for interrogating fiber optic sensors using flow-induced pipe vibration is proposed, then the fixed relationship between standard deviation of pipe wall’s vibration induced by fully developed turbulence and mean flow rate is determined.The advantage of this method is applicable to small flow measurement with non-intrusively.

Efficiency Analysis of the Geological-Technical Activities in Severo-Ostrovnoe Field

2019 ◽  
Vol 16 (11) ◽  
pp. 4584-4588
Author(s):  
I. A. Pogrebnaya ◽  
S. V. Mikhailova
Keyword(s):  
Hydraulic Fracturing ◽  
Production Rate ◽  
Oil Recovery ◽  
Oil Production ◽  
Horizontal Wells ◽  
Oil Field ◽  
Field Development ◽  
Multi Stage ◽  
Field Works ◽  
Technical Measures

The work is devoted to identifying the most relevant geological and technical measures carried out in Severo-Ostrovnoe field from the period of its development to the present. Every year dozens of geotechnical jobs (GJ) are carried out at each oil field-works carried out at wells to regulate the development of fields and maintain target levels of oil production. Today, there are two production facilities in the development of the Severo-Ostrovnoe field: UV1a1 and BV5. With the help of geotechnical jobs, oil-producing enterprises ensure the fulfillment of project indicators of field development (Mikhailov, N.N., 1992. Residual Oil Saturation of Reservoirs Under Development. Moscow, Nedra. p.270; Good, N.S., 1970. Study of the Physical Properties of Porous Media. Moscow, Nedra. p.208). In total, during the development of the Severo-Ostrovnoe field, 76 measures were taken to intensify oil production and enhance oil recovery. 12 horizontal wells were drilled (HW with multistage fracking (MSF)), 46 hydraulic fracturing operations were performed, 12 hydraulic fracturing operations were performed at the time of withdrawal from drilling (HW with MSF), five sidetracks were cut; eight physic-chemical BHT at production wells; five optimization of well operation modes. The paper analyzes the performed geological and technical measures at the facilities: UV1a1∦BV5 of the Severo-Ostrovnoe field. Four types of geological and technical measures were investigated: hydraulic fracturing, drilling of sidetracks with hydraulic fracturing, drilling of horizontal wells with multi-stage hydraulic fracturing, and physic-chemical optimization of the bottom-hole formation zone. It was revealed that two geotechnical jobs, namely, formation hydraulic fracturing (FHF) and drilling of lateral shafts in the Severo-Ostrovnoe field are the most highly effective methods for intensifying reservoir development and increasing oil recovery. SXL was conducted at 5 wells. The average oil production rate is 26.6 tons per day, which is the best indicator. Before this event, the production rate of the well was 2.1 tons per day. Currently, the effect of ongoing activities continues.

scholarly journals Combustion of Hydrogen Sulfide-Containing Oil on the Surface of the Water and Possible Applications of Combustion Method at Sea

2017 ◽  
Vol 19 (2) ◽  
pp. 133
Author(s):  
Z. Mansurov ◽  
B. Lesbayev ◽  
G. Smagulova ◽  
Zh. Kulekeev ◽  
G. Nurtaeva
Keyword(s):  
Hydrogen Sulphide ◽  
Caspian Sea ◽  
Combustion Process ◽  
Oil Production ◽  
Combustion Method ◽  
Oil Field ◽  
The Caspian Sea ◽  
Field Development ◽  
Ecological Requirements

Oil production in sea conditions is associated with certain difficulties of the field development process due to technological peculiarities of oil production at sea. The Caspian Sea is an enclosed pond with a very sensitive ecosystem, therefore, maritime operations here meet higher requirements than in open ponds. The uniqueness of the Caspian Sea is in the fact that its biological wealth has no analogues in the world, therefore, mining without complying with strict ecological requirements can cause irreparable harm to the environment. This work deals with the analysis of the possibility to use controlled combustion in situ in case of accidents on the Kashagan oil field which is located in the Caspian Sea. The Kashagan oil field is distinguished by a high content of hydrogen sulphide. In order to study the operational possibilities of oil combustion in situ, the process of evaporation and combustion of desulfurized oil from the Kashagan field depending on salinity of water was studied in this work. The process of evaporation of hydrogen sulphide from hydrogen sulphide-containing oil and the peculiarities of its combustion on water surface were studied in this work. It has been stated that the main difference in oil combustion with a high content of hydrogen sulphide is that the oil combustion process leads to the increase of sulfur concentration in oil residue after combustion.

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