scholarly journals Evaluation of oil and gas potential of blocks A and B Song Hong basin and suggested exploration plan

2015 ◽  
Vol 18 (4) ◽  
pp. 12-31
Author(s):  
Luan Thi Bui
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Petroleum System ◽  
Basement Rock ◽  
3D Seismic ◽  
Oil Accumulation ◽  
Recovery Coefficient ◽  
Gas Accumulation ◽  
Risk Parameters ◽  
Gas Potential

Basing on the structure, stratigraphic, depositional conditions and petroleum system the petroleum prospect, Song Hong northern basin, particularly, blocks A and B was evaluated. SIgnificantly high gas potential areas are Hong Ha, Sapa and Bach Long Bac structural sections. Predominantly oil potential is found in Hau Giang and Vam Co Dong structural areas. Low gas potential is found in Cay Quat and Ben Hai structural sections and low oil potential is found in Vam Co Tay, Chi Linh, Do Son and Tien Lang structural areas. The result of the calculation of a petroleum accumulattion capacity at the local, enhanced recoveral volume, risk parameters for stored gas and oil amount in blocks A and B are the oil potential in Kainozoi basement rock (KZ): oil accumulation volume at the local is 1722.9 million barrels (273.9 million cubic meters); oil recovery coefficient is 0.25 %; oil recoverable amount is 430.7 million barrels (68.5 million cubic meters). The gas potential in Miocene structural areas: gas accumulation volume at the local is 1620 BSCF (45.8 billion cubic meters); gas recoverable amount is 972 BSCF (27.5 billion cubic meters). The coefficient of success is quite low at 0.18 - 0.31 for gas and 0.08 – 0.23 for oil. Suggestion for the exploitation and exploration in further steps is to servey the 3D seismic in a 1500 square kilometer area and drill 2 wells for the exploration.

HYDROGEOLOGICAL CHARACTERISTICS OF RESERVOIR WATERS OF THE CASPIAN SEA DEPOSITS

2021 ◽  
Vol 82 (3) ◽  
pp. 33-48
Author(s):  
NABIEVA VICTORIA V. ◽  
◽  
SEREBRYAKOV ANDREY O. ◽  
SEREBRYAKOV OLEG I. ◽  
◽  
...  
Keyword(s):  
Oil Recovery ◽  
Caspian Sea ◽  
Oil And Gas ◽  
Chemical Properties ◽  
Water Area ◽  
Water Soluble ◽  
Salt Composition ◽  
The Caspian Sea ◽  
Recovery Coefficient ◽  
Hydrogeological Characteristics

Hydrogeological conditions of reservoir waters of oil and gas fields in the northern water area of the Caspian Sea characterize the geological features of the structure of the Northern Caspian shelf, as well as the thermodynamic parameters of the exploitation of productive deposits, production and transportation of oil and gas. Reservoir waters contain water-soluble gases. According to the size of mineralization, the ratio of the main components of the salt composition, as well as the presence of iodine and bromine, reservoir waters can be attributed to a relatively "young" genetic age, subject to secondary geochemical processes of changing the salt composition in interaction with "secondary" migrated hydrocarbons. The physical and chemical properties of reservoir waters are determined by PVT analysis technologies. Hydrogeological and geochemical studies of compatibility with reservoir waters of marine waters injected to maintain reservoir pressures (PPD) during the development of offshore fields in order to increase the oil recovery coefficient (KIN) indicate the absence of colmating secondary sedimentation in mixtures of natural and man-made waters.

scholarly journals ASSESSMENT OF THE OIL AND GAS POTENTIAL PROSPECTS OF THE NEOKOMIAN SEDIMENTS IN THE JOINT ZONE OF THE GYDAN, YAMAL AND NADYM-PURPEY OIL AND GAS BEARING REGIONS OF WESTERN SIBERIA ON THE BASIS OF 3D SEISMIC SURVEY

2021 ◽  
Vol 2 (1) ◽  
pp. 8-14
Author(s):  
Vladimir N. Borodkin ◽  
Oleg A. Smirnov
Keyword(s):  
Western Siberia ◽  
Oil And Gas ◽  
Seismic Facies ◽  
Seismic Survey ◽  
3D Seismic ◽  
Geological Modeling ◽  
Joint Zone ◽  
Water Zone ◽  
Gas Potential ◽  
Gas Bearing

The article presents a brief overview of the views on the stratification of the section of the neocomian deposits. As a basis for geological modeling, instead of formation units, seismic facies complexes were taken, including reservoirs in the coastal shallow-water zone, in a relatively deep-water zone - isochronous clinoform formations of the achimov strata. Within the researched territory, the characteristic of the established oil and gas potential of the complex is presented, on the basis of 3D seismic survey, perspective objects are identified, and their seismogeological characteristics are given.

scholarly journals Factors Controlling Natural Gas Accumulation in the Southern Margin of Junggar Basin and Potential Exploration Targets

2021 ◽  
Vol 9 ◽  
Author(s):  
Jianping Chen ◽  
Xulong Wang ◽  
Yongge Sun ◽  
Yunyan Ni ◽  
Baoli Xiang ◽  
...  
Keyword(s):  
Natural Gas ◽  
Tarim Basin ◽  
Oil And Gas ◽  
Junggar Basin ◽  
Petroleum System ◽  
Source Rocks ◽  
Gas Generation ◽  
Kuqa Depression ◽  
Gas Accumulation ◽  
Southern Margin

In this paper, factors controlling natural gas accumulation in the southern margin of Junggar Basin were mainly discussed by a comparison with natural gas generation and accumulation in the Kuqa Depression of Tarim Basin. The southern margin of Junggar Basin and the Kuqa Depression of Tarim Basin are located on the north and south sides of the Tianshan Mountains respectively, and they share the similar sedimentary stratigraphy and tectonic evolution history. In recent several decades, many large gas fields have been found in the Kuqa Depression of Tarim Basin, but no great breakthrough in the southern margin of Junggar Basin. Our results suggest that natural gas in the southern margin of Junggar Basin is mainly thermogenic wet gas, and can be divided into three types as coal-derived gas, mixed gas and oil-associated gas, of which the former two types are dominated. The Jurassic coal measures are the main source rocks of natural gas, and the main gas generation time from this set of source rocks matched well with the formation time of the anticline structures, resulting in favorable conditions for natural gas accumulation. In the western part of the southern margin in the Junggar Basin, the Permian lacustrine and the Upper Triassic lacustrine-swamp source rocks could be important sources of natural gas, and the main gas generation time also matched well with the formation time of traps. Compared with the Kuqa Depression of Tarim Basin, natural gas sources are better in the southern margin of Junggar Basin, and the geologic conditions are favorable for the formation of large oil and gas fields in the southern margin of Junggar Basin. The deep Permian-Jurassic-Cretaceous petroleum system is the most favorable petroleum system for natural gas exploration in the southern margin of Junggar Basin. The western part and the central part of the southern margin in the Junggar Basin could be the first targets for the discovery of the Jurassic coal-derived oil and gas reservoirs. The shallow Cretaceous-Neogene petroleum system is the second target for natural gas exploration.

GEOLOGICAL STRUCTURE AND OIL AND GAS POTENTIAL OF THE PRE-JURASSIC DEPOSITS OF THECENTRAL PART OF THE WEST SIBERIAN PLATE

2017 ◽  
pp. 58-66 ◽  
Author(s):  
A. B. Tugareva ◽  
G. A. Chernova ◽  
N. P. Yakovleva ◽  
M. L. Moroz
Keyword(s):  
Oil And Gas ◽  
Geological Structure ◽  
The West ◽  
Reservoir Rocks ◽  
Gas Accumulation ◽  
Basement Rocks ◽  
Middle Paleozoic ◽  
Gas Potential ◽  
Gas Bearing

In the presented work the features of the geological structure and oil and gas potential of the pre-Jurassic basement rocks are discussed. In the sediments of the oil and gas bearing horizon of zone of contact five types of reservoir rocks are distinguished. The greatest prospects for oil and gas potential are associated with the carbonate depositions of the Middle Paleozoic and effusive of the medium-acidic composition of the Permian-Triassic and Triassic age. From these deposits in the territory of the district the maximum oil inflows were received. 15 promising zones of oil and gas accumulation in the deposits of the oil and gas bearing horizon of zone of contact were distinguished, three of which are poorly studied by drilling and one zone (Predeniseyskaya) is in the Paleozoic oil and gas complex.

Keeping Net Cash Flow Alive for a Petroleum Exploration Project: Risk Analysis Approach

2010 ◽  
Author(s):  
Hadi Belhaj ◽  
Mohamad Haroun ◽  
Terry Lay
Keyword(s):  
Risk Analysis ◽  
Cash Flow ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Unit Price ◽  
Petroleum Exploration ◽  
Analysis Approach ◽  
Cost Category ◽  
Risk Parameters ◽  
The Impact

Meaningful risk analysis can be a tedious task to perform for many reasons, yet extremely rewarding. Lack of information, uncertainty surrounding risk parameters and their distributions, failure to define proper correlations relating some risk parameters, inappropriate selection of risk analysis criterion and misinterpretation of results are among these reasons. Risking net cash flow (NCF), through traditionally approaches can be a leap of faith. Rather, NCF should be treated with more subjectivity and in-depth understanding of all risk parameters and their interrelationships. Current practice of risk management in the petroleum industry adopts schemes that aim at separating risk into two main categories to understand, simplify, analyze, and evaluate existing contingencies. Commonly, the first category is referred to as subsurface risk that includes resource size, production rate, and access cost. Category two is surface risk that demonstrates total expenditure, facilities delivery, delays, performance, oil/gas prices, etc. Risk analysis of each is normally performed alone. Our study shows that separating risks for an investment with a singular outcome is misleading and extremely dangerous. In this paper, we introduce comprehensive criteria for handling risk associated with oil and gas exploration as well as development of mature reservoirs through EOR and IOR that involves large cash expenditures for; in-fill drilling, waterflooding, gas injection, and thermal and chemical treatment of heavy oil recovery. Basically, one or a combined uncertainty of these elements may create “business risk” that may cause “business impact”. The impact can be positive leading to “business opportunity” or negative leading to “business threat”. Also, instead of risking NCF using risk parameters like gross revenue that consists of hydrocarbon in-place and unit price of oil and gas, and net expenditure (CAPEX and OPEX) by simply defining their risk distributions and parameters, our approach breaks down each risk parameter to sub-parameters, then risk components and finally risk fragments. This produces a break-down model of risk analysis approach by including all parameters with no stage separation that avoids risk of poor assumptions. Hence, risk parameters are simplified by evaluating specific distributions. Case study involving one major Gulf States oil reservoirs is used to demonstrate the approach presented in this paper. Results show great improvement of results as compared to the traditionally used method.

scholarly journals On the question of creation of secondary porousity in large-depth sediments of the south-east of the Dneprovsk-Donetsk depression

2020 ◽  
Keyword(s):  
Oil And Gas ◽  
Practical Importance ◽  
Specific Power ◽  
Deep Zone ◽  
Porosity Formation ◽  
Secondary Porosity ◽  
Power Sources ◽  
Gas Accumulation ◽  
Gas Potential ◽  
Indicator Minerals

Introduction. Currently, most researchers associate the main prospects of oil and gas potential with great depths. The most important component of the problem of oil and gas potential at great depths is the problem of reservoir availability. This problem still has no clear solution. From the point of view of the classical theory of stadial catagenesis, with depth, the primary porosity naturally and irreversibly decreases, and we can only talk about how quickly this happens. In this case, large depths appear to be a zone of fading oil and gas potential without any special prospects. The theory of superimposed catagenesis comes to the rescue, which shows that there are processes that naturally lead to the formation of secondary porosity, a secondary reservoir, and then large depths represent a special deep zone of gas accumulation. According to the views of many researchers, including the authors of this work, quartz sandstones with regenerative quartz cement – quartzite sandstones - are the most promising in terms of reservoir properties at great depths. The aim of the work is to establish the regularities of compaction of quartzite sandstones with depth, to identify anomalies in the compaction process and to try to interpret them using mineral indicators of hypogenic-allogeneic porosity formation – one of the varieties of superimposed catagenesis of great depths. Previous study. The theory of metasomatic reservoir formation as a result of hypogenic-allogeneic porosity formation is one of the most developed. It is based on the penetration of a certain favorable composition of deep aggressive fluids into the reservoir during the period of tectonic-magmatic activation with leaching of some components and deposition of others. It is assumed that this process is accompanied by the crystallization of certain indicator minerals. Result of work. The graphs constructed in the course of this work reflect both a natural change in the porosity of this type of Sandstone with depth, and show an anomaly associated with some superimposed process that allows for different explanations. It is natural to use indicator minerals to solve the problem, but the analysis shows that specific indicator minerals of hypogenic-allogeneic decompression have not yet been found, and all the minerals involved can be interpreted as minerals of one of the stages of stadial catagenesis. This does not disprove the possibility of the formation of a secondary metasomatic reservoir by the above mechanism, but it is not possible to prove its implementation by the indicator minerals noted in the studied samples. Relevance. The question of the formation of secondary porosity is of great practical importance for assessing the prospects of gas content: either large depths are represented by the area of naturally decreasing gas accumulation, or the area of naturally occurring secondary reservoirs with good oil and gas prospects, which can be distinguished as a separate deep zone with its own specific power sources, reservoirs and cap rocks.

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