Creation of Geological 3D-Model of Komyshnianske Field Based on the Sequence Stratigraphy Principles

2021 ◽  
Author(s):  
Oleksii Viktorovych Noskov ◽  
Serhii Mykhailovych Levoniuk ◽  
Mykyta Leonidovych Myrontsov
Keyword(s):  
Sequence Stratigraphy ◽  
3D Model ◽  
Gas Condensate ◽  
Seismic Survey ◽  
3D Seismic ◽  
Reservoir Properties ◽  
New Approach ◽  
Sequence Stratigraphic ◽  
Seismic Resolution ◽  
Sedimentation Conditions

Abstract Currently, the sequence-stratigraphic section dismemberment is only being implemented in Ukraine, so this article is highly relevant. The authors created geological 3D model of Komyshnianske gas condensate field based on sequence-stratigraphic section dismemberment for the first time at this area. This approach is effective for the following conditions:-insufficient field geological study;-thickness of productive horizons does not reach the seismic resolution boundaries;-no significant difference in impedance values on reflection horizons. The selected technique includes the following stages:-field geological study, facies analysis (integration of well geophysical complexes, cores);-deduction and correlation of sequence boundaries;-construction of discrete log, which corresponds to specific sequences distribution;-conducting seismic interpretation of the 3D seismic survey study of research area;-construction of a structural framework with the involvement of correlated sequences boundaries;-comparison of volume seismic attributes with selected sequences distribution. A geological 3D model of Komyshnianske gas condensate field was created based on sequence-stratigraphic principles. During the research, a geological structure of field was analyzed, the separated conditions of sedimentation (sequences) were deducted and interpreted. During the seismic interpretation of 3D seismic survey of study area, local features of wave field were identified, their reflection in the core material was found and linked to the concept of changing sedimentation conditions. With a general understanding of the material transportation and accommodation direction, used method allows to qualitatively outline the distribution boundaries of sedimentation certain conditions and predict their development outside the study area. Construction of facies discrete log and their distribution in the seismic field allows grouping thin bed layers of collectors to reach the seismic resolution and use them to predict the distribution of facies associated with changes in the rocks reservoir properties (tracking beach facies of deltas/avandeltas, sloping sediments, etc.). The constructed model could be used as a trend for reservoir distribution at the stage of construction of static geological model. Involvement of sequence-stratigraphy technique is new approach to sedimentation conditions study within Dnipro-Donetsk depression (DDD) areas. The paper shows that provided methodology gives:-improved geological understanding of field through sedimentation analysis and facies logging;-trends for reservoir properties distribution with the involvement of construction facies volumes;-proposals for further field E&D. The general provisions under conditions of geological materials sufficient base can be applied to other DDD areas, especially in pre-border zones. Involvement of sequence-stratigraphy technique is new approach for sedimentation conditions study within Dnipro-Donetsk depression (DDD) area. On the example of Komyshnianske gas condensate field, the article shows that provided methodology gives:-improved geological understanding of field through sedimentation analysis and facies logging;-trends for reservoir properties propagation with the involvement of seismic volume studies;-propositions for further field Exploration & Development.

Exploring for stratigraphic traps in the Patchawarra Formation, Cooper Basin: an integrated seismic methodology

2018 ◽  
Vol 58 (2) ◽  
pp. 779
Author(s):  
Alexandra Bennett
Keyword(s):  
Complex Geometry ◽  
Imaging Techniques ◽  
South Australia ◽  
Seismic Interpretation ◽  
Seismic Survey ◽  
3D Seismic ◽  
Seismic Resolution ◽  
Seismic Reflectivity ◽  
Seismic Area ◽  
Cooper Basin

The Patchawarra Formation is characterised by Permian aged fluvial sediments. The conventional hydrocarbon play lies within fluvial sandstones, attributed to point bar deposits and splays, that are typically overlain by floodbank deposits of shales, mudstones and coals. The nature of the deposition of these sands has resulted in the discovery of stratigraphic traps across the Western Flank of the Cooper Basin, South Australia. Various seismic techniques are being used to search for and identify these traps. High seismic reflectivity of the coals with the low reflectivity of the relatively thin sands, often below seismic resolution, masks a reservoir response. These factors, combined with complex geometry of these reservoirs, prove a difficult play to image and interpret. Standard seismic interpretation has proven challenging when attempting to map fluvial sands. Active project examples within a 196 km2 3D seismic survey detail an evolving seismic interpretation methodology, which is being used to improve the delineation of potential stratigraphic traps. This involves an integration of seismic processing, package mapping, seismic attributes and imaging techniques. The integrated seismic interpretation methodology has proven to be a successful approach in the discovery of stratigraphic and structural-stratigraphic combination traps in parts of the Cooper Basin and is being used to extend the play northwards into the 3D seismic area discussed.

TOWARDS AN EFFICIENT EXPLORATION FRONTIER: CONSTRUCTING A PORTFOLIO OF STRATIGRAPHIC TRAPS IN FLUVIAL-LACUSTRINE SUCCESSIONS, COOPER-EROMANGA BASIN

2002 ◽  
Vol 42 (1) ◽  
pp. 131
Author(s):  
T. Nakanishi ◽  
S.C. Lang
Keyword(s):  
Net Present Value ◽  
Spatial Arrangement ◽  
Mean Value ◽  
Seismic Survey ◽  
3D Seismic ◽  
Sequence Stratigraphic ◽  
Depositional Systems ◽  
Efficient Exploration ◽  
3D Seismic Data ◽  
Eromanga Basin

In the Cooper-Eromanga Basin, the future of exploration lies in identifying an appropriate exploration portfolio consisting of stratigraphic traps in structurally low or flank areas. A variety of stratigraphic trap prospects in the Moorari and Pondrinie 3D seismic survey areas are identified in the Patchawarra, Epsilon, Toolachee and Poolowanna formations. To identify the stratigraphic traps, an integration of sequence stratigraphic concepts applied to non-marine basins and advanced 3D seismic data visualisation was employed. This paper focusses on estimating the chance of geologic success and the probabilistic reserves size for each prospect within its sequence stratigraphic context (lowstand, transgressive or highstand systems tracts). The geologic chance factors for an effective stratigraphic trap include reservoir, top seal, lateral seal and bottom seal within each depositional systems tract, the seal effectiveness of the adjacent depositional systems tracts and the appropriate spatial arrangement of these factors. The confidence values for the existence of geologic chance factors were estimated according to the distributions of the possible reservoir and seal rocks within each genetic-stratigraphic interval and the chance of geologic success of each prospect was calculated. For probabilistic reserves estimation, geologically reasonable ranges were estimated for each parameter employing Monte Carlo simulation to calculate the reserves distribution. When a series of possible exploration portfolios, including single or multiple prospects from the prospect inventory are plotted in terms of the chance of geologic success vs. the mean value of the reserves estimate, an efficient exploration frontier emerges. The portfolio candidates on the efficient exploration frontier were assessed with regard to chance of economic success and expected net present value (ENPV) using a simple cash flow model. The results indicate that appropriate portfolios include multiple prospect exploration especially with lowstand systems tract plays using single or multiple exploration wells. The portfolio construction approach for stratigraphic trap exploration should ultimately be made consistent with conventional play types, to enable an assessment of all exploration opportunities.

Porosity estimation and characterization of a geothermal carbonate reservoir in the South German Molasse Basin based on seismic inversion and attribute analysis

2021 ◽  
Author(s):  
Sonja Wadas ◽  
Hartwig von Hartmann
Keyword(s):  
Structural Information ◽  
Hanging Wall ◽  
Seismic Inversion ◽  
Middle Part ◽  
Seismic Survey ◽  
Molasse Basin ◽  
3D Seismic ◽  
Reservoir Properties ◽  
Attribute Analysis ◽  
Geothermal Potential

<p>The Molasse Basin is one of the most promising areas for deep geothermal exploration in Germany and a very ambitious project in this region is to power the entire district heating system of the city of Munich with renewable energies by 2040; a major part of this will consist of geothermal energy. As part of a joint project (financed by the German Federal Ministry For Economic Affairs And Energy; FKZ 0324332B) the Leibniz Institute for Applied Geophysics (LIAG) works together with the Munich City Utilities (Stadtwerke München), to improve reservoir characterization and sustainable reservoir exploration within the German Molasse Basin. The target horizon for hydrothermal exploration is the aquifer in the Upper Jurassic carbonates. A major problem is the strong heterogeneity of the carbonates. Compared to quantity and quality of the structural data of the reservoir, the database of reservoir properties such as density, porosity and permeability, which describe the geothermal potential, is insufficient. Therefore, it is necessary to generate such data in order to improve the value of the structural information. A 3D seismic survey cannot only provide structural information, but also important reservoir properties such as elastic parameters and seismic attributes. One of the most important attributes is the acoustic impedance, which can be determined with a seismic inversion and used to estimate a porosity volume.</p><p>The data basis for this study was the 170km² GRAME-3D seismic survey measured in Munich, a structural geological model, and drilling and logging data from the geothermal site “Schäftlarnstraße”.</p><p>The inversion results show low impedance values at the top of the reservoir, but also at the middle part. Spatially, the intermediate block of the Munich fault shows low values but also the eastern part of the hanging wall block and the western part of the footwall block. Based on a well correlation a relationship between acoustic impedance and porosity could be determined and a 3D porosity volume was calculated. In the upper part but also in the middle part of the reservoir areas with increased porosity (>10%) are shown, which might indicate a high geothermal potential.</p><p>For a better classification, an attribute analysis was performed. The intermediate block and the eastern part of the hanging wall block show strongly fractured rocks. In contrast, there are hardly any conspicuous features in the western part of the footwall block, although high porosities are also expected here. This suggests that the presence of faults is not the only factor favoring high porosities in carbonates. More likely is a combination with karstification processes, which is why even areas that do not show enhanced tectonic deformation have high porosities.</p>

scholarly journals Identification of Osinsky horizon organogenic structures by 2D and 3D seismic survey data in the north-eastern part of the Nepa-Botuoba anteclise

2021 ◽  
Vol 44 (1) ◽  
pp. 30-38
Author(s):  
R. S. Urenko ◽  
A. G. Vakhromeev
Keyword(s):  
Survey Data ◽  
Lower Cambrian ◽  
Seismic Survey ◽  
3D Seismic ◽  
Reservoir Properties ◽  
The North ◽  
Loose Packing ◽  
North Eastern ◽  
2D And 3D ◽  
North Eastern Part

The fields of Eastern Siberia belong to the one of the main centers of hydrocarbon production in the eastern part of Russia. The main part of hydrocarbon reserves is located in the area within the Nepa-Botuoba anteclise, where the Lower Cambrian deposits are major production objects. The main purpose of this research is to provide a detailed study of the inner space and features of organogenic structures of the Cambrian period, as well as to determine the procedures for detecting reef structures by seismic research methods. Statistical processing of the available factual material on reservoir properties has shown a very uneven distribution of cavernosity (porosity). It is found that pores were formed as a result of leaching of shaped formations in loose packing locations of epigenetic dolomite grains, along the cementing substance in the intergranular spaces, along cracks and stylolite seams. To identify organogenic structures in the Osinsky horizon of the Nepa-Botuoba anteclise on the basis of seismic studies some additional methodologies have been selected. Identification of single reef structures in the Osinsky horizon of the Lower Cambrian based on the analysis of seismic amplitudes was carried out by means of a 2D and 3D seismic survey. According to the data of seismic studies, the Nepa-Botuoba anteclise features the development zones of both linear and single carbonate structures. It is also revealed that there is an increase in effective thicknesses in wells located in the annular anomaly. Summing up the results and analyzing the compared materials, it can be concluded that the main identification method of ring zones in wells is the method of longitudinal wave slowness measurement. A comprehensive analysis of 2D and 3D seismic survey data by the common depth point method as well as by a number of other methods using a specific algorithm allowed us to identify individual formations of organogenic (riphogenic) structures in the carbonate section of the north-eastern part of the Nepa-Botuoba anteclise.

Geological justification for increasing the efficiency of development of deposits of hard-to-recover oil reserves in the collectors of the Tyumen arch of the Surgut (Western Siberia)

2020 ◽  
pp. 8-19
Author(s):  
S. R. Bembel ◽  
R. V. Avershin ◽  
R. M. Bembel ◽  
V. I. Kislukhin
Keyword(s):  
Geological Structure ◽  
Seismic Survey ◽  
Well Testing ◽  
3D Seismic ◽  
Data Sampling ◽  
River Channels ◽  
Reservoir Properties ◽  
Oil Reserves ◽  
Effective Development ◽  
Low Permeability Reservoirs

The article deals with the results of studies of the geological structure features of the US2 oil-bearing stratum in the upper part of Tyumen suite (a case study of the Surgut arch fields). Object US2 is represented by low-permeability reservoirs with complex facies variability and an uneven distribution of reservoir properties over area and section, characterized by a thin-layered structure. In this regard, the oil reserves of the US2 structure are naturally classified as hard-torecover, requiring additional work to further study its structure and features for effective development of oil reserves. The facies of river channels, riverbank shoals and sands of floodplain spills were identified, based on the analysis of geological and geophysical materials: 3D seismic survey, core studies, well testing data, sampling and dynamics of wells operation in the area of the deposits in the upper part of the US2 horizon. Based on the analysis of the detailed correlation, three types of section of the US2/1 formation were identified, differing in the nature of the reservoir spread. Based on the 3D seismic survey data, in order to clarify the structure of the US2 formation, a dynamic analysis of the attributes of the seismic record was carried out. Significant coefficients of cross-correlation between the dynamic characteristics and production parameters of the US2/1 formation were not obtained. It is necessary to develop optimal methods for exploration and clarification of the features of the geological structure and forecasting the distribution of reservoir properties, rational methods and approaches to the development of hard-to-recover reserves of Tyumen suite objects with a complex distribution of reservoir properties and variability of productive thicknesses.

scholarly journals Integrated reservoir characterization based on a comprehensive study of the geological structure using 3D seismic survey

2021 ◽  
Vol 266 ◽  
pp. 07009
Author(s):  
A.K. Zhumabekov ◽  
V.S. Portnov ◽  
L. Zhen
Keyword(s):  
Reservoir Characterization ◽  
Seismic Signal ◽  
Geological Structure ◽  
Point Of View ◽  
Oil Field ◽  
Seismic Survey ◽  
3D Seismic ◽  
Reservoir Properties ◽  
Sedimentation Environment ◽  
Analysis Of Results

The 3D seismic survey is the undisputed leader among tools of identifying potential exploration targets and reservoir characterization. This paper shows surveys that are crucial in the exploration and development of significant amounts of hydrocarbon resources, and enables operator companies to map complex geological structures and select better drilling locations. The purpose of the research is to have better understandings of formations and update previous studies in the oil field of Mangyshlak Basin, Western Kazakhstan. The Main results are the acoustic impedance, Vp/Vs ratio, lithological and reservoir properties data. The quality controls and analysis of results show a good match with well logs and good recovery of seismic signal in inversion, but it should be improved in some areas. The results, from a scientific point of view, expand the already known geological and geophysical studies of the reservoir and improve the quality of interpretation using seismic methods in studying the sedimentation environment.

scholarly journals Mid-Turonian–early Campanian sequence stratigraphy of northeast Iraq

GeoArabia ◽  
2007 ◽  
Vol 12 (2) ◽  
pp. 135-176 ◽  
Author(s):  
Sabah Noori Saleem Haddad ◽  
Momtaz Ahmed Amin
Keyword(s):  
Sequence Stratigraphy ◽  
Middle Part ◽  
Normal Faults ◽  
Reservoir Properties ◽  
Third Order ◽  
Sequence Stratigraphic ◽  
Tectonic Model ◽  
Facies Associations ◽  
North Iraq ◽  
Depositional Architecture

ABSTRACT A sequence stratigraphic and tectonic model for the mid-Turonian-early Campanian carbonate sequence in North Iraq was constructed based on subsurface lithologic, thin-section and well-log analyses of ten boreholes. The studied sequence is represented by the Gulneri, Kometan and Mushorah formations in the eastern sector (seven wells) and their correlative Khasib, Tanuma, Sa’adi and lower part of the Hartha formations in the western sector of the study area (three wells). Three second-order sequences (from oldest to youngest A, B and C) were identified. Sequence A consists of two third-order sequences (A1 and A2) and is represented by the mid-Turonian Gulneri Formation. Sequence B consists of three third-order sequences: B1 corresponds to the late Turonian-early Coniacian Khasib Formation and correlative lower part of Kometan Formation. Sequences B2 and B3 are exclusive to the late Coniacian-early Santonian Tanuma Formation and correlative middle part of the Kometan Formation. Sequence C is comprised of three third-order sequences of which C1 and C2 encompass the late Santonian Sa’adi Formation and correlative upper part of the Kometan Formation, while C3 corresponds to the early Campanian Mushorah Formation and correlative lower part of the Hartha Formation. Each of the third-order sequences is comprised of transgressive and highstand systems tracts, while the lowstand systems tract is restricted to sequences B2, B3, C1 and C2. These systems tracts are, in turn, comprised of vertically stacked parasequences of shallowing upward packages. The tectono-depositional model that was deduced from the sequence analysis is characterised by two flat-topped ramps that formed as a consequence of extensional tectonism. Three NW-trending normal faults are interpreted to separate the ramps whose inclined apex was continuously being eroded. The eroded detritus from the apex consists of shallow-marine carbonates that were deposited in basinal sites. Within this structural framework, the ten boreholes are placed within their appropriate depositional sites within the ramp system. Facies analysis demonstrated an array of facies associations, which generally accumulate in basins that are fed by an influx of eroded shallow-water derivatives. The depositional architecture developed in an open-marine, low-energy, middle- to outer-ramp setting in the case of Gulneri and Kometan formations. A middle–inner ramp setting is attributed to the Khasib, Tanuma and the lower part of the Hartha formations. A transition to a slope setting is suggested during the deposition of the Mushorah Formation; whereas slope-apron facies are common to all formations in the well Quwair-2. Diagenetic modification overprinted the carbonates and its effect on reservoir properties is considered. Recognition of third-order cycles demonstrates the utility of using genetic units and sequence stratigraphy to discern the depositional architecture of these formations. Local tectonic influences, which control sedimentation patterns, eustasy and sedimentation rates are additional determinants for the final stratigraphic framework.

Sequence stratigraphy of a mixed siliciclastic-carbonate setting, Scotian Shelf, Canada

2015 ◽  
Vol 3 (2) ◽  
pp. SN21-SN37 ◽  
Author(s):  
Farrukh Qayyum ◽  
Octavian Catuneanu ◽  
Crépin Eric Bouanga
Keyword(s):  
Sequence Stratigraphy ◽  
Seismic Data ◽  
Large Scale ◽  
Second Order ◽  
3D Seismic ◽  
Scotian Shelf ◽  
Sequence Stratigraphic ◽  
Stratigraphic Framework ◽  
3D Seismic Data

During the Jurassic Period, a large-scale carbonate bank (Abenaki Formation) and a siliciclastic (Sable) delta coexisted in North America. Conventionally, carbonate systems (in situ) are separated from siliciclastic systems (transported) because of their contrasting origin. However, we developed a case study to show that the basic principles of sequence stratigraphy remain applicable. We integrated the results obtained from a regional 2D study and a detailed follow-up study using 3D seismic data of the Scotian Shelf, Canada. The results were integrated with the prepared Wheeler diagrams, and a unified sequence stratigraphic framework was proposed. We determined that two second-order sequences were developed on a larger scale during the Jurassic Period. The first sequence developed during the transition from a ramp to rimmed margin. The second sequence developed during the evolution from a rimmed to ramp margin. These sequences formed a distinct stratigraphic style throughout the Scotian Shelf. The siliciclastic supply varied from the northeast to the southwest depending on the studied site; however, the regions close to the siliciclastic supply contained well-defined clinoform patterns. The topsets of such clinoforms were mostly eroded. Their directions were also found to be different than the carbonate-related clinoform geometries. Most of the carbonates were developed; as such, they kept up and prograded toward a backreef margin during the rimming stages. The second-order sequences were further subdivided into four third-order sequences. These were studied using the 3D seismic data and were found to contain several barrier reefs that could have stratigraphic exploration potential in the Penobscot area.

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