scholarly journals Seismic Sequence Stratigraphic Sub-Division Using Well Logs and Seismic Data of Taranaki Basin, New Zealand

2021 ◽  
Vol 11 (3) ◽  
pp. 1226
Author(s):  
Abd Al-Salam Al-Masgari ◽  
Mohamed Elsaadany ◽  
Abdul Halim Abdul Latiff ◽  
Maman Hermana ◽  
Umar Bin Hamzah ◽  
...  
Keyword(s):  
Sequence Stratigraphy ◽  
Seismic Data ◽  
Depositional Environment ◽  
Seismic Facies ◽  
Well Logs ◽  
Seismic Section ◽  
Sequence Stratigraphic ◽  
New Perspective ◽  
Potential Traps ◽  
Bottom To Top

This study focuses on the sequence stratigraphy and the dominated seismic facies in the Central Taranaki basin. Four regional seismic sequences namely SEQ4 to SEQ1 from bottom to top and four boundaries representing unconformities namely H4 to H1 from bottom to top have been traced based on the reflection terminations. This was validated using well logs information. An onlapping feature on the seismic section indicates a new perspective surface separated between the upper and lower Giant formation, which indicates a period of seawater encroachment. This study focused extensively on deposition units from SEQ4 to SEQ1. The seismic facies, isochron map, and depositional environment were determined, and the system tract was established. This study was also able to propose a new perspective sequence stratigraphy framework of the basin and probable hydrocarbon accumulations and from the general geological aspect, SA-Middle Giant Formation (SEQ3) could act as potential traps.

Integrating Wireline Logs and Seismic Data to Analyse The Facies snd Paleogeography of Tanjung Formation, Barito Basin, South Kalimantan

2020 ◽  
Author(s):  
E. A. Rosa
Keyword(s):  
Sequence Stratigraphy ◽  
Seismic Data ◽  
Depositional Environment ◽  
Well Logs ◽  
Facies Distribution ◽  
Sequence Stratigraphic ◽  
Core Data ◽  
Wireline Logs ◽  
Depositional Models

The study area is physiographically part of the Barito Basin, South Kalimantan (Van Bemmelen, 1949). 2D seismic data along with well logs from three wells, biostratigraphy data from two wells, and core data are utilized to do an integrated sequence stratigraphy. Petrography data from the equivalent formation at well-X from the study area is also used to support the evaluation. This study was to determine lithology facies and depositional environment based on several key maps: Sand Shale Ratio (SSR), Isopach, and Paleogeographic Maps. After that, seismically-supported sequence stratigraphy was applied to vertically and laterally subdivide the facies distribution and paleogeography into two depositional models based on the following key sequence-stratigraphic markers: (1) Sequence Boundary (SB)-1 to SB-2 that show regressive succession, and (2) SB-2 to Top Tanjung Formation that reflects transgressive phase.

scholarly journals Sequence Stratigraphic Modeling of the Lower Thamama Group, East Onshore Abu Dhabi, United Arab Emirates

GeoArabia ◽  
1997 ◽  
Vol 2 (2) ◽  
pp. 179-202 ◽  
Author(s):  
Sabah K. Aziz ◽  
Mohamed M. Abd El-Sattar
Keyword(s):  
United Arab Emirates ◽  
Seismic Data ◽  
Depositional Environment ◽  
High Energy ◽  
Source Rocks ◽  
Abu Dhabi ◽  
Sequence Stratigraphic ◽  
Reservoir Development ◽  
Energy Environment ◽  
Exploration Activity

ABSTRACT The Lower Cretaceous (Berriasian to Valanginian) Habshan Formation (Lower Thamama Group) of Abu Dhabi was deposited on a broad carbonate shelf. In east onshore Abu Dhabi, the Habshan Formation consists mainly of limestone and dolomite reaching a thickness of more than 1,100 feet. The depositional environment ranged from shallow-water peritidal to deeper shelf basin. The integration of seismic-stratigraphic, biostratigraphic, lithostratigraphic and electric log data reveals three sequences (I to III) and three shelf edges within the Habshan Formation in east onshore Abu Dhabi. These high energy shelfal sediments prograde toward the basin to the east and northeast with their shelf edges trending north-northwest to south-southeast. The seismic data indicates that the basin was filled in the east during the Hauterivian, after the deposition of Sequence IV (equivalent to the Zakum formation). Good reservoir development is found in the carbonates deposited in the high energy environment along the shelf edge of the Habshan sequence, particularly within the oblique and sigmoidal clinoforms, whereas potential source rocks are expected to be developed basinward. This combination renders the Habshan and Zakum sequences an attractive exploration target, both as structural and stratigraphic traps. Recent exploration activity in the area established the presence of hydrocarbons within the Habshan Sequence III in east onshore Abu Dhabi.

DEPOSITIONAL SEQUENCE OF THE WITHNELL FORMATION, DAMPIER SUB-BASIN

1995 ◽  
Vol 35 (1) ◽  
pp. 296
Author(s):  
J. S. Rasidi
Keyword(s):  
Late Cretaceous ◽  
Seismic Data ◽  
Depositional Environment ◽  
Thickness Distribution ◽  
Well Logs ◽  
Hydrocarbon Potential ◽  
Depositional Sequence ◽  
Well Data ◽  
Water Depths ◽  
Reservoir Facies

The Late Cretaceous Withnell Formation has attracted very little exploration attention because of the perception that it has poor hydrocarbon potential. This unfavourable perception has arisen from the fact that very little is known about its depositional environment and lithofacies and therefore, its petroleum prospectivity.A sudden fall of relative sea level occurred at the end of the Santonian, and was followed by the deposition of the siliciclastic Withnell Formation. The occurrence of a number of channels and canyons at the base of the formation, over the old shelf and slope on the southern margin of the sub-basin, supports the hypothesis that the Withnell Formation began as a lowstand systems tract. The thickness distribution of the formation and the progradation direction of seismic packages suggest a southeasterly provenance. Correlation of seismic data and well logs, and rock descriptions demonstrate the presence of units deposited during increasing water depths and subsequent highstand systems tract.Much more information, both seismic and well data, is required to establish the facies distribution within the Withnell Formation which may contain sand-prone lowstand facies such as basinfloor or slope fans. The presence of such reservoir facies would enhance the petroleum prospectivity of the Withnell Formation.

scholarly journals Transition zones analysis using empirical capillary pressure model from well logs and 3D seismic data on ‘Stephs’ field, onshore, Niger Delta, Nigeria

2019 ◽  
Vol 10 (3) ◽  
pp. 1227-1242
Author(s):  
O. Abiola ◽  
F. O. Obasuyi
Keyword(s):  
Capillary Pressure ◽  
Seismic Data ◽  
Niger Delta ◽  
Time Structure ◽  
Well Logs ◽  
3D Seismic ◽  
Seismic Section ◽  
Transition Zones ◽  
Mobile Water ◽  
3D Seismic Data

AbstractCapillary pressure is an important characteristic that indicates the zones of interaction between two-phase fluids or fluid and rock occurring in the subsurface. The analysis of transition zones (TZs) using Goda (Sam) et al.’s empirical capillary pressure from well logs and 3D seismic data in ‘Stephs’ field, Niger Delta, was carried out to remove the effect of mobile water above the oil–water contact in reservoirs in the absence of core data/information. Two reservoirs (RES B and C) were utilized for this study with net thicknesses (NTG) ranging from 194.14 to 209.08 m. Petrophysical parameters computed from well logs indicate that the reservoirs’ effective porosity ranges from 10 to 30% and the permeability ranges from 100 to > 1000 mD, which are important characteristics of good hydrocarbon bearing zone. Checkshot data were used to tie the well to the seismic section. Faults and horizons were mapped on the seismic section. Time structure maps were generated, and a velocity model was used to convert the time structure maps to its depth equivalent. A total of six faults were mapped, three of which are major growth faults (F1, F4 and F5) and cut across the study area. Reservoir properties were modelled using SIS and SGS. The capillary pressure log, curves and models generated were useful in identifying the impact of mobile water in the reservoir as they show the trend of saturating and interacting fluids. The volume of oil estimated from reservoirs B and C without taking TZ into consideration was 273 × 106 and 406 × 106 mmbbls, respectively, and was found to be higher than the volume of oil estimated from the two reservoirs while taking TZ into consideration which was 242 × 106 and 256 × 106 mmbbls, respectively. The results have indicated the presence of mobile water, which have further established that conventionally recoverable hydrocarbon (RHC) is usually overestimated; hence, TZ analysis has to be performed for enhancing RHC for cost-effective extraction and profit maximization.

DEPOSITIONAL MODELLING OF THE GIPPSLAND BASIN AND THE BARROW-EXMOUTH SUB-BASINS

1994 ◽  
Vol 34 (1) ◽  
pp. 350 ◽  
Author(s):  
Keyu Liu ◽  
Lincoln Paterson ◽  
Feng Xu Jian
Keyword(s):  
Sea Level ◽  
Sequence Stratigraphy ◽  
Seismic Data ◽  
High Frequency ◽  
Sedimentary Facies ◽  
Sediment Supply ◽  
Well Logs ◽  
Tectonic Movement ◽  
Depositional Processes ◽  
Gippsland Basin

SEDPAK is a forward modelling computer program for depositional processes developed by the University of South Carolina's StratMod Group. It simulates the geometry of generalised lithofacies in a sedimentary sequence or a basin by considering principally four major geological variables: eustatic sea level, tectonic movement, sediment accumulation, and initial and evolving basin surfaces.Based on seismic data, well logs and other information from drill holes, the geometries of sedimentary sequences of the Gippsland Basin and the Barrow-Exmouth Sub-basins have been successfully reproduced on both basin and reservoir scales using SEDPAK 3.12. The simulation results indicate that eustacy, tectonics, sediment input and basin physiography can be equally important in controlling the geometry of strata and basin architecture. However, some differences exist: (1) tectonic movement normally contributes to long-term variations of the first order (megasequence) basin architecture and configuration; (2) the second order (sequence) basin architecture and stratal geometry can be controlled by either sediment supply, eustacy, tectonism or a combination; and (3) high frequency facies variations and stratal geometry within individual sequences are primarily controlled by eustatic sea level variations and basin physiography.This study has demonstrated that SEDPAK is a useful tool for reconstruction of basin evolution histories and for reservoir characterisation. It can also be used to predict sedimentary facies in undrilled exploration frontier areas. In addition, it can be used to address some critical assumptions and problems in the sequence stratigraphy concept. SEDPAK is particularly useful in the study of high frequency sequence stratigraphy and cyclicity, where various sequence or parasequence bounding surfaces and internal geometry can not be easily recognised from seismic data, well logs and outcrops.

Detailed quantitative sequence stratigraphic interpretation for the characterization of Amangi field using seismic data and well logs

2021 ◽  
Vol 19 (3) ◽  
pp. 63-82
Author(s):  
S. Inichinbia ◽  
Halidu Hamza
Keyword(s):  
Seismic Data ◽  
Gamma Ray ◽  
Hydrocarbon Exploration ◽  
Well Logs ◽  
Rock Properties ◽  
Sequence Stratigraphic ◽  
Resistivity Logs ◽  
Hydrocarbon Saturation ◽  
Shaly Sand ◽  
Net To Gross

The sequence stratigraphy of Amangi field of the Niger Delta was studied using seismic data and well logs. The field is a structurally  complex one and presents serious challenges to hydrocarbon exploration and production. The main objective of these analyses is to  identify sand intervals using the available data. Well log data were used as additional tools to constrain the seismic correlations in order to solve the correlation problem. The well logs were evaluated for the field’s petrophysical properties by combining the gamma ray and resistivity logs to determine reservoir zones with considerable hydrocarbon saturation. Also, the relationship between some basic rock properties/attributes and litho-types were determined for the study area. Next, well-to-seismic ties were produced and two horizons were picked. Acoustic impedance inversion was also performed which revealed “hard sands” due to mixed lithologies (heterolithics). This made it difficult to discriminate the sands from shales in the P-impedance domain alone. So, progress was made to determine the net-to-gross of the field. The analysis revealed that these reservoirs have shaly sand with shale content of 10%, porosity averaging 21%, and hydrocarbon saturation of 90%. The result established a vertical stack of a series of reservoirs in an anticlinal structure of which the H1000 and H4000 stand out for their huge volumes of rich gas condensate accumulation. This discovery provoked the drive for the first phase of development of this field. Keywords: stratigraphy, facies, net-to-gross, horizon, lithology, well-to-seismic tie, impedance

Decoupling of seismic reflectors and stratigraphic timelines: A modeling study of Tertiary strata from Svalbard

Geophysics ◽  
2007 ◽  
Vol 72 (5) ◽  
pp. SM273-SM280 ◽  
Author(s):  
Ståle Johansen ◽  
Espen Granberg ◽  
Donatella Mellere ◽  
Børge Arntsen ◽  
Torben Olsen
Keyword(s):  
Seismic Data ◽  
Low Frequency ◽  
Ground Control ◽  
Seismic Section ◽  
Sequence Stratigraphic ◽  
Fundamental Assumption ◽  
Geologic Model ◽  
Seismic Sections ◽  
High Level ◽  
Seismic Reflectors

In sequence stratigraphic interpretations, the key premise is that stratal surfaces effectively represent geologic timelines. When applied to seismic sections, the fundamental assumption is that primary reflections generally mimic stratigraphic timelines. The main objective of this study was to test how well key reflectors in a seismic section couple to timelines. To achieve the high level of ground control needed for such testing, we combined photogrammetry and traditional sedimentologic fieldwork to optimize the geologic model. We relied further on petrophysical analysis to derive a numerical model suitable for the simulation of seismic data. In spite of laterally discontinuous vertical-impedance contrasts (VICs), false seismic continuity was created, and we observed frequent decoupling of seismic reflectors and stratigraphic timelines. These observations demonstrate how the low-frequency seismic method fails to image normal complexity in a stratigraphic unit. A seismic correlation test showed that the interpreters made numerous mistakes and that such mistakes are very difficult to avoid. The failure of a fundamental assumption, as illustrated here, creates serious problems for the sequence stratigraphic concept when applied to detailed correlation analysis on seismic sections.

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