Estimation of Reservoir Net Thickness Using Seismic Facies and Well Data in Middle Miocene Incised Valley Deposits of the Oficina FM. Oritupano Area, Eastern Venezuela

2001 ◽  
Author(s):  
C. Azalgara ◽  
M. Floricich
Keyword(s):  
Middle Miocene ◽  
Seismic Facies ◽  
Incised Valley ◽  
Well Data

A REVISED DEPOSITIONAL MODEL FOR EAST SPAR AND ITS IMPACT ON FIELD PERFORMANCE

2002 ◽  
Vol 42 (1) ◽  
pp. 461 ◽  
Author(s):  
N.P. Tupper ◽  
E.F. Tadiar ◽  
D.L. Price ◽  
J.D.S. Goodall
Keyword(s):  
Bottom Water ◽  
Field Performance ◽  
Depositional Model ◽  
Incised Valley ◽  
Water Influx ◽  
Lateral Extent ◽  
Well Data ◽  
Multi Phase ◽  
Regional Aquifer ◽  
Carnarvon Basin

The East Spar gas condensate field is located in production licence WA-13-L in the offshore Carnarvon Basin. Production commenced in 1996 with two subsea wells linked to processing facilities on Varanus Island via a multi-phase pipeline. The pressure performance of the field has been significantly different to predevelopment expectations. This prompted a reexamination of the seismic and well data to investigate the potential for alternative reservoir models.Integrated stratigraphic and seismic interpretation reveals that the Barrow Group reservoir sands were deposited within an incised valley of limited lateral extent. Sea level fall instigated erosion of a valley that on transgression was filled with successive fluvial, estuarine and marine sediments. Good quality sands are expected to be limited to this valley, the upper part of which can be mapped on seismic. Poor sand development in East Spar–2ST is consistent with its location at the edge of the incised valley.Before development, the primary production mechanism was expected to be a strong bottom water drive comparable with other Barrow Group fields in the Carnarvon Basin. The revised depositional model, however, and the observed decline in reservoir pressure, indicate that connection to this regional aquifer is limited. This implies that water influx will probably be later, and ultimate recovery higher, than previously anticipated.

Seismic facies and attribute analysis of the Miocene incised‐valley‐fill and submarine‐canyon systems in Tuxpan Basin, offshore Mexico

2003 ◽  
Author(s):  
Khaled Fouad ◽  
William A. Ambrose ◽  
Frank Brown ◽  
David Jennette ◽  
Mario Aranda ◽  
...  
Keyword(s):  
Submarine Canyon ◽  
Seismic Facies ◽  
Incised Valley ◽  
Valley Fill ◽  
Attribute Analysis

Multivariate statistical analyses applied to seismic facies recognition

Geophysics ◽  
1988 ◽  
Vol 53 (9) ◽  
pp. 1151-1159 ◽  
Author(s):  
Jean Dumay ◽  
Frederique Fournier
Keyword(s):  
Seismic Stratigraphy ◽  
Seismic Facies ◽  
Second Step ◽  
Multivariate Statistical Analyses ◽  
Multivariate Statistical ◽  
Seismic Parameters ◽  
Data Analyses ◽  
Well Data ◽  
Definition Of ◽  
Reservoir Facies

One of the most important goals of seismic stratigraphy is to recognize and analyze seismic facies with regard to the geologic environment. The first problem is to determine which seismic parameters are discriminant for characterizing the facies, then to take into account all those parameters simultaneously. The second problem is to be sure that there is a link between the seismic parameters and the geologic facies we are investigating. This paper presents a methodology for automatic facies recognition based upon two steps. The first, or learning step, begins with the definition of learning seismic traces for each facies we wish to recognize. The choice of learning traces is based upon either well data or a seismic stratigraphic interpretation. A large number of seismic parameters are then computed from the learning traces; multidimensional analyses are carried out in order to validate the choice of learning traces and to select, among all the available parameters, those that discriminate best. At this stage, a modeling step may be carried out to relate the seismic parameters to the geologic features. The second step is a predictive one which allows automatic facies recognition. We compute the previously chosen discriminant parameters on unknown seismic traces and classify the unknown traces with regard to the learning traces. We develop the methodology and successfully apply it to two examples of reservoir facies recognition. Our main conclusion is that seismic traces contain geologic information that can be extracted by multivariate data analyses of a large number of seismic parameters. Automatic facies recognition is reliable and fast; the derived facies map has the great advantage of combining simultaneously several discriminant parameters.

scholarly journals Palaeogeography of a Mid Miocene Turbidite Complex, Moki Formation, Taranaki Basin, New Zealand.

2021 ◽  
Author(s):  
◽  
Sarah Grain
Keyword(s):  
New Zealand ◽  
Sediment Supply ◽  
Seismic Facies ◽  
Meandering Channel ◽  
Progressive Development ◽  
Hydrocarbon Reservoir ◽  
The North ◽  
Basin Floor ◽  
Well Data ◽  
Seismic Reflection Profiles

<p>The Moki Formation, Taranaki Basin, New Zealand, is a Mid Miocene (Late Altonian to Early Lillburnian) sand-rich turbidite complex bounded above and below by the massive bathyal mudstone of the Manganui Formation. The Moki Formation is a proven hydrocarbon reservoir with its stacked, thick, tabular sandstone packages totalling more than 300 m in places. Previous regional studies of the formation have been based primarily on well data and resulted in varying palaeogeographic interpretations. This study, restricted to the southern offshore region of the basin, better constrains the spatial and temporal development of the Moki Formation by combining well data with seismic interpretation to identify key stratal geometries within the sediment package. Nearly 30,000 km of 2D seismic reflection profiles and two 3D surveys, along with data from 18 wells and three cores were reviewed and key sections analysed in detail. Seismic facies have been identified which provide significant insights into the structure, distribution and progressive development of the Moki Formation. These include: a clearly defined eastern limit of the fan complex, thinning and fining of the distal turbidite complex onto the basin floor in the north and west, evidence of fan lobe switching, spectacular meandering channel systems incised into the formation at seismic scales, and the coeval palaeoshelf-slope break in the south east of the basin. In addition, a Latest Lillburnian / Waiauan turbidite complex has been mapped with large feeder, fan and bypassing channels traced. This study presents an improved palaeogeographic interpretation of the Moki Formation and the younger, Latest Lillburnian / Waiauan-aged, turbidite complex. This interpretation shows that during the Late Altonian, sandstone deposition was localised to small fan bodies in the vicinity of Maui-4 to Moki-1 wells. A bathymetric deepening during the Clifdenian is identified, which appears to have occurred concurrently as the establishment of the Moki Formation fan system, centred around the southern and central wells. With continued sediment supply to the basin floor, the fan system prograded markedly northward and spilled onto the Western Stable Platform during the early Lillburnian. Sand influx to the bathyal basin floor abruptly ceased and large volumes of mud were deposited. By the Waiauan stage, sands were again deposited at bathyal depths on fan bodies and carried to greater depths through a complex bypassing channel system.</p>

Use of nonlinear chaos inversion in predicting deep thin lithologic hydrocarbon reservoirs: A case study from the Tazhong oil field of the Tarim Basin, China

Geophysics ◽  
2016 ◽  
Vol 81 (6) ◽  
pp. B221-B234 ◽  
Author(s):  
Handong Huang ◽  
Sanyi Yuan ◽  
Yintao Zhang ◽  
Jing Zeng ◽  
Wentao Mu
Keyword(s):  
Tarim Basin ◽  
Oil And Gas ◽  
Size Variation ◽  
Hydrocarbon Reservoirs ◽  
Oil Field ◽  
Seismic Facies ◽  
Background Information ◽  
Inversion Method ◽  
Inversion Methods ◽  
Well Data

With the gradual disappearance of traditional structural reservoirs, widely distributed deep thin lithologic reservoirs developed in continental and transitional sedimentary environments may offer significant petroleum reserves. Reservoir characterization through conventional impedance inversion methods without appropriate selection of regularization parameters and other empirical constraints cannot easily detect and assess these reserves, however, due to their size, variation, and features that conceal them. We have evaluated a nonlinear chaos inversion method that uses well data and seismic facies to characterize the oil and gas reservoirs of the Tazhong oil field in the Tarim Basin, China. The inverted results exhibited high agreement with the well data in highlighting the interfaces and lithologic bodies. This integrated method also provided enhanced resolution of depositional contacts and variable lithologic bodies. Specifically, the approach was able to describe a highly variable, approximately 5 m thick Carboniferous formation at depths greater than 3400 m. Borehole and core data provided a complementary hydrocarbon accumulation model. We used background information on hydrocarbon-bearing units within the main structure (an anticline) to detect and access (drill) ultra-thin lithologic reservoirs located in deeper areas of the structural high. Two wells drilled according to predictions derived from this new approach have each reached production rates of more than 30 tons of oil per day. Thus, we have determined the effectiveness of combining chaos inversion methods with empirical constraints in exploration of deep thin hydrocarbon reservoirs.

Morphology, architecture, and evolutionary processes of the Zhongjian Canyon between two carbonate platforms, South China Sea

2018 ◽  
Vol 6 (4) ◽  
pp. SO1-SO15 ◽  
Author(s):  
Yintao Lu ◽  
Wei Li ◽  
Shiguo Wu ◽  
Bryan T. Cronin ◽  
Fuliang Lyu ◽  
...  
Keyword(s):  
Seismic Data ◽  
Large Scale ◽  
Middle Miocene ◽  
Sedimentary Environment ◽  
Submarine Canyon ◽  
High Amplitude ◽  
Seismic Facies ◽  
Coarse Grained ◽  
Carbonate Platforms ◽  
Depositional Processes

Two isolated Neogene carbonate platforms (Xisha and Guangle carbonate platforms) have developed in the rifted uplifts since the Early Miocene. A large-scale submarine canyon system, the Zhongjian Canyon (ZJC), has developed in the tectonic depression between the two platforms since the Middle Miocene. High-resolution bathymetry data and 2D and 3D seismic data reveal the existence of the ZJC on the present seafloor, as well as in Neogene intervals. It exhibits typical characteristics of deepwater canyons that cut the surrounding rocks and indicate strong erosional features. The ZJC resulted from northwest–southeast strike-slip fault activities during synrift and postrift stages, and it periodically grew during the development of carbonate platforms since the Middle Miocene. We identified four cycles of parallel to subparallel high amplitude and dim reflectors in seismic data, which we interpreted as alternating canyon fill, based on the interpretation of seismic facies. Thus, the sedimentary evolution of the ZJC can be divided into four typical stages, which were in the Middle Miocene, Late Miocene, Early Pliocene, and Pleistocene. Considering the tectonic background of the carbonate platforms, as well as the on-going igneous activities, the sediment filling the canyon could be derived from a mixture of carbonate clasts, igneous clasts, mud, and silt. The laminar high-amplitude reflectors and dim-reflector package represented a fining-upward sedimentary cycle. The coarse-grained sediment in canyon fillings could be turbidites, carbonate debrites, and even igneous clasts. In contrast, the fine-grained sediment is likely to be dominated by pelagic to hemipelagic mud, and silt. This case study describes a deepwater canyon under a carbonate-dominated sedimentary environment and has significant implications for improving our knowledge of periplatform slope depositional processes. Furthermore, the insight gained into periplatform slope depositional processes can be applied globally.

Incised valleys and tidal seaways: the example of the Miocene Uzès-Castillon basin, SE France

2012 ◽  
Vol 183 (5) ◽  
pp. 471-486 ◽  
Author(s):  
Jean-Yves Reynaud ◽  
Emmanuelle Vennin ◽  
Olivier Parize ◽  
Jean-Loup Rubino ◽  
Chantal Bourdillon
Keyword(s):  
Shallow Water ◽  
Middle Miocene ◽  
Foreland Basin ◽  
Tidal Currents ◽  
Borehole Data ◽  
Depositional Sequences ◽  
Lower Miocene ◽  
Incised Valley ◽  
Valley Fills ◽  
Se France

Abstract The sedimentology and stratigraphy of the Miocene deposits of the Uzès-Castillon basin are revisited. This basin, located in SE France at the junction between the perialpine foreland basin and the W Mediterranean margin, sits in a syncline that formed during the latest Cretaceous Pyrenean tectonic phase. It records the succession of shallow-water mixed siliciclastic to dominantly bioclastic carbonates that alternate with shelf marls. The clastic carbonates were accumulated as a stack of subtidal dunes and bars that were formed by tidal currents channelized in a seaway following the syncline axis. The marls indicate deposition in more protected and locally deeper waters, as interfluves of the sea-way were drowned. Borehole data suggest that the marls are encased over tens of meters in the underlying bioclastic deposits, thus pointing to incised-valley fills. Contrarily to what is observed in the main Rhodanian basin, the molassic deposits are not restricted to transgressive systems tracts but may also correspond to forced regressive systems tracts. Four depositional sequences are identified, ranging from the Lower Burdigalian to the Langhian. They constitute a transgressive-regressive sequence set which might express the uplift of the area starting in the Late Burdigalian. This is consistent with the incision of the Middle Miocene deposits into the Lower Miocene ones as observed in other places of the main Rhodanian basin.

Seismic facies classification using supervised convolutional neural networks and semisupervised generative adversarial networks

Geophysics ◽  
2020 ◽  
Vol 85 (4) ◽  
pp. O47-O58 ◽  
Author(s):  
Mingliang Liu ◽  
Michael Jervis ◽  
Weichang Li ◽  
Philippe Nivlet
Keyword(s):  
Neural Networks ◽  
Seismic Data ◽  
Hydrocarbon Exploration ◽  
Training Data ◽  
Seismic Facies ◽  
Generative Adversarial Networks ◽  
Complex Data ◽  
Facies Classification ◽  
Good Ability ◽  
Well Data

Mapping of seismic and lithologic facies from 3D reflection seismic data plays a key role in depositional environment analysis and reservoir characterization during hydrocarbon exploration and development. Although a variety of machine-learning methods have been developed to speed up interpretation and improve prediction accuracy, there still exist significant challenges in 3D multiclass seismic facies classification in practice. Some of these limitations include complex data representation, limited training data with labels, imbalanced facies class distribution, and lack of rigorous performance evaluation metrics. To overcome these challenges, we have developed a supervised convolutional neural network (CNN) and a semisupervised generative adversarial network (GAN) for 3D seismic facies classification in situations with sufficient and limited well data, respectively. The proposed models can predict 3D facies distribution based on actual well log data and core analysis, or other prior geologic knowledge. Therefore, they provide a more consistent and meaningful implication to seismic interpretation than commonly used unsupervised approaches. The two deep neural networks have been tested successfully on a realistic synthetic case based on an existing reservoir and a real case study of the F3 seismic data from the Dutch sector of the North Sea. The prediction results show that, with relatively abundant well data, the supervised CNN-based learning method has a good ability in feature learning from seismic data and accurately recovering the 3D facies model, whereas the semisupervised GAN is effective in avoiding overfitting in the case of extremely limited well data. The latter seems, therefore, particularly adapted to exploration or early field development stages in which labeled data from wells are still very scarce.

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