GEOMETRY OF RESERVOIR TRENDS IN THE EPSILON FORMATION SANDS, SOUTHERN COOPER BASIN, SOUTH AUSTRALIA

1992 ◽  
Vol 32 (1) ◽  
pp. 339 ◽  
Author(s):  
W. A. Fairburn
Keyword(s):  
Gamma Ray ◽  
Facies Analysis ◽  
South Australia ◽  
Lower Permian ◽  
Isopach Maps ◽  
Continuous Sheet ◽  
Channel Deposits ◽  
Sand Bodies ◽  
Selection Of ◽  
Cooper Basin

Sandstone reservoirs within the Lower Permian Epsilon Formation, despite being gas productive in several fields in the Cooper Basin of South Australia, in particular Big Lake and Moomba, have proved to be elusive targets for exploration. This is mainly due to the distribution pattern of these sands, which differs markedly from that of the thicker and laterally extensive fluvial sands which are prevalent in the Toolachee and Patchawarra formations. As a consequence, there has been some acceptance that the distribution of Epsilon Formation reservoirs are unpredictable.Log correlation studies of the Epsilon Formation, in conjunction with sand trend mapping, have identified sands which are either laterally continuous ('sheet' sands) or laterally discontinuous ('ribbon' sands).Core facies analysis supports the interpretation that the 'sheet' sands are lake shore strandline deposits whereas the 'ribbon' sands are distributary channel deposits of prograding delta systems.Based on the inferred depositional models, and with the aid of detailed isopach maps, it has been possible to project reservoir trends of the channel sands and prepare sand maps, at varying gamma-ray cutoffs, of the shoreface sands.An understanding of the geometry of the various sand bodies has clarified the prospectivity of the Epsilon Formation and facilitated the selection of development well locations throughout the Southern Cooper Bas

Re-evaluation of depositional models for the lower Permian Patchawarra Formation, Cooper Basin, South Australia: implications for petroleum exploration

2020 ◽  
Vol 60 (2) ◽  
pp. 794
Author(s):  
Carmine Wainman ◽  
Peter McCabe
Keyword(s):  
Cold Water ◽  
South Australia ◽  
Petroleum Exploration ◽  
Lower Permian ◽  
Time Intervals ◽  
Fine Grained ◽  
Coal Beds ◽  
Hyperpycnal Flows ◽  
Lenticular Bedding ◽  
Cooper Basin

The Late Carboniferous–Triassic Cooper Basin is Australia’s most prolific onshore petroleum province. The lower Permian Patchawarra Formation, which is up to 680 m thick and consists of up to 10% coal, is a major exploration target in the basin. Eighteen cores through the formation have been logged to re-evaluate the existing fluviolacustrine depositional model. The siliciclastics form fining- and coarsening-upward sequences that are 1–10 m thick. They are predominately fine-grained with abundant lenticular bedding, wavy bedding and thinly interlaminated siltstones and clays resembling varves. Granules and pebbles, interpreted as dropstones, are present throughout the formation. Coal beds are up to 60 m thick and rich in inertinite. Other than the coal beds, there is little evidence of the establishment of terrestrial conditions: roots are rare and there are no siliciclastic palaeosols. The siliciclastics are interpreted as the deposits of a large glaciolacustrine system, with the fining-upward successions deposited in subaqueous channels cut by hyperpycnal flows and the coarsening-upward successions deposited as overbank splays between those channels. Hyperpycnal flows may have resulted from sediment-laden cold water emanating from glacially-fed rivers, similar to those seen in many large glacial lakes in high latitudes and altitudes today. Much of the coal is interpreted as the accumulation of peats from floating mires that covered large parts of the glaciolacustrine system at certain time intervals. The high inertinite content of many coals is interpreted as the decay of organic matter within the floating mire. These new interpretations have the potential to enhance reservoir characterisation within the basin.

AN EMPIRICAL APPROACH TO THE DETERMINATION OF POROSITY, SHALE PERCENTAGE, AND PERMEABILITY OF PERMIAN SANDSTONES IN THE COOPER BASIN, SOUTH AUSTRALIA

1976 ◽  
Vol 16 (1) ◽  
pp. 111
Author(s):  
C. R. Porter
Keyword(s):  
Gamma Ray ◽  
South Australia ◽  
Core Values ◽  
Empirical Approach ◽  
Good Agreement ◽  
Cooper Basin

Because of the limited yet adequate logging program run in Cooper Basin wells, porosity has been the most difficult parameter to calculate on a zone-by-zone basis. Empirically derived porosities from a gamma-ray (GK)-sonie (Δt) cross-plot show good agreement with core values of porosity. Furthermore shale percentages calculated from these porosities are in good agreement with shale values derived from crossplot techniques involving sonic, density and neutron log response parameters. An approximation of permeability may also be derived from a further simplified chart.

scholarly journals Lithological and facies analysis of the Roseneath and Murteree shales, Cooper Basin, Australia

2017 ◽  
Vol 37 ◽  
pp. 138-168 ◽  
Author(s):  
Quaid Khan Jadoon ◽  
Eric M. Roberts ◽  
Bob Henderson ◽  
Thomas G. Blenkinsop ◽  
Raphael A.J. Wüst ◽  
...  
Keyword(s):  
Facies Analysis ◽  
Cooper Basin

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.

scholarly journals Facies Analysis and Depositoinal Environment of D-3 Reservoir Sands Vin Field, Eastern Niger Delta

2019 ◽  
pp. 1-19
Author(s):  
Onyewuchi, Chinedu Vin ◽  
Minapuye, I. Odigi
Keyword(s):  
Seismic Data ◽  
Niger Delta ◽  
Depositional Environment ◽  
Gamma Ray ◽  
Facies Analysis ◽  
Depositional Environments ◽  
Width Ratio ◽  
Neutron Density ◽  
Wireline Logs ◽  
Isopach Map

Facies analysis and depositional environment identification of the Vin field was evaluated through the integration and comparison of results from wireline logs, core analysis, seismic data, ditch cutting samples and petrophysical parameters. Well log suites from 22 wells comprising gamma ray, resistivity, neutron, density, seismic data, and ditch cutting samples were obtained and analyzed. Prediction of depositional environment was made through the usage of wireline log shapes of facies combined with result from cores and ditch cuttings sample description. The aims of this study were to identify the facies and depositional environments of the D-3 reservoir sand in the Vin field. Two sets of correlations were made on the E-W trend to validate the reservoir top and base while the isopach map was used to establish the reservoir continuity. Facies analysis was carried out to identify the various depositional environments. The result showed that the reservoir is an elongate , four way dip closed roll over anticline associated with an E-W trending growth fault and contains two structural high separated by a saddle. The offshore bar unit is an elongate sand body with length: width ratio of >3:1 and is aligned parallel to the coast-line. Analysis of the gamma ray logs indicated that four log facies were recognized in all the wells used for the study. These include: Funnel-shaped (coarsening upward sequences), bell-shaped or fining upward sequences, the bow shape and irregular shape. Based on these categories of facies, the depositional environments were interpreted as deltaic distributaries, regressive barrier bars, reworked offshore bars and shallow marine. Analysis of the wireline logs and their core/ditch cuttings description has led to the conclusion that the reservoir sandstones of the Agbada Formation in the Vin field of the eastern Niger Delta is predominantly marine deltaic sequence, strongly influenced by clastic output from the Niger Delta. Deposition occurred in a variety of littoral and neritic environment ranging from barrier sand complex to fully marine outer shelf mudstones.

scholarly journals KERAGAMAN GENETIK MUTAN M-2 CABAI MERAH KERITING (Capsicum annuum L.) BERDASARKAN PENANDA RAPD

2020 ◽  
Vol 10 (2) ◽  
pp. 92
Author(s):  
Rosmaina Rosmaina ◽  
Dedi Mulyadi ◽  
Rita Elfianis ◽  
Zulfahmi Zulfahmi
Keyword(s):  
Capsicum Annuum ◽  
Gamma Ray ◽  
Rapd Analysis ◽  
Genetic Material ◽  
Polymorphic Loci ◽  
Capsicum Annuum L ◽  
Horticultural Plant ◽  
Dna Fragment ◽  
And Control ◽  
Selection Of

Chili is an important horticultural plant in Indonesia. This research aims to carry out RAPD analysis on Mutant M2 of chili pepper (Capsicum annuum L.). Six M2 genotypes of chili irradiated by gamma ray and control plants were amplified by 16 random primers. The amplification results of M2 chili with 16 primers produced 118 loci, with fragment sizes ranging from 150-2000 bp. The number of polymorphic loci was 96 loci and the percentage of polymorphic loci was 83.23%. The DNA fragment polymorphism produced in this research was relatively high and it showed that the gamma ray mutagen applied produced high chili genetic diversity. The value of genetic similarity between control plants and mutant plants ranged from 0.7474 to 0.4874. UPGMA dendogram classified seven genotypes tested into three groups, the first group consisted of mutants R2U6 and R2U17, the second group was mutants R1U14 and R1U17, and the third group was mutants R2U8, mutants R2U2 and control plants. The finding of this research can be used as a basic selection of genetic material for chili’s breeding in the future.

Evaluating the Lower Cruse and Navet Formations Within the Wd-8 Lease Operatorship Block

2021 ◽  
Author(s):  
Mark Emmanuel Bishop ◽  
Wilson Lalla ◽  
Xavier Ravi Moonan
Keyword(s):  
Well Testing ◽  
Geological Model ◽  
The South ◽  
Forest Reserve ◽  
The North ◽  
Well Spacing ◽  
Northern Portion ◽  
Channel Deposits ◽  
Sand Bodies ◽  
Slope Channel

Abstract Lease Operatorship block WD-8, lies within the Forest Reserve oilfield. Forest Reserve is known for having the ENE-WSW trending, south easterly verging Forest Reserve anticline which plunges into NW-SE trending Los Bajos Fault. Regionally to the south of the Forest Reserve anticline lies the south westerly plunging Siparia syncline and to the north of the Forest Reserve anticline is the Morne L′ Enfer syncline. WD-8 is situated on the northern flank of the Forest Reserve anticline with the axis of the anticline occurring within the southern part of the block. Prior to 2018, TETL last drilled within the WD-8 block in the year 2014. Drilling within the WD-8 block pre-2018 was mainly in the southern portion of the block. The year 2018 saw TETL drill five wells in the northern part of the WD-8 block. The results from these wells prompted an evaluation within the Northern portion of the WD-8 block to determine the structure and extent of the Lower Cruse and Navet reservoirs. Field wide mapping post 2018 drills within the block highlighted the sand trend at the Cruse level is in a WSW-ENE direction and that these sands in northern WD-8 are very narrow with maximum widths ranging between 100 ft – 150 ft. Additionally, it showed that by using a smaller well spacing, wells would encounter different producing sand bodies not seen in adjacent wells. Differences in the sand character between wells in the Southern part of the block to wells in the northern part of the block at the Lower Cruse level were also seen. The Lower Cruse section in the southern part of the WD-8 block tends to have thick stacked slope channel sand deposits, while the northern part of WD-8 has relatively thin stacked slope/base of slope channel deposits. Structurally, the presence of an ENE-WSW fault which separates the southern wells from the northern wells was also revealed. Abnormal stratigraphy was also found in Northern WD-8 where the Eocene Navet formation was encountered below the Late Miocene Lower Cruse formation. Two (2) wells in the northern portion of the block found the Navet formation resistive with only one well testing this reservoir. This then presents a new under exploited target reservoir with the block. Mapping of the Navet Formation indicates that this reservoir trends in a WSW-ENE direction. This updated geological model for the WD-8 block resulted in six infill developmental wells being identified to further exploit the remaining reserves within the Lower Cruse and Navet Formations in the WD-8 block.

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