Reservoir Prediction of Zhong 2 Block in Junggar Basin, NW China

2013 ◽  
Vol 868 ◽  
pp. 138-141
Author(s):  
Yong Yuan ◽  
Jin Liang Zhang ◽  
Ning Ning Meng
Keyword(s):  
Oil And Gas ◽  
Junggar Basin ◽  
Research Area ◽  
Seismic Inversion ◽  
Synthetic Seismograms ◽  
Extraction Technology ◽  
Reservoir Prediction ◽  
Seismic Attribute ◽  
Oil Accumulation ◽  
Multiple Attribute

Reservoir plane features of Zhong 2 block in Junggar Basin is analyzed with multiattribute analysis. Through the production of fine synthetic seismograms, the research area is analyzed by seismic attribute. On the basis of the calibration of synthetic seismograms and interpretation of horizon, accurate corresponding relation between the seismic reflection and geological horizon is established. By means of multiple attribute extraction technology, relatively independent attributes related to oil and gas are selected, and afterwards the analysis of the petrophysical characteristics and the optimization of the seismic attribute are achieved. Finally, through the seismic attributes analysis technology and the horizon slice technology, and seismic inversion is conducted, the favorable areas of oil accumulation are predicted.

Seismic Attributes Prediction of Changling Gas Field, Northeast China

2014 ◽  
Vol 962-965 ◽  
pp. 604-607
Author(s):  
Xiao Yu Yu ◽  
Yong Yuan ◽  
Jin Liang Zhang ◽  
Yuan Yuan Wang
Keyword(s):  
Oil And Gas ◽  
Seismic Attributes ◽  
Research Area ◽  
Synthetic Seismograms ◽  
Extraction Technology ◽  
Seismic Attribute ◽  
Gas Field ◽  
Multiple Attribute ◽  
Attribute Extraction ◽  
Multiattribute Analysis

Reservoir plane features of Changling No.1 gas field is analyzed with multiattribute analysis. Through the production of fine synthetic seismograms, the research area is analyzed by seismic attribute. On the basis of the calibration of synthetic seismograms and interpretation of horizon, accurate corresponding relation between the seismic reflection and geological horizon is established. By means of multiple attribute extraction technology, relatively independent attributes related to oil and gas are selected, and afterwards the analysis of the petrophysical characteristics and the optimization of the seismic attribute are achieved. Finally, through the seismic attributes analysis technology and the horizon slice technology, the favorable areas of gas accumulation are predicted.

Reservoir Prediction of Lishui Depression, East China Sea Basin

2013 ◽  
Vol 807-809 ◽  
pp. 2147-2150
Author(s):  
Guo Wei Hou ◽  
Yong Yuan ◽  
Jin Liang Zhang
Keyword(s):  
East China Sea ◽  
Seismic Inversion ◽  
Synthetic Seismograms ◽  
East China ◽  
Extraction Technology ◽  
Reservoir Prediction ◽  
Seismic Attribute ◽  
China Sea ◽  
Multiple Attribute ◽  
East China Sea Basin

Reservoir plane features of Lishui depression in East China Sea Basin is analyzed with multiattribute analysis. Through the production of fine synthetic seismograms, the research area is analyzed by seismic attribute. On the basis of the calibration of synthetic seismograms and interpretation of horizon, accurate corresponding relation between the seismic reflection and geological horizon is established. By means of multiple attribute extraction technology, relatively independent attributes related to oil and gas are selected, and afterwards the analysis of the petrophysical characteristics and the optimization of the seismic attribute are achieved. Finally, through the seismic attributes analysis technology and the horizon slice technology, and seismic inversion is conducted, the favorable areas of oil accumulation are predicted.

Seismic Sedimentology of Changling Gas Field, Northeast China

2014 ◽  
Vol 962-965 ◽  
pp. 608-611
Author(s):  
Xiao Song Li ◽  
Yong Yuan ◽  
Jin Liang Zhang ◽  
Xin Lv
Keyword(s):  
Oil And Gas ◽  
Signal To Noise Ratio ◽  
Sedimentary Facies ◽  
Extraction Technology ◽  
Seismic Attribute ◽  
Gas Field ◽  
Body Distribution ◽  
Multiple Attribute ◽  
Seismic Sedimentology ◽  
Multiattribute Analysis

Sedimentary facies plane features of Changling No.1 gas field is analyzed with multiattribute analysis. In Changling area, the signal to noise ratio of the seismic data is low and the sand body distribution in lateral lithologic reservoir changes fast. In this condition, research of seismic sedimentology is launched. Through the seismic stratigraphic classification, the target stratum, Denglouku group is divided into four sand groups. On the basis of the calibration of synthetic seismograms and interpretation of horizon, accurate corresponding relation between the seismic reflection and geological horizon is established. By means of multiple attribute extraction technology, relatively independent attributes related to oil and gas are selected, and afterwards the analysis of the petrophysical characteristics and the optimization of the seismic attribute are achieved. Finally, through the seismic attributes analysis technology and the horizon slice technology, combined with the result of sedimentary facies analysis, the favorable areas of gas accumulation are predicted.

Seismic attribute for characterization and prediction of carbonate faulted karst reservoirs in Tarim Basin, China

2021 ◽  
pp. 1-36
Author(s):  
Zhiwei Xiao ◽  
Li Wang ◽  
Ruizhao Yang ◽  
Dewei Li ◽  
Lingbin Meng
Keyword(s):  
Tarim Basin ◽  
Oil And Gas ◽  
Prediction Method ◽  
Strike Slip ◽  
Fault System ◽  
Bright Spot ◽  
Upper Ordovician ◽  
Reservoir Prediction ◽  
Seismic Attribute ◽  
Gas Field

An ultradeep, faulted karst reservoir of Ordovician carbonate was discovered in the Shunbei area of the Tarim Basin. Fractured-cavity reservoirs buried beneath the large thickness of upper Ordovician mudstone were formed along the fault-karst belts. The hydrocarbon accumulation in these reservoirs is controlled by the fault system, and the oil-gas accumulation was affected by karstification and hydrothermal reformation. Previous studies and 2D modeling revealed that the reservoirs had “bright spot” amplitude responses like “string beads,” and they have developed along the strike-slip faults. However, describing such a complex fault-controlled karst system is still a difficult problem that has not been well addressed. We have sought to instruct the attribute expression of faulted karst reservoirs in the northern part of the Tarim Basin. We applied coherence and fault likelihood (FL) seismic attributes to image faults and fractures zones. We then used a trend analysis method to calculate the residual impedance from the impedance of the acoustic inversion, using the fact that residual impedance has higher lateral resolution in reservoir predictions. Finally, we integrated the coherence, FL, and residual impedance attributes into a new seismic attribute, the “fault-vuggy body,” with a certain fusion coefficient. The fault-vuggy body attribute establishes a connection between faults and karst cavities. This method could help in the characterization and prediction of carbonate faulted karst reservoirs. Available drilling data were used to validate that the fused fault-vuggy body attribute was an effective reservoir prediction method. As the seismic sections and slices along the layer help delineate, the distribution of bright spots and strike-slip faults indicates that the main strike-slip fault zones are the most favorable reservoirs in the Shunbei Oil and Gas Field.

scholarly journals Late Cretaceous basin development of the southern Danish Central Graben

1969 ◽  
Vol 20 ◽  
pp. 15-18
Author(s):  
Finn Jakobsen ◽  
Claus Andersen
Keyword(s):  
Late Cretaceous ◽  
Oil And Gas ◽  
Seismic Inversion ◽  
Gas Production ◽  
Structural Development ◽  
Oil Accumulation ◽  
Oil And Gas Production ◽  
North West ◽  
The North ◽  
Basin Development

The Danish oil and gas production mainly comes from fields with chalk reservoirs of Late Cretaceous (Maastrichtian) and early Paleocene (Danian) ages located in the southern part of the Danish Central Graben in the North Sea. The area is mature with respect to exploration with most chalk fields located in structural traps known since the 1970s. However, the discovery by Mærsk Oil and Gas A/S of the large nonstructurally and dynamically trapped oil accumulation of the Halfdan Field in 1999 north-west of the Dan Field (e.g. Albrechtsen et al. 2001) triggered renewed exploration interest. This led to acquisition of new high quality 3-D seismic data that considerably enhanced imaging of different depositional features within the Chalk Group. Parallel to the endeavours by the operator to locate additional non-structural traps in porous chalk, the Geological Survey of Denmark and Greenland took advantage of the new data to unravel basin development by combining 3-D seismic interpretation of a large number of seismic markers, well log correlations and 2-D seismic inversion for prediction of the distribution of porous intervals in the Chalk Group. Part of this study is presented by Abramovitz et al. (in press). In the present paper we focus on aspects of the general structural development during the Late Cretaceous as illustrated by semi-regional time-isochore maps. The Chalk Group has been divided into two seismically mappable units (a Cenomanian–Campanian lower Chalk Unit and a Maastrichtian–Danian upper Chalk Unit) separated by a distinct basin-wide unconformity.

scholarly journals Simultaneous Seismic Inversion for Reservoir Characterization at Poseidon Field, Browse Basin, Australia

2021 ◽  
Vol 4 (1) ◽  
Author(s):  
Suleman Mauritz Sihotang ◽  
Ida Herawati
Keyword(s):  
Oil And Gas ◽  
Reservoir Characterization ◽  
Research Area ◽  
Seismic Inversion ◽  
Inversion Method ◽  
Well Log ◽  
Gas Field ◽  
Simultaneous Inversion ◽  
Fluid Saturation ◽  
Oil And Gas Field

Seismic inversion method has been widely used to obtain reservoir property in an oil and gas field. In this research, one of inversion methods known as simultaneous inversion is used to analyze reservoir characterization at Poseidon Field, Browse Basin. Simultaneous inversion is applied to partial angle stack data and result in volume of Acoustic Impedance (AI), Shear Impedance (SI) and Lame parameter (LMR). The objective of this study is to determine distribution of sandstone lithology with gas saturated in Plover reservoir formation. Sensitivity analysis is done by cross-plotting elastic and Lame parameter from five well log data and analyzing lithology type and fluid saturation. Based on those cross-plots, lithological type can be identified from AI, λρ, µρ and λ/µ parameters. Meanwhile, the presence of gas can be discriminated using SI, λρ, and λ/µ parameters. Gas-saturated sandstone presence is characterized by Lambda-Rho value less than 50 GPa g cc-1 and Lambda over Mu value less than 0.8 GPa g cc-1. Maps of each parameter are generated at reservoir interval. Based on those maps, it can be concluded that gas sand spread out in the eastern and western areas of research area.

scholarly journals Shale Plays Characterization of the Talang Akar Formation in the Jambi Sub-Basin, South Sumatra Basin

2020 ◽  
Vol 43 (3) ◽  
pp. 99-114
Author(s):  
Julikah Julikah ◽  
Ginanjar Rahmat ◽  
Ario Budi Wicaksono ◽  
Jakson Anwari
Keyword(s):  
Source Rock ◽  
Oil And Gas ◽  
Geophysical Methods ◽  
Seismic Inversion ◽  
Brittleness Index ◽  
Seismic Attribute ◽  
Early Maturity ◽  
Well Log Analysis ◽  
Better Than

The Jambi Sub-Basin is part of the prolifi c South Sumatra Basin which has been proven to produce conventional oil and gas in large quantities. In the basin, Talang Akar Formation (TAF) is believed to be the dominant source rock for commercial hydrocarbons. That means the TAF has potential as shale play resulting oil and gas. Generally, shale plays of the TAF was deposited on littoral-neritic environment during late period of syn-rift until early post-rift at Late Oligocene - Early Miocene. Based on well log analysis, identifi cation characters shale plays of the TAF in the Jambi Sub-Basin have good character as source rock reservoir. Several wells showed that early maturity level happened at depth less than 2000m. Most of TOC, S2 and HI values exist in the range of (1-10) wt%, (0.25 - 10) mg/g rock and (50 - 400) mg HC/ g TOC respectively. Shale plays of the TAF tend to have Type II, II / III and III kerogen. Most of existing wells are not located in the basin center. The geophysical methods such as seismic inversion and seismic attribute can be applied to predict the TOC (Total Organic Carbon) and brittleness index (BI) distributions especially in the basin center. Geologically, the shale plays quality in center of basin was interpreted better than the fl ank. Age of the shale in the Jambi Sub-Basin is relatively much younger when compared to shale in North America. This fact is suspected to cause the TAF shale play to be relatively less brittle. The data processing result shows that the brittleness index values of shale plays tend to be in the range of 40% - 70%.

DETERMINATION OF RESERVOIR DISTRIBUTION OVER THE BLACKBACK/TERAKIHI OIL FIELD, GIPPSLAND BASIN, AUSTRALIA

1993 ◽  
Vol 33 (1) ◽  
pp. 1
Author(s):  
M.D. Gross
Keyword(s):  
Oil And Gas ◽  
Group Structure ◽  
High Amplitude ◽  
Oil Field ◽  
Seismic Survey ◽  
Seismic Attribute ◽  
Oil Accumulation ◽  
Well Control ◽  
High Impedance ◽  
Gippsland Basin

The Blackback/Terakihi oil accumulation is located within the Gippsland Basin permit Vic-P24 on the edge of the present-day continental shelf in water depths ranging from 300 to more than 600 m. Accurate structural mapping, depth conversion and delineation of the reservoir units remain as major uncertainties associated with this oil and gas accumulation. To date three wells, Hapuku-1, Blackback-1 and Terakihi-1 have been drilled on the structure and a 3D seismic survey interpreted.The top of the Latrobe Group structure is a complex erosional remnant somewhat laterally offset from a deep-seated northeast to southwest trending, faulted anticline. Most of the hydrocarbons intersected to date have been encountered within the top of the Latrobe Group closure. All three wells drilled to date have intersected oil at the top of the Latrobe Group in three markedly different reservoir units. These reservoirs range in age from Late Cretaceous to Eocene, with porosity ranging from less than 12 per cent to 26 per cent and permeability from less than 1 md to greater than 3000 md.Given the extreme variation in reservoir quality and the field's location in relatively deep water, delineating the distribution of reservoir units using all available data remains crucial.The generation of seismic attribute maps such as dip, dip azimuth and horizon amplitude slices, calibrated on existing well penetrations has played a major role in delineating a complex reservoir distribution at the top of the Latrobe Group. The calibration of high amplitude seismic events with a high impedance channel infill unit of Eocene age was supported by modelling using SIERRAR modelling software.The integration of existing well control, seismic stratigraphy and fault geometry together with seismic attribute mapping and modelling has resulted in a more tightly constrained estimate of the field reserves.

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