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"Parameter Acoustic Impedance (AI) dan Shear Impedance (SI) umumnya digunakan untuk sensitivitas pemisahan litologi dan fluida, distribusi properti petrofisika, pemodelan fasies, dan estimasi reserve potensi migas. Namun parameter tersebut tidak sensitif untuk pemisahan litologi dan fluida pada Formasi Plover di lapangan-X cekungan Bonaparte. Analisis lanjut parameter AI dan SI dilakukan dengan merotasikan kedua sumbu parameter tersebut ke dalam sumbu parameter yang baru sehingga menghasilkan parameter Poisson Impedance (PI) yang memenuhi persamaan PI = AI - c*SI. Pemisahan litologi dan fl uida dapat ditentukan dengan pemilihan nilai c yang berbeda melalui analisis TCCA (Target Correlation Coefficient Analysis). Nilai c untuk indeks litologi (LI) diperoleh dengan melakukan korelasi antara PI dan rekaman Gamma Ray (GR) dan untuk indeks fluida (FI) melalui korelasi antara PI dan Saturasi Air (Sw). Pada penelitian ini, terdapat dua zona target, yaitu zona A (3760 - 3920 meter) dan zona B (3920 - 4010 meter). Batas pemisahan litologi antara batupasir dan batu serpih menggunakan koefisien c = 1.245 untuk zona-A dan c = 2.3433 untuk zona-B sedangkan indikasi fluida menggunakan koefisien c = 2.740 untuk zona-A dan c = 3.2607 untuk zona-B."

"[ABSTRAKIdentifikasi keberadaan hidrokarbon di bawah permukaan bumi merupakansalah satu tujuan utama dalam eksplorasi lapangan minyak bumi dalam usahamengidentifikasi keberadaan hidrokarbon. Impedansi-poisson yang merupakansalah satu metoda yang digunakan untuk mendiskriminasi sifat fisis batuanterhadap fluida dengan cara mengamati sensitivitas dari rasio poisson telahditerapkan lebih lanjut untuk menghasilkan suatu metoda turunan yang lebih baik.Pendekatan sifat fisika batuan antara impedansi-poisson dengan log sumuran yangmerepresentasikan properti batuan menghasilkan suatu metoda turunan yangdinamakan impedansi-litologi. Sedangkan pendekatan sifat fisis fluida yangterkandung didalam batuan terhadap impedansi-poisson menghasilkan diskriminasikandungan fluida didalam batuan yang kemudian dinamakan impedansi-fluida.Metoda TCCA – Target Coeffisien Corellation Analysis – yang digunakanuntuk mencari koefisien korelasi tertinggi dari sifat fisis batuan terhadapimpedansi-poisson telah digunakan dalam penelitian ini untuk menghasilkan logsumuran impedansi-litologi dan impedansi-fluida yang kemudian di propagasidengan neural network. Hasil propagasi impedansi-litologi digunakan sebagaiinput untuk kalkulasi atribut koherensi yang diperkuat dengan hasil propagasiimpedansi-fluida untuk menghasilkan prediksi sebaran batuan reservoar.Dari hasil penelitian pada horison FS33 terlihat pola channel yangterbentuk dan tervalidasi dengan data sumur. Demikian juga pada sayatan horisonFS37, pola channel batuan reservoar terlihat dengan jelas dan tervalidasi terhadapdua sumur yang dilalui. Sedangkan pada sayatan horison FS42 selainteridentifikasi pola channel reservoar yang terbentuk, teridentifikasi juga batuankarbonat yang divalidasi dengan data sumur dan data batuan inti

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ABSTRACTHydrocarbon identification in subsurface is one of main goals in petroleumexploration so that the litho-fluid content discriminations are a part of hydrocarbonidentifications which have been widely applied today. Poisson-impedance which isone of the new methods that are used to discriminate rocks by examining thesensitivity of physical rock properties of poisson-ratio has been further developedto produce derivatives method. Physical properties approaches between poissonratioand a well-log which represents rock properties can be used to get highestcorrelation to produce a new derivative well-log named lithology-impedance. As afluid-rock properties approach between poisson-ratio and a well-log representslitho-fluid content properties produces a new derivative well-log named fluidimpedance.TCCA method –Target Coeffisien Corellation Analyst– is used to find thehighest correlation coefficient of the physical properties of rock fluid on thepoisson ratio has been used in this study to generate two new derivatives well-logwhich would be propagated by means of neural-networks. The result of lithologyimpedancepropagation is further proceed with seismic coherence attribute as areflection of geology and stratigraphy forms which are then combined with fluidimpedancepropagation result to emphasize reservoir prediction distributionlaterally.The study results of FS33 slicing discovers sand channels pattern andvalidated by well-log. Similarly with horizon slicing of FS37, patterns of sandchannels reservoir are clearly visible and validated against two well-logs thatpassed. While on horizon slicing of FS42 besides discovering sand channels,carbonate rocks is also identified which is validated by well-log and core sampleanalyst.;Hydrocarbon identification in subsurface is one of main goals in petroleumexploration so that the litho-fluid content discriminations are a part of hydrocarbonidentifications which have been widely applied today. Poisson-impedance which isone of the new methods that are used to discriminate rocks by examining thesensitivity of physical rock properties of poisson-ratio has been further developedto produce derivatives method. Physical properties approaches between poissonratioand a well-log which represents rock properties can be used to get highestcorrelation to produce a new derivative well-log named lithology-impedance. As afluid-rock properties approach between poisson-ratio and a well-log representslitho-fluid content properties produces a new derivative well-log named fluidimpedance.TCCA method –Target Coeffisien Corellation Analyst– is used to find thehighest correlation coefficient of the physical properties of rock fluid on thepoisson ratio has been used in this study to generate two new derivatives well-logwhich would be propagated by means of neural-networks. The result of lithologyimpedancepropagation is further proceed with seismic coherence attribute as areflection of geology and stratigraphy forms which are then combined with fluidimpedancepropagation result to emphasize reservoir prediction distributionlaterally.The study results of FS33 slicing discovers sand channels pattern andvalidated by well-log. Similarly with horizon slicing of FS37, patterns of sandchannels reservoir are clearly visible and validated against two well-logs thatpassed. While on horizon slicing of FS42 besides discovering sand channels,carbonate rocks is also identified which is validated by well-log and core sampleanalyst.;Hydrocarbon identification in subsurface is one of main goals in petroleumexploration so that the litho-fluid content discriminations are a part of hydrocarbonidentifications which have been widely applied today. Poisson-impedance which isone of the new methods that are used to discriminate rocks by examining thesensitivity of physical rock properties of poisson-ratio has been further developedto produce derivatives method. Physical properties approaches between poissonratioand a well-log which represents rock properties can be used to get highestcorrelation to produce a new derivative well-log named lithology-impedance. As afluid-rock properties approach between poisson-ratio and a well-log representslitho-fluid content properties produces a new derivative well-log named fluidimpedance.TCCA method –Target Coeffisien Corellation Analyst– is used to find thehighest correlation coefficient of the physical properties of rock fluid on thepoisson ratio has been used in this study to generate two new derivatives well-logwhich would be propagated by means of neural-networks. The result of lithologyimpedancepropagation is further proceed with seismic coherence attribute as areflection of geology and stratigraphy forms which are then combined with fluidimpedancepropagation result to emphasize reservoir prediction distributionlaterally.The study results of FS33 slicing discovers sand channels pattern andvalidated by well-log. Similarly with horizon slicing of FS37, patterns of sandchannels reservoir are clearly visible and validated against two well-logs thatpassed. While on horizon slicing of FS42 besides discovering sand channels,carbonate rocks is also identified which is validated by well-log and core sampleanalyst., Hydrocarbon identification in subsurface is one of main goals in petroleumexploration so that the litho-fluid content discriminations are a part of hydrocarbonidentifications which have been widely applied today. Poisson-impedance which isone of the new methods that are used to discriminate rocks by examining thesensitivity of physical rock properties of poisson-ratio has been further developedto produce derivatives method. Physical properties approaches between poissonratioand a well-log which represents rock properties can be used to get highestcorrelation to produce a new derivative well-log named lithology-impedance. As afluid-rock properties approach between poisson-ratio and a well-log representslitho-fluid content properties produces a new derivative well-log named fluidimpedance.TCCA method –Target Coeffisien Corellation Analyst– is used to find thehighest correlation coefficient of the physical properties of rock fluid on thepoisson ratio has been used in this study to generate two new derivatives well-logwhich would be propagated by means of neural-networks. The result of lithologyimpedancepropagation is further proceed with seismic coherence attribute as areflection of geology and stratigraphy forms which are then combined with fluidimpedancepropagation result to emphasize reservoir prediction distributionlaterally.The study results of FS33 slicing discovers sand channels pattern andvalidated by well-log. Similarly with horizon slicing of FS37, patterns of sandchannels reservoir are clearly visible and validated against two well-logs thatpassed. While on horizon slicing of FS42 besides discovering sand channels,carbonate rocks is also identified which is validated by well-log and core sampleanalyst.]"

"Extended Elastic Impedance method is one of the methods in reservoir characterization, which is used to identify lithology and fluids content. This method is an extension of Elastic Impedance method by changing Sin²θ in Zoeppritz equation with tan χ to get scaled reflectivity equation. χ is angle range between -90° up to 90°. By using proper angle (χ), we can calculate the reflectivity that associates with the log parameter (Gamma Ray, Porosity, Lamda-Rho and Mhu-Rho). To proceeds this scheme we need to derive gradient and intercept from AVO analysis, which is used in Zoeppritz equation to calculate reflectivity volume. The proper angle (χ), which is derived from Whitcombe equation, is 30° for Gamma Ray. While the proper angle (χ) for porosity, mhu-rho, and lambda-rho is 60°, -90° and 15° respectively.The result of mhu-rho and lamda-rho inversion in the target area contain of sandstone and oil in the time depth range of 1545 ? 1573 ms for horizon 1 and horizon 2. Based on seismic inversion, lamda-rho and mhu-rho crossplot analysis we can see that the distribution of reservoir in target area has lamda-rho value between 9050 ? 9300 m/s*g/cc or 25 ? 37 GPa*g/cc and mhu-rho value between 7500 ? 11200 m/s*g/cc or 25 ? 35 GPa*g/cc."

"Pemetaan distribusi reservoir dan identifikasi fluida pada lapangan Blackfoot dilakukan dengan menggunakan kombinasi inversi antara impedansi P dan impedansi S. Pada studi ini data seismik stack diinversi dengan konstrain impedansi akustik (Ip) dan impedansi elastik (Is) yang diturunkan dari data sumur untuk mengubah data volume seismik menjadi data volume Ip dan Is. Inversi seismik sparse-spike digunakan untuk melakukan proses inversi tersebut. Kajian mendalam terhadap hasil inversi ditekankan pada reservoar sand pada formasi Lower Cretaceous Glauconitic yang terdapat pada kedalaman 1500m - 1600m. Identifikasi reservoar pada data log sumuran memperlihatkan indikasi yang jelas pada kedalaman 1550m -1600m dan dipertajam dengan data seismik pada kedalaman 1410ms - 1440ms. Hasil inversi Ip memperlihatkan bahwa distribusi Ip mampu membantu mendeliniasi sebaran reservoir dan hasil Is dapat mengenali keberadaan fluida didalam reservoar.

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Mapping reservoir distribution and identification of fluid in the Blackfoot field is done by using a combination of impedance inversion between P and S impedance. In this study the seismic data stack inversion with the constrain of acoustic impedance (AI) and shear impedance (SI) which is derived from existing wells to change the volume of seismic data to the data volume of AI and SI. In this study Sparse-spike inversion of seismic method is used to perform the inversion process.

Focusing in this study of the inverted result is on sand reservoir in the Lower Cretaceous formations Glauconitic, in the depth of 1500m - 1600m. Identify reservoir from log data shows a clear indication of reservoir at a depth of 1550m-1600m and sharpened with the seismic data at depths of 1410ms - 1440ms. AI inversion results are expected to help delineate the distribution of the reservoir and the results SI able to recognize the presence of fluid in the reservoir."

"ABSTRAKLapangan WR yang merupakan area target penelitian berada pada cekungan Bonaparte, dengan target reservoar batupasir berumur jurassic dan fluida yang tersaturasi berupa gas. Karakter reservoar dari data sumur mengindikasikan lingkungan pengendapan daerah Estuarine, dengan tipe batupasir yang blocky dengan sedikit sisipan serpih. Terdapat data seismik 3D prestack dan tiga data sumur yang memiliki kecepatan gelombang-P Vp dan gelombang-S Vs . Dalam perkembangannya terdapat tiga metode dengan memanfaatkan Vp dan Vs yaitu Extended Elastic Impedance EEI 2002 , Poisson Impedance PI 2006 , dan Curved Pseudo Elastic Impedance CPEI 2014 . Ketiga metode tersebut diaplikasikan pada data seismik dan sumur untuk melihat perbandingannya dalam mengkarakterisasi reservoar pada lapangan WR berupa persebaran litologi dan fluida secara lateral maupun vertikal. Hasil yang didapat dari ketiga metode tersebut berkorelasi baik dengan litologi pada nilai sudut chi ? untuk EEI 30 , PI 59 , dan CPEI -69 , sedangkan dengan fluida didapatkan nilai chi ? yang berkorelasi dengan EEI 20 , PI 51 , dan CPEI -60 . Korelasi tertinggi terhadap target log litologi yaitu log GR dan fluida berupa log SW dari ketiga metode tersebut adalah metode CPEI dengan korelasi 0.881 untuk log GR dan 0.604 untuk log SW. Secara vertikal dari ketiga metode tersebut menunjukkan karakter reservoar yang cukup baik dengan tingkat saturasi gas yang cukup tinggi. Hasil persebaran lateral dari ketiga metode tersebut menunjukkan karakter lingkungan pengendapan pada reservoir target berada pada lingkungan estuarine, dengan arah dari sumber supplay sedimen berarah tenggara, dan hasil ini cocok dengan konsep geologi regional pada lapangan tersebut.

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ABSTRACTThe WR field, which is the target area of the study, is in the bonaparte basin, with the target of jurassic sandstone reservoirs with saturated gas fluid. The reservoir character of the well data indicates the deposition environment of the estuarine region, with blocky sandy type with slight shale inserts. There are prestack 3D seismic data and three well data that have P wave velocity Vp and S wave Vs . In its development there are three methods by utilizing Vp and Vs namely Extended Elastic Impedance EEI 2002 , Poisson Impedance PI 2006 , and Curved Pseudo Elastic Impedance CPEI 2014 . All three methods are applied to seismic and well data to see the comparison in characterizing reservoir on WR field in the form of lateral and vertical lithology and fluid spread. The results obtained from these three methods correlate well with lithology at the angle value of chi for EEI 300 , PI 590 , and CPEI 690 , whereas with fluid obtained chi values correlated with EEI 200 , PI 510 , and CPEI 600 . The highest correlation to the log lithology targets ie log GR and the SW log flu of the three methods is the CPEI method with the correlation of 0.881 for the GR log and 0.604 for the SW log. The vertical of the three methods shows a good reservoir character with high saturation rate of gas. The result of the lateral distribution of the three methods shows the character of the deposition environment in the target reservoir located in the estuarine environment, with the direction from the source of the southeast centered sedimentary sediment, and the result matches the regional geological concept in the field. "

"Metode AVO yang bekerja pada domain reflektifitas secara umum dapat dipakai untuk mengidentifikasi dan menganalisa adanya anomali hidrokarbon, akan tetapi pada kasus-kasus tertentu diperlukan analisa yang lebih dalam untuk mendeteksi keberadaan hidrokarbon. Dalam studi ini digunakan workflows Extended Elastic Impedance (EEI) untuk memetakan lapisan karbonat dan kandungan fluidanya di lapangan "X" Jawa Barat Utara. Dalam studi ini Metode Extended Elastic Impedance (EEI) akan dikombinasikan dengan metode Color Inversion untuk menghasilkan peta penyebaran fluida (gas) dan litologi.Identifikasi reservoar dilakukan dengan cara cross correlation antara kurva EEI dengan kurva GammaRay sedangkan untuk identifikasi kandungan fluidanya, dilakukan cross correlation antara kurva EEI dengan Resistiviti.Metoda cross correlation tersebut dilakukan dengan increment sudut 0 10 = c pada sumur lapangan dari sudut 0 90 − sampai dengan 0 90 . Hasil nilai c (chi) dengan koefisien korelasi terbesar yang didapatkan kemudian ditransformasikan ke dalam nilai sudut datang ( q) dengan menggunakan hubungan c tan = q 2 sin . Sudut q (teta) tersebut kemudian digunakan dalam kombinasi proyeksi linier antara inversi data seismik near dan far.Aplikasi metode EEI pada studi ini berhasil memperlihatkan pola penyebaran reservoar dan kandungan fluida (gas) nya sehingga selanjutnya bisa digunakan untuk keperluan pengembangan lapangan "X" di Jawa Barat Utara.

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AVO method that works in reflectivity domain used to identify and analyze hydrocarbon anomaly. But, in some cases we need deeper analysis to predict the existence of hydrocarbon. In this study we use EEI workflows to predict lithology and fluid distribution of carbonate reservoir in "X" field, at North West Java basin.In this study, Extended Elastic Impedance (EEI) as an extension from Elastic Impedance (EI) method will be combined with Color Inversion method to predict lithology from fluid (gas).Cross correlation between EEI curve with Gamma Ray curve was used as a lithology identification and cross correlation between EEI curve with Resistivity curve as a fluid identification. The cross correlation was conducted every 0 10 of c(chi) value between 0 90 − to 0 90 . The c(chi) with the biggest coefficient correlation value then will be transformed to the angle of incident q (teta) thru equation : c tan = q 2 sin . Furthermore, the lithology and fluid impedance can be obtained by projecting seismic near and far inverse volume with q (teta) as an angle projection .The result of EEI method in this study has been successfully predicting lithology and fluid (gas) distribution, therefore this method is applicable for field development purposes for "X" field at North West Java area."

"Model impedansi akustik dapat menjadi indikator litologi, porositas, serta sebagai data untuk analisis kuantitatif dari sifat fisik reservoar seperti porositas. Hasil analisis inversi impedansi akustik serta dengan pendekatan geostatistika menunjukkan bahwa reservoar yang berkembang di lapangan penelitian adalah batupasir tight yang diendapkan pada lingkungan fluvial ? dominated fan delta, dengan nilai impedansi akustik yang tinggi, hidrokarbon gas, nilai porosity yang rendah, nilai gamma ray yang rendah, nilai resistivity yang tinggi, nilai sonic yang tinggi, dan nilai density yang tinggi pada horison Caddo, Davis, Runaway, Vineyard. Namun reservoarnya tidak tebal dan dibawah limit of separability tetapi masih diatas limit of visibility.

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The reservoir is developed in the field of research is that tight sandstones deposited in fluvial environment - dominated fan delta, with high acoustic impedance value, hydrocarbon gases, low porosity value, low gamma ray value, high resistivity value, high sonic value, and high density value in horizon of Caddo, Davis, Runaway, Vineyard. But not thick reservoir and below the limit of separability but still above the limit of visibility."

"Metoda seismik inversi saat ini memegang peranan penting dalam dunia eksplorasi sebagai alat identifikasi parameter fisis suatu batuan, dan terkadang untuk identifikasi hidrokarbon dalam suatu reservoir. Dalam penelitian ini dipilih metoda inversi Extended Elastic Impedance (EEI) yang merupakan perluasan dari metoda Elastic Impedance (EI) dengan cara merubah |sin2θ| dengan tan χ dalam persamaan Elastic Impedance. Variabel χ mempunyai harga antara -90o dan 90o yang merupakan range sudut untuk memperoleh parameter fisik batuan. Dengan menggabungkan parameter intercept dan gradient dengan sudut (χ) yang optimum akan menghasilkan reflektivitas parameter fisik batuan tersebut.Tujuan studi ini adalah meneliti aplikasi metode EEI sebagai alat untuk menghasilkan prediksi berbagai parameter fisik batuan termasuk Lambda-Mu-Rho (LMR) yang dapat menunjukkan keberadaan sebaran reservoir dan keberadaan hidrokarbon di dalam lapisan reservoir. Hasil dari studi ini diperoleh dengan melakukan korelasi antara log LMR dengan model log EEI untuk mendapatkan harga sudut optimumnya. Sudut optimum Lambda-Rho yang diperoleh sebesar 18o dengan korelasi 0.7 dan Mu-Rho sudut optimumnya sebesar -45o dengan korelasi 0.9. Dari slicing hasil inversi reflectivity Lambda-Rho dan Mu-Rho menunjukkan akumulasi gas berada pada 10 ms ? 30 ms di bawah Formasi Talang Akar yang berada pada daerah tinggian dari struktur dan yang bukan merupakan tinggian, sehingga menunjukkan jebakan yang terjadi merupakan jebakan struktur dan stratigrafi.

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The Seismic Inversion method are important in the exploration nowadays, as tool to identify the basic physics of rocks, and also to determine the hydrocarbon in a reservoar. In this study, Extended Elastic Impedance (EEI) is extension of Elastic Impedance (EI) with modify the definition of Elastic Impedance beyond the range of physically meaningful angles by substituting tan χ for sin2θ in the two-term reflectivity equation. The primary variable now becomes χ rather than θ. The χ has vary between -90o and 90o , which gives an extension of EI for any combination of intercept and gradient. With combine χ optimum can create physic parameters reflectivity.

The aim this study is apply EEI method as tool to predict rock physic parameters include Lambda-Mu-Rho (LMR) can determine hydrocarbon presence in a reservoar. The study result is gained through the correlation between LMR log and EEI log model to get an optimum angle. The correlation extracting Lambda-Rho optimum angle is 18o with coefficient correlation 0.7 and Mu-Rho optimum angle is -45o with coefficient correlation 0.9. Lambda-Rho dan Mu-Rho inversion slices show the gas presence at 10 ms to 30 ms below Talang Akar Formation and also describe that the traps are stratigraphyc and structural."

"ABSTRAKDalam bidang geologi dan geofisika, pendeteksian, identifikasi sertapengkualifikasian batuan reservoir berdasarkan parameter berupa ketebalan, porositas dan kandungan fluida menggunakan data seismic refleksi merupakan hal yang sangat krusial. AVO dan inversion merupakan metoda yang berguna dalam membedakan batuan reservoir dengan kandungan hidrokarbon dari batuan lain disekitarnya. Batupasir yang memiliki kandungan gas, umumnya dicirikan olehkontras impedance yang relatif besar dibandingkan batuan di sekitarnya. Kombinasi antara data seismik, pemodelan langsung baik sebelum atau sesudah stack ditambah dengan informasi yang diperoleh dari sumur pemboran akan mempermudah proses penarikan kesimpulan berkaitan dengan distribusi penyebaran reservoir disertai perubahan yang terjadi pada parameter - parameter reservoir itu sendiri ; misalnya variasi tebal bersih kolom gas, tebal bersih reservoir/tebal bersih porositas.Pada daerah studi lapangan Blackfoot, dilakukan perhitungan rasio AI, EI dan ?Mu-Rho? dengan tujuan menentukan jenis unit litologi. Hal ini dapat dilakukan dengan memanfaatkan hasil perhitungan even P-P dan P-S yang diperoleh dari data sonic. Korelasi yang diperoleh antara data log sumur dengan even seismik, didukung oleh rasio AI, EI dan ?Mu-Rho? memperlihatkan bahwa perubahan nilai Impedansi akustik, EI dan ?Mu-Rho?dapat dikaitkan secaralangsung dengan rasio sand/shale dan tingkat konsolodasi batuan sedimen baik secara lateral maupun vertikal. Hasil analisis menunjukkan bahwa batuan reservoir yang berkembang dilapangan Blackfoot adalah batupasir glaukonit yang diendapkan pada lingkungan incised valley. Dalam seismic dapat dikenali melalui kedalamannya yang relatif dangkal (1500-1600 m), nilai porositas yang tinggi (15-26%), ketebalan batupasir dibawah tuning ( kurang dari 20 m) serta adanya anomali amplitudo yang tinggi (bright spot). Secara umum, glauconitic channel sand produk dari incised valleypada lapangan Blackfoot memiliki karakter berupa nilai rasio Vp/Vs yang rendah, nilai P ? Impedance dan S ? Impedance yang rendah, Elastik Impedance yang rendah, nilai Mu ? Rho yang tinggi dan nilai Lambda ? Rho yang rendah.

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ABSTRACTThe detection, identification, and qualification of thickness, porosity, and fluid content in reservoirs rocks, using seismic reflection data, is a very important topic in the area of geology and geophysics. AVO and Inversion method is gained to identify the reservoirs that contain hydrocarbon. For the gas sands has relatively strong contrast between the elastic properties of these and those of thesurrounding rocks is expected, the detection and qualification depends upon many other factors: degree of consolidation, ratio depth/thickness, lithologies involve, clay content, etc. The integration of seismic data with direct modeling, both before and afterstack, and with well information, allowed us to draw important conclusions regarding reservoirs extensions, as well as changes in other properties (net gas thickness in one case, and net sand thickness/net porosity thickness for the other) which are important for advanced development of these fields. Using the interpreted correlations the interval times of P-P and P-S events were used to calculate AI, EI, ?Mu-Rho? ratio for the principal lithologic units inBlackfoot area. Well log correlations to seismic events and AI, EI, ?Mu-Rho? ratio data indicate that changes in AI, EI, ?Mu-Rho? can be directly related to changes in the sand/shale ratio and the consolidation state of the sediments both laterally and vertically in the section. The AI ratio as the function of P-Impedance and S-Impedance correlatewith Elastic Impedance of the reservoirs properties and ?Lambda-Mu-Rho?are giving the best result to determine the lithology and fluid contents. In this seismic perspective, I considered with glauconitic incised valley sands. At Blackfoot filed, which is characterized by shallow depth (1500-1600 m), high porosities (15-26 %), sand thickness below tuning (less than 20 m), and where the reservoirs show as high amplitude anomalies (bright spot).In the Blackfoot area, the productive glauconitic incised valley sands can be identified by Vp/Vs ratio at the low value, P-Impedance and S-Impedance at low value, Elastic Impedance at the low value, Mu-Rho at the high value and Lambda-Rho at the low value."