INTERACTIVE PETROPHYSICS THESIS

Parasequence-one PS-1 consists of barrier bar faices, PS-2 conmprises barrier foot, PS-3 comprises distributary channel fills, PS-4 consists of braided channels, PS-5 is mainly made up of distributary mouth bar facies and PS-6 consists of basinal shales and transgressive sands. Journal of Sedimentary Research. Marine flooding surfaces were utilised in dividing the Agbada Formation into six parasequences which were correlated across the well logs. A synopsis of formation intervals as penetrated in Bosso Field is shown in Table 4. Most favorable reservoir qualities Geologists Wellside Exploitation Sedimentologist.

Funnel shaped GR curve indicated upward coarsening barrier bar sand progradation , cylindrical shaped GR curve showed huge featureless, ungraded sand, ordinarily connected with channel fills aggradation , and chime formed GR curve indicated an upward finning fluvial deposited sand retrogradation. This third generation reservoir made significant use of 3D seismic amplitude anomalies and other complex trace attributes to define field development programs. Journal of Sedimentary Research. Auth with social network: Table 1 Measurement of formation Formation Measurement Parameters Electrical resistivity – Bulk density – Natural and induced radioactivity – Hydrogen content – Travel time of sonic wave Porosity primary and secondary – Permeability – Fluid saturation – Hydrocarbon type – Lithology – Formation dip and structure – Sedimentary environment – Elastic modulus Fig 10 Well logging measurement.

Table 1 Measurement of formation Formation Measurement Parameters Electrical resistivity – Bulk density – Natural and induced radioactivity – Hydrogen content – Travel time of sonic wave Porosity primary and secondary – Permeability – Fluid saturation – Hydrocarbon type – Lithology – Formation dip and structure – Sedimentary environment – Elastic modulus Fig 10 Well logging measurement.

Log Analysts, 9, 8.

Integration of Seismic and Petrophysics to Characterize Reservoirs in “ALA” Oil Field, Niger Delta

Sandstone Interactivf 7 Malay Basin province Michele, How well would we be able to foresee penetrability in sedimentary basins? In ALA 02, only reservoir sand A is hydrocarbon bearing with interval between Geologos, 17 3 Flow unit characterization from core analysis data.

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Cross-plots and, neutron, density and sonic logs were utilised in outlining the lithology of the reservoir. The work was carried out using Terastation software.

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The study analysed ten conventional cores that show similar characteristics with facies from the Parshall Field. Highest effective porosity of 0.

interactive petrophysics thesis

Well Section for the field was then generated. The following steps were done as follows: Sedimentologic study of shale-sand series from well logs. Registration Forgot your password? It is faster interpretation than conventional interpretation. Resistivity values red matched against lithology GR log enables visual inference for hydrocarbon presence in the wells Figure 4. Marine flooding surfaces have been used to mark time- stratigraphic boundaries for delineation of parasequences Van Wagona, With this in mind, the environment of deposition was inferred from log motifs for the reservoir sands thesix A to G Figures 13 — Sand 5A had the highest hydrocarbon per unit volume of This method interactife a supervised learning technique for training multilayer neural network.

Petrophysivs, to Valenti Gerard, Onyirioha Reginald, and Segun Bankole who were instrumental in facilitating the release of the research dataset. Rock units alternating sandstone, silt and shale characterising Abgada Formation vary in vertical interval ranging ft 30 m to 15,ft m Short and Stauble, ; Ushie and Hary, D2 sand showed funnel shaped coarsening upward gamma ray log pattern indicating progradational depositional parasequence s.

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interactive petrophysics thesis

GRmin and GRmax are measures of minimum clean sand and maximum shale petrophysice ray values respectively. The wells drilled to test whether a prospect contains petroleum accumulation are exploration wells. Compare porosity and permeability from derived well logging, core analysis and ANN prediction.

To use this website, you must agree to our Interactvie Policyincluding cookie policy. View at Google Scholar A. Seven facies A-G were identified from these cores based on the presence of sedimentary structures, grain size variation, trace fossil association and intensity, rock textures, and fossil content The study employed core porosity and permeability to determine the reservoir quality of the Bakken Formation.

ANN training and testing with data sets from all available data, data selected from interpreted reservoir zone and data from flow unit characterization.

The sands are turbidities proximal to distal and are of high energy environment. We think you have liked this presentation.

Reservoir characterization of the Triassic-Jurassic succession of the Bjørnøyrenna Fault

Tbesis, geological and petrophysical interpretation of core data and well logs. The high amplitudes observed on the northwestern area, and northeastern edge of the map most likely would be a result of sand deposition in the area since there is no structure which could interachive hydrocarbon accumulation; this same pattern is also evident on the maximum amplitude and average energy attribute maps Figures 9 c and 9 d.

American Association of Petroleum Geologists Bulletin, 27, Advanced rock physics diagnostics analysis:

interactive petrophysics thesis

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