Agreement DE-FC26-02NT15342, Seismic Evaluation of ...

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predictions can help to improve the interpretation of Direct Hydrocarbon Indicators. Presence of turbidite features might be an alternative explanation for the occurrence of high amplitude seismic events, which may be misidentified as hydrocarbon indicators. The combination of the geological study, which helps to identify depth intervals of interest, with the computed composite reflection coefficient provides some potentially important insights into seismic characterization of turbidite sequences. Also, we found the use of outcrop observations could enhance interpretation of deepwater sediments and add to understanding of the lithology, geometry and rock properties that exist in these settings. It was recognized early that the Brushy Canyon deepwater outcrops are not a perfect analog to the deepwater intraslope basin setting of Ursa field. The Brushy is a sand rich system that is now highly cemented and was deposited in mainly unconfined conditions, whereas the Ursa field is a mud rich system that formed in a confined intraslope basin setting controlled by salt tectonics, sediment loading and eustacy. However, many of the deepwater elements of the Brushy such as sheet sands, thin bed levee overbank deposits and channel systems, could be found in both types of settings and both have similar stratigraphic patterns in common. By performing forward modeling on some of these main deepwater features, we can better understand the Ursa seismic data. To summarize, outcrop modeling of geobodies combined with Ursa data have enhanced interpretation by: • Helping to identify patterns in deepwater seismic facies • Helping to differentiate causes of a substantial DHI’s (fluid vs lithology) • Investigation of sub-seismic features that control fluid flow and compartmentalization • Identification of a possible misinterpreted DHI • Recommendations on future applications A general summary of these observations can be seen in Table 5. Agreement DE-FC26-02NT15342, Seismic Evaluation of Hydrocarbon Saturation 132
Table 5 Summary of the model facies and the detection of lithology fluids, thickness, tuning and amplitude response. Figure 110 shows a table and graph comparing detectability, lithology and amplitudes. This figure provides a qualitative visual comparison of the attributes and parameters associated with each reservoir facies modeled. The sheet sands are the easiest to identify lithology and fluids, the thicknesses are relatively large and less problems with tuning result. For channel sands the lithology is relatively easy to distinguish, amplitudes are moderately indicators of channel presence and the detectability depends on the channel size and amalgamation. The levee overbank facies are least detectable, lithology is difficult to identify and amplitudes can be variable depending on the fluid presence. Agreement DE-FC26-02NT15342, Seismic Evaluation of Hydrocarbon Saturation 133
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June 29, 2006 Seismic Evaluation of
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Abstract: During this last quarter
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Ursa Data .........................
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Figures: Figure 1. Relationship of
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Figure 38. Schematic of geometry an
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Figure 73. The extracted wavelet an
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Executive Summary: In this joint pr
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Results and Discussion Introduction
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Inversion of Sw and porosity from s
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saturation from seismic data. Valid
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The Lagrange function (5) has a sad
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ρ ma − ρ + ( ρ w − ρ g ) ×
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With a water saturation log calcula
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Figure 11. permeability versus poro
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Figure 13. Measured dry and brine s
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Figure 15. The HP (deep) sands have
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pressure-porosity relations. The n
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Figure 19. measure dry and brine sa
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Relations between Sw, porosity, and
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Figure 21. An example realization o
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otherwise the seismic properties we
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correctly reproduce those found in
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study of field data from the Teal S
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Figure 30. Spectral decomposed pres
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(Adapted from CSM Slope and Basin C
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Figure 34. Sequence stratigraphic f
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Figure 36. Schematic depiction of c
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Figure 38. Schematic of geometry an
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Figure 40. Middle slope channel (Ad
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Figure 43. Amalgamated sandstone sh
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CHANNEL AXIS SINGLE STORY CHANNEL C
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MEDIAL LEVEE/OVERBANK 7.62 cm Figur
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L1054 L1041 • Ursa Well A4 Green=
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1.9 miles 37 ft Fizz 19 ft Oil 4.0
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esults in shifts followed by subsid
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Figure 55. Schematic of depositiona
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4 miles 1.5 s 2 s 3 s Hydrocarbon I
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In addition to comparing calculated
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Figure 61. Shear velocity trend for
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each reservoir interval modeled. Th
Page 81 and 82: Figure 65. Histograms of frequency
Page 83 and 84: the pressure trends were analyzed,
Page 85 and 86: P Impedance Model Synthetic 2 -D Mo
Page 87 and 88: Above Magenta reservoir model The A
Page 89 and 90: Figure 73. The extracted wavelet an
Page 91 and 92: saturation and 50% gas saturation.
Page 93 and 94: Figure 77. The amalgamated channel
Page 95 and 96: Figure 79. Channel complex model 2
Page 97 and 98: Figure 81. AVO stack and gathers fo
Page 99 and 100: Figure 82. Log signature includes g
Page 101 and 102: Figure 85. Extracted wavelet and mo
Page 103 and 104: Figure 87. Amalgamated sheet sand m
Page 105 and 106: Figure 89. Pseudo logs, wavelet, sy
Page 107 and 108: Figure 90. Medial basin floor chann
Page 109 and 110: Figure 92. Pseudo logs, wavelet, sy
Page 111 and 112: Figure 94. The post stack seismic e
Page 113 and 114: Figure 96. Statistically extracted
Page 115 and 116: Figure 98. The proximal levee overb
Page 117 and 118: Figure 99. The response of the prox
Page 119 and 120: Figure 101. The pseudo log, wavelet
Page 121 and 122: Figure 102. The distal levee overba
Page 123 and 124: Figure 104. The complex well log ba
Page 125 and 126: then scaled to the model data by mu
Page 127 and 128: Figure 107. The Ursa log displays g
Page 129 and 130: Figure 109. Composite reflection co
Page 131: Conclusions One of the main conclus
Page 135 and 136: REFERENCES Alford, R. M., Kelly, K.
Page 137 and 138: Gardner, M. H., Anderson, D. A., Bo
Page 139 and 140: Mahaffie, M.J., 1994, Reservoir cla
Page 141 and 142: Rothman, D.H., Grotzinger, J.P., Fl
Page 143 and 144: Vail, P., 1977, Seismic Stratigraph
Page 145 and 146: downlap (Mtchum, 1977): A base-disc
Page 147 and 148: direction and downlap onto the tran
Page 149 and 150: Agreement DE-FC26-02NT15342, Seismi
Page 159 and 160: APPENDIX E: VALUES USED FOR RESERVO
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