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

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Figure 69. Increase in acoustic impedance results in a peak at the reservoir top. Decreased acoustic impedance results in a trough at the reservoir top. Tuning point occurs around 10 m thickness. These results will help to interpret the results of the more complex models and verify if the model response is accurate. It is important to note that the tuning effects can be much more complex than simple tuning between the, top and base of the reservoir. Internal reservoir complexities can also cause complications with the tuning effect, which are beyond the scope of this study. This chapter summarizes the method of building models and general forward modeling. The next three chapters will show three reservoirs representing three separate deepwater facies. Along with each reservoir will be two models that were developed with Brushy Canyon outcrop models, AVO models and the interpretation of the forward model results. Finally, these models will be compared to the actual Ursa seismic data. Agreement DE-FC26-02NT15342, Seismic Evaluation of Hydrocarbon Saturation 86
Above Magenta reservoir model The Above Magenta reservoir interval was interpreted to be an amalgamated channel (Hilterman, 2001, Meckel et al., 2001). Its log signature (Figure 70) shows a blocky fining upward gamma with flat base that changes over long distances. It has high resistivity indicating hydrocarbon presence and relatively high porosity. (Meckel, 2001) Figure 70. Wireline log of Ursa Above Magenta interval (orange) with gamma, resistivity, porosity, sonic, computed shear sonic, density and synthetic trace. The seismic response of the Above Magenta reservoir interval can be seen in Figure 71 The reservoir top occurs as a strong trough. The reservoir is expressed as a shingled seismic geometry that converges along the 2-D seismic profile. According to Meckel (2001), the reservoir occurs as a sheet channel couplet in the continuous parallel facies. The prestack gathers in Figure 72 show a decrease in amplitude with offset. Figure 71. Above Magenta reservoir interval in seismic data. Agreement DE-FC26-02NT15342, Seismic Evaluation of Hydrocarbon Saturation 87
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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
Page 35 and 36: Figure 19. measure dry and brine sa
Page 37 and 38: Relations between Sw, porosity, and
Page 39 and 40: Figure 21. An example realization o
Page 41 and 42: otherwise the seismic properties we
Page 43 and 44: correctly reproduce those found in
Page 45 and 46: study of field data from the Teal S
Page 47 and 48: Figure 30. Spectral decomposed pres
Page 49 and 50: (Adapted from CSM Slope and Basin C
Page 51 and 52: Figure 34. Sequence stratigraphic f
Page 53 and 54: Figure 36. Schematic depiction of c
Page 55 and 56: Figure 38. Schematic of geometry an
Page 57 and 58: Figure 40. Middle slope channel (Ad
Page 59 and 60: Figure 43. Amalgamated sandstone sh
Page 61 and 62: CHANNEL AXIS SINGLE STORY CHANNEL C
Page 63 and 64: MEDIAL LEVEE/OVERBANK 7.62 cm Figur
Page 65 and 66: L1054 L1041 • Ursa Well A4 Green=
Page 67 and 68: 1.9 miles 37 ft Fizz 19 ft Oil 4.0
Page 69 and 70: esults in shifts followed by subsid
Page 71 and 72: Figure 55. Schematic of depositiona
Page 73 and 74: 4 miles 1.5 s 2 s 3 s Hydrocarbon I
Page 75 and 76: In addition to comparing calculated
Page 77 and 78: Figure 61. Shear velocity trend for
Page 79 and 80: 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: P Impedance Model Synthetic 2 -D Mo
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 and 132: Conclusions One of the main conclus
Page 133 and 134: Table 5 Summary of the model facies
Page 135 and 136: REFERENCES Alford, R. M., Kelly, K.
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Gardner, M. H., Anderson, D. A., Bo
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Mahaffie, M.J., 1994, Reservoir cla
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Rothman, D.H., Grotzinger, J.P., Fl
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Vail, P., 1977, Seismic Stratigraph
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downlap (Mtchum, 1977): A base-disc
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direction and downlap onto the tran
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Agreement DE-FC26-02NT15342, Seismi
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APPENDIX E: VALUES USED FOR RESERVO
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