--> Delineation of a Diagenetic Trap Using P-Wave and Converted-Wave Seismic Data in the Miocene McLure Shale, San Joaquin Basin, California, by Robert Kidney, John Arestad, Anne Grau, Robert Sterling, #20012 (2003).
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Delineation of a Diagenetic Trap Using P-Previous HitWaveNext Hit and Converted-Previous HitWaveNext Hit Seismic Data in the Miocene McLure Shale, San Joaquin Basin, California*

By

Robert Kidney1, John Arestad2, Anne Grau1, and Robert Sterling1

 Search and Discovery Article #20012 (2003)

 

*Adapted from an oral presentation at the AAPG’s annual convention, 2003, Salt Lake City, Utah, May, 2003. A companion article, entitled “Success! Using Seismic Attributes and Horizontal Drilling to Delineate and Exploit a Diagenetic Trap, Monterey Shale, San Joaquin Valley, California,” is Search and Discovery Article #20011 (2003).

1EOG Resources, Inc, Denver, CO ([email protected])

2ExplorTech, Littleton, CO

Abstract

North Shafter and Rose oil fields, located in California’s San Joaquin Basin, produce hydrocarbons from a subtle stratigraphic trap within the Miocene Monterey Formation. The trap-reservoir system was created during the burial process of a thick diatomaceous shale sequence that forms various diagenetic facies. Integration of well and 2-D p-Previous HitwaveNext Hit seismic data shows that a significant amplitude anomaly is present over both the reservoir (quartz) and seal (Opal-CT) facies, making delineation of the updip edge problematic. The porosity of the Opal-CT and reservoir quartz facies ranges from 50% to 24%.

From petrophysical analysis and seismic modeling the following conclusions can be drawn. The Opal-CT and hydrocarbon-saturated quartz have nearly the same acoustic impedance. The Opal-CT is low density while the hydrocarbon-saturated quartz is low velocity. The presence of gas-saturated oil in the quartz reduces the interval velocity in a manner similar to the Gassmann effect in high porosity sandstones. The down-dip wet quartz interval is not associated with a seismic amplitude anomaly since its impedance is similar to the bounding shales. Finally, converted-Previous HitwaveNext Hit data, which primarily images lithology rather than fluids, can be used to delineate the low density Opal-CT from the higher density quartz.

Based on the above conclusions, 2-D converted-Previous HitwaveNext Hit data were acquired to complement the p-Previous HitwaveNext Hit data. From these data sets the regional Opal-CT to quartz phase transformation boundary was mapped and a matrix of amplitude signatures versus facies was constructed. This work then formed the basis for mapping the hydrocarbon saturated quartz facies.

 

 

uAbstract

uFigures captions

uRock properties & seismic attributes

uDiscrimination of lithology & fluid type

uSeismic anomaly

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

uAbstract

uFigures captions

uRock properties & seismic attributes

uDiscrimination of lithology & fluid type

uSeismic anomaly

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

uAbstract

uFigures captions

uRock properties & seismic attributes

uDiscrimination of lithology & fluid type

uSeismic anomaly

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

uAbstract

uFigures captions

uRock properties & seismic attributes

uDiscrimination of lithology & fluid type

uSeismic anomaly

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Figure Captions

Figure 1. Regional P-Previous HitwaveNext Hit seismic amplitude anomaly with discovery well. Early drilling that targeted the P-Previous HitwaveNext Hit seismic amplitude anomaly resulted in McLure penetrations of both the trap and reservoir facies.

 

Figure 2. Cross plotting density vs. sonic identifies pay on wells logs--but not on seismic. Typical values in oil reservoir  are 150 msec/ft (sonic) and 2.00 gm/cc (density).

 

Figure 3. Tie of seismic attributes to rock properties. Seismic anomaly reflects change in fluid content and change in mineralogy.

 

 

Figure 4. Gassmann effect (reduction of interval velocity in quartz section with gas-saturated oil), shown by P-Previous HitwaveNext Hit/S-Previous HitwaveNext Hit plot.

 

 

Figure 5. P- and S- Previous HitwaveNext Hit seismic modeling, with Gassman effect in the P-Previous HitwaveNext Hit model, which shows both mineralogical and fluid effects, while only the mineralogical changes are shown in the S-Previous HitwaveNext Hit model.

 

Figure 6. P- and C- Previous HitwaveNext Hit seismic program developed for Rose / North Shafter development.

 

 

Figure 7. Seismic lithology discrimination: Lower interval, North Shafter Field, with P-Previous HitwaveNext Hit seismic showing Gassman effect and C-Previous HitwaveNext Hit seismic showing the change in mineralogy.

 

Figure 8. Seismic lithology discrimination: Lower interval, North Shafter Field. Both P-Previous HitwaveNext Hit and C-Previous HitwaveNext Hit show only the change in mineralogy.

 

 

Figure 9. Regional conversion in lower interval of opal CT to quartz on P-Previous HitwaveNext Hit and C-Previous HitwaveNext Hit seismic profiles. The two lines are from North Shafter Field and the northern boundary of North Shafter Field.

 

Figure 10. Regional conversion in upper interval of opal CT to quartz on P-Previous HitwaveNext Hit seismic profiles. One profile is from the northern boundary of North Shafter Field, and the other is from the north boundary of Rose Field.

 

Figure 11. Seismic profile, illustrating that an amplitude map necessarily is a composite of both upper and lower intervals.

 

 

Figure 12. Seismic profiles (top profile from Rose Field and lower profile from North Shafter Field), demonstrating that amplitudes downdip from the regional are the anomalies.

 

 

 

Rock Properties and Seismic Attributes

(Figures 1, 2, 3, 4 and 5)

An integrated study of the Miocene Monterey Formation in the San Joaquin Basin resulted in discovery of oil in its McLure Member and in the subsequent development of North Shafter and Rose oil fields (Figure 1). Integration of density vs. sonic data from well logs with 2-D (P-Previous HitwaveNext Hit) seismic data does not delineate the reservoir from the updip seal. The two corresponding reservoir and trap facies (hydrocarbon-bearing quartz and Opal-CT, respectively) have essentially the same impedance (velocity x density). On the other hand, the impedance of the downdip, water-bearing quartz stratigraphic section is similar to that of the bounding shales.

 

Discrimination of Lithology and Fluid Type by Seismic

(Figures 5, 6, 7, 8, 9 and 10)

Planning of a seismic program (Figure 6) subsequent to seismic modeling (Figure 5) of P- and S- Previous HitwaveNext Hit data focused on discriminating lithology and fluid type, given the following:

Opal-CT stratigraphic section is low-density.

Hydrocarbon-saturated, quartz section has low velocity.

C(converted)-Previous HitwaveNext Hit data images lithology rather than fluids.

Data from the seismic program shows that the gas-saturated oil in the quartz section in both an upper and a lower interval reduces the interval velocity in a similar fashion to the Gassmann effect in sandstones with high porosity (Figures 4 and 5). There is no seismic anomaly associated with the water-bearing quartz section in both intervals. Converted-Previous HitwaveNext Hit data delineates the Opal-CT section (with low density) from the quartz section (with higher density).

In effect, the P-Previous HitwaveNext Hit data define the downdip water-bearing interval, and the converted-Previous HitwaveTop data defines the updip diagenetic seal formed by the Opal-CT interval (Figures 7, 8, 9, and 10). The region in between these two areas is the hydrocarbon-bearing reservoir interval.

 

Seismic Anomaly

(Figures 1, 11, and 12) 

Amplitude anomalies of the upper interval and the lower interval are downdip from the regional (Figures 11 and 12). The seismic-anomaly map (Figure 1) presents a composite of both intervals (Figure 12).

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