Tracking Production Changes in a Turbidite Reservoir Using 4D Elastic Inversion

McInally, A.; Kunka, J.; Garnham, J.; Redondo-López, T.; Hansen, Laurence

doi:10.3997/2214-4609-pdb.15.p665

Cited by 4 publications

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“…4 supports the notion that saturation dominates. Indeed, there are many examples of detecting fluid contact movement (Kloosterman et al 2001;McInally et al 2001) or saturation changes due to waterflooding (Lumley et al 1999;Johann et al 2009). In many instances a signal is observed despite fairly high non-repeatability levels for the 4D seismic data (with an NRMS metric of 0.40 or above).…”

Section: Observations From the Literaturementioning

confidence: 99%

An insightful parametrization for the flatlander's interpretation of time‐lapsed seismic data

Alvarez

MacBeth

2013

Geophysical Prospecting

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A B S T R A C TAn approximation is developed that allows mapped 4D seismic amplitudes and timeshifts to be related directly to the weighted linear sum of pore pressure and saturation changes. The weights in this relation are identified as key groups of parameters from a petroelastic model and include the reservoir porosity. This dependence on groups of parameters explains the inherent non-uniqueness of this problem experienced by previous researchers. The proposed relation is of use in 4D seismic data feasibility studies and inversion and interpretation of the 4D seismic response in terms of pore pressure and water saturation changes. A further result is drawn from analysis of data from the North Sea and West Africa, which reveals that the relative interplay between the effects of pore pressure and saturation changes on the seismic data can be simplified to the control of a single, spatially variant parameter C S /C P . Combining these results with those from published literature, we find that C S /C P = 8 appears to be a generality across a range of clastic reservoirs with a similar mean porosity. Using this C S /C P value, an in situ seismic-scale constraint for the rock stress sensitivity component of the petroelastic model is constructed considering this component carries the largest uncertainty.

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Section: Observations From the Literaturementioning

confidence: 99%

An insightful parametrization for the flatlander's interpretation of time‐lapsed seismic data

Alvarez

MacBeth

2013

Geophysical Prospecting

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An evaluation of pore pressure diffusion into a shale overburden and sideburden induced by production-related changes in reservoir fluid pressure

et al. 2012

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Quantifying remaining oil saturation using time-lapse seismic amplitude changes at fluid contacts

Alvarez

MacBeth

Brain

2016

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Our study shows that time-lapse changes in the amplitude of the seismic reflection at an oil–water contact (OWC) and/or produced OWC can be used to estimate directly the displacement efficiency of water displacing oil, E D , without the need of a rock and fluid physics model. From this value, it is possible to determine the remaining oil saturation if required. A preliminary application is performed using several published literature examples, which are reinterpreted to assess the average E D and ensure that the theory is consistent with expectations. Next, a North Sea field model with a known E D is used to create fluid-flow predictions and the corresponding synthetic time-lapse seismic data. Application to these data again confirms the basic principles of the method and defines the accuracy when applied to 4D seismic data. Finally, an observed 4D seismic dataset from a producing field in the North Sea is analysed. The results suggest a displacement efficiency of between 21 and 65% with an accuracy of 3% due to data non-repeatability (with a NRMS of between 11 and 13%). Given an average irreducible water saturation of 0.32, this calculates the remaining oil saturations at between 24 and 53% for this field. A prerequisite for use of the proposed OWC approach is that a discrete contact be interpreted on either the 3D or 4D seismic datasets. Therefore, successful application of this technique requires moderate- to high-quality seismic data and a fairly thick reservoir sequence without significant structural complexity.

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Tracking Production Changes in a Turbidite Reservoir Using 4D Elastic Inversion

Cited by 4 publications

References 0 publications

An insightful parametrization for the flatlander's interpretation of time‐lapsed seismic data

An insightful parametrization for the flatlander's interpretation of time‐lapsed seismic data

An evaluation of pore pressure diffusion into a shale overburden and sideburden induced by production-related changes in reservoir fluid pressure

Quantifying remaining oil saturation using time-lapse seismic amplitude changes at fluid contacts

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