dc.contributor.advisor | Kleppe, Jon | |
dc.contributor.advisor | Haukaas, Jarle | |
dc.contributor.author | Gram, Nina | |
dc.date.accessioned | 2019-09-11T09:01:50Z | |
dc.date.created | 2018-06-11 | |
dc.date.issued | 2018 | |
dc.identifier | ntnudaim:19213 | |
dc.identifier.uri | http://hdl.handle.net/11250/2615128 | |
dc.description.abstract | To model the future of a complex system, it is first necessary to be able to model the
past. Accurate and efficient reservoir modeling is crucial for production forecasting
and reservoir development. In this work the potential of using 4D seismic data for
ensemble based history matching of a reservoir model based on a North Sea oil field
is studied.
A general methodology for rock physics calibration for ensemble based history
matching is presented. The patchy cement rock physics model is used to calculate
synthetic seismic time strain values. The model is calibrated based on sensitivity
studies. It is concluded that for this particular rock physics model the time strain
is especially sensitive to the input parameter cement patchiness. This parameter
determines the volume fraction of consolidated, pressure insensitive rock in a patchy
cemented sandstone. An ensemble experiment varying this parameter between the
minimum and maximum value is performed. This experiment quantifies the sensitivity
and the resulting uncertainty in the time strain described by the ensemble
span. The ensemble experiment reveal a broad ensemble span of time strain values
for reservoir grid cells where pressure and saturation effects give significant time
strain changes. However the ensemble span is in some cases not able to cover the
observed time strain values. This is related to the fluid and pressure changes predicted
by the reservoir model being inconsistent with what the observed time strain
values are indicating. It is concluded that the cement patchiness affect the saturation
effect on the compressional velocities and therefore the time strain. When a
fluid substitution occurs the bulk density change and the bulk modulus change work
in opposite directions. When the cement patchiness is set to high values the increase
in the saturated bulk modulus make it less sensitive to fluid changes which might
cause the density change to be dominant. The reservoir parameter transmissibility is varied to alter the saturation and pressure changes in the reservoir. It is established
that varying both the cement patchiness and the transmissibility provide a broader
ensemble span covering more of the observed time strain values. This increases the
potential of getting a good 4D seismic history match for the studied area in the
reservoir model.
The study indicates that care must be taken in evaluating the saturation effect
on synthetic time strain generated with the patchy cement model due to varying
saturation effect. This research demonstrate a potential for using ensemble modeling
varying only rock physics parameters to quantify how sensitive the synthetic seismic
data is to the uncertain rock physics parameters. The results suggests that it can
be important to include uncertain rock physics parameters in addition to reservoir
parameters to be updated when performing 4D seismic history matching. | en |
dc.language | eng | |
dc.publisher | NTNU | |
dc.subject | Petroleumsfag, Reservoarteknologi og petrofysikk | en |
dc.title | Rock Physics Calibration for Ensemble Based 4D Seismic History Matching | en |
dc.type | Master thesis | en |
dc.source.pagenumber | 121 | |
dc.contributor.department | Norges teknisk-naturvitenskapelige universitet, Fakultet for ingeniørvitenskap,Institutt for geovitenskap og petroleum | nb_NO |
dc.date.embargoenddate | 10000-01-01 | |