Why Monitoring With a Single Downhole Microseismic Array May Not Be Enough: A Case For Multiwell Monitoring of Cyclic Steam in Diatomite
- Anthony S. Murer (Aera Energy) | Greg R. McNeish (Aera Energy) | Theodore I. Urbancic (ESG Canada) | Marc Prince (ESG Canada) | Adam M. Baig (ESG Canada)
- Document ID
- Society of Petroleum Engineers
- SPE Reservoir Evaluation & Engineering
- Publication Date
- June 2012
- Document Type
- Journal Paper
- 385 - 392
- 2012. Society of Petroleum Engineers
- 1.6 Drilling Operations, 3 Production and Well Operations, 5.4.6 Thermal Methods, 2.4.3 Sand/Solids Control, 3.2.3 Hydraulic Fracturing Design, Implementation and Optimisation
- 0 in the last 30 days
- 447 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 10.00|
|SPE Non-Member Price:||USD 30.00|
Nine wells were drilled to test cyclic steam stimulation as a recovery mechanism in the diatomite reservoir in the Belridge field. Microseismic monitoring was proposed to evaluate steam chest and fracture growth. A series of models were constructed to determine both microseismic event detectability and locatability. The modeling indicated that poor signal-to-noise ratios would constrain the ability to locate events using a single array. As a result, three monitoring wells were installed. The purpose of this paper is to evaluate the microseismic event location results obtained from the 3-well solution and compare them with the solutions obtained when turning off one or two of the arrays. This first phase of investigation was performed on the sand-propped hydraulic fracture stimulation prior to the cyclic steam operations. This study may be applied to other areas including imaging hydraulic fracture stimulations in shale plays, reservoir steam monitoring, or in any area where location precision in microseismic monitoring is necessary.
It has been demonstrated in the field that the monitoring range of a microseismic system can be increased and the potential for locating microseismic events improved by installing multiple arrays having overlapping radii of observation. Innovative system design, deployment techniques and operational procedures, plus advanced multi-well processing strategies have all contributed to creating a growing data set with over 4,000 events recorded during the first 13 months of operation. Results of turning off arrays showed increased location error with two well solutions and a significant increase in error with one-well solutions notwithstanding the reduction in event location count due to lack of multi-phase signals on a single array. Azimuth errors in single microseismic observation well solutions result in disperse interpreted fracture geometry and in mis-interpretation.
Overall, our observations show that, for both multi- and single-phase events, the observed detection limits and size distribution of the seisms has far exceeded those originally predicted by the earlier modeling.
|File Size||9 MB||Number of Pages||8|
Bowman, S. and Urbancic, T. 2009. Determining EffectiveHydraulic Fracture Volume Utilizing PSO and Seismic Deformation. Paper Paper334 presented at the Frontiers + Innovation 2009 CSPG CSEG CWLS Convention,Calgary, 4-8 May.
De, G.S., Winterstein, D.F., and Meadows, M.A. 1994. Comparisonof P- and S-wave velocities and Q's from VSP and sonic log data.Geophysics 59 (10): 1512-1529. http://dx.doi.org/10.1190/1.1443541.
Fast, R.E., Murer, A.S., and Timmer, R.S. 1994. Description andAnalysis of Cored Hydraulic Fractures--Lost Hills Field, Kern CountyCalifornia. SPE Prod & Fac 9 (2): 107-114.SPE-24853-PA. http://dx.doi.org/10.2118/24853-PA.
Maxwell, S.C. 2009. Assessing the Impact of MicroseismicLocation Uncertainties On Interpreted Fracture Geometries. Paper SPE 125121presented at the SPE Annual Technical Conference and Exhibition, New Orleans,4-7 October. http://dx.doi.org/10.2118/125121-MS.
Murer, A.S., McClennen, K.L., Ellison, T.K., et al. 2000. SteamInjection Project in Heavy-Oil Diatomite. SPE Res Eval & Eng 3 (1): 2-12. SPE-60853-PA. http://dx.doi.org/10.2118/60853-PA.
Rawlinson, N. and Sambridge, M. 2004. Wave frontevolution in strongly heterogeneous layered media using the fast marchingmethod. Geophys. J. Int. 156 (3): 631-647. http://dx.doi.org/10.1111/j.1365-246X.2004.02153.x.
Reyes-Montes, J.M., Pettitt, W., Hemmings, B., Haycox, J.R.,Andrews, J., and Young, R.P. 2009. Application of Relative Location Techniquesto Induced Microseismicity from Hydraulic Fracturing. Paper SPE 124620presented at the SPE Annual Technical Conference and Exhibition, New Orleans,4-7 October. http://dx.doi.org/10.2118/124620-MS.
Sethian, J.A. and Popovici, A.M. 1999. 3-D traveltimecomputation using the fast marching method. Geophysics 64(2): 516-523.
Swanson, P.L., Estey, L.H., Boler, F.M., and Billington, S.1992. Accuracy and Precision of Microseismic Event Locations in Rock BurstResearch Studies. Report of Investigations 9395, US DOI/Bureau of Mines,Washington, DC, http://www.cdc.gov/niosh/mining/pubs/pdfs/ri9395.pdf.
Vinegar, H.J., Wills, P.B., DeMartini, D.C., et al. 1992.Active and Passive Seismic Imaging of a Hydraulic Fracture in Diatomite. JPet Technol 44 (1): 28. SPE-22756-PA. http://dx.doi.org/10.2118/22756-PA.
Warpinski, N.R., Waltman, C.K., Du, J., and Ma, Q. 2009.Anisotropy Effects in Microseismic Monitoring. Paper SPE 124208 presented atthe SPE Annual Technical Conference and Exhibition, New Orleans, 4-7 October.http://dx.doi.org/10.2118/124208-MS.