Waterflood Study of High Viscosity Saturated Reservoir with Multiwell Retrospective Testing and Cross-Well Pressure Pulse-Code Testing
- Artur Aslanyan (Nafta College) | Igor Kovalenko (Gazpromneft STC) | Ilnur Ilyasov (Messoyahaneftegas) | Danila Gulyaev (Sofoil) | Anton Buyanov (Sofoil) | Kharis Musaleev (Sofoil)
- Document ID
- Society of Petroleum Engineers
- SPE International Heavy Oil Conference and Exhibition, 10-12 December, Kuwait City, Kuwait
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 5.6.11 Reservoir monitoring with permanent sensors, 2 Well completion, 2.3 Completion Monitoring Systems/Intelligent Wells, 5.6 Formation Evaluation & Management, 5.4.1 Waterflooding, 2.3.2 Downhole Sensors & Control Equipment, 5 Reservoir Desciption & Dynamics, 4.3.4 Scale, 5.4 Improved and Enhanced Recovery, 5.1.5 Geologic Modeling
- waterflood, multiwell retrospective testing, high viscosity, cross-well pressure pulse code testing, connectivity
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A waterflood study has been performed on a high viscosity saturated oil deposit with bottom water aquifer and complex geometry driven by regional tectonic stress and numerous shale breaks. The commercial production is on-going for the last 2 years with medium length (1,000 m) horizontal wells and start facing formation pressure decline.
The foremost challenge was to check if injection pressure is transmitted through the oil pay without leaking into the bottom water aquifer. The next question was whether the full net pay is engaged in pressure support under water injection. The last question was to check on permeability anisotropy.
The transmissibility between wells have been assessed with multi-well retrospective testing (MRT) of permanent downhole gauges (PDG) historical data records which are a part of standard ESP telemetry. The fluid mobility and hydrodynamic average thickness between water injector and oil producers have been estimated with cross-well pulse-code pressure pulsations (PCT) based on pre-designed rate variation sequence [1 – 8]. The pulse-code sequence was designed in full-field 3D dynamic model to ensure capturing response in two contrast scenarios: with pressure propagating via aquifer and via oil pay, which have a high degree (30:1) of fluid mobility contrast. The data processing and interpretation was performed in PolyGon™ software  using the pulse-code decomposition for PCT tests and multi-well deconvolution for MRT tests.
The cross-well mobility in injector-producer pairs from PCT was indicating that pressure was fairly propagating via oil pay. The effective thickness of PCT-scanned area turned to be in-line with net oil column thickness from 3D geological model.
The MRT-scanned area was showing much lower transmissibility than 3D geological model prediction which was interpreted as the most part of the oil pay in this area has intermittent connectivity due to severe shale breaks development. This gives strong indication on searching the way to commingle production from isolated reservoir elements in this area [8 – 14].
The areal analysis of permeability in PCT-scanned and MRT-scanned areas has indication for 1:2 permeability anisotropy transversal to the regional stress direction which should be reconfirmed by a dedicated study.
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