Injectites Effect from Connectivity Within the Lianzi Development, Angola/Congo 14K /A-IMI Unit
Kathleen Mabe1, Linda Martinsen1, and Sebastien Strebelle2
1South Africa Business Unit, Chevron, Houston, TX
2Energy Technology Co., Chevron, San Ramon, CA
The Lianzi development lies on the border of Angola Block 14 and Republic of Congo within the 14K / A-IMI Unit. Chevron as Unit operator along with participants; Total, ENI, SNL P&P, SNPC, and Galp have been exploring and appraising the region since the unit agreement was signed in 2002. Lianzi field was discovered in 2004 by drilling the Lianzi-1 discovery well followed by successful delineation in 2005 with the Lianzi-2 appraisal well.
The Lianzi base case development comprises a Miocene channel-levee system with two separate oil pools. Lianzi Central and West are combination structural and stratigraphic traps. Lianzi reservoirs are 6000-7000 feet below mud line in 2000 feet of water and contain 37 degree API oil. The reservoir has been evaluated using 3D model-based probabilistic OOIP and recovery assessments to define the Reservoir Basis of Design.
The Lianzi-1 well cored 36 feet of injectites with excellent reservoir properties comparable to the channel axis facies. Reservoir models are built incorporating injectites to estimate their impact on OOIP volumes and recoveries. Training images for Multi Point Statistics (MPS) are defined by using measurements of injectites in field outcrops. High resolution 3D seismic is also used to identify areas of injectition. Simultaneous inversion is used to predict sand in the reservoir model. Communication between channel elements is modeled in simulation by building an accurate geological model with injectites and using the pinch out option in the simulator.
Upside potential is defined for Lianzi field by incorporating injectites into the reservoir modeling work flow. Modeling methods are continually improving as we learn more about injectites from outcrops, core and seismic.
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