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7th Middle East Geosciences Conference and Exhibition
Manama, Bahrain
March 27-29, 2006
1 Chevron Energy Technology Company, 1500 Louisiana, Houston, TX 77002, phone: 832-854-6724,
[email protected]
2 Chevron Energy Technology Company, 1500 Louisiana, Houston, 77002
3 Divided Zone Group, Kuwait Oil Company
4 Saudi Arabian Texaco, 1500 Louisiana, Houston, 77002
A design of experiments
(DoE) workflow was used to evaluate the Jurassic-age Humma Marrat reservoir in the Partitioned
Neutral Zone (PNZ). The Humma Marrat reservoir consists of productive limestone and dolomite intervals separated by
very tight limestone and/or shaly limestone zones. The reservoir was discovered in 1998 and produces from five wells.
Additional delineation wells were drilled in 2005.
Connectivity and volumetric uncertainties were evaluated using 13 earth models defined by parameter combinations given
in a Plackett-Burman design of experiments
(DoE) table. The response variable was cumulative oil production through 30
years. Parameters included in the first level DoE analysis were structural uncertainty (seismic interpretation and time -todepth
conversion), facies distribution, porosity and Sw histograms, original oil/water contact, porosity semivariogram range,
permeability multiplier, fault compartmentalization, and fault transmissibility. Only the porosity histogram emerged as
statistically significant.
The second level DoE focused on “traditional” dynamic uncertainty parameters including aquifer support, rock
compressibility, heavier oil distribution, kv/kh, PI multiplier, Sorw, and krw@Sorw. An additional uncertainty included in the
second level analysis was the extent to which the Humma structure may be open to the south towards the Jauf structure in
Saudi Arabia. This was studied using a pore volume multiplier in the the southern-most portion of the model
. Only the earth
model
and PI multiplier uncertainties were statistically significant.
The results of the DoE analysis were used to define the reservoir models for development optimization. The P50 model
was
used to screen development options that included well spacing, well type, and horizontal well length. Economic analyses
were conducted to select the optimum development scenario using the P10, P50, and P90 reservoir models.