1. RESERVOIR SIMULATION
By: Mukesh Mathew
Team M

2. RESERVOIR MODELLING
Static Model
• Appropriate grid size is used to balance
between the simulation running time and
heterogeneity of the formation
• Well logs (corrected against core porosity
and permeability) are used for correlation
and layering
• Porosity ranging from 10 to 26% and
permeability ranging from 10 to 1000mD
Uncertainties
•Correlation is done based on team member’s understanding and consultation, but this
may vary from one individual to another.
•Upscaling may inherit uncertainty

3. DYNAMIC MODEL
 Static model from PETREL was used to create dynamic model.(ECLIPSE 100-
Black oil model)
 Data's obtained from PVT,DST, and well test analysis along with normalized
capillary curves and relative permeability curves were used as the input parameters
 Natural depletion
 Water flooding
 Gas injection
 EORs- Water Alternating Gas and Polymer flooding
Considered recovery mechanisms

4. Comparison of available development options

5. OPTIMUM SCENARIO[13 producer
wells(11 vertical,2 horizontal) and 8 injector
wells]
 FOE =55% and Water cut = 74.78%
1st
stage
(2 years)
2nd
stage
(4 Years)
3rd
stage
(19 years)
Total
(25 years)
No. of
producer
wells
3 4 6
(4 Vertical,
2 Horizontal)
13
(11 Vertical,
2 Horizontal)
No. of
injector wells
5 0 3 8

6. Proposed location for drilling centre
Oil water contact @ 8670 ft TVDSS
Producer wells
Water injection wells
• 13 oil producers, 8 water injectors
LOCATION OF WELLS

7. SIMULATION RESULTS-OPTIMUM SCENARIO

8. ALTERNATE DEVELOPMENT PLANS
1. Gas injection(5 WATER INJECTORS, 3 GAS
INJECTORS AND 13 PRODUCERS)
 FOE=52.3% and water cut =67.52%.
1st
stage
(2 years)
2nd
stage
(9 Years)
3rd
stage
(14 years)
Total
(25 years)
No. of
producer
wells
3 4 6
(4 Vertical,
2
Horizontal)
13
(11 Vertical,
2
Horizontal)
No. of
injector
wells
5
(water
injectors)
0 3(Gas
injectors)
8
(5 water
injectors, 3
gas injectors)

9. 3. Polymer flooding
 consists of 8 injector wells which inject polymer of viscosity
2cP with 13 producer wells (11 vertical, 2 Horizontal)
 FOE=49.21% and water cut =52.7%.
2. Water Alternating Gas[13 producers (11vertical,
2Horizontal) and 8 injector wells]
 Same build up plan like the water flooding but after water injection
for the first 2 years, gas is injected for the next two years.
 FOE=56.02% and water cut =74.9%.

10. NUMBER OF PRODUCER WELLS –CALCULATION
STOOIP= 371.4MMBBL
The oil production has to reach the plateau phase as soon as possible which
corresponds approximately 10% of STOOIP.
10% STOOIP= 37.14MMBBL
Average flow rate = 3170 STB/day( based on the datas obtained from
appraisal wells)
Plateau period = 5*365 days
Number of producer wells =(10% STOOIP)/[Average flow rate * Plateau period )
= 6-7 producer wells minimum)
Number of injection wells used are determined on the basis of number and
production rate of producer wells such that water injected balances the oil
recovered from the reservoir.
APPENDIX