This document contains information from a reservoir simulation project. It includes: 1. Names of team members and thanks to the project supervisor. 2. An assignment to calculate the original oil in place (OOIP) using material balance and estimate porosity, and match the water production rate in the history. 3. Details of the reservoir data, equations, and spreadsheets used to calculate OOIP and porosity. 4. Comments that the model achieved a good history match for wellhead pressure and oil rate and that changes made to parameters like porosity and permeability were reasonable.

2.  LIM ZHEN HAO 1001231762
 TAN HAN YEONG 1001231861
 AU WAI SOON 1001335227
 MOHAMMED TAWFIK 1001334767

3.  Team Eclipse would like to express our
special thanks of gratitude to our project
supervisor, Mr. PremKumaran who gave us
the golden opportunity to do this wonderful
project which also helped us to increase the
knowledge in Reservoir Simulation and we
came to know about so many new things

4.  Harold History – Apply the Material Balance
equation to calculate the original stock tank oil in
place (STOOIP) and from that estimate a single
porosity value to use in the model.
 Adjust history matching parameters to give correct
water production rate.
 Predict optimum development strategy for
remainder of field life.

10.  Assigned to use MBE EQN to calculate (STOOIP) and estimate Porosity.
 1.
 2. With the aid of spread sheet CM2Ex1_RECIP.xls from Core Module 2 to
assist with this calculation
 3. Use the table below which contains pressures and cumulative production
for the initial period of production in this reservoir, before there is any water
injection and before water breakthrough.
 Reference Point is 1 Jan 2006 where the BHP & Cum. Oil Prod are
 4. STOOIP = N = (bulk volume / Bo(init)) x Ø x NTG x Soil to calculate Ø.
4884.6 133597

14.  According to previous data, it has shown a
good match on the model.
 Usually we determine a good match from
matching individual well RFT pressure,
individual well gas/oil ratio, water-cut and
shut-in pressure and avg Reservoir pressure
 In Harold Case, we are able to match WBHP &
FOPR [ Line overlapping ]
 With % diff only 0.000929

15.  Several ways to decide if a match is satisfactory. If a
coarse study is being performed, the quality of the
match between observed and simulated parameters
does not need to be as accurate as it would be for a
more detailed study.
 If the model has a good match but the changes made
were not realistic, then the model results should be
viewed with skepticism.
[ Changes in Harold case are reasonable ]
 Ultimate objective of reservoir simulation is not
achieving a history match; it is being able to
reasonably predict the future performance of the
reservoir. The history match is only an intermediate
step in the modeling process.

16.  History match after start of water injection on 01/05/06 up to
01/09/08
INCLUDE
'includesSCHED-HIST-TO-1-may-2006.INC' /
INCLUDE
'includesSCHED-HIST-TO-1-Sep-2008.INC' /
- Parameters adjusted : Porosity, Net-Gross Ratio, Perm XYZ

21.  Using Trials and Error
 On water production rate
- Water Influx
- Bottom Hole Pressure
- NTG
- Porosity
- Permeability XYZ

24.  By Adding 1 INJ Well & 1 PROD Well at year 2008
October based on extra budget.
 Simulation for these additional wells lasted until
year 2010
 Initial Recovery Factor = 0.32
 Recovery Factor has seen to be increased to 0.42
(42 % )with water flooding
 Globally, the overall recovery factors for combined
primary and secondary recovery range between 35
and 45%.

25.  Never include I1 & D10 in year 2010 SCHED
HIST FILE which caused initial wells stop its
production after 2008 and only I2 & D11 are shown
in FloViz diagram. ( 4 wells are supposed to appear
at the same time in the FloViz diagram )