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using neuramap software the location of the 3 wells was determined by obtaining the coordinates for each well.
next thing was to digitalize the contour map using the same software.
then both results was exported to a file in order to use them later for well positioning in petrel.

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Range to determine the type of fluid based on pressure gradient obtained

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Payzone is a area of producing oil and gas. To determine which area have more hydrocarbons.
Based on wild cat log, the payzone is 4200-4230 ft.
For appraisal well 1, around 4300-4328 ft.
For appraisal well 2, 4600-4610 ft.
How it determined? Based on the resistivity log, gamma ray log, sp log and sonic log.
- Resistivity represent HC in the well. To the right indicates more HC
- GR represent organic material. To the left indicates more organic material
- SP log represent the permeability of the reservoir. To the right it is more permeable.
- Sonic log to the left indicates high porosity.

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1. Need to determine the pressure gradient of each well (Wildcat, Appraisal 1, Appraisal 2).
2. From Depth 4200ft until 4609ft, pressure gradient obtained is 0.312 psi/ft to show the depth contains oil only.
3. At 4609 ft, there is change of gradient in the graph which is 0.456 psi/ft to show the presence of water in the well.
4. The change of gradient occurs at Appraisal Well 2.
5. The intersection of both lines is at depth 4609 ft as the oil water contact occurs at that depth.

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1. Using PVTP software
2. PVT analysis is modelled using CCE.
3. Constant the temperature (185 oF), and using pressure from 14.7 psia until 2799.7 psia with 20 values to plot the graph.
4. Oil Viscosity graph - Obtained oil viscosity 0.65 cp at 2358 psia (bubble point).
5. Oil FVF graph - Obtained Bo 1.34 Rb/STB at 2358 psia.
6. GOR graph - Obtained 666.7 scf/STB at 2358 psia.
7. Liquid dropout - Starting from 2358 psia onwards, 100% liquid presence.

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1. Cricondentherm - The maximum temperature at which liquids and gas can coexist which is 802.9 oF.
2. Cricondenbar -  The maximum pressure which no gas can be formed above the point. (2897.8 psia)
3. Reference point used is 185 oF , 2799.7 psia.
4. Reference point is above the curve line (bubble point) to show that the reservoir is undersatured (no gas exist).

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*The focus is on the wireline_log AW2. However the same method used to obtain the data in AW1 and AWC.

The first thing that was done was to extract the wireline log data into excel.

Once extracted, graph was created for each logs versus the depth.

Then find the volume of shale(Vsh), porosity, Saturation (Sw and So)

1. Vsh calculation

Determine from the GR log and SP log. After getting both the value then find the average.

Need to find the max and min value of. The max indicate shale while min indicate clean sand.

1. Porosity calculation

Porosity determination used three logs(sonic,neutron,density). For each logs porosity, its effective porosity need to be calculated. From the eff porosity the average is then determined.

For density porosity, the matrix density used is 2.65 while its fluid density is 1.

For sonic, matrix travel time used is 55.5 while the fluid time travel is 189.

1. Saturation determination

Sw can only be found in the well which has the OWC. In our case, AW2 has the OWC while the other two doesn’t have. That’s why the Sw is only calculated in AW2. Water saturation is determined bybusing the Archie eqn. Where the constant a=1, m=2, n=2. While So is determined by using the eqn 1-Sw.

1. Permeability calculation

Permeability also determined in the well that has the owc because the eqn used needs the value of sw. while the other two wells the data calculated only for Vsh and porosity.