FORMATION EVALUATION
PROJECT
PRESENTERS: Ruzin, Jala and Mahmud

SHALE VOLUME
10173 ft:
𝐼𝐺𝑅 =
𝐺𝑅𝑙𝑜𝑔 − 𝐺𝑅𝑚𝑖𝑛
𝐺𝑅𝑚𝑎𝑥 − 𝐺𝑅𝑚𝑖𝑛
=
53 − 11
99 − 11
= 0.477
𝑉𝑠ℎ = 0.083 23.7×𝐼𝐺𝑅 − 1 = 𝟎. 𝟏𝟗𝟗 𝒐𝒓 𝟏𝟗. 𝟗%

Density porosity
𝜑𝑑 =
𝜌𝑚𝑎 − 𝜌𝑏
𝜌𝑚𝑎 − 𝜌𝑓
=
2.65 − 2.420818
2.65 − 1
= 𝟎. 𝟏𝟑𝟖𝟗 𝒐𝒓 𝟏𝟑. 𝟖𝟗%
𝜌𝑚𝑎= 2.65 g/cm3
𝜌𝑓= 1 g/cm3
𝜌𝑏= 2.420818 g/cm3

Sonic Porosity
𝜑𝑠 =
5
8
×
∆𝑡𝑙𝑜𝑔 − ∆𝑡𝑚𝑎
∆𝑡𝑙𝑜𝑔
=
94.27595 − 55.6
94.27595
= 𝟎. 𝟐𝟓𝟔𝟒 𝒐𝒓 𝟐𝟓. 𝟔𝟒%
∆𝑡𝑚𝑎= 55.6
us
ft
∆𝑡𝑙𝑜𝑔= 94.27595 us/ft

Neutron porosity
𝜑𝑁 = 𝟎. 𝟐𝟑𝟖𝟕𝟏𝟏𝟓 𝒐𝒓 𝟐𝟑. 𝟖𝟕%

Average or Total porosity
𝜑𝑎 =
𝜑𝑑 + 𝜑𝑠 + 𝜑𝑛
3
=
13.89 + 25.64 + 23.87
3
= 𝟐𝟏. 𝟏𝟑%

Effective porosity
𝜑𝑒 = 𝜑𝑡 × 1 − 𝑉𝑠ℎ = 21.13 × 1 − 0.199 = 𝟏𝟔. 𝟗𝟐𝟓 %

Water Saturation
𝑆𝑤 = (
𝑎 × 𝑅𝑤
𝑅𝑡 × 𝜑𝑚)
1/𝑛
= (
0.81 × 0.066
47.38 × 0.242552)0.5
= 𝟏𝟑. 𝟖𝟒𝟖 %
a = 0.81
m = 2
n = 2
𝑅𝑤 = 0.066 ohm m
RESERVOIR INTERVAL: 10362-11160 ft

𝑆ℎ = 1 − 𝑆𝑤 = 1 − 0.13848 = 𝟎. 𝟖𝟔𝟏𝟓𝟐 𝒐𝒓 𝟖𝟔. 𝟏𝟓𝟐 %
Sh > 60 %, it is considered as pay zone for the well.
Negative hydrocarbon saturation values show
water bearing formations.

Permeability
𝑘 = (
100𝜑2.25
𝑆𝑤𝑖
)2
= (
100 × 0.242552.25
0.2
)2
= 𝟒𝟐𝟔. 𝟏𝟒 𝒎𝑫

THANKS FOR ATTENTION