APENDIX OF PETROPHYSICAL WORKFLOW FORMULA

petrophysics workflow apendix

1. 8.2 KEY STEP 1 : Petrophysical Intrpretation and Reservoir Zonation 1a. Reservoir Zone Top and Bases all wells Fault Identification & missing / Repeat Section all wells 1b. Total Porosity = PORD Sand Porosity = PORSAND Shale Volume = VSH Net to Gross = NGSD Pre Prod Fluid Distribution = (FWL, FOL, GOC, GDT, GWC, OWC, OUT, ODT, WUT) No 10.X ITEMS REMARKS COMPLIANCE (YES/NO) 2 Measured depth in wells shall be converted to TVDSS 10.2   3 All log data & core shall be matched to the PRIMARY DEPTH (First MWD log) 10.3   4 RESERVOIR ZONES tops/bases & fluid contact shall be reported to the nearest 0.1524 m 10.4   4.1 MTD sand reservoir with oil bearing shall be set to null 10.4.1   5.1 Marker tops & bases of RESERVOIR ZONES shall be listed MD & TVDSS 10.5.1   5.2 Fault picks & missing section of RESERVOIR ZONES shall be listed MD & TVDSS 10.5.2  

2. No APENDIX PETROPHYSICS ITEMS REMARKS COMPLIANCE (YES/NO) 1 Sampling rate 0.1524 increments 10.6.1   2 Value shall be reported to 3 decimal places 10.6.1     VSH 3 Thomas Stiber Methodology shall be used 10.6.3   4 Calculate Neutron-Density Separation Curve (RPD). Difference zone & fluid settings. 10.6.4   5 Assign Density ( Rhoma ) & Neutron ( Nma ) matrix. Parameter table included. 10.6.5   6 Assign Density ( Rhofl ) & Neutron ( Nfl ) Fluid Points. Parameter table included. 10.6.6   7 For new cored well, rhofl will be calculated using determined equation 10.6.8   8 Assign Density ( Rhosh ) & Neutron ( Nsh ) Shale Points. 10.6.9   9 Calculate Shale Volume ( Vsh ) using determined equation. 10.6.10   10 Unreliable Neutron log shall be replace with GR log in Thomas- Stiber Method 10.7   11 Guidance for Vsh calculation using GR log 10.8   12 Vsh log shall be nulled in the vent no reliable data available. This nulled interval shall be populated in model. 10.8.3 & 4     Porosity Total & Net 13 Bulk Total Porosity (PORD) calculated using determined equation 10.6.7   14 Calculate Sandstone & shale porosity using determined equation. 10.9   15 Calculate Sands & shale volume using Thomas-Stieber- Juhasz methodology. 10.10   16 Calculate Total porosity of Sandstone/Sandstone Laminae 10.12     NTG 17 Net Sand cut off: NGSD>0.1 & PORSAND >=0.14 10.13   Original Fluid Distribution 18 Observed contact from well log data shall be tabulated 10.9.1   19 Observed contact shall only be determied in the net reservoir 10.9.2   20 Residual Oil/Gas cannot be used for observed contact determination 10.9.3  

3. 10.6 PETROPHYSICAL INTERPRETATION

4. 10.6.4 Calculate Neutron – Density Separation Curve (RPD)

5. 10.6.5 Assign Density Matrix ( Rhoma ) & Neutron Matrix ( Nma ) point for each Reservoir zone

6. 10.6.6 Assign Density ( Rhof ) and Neutron ( Nfl ) Fluid Points

7. 10.6.7 Bulk Total Porosity (PORD)

8. 10.6.8 For New Cored Well, PRE-PRODUCTION in-situ stress corrected core porosity

9. 10.6.9 Asign Density ( Rhosh ) and Neutron ( Nsh ) shale point

10. 10.6.10 Calculate Shale Volume (VSH Final) 10.7 Unreliable Log Data

11. 10.8 Vsh from Vsh GR method

12. 10.9 Calculate Sandstone and Shale Porosity End Point

13. 10.10 Calculate Sand and Shale Volume

14. 10.12 Calculate Total Porosity of Sandstone / Sandstone Laminae (PORSAND) 10.13 Net Sand Cut-Offs 10.11 Not Used

15. 10.14 Original Fluid Distribution in Wells

16. APENDIX