Scope of work completed

Completed tasks

1. Data base in Techlog software was created. All core data, well tests, pressures, logs and well deviation surveys were loaded;
2. Logs were calibrated by depth and levels;
3. Mud log analysis;
4. Formation correlation by logs data;
5. Porosity models by logs (P90, P50, P10 cases);
6. Net pay criteria by logs (P90, P50, P10 cases);
7. Permiability models by logs (P90, P50, P10 cases);
8. Water saturation models by electrical logs (P90, P50, P10 cases);
9. Capilarity model of water saturation (P90, P50, P10 cases);
10. OWC in different regions was defined be logs and well tests;
11. Estimation of linear oil volumes;
12. Analysis of uncertainties between probability cases (P90, P50, P10);
13. Digital CPI were created for future 3D geological and simulation modeling of 3 cases (P90, P50, P10);
14. Data base of all available data (3D seismic, 2D seismic, well head coordinates, deviations, logs and well tops for reservoir, Digital CPI for 3 cases (P90, P50, P10)) was created in Petrel software;
15. Pre-processing of 3D and 2D seismic;
16. 3D cube was loaded to Hampson-Russel software and top of the reservoir was tie to seismic data;
17. wo way time interpretation of the reservoir;
18. Time to depth conversion using constructed velocity model;
19. Created structural map of top of the reservoir allow us to delineate boundaries of the oil field;
20. Dynamic interpretation of seismic using 13 different attributes;
21. Deep attributes analysis was performed. Correlation of all petrophysical parameters vs. all various attributes;
22. Detected most sensitive attributes to reservoir parameters for future 3D geo modeling;
23. Geological modeling of P50 case;
24. OOIP estimation of P50 case;
25. Model upscaling of P50 case.

Scope of future work

1. Geological modeling of 2 cases (P90, P10);
2. OOIP estimation of 2 cases (P90, P10);
3. Model upscaling of 2 cases (P90, P10);
4. Actualization of PVT due to production reports;
5. History matching of 3 cases (P90, P50, P10);
6. New well locations and drilling schedule;
7. Simulation modeling of 3 cases (P90, P50, P10);
8. Production profiles prognosis of 3 cases (P90, P50, P10);
9. Supporting of 3D simulation model due to new drilling and production in order to decrease investment uncertainties of 3 cases (P90, P50, P10);

The completed tasks developed new approach to both reservoirs within the area and beyond. Based on that research we can specify new horizon of development of
Reservoir as major regional play and therefore we appear to be pioneer of the full scale development of this type of reservoir in the region. We simulate 3,5 and 7 stage fracks to determine to most suitable for Reservoir in order to maintain high level of daily flow rate first 2 to 3 years.

Say 2500 bbl/d instead of 1200. Subsurface team by the end of the task will create simulation 3D model that will reduce investment risks and increase success of
future drilling. Current FDP will let company to develop the reservoir for at least 20 more years and during that time our professionals will be monitoring this process.