scholarly journals The Optimization Study of Field Development Plan of Marginal Offshore, Deep Water, Turbidite, Heavy-Oil Field with Gas Cap—A Case of Congo A Oil Field

2015 ◽  
Vol 03 (06) ◽  
pp. 193-201
Author(s):  
珂 李
Keyword(s):  
Deep Water ◽  
Heavy Oil ◽  
Oil Field ◽  
Development Plan ◽  
Field Development ◽  
Optimization Study

Oil Reserves Evaluation and Field Development plan of Hakim Oil Field in Libya

2016 ◽  
Vol 18 (1) ◽  
pp. 39-53
Author(s):  
Omar Salih ◽  
Mahmoud Tantawy ◽  
Sayed Elayouty ◽  
Atef Abd Hady
Keyword(s):  
Oil Field ◽  
Development Plan ◽  
Field Development ◽  
Oil Reserves

Improvement of Drilling Technology for the Yarega Heavy Oil Field Development by SAGD Method With Counter Producing and Injecting Wells

2014 ◽  
Author(s):  
Denis S. Loparev ◽  
Mikhail V. Chertenkov ◽  
George V. Buslaev ◽  
Asif A. Yusifov ◽  
Aleksey V. Klyavlin
Keyword(s):  
Heavy Oil ◽  
Oil Field ◽  
Field Development ◽  
Oil Field Development ◽  
Drilling Technology

Conceptual Field Development Plan for X Field

2021 ◽  
Author(s):  
Khadijah Ibrahim ◽  
Petrus Nzerem ◽  
Ayuba Salihu ◽  
Ikechukwu Okafor ◽  
Oluwaseun Alonge ◽  
...  
Keyword(s):  
Capital Expenditure ◽  
Probabilistic Approach ◽  
Cost Effective ◽  
Oil Field ◽  
Development Plan ◽  
Recovery Factor ◽  
Reservoir Rock ◽  
Production Forecast ◽  
Field Development ◽  
Water Cut

Abstract The development plan of the new oil field discovered in a remote offshore environment, Niger Delta, Nigeria was evaluated. As the oil in place is uncertain, a probabilistic approach was used to estimate the STOOIP using the low, mid, and high cases. The STOOIP for these cases were 95 MMSTB, 145 MMSTB and 300 MMSTB which are the potential amount of oil in the reservoir. Rock and fluid properties were determined using PVT sample and then matched to the Standing correlations with an RMS of 4.93%. The performance of the different well models were analyzed, and sensitivities were run to provide detailed information to reduce the uncertainties of the parameters. Furthermore, production forecast was done for the field for the different STOOIP using the predicted number of producer and injector wells. The timing of the wells was accurately allocated to provide information for the drillers to work on the wells. From the production forecast, the different STOOIP cases had a water cut ranging from 68-73% at the end of the 15-year field life. The recoverable oil estimate was accounted for 33.25 MMSTB for 95 MMSTB (low), 55.1 MMSTB for 145 MMSTB (mid) and 135 MMSTB for 300 MMSTB (high) at 35%, 38% and 45% recovery factor. Based on the proposed development plan, the base model is recommended for further implementation as the recovery factor is 38% with an estimate of 55.1 MMSTB. The platform will have 6 producers and 2 injectors. The quantity of oil produced is estimated at 15000 stbo/day which will require a separator that has the capacity of hold a liquid rate of about 20000 stb/day. The developmental wells are subsequently increased to achieve a water cut of 90-95% with more recoverable oil within the 15-year field life. This developmental plan is also cost effective as drilling more wells means more capital expenditure.

Improvement of Drilling Technology for the Yarega Heavy Oil Field Development by SAGD Method With Counter Producing and Injecting Wells (Russian)

2014 ◽  
Author(s):  
Denis S. Loparev ◽  
Mikhail V. Chertenkov ◽  
George V. Buslaev ◽  
Asif A. Yusifov ◽  
Aleksey V. Klyavlin
Keyword(s):  
Heavy Oil ◽  
Oil Field ◽  
Field Development ◽  
Oil Field Development ◽  
Drilling Technology
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