@inproceedings{scholars10697,
            note = {cited By 2; Conference of SPE Asia Pacific Oil and Gas Conference and Exhibition 2018, APOGCE 2018 ; Conference Date: 23 October 2018 Through 25 October 2018; Conference Code:143432},
            year = {2018},
           title = {Sand prediction for a cost-effective marginal green field development},
       publisher = {Society of Petroleum Engineers},
         journal = {Society of Petroleum Engineers - SPE Asia Pacific Oil and Gas Conference and Exhibition 2018, APOGCE 2018},
          author = {Hatta, S. A. M. and Zawawi, I. and Gupta, A. and Safwan Ahmad Nadzri, M. and Salleh, N. I. and Jeffry, S. J. M. and Md Sharif, N. and Ishak, I. H. and Azuwan Maoinser, M.},
            isbn = {9781613995952},
        keywords = {Control equipment; Cost effectiveness; Forecasting; Gasoline; Offshore oil well production; Offshore oil wells; Petroleum geology; Petroleum reservoir evaluation; Sand; Sand consolidation; Well equipment; Well logging; Well stimulation, Development stages; Field development; Integrity assurance; Laboratory measurements; Oriented perforation; Pressure depletion; Reservoir pressures; Strength characterization, Well perforation},
             url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85059947399&partnerID=40&md5=9c14c317ca26eef9cb04fd8e3e0ad30a},
        abstract = {Field B is a marginal green field located offshore Sarawak, Malaysia with formation depth of less than 1000 meters. The compressional sonic transit time range is from 100 {\^a}?? 115 {\^I}1/4s/ft, which immediately triggered the possibility of using active downhole sand control as this range is assumed to be unconsolidated. However, the rock mechanical strength characterization tests from sidewall core indicated contradictory result of a consolidated formation. Since the field is considered as a small field, the cost of the well especially on downhole sand control device need to be extensively optimized. Hence, sand prediction study for a small green field development using field and laboratory measurements was performed. Several methodologies of sand prediction were utilized to evaluate the optimum sandface completion and sand control management for the field. Empirical and analytical sand prediction based on the well logs, sidewall cores analysis, and sand prediction software are employed to evaluate the likelihood of sand production and the optimum well completion design for the field development. The available data from appraisal wells of Field B is also calibrated to the nearby brown field, Field A that has been producing for more than 30 years. This paper will discuss on the sand onset prediction results between full perforation versus oriented perforation, and pressure depletion impact on the sand production. The study shows that the formation is not prone to sand production especially in the early part of the production life with high reservoir pressure and low watercut. The expected Critical Drawdown Pressure (CDP) generated from different methods show large variation of sand onset pressure if the sandface is completed using full perforation. Oriented perforation tremendously expands the sand free drawdown limit. Based on the results of the study, expected reservoir pressure depletion and watercut, the completion of the wells adopted Oriented Perforation with no other downhole sand control equipment. This paper is beneficial for petroleum and well completion engineers especially on sand prediction part of well completion design in development stage. This will assist in ensuring the field meets the EUR and bring forward economic value as well as well integrity assurance. Copyright 2018, Society of Petroleum Engineers}
}