Africa (Sub-Sahara) An 816-mile 2D seismic acquisition program was completed on the Ampasindava block, located in the Majunga deepwater basin offshore northwest Madagascar. The data will provide improved subsurface imaging of the large Sifaka prospect and will potentially mature additional prospects in the Ampasindava block to drill-ready status. Sterling Energy (UK) holds a 30% interest in the Ampasindava production sharing contract, which is operated by ExxonMobil Exploration and Production (Northern Madagascar) (70%). Asia Pacific Production began on the Liuhua 19-5 gas field in the Pearl River Mouth basin in the South China Sea. The field is expected to hit peak production of 29 MMcf/D this year. China National Offshore Oil Corporation (100%) is the operator. Drilling began on the YNG 3264 and the CHK 1177 development wells onshore in Myanmar.
Africa (Sub-Sahara) Bowleven began drilling operations at its Zingana exploration well on the Bomono permit in Cameroon. Located 20 km northwest of Douala, Cameroon's largest city, the well will target a Paleocene (Tertiary) aged, three-way dip closed fault block. The company plans to drill the well to a depth of 2000 m and will then spud a second well in Moambe, 2 km east of Zingana. Bowleven is the operator and holds 100% interest in the license. Asia Pacific China National Offshore Oil Company (CNOOC) has brought its Dongfang 1-1 gas field Phase I adjustment project on line ahead of schedule. The field is located in the Yinggehai basin of the Beibu Gulf in the South China Sea and has an average water depth of 70 m. The field is currently producing 53 MMcf/D of gas and is expected to reach its peak production of 54 MMcf/D before the end of the year.
Badra oilfield started production in 2014.
After some time from the beginning of the field operation, several troubles manifested itself.
Analysis of tubing performance detected clear indication of gas slippage effect on low rate wells and tubing choking effect on high rate wells. Several issues with well integrity also lead to re-assessment of completion design.
During selection of new tubing size and completion equipment, factors like production rate, reservoir depletion, GOR, Flowing buttonhole pressure, wellhead pressure and temperature were taken into account.
In addition to that, possible well interventions and expected tubing loads were considered.
As a result three groups of wells have been identified - low, high and medium production rates in terms of Badra field with new completion concept for each group.
New completion design was selected and implemented on several wells and showed its better performance for new production conditions.
Moreover, selected production tubing diameter and completion components has lower cost and allows any well interventions that might be planned on the field. In addition to that, new completion string can last longer due to its higher corrosion allowance.
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