A Successful Application of Fiber-Optic-Enabled Coiled Tubing With Distributed-Temperature Sensing Along With Pressures To Diagnose Production Decline in an Offshore Oil Well
- P.E. Parta (Schlumberger) | Arthur P. Parapat (Schlumberger) | Rex Burgos (Schlumberger) | Jonathan M. Christian (Schlumberger) | Abul Jamaluddin (Schlumberger) | Graeme Rae (Talisman Malaysia Limited) | Siak K. Foo (Talisman Malaysia Limited) | Juanih Ghani (Talisman Malaysia Limited) | Muzily Musa (Talisman Malaysia Limited)
- Document ID
- Society of Petroleum Engineers
- SPE Production & Operations
- Publication Date
- May 2010
- Document Type
- Journal Paper
- 204 - 210
- 2010. Society of Petroleum Engineers
- 4.3 Flow Assurance, 4.1.2 Separation and Treating, 3 Production and Well Operations, 1.12.5 Real Time Data Transmission, 1.10 Drilling Equipment, 2.7.1 Completion Fluids, 4.3.3 Aspaltenes, 3.2.2 Downhole intervention and remediation (including wireline and coiled tubing), 2.4.3 Sand/Solids Control, 1.8 Formation Damage, 2 Well Completion, 5.6.11 Reservoir monitoring with permanent sensors, 1.6.1 Drilling Operation Management, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 5.4.2 Gas Injection Methods, 5.2 Reservoir Fluid Dynamics, 5.2.1 Phase Behavior and PVT Measurements, 1.6 Drilling Operations
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In this paper, we present a field example where pressure and distributed-temperature measurements enabled understanding of reservoir characteristics and fluid movement causing production hindrance in an offshore horizontal well. The field example has a horizontal well in the South China Sea that was completed as an openhole monobore oil producer using a slotted liner. The well began production with an initial oil rate of 1,800 B/D. Oil production quickly dropped to 1,000 B/D and gradually declined to 200 B/D. During this period, the gas/oil ratio (GOR) steadily increased from 200 scf/bbl to 2,200 scf/bbl. To arrest production decline, a chemical treatment was conducted to remove suspected emulsions and polymers assumed to have been depositedduring drilling. Immediate post-treatment production increased to 3,700 B/D, but dropped dramatically and stabilized at pretreatment rates soon after. Formation of emulsions and asphaltenes were believed to be the cause of the production decline. However, with inadequate information, the diagnosis was inconclusive. Consequently, another chemical treatment was conducted and this time a fiber-optic-enabled coiled-tubing (CT) string along with real-time bottomhole-pressure and temperature gauges were used to acquire distributed temperatures and pressures of the entire horizontal section of the wellbore.
Results of the pressure survey revealed that the well was receiving insufficient pressure support from the water injector, which was causing gas-cap expansion. The distributed-temperature survey indicated excessive gas production from the toe of the horizontal section as a result of this expansion, thus limiting liquid production. The combination of gas rates with oil and water production has also created tight emulsions, further hindering production performance. It was concluded that the high gas production from the toe could not be selectively shutoff or controlled in the horizontal openhole slotted-liner completion to perform an effective stimulation program and treat the tight viscous emulsions.
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