The Cliff Head Field Development--Flow Assurance and Production Chemistry Challenges in a Marginal Field Context
- Simon B. Daniel (ROC Oil Company Limited) | Jonathan L. Roberts (Advantage Energy Limited)
- Document ID
- Society of Petroleum Engineers
- SPE Projects, Facilities & Construction
- Publication Date
- June 2009
- Document Type
- Journal Paper
- 19 - 26
- 2009. Society of Petroleum Engineers
- 6.5.2 Water use, produced water discharge and disposal, 4.5.3 Floating Production Systems, 2.4.3 Sand/Solids Control, 1.6.9 Coring, Fishing, 1.8 Formation Damage, 5.2 Reservoir Fluid Dynamics, 4.1.2 Separation and Treating, 4.2.3 Materials and Corrosion, 3.1.2 Electric Submersible Pumps, 4.2 Pipelines, Flowlines and Risers, 5.6.4 Drillstem/Well Testing, 4.3.4 Scale, 4.1.5 Processing Equipment, 4.1.9 Tanks and storage systems, 4.3 Flow Assurance, 4.2.5 Offshore Pipelines, 2 Well completion, 4.5 Offshore Facilities and Subsea Systems, 4.5.7 Controls and Umbilicals, 1.6.6 Directional Drilling, 4.3.3 Aspaltenes
- 1 in the last 30 days
- 698 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 10.00|
|SPE Non-Member Price:||USD 30.00|
The Cliff Head Field, offshore Western Australia, faced significant development challenges because of its location and reservoir fluid properties. The influence of these challenges is apparent in the development solution adopted from sandface to market. The modest reserve size required the application of a number of firsts, including coiled tubing (CT), deployed electric submersible pumps (ESPs) combined with intelligent completion technology, a novel water "spike" approach to waxy crude transportation, a distributed chemical injection system, a remote-controlled, normally unmanned production platform, produced water re-injection, and "hydrofrac" water-injection capacity.
This paper describes the flow assurance and production chemistry challenges facing the development, the resulting development solution, and the production history to date.
The Cliff Head field is located in Commonwealth hydrocarbon exploration permit WA-286-P in the offshore Northern Perth Basin, Western Australia. Cliff Head is the first offshore development within the region. The field was discovered in December 2001 when Brent crude prices were at USD $20 per barrel. The field contains 15.7 million barrels of estimated ultimate oil recovery.
|File Size||464 KB||Number of Pages||8|
Cassinat, J.C., Payette, M.C., Taylor, D.B., and Cimolai, M.P. 2002. Optimizing Water Flood Performance byUtilizing Hot Water Injection in a High Paraffin Content Reservoir. PaperSPE 75141 presented at the SPE/DOE Improved Oil Recovery Symposium, Tulsa,13-17 April. doi: 10.2118/75141-MS.
Jamaluddin, A., Nighswander, J., and Joshi, N. 2001. A Systematic Approach in DeepwaterFlow Assurance Fluid Characterization. Paper SPE 71546 presented at the SPEAnnual Technical Conference and Exhibition, New Orleans, 30 September-3October. doi: 10.2118/71546-MS.
Joseph D.D., Bai R., Chen, K.P., and Renardy, Y.Y. 1997. Core-Annular Flows.Annu. Rev. Fluid Mech. 29: 65-90.doi:10.1146/annurev.fluid.29.1.65.
Tang, Y., Shuler, P.J., Cheug, S.K., Goodgame, J.A., Hsu, J.J., and Padilla,A.V. 2003. Improved Transportationof Waxy Crude Oils and Emulsions in Bekasap Area Indonesia. Paper SPE 80243presented at the International Symposium on Oilfield Chemistry, Houston, 5-7February. doi: 10.2118/80243-MS.
Way, C., Daniel, S., Bird, E., Jordan, J., Guatelli, V.J., and Bettridge,J.M. 2007. Cliff Head IntelligentCompletion With Coiled Tubing Deployed ESPs--Increased Production, ReducedLife-Cycle Cost. Paper SPE 108381 presented at the Asia Pacific Oil and GasConference and Exhibition, Jakarta, 30 October-1 November. doi:10.2118/108381-MS.