Preproduction-Deployed Scale-Inhibition Treatments in Deepwater West Africa
- David Patterson (Chevron) | Wade Williams (Chevron) | Myles Jordan (Nalco Champion) | Raymond Douglas (Nalco Champion)
- Document ID
- Society of Petroleum Engineers
- SPE Production & Operations
- Publication Date
- August 2017
- Document Type
- Journal Paper
- 333 - 342
- 2017.Society of Petroleum Engineers
- solid scale inhibitor, liquid scale inhibitor, Inorganic scale, Frac gel scale inhibitor, pre production
- 1 in the last 30 days
- 202 since 2007
- Show more detail
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The injection of seawater into oil-bearing reservoirs for the purposes of maintaining reservoir pressure and improving secondary recovery is a well-established, mature operation. Moreover, the degree of risk posed by deposition of mineral scales (carbonate/sulfate) to the injection and production wells during such operations has been much studied. The current deepwater subsea developments offshore West Africa and Brazil have brought into sharp focus the need to manage scale in an effective way.
In a deepwater West African field, the relatively small number of high-cost, highly productive wells, coupled with a high barium sulfate scaling tendency upon breakthrough of injection seawater, meant that effective scale management was critical to achieving high hydrocarbon recovery and that even wells at low water cuts have proved to be at sufficient risk to require early squeeze application.
To provide effective scale control in these wells at low water cuts, phosphonate-based inhibitors were applied as part of the acid-perforation wash and overflush stages before frac-packing operations. The deployment of this inhibitor proved effective in controlling barium sulfate scale formation during initial water production, eliminating the need to scale squeeze the wells at low water cuts (<10% basic sediment and water). To increase the volumes of scale inhibitor (SI) being deployed in the preproduction treatments and so extend the treatment lifetimes, SI was also added to the fracturing gel used to carry the fracturing sand.
This paper outlines the selection methods for the inhibitor chemical for application in fracturing fluids in terms of rheology, retention/release, and formation damage, and presents the chemical-return profiles from the five wells treated (some treatments lasting longer than 300 days), along with the monitoring methods used to confirm scale control in the treated wells.
Many similar fields are currently being developed in the Campos Basin, Gulf of Mexico, and West Africa, and this paper is a good example of best-practice sharing from another oil basin.
|File Size||1019 KB||Number of Pages||10|
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