Tunu: From Lab to Field Application with a New Hybrid Inorganic-Organic Sand Consolidation Fluid as Primary Treatment on Shallow Reservoirs
- J. Andrieu (Engineered nanoProducts Germany AG) | B. Kutzky (Engineered nanoProducts Germany AG) | B. T. Schackmann (Engineered nanoProducts Germany AG) | A. Mahardhini (Total) | I. Abidiy (Total) | H. M. Poitrenaud (Total)
- Document ID
- Society of Petroleum Engineers
- SPE International Conference and Exhibition on Formation Damage Control, 7-9 February, Lafayette, Louisiana, USA
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 1.6 Drilling Operations, 4.1.2 Separation and Treating, 4 Facilities Design, Construction and Operation, 2.4 Sand Control, 3.2 Well Operations and Optimization, 3 Production and Well Operations, 4.1 Processing Systems and Design, 3.2.3 Produced Sand / Solids Management and Control, 1.6.9 Coring, Fishing, 2.4 Sand Control
- sand consolidation, inoganic-organic hybrid material, nano-composite material
- 1 in the last 30 days
- 105 since 2007
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Tunu field, which is located in Mahakam area, consists of sandstone reservoir. Due to the maturity of the field, producing layer has moved from the deep zone, which has consolidated sand, into shallow zone, which has unconsolidated sand. Hydrocarbon production from shallow zone is unmanageable without having primary sand control downhole.
Here, we present a new type of sand consolidation composite (or hybrid) low-viscous binding material, based on combination of both inorganic and organic components. After describing the properties of this material, like low viscosity and strong adhesion to sand surface, we introduce the models used in the laboratory to stay as close as possible to the injection parameters on the field. We present the results of consolidation and regained permeabilities obtained in the laboratory with this binder on several substrates (loose sand and sand stone cores) with various porosities. The formulation was tested with success on samples ranging from several darcys down to 80 millidarcys. It is also noteworthy that samples display strong consolidation after extensive brine-based overflush.
Then, this paper discusses the results obtained during eight field trials divided into three successive campaigns. The volume of water-based overflush was identified as the main parameter to find the right balance between consolidation strength without sand production and expected productivity. We achieved improvement of the formulation as well as learning curve from each campaign. After first campaign with 6 pore volumes overflush, three wells out of five produced sand free. During second campaign (1.5 pore volume overflush), two wells were treated and able to produce sand free with average gas rate 1 MMscfd (million standard cubic feet per day), after productivity impairment was solved. The trial on one well in a third campaign with 3 pore volumes overflush was successful, with the well producing sand free with average gas rate 0.8 MMscfd.
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