Chemical Water Shutoff Pilot in a Mature Offshore Carbonate field
- Christophe Cottin (TOTAL ABK;) | Omar Al-Amrie (TOTAL ABK;) | Emmanuel Barrois (TOTAL ABK;) | Arnaud Templier (POWELTEC) | Nazanine Salehi (POWELTEC) | Alain Zaitoun (POWELTEC)
- Document ID
- Society of Petroleum Engineers
- Abu Dhabi International Petroleum Exhibition & Conference, 13-16 November , Abu Dhabi, UAE
- Publication Date
- Document Type
- Conference Paper
- 2017. Society of Petroleum Engineers
- 2.4 Hydraulic Fracturing, 5.5 Reservoir Simulation, 5.3.2 Multiphase Flow, 2.1.3 Completion Equipment, 4.1 Processing Systems and Design, 5.4.2 Gas Injection Methods, 5.8.7 Carbonate Reservoir, 5 Reservoir Desciption & Dynamics, 5.4 Improved and Enhanced Recovery, 3.5.5 Water Shut-off, 4.1.2 Separation and Treating, 3 Production and Well Operations, 3.5 Well Intervention, 5.4 Improved and Enhanced Recovery, 2 Well completion, 4 Facilities Design, Construction and Operation, 5.8 Unconventional and Complex Reservoirs, 2.5.2 Fracturing Materials (Fluids, Proppant), 2.2 Installation and Completion Operations, 5.4.1 Waterflooding, 3 Production and Well Operations, 3 Production and Well Operations
- Chemical Water Shut Off, Mature field, Offshore field, Carbonate field
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Total has been operating oil and gas production from a series of heterogeneous carbonate reservoirs offshore Abu Dhabi since 1974. New technologies to increase oil recovery have been always tested and deployed on this field as tertiary gas injection since the 1990's or chemical EOR with a surfactant polymer pilot recently. On the same dynamic, we tested chemical water shut off treatment on two highly waterflooded wells with the injection of relative permeability modifiers (microgels).
This paper describes the full workflow followed for the pilot implementation and lessons learnt.
A particularity of this field is to produce in commingle oil from different thin reservoirs, with permeabilities ranging from to 0.5 to 50mD. Well production is combined through a single sliding sleeve, thus any mechanical shut off is impossible to block the water coming from the high permeability zones that is why the injection of RPM was considered.
Microgels were preferred over conventional polymers gels due to their higher resistance to salinity, shear, and H2S.
Laboratory studies were conducted to select the best microgel size and to obtain inputs for near well-bore model simulation (microgel adsorption, permeability reduction, injectivity). Numerical simulations were performed to predict the well responses and to define the optimal slug injection.
For this first pilot using microgels in high salinity environment, two vertical wells producing from two different reservoirs were tested, with watercut of 92 and 97%.
The microgel fluids were bullheaded into the whole perforated interval, the fluids were prepared on a nearby marine vessel; the operational challenges faced are detailed.
Preliminary results and way forward are described. The application of this microgel technology to high salinity and moderate temperature carbonate fields has a great potential to improve recovery in very mature fields at low cost.
|File Size||2 MB||Number of Pages||13|