IOR 2007 - 14th European Symposium on Improved Oil Recovery

A04 Ula WAG – World Class EOR – Breathing the Gas of Life into a Mature Oil Field C. de Jongh* (BP Norway) E. Lund (BP) M. Hole (BP Norway) & J. Duncan (BP Norway) SUMMARY The Ula field is located in the Norwegian sector of the North Sea. The field has a STOOIP of around 1 billion stb and has been on production since 1986; water injection started in 1988. In the mid-nineties the field was on a steep waterflood decline with less than a decade of future. Ula WAG (Water Alternating Gas)was started up in 1998 and targets

A06 IOR Strategies for the Final Stage of the Development of Chutyrsko-Kiengopskoye Oil Field A.A. Mosesyan* (Petroleum Technologies) A.A. Forafonov (Petroleum Technologies) R.A. Rybakov (Petroleum Technologies) A.V. Berlin (Izhevsk Oil Scientific Centre (Udmurtneft)) & A.L. Gavrikov (Izhevsk Oil Scientific Centre (Udmurtneft)) SUMMARY Chutyrsko-Kiengopskoye is the largest carbonate field in Udmurtia Russia with more than 400 million tons (2.2 billion barrels) of oil in place. The field is laterally divided into two areas with four similar productive horizons in each. The field has been in development since 1971 with more than 1300 wells drilled. Viscosity of reservoir fluid ranges from 9

A08 Water & Chemical Flooding in Heavy Oil Field in Southern Oman D. Boersma* (PDO) & S. Sikaiti (PDO) SUMMARY This paper deals with a development strategy to achieve world class recovery factors in a giant oil field in Southern Oman. A comprehensive field development plan urban plan and a risk based decision and assurance frame work has been designed to move from conventional recovery to improved recovery by water flood from water flood to polymer flood and from polymer flood to Alkaline Surfactant Polymer flood. The approach allows for early implementation of the development in a brown field environment

A10 New Microgels for EOR – From Laboratory to Field Applications D. Rousseau* (Institut Français du Pétrole) R. Tabary (Institut Français du Pétrole) A. Zaitoun (Poweltec) T. Pichery (Gaz de France) P. Mallo (SEPPIC) & O. Braun (SEPPIC) SUMMARY New microgels specifically designed for EOR applications were extensively studied at laboratory scale and subjected to a field test. Microgels are micron-scale particles of chemically crosslinked polymers. They are preformed stable fully water soluble non-toxic and both their size and rigidy are controlled during the manufacturing process. Microgels have remarkable mechanical and thermal stability. In porous media they gather important advantages:

A13 Gravity Segregation in Non-Newtonian Foam IOR C. Shen* (The University of Texas at Austin) W.R. Rossen (Delft University of Technology) & Q.P. Nguyen (The University of Texas at Austin) SUMMARY A useful model for gravity override in gas IOR is Stone’s model (SPE 11140; SPE 12632) which describes gravity override during simultaneous water-gas flow into a homogeneous reservoir. Shi and Rossen (SPEREE April 1998) and Cheng et al. (SPE 59287 2000) extended the model to foam processes with Newtonian rheology and Rossen and van Duijn (J. Petr. Sci. Eng. 43 99-111 2004) showed that the model is rigorously correct

A15 Offshore CO2–EOR in the Heidrun Field A.S. Lackner* (Statoil) P.H. Janssen (Statoil) J.A. Stensen (Statoil) & V. Haugse (Statoil) SUMMARY For more than 30 years CO2 has been successfully used for onshore EOR in oil fields worldwide. Today with the focus on CO2 as both an EOR-agent in fields on declining production and for reduction of greenhouse gas emissions the interest for offshore CO2-EOR and storage has increased substantially. A planned gas power plant may supply oil fields in the Halten area with about 2.3 Mton of CO2 per year from 2011 on. The Heidrun field is a candidate

A17 Visualization of the Effects of Pressure and Gas CO2 Content on Asphaltene Precipitation while Displacement of Oil Via Gas S. Nejadi (Arvandan Oil and Gas Production) V.A. Sajjadian* (Arvandan Oil and Gas Production) & M. Jahedi (Arvandan Oil and Gas Production) SUMMARY Asphaltene precipitation is a fact that leads to significant problems due to incompatibility of the fluids while gas injection to an oil reservoir for pressure maintenance or EOR purposes. In the current research nine experiments were carried out to study problems which might encounter while that mentioned phenomena. Sample of a gigantic Iranian gas reservoir combined with

A19 Features Concerning Capillary Pressure and the Effect on Two-phase and Three-phase Flow E.I. Dale* (Centre for Integrated Petroleum Research UiB) & A. Skauge (Centre for Integrated Petroleum Research UiB) SUMMARY The effect of capillary pressure related to immiscible WAG (Water Alternate Gas) is studied by use of a numerical simulator. The capillary pressure is found to have a significant effect on the pressure gradient and the total oil production both in two-phase and three-phase flow situations. When the capillary pressure is included in the simulation the total oil production is considerably lower than when the capillary pressure is neglected.

A21 Gas Flooding a Tight and Heterogeneous Silicilite Reservoir – Quantification of Sweep Efficiency H. Al-Shuraiqi* (Petroleum Development Oman) & V. van Engelen (Petroleum Development Oman) SUMMARY The Al Noor field was discovered in 1989 in the South Oman salt basin. The field is at a depth of 4 km and contains the unique Athel silicilyte. The reservoir has a gross thickness of around 400 m and is fully encased in sealing salt as a result of which the reservoir is geopressured to 80 MPa. The permeability is extremely low (typical 1 – 100 micro-darcy) due to the fact that

A23 The Road to Sour Gas Flooding of a High Pressure Reservoir H. Soek* (PDO) D. Davis (PDO) A. Hadhrami (PDO) & G. Deinum (PDO) SUMMARY A Cluster in South Oman is being developed in a staged manner for a miscible gasflood. The business drive is to deliver projects as fast as possible in a prudent manner. Acceleration needs to be balanced against the risk of a suboptimal development. Parallel working on appraisal and project definition is one answer. This article describes some of the learnings encountered on subsurface-surface interfaces and the advanced technologies utilised to monitor reservoir performance and