ASP Flooding

Taber South Mannville B Pool

Presented by: Behzad Hosseinzadeh

Number of slides:16 Fall: 2013

EOR course presentation

AlkAline-SurfActAnt-Polymer (ASP) flooding

Chemical Injection in EOR Chemical Injection

in EOR Methods

-Surfactant Method -Alkaline Method -Polymer Method

What is ASP? Reservoir Location Rock and reservoir

properties Injection sequence Operations Challenges Solutions Results

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Surfactant MethodIn a system with water and oil, a surfactant will reduce the interfacial tension between the two liquid phases, which “liberates” residual oil held by capillary forces, i. e. a reduction of capillary pressure in the reservoir, leaving it water-wet. This “liberated” oil can now be more easily mobilized and produced(3).

Chemical Injection in EOR

Methods -Surfactant Method -Alkaline Method -Polymer Method



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The use of alkali in a chemical flood is beneficial in many ways:1. reduces the absorption of the surfactant on the reservoir

rock.2. alkali makes the reservoir rock more water-wet.3. alkali is relatively inexpensive.-Softened injection water is required in ASP i.e. very low concentrations of divalent cations (hardness) such as Ca +2 and Mg +2 . Otherwise, these cations react with the alkali agent and form a precipitate (e.g. hydroxides), which could plug the pores of most reservoirs.-Higher salinity of the water phase can also be undesirable; it can decrease the solubility of surfactant molecules in the water. In essence, the alkali, usually caustic soda, reacts with components present in some oil to form soap.

Alkaline Method Chemical Injection

in EOR Methods




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Polymer Method Chemical Injection

in EOR Methods




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What is ASP? Chemical Injection

in EOR Methods




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Reservoir Location Chemical Injection

in EOR Methods




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Rock and Fluid Properties Chemical Injection

in EOR Methods




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Injection Sequence

From Husky oil, IETP Annual Report 2010

Phase 1





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Alkali: 0.75 weight % sodium hydroxide (NaOH), Surfactant: 0.15 weight % ORS-97HF polyacrylamide Polymer: 1,200 ppm Flopaam 3630 34% Pore Volume of ASP Injectionthe 45 wells, which are producing

and 18 injector wells (all vertical or directional completions)

Viscosity ranged between 20-26 cp during the ASP portion of injection and ranges between 28-35 cp with polymer only injection.

Operation Chemical Injection

in EOR Methods




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2 producers and 3 injectors were drilled (infill) during the first half of 2008.Baker Chemicals was able to supply a scale inhibitor that helped control the scale

being produced at this time. Installation of chemical pumps on producing ASP wells to continuously inject scale inhibitor on problem wells.

Silicate scale and reduced injectivity have been the biggest factors contributing to the lower production.

“silicate” (silica) scale has plagued the project, with “very frequent” well servicing required and chemical companies working toward a solution to this problem

As a result, the productionforecast and reserves estimates have be reduced.

The decision has also been made to increase the polymer injection to 40% pore volume (from 30%).

Redrilling wells that had plugged off with scale.

Challenge Chemical Injection

in EOR Methods




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Scale issues continue to be a problem in 2010, but after that advances in the scale inhibitors used have allowed for increased runtime.

Scale issues continue to be a problem in 2010, however recent advances in the scale inhibitors used have allowed for increased runtime.

Pipelines are pigged frequently and there is always lots of scale returns.

Solution Chemical Injection

in EOR Methods




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Result

ASP injection Polymer injection





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ResultIncremental reserves decreased from 14.1% to 12.7% OOIP

for the unrisked production, and a drop from 11.4% to 11.3% for the risked production.





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References1. Marc Charest, M.Sc., P.Geol., Senior Exploration Analyst, “Marc Charest,

M.Sc., P.Geol., Senior Exploration Analyst”, Canadian Discovery, 20132. Lee McInnis, “Innovative Energy Technologies Program Application 01-

023Taber S Mannville B Alkaline-Surfactant-Polymer Flood Warner ASP Flood”, Annual Report June 25, 2010

3. Lee McInnis, “Innovative Energy Technologies Program Application 01-023Taber S Mannville B Alkaline-Surfactant-Polymer Flood Warner ASP Flood”, Annual Report June 25, 2008

4. R. A. Shaw" and D. H. Stright, Jr, “Performance of the Taber South Polymer Flood”, Ashland Oil Canada Limited,1977

5. http://www.rigzone.com6. http://www.canadiandiscovery.com/7. http://www.chemistry.co.nz/surfactants.htm8. http://www.aer.ca/

http://www.rigzone.com/

http://www.canadiandiscovery.com/



http://www.chemistry.co.nz/surfactants.htm

http://www.chemistry.co.nz/surfactants.htm

http://www.aer.ca/

http://www.aer.ca/

http://www.aer.ca/

ASP Flooding

Engineering

Transcript of ASP Flooding