EOR Solutions
Conformance Improvement and Water Shut-off for High-Temperature Applications

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Extremely hot reservoirs - above about 220ºF – have traditionally been difficult to work with because the high temperatures cause premature gel formation, making placement of large gel treatments difficult.

APPLICATION
The gel can be injected into production or injection wells at temperatures from 200° to 300°F. It can solve the following problems:

	Producing Wells: Bottom water coning, early water breakthrough, fracturing out of zone, conduit from injector to producer, natural fractures connected to bottom water drive
	Injection Wells: Conduit from injector to producer, injection out of zone, thief intervals of natural fractures or high permeability streaks

DESCRIPTION
These gels are made up of a polymer, a crosslinker, and a stabilizing agent. The three components are mixed at the surface, then injected down into the formation. The reaction rate is sufficiently delayed at high temperatures to allow placement some distance from the wellbore.

ADVANTAGES
	Robust, versatile gel chemistry that does not require exact chemical concentrations
	Can be used in almost any type of mix water, fresh water is best
	May not require zone isolation in fractured reservoirs
	Zone isolation typically not needed in injection wells
	Can place large volumes to block water flow paths further out from the wellbore than other methods. This reduces new flow paths by passing the gel
	Works up to 300ºF. Can be formulated to work up to 350ºF
	Payout is often within 6 to 9 months

CRITICAL DESIGN FACTORS
	Producers with high fluid levels are excellent candidates
	Perfs must be clean so the gelant can be readily injected
	Minimum efficient injection rate and maximum injection pressure constrain treatment volumes
	Should be able to place over 50% of design gel volume without reaching pressure limit