Steam anti-coning/cresting technology ( SACT) remediation process
A cyclic remediation process to restore oil recovery from a primary oil production well that has watered off from bottom water encroachment (cone or crest) whereby: (a) the primary oil production well has a produced water cut in excess of 95% (v/v); (b) the oil is heavy oil, with in-situ viscosity >1000 cp; wherein the process includes: (c) injecting a steam slug with a volume of 0.5 to 5.0 times the cumulative primary oil production, with steam volumes measured as water volumes; (d) shutting in the well for a soak period, after the steam injection is complete; and (e) producing the well until the water cut exceeds 95%.
1. A cyclic remediation process to restore oil recovery from a primary oil production well that has watered off from bottom water encroachment whereby:
(a) the primary oil production well has a produced water cut in excess of 95% (v/v);
(b) the oil is heavy oil, with in-situ viscosity >1000 cp; wherein said process comprises:
(c) injecting a steam slug with a volume of 0.5 to 5.0 times the cumulative primary oil production, with steam volumes measured as water volumes;
(d) shutting in the well for a soak period after the steam injection is complete; and
(e) producing the well until the water cut exceeds 95%.
2. The process according to claim 1 , where the primary oil production well has been previously steamed.
3. The process according to claim 1 , where the steam is injected using the existing primary oil production well.
4. The process according to claim 1 , where the steam is added using a separate well.
5. The process according to claim 1 , where the primary oil production well is a horizontal well and bottom water encroachment forms a water crest zone beneath the primary oil production well.
6. The process according to claim 5 , where the primary oil production well is not suitable for steam injection and several substantially parallel horizontal wells are linked with a separate substantially perpendicular horizontal well completed in the steam crest zone of each of the substantially parallel horizontal wells.
7. The process according to claim 6 , where the separate substantially perpendicular horizontal well is linked at or near the midpoint of the horizontal well lengths, in the crest zone.
8. The process according to claim 1 , where the heavy oil is bitumen.
9. The process according to claim 8 , wherein the bitumen has API<10 and μ>100,000 cp.
10. A cyclic remediation process to restore bitumen recovery from a bitumen production well that has watered off from bottom water encroachment whereby:
(a) the bitumen production well has a produced water cut in excess of 70% (v/v);
(b) injecting a steam slug with a volume of 0.5 to 5.0 times the cumulative bitumen, with steam volumes measured as water volumes;
(c) shutting in the well for a soak period after the steam injection is complete; and
(d) producing the well until the water cut exceeds 70%, wherein bitumen is an in-situ hydrocarbon with <10 API gravity and >100,000 cp. in-situ viscosity.
11. The process according to claim 10 , where the bitumen production well is used for steam remediation injection.
12. The process according to claim 10 where steam injection rates are 0.5 to 5.0 times fluid production rates when the primary well had watered off.
13. The process according to claim 10 where steam quality at the steam injector well head is controlled between 50 and 100%.
14. The process according to claim 10 where the well is shut in for a soak period of 1 to 10 weeks.