Well tubing/casing corrosion deposits descaling model

1. A method for performing a maintenance operation of a well in an oil/gas field, the method comprising:

identifying, based on a measured sequence of internal diameters of a tubular in the well with respect to longitudinal distances along the well, an extent of corrosion deposit in the tubular;

predicting, using a descaling model of the oil/gas field and based on the extent of corrosion deposit, expected descaling metal loss in the tubular of the well, wherein the descaling model correlates measured descaling metal loss in a reference tubular in a reference well with respect to a difference between a measured sequence of internal diameters of the reference tubular and an original internal diameter of the reference tubular, wherein the reference well is separate from the well;

calculating, based on the expected descaling metal loss, a tubular burst/collapse pressure for a predicted thickness of the tubular;

comparing the tubular burst/collapse pressure against a well operating pressure to generate a comparison result; and

performing the maintenance operation of the well based on the comparison result.

2. The method of claim 1 , further comprising:

performing a de-scaling treatment in the reference well, wherein the measured sequence of internal diameters of the reference tubular is generated prior to the de-scaling treatment;

measuring, subsequent to the de-scaling treatment in the reference well, a sequence of post-treatment internal diameters of the reference tubular with respect to the longitudinal distances along the reference well; and

generating the descaling model based on the measured sequence of internal diameters of the reference tubular and the measured sequence of post-treatment internal diameters of the reference tubular.

3. The method of claim 2 , said generating the descaling model comprises:

correlating a post-treatment tubular profile of the reference well with a pre-treatment tubular profile of the reference well,

wherein the pre-treatment tubular profile comprises the difference between the measured sequence of internal diameters of the reference tubular and the original internal diameter of the reference tubular, and

wherein the post-treatment tubular profile comprises a difference between the measured sequence of post-treatment internal diameters of the reference tubular and the original internal diameter of the reference tubular.

4. The method of claim 3 , said generating the descaling model further comprises:

generating a trend between corrosion deposit build up and the measured descaling metal loss,

wherein the corrosion deposit build up corresponds to the pre-treatment tubular profile, and

wherein the measured descaling metal loss corresponds to the post-treatment tubular profile.

5. The method of claim 1 ,

wherein the extent of corrosion deposit of the well corresponds to a difference between the measured sequence of internal diameters of the tubular and an original internal diameter of the tubular.

6. The method of claim 1 ,

wherein the predicted thickness of the tubular is calculated by subtracting the expected descaling metal loss from an original tubular thickness.

7. The method of claim 1 , said performing the maintenance operation comprises:

performing, based on the comparison result, a chemical descaling operation of the tubular.

8. The method of claim 7 ,

wherein the comparison result indicates that the tubular burst/collapse pressure exceeds a maximum well operating pressure of the well.

9. The method of claim 1 , said performing the maintenance operation comprises:

performing, based on the comparison result, a mechanical descaling operation of the tubular.

10. The method of claim 9 ,

wherein the comparison result indicates that the tubular burst/collapse pressure exceeds a maximum well operating pressure of the well.

11. The method of claim 1 , said performing the maintenance operation comprises:

performing, based on the comparison result, a replacement operation of the tubular.

12. The method of claim 11 ,

wherein the comparison result indicates that the tubular burst/collapse pressure is less than a maximum well operating pressure of the well.

13. A system for performing a maintenance operation of a well in an oil/gas field, comprising:

a well control system for performing well maintenance operations of the well; and

a well maintenance management system comprising:

a tubular profiling engine configured to identify, based on a measured sequence of internal diameters of a tubular in the well with respect to longitudinal distances along the well, an extent of corrosion deposit in the tubular;

a descaling modeling engine configured to:

generate a descaling model based on a reference well in the oil/gas field wherein the descaling model correlates measured descaling metal loss in a reference tubular in the reference well with respect to a difference between a measured sequence of internal diameters of the reference tubular and an original internal diameter of the reference tubular, wherein the reference well is separate from the well; and

predict, using the descaling model and based on the extent of corrosion deposit, expected descaling metal loss in the tubular of the well; and

a descaling management engine configured to:

calculate, based on the expected descaling metal loss, a tubular burst/collapse pressure for a predicted thickness of the tubular;

compare the tubular burst/collapse pressure against a well operating pressure to generate a comparison result; and

facilitate, based on the comparison result, performing the maintenance operations of the well by the well control system.

14. The system of claim 13 , said generating the descaling model comprises:

performing a de-scaling treatment in the reference well, wherein the measured sequence of internal diameters of the reference tubular is generated prior to the de-scaling treatment;

measuring, subsequent to the de-scaling treatment in the reference well, a sequence of post-treatment internal diameters of the reference tubular with respect to the longitudinal distances along the reference well; and

correlating a post-treatment tubular profile of the reference well with a pre-treatment tubular profile of the reference well,

wherein the pre-treatment tubular profile comprises the difference between the measured sequence of internal diameters of the reference tubular and the original internal diameter of the reference tubular, and

wherein the post-treatment tubular profile comprises a difference between the measured sequence of post-treatment internal diameters of the reference tubular and the original internal diameter of the reference tubular.

15. The system of claim 14 , said generating the descaling model further comprises:

generating a trend between corrosion deposit build up and the measured descaling metal loss,

wherein the corrosion deposit build up corresponds to the pre-treatment tubular profile, and

wherein the measured descaling metal loss corresponds to the post-treatment tubular profile.

16. The system of claim 13 ,

wherein the extent of corrosion deposit of the well corresponds to a difference between the measured sequence of internal diameters of the tubular and an original internal diameter of the tubular.

17. The system of claim 13 ,

wherein the predicted thickness of the tubular is calculated by subtracting the expected descaling metal loss from an original tubular thickness.

18. The system of claim 13 , said performing the maintenance operation comprises:

performing, based on the comparison result, a chemical descaling operation of the tubular.

19. The system of claim 13 , said performing the maintenance operation comprises:

performing, based on the comparison result, a mechanical descaling operation of the tubular.

20. The system of claim 13 , said performing the maintenance operation comprises:

performing, based on the comparison result, a replacement operation of the tubular.