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1. WO2015017220 - SYSTÈMES ET PROCÉDÉS PERMETTANT DE PRODUIRE DES PUITS DE GAZ AVEC DE MULTIPLES COLONNES DE PRODUCTION

Note: Texte fondé sur des processus automatiques de reconnaissance optique de caractères. Seule la version PDF a une valeur juridique

[ EN ]

CLAIMS

What is claimed is:

1. A method for producing gas from a well including a wellbore extending from a surface into a subterranean formation, the method comprising:

(a) installing a first production tubing string within the wellbore;

(b) installing a second production tubing string within the wellbore;

(c) producing gas from a first production zone in the subterranean formation through the first production tubing string at a first velocity that is greater than a critical velocity after both (a) and (b);

(d) shutting in the first production tubing string and opening the second production tubing string after (c) after the first velocity decreases below the critical velocity to transition the production of gas from the first production zone from the first production tubing string to the second production tubing string, wherein the first production tubing string has a first inner diameter and the second production string has a second inner diameter that is less than the first inner diameter; and

(e) producing gas from the first production zone through the second production tubing string after (d) at a second velocity that is greater than the critical velocity.

2. The method of claim 1, further comprising:

(f) producing gas from the first production zone through both the first production tubing string and the second production tubing string simultaneously before (c) and after both (a) and (b) at a third velocity that is greater than the critical velocity; and

(g) shutting in the second production tubing string after (f) and before (c) when the third velocity decreases below the critical velocity to transition the production of gas from the first production zone from both the first production tubing string and the second production string to the first production tubing string.

3. The method of claim 2, further comprising:

(h) producing gas from the first production zone through an annulus disposed about the first production string and the second production string before (f) and after both (a) and (b) at a fourth velocity that is greater than the critical velocity; and

(i) shutting in the annulus and opening the first production tubing string and the second production tubing string after (h) and before (f) when the fourth velocity decreases below the critical velocity to transition the production of gas from the first production zone from the annulus to both the first production tubing string and the second production string.

4. The method of claim 1, wherein the second velocity is greater than the first velocity when the production of gas from the first production zone is transitioned from the first production tubing string to the second production tubing string in (d).

5. The method of claim 1 , further comprising:

(f) installing a third production tubing string within the wellbore;

(g) installing a fourth production tubing string within the wellbore;

(h) producing gas from a second production zone in the subterranean formation through the third production tubing string at a fifth velocity that is greater than the critical velocity after both (f) and (g), wherein the second production zone is below the first production zone;

(i) shutting in the third production tubing string and opening a fourth production tubing string after (h) after the fifth velocity decreases below the critical velocity to transition the production of gas from the second production zone from the third production tubing string to the fourth production tubing string, wherein the third production tubing string has a third inner diameter and the further production string has a fourth inner diameter that is less than the third inner diameter; and

(j) producing gas from the second production zone through the second production tubing string after (i) at a sixth velocity that is greater than the critical velocity.

6. The method of claim 5, further comprising:

(k) producing gas from the second production zone through both the third production tubing string and the second production tubing string simultaneously before (h) and after both (f) and (g) at a seventh velocity that is greater than the critical velocity; and

(1) shutting in the fourth production tubing string after (k) and before (h) when the seventh velocity decreases below the critical velocity to transition the production of gas from the second production zone from both the first production tubing string and the second production tubing string to the first production tubing string.

7. The method of claim 5, wherein sixth velocity is greater than the fifth velocity when the production of gas from the second production zone is transitioned from the third production tubing string to the fourth production tubing string in (i).

8. A system for producing hydrocarbons from a subterranean well including a wellbore extending from a surface into a subterranean formation, the system comprising:

a wellhead disposed at the surface;

a production tree coupled to the wellhead;

a casing coupled to the wellhead and extending into the wellbore; and

a first plurality of production tubing strings extending into the casing from the wellhead to a first production zone, wherein each of the first plurality of production tubing strings is configured to provide a fluid flow path for gases from the first production zone;

wherein the production tree is configured to selectively and independently control fluid flow through each of the first plurality of production tubing strings.

9. The system of claim 8, wherein the first plurality of production tubing strings comprise a first production tubing string and a second production tubing string;

wherein the production tree is configured to selectively allow and restrict fluid flow through the first production tubing string and/or the second production tubing string.

10. The system of claim 9, wherein the first production tubing string has an inner diameter D1, wherein the second production tubing string has an inner diameter D2, and wherein D1 is larger than D2.

11. The system of claim 9, wherein the first production tubing string extends to a first depth; wherein the second production tubing string extends to a second depth; and wherein the first depth and the second depth are substantially the same.

12. The system of claim 1, wherein the production tree includes a plurality of valves and the production tree is configured to selectively and independently control fluid flow through each of the first plurality of production tubing strings when at least some of the plurality of valves are actuated.

13. The system of claim 1, further comprising:

a second plurality of production tubing strings extending within the casing to a second production zone, wherein the second production zone is farther from the surface than the first production zone; and where each of the second plurality of production tubing strings is configured to provide a fluid flow path for gases produced from the second production zone to the surface;

wherein the production tree is configured to selectively allow and restrict fluid flow through each of the second plurality of production tubing strings independently.

14. A method for producing gas from a well including a wellbore extending from a surface into a subterranean formation, the method comprising:

(a) installing a first flow path within the wellbore, wherein the first flow path has a first cross-sectional area;

(b) installing a second flow path within the wellbore, wherein the second flow path has a second cross-sectional area that is smaller than the first cross-sectional area;

(c) flowing gas from a first production zone in the subterranean formation during a first production period through the first flow path after both (a) and (b) until a flow rate from the first production zone reaches a first value;

(d) shutting in the first production flow path;

(e) flowing gas from the first production zone during a second production period through the second flow path after (a), (b), and (d) until the flow rate from the first production zone reaches a second value that is smaller than the first value;

(f) shutting in the second production flow path.

15. The method of claim 14, further comprising:

(g) determining that gas is flowing below a critical velocity through the first flow path during (c) and before (d) and (e).

16. The method of claim 14, wherein (g) comprises determining that a first pressure drop per unit length of the first flow path is increasing during (c) and after both (a) and (b).

17. The method of claim 14, further comprising:

(g) installing a third flow path within the wellbore, wherein the third flow path has a third cross-sectional area;

(h) installing a fourth flow path within the wellbore, wherein the fourth flow path has a fourth cross-sectional area that is smaller that the third cross-sectional area;

(i) flowing gas from a second production zone in the subterranean formation during a third production period through the third flow path after both (g) and (h) until a flow rate from the second production zone reaches a third value, wherein the second production zone is farther from the surface than the first production zone;

(j) shutting in the third production flow path;

(k) flowing gas from the second production zone during a fourth production period through the fourth flow path after (g), (h), and (i) until the flow rate from the second production zone reaches a fourth value that is smaller than the third value;

(l) shutting in the fourth production flow path.

18. The method of claim 17, further comprising:

(m) determining that gas is flowing below a critical velocity through the first flow path during (i) and before (j) and (k).

19. A method for producing gas from a well including a wellbore extending from a surface into a subterranean formation, the method comprising:

(a) installing a first production tubing string within the wellbore;

(b) installing a second production tubing string within the wellbore;

(c) flowing gas from a first production zone in the subterranean formation through the first production tubing string after both (a) and (b);

(d) flowing gas from a first production zone in the subterranean formation through the second production tubing string during (c);

(e) determining a first pressure within the wellbore at an entrance of the first production tubing string;

(f) determining a second pressure of gas within the first production tubing string at the surface; and

(g) regulating a flow of gas through the second production tubing string during (d) to minimize a difference between the first pressure and the second pressure.

20. The method of 19, wherein (c) comprises flowing gas from the first production zone through the first production tubing string at a first velocity, wherein the first velocity is greater than the critical velocity.

21. The method of claim 19, wherein (e) comprises choking the flow through the second production tubing string using a variable choke assembly.

22. The method of claim 19, further comprising:

(h) shutting in an annulus disposed about the first production string and the second production string before (c) and (d); and

wherein (e) comprises:

(e1) measuring a third pressure within the annulus at the surface;

(e2) estimating a fourth pressure exerted by a static column of fluid extending between the surface and the entrance of the first production tubing string; and

(e3) adding the third pressure to the fourth pressure to determine the second pressure.