Method for controlling rock dissolution and pipe corrosion during oil well steam injection

Claim 2

In a process for the recovery of hydrocarbons from a silicate or carbonate containing hydrocarbon-bearing formation penetrated by at least one steam injection well and at least one production well spaced therefrom, the process which inhibits formation dissolution while preventing pipe corrosion which comprises: (a) injecting steam into said steam injection well to displace hydrocarbons toward said production well, said steam produced from a water having added thereto a sufficient amount of a salt to reduce the pH of the residual liquid phase of said steam to within the range of from 8.0 to 10.0, said salt comprises a volatile cationic component and a nonvolatile anionic component; (b) monitoring the pH of said residual liquid phase and continually adjusting the addition of said salt to maintain the pH within the range of from 8.0 to 10.0; and (c) producing said hydrocarbons from said production well.

Claim 3

The process according to claim 1 wherein said salt is an ammonium salt.

Claim 4

The process according to claim 2, wherein said ammonium salt is selected from the group consisting of ammonium sulfate, ammonium chloride, ammonium hydroxide, ammonium acetate, ammonium nitrate, and mixtures thereof.

Claim 5

The process according to claim 3 wherein the ammonium salt is ammonium sulfate.

Claim 6

The process according to claim 3 wherein the ammonium salt is ammonium chloride.

Claim 7

The process according to claim 3 wherein the pH ranges in steps (a) and (b) of claim 1 are both from 8.5 to 9.5.

Claim 8

The process according to claim 6 wherein said steam injection well contains a gravel pack.

Claim 9

The process according to claim 7 which further comprises adding a surfactant selected from the group consisting of anionic, cationic and nonionic surfactants to the injected steam.

Claim 10

The process according to claim 8 wherein said steam has a temperature of at least about 150° C.

Claim 11

In a process for the recovery of hydrocarbons from a silicate or carbonate containing hydrocarbon-bearing formation penetrated by at least one production well spaced therefrom, the process which inhibits formation dissolution while preventing pipe corrosion which comprises: (a) injecting steam into said production well, said steam produced from a water having added thereto a sufficient amount of a salt to reduce the pH of the residual liquid phase of said steam to within the range of from 8.0 to 10.0, said salt comprises a volatile cationic component and a nonvolatile anionic component; (b) monitoring the pH of said residual liquid phase and continually adjusting the addition of said salt to maintain the pH within the range of from 8.0 to 10.0; and then (c) producing said hydrocarbons from said production well.

Claim 12

In a process for the recovery of hydrocarbons from a silicate or carbonate containing hydrocarbon-bearing formation penetrated by at least one production well spaced therefrom, the process which inhibits formation dissolution while preventing pipe corrosion which comprises: (a) injecting steam into said production well, said steam produced from a water having added thereto a sufficient amount of a salt to reduce the pH of the residual liquid phase of said steam to within the range of from 8.0 to 10.0, said salt comprises a volatile cationic component and a nonvolatile anionic component; (b) monitoring the pH of said residual liquid phase and continually adjusting the addition of said salt to maintain the pH within the range of from 8.0 to 10.0; and then (c) producing said hydrocarbons from said production well.

Claim 13

The process according to claim 10 wherein said salt is an ammonium salt.

Claim 14

The process according to claim 11 wherein said ammonium salt is selected from the group consisting of ammonium sulfate, ammonium chloride, ammonium hydroxide, ammonium acetate, ammonium nitrate, and mixtures thereof.

Claim 15

The process according to claim 12 wherein the ammonium salt is ammonium sulfate.

Claim 16

The process according to claim 12 wherein the ammonium salt is ammonium chloride.

Claim 17

The process according to claim 12 wherein the pH ranges in steps (a) and (b) of claim 10 are both from 8.5 to 9.5.

Claim 18

The process according to claim 15 which further comprises adding a surfactant selected from the group consisting of anionic, cationic and nonionic surfactants to the injected steam.

Claim 19

In a process for the recovery of hydrocarbons from a silicate or carbonate containing hydrocarbon-bearing formation penetrated by at least one steam injection well and at least one production well spaced therefrom, the process which inhibits formation dissolution while preventing pipe corrosion which comprises: (a) injecting steam into said steam injection well to displace hydrocarbons toward said production well, said steam produced from a water having added thereto a sufficient amount of an ammonium salt selected from the group consisting of ammonium sulfate and ammonium chloride to reduce the pH of the residual liquid phase of said steam to within the range of from 8.5 to 9.5; (b) monitoring the pH of said residual liquid phase and the temperature of the steam as it is injected in the steam injection well; (c) continually calculating the effective pH of said injected steam; (d) continually adjusting the addition of said ammonium salt to maintain the effective pH of said injected steam within the range of from 8.5 to 9.5; and (e) producing said hydrocarbons from said production well.

Claim 20

In a process for the recovery of hydrocarbons from a silicate or carbonate containing hydrocarbon-bearing formation penetrated by at least one steam injection well and at least one production well spaced therefrom, the process which inhibits formation dissolution while preventing pipe corrosion which comprises: (a) injecting steam into said steam injection well to displace hydrocarbons toward said production well, said steam produced from a water having added thereto a sufficient amount of an ammonium salt selected from the group consisting of ammonium sulfate and ammonium chloride to reduce the pH of the residual liquid phase of said steam to within the range of from 8.5 to 9.5; (b) monitoring the pH of said residual liquid phase and the temperature of the steam as it is injected in the steam injection well; (c) continually calculating the effective pH of said injected steam; (d) continually adjusting the addition of said ammonium salt to maintain the effective pH of said injected steam within the range of from 8.5 to 9.5; and (e) producing said hydrocarbons from said production well.

Claim 23

A method, according to claim 18, wherein said salt comprises an ammonium salt.

Claim 24

A method, according to claim 19, wherein said ammonium salt is selected from the group consisting of ammonium sulfate, ammonium chloride, ammonium hydroxide, ammonium acetate, ammonium nitrate, and mixtures thereof.

Claim 25

A method, according to claim 20, wherein the ammonium salt is ammonium sulfate.

Claim 26

A method, according to claim 20, wherein the ammonium salt is ammonium chloride.

Claim 27

A method, according to claim 18, wherein the pH ranges in steps (a) and (b) of claim 18 are both from 8.5 to 9.5.

Claim 28

A method, according to claim 23, wherein said well contains a gravel pack.

Claim 29

A method, according to claim 24, which further comprises adding a surfactant selected from the group consisting of anionic, cationic, and nonionic surfactants to said steam.

Claim 30

A method, according to claim 25, wherein said steam has a temperature of at least about 150° C.

Claim 31

A method of claim 18 wherein said well is converted to a production well and hydrocarbons are produced therefrom.

Claim 32

The method of claim 18 where a spaced apart production well is used to recover hydrocarbons from said formation.

Claim 35

A method, according to claim 29, wherein said salt is an ammonium salt.

Claim 36

A method, according to claim 30, wherein said ammonium salt is selected from the group consisting of ammonium sulfate, ammonium chloride, ammonium hydroxide, ammonium acetate, ammonium nitrate, and mixtures thereof.

Claim 37

A method, according to claim 31, wherein the ammonium salt is ammonium sulfate.

Claim 38

A method, according to claim 31, wherein the ammonium salt is ammonium chloride.

Claim 39

A method, according to claim 31, wherein the pH ranges in steps (a) and (b) of claim 29 are both from 8.5 to 9.5.

Claim 40

A method, according to claim 34, which further comprises adding a surfactant selected from the group consisting of anionic, cationic and nonionic surfactants to said steam.

Claim 41

The method of claim 29 where said at least one well is converted to a production well and hydrocarbons are recovered therefrom.

Claim 42

The method of claim 29 where said at least one well is an in injection well and hydrocarbons are recovered from a spaced apart production well penetrating said formation.

Claim 43

The method of claim 29 where said salt is selected from the group consisting of ammonium sulfate and ammonium chloride to reduce the pH of said liquid phase to within the range of from about 8.5 to about 9.5; monitoring the pH of said residual liquid phase and the temperature of steam as it is injected into said well; continually calculating the effective pH of said injected steam; and continually adjusting the addition of said ammonium salt to maintain the effective pH of said injected steam within the range of from about 8.5 to about 9.5.