Cationic formation stabilizers compatible with anionic friction reducing polymers

Patent metadata

Field	Value
Publication number	US-11274240-B2
Application number	US-201916507636-A
Country	US
Kind code	B2
Filing date	Jul 10, 2019
Priority date	Jul 10, 2019
Publication date	Mar 15, 2022
Grant date	Mar 15, 2022

Abstract

A wellbore servicing fluid comprising (a) a cationic formation stabilizer having (i) a molecular weight in a range of from equal to or greater than 0.05 to equal to or less than 2.0 kiloDaltons (kDa), or (ii) cationic charge functional groups of greater than 2 to equal to or less than 5 cationic charges per molecule, or (iii) both (i) and (ii), (b) an anionic friction reducer, and (c) an aqueous fluid.

First claim

We claim:

1. A wellbore servicing fluid comprising:
(a) a cationic formation stabilizer having (i) a molecular weight in a range of from equal to or greater than 0.05 to equal to or less than 2.0 kiloDaltons (kDa), or (ii) cationic charge functional groups of greater than 2 to equal to or less than 5 cationic charges per molecule, or (iii) both (i) and (ii) wherein the cationic formation stabilizer comprises a cationic guanidinium-containing compound (GCC) comprising the moiety of Structure IV:

wherein R 1 , R 2 , R 3 , R 4 ,R 5 and R 6 are each independently an organyl group,
(b) an anionic friction reducer wherein the anionic friction reducer has a molecular weight in a range of equal to or greater than 5 MM Da to equal to or less than 25 MM Daltons (Da); and
(c) an aqueous fluid.

2. The wellbore servicing fluid of claim 1 , wherein the cationic formation stabilizer comprises arginine, lysine, polylysine, guanidine, ethoxylated amines, polyoxyalkylene amines, polyoxyethylene amines, polyoxypropylene amines, polyoxyalkylene cocamines, polyoxyethylene cocamines, polyoxypropylene cocamines, polyoxyalkylene tallow amines, polyoxyethylene tallow amines, polyoxypropylene tallow amines, polyoxyalkylene lauryl amines, polyoxyethylene lauryl amines, polyoxypropylene lauryl amines polyoxyalkylene amidoamines, polyoxypropylene amidoamine, polyether amines, polyether diamine, polyamino polyether, or combinations thereof.

3. The wellbore servicing fluid of claim 1 , wherein the cationic formation stabilizer comprises a compound according to Structure I, II, or III:

4. The wellbore servicing fluid of claim 1 , wherein the cationic formation stabilizer comprises a guanidine compound.

5. The wellbore servicing fluid of claim 1 , wherein the cationic formation stabilizer comprises a cationic guanidinium-containing compound (GCC) comprising the moiety of Structure IV:

wherein R 1 , R 2 , R 3 , R 4 , R 5 and R 6 are each independently hydrogen, a halogen or an organyl group.

6. The wellbore servicing fluid of claim 5 , wherein the GCC is an oligomer as represented by the compound of Structure V:

wherein R 1 , R 2 , R 3 , R 4 , and R 5 are each independently hydrogen, a halogen or an organyl group and the GCC has a molecular weight ranging from about 50 Daltons (Da) to about 2000 Daltons (Da).

7. The wellbore servicing fluid of claim 1 , wherein the cationic formation stabilizer is present in an amount in a range of from about 0.001 weight percent to about 3 weight percent based on the total weight of the wellbore servicing fluid.

8. The wellbore servicing fluid of claim 1 , wherein the anionic friction reducer comprises one or more functional groups selected from the group consisting of (a) alkyl-, vinyl-, aryl-, amide; (b) dialkyl-, divinyl-, diaryl-, amide; (c) carboxylic acid; (d) carboxylic acid mono- or multi-valent metal salt; (e) carboxylic acid ammonium salt; (f) carboxylic acid alkyl-, vinyl-, aryl ammonium salt; (g) carboxylic acid oxyethyltrimethylammonium salt; (h) carboxy-1-propanesulfonic acid; (i) carboxy-1-proanesulfonic acid mono- and multivalent salts; (j) Sulfopropyl salt; (k) Amido-2-methylpropane sulfonic acid; (l) Amido-2-methylpropane sulfonic acid mono- or multi-valent metal salt; (m) amidopropyl timethylammonium salt; (n) carboxylic acid methyl(C1)-thru octydecyl(C18) ester; and (o) combinations thereof.

9. The wellbore servicing fluid of claim 1 , wherein the anionic friction reducer is present in an amount in a range of from about 0.001 weight percent to about 3 weight percent, based on the total weight of the wellbore servicing fluid.

10. The wellbore servicing fluid of claim 1 , further comprising:
(d) a proppant; and
(e) a gelling agent, wherein the gelling agent has a molecular weight in a range of equal to or greater than 1.2 MM Da to equal to or less than 5 MM Daltons (Da).

11. The wellbore servicing fluid of claim 10 , wherein the gelling agent comprises a guar, hydrdoxypropyl guar (HPG), carboxymethyl guar (CMG), carboxymethyl hydroxyl propyl guar (CMHPG), hydroxyethyl cellulose (HEC), carboxymethyl hydroxyethyl cellulose, carboxymethyl cellulose (CMC), xanthan, pectins, diutans, or combinations thereof.

12. The wellbore servicing fluid of claim 10 , wherein the gelling agent is present in an amount in a range of from about 0.01 weight percent to about 3 weight percent, based on the total weight of the wellbore servicing fluid.

13. The wellbore servicing fluid of claim 1 , wherein the cationic formation stabilizer produces equal to or less than 0.5 mg/pore volume (PV) of fines as determined by measuring the amount of fine particulate particles emitted from a 1-inch inside diameter, 10-inch length sandpack column comprising 10% illite at a treatment flow rate ranging from 5 to 25 mL/min of the servicing fluid.

14. The wellbore servicing fluid of claim 13 , wherein the cationic formation stabilizer has a permanency of equal to or greater than 30 pore volumes (PV) as determined by measuring the amount of fine particulate particles in mg/PV emitted from a 1-inch inside diameter 10-inch length of a previously treated sandpack column comprising 10% illite at a flow rate ranging from 5 to 25 mL/min of water and the amount of fine particular particles recovered does not exceed 0.5 mg/PV prior to at least 30 PVs of water being passed through the previously treated sandpack column.

15. The wellbore servicing fluid of claim 14 , wherein the cationic formation stabilizer and the anionic friction reducer are visibly clear when mixed.

16. A method of servicing a wellbore penetrating a subterranean formation, comprising:
placing a wellbore servicing fluid into the wellbore, wherein the subterranean formation comprises shale and wherein the wellbore servicing fluid comprises (a) a cationic formation stabilizer having (i) a molecular weight in a range of from equal to or greater than 0.05 to equal to or less than 2.0 kiloDaltons (kDa), or (ii) cationic charge functional groups of greater than 2 to equal to or less than 5 cationic charges per molecule, or (iii) both (i) and (ii); (b) an anionic friction reducer; and (c) an aqueous fluid.

17. A wellbore servicing fluid comprising:
(a) a cationic formation stabilizer comprising a modified guanidium salt having the formula:

N 1 -(bis(dimethylamino)methylene)-2-hydroxy-N 1 -(2-hydroxy-3-(trimethylammonio)propyl)-N 3 ,N 3 ,N 3 -trimethylpropane-1,3-diaminium dichloride
(b) an anionic friction reducer comprising acrylamide and acrylic acid copolymers of the formula:

(c) water,
(d) sand, and
(e) carboxymethyl cellulose.

18. The wellbore servicing fluid of claim 17 , wherein the cationic formation stabilizer is present in an amount in a range of from about 0.001 weight percent to about 3 weight percent, based on the total weight of the wellbore servicing fluid.

19. The wellbore servicing fluid of

Assignees

• Halliburton Energy Services Inc

Inventors

• Benoit Denise Nicole
• Holan Kristina Henkel
• Recio Iii Antonio

Classifications

• C09K8/68

  containing organic compounds · CPC title

• C09K8/24 Primary

  Polymers · CPC title

• C09K8/88

  macromolecular compounds · CPC title

• C09K8/035

  Organic additives · CPC title

• C09K8/04 Primary

  Aqueous well-drilling compositions · CPC title