COMPOSITIONS AND METHODS FOR INHIBITING LOST CIRCULATION DURING WELL OPERATION

• US 20100230164A1
• Filed: 06/30/2009
• Published: 09/16/2010
• Est. Priority Date: 03/12/2009
• Status: Abandoned Application

• Current Assignee: Daniel Guy Pomerleau
• Original Assignee: Daniel Guy Pomerleau
• Inventors: POMERLEAU, Daniel Guy
• Application Number:
  US12/495,251
• Publication Number:
  US 20100230164A1
• Time in Patent Office: Days
• US Class Current: 175/40
• CPC Class Codes: C09K 2208/08 Fiber-containing well treatment fluids
• CPC Class Codes: C09K 8/032 Inorganic additives
• CPC Class Codes: C09K 8/5045 containing inorganic compounds
• CPC Class Codes: E21B 21/003 Means for stopping loss of drilling fluid plastering the borehole wall E21B33/138
• CPC Class Codes: E21B 43/267 reinforcing fractures by propping
• CPC Class Codes: Y10T 428/2982 Particulate matter [e.g., sphere, flake, etc.]

Abstract

Drilling fluid additive compositions are provided for use with synthetic, oil based, or water based drilling fluids. The combined additive and drilling fluid are effective for reducing lost circulation, seepage loss as well as wellbore strengthening and/or wellbore lining. The method includes injecting the drilling fluid and 0.01 or more pounds per barrel of a loss control additive including ground and sized pumice, barite, anthracite or dolomite.

Claims

1. A drilling fluid additive for reducing circulation loss during drilling operations comprising ground pumice, barium, anthracite or dolomite having an average particle size between 100 and 4000 microns.

2. A drilling fluid composition comprising a liquid carrier and a drilling fluid additive including any one of or a combination of ground pumice, barium, anthracite or dolomite having an average particle size between 100 and 4000 microns.

3. A drilling fluid composition as in claim 2 characterized in that the additive is mixed with the liquid carrier such that the concentration of additive in the liquid carrier is greater then 0.01 pounds per barrel (ppb) of liquid carrier.

4. A drilling fluid composition as in claim 3 wherein the additive is barite and the concentration is 0.01-700 ppb.

5. A drilling fluid composition as in claim 3 wherein the additive is pumice and the concentration is 0.01-300 ppb.

6. A drilling fluid composition as in claim 3 wherein the additive is dolomite and the concentration is 0.01-300 ppb.

7. A drilling fluid composition as in claim 3 wherein the concentration is less than 48% by volume additive in liquid carrier.

8. A drilling fluid as in claim 3 wherein the additive has an average particle size between 180 and 4000 microns.

9. The drilling fluid of claim 3 where the additive has an average particle size between 600 and 2000 microns.

10. The drilling fluid of claim 3 where the additive has an average particle size between 750 and 1400 microns.

11. The drilling fluid of claim 3 where the additive has a particle size distribution of 180 to 425 microns.

12. The drilling fluid of claim 3 further comprising a secondary additive selected from any one of or a combination of hydrophobic synthetic fibrous particles, comminuted particles of plant and mineral materials, weighting materials and gelling agents.

13. A drilling fluid composition as in claim 12 wherein the hydrophobic synthetic fibrous particles are selected from any one of or a combination of nylon, rayon, polyolefin fibers.

14. A drilling fluid composition as in claim 12 wherein the comminuted particles of plant and mineral materials are selected from particles derived from nut and seed shells or hulls including peanut, almond, brazil, cocoa bean, coconut, cotton, flax, grass, linseed, maize, millet, oat, peach, peanut, rice, rye, soybean, sunflower, walnut, wheat;

rice fractions including rice tips, rice straw and rice bran;

crude pectate pulp;

peat moss fibers;

flax;

cotton;

cotton linters;

wool;

sugar cane;

paper;

shredded paper;

ground hemp;

paper pulp;

cellophane strips;

ground bark;

bagasse;

bamboo;

corn stalks;

tree fractions including sawdust, wood or bark;

straw;

cork;

dehydrated vegetable matter;

whole or ground corn cobs;

corn cob fractions including light density pith core, corn cob ground woody ring portion, corn cob coarse or fine chaff portion;

cotton seed stems;

flax stems;

wheat stems;

sunflower seed stems;

soybean stems;

maize stems;

rye grass stems;

millet stem;

gilsonite;

asphaltine;

waxes; and

calcium carbonate.

15. A drilling fluid composition as in claim 12 wherein the weighting materials are selected from any one of or a combination of barite, barium sulfate, calcium carbonate, galena, hematite, magnetite, iron oxides, ilmenite, siderite, celestite, dolomite, calcite, manganese oxides, zinc oxide and zirconium oxides.

16. A drilling fluid composition as in claim 12 wherein the gelling agents are selected from any one of or a combination of starch or derivatized starches and chemically modified starches including carboxymethyl starch, hydroxyethyl starch, hydroxypropyl starch, acetate starch, sulfamate starch, phosphate starch, nitrogen modified starch, starch cross-linked with aldehydes, epichlorohydrin, borates, and phosphates.

17. A method for ameliorating seepage loss while drilling a subterranean well comprising the steps of:

c. monitoring seepage loss while drilling;

d. circulating a synthetic oil, oil, or water based drilling mud into the drill string wherein the drilling fluid comprises a liquid carrier and an additive of ground pumice, barite, anthracite or dolomite or a combination thereof and wherein the liquid carrier is a synthetic, oil, or water based drilling mud and the additive is added to the liquid carrier at a concentration of greater then 0.01 pounds per barrel of liquid carrier.

18. A method as in claim 17 wherein the additive is barite and the concentration is 0.01-700 ppb.

19. A method as in claim 17 wherein the additive is pumice and the concentration is 0.01-300 ppb.

20. A method as in claim 17 wherein the additive is dolomite and the concentration is 0.01-300 ppb.

21. A method as in claim 17 wherein the additive is anthracite and the concentration is 0.01-300 ppb.

22. A method as in claim 17 wherein the concentration is less than 48% by volume additive in liquid carrier.

23. A method as in claim 17 wherein the additive has an average particle size between 100 and 4000 microns.

24. A method as in claim 17 wherein the concentration of additive is increased during circulation.

25. A method as in claim 17 wherein step b) is initiated with an additive having an average particle size in the lower half of the range of 100-4000 microns and wherein step b) is repeated with an additive having a larger average particle size than the lower half.

26. A method as in claim 17 wherein step b) is initiated with an additive having an average particle size in the upper half of the range of 100-4000 microns and wherein step b) is repeated with an additive having a smaller average particle size than the upper half.

27. A method as in claim 17 wherein step b) is initiated with an additive having an average particle size in the lower quartile of the range of 100-4000 microns and wherein step b) is repeated with an additive having a larger average particle size than the lower quartile.

28. A method as in claim 17 wherein step b) is initiated with an additive having an average particle size in the upper quartile of the range of 100-4000 microns and wherein step b) is repeated with an additive having a smaller average particle size than the upper quartile.

29. A method of recognizing and controlling an underground blowout in a subterranean formation comprising the steps of:

e. monitoring surface pressure within a well to detect a pressure increase indicating fluid influx into the well;

f. closing in the well in response to the pressure increase;

g. monitoring surface pressure and detecting an underground blowout if well pressure drops and fluid loss increases above threshold values;

h. circulating a drilling fluid composition comprising a liquid carrier and a drilling fluid additive including any one of or a combination of ground pumice, barium, anthracite or dolomite having an average particle size between 100 and 4000 microns; and

,

i. monitoring the fluid loss and adjusting the size and/or concentration of drilling fluid additive in response to changes or lack of changes in the fluid loss.

30. A proppant for use in downhole fracturing comprising any one of or a combination of ground pumice, barium, anthracite and dolomite wherein the pumice, barium, anthracite or dolomite having an average particle size between 100 and 35,000 microns.

31. A proppant as in claim 30 wherein the proppant is anthracite.

32. A proppant as in claim 30 wherein the proppant is pumice.