Polyacrylamide drag reducer compositions
Polyacrylamide (PAM) compositions and methods of using the compositions as drag reducers in well treatment fluids are disclosed. The compositions use PAM particles with log-asymmetric particle size distributions. For example, about 10% or more of the PAM particles may have particle sizes above 76 μm, but the particle size distribution tails toward lower particles sizes. Dry PAM formulations and premixed concentrate compositions are disclosed. Well treating fluids prepared using the disclosed compositions reach maximum drag reduction very quickly and also exhibit high sustained drag reduction.
1. A composition for preparing a fracturing fluid, the composition comprising:
an organic fluid,
a suspension agent, and
a population of particles consisting of polyacrylamide (PAM) having a particle size distribution, wherein the specific surface area of the particle size distribution is about 35 m 2 /kg or greater, wherein the composition is a concentrate composition, and wherein the PAM particles are within a molecular weight range of 10,000,000 to 30,000,000 Da.
2. The composition of claim 1 , wherein the specific surface area of the particle size distribution is 100 m 2 /kg or greater.
3. The composition of claim 1 , wherein at least 3% of the particles have a particle size less than 11 μm.
4. The composition of claim 1 , wherein at least 10% of the particles have a particle size less than 21 μm.
5. The composition of claim 1 , wherein 40-65% of the particles are in a particle size range of 76-211 μm.
6. The composition of claim 1 , wherein at least 10% of the particles have a particle size of greater than about 76 μm.
7. The composition of claim 1 , wherein the particle size distribution, when plotted using a logarithmic particle size axis, is asymmetric and is negatively skewed.
8. The composition of claim 1 , wherein the organic fluid is a low aromatic mineral oil.
9. The composition of claim 1 , wherein the suspension agent is an organophilic clay.
10. The composition of claim 9 , further comprising a polar activator.
11. The composition of claim 10 , wherein the polar activator comprises propylene carbonate.
12. The composition of claim 1 , further comprising one or more surfactants.
13. The composition of claim 1 , comprising 2-6 pounds of the PAM particles per gallon of the concentrate composition.
14. A method of treating a wellbore, the method comprising:
providing a concentrate composition comprising:
an organic fluid,
a suspension agent, and
a population of particles consisting of polyacrylamide (PAM) having a particle size distribution, wherein the specific surface area of the particle size distribution is about 35 m 2 /kg or greater, wherein the composition is a concentrate composition, and wherein the PAM particles are within a molecular weight range of 10,000,000 to 30,000,000 Da,
preparing a well treatment fluid by mixing the concentrate composition with a base treating fluid, and
pumping the well treatment fluid into the wellbore.
15. The method of claim 14 , wherein the well treatment fluid comprises 0.1 to 5 gallons of concentrate composition per 1,000 gallons of well treatment fluid.
16. The method of claim 14 , wherein the well treatment fluid comprises 0.1 to 35 pounds of PAM per 1,000 gallons of well treatment fluid.
17. The method of claim 14 , wherein the well treatment fluid comprises 0.1 to 8 pounds of PAM per 1,000 gallons of well treatment fluid.
18. The method of claim 14 , wherein the well treatment fluid comprises 8 to 35 pounds of PAM per 1,000 gallons of well treatment fluid.
19. The method of claim 14 , further comprising blending a proppant with the well treatment fluid before pumping the well treatment fluid into the wellbore.