A method for improving wellbore pressure containment comprising: a) selecting a fracture sealing width of a fracture connecting to a wellbore in a formation; b) defining a particulate fracture sealing composition; c) determining a spurt loss volume for the fracture sealing width at different concentrations of the defined sealing composition in a fluid; d) evaluating a fracture volume capacity by i) computing the value of L = W R • E 4 1 − v 2 Δ ⁢ P 2 + R 2 where W is the selected fracture sealing width at the fracture mouth, R is the wellbore radius, v is a Poisson' s ratio of the formation, E is a Young's modulus of the formation, L is the distance from the center of the wellbore to the fracture tip, and Δ P is the net pressure of fracture pressure above the fracture closing stress; ii) computing the value of A = ∫ R L W x dx where A is a pressurized fracture cross section area; iii) W x = 4 1 − v 2 Δ ⁢ P E L 2 − x 2 where W(x) is an inflated fracture width at a location x between the fracture mouth and the fracture tip; iv) computing the value of fracture volume capacity V c =A•H wherein H defines a fracture height; and e) selecting a concentration of the sealing composition for particulate fracture sealing fluid wherein the spurt loss volume for the sealing fluid is less than or equal to the fracture volume capacity. a) selecting a fracture sealing width of a fracture connecting to a wellbore in a formation; b) defining a particulate fracture sealing composition; c) determining a spurt loss volume for the fracture sealing width at different concentrations of the defined sealing composition in a fluid; d) evaluating a fracture volume capacity by i) computing the value of L = W R • E 4 1 − v 2 Δ ⁢ P 2 + R 2 where W is the selected fracture sealing width at the fracture mouth, R is the wellbore radius, v is a Poisson' s ratio of the formation, E is a Young's modulus of the formation, L is the distance from the center of the wellbore to the fracture tip, and Δ P is the net pressure of fracture pressure above the fracture closing stress; ii) computing the value of A = ∫ R L W x dx where A is a pressurized fracture cross section area; iii) W x = 4 1 − v 2 Δ ⁢ P E L 2 − x 2 where W(x) is an inflated fracture width at a location x between the fracture mouth and the fracture tip; iv) computing the value of fracture volume capacity V c =A•H wherein H defines a fracture height; and i) computing the value of L = W R • E 4 1 − v 2 Δ ⁢ P 2 + R 2 where W is the selected fracture sealing width at the fracture mouth, R is the wellbore radius, v is a Poisson' s ratio of the formation, E is a Young's modulus of the formation, L is the distance from the center of the wellbore to the fracture tip, and Δ P is the net pressure of fracture pressure above the fracture closing stress; ii) computing the value of A = ∫ R L W x dx where A is a pressurized fracture cross section area; iii) W x = 4 1 − v 2 Δ ⁢ P E L 2 − x 2 where W(x) is an inflated fracture width at a location x between the fracture mouth and the fracture tip; iv) computing the value of fracture volume capacity V c =A•H wherein H defines a fracture height; and e) selecting a concentration of the sealing composition for particulate fracture sealing fluid wherein the spurt loss volume for the sealing fluid is less than or equal to the fracture volume capacity.