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A final fracture treatment that achieves maximum fracture length, fracture width and proppant conductivity is determined to be optimal.
An optimization algorithm is proposed for maximizing the storage based on injection temperature while limiting the maximum fracture length and minimizing the risk of leakage from thermal effects of CO2 storage while improving the injection capacity.
There is a real chance of a deceptive fracture pattern if: i) the angular values at the intersection of the fault and its fractures (mode I opening fracture) exceed 50° in the wall damage zone; ii) the scaling relation between fault length and maximum fracture length does not fit a power law; iii) fractures acted as shear fractures.
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Maximum propped fracture length is obtained at 60 pptg for any proppant size.
In the engineered volume of Soultz with a vertical reservoir extension of about 3500 m, maximum mean fracture length and damage zone size are of about 2700 and 60 m, respectively (Massart et al. 2010).
It also provides the ability to set a maximum number of jobs per schedule and a maximum shift length.
Table 2 Base input parameters used for model comparison Parameter Value Wellbore radius, m 0.15 Fracture length, m 0.15 Minimum horizontal stress, MPa 24.82 Maximum horizontal stress, MPa 20.68 Pore pressure, MPa 12.41 Fracture toughness, MPa-m0.5 2.2 Tensile strength, MPa 15 Rock permeability, mD 1 Mudcake permeability, mD 0.01.
This paper introduces a general 3D mixed-mode fracture criterion based on the maximum mean principal stress (MMPS) by introducing the concept of a characteristic fracture length that is related to the material tensile strength.
With careful observation, it can be found that the maximum width locates at the wellbore (the center of the fracture), and then gradually deceases along the fracture length directions.
Fracture length.
Half fracture length (m).
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