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Additional resources for A Practical Companion to Reservoir Stimulation

Example text

5h). 20 (B-23) In both Eqs. B-22 and B-23, the inverse cosine must be entered in degrees. Table B-3 is a summary of fracture height migration, both upward (from the base of the reservoir) and downward (from the top of the reservoir), and the corresponding net pressures. Finally, Fig. B-3 is a graph of net pressure, Ap, for both upward and downward fracture height migration. The quantity Ahuimplies migration above the top of the reservoir; Ahd 80 30 I 277 90 323 430 I I I 370 140 433 578 120 180 473 630 150 210 492 656 200 260 514 685 Table B-3-Net pressure required for upward and downward fracture height migration for Example B-6.

2-14, To calculate Biot’s poroelastic constant, the total and bulk compressibilities are required. C, Since no information was given on reservoir pressure, then c, = 10-5psi +3x (B-9) Table B-1-Formation data for Example B-2. B-3 PRACTICAL COMPANION T O RESERVOIR STIMULATION EXAMPLE B-3 EXAMPLE B-4 Calculation of Horizontal Stresses Critical Depth for Horizontal vs. Vertical Hydraulic Fractures Calculate the minimum horizontal stress at 10,000 ft depth for a formation with the properties used in Example B-2.

Solution (Ref. 1) From Eq. 7) ( ~ 71. 5 x andp, (from Fig. 23. Then, from Eq. 8-6, q h = 160 STB/d, and from Eqs. 8-7 and 8-8, qvon,l = 261 STB/d. Finally, from Eq. 8-9, [ = 10. 2 pwf 4700 Since A = 320 acres, the side of the square is 3734 ft, and the reservoir half-length is 1867 ft, which can contain the designed fracture half-length. Thus, Fig. 8-2 for FcD = 10 can be used for the forecast. Fort = 10 days, the dimensionless time can be calculated from Eq. 245 - ,’I. 7 x lo-* andp, (from Fig.

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