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Table 2 Pore pressure deviations (dP) between 3D basin models and estimated/measured pressures as average absolute deviation (dPPTVD; dPPmax), at depth of estimated maximum pore pressure (dPPTVD), and maximum pore pressures (dPPmax)

From: Predictability and controlling factors of overpressure in the North Alpine Foreland Basin, SE Germany: an interdisciplinary post-drill analysis of the Geretsried GEN-1 deep geothermal well

Model ID Permeability modela Average abs(dPPmax) Average abs(dPPTVD) Well A (PPmax = 1.09 g/cm3) Well B (PPmax = 1.65 g/cm3) Well C (PPmax = 1.89 g/cm3) Well D (PPmax = 1.76 g/cm3)
Ch Ru Sch UC dPP2554 m dPPmax dPP4035 m dPPmax dPP4278 m dPPmax dPP3633 m dPPmax
 g/cm3  g/cm3  g/cm3 g/cm3 g/cm3 g/cm3 g/cm3  g/cm3 g/cm3  g/cm3
Pressure calibration
 C1 50 50 50 50 0.52 0.66 − 0.23 − 0.04 − 0.73 − 0.58 − 0.89 − 0.76 − 0.79 − 0.7
 C2 70 70 70 70 0.16 0.53 − 0.17 0.06 − 0.64 − 0.1 − 0.7 − 0.23 − 0.62 − 0.26
 C3 90 90 90 90 0.57 0.40 0.21 0.89 − 0.53 0.58 − 0.47 0.35 − 0.37 0.45
 C4 50 50 090B 090B 0.39 0.40 − 0.06 − 0.04 − 0.47 − 0.46 − 0.59 − 0.59 − 0.46 − 0.46
 C5 50 70 090B 090B 0.29 0.30 − 0.06 − 0.04 − 0.41 − 0.4 − 0.39 − 0.38 − 0.35 − 0.35
 C6 50 90 090B 090B 0.05 0.06 − 0.04 − 0.04 − 0.1 − 0.09 − 0.03 0 − 0.06 − 0.06
 C7 50 050B 090B 090B 0.25 0.25 − 0.06 − 0.04 − 0.32 − 0.31 − 0.32 − 0.32 − 0.31 − 0.31
 C8 50 070B 090B 090B 0.08 0.03 − 0.04 − 0.03 0.04 0.12 0 0.09 0.04 0.06
 C9 50 090B 090B 090B 0.37 0.05 0.08 0.08 0.09 0.53 − 0.02 0.41 0.03 0.45
 C10 50 070B 070B 070B 0.05 0.20 − 0.04 − 0.04 − 0.4 − 0.06 − 0.18 0.03 − 0.19 − 0.06
 C11 50 070B 070B 090B 0.04 0.04 − 0.04 − 0.04 − 0.08 0.04 − 0.04 0.06 − 0.01 0.01
 C12 50 070B 090B 070B 0.05 0.06 − 0.04 − 0.03 − 0.09 0.07 − 0.09 0.07 − 0.03 0.03
 C13 50 90 070B 070B 0.16 0.22 − 0.07 − 0.04 − 0.4 − 0.3 − 0.18 − 0.09 − 0.24 − 0.22
 C14 50 90 070B 090B 0.08 0.10 − 0.07 − 0.04 − 0.18 − 0.16 − 0.07 − 0.04 − 0.09 − 0.09
 C15 50 90 090B 070B 0.09 0.12 − 0.04 − 0.04 − 0.19 − 0.15 − 0.11 − 0.03 − 0.14 − 0.13
 C16 60 90 070B 070B 0.09 0.18 − 0.03 0 − 0.33 − 0.17 − 0.17 − 0.06 − 0.2 − 0.15
 C17 60 90 070B 090B 0.03 0.06 − 0.04 0 − 0.1 − 0.06 − 0.06 − 0.01 − 0.05 − 0.05
 C18 60 90 090B 070B 0.04 0.08 0.03 0.04 − 0.11 − 0.05 − 0.1 − 0.01 − 0.09 − 0.06
 C19 (best fit) 60 90 090B 090B 0.03 0.03 0.03 0.04 − 0.02 0.01 − 0.02 0.03 − 0.03 − 0.03
 C20 60 070B 070B 070B 0.03 0.20 0.02 0.03 − 0.39 − 0.02 − 0.19 0.02 − 0.18 − 0.05
 C21 (Fig. 8) 60 070B 070B 090B 0.04 0.03 0.01 0.02 − 0.06 0.06 − 0.05 0.06 0 0.02
 C22 60 070B 090B 070B 0.06 0.06 0.04 0.04 − 0.08 0.08 − 0.1 0.06 − 0.03 0.04
 C23 60 070B 090B 090B 0.08 0.04 0.04 0.04 0.05 0.13 − 0.01 0.08 0.04 0.06
 C24 70 90 070B 070B 0.08 0.16 0.1 0.2 − 0.24 0.04 − 0.14 0.01 − 0.15 − 0.05
 C25 70 70 090B 090B 0.12 0.11 0.16 0.2 0 0.08 − 0.16 − 0.09 − 0.12 − 0.1
 C26 70 90 090B 090B 0.13 0.09 0.22 0.25 0.09 0.14 0.01 0.07 0.03 0.06
Impact of Schoeneck Formation and Eocene
 Sch1 60 90 50 090B 0.04 0.07 − 0.06 − 0.01 − 0.12 − 0.07 − 0.06 − 0.01 − 0.05 − 0.05
 Sch2 (Fig. 8) 60 90 Lmst 090B 0.22 0.70 − 0.06 − 0.01 − 0.8 − 0.28 − 1.01 − 0.22 − 0.91 − 0.38
 Eo1b (Fig. 8) 60 90 090B 090B 0.09 0.18 0.02 0.03 − 0.16 − 0.09 − 0.37 − 0.12 − 0.18 − 0.12
Impact of Upper Cretaceous
 LC1 60 90 090B 50 0.08 0.17 0.03 0.04 − 0.15 − 0.07 − 0.34 − 0.1 − 0.17 − 0.11
 LC2 60 90 090B Lmst 0.08 0.18 0.03 0.04 − 0.15 − 0.08 − 0.35 − 0.11 − 0.18 − 0.11
 LC3c (Fig. 8) 60 90 090B 090B 0.25 0.24 0.75 0.75 0.17 0.17 0 0.04 0.02 0.02
  1. a50, 60, 70, 90 = clay content in percentage applied to the porosity, permeability model of Yang and Aplin (2010); 50B, 70B, 90B = 2-phase permeability model of Busch and Amann-Hildenbrand (2013) applied to porosity–permeability model of Yang and Aplin (2010) with clay contents of 50%, 70% and 90%, respectively. Lmst = ooid grain stone (Hantschel and Kauerauf 2009)
  2. bEocene modeled as ooid grain stone (Hantschel and Kauerauf 2009)
  3. cLower Cretaceous modeled as 2-phase permeability-corrected (Busch and Amann-Hildenbrand 2013) porosity–permeability relationship (Yang and Aplin 2010) for 90% clay content