Preface: Hydraulic Fracturing, A Technology for All Time |
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1 | (1) |
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Reservoir Stimulation in Petroleum Production |
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1 | (2) |
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1 | (2) |
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3 | (1) |
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3 | (8) |
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4 | (1) |
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IPR for pseudosteady state |
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5 | (1) |
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IPR for transient (or infinite-acting) flow |
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5 | (1) |
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Horizontal well production |
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6 | (4) |
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10 | (1) |
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Alterations in the near-wellbore zone |
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11 | (7) |
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11 | (1) |
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Components of the skin effect |
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12 | (1) |
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Skin effect caused by partial completion and slant |
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12 | (1) |
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13 | (3) |
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Hydraulic fracturing in production engineering |
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16 | (2) |
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Tubing performance and NODAL* analysis |
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18 | (2) |
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Decision process for well stimulation |
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20 | (2) |
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21 | (1) |
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Physical limits to stimulation treatments |
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22 | (1) |
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Reservoir engineering considerations for optimal production enhancement strategies |
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22 | (6) |
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Geometry of the well drainage volume |
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23 | (1) |
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Well drainage volume characterizations and production optimization strategies |
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24 | (4) |
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28 | (1) |
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28 | |
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18 | |
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Formation Characterization: Well and Reservoir Testing |
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Christine A. Ehlig-Economides |
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Evolution of a technology |
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1 | (2) |
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Horner semilogarithmic analysis |
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1 | (1) |
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2 | (1) |
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Pressure derivative in well test diagnosis |
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3 | (4) |
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Parameter estimation from pressure transient data |
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7 | (5) |
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7 | (2) |
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9 | (1) |
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10 | (1) |
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11 | (1) |
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Wellbore storage and pseudosteady state |
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11 | (1) |
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Test interpretation methodology |
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12 | (2) |
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Analysis with measurement of layer rate |
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14 | (1) |
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Layered reservoir testing |
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15 | (1) |
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Selective inflow performance analysis |
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15 | (1) |
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Analysis of multilayer transient test data |
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16 | (1) |
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Testing multilateral and multibranch wells |
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16 | (1) |
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Permeability determination from a fracture injection test |
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17 | (1) |
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Pressure decline analysis with the Carter leakoff model |
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17 | (4) |
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Filter-Cake plus reservior pressure drop leakoff model (according to Mayerhofer et al., 1993) |
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21 | |
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Formation Characterization: Rock Mechanics |
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1 | (3) |
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Sidebar 3A. Mechanics of hydraulic fracturing |
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2 | (2) |
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4 | (2) |
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4 | (1) |
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5 | (1) |
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5 | (1) |
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6 | (6) |
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6 | (2) |
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Sidebar 3C. Elastic constants |
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8 | (1) |
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Influence of pore pressure |
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8 | (1) |
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9 | (2) |
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11 | (1) |
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11 | (1) |
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Rock mechanical property measurement |
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12 | (9) |
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Importance of rock properties in stimulation |
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12 | (1) |
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13 | (1) |
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14 | (1) |
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15 | (4) |
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Rock strength, yield criterion and failure envelope |
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19 | (1) |
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19 | (1) |
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Sidebar 3D. Fracture toughness testing |
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20 | (1) |
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State of stress in the earth |
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21 | (7) |
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22 | (1) |
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23 | (1) |
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23 | (2) |
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Influence of pore pressure |
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25 | (1) |
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26 | (1) |
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Principal stress direction |
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26 | (1) |
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Stress around the wellbore |
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26 | (1) |
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Stress change from hydraulic fracturing |
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27 | (1) |
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In-situ stress management |
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28 | (1) |
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Importance of stress measurement in stimulation |
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28 | (1) |
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Micro-hydraulic fracturing techniques |
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28 | (6) |
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Fracture calibration techniques |
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34 | (1) |
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34 | |
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Formation Characterization: Well Logs |
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1 | (1) |
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2 | (1) |
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2 | (1) |
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Properties related to the diffusion of fluids |
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3 | (10) |
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3 | (2) |
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5 | (1) |
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6 | (2) |
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Sidebar 4A. Permeability-porosity correlations |
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8 | (2) |
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10 | (1) |
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Skin effect and damage radius |
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11 | (1) |
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12 | (1) |
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Properties related to the deformation and fracturing of rock |
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13 | (11) |
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13 | (2) |
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15 | (9) |
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24 | |
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Basics of Hydraulic Fracturing |
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1 | (8) |
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1 | (3) |
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4 | (2) |
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Design considerations and primary variables |
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6 | (1) |
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Sidebar 5A. Design goals and variables |
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7 | (2) |
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9 | (1) |
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9 | (1) |
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10 | (3) |
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11 | (1) |
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Sidebar 5B. Highway analogy for dimensionless fracture conductivity |
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11 | (1) |
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12 | (1) |
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Reservoir effects on fluid loss |
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13 | (1) |
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13 | (7) |
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13 | (1) |
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14 | (1) |
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15 | (1) |
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Fluid mechanics and fluid flow |
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15 | (1) |
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Fracture mechanics and fracture tip effects |
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16 | (1) |
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17 | (1) |
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Variable sensitivities and interactions |
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18 | (2) |
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Treatment pump scheduling |
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20 | (6) |
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Fluid and proppant selection |
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20 | (1) |
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21 | (2) |
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23 | (1) |
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24 | (1) |
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25 | (1) |
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Economics and operational considerations |
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26 | (1) |
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26 | (1) |
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27 | |
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Appendix: Evolution of hydraulic fracturing design and evaluation |
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1 | (1) |
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Mechanics of Hydraulic Fracturing |
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1 | (1) |
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History of early hydraulic fracture modeling |
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2 | (6) |
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2 | (1) |
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Hydraulic fracture modeling |
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3 | (3) |
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Sidebar 6A. Approximation to the Carter equation for leakoff |
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6 | (1) |
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Sidebar 6B. Approximations to Nordgren's equations |
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6 | (2) |
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Sidebar 6C. Radial fracture geometry models |
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8 | (1) |
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Three-dimensional and pseudo-three-dimensional models |
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8 | (17) |
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Sidebar 6D. Field determination of fracture geometry |
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10 | (1) |
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Planar three-dimensional models |
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11 | (1) |
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Sidebar 6E. Lateral coupling in pseudo-three-dimensional models |
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12 | (1) |
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Sidebar 6F. Momentum conservation equation for hydraulic fracturing |
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13 | (1) |
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Sidebar 6G. Momentum balance and constitutive equation for non-Newtonian fluids |
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14 | (2) |
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Cell-based pseudo-three-dimensional models |
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16 | (4) |
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Sidebar 6H. Stretching coordinate system and stability analysis |
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20 | (3) |
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Lumped pseudo-three-dimensional models |
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23 | (2) |
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25 | (3) |
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25 | (1) |
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26 | (1) |
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26 | (1) |
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26 | (1) |
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27 | (1) |
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27 | (1) |
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28 | (1) |
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Effect of proppant on fracturing fluid rheology |
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28 | (1) |
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28 | (1) |
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29 | (1) |
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29 | (1) |
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Historical heat transfer models |
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30 | (1) |
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Improved heat transfer models |
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30 | (1) |
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30 | (6) |
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Sidebar 6I. Efficient heat transfer algorithm |
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31 | (1) |
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Sidebar 6J. Verification of efficient thermal calculations |
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32 | (1) |
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Linear elastic fracture mechanics |
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32 | (1) |
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Sidebar 6K. Crack tip stresses and the Rice equation |
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33 | (1) |
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34 | (1) |
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35 | (1) |
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Tortuosity and other near-well effects |
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36 | (4) |
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Fracture geometry around a wellbore |
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36 | (1) |
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Perforation and deviation effects |
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36 | (1) |
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37 | (1) |
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37 | (1) |
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38 | (2) |
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40 | (4) |
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Historical acid fracturing models |
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40 | (1) |
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40 | (1) |
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Acid fracture conductivity |
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41 | (1) |
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Energy balance during acid fracturing |
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42 | (1) |
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42 | (1) |
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42 | (1) |
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43 | (1) |
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Acid fracturing: fracture geometry model |
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43 | (1) |
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44 | (2) |
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46 | (2) |
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Sidebar 6L. Approximate proppant schedules |
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47 | (1) |
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Pressure history matching |
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48 | (1) |
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Sidebar 6M. Theory and method of pressure inversion |
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48 | |
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Fracturing Fluid Chemistry and Proppants |
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1 | (1) |
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1 | (5) |
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6 | (1) |
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7 | (1) |
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Materials and techniques for acid fluid-loss control |
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7 | (1) |
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Materials and techniques for acid reaction-rate control |
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8 | (1) |
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8 | (2) |
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9 | (1) |
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9 | (1) |
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10 | (9) |
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10 | (3) |
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Sidebar 7A. Ensuring optimum crosslinker performance |
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13 | (1) |
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14 | (2) |
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Sidebar 7B. Breaker selection |
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16 | (1) |
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16 | (2) |
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18 | (1) |
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18 | (1) |
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19 | (1) |
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19 | (1) |
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19 | (3) |
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Physical properties of proppants |
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19 | (2) |
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21 | (1) |
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Sidebar 7C. Minimizing the effects of resin-coated proppants |
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22 | (1) |
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22 | (1) |
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22 | (1) |
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23 | (1) |
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23 | |
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Performance of Fracturing Materials |
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1 | (1) |
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Fracturing fluid characterization |
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1 | (1) |
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2 | (1) |
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Translation of field conditions to a laboratory environment |
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2 | (1) |
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Molecular characterization of gelling agents |
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2 | (4) |
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Correlations of molecular weight and viscosity |
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2 | (1) |
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Concentration and chain overlap |
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3 | (1) |
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Molecular weight distribution |
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4 | (1) |
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Characterization of insoluble components |
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5 | (1) |
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Reactions sites and kinetics of crosslinking |
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5 | (1) |
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6 | (13) |
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7 | (1) |
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7 | (1) |
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Models that more fully describe fluid behavior |
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8 | (2) |
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Determination of fracturing fluid rheology |
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10 | (2) |
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Rheology of foam and emulsion fluids |
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12 | (3) |
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Effect of viscometer geometry on fluid viscosity |
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15 | (1) |
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Characterization of fluid microstructure using dynamic oscillatory measurements |
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16 | (1) |
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17 | (1) |
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17 | (2) |
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19 | (3) |
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Characterization of proppant transport properties |
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19 | (2) |
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Particle migration and concentration |
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21 | (1) |
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22 | (1) |
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Fluid loss under static conditions |
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23 | (1) |
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Fluid loss under dynamic conditions |
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24 | (1) |
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Shear rate in the fracture and its influence on fluid loss |
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25 | (1) |
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Influence of permeability and core length |
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26 | (1) |
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Differential pressure effects |
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26 | |
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Fracture Evaluation Using Pressure Diagnostics |
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1 | (1) |
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2 | (1) |
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Fundamental principles of hydraulic fracturing |
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3 | (7) |
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Fluid flow in the fracture |
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3 | (1) |
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Material balance or conservation of mass |
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4 | (1) |
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4 | (2) |
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Sidebar 9A. What is closure pressure? |
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6 | (3) |
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Sidebar 9B. Pressure response of toughness-dominated fractures |
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9 | (1) |
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10 | (24) |
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Time variation for limiting fluid efficiencies |
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12 | (1) |
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Inference of fracture geometry from pressure |
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12 | (2) |
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Diagnosis of periods of controlled fracture height growth |
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14 | (1) |
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Examples of injection pressure analysis |
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15 | (1) |
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Sidebar 9C. Pressure derivative analysis for diagnosing pumping pressure |
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16 | (2) |
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Diagnostics for nonideal fracture propagation |
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18 | (5) |
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Sidebar 9D. Fluid leakoff in natural fissures |
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23 | (1) |
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Formation pressure capacity |
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24 | (3) |
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Pressure response after a screenout |
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27 | (1) |
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Fracture diagnostics from log-log plot slopes |
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28 | (2) |
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30 | (2) |
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Sidebar 9E. Rate step-down test analysis-a diagnostic for fracture entry |
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32 | (2) |
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Analysis during fracture closure |
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34 | (11) |
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34 | (3) |
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Basic pressure decline analysis |
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37 | (1) |
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Decline analysis during nonideal conditions |
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38 | (4) |
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Generalized pressure decline analysis |
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42 | (1) |
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Sidebar 9F. G-function derivative analysis |
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43 | (2) |
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Pressure interpretation after fracture closure |
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45 | (14) |
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Why linear and radial flow after fracture closure? |
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46 | (2) |
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Linear, transitional and radial flow pressure responses |
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48 | (1) |
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Sidebar 9G. Impulse testing |
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49 | (1) |
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50 | (1) |
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Integration of after-closure and preclosure analyses |
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50 | (1) |
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Physical and mathematical descriptions |
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51 | (2) |
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53 | (1) |
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Consistent after-closure diagnostic framework |
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54 | (2) |
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Application of after-closure analysis |
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56 | (1) |
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57 | (2) |
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Numerical simulation of pressure: combined analysis of pumping and closing |
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59 | (2) |
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60 | (1) |
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60 | (1) |
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Comprehensive calibration test sequence |
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61 | |
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Background for hydraulic fracturing pressure analysis techniques |
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1 | (1) |
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Fracture Treatment Design |
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1 | (2) |
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Sidebar 10A. NPV for fixed costs or designated proppant mass |
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2 | (1) |
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3 | (11) |
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3 | (1) |
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Treatment optimization design procedure |
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3 | (1) |
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4 | (2) |
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Dimensionless fracture conductivity |
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6 | (2) |
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8 | (1) |
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8 | (1) |
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9 | (1) |
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10 | (1) |
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11 | (1) |
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Sidebar 10B. Fluid exposure time |
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12 | (1) |
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13 | (1) |
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14 | (3) |
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Sidebar 10C. Geometry models |
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14 | (1) |
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15 | (1) |
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Sources of formation parameters |
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16 | (1) |
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Sidebar 10D. In-situ stress correlation with lithology |
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16 | (1) |
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17 | (7) |
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Sidebar 10E. Fracturing economics sensitivity to formation permeability and skin effect |
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17 | (1) |
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Normal proppant scheduling |
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18 | (3) |
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21 | (3) |
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24 | (6) |
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24 | (1) |
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25 | (1) |
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Single fracture across multilayers |
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25 | (1) |
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Two fractures in a multilayer reservoir |
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26 | (2) |
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28 | (1) |
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Sidebar 10F. Fracture evaluation in multilayer zones |
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28 | (2) |
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30 | (12) |
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Acid-etched fracture conductivity |
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31 | (1) |
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Sidebar 10G. Acid-etched conductivity |
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32 | (1) |
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33 | (1) |
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Sidebar 10H. Fluid-loss control in wormholes |
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34 | (1) |
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35 | (1) |
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36 | (1) |
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36 | (5) |
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Formation reactivity properties |
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41 | (1) |
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Propped or acid fracture decision |
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41 | (1) |
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Deviated wellbore fracturing |
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42 | (1) |
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43 | (2) |
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45 | (1) |
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45 | (2) |
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Fracturing execution in deviated and horizontal wells |
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47 | (2) |
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49 | |
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1 | (1) |
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1 | (7) |
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Deviated and S-shaped completions |
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1 | (1) |
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Horizontal and multilateral completions |
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2 | (1) |
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Slimhole and monobore completions |
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2 | (1) |
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2 | (1) |
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Sidebar 11A. Factors influencing cement bond integrity |
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3 | (3) |
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Sidebar 11B. Coiled tubing-conveyed fracture treatments |
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6 | (2) |
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8 | (11) |
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8 | (1) |
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Sidebar 11C. Estimating multizone injection profiles during hydraulic fracturing |
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9 | (2) |
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Sidebar 11D. Propagating a microannulus during formation breakdown |
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11 | (1) |
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Perforation phasing for hard-rock hydraulic fracturing |
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11 | (3) |
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Other perforating considerations for fracturing |
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14 | (2) |
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Frac and packs and high-rate water packs |
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16 | (1) |
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Fracturing for sand control without gravel-pack screens |
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16 | (1) |
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Sidebar 11E. Calculation of minimum shot density for fracture stimulation |
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17 | (1) |
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Extreme overbalance stimulation |
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18 | (1) |
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Well and fracture connectivity |
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18 | (1) |
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Surface equipment for fracturing operations |
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19 | (7) |
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19 | (1) |
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19 | (3) |
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22 | (1) |
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23 | (1) |
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Proppant storage and delivery |
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23 | (1) |
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24 | (2) |
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26 | (1) |
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Bottomhole pressure measurement and analysis |
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26 | (3) |
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Proppant flowback control |
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29 | (1) |
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30 | (1) |
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30 | (1) |
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30 | (1) |
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|
30 | (1) |
|
|
30 | (2) |
|
Sidebar 11F. Fiber technology |
|
|
31 | (1) |
|
Quality assurance and quality control |
|
|
32 | (1) |
|
Health, safety and environment |
|
|
32 | (1) |
|
|
32 | (1) |
|
Environmental considerations |
|
|
33 | |
|
Appendix: Understanding perforator penetration and flow performance |
|
|
1 | (1) |
|
|
|
|
|
Post-Treatment Evaluation and Fractured Well Performance |
|
|
|
|
|
|
|
|
|
|
|
|
1 | (9) |
|
Fracture mapping techniques |
|
|
1 | (5) |
|
Pressure transient analysis |
|
|
6 | (4) |
|
Post-treatment fracture evaluation |
|
|
10 | (6) |
|
Wellbore storage dominated flow regime |
|
|
11 | (1) |
|
Fracture storage linear flow regime |
|
|
11 | (1) |
|
|
11 | (2) |
|
Formation linear flow regime |
|
|
13 | (1) |
|
|
14 | (1) |
|
Pseudosteady-state flow regime |
|
|
15 | (1) |
|
Factors affecting fractured well performance |
|
|
16 | (11) |
|
|
16 | (4) |
|
Nonlinear fluid properties |
|
|
20 | (1) |
|
Fracture damage and spatially varying fracture properties |
|
|
21 | (4) |
|
Damage in high-permeability fracturing |
|
|
25 | (1) |
|
|
26 | (1) |
|
Well test analysis of vertically fractured wells |
|
|
27 | (12) |
|
Wellbore storage dominated flow analysis |
|
|
28 | (1) |
|
Fracture storage linear flow analysis |
|
|
28 | (1) |
|
|
29 | (1) |
|
Formation linear flow analysis |
|
|
29 | (1) |
|
Pseudoradial flow analysis |
|
|
29 | (1) |
|
Well test design considerations |
|
|
30 | (1) |
|
Example well test analyses |
|
|
31 | (8) |
|
Prediction of fractured well performance |
|
|
39 | |
|
Introduction to Matrix Treatments |
|
|
|
|
|
|
|
|
|
|
|
|
1 | (3) |
|
|
1 | (1) |
|
Sidebar 13A. The history of matrix stimulation |
|
|
2 | (1) |
|
Formation damage characterization |
|
|
3 | (1) |
|
Stimulation technique determination |
|
|
3 | (1) |
|
Fluid and additive selection |
|
|
3 | (1) |
|
Pumping schedule generation and simulation |
|
|
3 | (1) |
|
|
4 | (1) |
|
|
4 | (1) |
|
|
4 | (1) |
|
|
4 | (4) |
|
Identifying low-productivity wells and stimulation candidates |
|
|
4 | (2) |
|
Sidebar 13B. Candidate selection field case history |
|
|
6 | (1) |
|
Impact of formation damage on productivity |
|
|
6 | (1) |
|
Preliminary economic evaluation |
|
|
7 | (1) |
|
Formation damage characterization |
|
|
8 | (2) |
|
Sidebar 13C. Formation damage characterization field case history |
|
|
9 | (1) |
|
Sidebar 13D. Fluid and additive selection field case history |
|
|
10 | (1) |
|
Stimulation technique determination |
|
|
10 | (1) |
|
|
11 | (21) |
|
Matrix stimulation techniques |
|
|
11 | (1) |
|
Treatment fluid selection |
|
|
12 | (7) |
|
Pumping schedule generation and simulation |
|
|
19 | (10) |
|
Sidebar 13E. Placement study case histories |
|
|
29 | (3) |
|
Final economic evaluation |
|
|
32 | (1) |
|
|
32 | (3) |
|
|
32 | (2) |
|
|
34 | (1) |
|
|
35 | (1) |
|
|
35 | (1) |
|
|
35 | (2) |
|
Post-treatment evaluation |
|
|
37 | |
|
Formation Damage: Origin, Diagnosis and Treatment Strategy |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1 | (1) |
|
|
1 | (3) |
|
|
2 | (1) |
|
Pseudoskin effects and well completion and configuration |
|
|
3 | (1) |
|
Formation damage descriptions |
|
|
4 | (9) |
|
|
4 | (2) |
|
|
6 | (1) |
|
|
6 | (1) |
|
|
7 | (1) |
|
|
8 | (1) |
|
|
9 | (1) |
|
Induced particle plugging |
|
|
9 | (1) |
|
|
10 | (1) |
|
Acid reactions and acid reaction by-products |
|
|
11 | (1) |
|
|
11 | (1) |
|
|
12 | (1) |
|
|
13 | (1) |
|
Origins of formation damage |
|
|
13 | (13) |
|
|
13 | (8) |
|
|
21 | (1) |
|
|
21 | (1) |
|
|
22 | (1) |
|
|
22 | (1) |
|
Stimulation and remedial treatments |
|
|
23 | (1) |
|
Normal production or injection operations |
|
|
24 | (2) |
|
Laboratory identification and treatment selection |
|
|
26 | (5) |
|
|
26 | (2) |
|
|
28 | (3) |
|
Treatment strategies and concerns |
|
|
31 | (8) |
|
|
33 | (1) |
|
|
34 | (1) |
|
|
35 | (1) |
|
|
35 | (1) |
|
|
36 | (1) |
|
|
36 | (1) |
|
Induced particle plugging |
|
|
36 | (1) |
|
|
37 | (1) |
|
|
37 | (1) |
|
|
38 | (1) |
|
|
38 | (1) |
|
|
39 | |
|
Additives in Acidizing Fluids |
|
|
|
|
|
|
|
|
|
|
|
|
1 | (1) |
|
|
2 | (3) |
|
|
2 | (1) |
|
|
2 | (1) |
|
Pitting types of acid corrosion |
|
|
3 | (1) |
|
|
3 | (1) |
|
Corrosion by different acid types |
|
|
3 | (1) |
|
|
4 | (1) |
|
Compatibility with other additives |
|
|
4 | (1) |
|
Laboratory evaluation of inhibitors |
|
|
5 | (1) |
|
Suggestions for inhibitor selection |
|
|
5 | (1) |
|
|
5 | (6) |
|
|
6 | (1) |
|
|
6 | (1) |
|
|
6 | (1) |
|
|
7 | (1) |
|
|
7 | (1) |
|
Properties affected by surfactants |
|
|
7 | (2) |
|
Applications and types of surfactants |
|
|
9 | (2) |
|
|
11 | (2) |
|
|
11 | (1) |
|
|
12 | (1) |
|
|
12 | (1) |
|
|
12 | (1) |
|
|
13 | (1) |
|
|
13 | (1) |
|
Adsorption of mutual solvents |
|
|
14 | (1) |
|
Chlorination of mutual solvents |
|
|
14 | (1) |
|
|
14 | (2) |
|
|
14 | (1) |
|
|
15 | (1) |
|
|
16 | (2) |
|
|
18 | (1) |
|
|
18 | (1) |
|
|
18 | (1) |
|
|
18 | (1) |
|
|
19 | (1) |
|
Facility upsets following acid stimulation |
|
|
19 | (1) |
|
|
19 | (1) |
|
Prevention of facility upsets |
|
|
20 | |
|
Fundamentals of Acid Stimulation |
|
|
|
|
|
|
|
|
|
|
|
|
1 | (1) |
|
Acid-mineral interactions |
|
|
2 | (11) |
|
Acid-mineral reaction stoichiometry |
|
|
2 | (2) |
|
Acid-mineral reaction kinetics |
|
|
4 | (1) |
|
Sidebar 16A. Calculating minimum acid volume using dissolving power |
|
|
5 | (3) |
|
Sidebar 16B. Relative reaction rates of sandstone minerals |
|
|
8 | (2) |
|
Precipitation of reaction products |
|
|
10 | (1) |
|
Sidebar 16C. Geochemical model predictions |
|
|
11 | (2) |
|
|
13 | (6) |
|
|
13 | (1) |
|
|
13 | (1) |
|
Sandstone acidizing models |
|
|
13 | (3) |
|
Sidebar 16D. Comparison of acid volumes for radial and perforation flow |
|
|
16 | (3) |
|
|
19 | (1) |
|
|
19 | (1) |
|
|
19 | (1) |
|
|
20 | (1) |
|
|
21 | (2) |
|
|
23 | (3) |
|
Sidebar 16E. Optimum injection rate for initiating carbonate treatment |
|
|
26 | (1) |
|
|
27 | |
|
Appendix: Advances in understanding and predicting wormhole formation |
|
|
1 | (1) |
|
|
|
|
|
Carbonate Acidizing Design |
|
|
|
|
|
|
|
|
|
|
|
|
1 | (1) |
|
Rock and damage characteristics in carbonate formations |
|
|
1 | (1) |
|
|
1 | (1) |
|
|
2 | (1) |
|
Carbonate acidizing with hydrochloric acid |
|
|
2 | (7) |
|
|
2 | (1) |
|
|
2 | (1) |
|
Reactivity of carbonate minerals with hydrochloric acid |
|
|
3 | (1) |
|
|
4 | (2) |
|
Sidebar 17A. Wormhole initiation and propagation |
|
|
6 | (1) |
|
Application to field design |
|
|
7 | (1) |
|
Sidebar 17B. Acidizing case study |
|
|
8 | (1) |
|
|
9 | (5) |
|
|
9 | (1) |
|
|
10 | (1) |
|
|
11 | (1) |
|
|
11 | (1) |
|
|
12 | (1) |
|
|
12 | (1) |
|
Sidebar 17C. Examples of special treatments |
|
|
13 | (1) |
|
Sidebar 17D. Placement using self-diverting acid |
|
|
13 | (1) |
|
|
14 | (1) |
|
|
14 | (1) |
|
|
14 | (1) |
|
|
14 | (1) |
|
|
14 | (1) |
|
|
14 | (1) |
|
|
15 | |
|
|
|
|
|
|
|
|
|
|
|
|
1 | (1) |
|
|
1 | (3) |
|
Hydrochloric acid chemistry |
|
|
2 | (1) |
|
Chemistry of hydrofluoric acid systems |
|
|
2 | (2) |
|
Solubility of by-products |
|
|
4 | (2) |
|
|
5 | (1) |
|
Alkali fluosilicates and fluoaluminates |
|
|
5 | (1) |
|
Aluminum fluoride and hydroxide |
|
|
5 | (1) |
|
|
5 | (1) |
|
Kinetics: factors affecting reaction rates |
|
|
6 | (1) |
|
Hydrofluoric acid concentration |
|
|
6 | (1) |
|
Hydrochloric acid concentration |
|
|
6 | (1) |
|
|
7 | (1) |
|
Mineralogical composition and accessible surface area |
|
|
7 | (1) |
|
|
7 | (1) |
|
Hydrofluoric acid reaction modeling |
|
|
7 | (1) |
|
Other acidizing formulations |
|
|
8 | (4) |
|
|
8 | (2) |
|
|
10 | (1) |
|
|
11 | (1) |
|
Mud acid plus aluminum chloride for retardation |
|
|
11 | (1) |
|
|
11 | (1) |
|
Self-generating mud acid systems |
|
|
12 | (1) |
|
Buffer-regulated hydrofluoric acid systems |
|
|
12 | (1) |
|
Damage removal mechanisms |
|
|
12 | (6) |
|
Formation response to acid |
|
|
13 | (1) |
|
|
13 | (1) |
|
Formation brine compatibility |
|
|
13 | (1) |
|
|
14 | (1) |
|
Formation mineral compatibility with fluid systems |
|
|
14 | (2) |
|
Acid type and concentration |
|
|
16 | (2) |
|
Methods of controlling precipitates |
|
|
18 | (1) |
|
|
18 | (1) |
|
Mud acid volume and concentration |
|
|
18 | (1) |
|
|
18 | (1) |
|
Acid treatment design considerations |
|
|
19 | (4) |
|
Selection of fluid sequence stages |
|
|
20 | (1) |
|
Typical sandstone acid job stages |
|
|
20 | (1) |
|
|
20 | (1) |
|
|
20 | (1) |
|
|
21 | (1) |
|
|
21 | (1) |
|
|
22 | (1) |
|
Typical sandstone acid job stages |
|
|
22 | (1) |
|
Matrix acidizing design guidelines |
|
|
23 | (3) |
|
|
24 | (1) |
|
Flowback and cleanup techniques |
|
|
25 | (1) |
|
Acid treatment evaluation |
|
|
26 | (1) |
|
|
27 | |
|
Fluid Placement and Pumping Strategy |
|
|
|
|
|
|
|
|
|
|
|
|
1 | (1) |
|
Choice of pumping strategy |
|
|
1 | (3) |
|
Importance of proper placement |
|
|
1 | (1) |
|
Comparison of diversion methods |
|
|
2 | (1) |
|
Fluid placement versus injection rate |
|
|
3 | (1) |
|
|
3 | (1) |
|
Chemical diverter techniques |
|
|
4 | (2) |
|
|
4 | (1) |
|
Diverting agent properties |
|
|
4 | (1) |
|
Classification of diverting agents |
|
|
4 | (1) |
|
Potential problems during diversion treatment |
|
|
5 | (1) |
|
Laboratory characterization |
|
|
6 | (4) |
|
Modeling diverter effects |
|
|
7 | (2) |
|
|
9 | (1) |
|
|
10 | (8) |
|
|
10 | (1) |
|
|
10 | (2) |
|
Foam behavior in porous media |
|
|
12 | (2) |
|
Foam diversion experiments |
|
|
14 | (1) |
|
Modeling and predicting foam diversion |
|
|
15 | (1) |
|
Application to field design |
|
|
16 | (2) |
|
|
18 | (1) |
|
|
19 | (1) |
|
|
20 | (3) |
|
|
20 | (2) |
|
|
22 | (1) |
|
|
23 | (1) |
|
|
24 | |
|
Matrix Stimulation Treatment Evaluation |
|
|
|
|
|
|
|
|
|
|
|
|
1 | (1) |
|
Derivation of bottomhole parameters from wellhead measurements |
|
|
1 | (1) |
|
Monitoring skin effect evolution during treatment |
|
|
1 | (3) |
|
McLeod and Coulter technique |
|
|
1 | (1) |
|
|
2 | (2) |
|
Prouvost and Economides method |
|
|
4 | (1) |
|
Deriving skin effect during treatment |
|
|
4 | (1) |
|
Determining reservoir characteristics before treatment |
|
|
4 | (1) |
|
|
5 | (1) |
|
Inverse injectivity diagnostic plot |
|
|
5 | (1) |
|
Limitations of matrix treatment evaluation techniques |
|
|
5 | (3) |
|
Sidebar 20A. Example calculation of the Prouvost and Economides method |
|
|
6 | (1) |
|
Sidebar 20B. Example application of the Hill and Zhu method |
|
|
7 | (1) |
|
Treatment response diagnosis |
|
|
8 | (3) |
|
Sidebar 20C. Production indications for matrix stimulation requirements |
|
|
10 | (1) |
|
Post-treatment evaluation |
|
|
11 | (1) |
|
|
11 | (1) |
|
|
11 | (1) |
|
|
12 | |
References |
|
|
|
R-1 | |
|
|
R-45 | |
Nomenclature |
|
N-1 | |
Index |
|
I-1 | |