TABLE OF CONTENTS. iii. Volume I

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3 iii TABLE OF CONTENTS Volume I Page CHAPTER I INTRODUCTION Historical Background Literature Review Research Objectives Research Procedure... 7 CHAPTER II RESERVOIR GEOLOGY Geologic Description Depositional Environments Rock Fabrics Summary CHAPTER III PERMEABILITY PREDICTION Definition of Permeability and Its Importance in Reservoir Characterization Literature Review: Capillary Pressure Data for Permeability Prediction Application of Predictive Models for Permeability to NRU Data Assessment of Core Data Quality CHAPTER IV CORE-LOG MODELING FOR PERMEABILITY PREDICTION Application of Predictive Models to NRU Data Literature Review: Use of Well Log Data for Permeability Prediction Conventional Core and Well Log Data Available for NRU Study Previous Permeability Modeling Efforts for the Clear Fork at the NRU Sources of Error Current Work New Rock-Log Model

4 iv Page 4.8 Summary CHAPTER V MATERIAL BALANCE DECLINE TYPE CURVE ANALYSIS Introduction Literature Review: Liquid Case (Radial Flow) Fetkovich-McCray Decline Type Curve (Radial Flow Case) Introduction and Review: Well with Infinite-Conductivity Fracture in the Center of a Bounded Circular Reservoir (Liquid Case) Summary CHAPTER VI RESERVOIR SURVEILLANCE Pressure Transient Test Overview Pressure Transient Testing at the NRU Data Acquisition Data Analysis Procedures Estimation of Average Reservoir Pressure Field Examples Water Injection Well Surveillance Reservoir Conformance Studies Field Example: Combining Waterflood Surveillance Diagnostic Tools Summary Volume II CHAPTER VII COMPLETION AND STIMULATION OPTIMIZATION Introduction Rock Mechanical Properties Study Laboratory Work Correlation of Laboratory-Derived Static and Dynamic Core Rock Properties Correlation with Well Log Data

5 v Page 7.6 Predictive Models for Static Elastic Moduli Well Completion Optimization Hydraulic Fracture Design Optimization CHAPTER VIII DATA INTEGRATION Identification of Interwell Reservoir Quality Trends Identification of Intrawell Reservoir Quality Trends Summary CHAPTER IX 10-ACRE INFILL WELL PERFORMANCE Initial Production Rate Comparison Incremental versus Accelerated Reserves Pressure Transient (Interval) Tests Production and Injection Data Analysis Summary CHAPTER X CONCLUSIONS Geology and Petrophysics Long-Term Production and Injection Data Analysis Reservoir Surveillance Rock Mechanical Properties Prediction Completion and Stimulation Data Integration and 10-Acre Well Performance Future Considerations NOMENCLATURE REFERENCES APPENDIX A CAPILLARY PRESSURE DATA FOR 10-ACRE INFILL WELLS APPENDIX B RELATIVE PERMEABILITY DATA 10-ACRE INFILL WELLS

6 vi Page APPENDIX C COMPUTED AXIAL TOMOGRAPHY SCAN SUMMARY, FORMATION RESISTIVITY, ROCK COMPRESSIBILITY AND MINI-PERMEAMETER DATA FOR 10-ACRE INFILL WELLS C.1 Fracture Detection, Lithologic Characterization and Core Screening of Heterogeneous Carbonate Cores from the North Robertson (Clear Fork) Unit Using X-Ray Computerized Tomography C.2 Formation Resistivity Data C.3 Rock Compressibility Data C.4 Mini-Permeameter Data Volume III APPENDIX D CONVENTIONAL CORE DATA FOR 10-ACRE AND 20-ACRE INFILL WELLS APPENDIX E WELL LOG DATA FOR CORED 10-ACRE AND 20-ACRE INFILL WELLS APPENDIX F CURRENT WATER SALINITIES, CORRELATION COEFFICIENTS FOR WELL LOG PERMEABILITY PREDICTORS, HFU MODEL PROBABILITIES AND NON-PARAMETRIC MODELING RESULTS BY ROCK TYPE F.1 Formation Water Salinities for the NRU (Clear Fork) F.2 Pearson Correlation Coefficients for Permeability Prediction by Rock Type F.3 Determination of Hydraulic Flow Units by Rock Type F.4 Determination of Non-Parametric Model Equations for Permeability Prediction by Rock Type APPENDIX G MATERIAL BALANCE DECLINE TYPE CURVE RELATIONS FOR UNFRACTURED WELLS (RADIAL FLOW CASE) G.1 Derivation of Material Balance Plotting Functions for Production Data G.2 The Arps Empirical Rate Decline Functions

7 vii Page G.3 Procedures for the Analysis of Production Data Using the Fetkovich-McCray Type Curves for Unfractured Wells APPENDIX H MATERIAL BALANCE DECLINE TYPE CURVE RELATIONS FOR THE CASE OF A WELL WITH AN INFINITE-CONDUCTIVITY VERTICAL FRACTURE IN A CIRCULAR BOUNDED RESERVOIR H.1 The Constant Rate Solution for a Well with a Uniform Flux or Infinite-Conductivity Vertical Fracture in a Circular Bounded Reservoir H.2 Plotting Functions for Decline Curve Analysis Using Type Curves for a Well with an Infinite-Conductivity Vertical Fracture H.3 Procedures for the Analysis of Production or Injection Data Using the Fetkovich-McCray Type Curves for Fractured Wells APPENDIX I ESTIMATION OF FLUID PROPERTIES USED FOR ANALYSES OF NRU (CLEAR FORK) PRESSURE TRANSIENT, PRODUCTION AND INJECTION DATA APPENDIX J MATERIAL BALANCE DECLINE TYPE CURVE MATCHES FOR ORIGINAL 40-ACRE PRODUCING WELLS Volume IV APPENDIX K APPENDIX L APPENDIX M MATERIAL BALANCE DECLINE TYPE CURVE MATCHES FOR 20-ACRE INFILL PRODUCING WELLS MATERIAL BALANCE DECLINE TYPE CURVE MATCHES FOR 10-ACRE INFILL PRODUCING WELLS MATERIAL BALANCE DECLINE TYPE CURVE MATCHES FOR WATER INJECTION WELLS Volume V APPENDIX N PRESSURE TRANSIENT ANALYSIS RELATIONS N.1 Semilog Analysis Relations

8 viii Page N.2 Type Curves for an Unfractured Well in a Homogeneous, Infinite- Acting Reservoir with Wellbore Storage and Skin Effects N.3 Type Curves for a Fractured Well with a Finite Conductivity Vertical Fracture in a Homogeneous, Infinite-Acting Reservoir with Wellbore Storage Effects APPENDIX O PRESSURE TRANSIENT TEST DATA O Raw Pressure Buildup Test Data (Acoustic Well Sounder) O Raw Pressure Falloff Test Data (Surface Spider TM Gauge) O and 1996 Raw Pressure Buildup Test Data (Memory Gauge and EM) O Raw Pressure Buildup and Drawdown Test Data (Memory Gauge) O Raw Pressure Buildup Test Data (Memory Gauge and AWS) APPENDIX P PRESSURE TRANSIENT TEST RESULTS P Pressure Buildup (Acoustic Well Sounder) Tests P Pressure Falloff (Surface Spider TM Gauge) Tests P and 1996 Pressure Buildup (Downhole Memory Gauge) Tests P Pressure Drawdown/Buildup Tests on Selected Completion Intervals (10-acre Infill Wells) P Pressure Buildup (Acoustic Well Sounder/Memory Gauge) Tests APPENDIX Q FORMATION TEST DATA FROM 10-ACRE INFILL WELLS APPENDIX R STATIC ELASTIC PROPERTIES FOR SELECTED CORE SAMPLES FROM 10-ACRE INFILL WELLS APPENDIX S DYNAMIC ELASTIC PROPERTIES AND AVERAGED WELL LOG RESPONSES FOR SELECTED CORE SAMPLES FROM 10-ACRE INFILL WELLS

9 ix Page APPENDIX T APPENDIX U APPENDIX V Volume VI GRAPHICAL COMPARISON OF STATIC, DYNAMIC AND FWS-CALCULATED ELASTIC MODULI FOR SELECTED CORE SAMPLES FROM 10-ACRE INFILL WELLS CORRELATION OF WELL LOG RESPONSES WITH LAB-MEASURED STATIC ELATIC MODULI 10-ACRE WELLS COMPARISON OF PREDICITVE MODEL RESULTS WITH LAB-MEASURED AND FWS-CALCULATED ELASTIC MODULI FOR CORED AND NON-CORED 10-ACRE INFILL WELLS V.1 Cored Wells V.2 Non-Cored Wells APPENDIX W PREDICTIVE MODEL AND FWS-CALCULATED IN-SITU STRESS PROFILES FOR 10-ACRE INFILL WELLS VITA

10 x LIST OF FIGURES Volume I FIGURE Page 1.1 Location of North Robertson (Clear Fork) Unit, Permian Basin, West Texas NRU production and injection history Stratigraphic units for the Permian Age on the Central Basin Platform Idealized depositional model for the Clear Fork Formation Permeability-porosity relationship for open marine deposits based on quick plug core data from NRU wells 1509, 1510 and Grainstone shoal with numerous pellets and fossil allochems NRU 3319 (Lower Clear Fork) Permeability-porosity relationship for grainstone shoal deposits from quick plug core data from NRU wells 1509, 1510 and Fusulinid shoal with numerous pellets and fusulinids NRU 1509 (Lower Clear Fork) Intershoal wackestone-packstone with pellets, fossil fragments and varying amounts of carbonate mud NRU 3319 (Lower Clear Fork) Permeability-porosity relationship for intershoal deposits based on quick plug core data from NRU wells 1509, 1510 and Reef with rugose coral (upper left of slab) and dense white bryzoan in near growth position NRU 1509 (Lower Clear Fork) Permeability-porosity relationship for reef center deposits based on quick plug core data from NRU wells 1509, 1510 and Reef talus grainstone with prominent bedding NRU 1510 (Lower Clear Fork) Permeability-porosity relationship for reef talus deposits based on quick plug core data from NRU wells 1509, 1510 and Reef debris apron grainstone with numerous allochems NRU 1510 (Lower Clear Fork) Permeability-porosity relationship for reef debris apron deposits based on quick plug core data from NRU wells 1509, 1510 and

11 xi FIGURE Page 2.15 Permeability-porosity relationship for open lagoon deposits based on quick plug core data from NRU wells 1509, 1510 and Permeability-porosity relationship for restricted lagoon deposits based on quick plug core data from NRU wells 1509, 1510 and Dense and light gray burrowed island center NRU 3319 (Lower Clear Fork) Permeability-porosity relationship for island deposits based on quick plug core data from NRU wells 1509, 1510 and Permeability-porosity relationship for island beach deposits based on quick plug core data from NRU wells 1509, 1510 and Island sequence with carbonaceous unit overlying algal mat NRU 3319 (Lower Clear Fork) Permeability-porosity relationship for tidal flat deposits based on quick plug core data from NRU wells 1509, 1510 and Tidal flat algal mat NRU 3319 (Lower Clear Fork) Tidal channel with burrowed top and abundant carbonaceous plant fragments on top of algal mat NRU 3319 (Lower Clear Fork) Permeability-porosity relationship for tidal flat channel deposits based on quick plug core data from NRU wells 1509, 1510 and Permeability-porosity relationship for shallow sub-tidal deposits based on quick plug core data from NRU wells 1509, 1510 and Supratidal mud cracks and silty dolostone NRU 1509 (Upper Clear Fork) Permeability-porosity relationship for supratidal deposits based on quick plug core data from NRU wells 1509, 1510 and Solution collapse breccia with oil staining outlining broken fragments NRU 3533 (Upper Clear Fork) Permeability-porosity relationship for solution collapse breccia deposits based on quick plug core data from NRU wells 1509, 1510 and Calculation of Brooks and Corey pore distribution factor NRU 3533 (core #15B) and NRU 1510 (core #5D) Type curve for the prediction of absolute permeability from capillary pressure data

12 xii FIGURE Page 3.3 Prediction of air permeability from the Swanson correlating parameter, (S b /p c ) A, SCAL plug trimmed ends Air permeability estimate from data overlay NRU 3533, core sample #15B Air permeability estimate from data overlay NRU 3533, core sample #5B Prediction of air permeability from median pore throat radius, MPTR, SCAL plug trimmed ends Prediction of air permeability from Hagiwara equation SCAL plug trimmed ends Comparison between laboratory-measured k air and type curve-calculated k abs six core samples from four wells Prediction of absolute permeability NRU 1509, core #11A Prediction of absolute permeability NRU 3533, core #15B Prediction of absolute permeability NRU 3319, core #30C CAT scan and spectral display for 2-mm. slice of Upper Clear Fork core sample, NRU MPTR versus gamma ray log MPTR versus compensated neutron log MPTR versus bulk density log MPTR versus photoelectric capture cross-section log MPTR versus deep resistivity log MPTR versus shallow resistivity log Graphical estimation of FZI Volumetric proportions of pore types in each rock type Core porosity versus core permeability for the Clear Fork interval Porosity-permeability relationship for one rock type Differentiating "pay" from "non-pay" reservoir rocks Differentiating "pay" reservoir rocks Differentiating rock types 3 and

13 xiii FIGURE Page 4.14 Whole core k MAX and model calculated permeability versus depth for NRU Whole core k MAX and model calculated permeability versus depth for NRU Comparison of visually determined rock types with model-calculated rock types for SCAL plug clip end samples Relationship between effective air, brine and oil permeabilities from mini-permeameter and native-state, unsteady-state relative permeability data NRU Whole core preparation for NRU infill wells Linear relationship between whole core k 90 and k MAX Dykstra-Parsons coefficient calculation for whole core data Dykstra-Parsons coefficient calculation for quick plug data Frequency histogram for whole core permeability measurements Frequency histogram for quick plug permeability measurements Density-neutron crossplot NRU Density-neutron crossplot NRU Density-neutron crossplot NRU NRU rock typing and pay prediction algorithm Initial lithology determination using bulk density and PE data Differentiating "pay" from "non-pay" rock types Segregating rock types 1 4 using deep resistivity data Segregating rock types 3 and 4 using shallow resistivity data Water salinities (ppm) for Lower Clear Fork (northern infill area) Water salinities (ppm) for Middle Clear Fork (northern infill area) Water salinities (ppm) for Upper Clear Fork (northern infill area) Graphical illustration of cementation factor calculation Whole core k MAX versus compensated neutron porosity Whole core k MAX versus bulk density Whole core k MAX versus deep resistivity

14 xiv FIGURE Page 4.39 Whole core k GEOM and model-calculated permeabilities versus depth for NRU Graphical illustration of HFU determination and assignment of FZI Whole core k GEOM and model-calculated permeabilities versus depth for NRU Whole core k GEOM versus HFU model-calculated permeabilities Optimal transformation of ln(gr) Optimal transformation of ln(lld) Optimal transformation of ln(φ c ) Summation of optimal transforms to predict whole core k GEOM Whole core k GEOM and model-calculated permeabilities versus depth for NRU Whole core k GEOM versus the non-parametric model-calculated permeabilities NMR permeability and FFI data matched with quick plug and whole core permeabilities for NRU Estimation of permeability cutoff for NRU Estimation of porosity cutoff for NRU Relation between unstressed effective air permeability and stressed oil permeability from native-state relative permeability tests Fetkovich q Dd and q Ddd type curves for an unfractured well (radial flow case) centered in a bounded circular reservoir Fetkovich-McCray q Dd, q Ddi and q Ddid type curves for an unfractured well (radial flow case) centered in a bounded circular reservoir Semilog production plot for simulated case #1 (constant p wf ) Log-Log production plot for simulated case #1 (constant p wf ) Rate functions for simulated case #1 (constant p wf ) Estimated movable oil from rate history for simulated case #1 (constant p wf ) Estimated movable oil from pressure drop normalized rate history for simulated case #1 (constant p wf ) Estimated movable oil from p cal for simulated case #1 (constant p wf )

15 xv FIGURE Page 5.9 Match of production data for simulated case #1 (constant p wf ) on the Fetkovich-McCray type curve for an unfractured well centered in a bounded circular reservoir Semilog production plot for simulated case #2 (variable p wf ) Log-Log production plot for simulated case #2 (variable p wf ) Rate functions for simulated case #2 (variable p wf ) Estimated movable oil from rate history for simulated case #2 (variable p wf ) Estimated movable oil from pressure drop normalized rate history for simulated case #2 (variable p wf ) Estimated movable oil from p cal for simulated case #2 (variable p wf ) Match of production data for simulated case #2 (variable p wf with shut-ins) on the Fetkovich-McCray type curve for an unfractured well in a bounded circular reservoir North Robertson (Clear Fork) Unit, Gaines County, Texas Producing bottomhole pressures for 10-acre infill wells Location of NRU Semilog production plot for NRU Log-Log production plot for NRU Match of production data for NRU 4202 on the Fetkovich-McCray type curve for an unfractured well in a bounded circular reservoir Estimated movable oil from rate history for NRU Location of NRU Semilog production plot for NRU Log-Log production plot for NRU Match of production data for NRU 1004 on the Fetkovich-McCray type curve for an unfractured well in a bounded circular reservoir Estimated movable oil from rate history for NRU Cartesian plot of p D versus t DA solutions with pseudosteady-state solutions superimposed for the infinite-conductivity fracture case

16 xvi FIGURE Page 5.30 Correlation of b Dpss and r ed values for fractured well solutions infinite-conductivity fracture case q Dd versus t Dd for infinite-conductivity fracture case (establishes "Fetkovich" type curve plotting functions for fractured wells) Fetkovich-McCray q Dd, q Ddi and q Ddid type curves for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Match of production data for NRU 4202 on the Fetkovich-McCray type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Final data match on log-log plot for NRU 4202 pressure buildup test data (Nov. 1988) Location of NRU Semilog production plot for NRU Log-Log production plot for NRU Match of production data for NRU 102 on the Fetkovich-McCray type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Estimated movable oil from rate history for NRU Semilog rate and Cartesian injection pressure versus time for NRU 102(WI) Match of injection data for NRU 102(WI) on the type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Estimated injectable water from a plot of pressure drop normalized injection rate versus cumulative injection for NRU 102(WI) Location of NRU Semilog production plot for NRU Log-Log production plot for NRU Match of production data for NRU 301 on the Fetkovich-McCray type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Estimated movable oil from rate history for NRU

17 xvii FIGURE Page 5.48 Semilog rate and Cartesian injection pressure versus time for NRU 301(WI) Pre-workover match of injection data for NRU 301(WI) on the Fetkovich-McCray type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Estimated injectable water from a plot of pressure drop normalized injection rate versus cumulative injection for NRU 301(WI) Post-workover match of injection data for NRU 301(WI) on the Fetkovich-McCray type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Downhole configuration for majority of NRU pressure buildup and pressure drawdown tests ( ) "Pressure" type curve for an unfractured well in an infinite-acting homogeneous reservoir "Pressure-Integral" type curve for an unfractured well in an infinite-acting homogeneous reservoir "Pressure" type curve for a well with a finite conductivity vertical fracture in an infinite-acting homogeneous reservoir "Pressure-Integral" type curve for a well with a finite conductivity vertical fracture in an infinite-acting homogeneous reservoir Preliminary type curve match for NRU 2703 pressure buildup test data for a well with a finite conductivity vertical fracture in an infinite-acting homogeneous reservoir Estimated bottomhole pressure using the RHM method Final data match on log-log plot for NRU 2703 pressure buildup test data (Dec. 1995) average reservoir pressure map Location of NRU Semilog analysis for NRU 905 pressure buildup test data Preliminary log-log results for NRU 905 pressure buildup test data Preliminary log-log results for NRU 905 pressure buildup test data Final data match on log-log plot for NRU 905 pressure buildup test data (June 1995)

18 xviii FIGURE Page 6.15 Location of NRU NRU 207 wellbore schematic and completion history Comparison of raw AWS and bottomhole memory gauge pressure buildup data for NRU Preliminary results for NRU 207 smoothed AWS pressure buildup test data Preliminary results for NRU 207 memory gauge pressure buildup test data Final data match on log-log plot for NRU 207 pressure buildup test data (Jan. 1997) Average reservoir pressure estimates for raw AWS and bottom hole memory gauge pressure buildup data for NRU 207 using the equation for a rectangular hyperbola (RHM) Fetkovich-McCray type curves for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Match of production data for NRU 3510 on the Fetkovich-McCray type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Final data match on log-log plot for NRU 3510 AWS pressure buildup test data (Nov. 1988) Match of water injection data for NRU 3510 on the Fetkovich-McCray type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Final data match on log-log plot for NRU 3510(WI) pressure falloff test data (Aug. 1994) Map of propagated fracture half-lengths from long-term injection data analyses Hall diagnostic plot Hall plot for NRU 403(WI) indicating pore plugging and possible fracture propagation Individual well and average reservoir parting pressure trends from step-rate tests performed at the NRU Waterflood recovery mechanisms Location of NRU

19 xix FIGURE Page injection and temperature profiles for NRU 1601(WI) injection and temperature profiles for NRU 2901(WI) Comparison of original open-hole and 1995 TND water saturations for NRU Estimated ultimate recovery for NRU Estimated ultimate recovery for NRU Estimated ultimate recovery for NRU Location of NRU Comparison of original open-hole and 1997 TND water saturations for the Upper Clear Fork NRU Comparison of original open-hole and 1997 TND water saturations for the Middle Clear Fork NRU Comparison of original open-hole and 1997 TND water saturations for the Lower Clear Fork NRU injection and temperature profiles for NRU 3511(WI) injection and temperature profiles for NRU 3516(WI) Idealized vertical pressure profiles for homogenous and heterogeneous reservoirs FT vertical pressure profiles for NRU 3532, 3533 and 3534 located in Section 329 (northern infill area) of the NRU Location of survey wells NRU 505, 1509 and 2705 in Section FT vertical pressure profiles for NRU 505, 1509 and 2705 located in Section 327 (southern infill area) of the NRU injection and temperature profiles for NRU 1591(WI) injection and temperature profiles for NRU 3004(WI) Comparison of original open-hole and 1997 TND water saturations for the Lower Clear Fork NRU NRU pore pressure gradient estimate from FT pressure data on seven unit wells in Sections 327, 329 and Qualitative indication of injection support, continuity and reservoir quality from raw pressure-time data Location of wells NRU 301(WI) and NRU 2601(WI)

20 xx FIGURE Page 6.55 Data match on semilog plot for NRU 301(WI) pressure falloff test data (Aug. 1994) Final data match on log-log plot for NRU 301(WI) pressure falloff test data (Aug. 1994) Hall plot for NRU 301(WI) Injection rate and bottomhole injection pressure for NRU 301(WI) Plot of injectivity factor (pressure drop normalized rate) versus cumulative water injected for NRU 301(WI) Match of pre-workover injection data for NRU 301(WI) on the type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Match of post-workover injection data for NRU 301(WI) on the type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir Hall plot for NRU 2601(WI) injection and temperature profiles for NRU 2601(WI) Injection rate and bottomhole injection pressure for NRU 2601(WI) Plot of injectivity factor (pressure drop normalized rate) versus cumulative water injected for NRU 2601(WI) Match of injection data for NRU 2601 (WI) on the type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir (prior to NRU 301 workover) Semilog plot of injection rates for communicating wells Cartesian plot of bottomhole injection pressures for communicating wells Hall plot for NRU 3004(WI) Final data match on log-log plot for NRU 3004(WI) pressure falloff test data (Aug. 1994) Match of injection data for NRU 3004(WI) on the type curve for a well with an infinite-conductivity fracture centered in a bounded circular reservoir

21 xxi FIGURE Page Volume II 7.1 Static Young's modulus versus confining pressure sample 1A Dynamic Poisson ratio versus net axial stress sample 20C Dynamic Poisson ratio versus confining pressure sample 34B Static E versus dynamic E for stress-unloading sequences on saturated core samples Static ν versus dynamic ν for stress-unloading sequences on saturated core samples Comparison of laboratory and well log compressional travel times for depth correlation Comparison of laboratory and well log shear travel times for depth correlation Laboratory measured static E versus FWS-calculated dynamic E Laboratory measured dynamic E versus FWS-calculated dynamic E Laboratory measured static ν versus FWS-calculated dynamic ν Laboratory measured dynamic ν versus FWS-calculated dynamic ν Laboratory measured static E versus gamma ray log response Laboratory measured static E versus bulk density log response Laboratory measured static E versus PE log response Laboratory measured static E versus compressional t log response Laboratory measured static E versus shear t log response Comparison of full and reduced non-parametric predictive models to illustrate data "over-fit." Optimal transformation of ln(φ N ) Optimal transformation of ln(pe) Optimal transformation of ln(ρ b ) Summation of optimal transforms to predict Young's modulus, E Comparison of model-predicted static E with lab-derived (core) static E and FWS-calculated dynamic E for NRU 1509 (LCF)

22 xxii FIGURE 7.23 Optimal transformation of ln( t c ) Optimal transformation of ln(gr) Optimal transformation of ln(φ N ) Optimal transformation of ln(ρ b ) Summation of optimal transforms to predict Poisson ratio, ν Page 7.28 Comparison of predicted static ν with lab-derived (core) static ν and FWS-calculated dynamic ν Calculated in-situ stress profile for NRU Typical hydraulic fracturing scenario for limited-entry perforating Typical hydraulic fracturing scenario when cluster perforating only the highest reservoir quality section of the completion interval Determination of optimal dimensionless fracture conductivity Comparison of one-year oil rate profiles for recently completed 10-acre infill wells Incremental cumulative oil production attributable to CO 2 fracs over a two-year production period Closure stress calculation for NRU 1510(WI) Upper Clear Fork Net pressure profile for NRU 1510(WI) Upper Clear Fork Closure stress calculation for NRU 3532 Middle Clear Fork Net pressure profile for NRU 3532 Middle Clear Fork Closure stress calculation for NRU 2705 Lower Clear Fork Net pressure profile for NRU 2705 Lower Clear Fork Estimated oil flow capacity, k o h, calculated from core-log model for the NRU 10- and 20-acre infill wells Estimated net hydrocarbon-feet, φhs o, calculated from core-log model for the NRU 10- and 20-acre infill wells "Contacted" original oil-in-place calculated from decline type curve analyses on the NRU original 40-acre development wells Estimated ultimate recovery calculated from the NRU original 40-acre development wells

23 xxiii FIGURE Page 8.5 Estimated oil flow capacity, k o h, calculated from decline type curve analyses on the NRU original 40-acre development wells Estimated ultimate recovery calculated from the NRU 20-acre infill wells Estimated oil flow capacity, k o h, calculated from decline type curve analyses on the NRU 20-acre infill wells estimated average reservoir pressure from pressure transient tests estimated average reservoir pressure from pressure transient tests Idealized illustration of Clear Fork depositional environment Correlation between infill well EUR and core-log model predicted net pay thickness Correlation between infill well EUR and core-log model predicted hydrocarbon pore volume Correlation between infill well EUR and core-log model predicted oil flow capacity Correlation between infill well EUR and core-log model predicted rock type 6 (anhydritic dolomite) Predictive equation for EUR using core-log model outputs as predictor variables 10-acre infill wells Predictive equation for EUR using core-log model outputs as predictor variables 20-acre infill wells Predictive equation for EUR using core-log model outputs as predictor variables 10-acre and 20-acre infill wells Comparison between model-predicted EUR and actual EUR for 10-acre infill wells Initial 10-acre infill drilling locations ( ) Unit oil rate increase attributable to initial 10-acre infill wells First year initial oil rates for 40-, 20- and 10-acre wells in the northern infill area First year initial oil rates for 40-, 20- and 10-acre wells in the southern infill area

24 xxiv FIGURE Page 9.5 Production interference effect caused by NRU 3604 infill well Final data match on log-log plot for NRU 3532 (Middle Clear Fork) pressure drawdown test data (May 1996) Initial rate profile for NRU Production interference effect due to addition of NRU Initial rate profile for NRU Production interference effect due to addition of NRU Initial rate profile for NRU Production interference effect due to addition of NRU Initial rate profile for NRU Initial rate profile for NRU Initial rate profile for NRU Initial rate profile for NRU Initial rate profile for NRU Initial rate profile for NRU Production interference effect due to addition of NRU Initial rate profile for NRU Initial rate profile for NRU Production interference effect due to addition of NRU Initial rate profile for NRU Initial rate profile for NRU Production interference effect due to addition of NRU Initial rate profile for NRU Production interference effect due to addition of NRU Injection interference effect due to addition of NRU 1510(WI) Injection interference effect due to addition of NRU 1512(WI) Injection interference effect due to addition of NRU 3536(WI) Injection interference effect due to addition of NRU 3539(WI) Relationship between IP and EUR for 10-acre infill wells

25 xxv LIST OF TABLES Volume I TABLE Page 1.1 NRU cumulative production and injection Classification of carbonate porosity Special core analysis (SCAL) database Comparison between lab data and type curve match results SCAL plug trim ends: air permeability and MPTR statistics SCAL plug trim ends segregated by rock type: air permeability and median pore throat radii statistics Use of well log responses to describe rock characteristics Relationship between well log response and permeability Conventional core database Well log database Pore type and classification at the NRU Capillary characteristics by rock type based on mercury injection Porosity, permeability and lithology by rock type Statistics for all core permeability data Statistics for whole core permeability (k GEOM ) data by rock type Pearson correlation coefficients for statistically significant predictor variables for whole core k 90 RT2 (77 sample measurements) Determination of flow units using ln (FZI) for rock type HFU probability for a given range of deep resistivity rock type Summary of non-parametric modeling results by rock type Summary of modeling results for 10-acre infill wells Summary of modeling results for 20-acre infill wells Rate and pressure histories for two simulated data cases Correlative values of b Dpss and r ed for a fractured well in a bounded circular reservoir (infinite-conductivity vertical fracture case) NRU shut-in bottomhole pressure estimates ( )

26 xxvi TABLE Page 6.2 Summary of results for well NRU Volume II 7.1 NRU core samples chosen for rock mechanical property study Summary of dynamic and static moduli for stress-unloading condition on saturated cores Depth-averaged well log data for sample 1A Results for 10-acre infill well core-log modeling Results for 10-acre infill well decline type curve analyses Results for 20-acre infill well core-log modeling Results for 20-acre infill well decline type curve analyses Relative production contribution of individual Clear Fork intervals Material balance decline type curve analysis results for 10-acre infill wells

27 1641 APPENDIX T GRAPHICAL COMPARISON OF STATIC, DYNAMIC AND FWS- CALCULATED ELASTIC MODULI FOR SELECTED CORE SAMPLES FROM 10-ACRE INFILL WELLS Figure T.1 Young's modulus for core sample #1A dry state. Figure T.2 Poisson ratio for core sample #1A dry state.

28 1642 Figure T.3 Young's modulus for core sample #1A saturated state. Figure T.4 Poisson ratio for core sample #1A saturated state.

29 1643 Figure T.5 Young's modulus for core sample #3D dry state. Figure T.6 Poisson ratio for core sample #3D dry state.

30 1644 Figure T.7 Young's modulus for core sample #3D saturated state. Figure T.8 Poisson ratio for core sample #3D saturated state.

31 1645 Figure T.9 Young's modulus for core sample #5A dry state. Figure T.10 Poisson ratio for core sample #5A dry state.

32 1646 Figure T.11 Young's modulus for core sample #5A saturated state. Figure T.12 Poisson ratio for core sample #5A saturated state.

33 1647 Figure T.13 Young's modulus for core sample #9D dry state. Figure T.14 Poisson ratio for core sample #9D dry state.

34 1648 Figure T.15 Young's modulus for core sample #9D saturated state. Figure T.16 Poisson ratio for core sample #9D saturated state.

35 1649 Figure T.17 Young's modulus for core sample #18B dry state. Figure T.18 Poisson ratio for core sample #18B dry state.

36 1650 Figure T.19 Young's modulus for core sample #18B saturated state. Figure T.20 Poisson ratio for core sample #18B saturated state.

37 1651 Figure T.21 Young's modulus for core sample #19A dry state. Figure T.22 Poisson ratio for core sample #19A dry state.

38 1652 Figure T.23 Young's modulus for core sample #19A saturated state. Figure T.24 Poisson ratio for core sample #19A saturated state.

39 1653 Figure T.25 Young's modulus for core sample #20C dry state. Figure T.26 Poisson ratio for core sample #20C dry state.

40 1654 Figure T.27 Young's modulus for core sample #20C saturated state. Figure T.28 Poisson ratio for core sample #20C saturated state.

41 1655 Figure T.29 Young's modulus for core sample #22B dry state. Figure T.30 Poisson ratio for core sample #22B dry state.

42 1656 Figure T.31 Young's modulus for core sample #22B saturated state. Figure T.32 Poisson ratio for core sample #22B saturated state.

43 1657 Figure T.33 Young's modulus for core sample #24B dry state. Figure T.34 Poisson ratio for core sample #24B dry state.

44 1658 Figure T.35 Young's modulus for core sample #24B saturated state. Figure T.36 Poisson ratio for core sample #24B saturated state.

45 1659 Figure T.37 Young's modulus for core sample #27A dry state. Figure T.38 Poisson ratio for core sample #27A dry state.

46 1660 Figure T.39 Young's modulus for core sample #27A saturated state. Figure T.40 Poisson ratio for core sample #27A saturated state.

47 1661 Figure T.41 Young's modulus for core sample #30B dry state. Figure T.42 Poisson ratio for core sample #30B dry state.

48 1662 Figure T.43 Young's modulus for core sample #30B saturated state. Figure T.44 Poisson ratio for core sample #30B saturated state.

49 1663 Figure T.45 Young's modulus for core sample #34B dry state. Figure T.46 Poisson ratio for core sample #34B dry state.

50 1664 Figure T.47 Young's modulus for core sample #34B saturated state. Figure T.48 Poisson ratio for core sample #34B saturated state.

51 1665 Figure T.49 Young's modulus for core sample #36A dry state. Figure T.50 Poisson ratio for core sample #36A dry state.

52 1666 Figure T.51 Young's modulus for core sample #36A saturated state. Figure T.52 Poisson ratio for core sample #36A saturated state.

53 1667 Figure T.53 Young's modulus for core sample #41C dry state. Figure T.54 Poisson ratio for core sample #41C dry state.

54 1668 Figure T.55 Young's modulus for core sample #41C saturated state. Figure T.56 Poisson ratio for core sample #41C saturated state.

55 1669 APPENDIX U CORRELATION OF WELL LOG RESPONSES WITH LAB- MEASURED STATIC ELASTIC MODULI 10-ACRE WELLS Figure U.1 Correlation of lab-measured static Young's modulus with the Gamma Ray Log 16 core samples. Figure U.2 Correlation of lab-measured static Young's modulus with the Bulk Density Log 16 core samples.

56 1670 Figure U.3 Correlation of lab-measured static Young's modulus with the Compensated Neutron φ Log 16 core samples. Figure U.4 Correlation of lab-measured static Young's modulus with the PE Log 16 core samples.

57 1671 Figure U.5 Correlation of lab-measured static Young's modulus with the t c Log 16 core samples. Figure U.6 Correlation of lab-measured static Young's modulus with the t s Log 16 core samples.

58 1672 Figure U.7 Correlation of lab-measured static Young's modulus with deep resistivity from the Laterolog 16 core samples. Figure U.8 Correlation of lab-measured static Poisson ratio with the Gamma Ray Log 16 core samples.

59 1673 Figure U.9 Correlation of lab-measured static Poisson ratio with the Bulk Density Log 16 core samples. Figure U.10 Correlation of lab-measured static Poisson ratio with the Compensated Neutron φ Log 16 core samples.

60 1674 Figure U.11 Correlation of lab-measured static Poisson ratio with the PE Log 16 core samples. Figure U.12 Correlation of lab-measured static Poisson ratio with the t c Log 16 core samples.

61 1675 Figure U.13 Correlation of lab-measured static Poisson ratio with the t s Log 16 core samples. Figure U.14 Correlation of lab-measured static Poisson ratio with deep resistivity from the Laterolog 16 core samples.

62 1676 APPENDIX V COMPARISON OF PREDICTIVE MODEL RESULTS WITH LAB- MEASURED AND FWS-CALCULATED ELASTIC MODULI FOR CORED AND NON-CORED 10-ACRE INFILL WELLS V.1 Cored Wells Figure V.1.1 Comparison of Young's modulus data for NRU 1509 (UCF).

63 1677 Figure V.1.2 Comparison of Poisson ratio data for NRU 1509 (UCF). Figure V.1.3 Comparison of Young's modulus data for NRU 1509 (LCF).

64 1678 Figure V.1.4 Comparison of Poisson ratio data for NRU 1509 (LCF). Figure V.1.5 Comparison of Young's modulus data for NRU 1510 (MCF).

65 1679 Figure V.1.6 Comparison of Poisson ratio data for NRU 1510 (MCF). Figure V.1.7 Comparison of Young's modulus data for NRU 1510 (LCF).

66 1680 Figure V.1.8 Comparison of Poisson ratio data for NRU 1510 (LCF). Figure V.1.9 Comparison of Young's modulus data for NRU 3319 (LCF).

67 1681 Figure V.1.10 Comparison of Poisson ratio data for NRU 3319 (LCF). Figure V.1.11 Comparison of Young's modulus data for NRU 3533 (UCF).

68 1682 Figure V.1.12 Comparison of Poisson ratio data for NRU 3533 (UCF). Figure V.1.13 Comparison of Young's modulus data for NRU 3533 (MCF).

69 1683 Figure V.1.14 Comparison of Poisson ratio data for NRU 3533 (MCF). Figure V.1.15 Comparison of Young's modulus data for NRU 3533 (LCF).

70 Figure V.1.16 Comparison of Poisson ratio data for NRU 3533 (LCF). 1684

71 1685 V.2 Non-Cored Wells Figure V.2.1 Comparison of Young's modulus data for NRU Figure V.2.2 Comparison of Poisson ratio data for NRU 1511.

72 1686 Figure V.2.3 Comparison of Young's modulus data for NRU 1512(WI). Figure V.2.4 Comparison of Poisson ratio data for NRU 1512(WI).

73 1687 Figure V.2.5 Comparison of Young's modulus data for NRU Figure V.2.6 Comparison of Poisson ratio data for NRU 3018.

74 1688 Figure V.2.7 Comparison of Young's modulus data for NRU 3536(WI). Figure V.2.8 Comparison of Poisson ratio data for NRU 3536(WI).

75 1689 Figure V.2.9 Comparison of Young's modulus data for NRU Figure V.2.10 Comparison of Poisson ratio data for NRU 3538.

76 1690 Figure V.2.11 Comparison of Young's modulus data for NRU Figure V.2.12 Comparison of Poisson ratio data for NRU 3539.

77 1691 Figure V.2.13 Comparison of Young's modulus data for NRU Figure V.2.14 Comparison of Poisson ratio data for NRU 3604.

78 1692 APPENDIX W PREDICTIVE MODEL AND FWS-CALCULATED IN-SITU STRESS PROFILES FOR 10-ACRE INFILL WELLS Figure W.1 Calculated in-situ stress profile for NRU 1509.

79 1693 Figure W.2 Calculated in-situ stress profile for NRU 1510(WI). Figure W.3 Calculated in-situ stress profile for NRU 1511.

80 1694 Figure W.4 Calculated in-situ stress profile for NRU 1512(WI). Figure W.5 Calculated in-situ stress profile for NRU 3018.

81 1695 Figure W.6 Calculated in-situ stress profile for NRU Figure W.7 Calculated in-situ stress profile for NRU 3533.

82 1696 Figure W.8 Calculated in-situ stress profile for NRU 3536(WI). Figure W.9 Calculated in-situ stress profile for NRU 3538.

83 1697 Figure W.10 Calculated in-situ stress profile for NRU 3539(WI). Figure W.11 Calculated in-situ stress profile for NRU 3604.

84 1698 VITA Name: Born: Permanent Address: Louis Edward Doublet Quantico, Virginia Bending Birch Court Cypress, TX USA Education: B.S., Mechanical Engineering, 1981 Georgia Institute of Technology Atlanta, Georgia M.S., Petroleum Engineering, 1988 Texas A&M University College Station, Texas Professional Experience: Dresser Atlas Oilfield Services Field Engineer, Marathon Oil Company Assoc. Petroleum Engineer, Halliburton Energy Services Field Engineer, Texas A&M University Asst. Research Engineer, Asst. Lecturer, 1998 Gaither Petroleum Corporation Reservoir Engineer, 1999 present