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IPTC 18916 presentation slides (technical session 11)
- 1. IPTC-18916-MS Evaluation of MultistageHydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model Theerapat Suppachoknirun, PTT Exploration and Production Plc. Dr. Azra N. Tutuncu and Dr. Hossein Kazemi, Colorado School of Mines
- 2. Introduction & Goal Slide2 IPTC-18916-MS • Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Fracturing Patterns to Optimize Production − Conventional − Zipper − Texas Two-step (Alternating Pattern) Optimum Option for Naturally Fractured Shale Reservoir … ? 1 2 3 ** Model to accurately represent fracture network is indispensable 12 3
- 3. Presentation Outline Slide 3 IPTC-18916-MS• Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun • Challenges - Approaches • Model (Field Case) Development and Validation • Evaluation of 3 Fracturing Patterns in Multiple-Horizontal-Well Pad − Fracture geometry, Conductivity − Production performance, SRV − Individual well performance • Summary
- 4. Challenges and Approaches Slide4 IPTC-18916-MS • Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun • Modeling of Complex Fracture Network − Stress shadow effect − Fluid and proppant transport − Fracture propagation mechanics − Various modes of HF – NF interactions • Model for Production Performance Prediction − “Geomechanics-incorporated fracture model” integrated in production grid • Attainable and Reliable Based on the “Available Data”
- 5. Workflow Slide 5 IPTC-18916-MS •Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Integrated Fracture and Fluid Flow Model Field Production Data History Matching Field Microseismic Fracture Mapping Evaluation of Multistage Fracturing Techniques Conventional Consecutive Sequence Zipper Fracturing Pattern Alternating Fracturing Pattern Modeling and Validating Using Field Data Phase I Hydraulic Fracturing Job data Reservoir Rock & Geomechanical Properties Pre-existing DFN (Upscaled characteristics) Representative DataAvailable Data Hydraulic Fracturing Job data Reservoir Rock & Geomechanical Properties (Directed & Derived measurement, and Correlation) Pre-existing DFN (Available information)
- 6. Workflow Slide 6 IPTC-18916-MS •Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Integrated Fracture and Fluid Flow Model Field Production Data History Matching Field Microseismic Fracture Mapping Evaluation of Multistage Fracturing Techniques Conventional Consecutive Sequence Zipper Fracturing Pattern Alternating Fracturing Pattern Modeling and Validating Using Field Data Hydraulic Fracturing Job data Reservoir Rock & Geomechanical Properties Pre-existing DFN (Upscaled characteristics) Available Data Hydraulic Fracturing Job data Reservoir Rock & Geomechanical Properties (Directed & Derived measurement, and Correlation) Pre-existing DFN (Available information) Phase II (This Work) Representative Data
- 7. Model Development (FieldData) Slide 7 IPTC-18916-MS • Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Well T-1: 14 stages Well T-3: 13 stages Well T-5: 14 stages N Simulated Fracture Network Production Simulation Grid Multistage Hydraulically Fractured Multiple- Horizontal-Well Pad in the Eagle Ford Oil Window
- 8. Model Validation: FieldData Matching Slide 8 IPTC-18916-MS • Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Microseismic Fracture Mapping • Vertical containment • Geometry, Half-length, SRA • Fracture orientations T-1 T-3 T-5
- 9. Model Validation: FieldData Matching (cont.) Slide 9 IPTC-18916-MS • Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Production History 0 500 1,000 1,500 2,000 2,500 3,000 0 3 6 9 12 15 18 Rate(STB/D) Time (Month) Production Rate (Field Data) Simulated Oil Production Rate 0 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000 4,500 0 3 6 9 12 15 18 Rate(MSCF/D) Time (Month) Production Rate (Field Data) Simulated Gas Production Rate Oil Production Rate (Monthly Average) Gas Production Rate (Monthly Average)
- 10. Simulation Case Study Slide10 IPTC-18916-MS • Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun • 3 Cases Utilizing : CON, ZIP, or ALT Sequences • Based on the Pad Configuration & Reservoir Data • Approx. Treatment Size per Stage – 40/70, 30/50, 20/40 proppants; 360 klb total mass – 1.0 – 3.5 ppa Conc., 60 bpm inj. Rate – 23% pad volume; 5,900 bbl total slurry
- 11. Pressure Distribution Producing over20-Year Simulated Period Slide 11 IPTC-18916-MS • Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Conventional Zipper Alternating (**Top view at perforating depth)
- 12. Fracture Conductivity Slide 12 IPTC-18916-MS• Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun CON. ZIP. ALT. (After 1 Year) Impacts of Fracturing Pattern on Fracture Conductivity - Implied by difference in pressure change
- 13. Stimulated Reservoir Area Slide13 IPTC-18916-MS • Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Estimation of Stimulated Reservoir Area (SRA) - Area experiencing pressure drop more than a specific value (ΔPdrop) over 20-years simulated production time Conventional + 6 %“Base Case” - 1 % Zipper Alternating
- 14. IPTC-18916-MS • Evaluationof Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Simulated Prod. Results & Comparison Slide 14 Overall Oil Production Rate • Oil rate drop drastically regardless of implemented patterns Oil Rate Comparison (Consecutive, Zipper, and Alternating) • CON: Lowest production performance • ZIP : Slowest drop; best late-time rate • ALT : Greatest initial rate, but drop faster the ZIP
- 15. Simulated Prod. Results& Comparison (cont.) • Late-time Relative Rate Gain % - ZIP. : increase with time - ALT. : decrease with time • At 20-Year Simulated Prod. Slide 15 IPTC-18916-MS • Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Oil Production Rate Gain (i.e., % above the base case) CON. ZIP. ALT. N/A (Base) +10 % +2 %
- 16. Simulated Prod. Results& Comparison (cont.) • Relative Oil Volume Gain % - ZIP. : increase with time - ALT. : decrease with time • After 20-Year Simulated Prod. Slide 16 IPTC-18916-MS • Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Cumulative Oil Production Gain CON. ZIP. ALT. N/A (Base) +6 % +11 %
- 17. Recommendation Slide 17 IPTC-18916-MS •Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Recommended Fracturing Technique CON. ZIP. ALT. Production Rate & Cumulative Volume Field Applicability & Complexity Time and Cost Optimization
- 18. Individual Well Performance(Zipper Case) Slide 18 IPTC-18916-MS • Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun Portion Produced by an Individual Well = 𝐎𝐢𝐥 𝐑𝐚𝐭𝐞 𝒐𝒓 𝐕𝐨𝐥𝐮𝐦𝐞 (𝐈𝐧𝐝𝐢𝐯𝐢𝐝𝐮𝐚𝐥 𝐖𝐞𝐥𝐥) 𝐎𝐢𝐥 𝐑𝐚𝐭𝐞 𝒐𝒓 𝐕𝐨𝐥𝐮𝐦𝐞 (𝐖𝐞𝐥𝐥 𝐏𝐚𝐝) × 𝟏𝟎𝟎 % ** Producing at Constant FBHP % of Pad Production Some Contributing Factors: − Well spacing, − Fracture geometry & conductivity − Connectivity to a well, − Formation heterogeneity More improvement possible?
- 19. Summary Slide 19 IPTC-18916-MS •Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun • Approach and Workflow to Develop “A Representative Model” • Impacts of MS Fracturing Patterns on : - Fracture Geometry, Fracture Conductivity, SRV • Production Characteristics in Relative Comparison - Improve production by using ALT. or ZIPPER - Gain % as a function of Time : Time ↑ - ZIPPER Gain % ↑ - ALT. Gain % ↓
- 20. Summary (Cont.) Slide 20 IPTC-18916-MS• Evaluation of Multistage Hydraulic Fracturing Techniques for Production Optimization in Naturally Fractured Reservoirs Using Coupled Geomechanics Fracture and Flow Model • Theerapat Suppachoknirun • “Zipper” Sequence Preferable • Individual Well Performance in Multiple-Horizontal-Well Layout − Influenced by: Well spacing, Fracture geometry & Conductivity, Connectivity to a well, and Formation heterogeneity; − Predictable after an initial period Strategy for production optimization could be more effective More optimal solution for 3-parallel wells using Zipper patterns
- 21. Acknowledgements PTT Explorationand Production Plc. (PTTEP) Unconventional Natural Gas and Oil Institute (UNGI); and Coupled Integrated Multiscale Measurements and Modeling (CIMMM) Consortium Colorado School of Mines Slide 21 Thank You . . . Q & A