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Identifying By-passed Pay and New Reservoirs by Jeff Bayless of Nutech

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SIPES Houston: 2015 Continuing Education Seminar

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Identifying By-passed Pay and New Reservoirs by Jeff Bayless of Nutech

  1. 1. Identifying By-Passed Pay and New Reservoirs Using Rock Texture Petrophysics Integrated with 3D Geologic Modeling Offshore Gulf of Mexico New Wells and Thin Bed Process Update
  2. 2. Presentation Outline Thin Bed Well Log Analysis Structure Modeling Facies Modeling Petrophysical Modeling Volumetric Summary Conclusions and Recommendations
  3. 3. Summary Objectives • Previous traditional models underestimated OIP • Run Thin Bed Process for higher resolution characterization • Build a 3D geological model and distribute facies and petrophysical properties • Update Original Oil in Place • Recommend new drilling opportunities and bypassed pay recompletions Inputs • 28 wells, directional surveys, wireline logs • Well formation tops • Interpreted structure maps • Seismic amplitude • Geologic depositional model • Well completion and production history Petrophysical Overview • Wells were analyzed using the comprehensive modeling process for Thin Bed environments • All data was incorporated into the 3D reservoir modeling process Geological Observations • The depositional system characterized as a fluvial deltaic system with channel and lobe deposits • Reservoir trapping appears to be primarily structural with possible stratigraphic elements
  4. 4. Thin Bed Analysis
  5. 5. Thin Bed Analysis • Ability to get high resolution results from conventional data • Higher resolution answers from old log data • Important for highly laminated and low contrast intervals FEATURES • Better net-to-gross determination • Better determination of hydrocarbons in place • Better perm determination • High resolution analysis BENEFITS
  6. 6. Input Data Requirements Minimum requirement • Resistivity/SP (best results occur when triple combo data is available) • One high resolution device (i.e. shallow resistivity or some device that indicates laminations)
  7. 7. How Thin Bed Analysis Works • Utilizes second derivative to determine inflection points along log • Adjustable for given area, like multi-layer simulator • Corrects RT, Density, GR and Neutron for thin beds
  8. 8. Thin Bed Output to Textural Based Processing hydrocarbon mobile water capillary bound water clay bound water PHIE PHIT FFIBVICBW NMR T2 CLAY BOUND WATER CAPILLARY BOUND WATER MEDIUM GRAINED PORES COURSE GRAINED PORES BIN1 BIN2 BIN3 BIN4 NTV Pore Size PHIE PHIT
  9. 9. Gulf of Mexico Example
  10. 10. Gulf of Mexico Example - Thin Bed Analysis 14 MMCFPD w/ 1200 bbls condensate
  11. 11. Gulf of Mexico Turbidite
  12. 12. Gulf of Mexico Turbidite – Thin Bed Analysis 6 MMCFPD 15 MMCFPD
  13. 13. Geological Application 3D reservoir modeling with higher resolution property models, improved reservoir characterization and more accurate volumetric calculations
  14. 14. Structure Model
  15. 15. Original Client Data A-10 A-13 A-10 A-13 Structure Base Map
  16. 16. Mean Sea Level & 6000’ Structure
  17. 17. 6000’ Structure Top Fault Block C
  18. 18. 6000’ Structure Top Fault “T” Fault “R”
  19. 19. Wells and Cross-Section Lines A A’ B B’
  20. 20. Well Section A-A’ A A’ A A’ B B’
  21. 21. Well Section B-B’ B B’ A A’ B B’
  22. 22. 3D Structure Model
  23. 23. Facies and Petrophysical Modeling
  24. 24. Conceptual Model - Fluvial Deltaic System Delta Channels Shale/Non Reservoir
  25. 25. Seismic Amplitude
  26. 26. Facies Model - Fluvial Deltaic System Coalescing Deltaic Channel BodiesShale/Non Reservoir Delta Lobes Deltaic Channels
  27. 27. Net to Gross 6000’ Zone 6050’ Zone
  28. 28. Effective Porosity Zone Average 6000’ Zone 6050’ Zone
  29. 29. Permeability Zone Average 6000’ Zone 6050’ Zone
  30. 30. STOIIP Zone Sum (STB/AC) - contact @ 6400’ 6000’ Zone 6050’ Zone
  31. 31. Reservoir Modeling Results
  32. 32. Volumetric Summary Reservoir Volumetric Summary (Oil/Wtr Contact at 6350’) Source: NuView Reservoir Model Reservoir Bulk (rb) Net (rb) Pore (rb) HCPV (rb) STOIIP (bbl) Assoc. Gas (mcf) 6000 189,729,115 189,729,115 44,872,606 26,176,740 22,183,678 8,429,189 6050 113,871,978 113,871,978 28,211,787 15,220,658 12,898,863 4,901,214 Total 303,601,093 303,601,093 73,084,393 41,397,397 35,082,541 13,330,404 Reservoir Volumetric Summary (Oil/Wtr Contact at 6400’) Source: NuView Reservoir Model Reservoir Bulk (rb) Net (rb) Pore (rb) HCPV (rb) STOIIP (bbl) Assoc. Gas (mcf) 6000 243,917,923 243,917,923 57,905,811 30,429,705 25,787,886 9,798,690 6050 164,936,450 164,936,450 40,776,820 19,749,456 16,736,828 6,359,536 Total 408,854,374 408,854,374 98,682,631 50,179,161 42,524,714 16,158,225 Main Pass Blk 59 Fault Block C Reservoir Volumetric Summary (Oil/Wtr Contact at 6350’) Source: NuView Reservoir Model Reservoir Bulk (rb) Net (rb) Pore (rb) HCPV (rb) STOIIP (bbl) Assoc. Gas (mcf) 6000 170,827,175 170,827,175 39,956,971 15,594,800 13,215,933 894,401,491 6050 101,353,757 101,353,757 26,932,575 13,477,824 11,421,885 772,987,504 Total 272,180,932 272,180,932 66,889,546 29,072,624 24,637,817 1,667,388,995 Previous Traditional Log Analysis 2006 2014 Current Thin Bed Log Analysis
  33. 33. A-15 Pre-Drill and Post-Drill Comparison Post-Drill NuLook A15_Loc Pre-Drill Virtual Well 5600’ SD 5900’ SD 6000’ SD 6050’ SD
  34. 34. New Well A-15 – Upper Sand IP’d at 1000 BOPD
  35. 35. New Well A-15 – Lower Sand Has not previously been completed Has not previously been completed
  36. 36. Well A-15 Standard vs Thin Bed Processing Standard Processing -140 Net Ft Pay Thin Bed Processing – 187’ Net Pay
  37. 37. A-15 Monthly Production
  38. 38. A-19 Monthly Production
  39. 39. Conclusions and Recommendations • Previous study recommended two successful wells: A-15 and A-19 that are still producing today. • Addition of this new well data and refined Thin Bed log processing has resulted in an improved reservoir model. • Improved model has increased the hydrocarbon volumes to account for the over production of initial estimate. • The following are recommendations for further field development: 3 new wells and 2 recompletions. A new well should be planned to test the 5900’ zone and the 6000’ zone at a location just between the A10 and A8 wells. This was proven successful with the new A19 well. Re-complete the A14 well in the 6000’ zone before leaving the well. Re-complete the 6050’ zone in the A2 well. A well should be considered between the A8 and the A14 wells for the 6000’- 6050’ zones as the model indicates good properties in that location. A well should be considered between the A9 and the fault to the West as both the A9 and 8461_2 show overbank deposits leaving room for good quality sand to the West with good amplitude. The Thin Bed log processing has resulted in a higher resolution model and increased hydrocarbon volume by ~40% addressing the overproduction concern as well as a better understand of the reservoir connectivity and stratigraphic traps created by thin coalescing channel bodies.
  40. 40. The information is confidential and proprietary to Nutech Energy Alliance. It is intended to be reviewed only by intended and the information may not be copied, shared, distributed or otherwise communicated to any person or entity other than the recipient, without the express written consent of Nutech. While Nutech Energy Alliance has taken every precaution as to the accuracy of content and data presented herein, Nutech cannot be held responsible for the individual interpretation of the data presented any loss of damage to any property whatsoever, injury or death to any persons whatsoever, or any claims, demands, actions, complaints, proceedings, judgment, losses, damages, compensation, liabilities, costs or charges, however arising from the unauthorized, undirected use of this material or the data it contains.

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