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Cairn case study

A solution of a case study given by cairn India at earth science department, IIT Roorkee

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Cairn case study

  1. 1. SpotlightAkhil Prabhakar (Int. Mtech 4th yr GPT)Swapnil Pal (Int. Mtech 4th yr GT)Ojaswita Singh (Mtech 1st yr GPT)IIT Roorkee
  2. 2. Base mapA BCD
  3. 3. 02004006008001000120014001600Depth(m)Cross-section across A-BA BS N
  4. 4. 05001000150020002500Cross-section across C-DCDSE NW
  5. 5. 050010001500200025000 20 40 60 80 100 120 140 160 180 200DepthDistanceCross-section across C-DSE NW
  6. 6. TrapsAnticlinal trap Fault trap
  7. 7. Following conclusions can be drawn fromthe base map:Primary structural element: antiformal fold and faultTrap: anticlinal trapArea of Hydrocarbon accumulation: 53.15 Km2
  8. 8. Well log templates (GR)Well 1 Well 2 Well 3Well no. TopreservoirBasereservoirmTVD mTVDWell 1 765 859Well 2 909 960Well 3 878 956Marker Data
  9. 9. Well log templates (GR)Well 1Average gross reservoir thickness = 94mNet-sand thickness = 27.5mNet to gross (NTG) = 0.293Average porosity = 27%Average water saturation = 0.1
  10. 10. Well log templates (GR)Well 2Average gross reservoir thickness = 51mNet-sand thickness = 21mNet to gross (NTG) = 0.411Average porosity = 27.17%Average water saturation = 0.08
  11. 11. Well log templates (GR)Well 3Average gross reservoir thickness = 78mNet-sand thickness = 19mNet to gross (NTG) = 0.244Average porosity = 25.7%Average water saturation = 0.09
  12. 12. Comparison of different wellsWell 1 Well 2 Well 3 FieldAverage gross reservoirthickness94m 51m 78m 74.3mNet sand thickness 27.5m 21m 19m 22.5mNet to Gross 0.293 0.411 0.244 0.316Average porosity 27% 27.17% 25.7% 26.6Average water saturation 0.1 0.08 0.09 0.09
  13. 13. Depositional environmentFluvial/detaic environment.• Alternating sand and shale.• Clastic sediments deposition in passive margin.Recovery factor: Primary 40%EOR 50-60%
  14. 14. Formation Pressure Data (Well 2)Depth (mTVD) Formation pressure (psi)946 1614952 1619956 1622969.5 1639977 1650980.5 1655
  15. 15. Formation Pressure Data (Well 2)
  16. 16. Formation pressure16101615162016251630163516401645165016551660944 946 948 950 952 954 956 958 960 962 964 966 968 970 972 974 976 978 980Formationpressure(psi)Depth (mTVDSS)Fluid contact depthformation pressureSlope = 0.45 psi/feetSlope = 0.25 psi/feetSlope = 0.22 psi/feetSlope = 0.38 psi/feetSlope = 0.44 psi/feetOil filledreservoirWater filledreservoirOil-water contact
  17. 17. Calculations:Total in-place hydrocarbon = 516.3319986 million hydrocarbon volumesRecoverable reserves = 206.5327994 million hydrocarbon volumesVolume produced per day by a well = 5000 hydrocarbon volumesProduction at this rate from 1 well for 15 yrs. = 27.375 million hydrocarbon volumesNumber of wells needed = 18 or 19 wells
  18. 18. Thank you

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