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The influence of wettability and carbon dioxide injection on hydrocarbon recovery

The influence of wettability and carbon dioxide injection on hydrocarbon recovery. Saif Al Sayari Martin J. Blunt. Outline. Objective The influence of wettability on Electrical resistivity NMR Pc Kr Pore scale modelling Efficacy of CO 2 injection for hydrocarbon recovery

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The influence of wettability and carbon dioxide injection on hydrocarbon recovery

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  1. The influence of wettability and carbon dioxide injection on hydrocarbon recovery Saif Al Sayari Martin J. Blunt

  2. Outline • Objective • The influence of wettability on • Electrical resistivity • NMR • Pc • Kr • Pore scale modelling • Efficacy of CO2 injection for hydrocarbon recovery • Tertiary HC gas injection • Tertiary WAG injection • Tertiary CO2 Injection

  3. Objectives • Evaluate the influence of wettability • Compare the results with numerical predictions using pore-scale modelling where the pore space has been imaged using micro-CT scanning. • Assess CO2 injection in carbonate oil fields.

  4. Conventional core analysis • Sandpack • Porosity ~ 34% • Permeability ~ 35 Darcy • Sandstone – Fontainebleau • Porosity ~ 9 % • Permeability ~ 140 mD • Carbonate – Middle East • Porosity ~ 28 % • Permeability ~ 7 mD

  5. MICP • Mercury injection capillary pressure is employed: • to describe the pore-size distribution • to draw drainage capillary pressure that can be used to compare to other methods such as the porous plate method. Carbonate SN 4

  6. Influence of wettability Knowledge of the wettability of a reservoir rock and its influence on petrophysical properties is a key factor for determining oil recovery mechanisms and making estimates of recovery efficiency. We combine in one study the effects of wettability on multiphase flow parameters, looking at capillary pressure, relative permeability, electrical properties and NMR.

  7. Wettability Influence: Electrical Resistivity Carbonate SN 4 - 5

  8. Wettability Influence: Capillary Press. Carbonate sample: Pc (Oil-wet vs. Water wet) Very similar samples (Pore throat distribution)

  9. Wettability Influence: Relative Perm. Steady-state relative permeability for carbonate sample at water-wet condition. The sample is then aged in crude oil and elevated temperature and the relative perm. will be conducted again Carbonate SN 1

  10. Network Core Micro-CT Rock Properties Porosity Permeability Formation Factor Capillary Pressure Relative Permeability NMR Response Porosity Permeability Formation Factor NMR Response Porosity Permeability Formation Factor Capillary Pressure Relative Permeability NMR Response Relative Permeability, SPE84550 Capillary Pressure • Pore-scale modeling: • Complementary to SCAL, for the determination of single and multiphase flow properties. • Looking at trends where data is lacking, different rock types, wettability and three-phase flow Laboratory – pore scale

  11. Sand pack - LV60B Sand pack - F42B NMR – Results Sandpacks

  12. Carbonate (2) Network: Tuned Berea Pores: 12,349 Throats: 26,146 Simulation Parameters Diffusion Coefficient: 2.07x10-9m2/s (Vinegar, 1995) Bulk Relaxivity: 3.1s (Vinegar, 1995) 2.8μm/s Surface Relaxivity: Number of walkers: 2,000,000 Comparison of the experimental capillary pressures of carbonate C22 with simulation results from a tuned Berea network. NMR – Results Carbonats

  13. Carbonate (3) Network: Tuned Berea Pores: 12,349 Throats: 26,146 Simulation Parameters Diffusion Coefficient: 2.07x10-9m2/s (Vinegar, 1995) Bulk Relaxivity: 3.1s (Vinegar, 1995) 2.1μm/s Surface Relaxivity: Number of walkers: 2,000,000 Comparison of the experimental capillary pressures of carbonate C32 with simulation results from a tuned Berea network. NMR – Results Carbonats

  14. Efficacy of CO2 injection Reservoir condition core flooding test have commenced using a composite core plug from a producing field from the Middle East. Reservoir temp. ~ 250 oF and press. ~ 4000 psi After flooding the sample with brine, vertical flooding sequence has been applied: • Tertiary Gas flood. • Tertiary Water Alternating Gas. • Tertiary CO2 injection.

  15. Efficacy of CO2 injection • Oil produced from waterflooding was 42%

  16. Tertiary Gas injection • Oil produced from gas flooding was 82%

  17. Tertiary WAG injection • Oil produced from WAG flooding was 80%

  18. Injection of CO2 stopped Tertiary CO2 injection • Oil produced from CO2 flooding was 96%

  19. Efficacy of CO2 injection • Comparison between different tertiary flooding methods

  20. The influence of wettability and carbon dioxide injection on hydrocarbon recovery Saif Al Sayari Martin J. Blunt

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