1. Evaluation of Wax Deposition and Its Control During Production of Alaska North Slope Oils Annual Report Jan – Dec, 2006 University of Alaska Fairbanks Kansas University ConocoPhilips 22 January 2007

2. Project Objectives Evaluate the mechanisms and environments leading to wax deposition during ANS oil production Develop predictive models and give guidance for potential wax-free production Evaluate methods and techniques to prevent and control wax deposition during production

3. Wax Deposition Diagram Pressure ● Temperature Critical Point Initial Reservoir Condition ● Wax Envelope Gas Liquid Liquid + Gas P-T Path

4. To Achieve Wax-Free Production P-T path for production must stay outside of the wax envelope Requires in-depth understanding of Thermodynamic properties of crude oil Heat transfer characteristics of production string and the influence of permafrost Wax deposition under dynamic conditions

5. Work Done Density determination of all tank oil samples as function of temperature Molecular weight determination of crude oil using Cryette A for all 28 tank oil samples Determination of tank oil WATs by cross polar microscope (CPM) (12 samples) and viscometer (28 samples) Composition analysis of crude oil using GC-MS Selection of suitable thermodynamic model for wax precipitation Bubble point curve prediction program

6. Work Done (Cont.) Development of program for plus fraction splitting into suitable number of components Algorithm development for prediction of WAT of the oil Development of analytical solution for wellbore geometry (by KU) Development of numerical solution for wellbore geometry (by KU) Development of computer program for solid- liquid flash problem (by KU)

7. Density Measurement Density measured using ANTON- PAAR density-meter Density as a function of temperature is determined for modeling purpose

8. Density Measurement Results (Cont.) Sample density at 15 0 C

9. Density Measurement Results (Cont.) Density of all samples as a function of temperature

10. Molecular Weight Measurement Need for measurement of molecular weight Used for calculating critical properties of fractions which are required for modeling Instrument- Cryette A Measures depletion in freezing point and relates it to the concentration of solvent (benzene) and hence to the molecular weight of the solute K f = 5.12 0 C/mole, ΔFP= Meter Reading

11. Cryette A apparatus

12. Molecular Weight Measurement Results Sample No.Avg. MWSample No.Avg. MW 1137.3015157.83 2174.2716512.27 3196.1017361.33 4323.3618109.60 5300.2919150.59 6234.9820155.79 7190.2321172.06 8292.3222169.19 9174.6323279.96 10215.5324236.32 11140.5825230.74 12135.1626205.25 13225.0927230.27 14364.8528220.24

13. Wax Appearance Temperature (WAT) measurement Dead oil WAT measurement using Brookfield Programmable viscometer, Model LVDV-II+ Sudden increase in viscosity is used as indication of sign of wax appearance Dead oil WAT measurement using Cross Polar Microscope (CPM) Polar light makes the wax crystals shine as soon as they appear

14. WAT measurement by Viscometry Brookfield viscometer Data gathering PC Programmable LVDV-II+ Viscometer Heating/Refrigerating bath

15. WAT By CPM (for dead oil) Cooling Gas CCDCCD Analyzer 10 20 50 Hot Stage Top View Hot Stage IR - Filter Polarizer 360° Rotatable stage

16. WAT by Viscometry Spindle: SC4-21 RPM: 200 Temp range: 50 to 0 o C WAT = 20.3 o C WAT plot of sample 06

17. WAT Results by Viscometry Sample noWAT (Viscometery) CF 128.182.58 23086 343.1109.58 43086 536.196.98 629.184.38 744.2111.56 843.2109.76 936.597.7 1043.2109.76 1344.2111.56 1446.2115.16 1653.4128.12 1754.3129.74 233696.8 2444.2111.56 2536.196.98 263289.6 2734.193.38 2837.198.78

18. Oil Sample slides using CPM at T=60 o C (T>WAT)

19. Oil Sample slides using CPM at T=31.8 o C (T=WAT)

20. Oil Sample slides using CPM at T=28.8 o C (T<WAT)

21. Oil Sample slides using CPM at T=25.1 o C (T<WAT)

22. Oil Sample slides using CPM at T=8.7 o C (T<WAT)

23. WAT measurement by CPM Sample noWAT (CPM) deg Cdeg F 12780.6 227.982.22 325.778.26 431.889.24 540.6105.08 633.892.84 82984.2 142882.4 2331.588.7 243696.8 2533.692.48 2634.293.56

24. Comparison of WAT by Viscometry and CPM

25. Composition Analysis Need for composition analysis Used for identifying the type of crude Required for modeling phase equilibrium and properties of hydrocarbon mixtures Method of analysis GC-MS Flame Ionization Detector

26. Composition Analysis Results for Sample 13

27. Procedure For Bubble Point Prediction

28. Bubble Point Prediction Results

29. Plus Fraction Splitting Need for plus fraction splitting Not well defined composition gives gross information and make EOS models behave poorly Extended composition distribution gives better results Pedersen’s method used for splitting plus fraction into suitable number of components Program flexible to consider splitting upto desired carbon number depending on the requirement

30. Plus Fraction Splitting Results North Sea Crude Oil sample

31. Work Done at University of Kansas (KU) Thermodynamic Model Heat-Transfer Model Dynamic Wax Deposition Model

32. Heat-Transfer Model Objective: Establish temperature profiles in production string. Approach: Model heat exchanges between producing fluids, production string, insulation materials and formation rock/permafrost using total system energy balance. Generate system temperature profiles by solving total-system- energy-balance equation numerically using finite-difference method.

33. Physical Model

34. Total System Energy Balance Heat loss into the formation = Total heat flow from center of well to cement/formation interface Newton’s Law of Cooling: Where A: crossectional-area T: temperature U t : overall heat-transfer coefficient Equating Eqs. (1) and (2) yields

35. Overall Energy Balance of Heat Transfer Into Formation Rock

36. Assumptions: Physical properties of system components independent of temperature. Steady-state heat flow in the formation rock. Radial heat flow from wellbore into formation rock. Heat transfer from center of wellbore to cement/formation interface (0 → r h ) represented by an overall heat transfer coefficient, U t.

37. Overall Energy Balance of Heat Transfer Into Formation Rock Boundary Conditions:

38. Numerical Model Finite Difference Approximation:

39. Simulation of Heat Loss from Cement/Formation Interface into Formation Rock Steam Injection Example Well Depth= 5,000 ft, K e = 1.0 Btu/hr-ft-°F, c e = 0.21 Btu/lb-°F, c f = 1.0 Btu/lb-°F, T f = 600 °F, T e = 80 °F, U t = 3.4274 Btu/hr- sq ft-°F, ρ = 167 lb/ft 3, r to = 0.146 ft, r h = 0.5 ft.

40. Analytical Solutions Analytical solutions of heat conduction in an infinite circular cylinder bounded by a surface can be used to calculate cement/formation temperature change vs. time (Willhite, 1967). where f(t): transient heat conduction function solved analytically

41. Validation of Numerical Model with Analytical Solutions Eq. (3) can be rearranged as Eq. (4) can be used to calculate f(t) using temperature data from numerical model. Numerical model can be validated by comparing f(t) analytical vs. f(t) numerical

42. Analytical vs. Numerical Solutions Steam Injection Example Well During first 200 hours of steam injection, cement/formation interface temperatures calculated using Numerical model match analytical solutions well.

43. Phase Composition in Solid-Liquid Equilibrium (Experimental data from Dauphin et al. 1999) Predictions from our thermodynamic model match experimental data well. Thermodynamic Model

44. Future Work Measure WAT of remaining tank oil and live oil samples by CPM Complete GC-MS characterization Conduct PVT Analysis Complete GC-FID analysis Develop program to predict WAT Development of the thermodynamic model to predict cloud point

45. We gratefully acknowledge the financial support from AEDTL/NETL/DOE Acknowledgement

46. Thanks and Questions?