This document summarizes a wax deposition study on the Ravn oil field production system. It found that: 1) Wax deposition could reduce pipeline flow area and cause blockages. The study modeled wax deposition risks in the Ravn infield and export lines. 2) For the infield line, up to 4mm of wax could deposit at the seabed and 13mm at topsides within 30 days without inhibitors. Inhibitors could reduce this by 40%. Pigging was recommended every month without inhibitors and every 45 days with. 3) For the export line, up to 4mm of wax could deposit at the seabed within 22-31 days depending on inhibitors. Higher flows increased deposition risks

1. Flow Assurance Wax Study on the Ravn Field
Production System
Wood Group Kenny: Hooman Haghighi, Jamie Littler, Fujiang Zhu,
Temitope Solanke
Wintershall: Leif H. Blidegn, Amir Mofidi

2. 2 - www.woodgroup.com
Agenda
• Introduction to the risks of wax deposition
• Ravn Field Overview
• Fluid Tuning
• Results of Infield and Export Lines
• Conclusions and recommendations

3. Wax deposition risks
Wax is long-chain simple hydrocarbons. Can be stable in the solid
phase at various temperatures.
Wax deposition can cause:
• Reduction in flow area
• Change in wall friction
• Blockage of the pipeline
These pictures are from public domain.

4. Wax management
Maintain the system temperature above the
wax appearance and/or fluid pour point.
• Insulation
• Displacement with stabilized crude,
diesel or condensate
• Active heating of the pipeline
Physical removal of wax
• Periodic scraping of the wax layer via
pigging operations.
• Heating
Chemical treatment
Blideng et al. (2011), Running-in a new Platform, 22nd
International Oil Field Chemistry Symposium

5. Ravn system schematic
Ravn
F3-FB Platform
4” Oil Export Line (119 km)
72m
5°C
0.34 m/s
- 10°C
54 m/s
66m
API° 38.2
Viscosity at 60°F (cP) 24.1
WAT (°C) 27.5
N-Paraffin Content (wt%) 2.625
Pour Point (°C) -51
Fluid Properties
Export T = 55°C
Ambient Conditions
FWHT= 60°C
8” Infield Line (18 km)
A6A Platform

6. Wax deposition (MolecularDiffusion)
• Molecular Diffusion is the dominant wax deposition mechanism
• Radial diffusion of dissolved wax molecules in the oil
• Concentration gradient between dissolved wax in the turbulent core
and the wax in solution at the pipe wall
• Dissolved wax diffuses towards the wall where it precipitates
Turbulent Core

7. • There are a few lab techniques available for wax
measurements:
• Viscosimetry
• Cold finger
• Differential Scanning Calorimetry (DSC)
• Cross Polarization Microscopy
• Filter Plugging
• Fourier Transform Infrared Spectroscopy (FTIR)
Wax Appearance Temperature (WAT):
The temperature below which the paraffin's start to
precipitate as wax crystals is defined as crude cloud point or
WAT.
Pour Point:
The temperature at which oil sample movement stops is
defined as the crude oil pour point.
Wax testing
These pictures are from public domain.

8. Wax properties
Lab Data
WAT [oC] 27.5
WDT [oC] 55
Wax Paraffinic content [wt%] NOTE1 2.625
Cold Finger Test
Note 1: C17+
Static Cold Finger Set-up
• Hayduk Minhas correlation was used to calculate the diffusion
Coefficient (9.78E-08 cm2/s)
• Wax Inhibitor from lab test was shown to reduce the deposition rate
by 40-80% (40% has been assumed as a conservative approach in
this study)

9. Viscosity tuning
Shear Rate Calculation-Catcher
Shear rate= 10 S-1
Temp= 15 C
μ= 22 cp
ID= 0.1016 m 4"
ρ= 834.9702 kg/m3
QLT= 1950 bpd
0.003588 m3/s
u= 0.442594 m/s
Velocity
Re= 1706.661 Re<2300 Laminar
Re>4000 Turbulent
Laminar
τ= 1.0 N/m2
s= 0.045805 S-1 Turbulent
s= 34.84989 S-1 Laminar
note: use the lab data with shear rate =10 S-1
• A shear-thinning behaviour of the fluid has been observed at low
temperature.
• The shear rate has been identified to represent the actual flowing
condition (for each flow rate) and viscosity has been tuned based on
the selected shear rate.
0
10
20
30
40
50
60
70
80
90
100
0 5 10 15 20 25 30 35 40 45 50
DynamicViscositymPa.s[cP]
Temperature °C
Steady State Dynamic Viscosity Profiles For Ravn Oil
1 s-1
10 s-1
100 s-1
non-Newtonian Behaviour at Low temperature

10. Fluid modelling
Effect of pressure & light end component on WAT
Note:The dynamic changes in the fluid composition(e.g. Gas Oil Ratio) in the pipeline and the effecton WAT has been
consideredin thermo-hydraulicsimulation.Howeverthe model has not taken into account the compositionchange
due to wax drop-out(conservative).
0
50
100
150
200
250
0 10 20 30 40 50 60 70 80 90
Pressure[bara]
Temperature / Wax Appearance Temperature [oC]
Wintershall Ravn Field
Fluid Modelling
in-Field Line
Wax Appearance Temperature (WAT) as a Function of GOR and Pressure
Bubble Line (Case 1+GL - GOR = 1900 Scf/bbl)
WAT (Case 1+GL - GOR = 1900 Scf/bbl)
Bubble Line (Case 2 - GOR = 533 Scf/bbl)
WAT (Case 2 - GOR = 533 Scf/bbl)
Bubble Line (Case 3+GL - GOR = 986Scf/bbl)
WAT (Case 3+GL - GOR = 986 Scf/bbl)

11. Risk of wax deposition (in-fieldline, early life)
-20
-10
0
10
20
30
40
50
60
70
0 2 4 6 8 10 12 14 16 18 20
Temperature[C]
Length [km]
Wintershall Ravan Field
Wax Deposition Simulation
In-field Line
Temperature and Wax Depostion Profiles (Case 1+ GL)
Fluid T
WAT
T Ambient
Wintershall Ravn Field

12. Wax deposition thickness (in-field,early life)
0
2
4
6
8
10
12
14
0 2 4 6 8 10 12 14 16 18 20
WaxThickness[mm]
Length [km]
Wintershall Ravn Field
Wax Deposition Simulation
In-field Line
Wax Depostion Profiles (Case 1+ GL)
30 days
20 days
10 days
Risk of Wax Depostion at the Topsides
Risk of Wax Depostion at the Subsea

13. 0
1
2
3
4
5
6
7
8
9
10
0 5 10 15 20 25 30
TotalWaxDeposited[m3]
Time [days]
Wintershall Ravn Field
Wax Deposition Simulation
In-field Line - No Inhibitor
Volume of Wax Deposition
Case 1
Case 2
Case 3
Case 4
Total wax deposition (withoutinhibitor)
Total growthrate of wax (in-fieldpipeline) is <0.4 m3/d without inhibitor
Oil Gas Water
[m3
/d] [m3
/d] [m3
/d] [m3
/d]
1 310 29448 0 + GL
2 620 58896 0 0
3 620 58896 0 50000
4 369 39979 52 100000
Case
Production Rates
Gas Lift

14. 0
1
2
3
4
5
6
7
8
0 5 10 15 20 25 30
TotalWaxDeposited[m3]
Time [days]
Wintershall Ravn Field
Wax Deposition Simulation
In-field Line - With Inhibitor
Volume of Wax Deposition
Case 1
Case 2
Case 3
Case 4
Total wax deposition (withinhibitor)
Total growthrate of wax (in-fieldpipeline)is <0.3 m3/d with inhibitor
Oil Gas Water
[m3
/d] [m3
/d] [m3
/d] [m3
/d]
1 310 29448 0 + GL
2 620 58896 0 0
3 620 58896 0 50000
4 369 39979 52 100000
Case
Production Rates
Gas Lift

15. Summary of the results (in-fieldline)
• WAT is lower at higher pressure for the live fluid
• The effect of pressure is more pronounced for the fluids with a
higher GOR (i.e. Gas Oil Ratio)
• As soon as the fluid reaches ambient temperature, no wax
deposition would occur (No heat flux to drive the wax deposition –
cold slurry flow).
• The first location for wax to deposit depends on the flow rates,
GOR, phase fractions, etc.
• After 30 days of operation <4mm and <13mm of (max) wax
thickness can be expected at seabed and topside conditions
respectively without inhibitor.
• The recommended frequency of pigging operation is every month
(based on maximum 4mm of wax deposition in the system) without
inhibitor and every 45 days with inhibitor injection (40% efficiency).

16. Risk of wax deposition (ExportLine)
-20
-10
0
10
20
30
40
50
60
0 20 40 60 80 100 120 140
Temperature[C]
Distance (km)
Wintershall Ravn Field
Wax Deposition Simulation - Export Line
Temperature Profile and Risk of Wax Deposition
Ambient T
WAT
1950bpd Fluid T
2500bpd Fluid T
3500bpd Fluid T
4500bpd Fluid T
Risk of Wax Depostion at the Subsea
Risk of Wax Depostion at the Topsides

17. Wax deposition thickness (Exportline)
0
2
4
6
8
10
12
14
0 20 40 60 80 100 120 140
WaxThickness[mm]
Length [km]
Wintershall Ravn Field
Wax Deposition Simulation
Export Line
Wax Depostion Profiles (2500 bpd)
5 days
10 days
15 days
20 days
30 days
Risk of Wax Depostion at the Topsides
Risk of Wax Depostion at the Subsea

18. Pressure drop vs. max wax thickness
(ExportLine)
0
5
10
15
20
25
30
35
0 2 4 6 8 10 12 14
PressureDrop[bara]
Max Wax Thickness [mm]
Wintershall Ravn Field
Wax Deposition Simulation
Export Line
Pressure Drop vs. Max. Deposition Thickness
1950 bpd
2500 bpd
3500 bpd
4500 bpd

19. Self insulation on wax deposition
(ExportLine)
Results are forthe topsides (i.e.the highest deposition thickness and rates)
0
2
4
6
8
10
12
14
0
0.2
0.4
0.6
0.8
1
1.2
1.4
1.6
0 5 10 15 20 25 30
MaxWaxThickness[mm]
MaxDepositionRate[mm/day]
Time [days]
Wintershall Ravn Field
Wax Deposition Simulation
In-Field Line
Effect of Wax Thickness on Depostion Rates
Case 1 - Deposition Rate Case 2 - Deposition Rate Case 3 - Deposition Rate Case 4 - Deposition Rate
Case 1 - Max Wax Thickness Case 2 - Max Wax Thickness Case 3 - Max Wax Thickness Case 4 - Max Wax Thickness

20. Summary of the results (Exportline)
• Higher flow rate leads to longer section of the export line subject
to wax deposition risk.
• Lower rate of deposition by time due to the wax self-isolation
effect.
• The maximum wax thicknesses identified for the 4 cases are
comparable, however the total wax deposited is more at higher
flow rates.
• After 22 days and 31 days of operation <4mm of (max) wax
thickness can be expected at seabed condition without and with
inhibitor (40% efficiency), respectively.
• Pigging of 4” >100 km export line is challenging and is currently
under further evaluation.
• Alternative wax mitigation strategy like wax dispersant, gas
condensates has been considered.

21. Other Flow Assurance challenges
• Slugging in the in-field line at the early life and during the start-up
and turn-down operations has been observed. The following
mitigation methods has been considered:
o Increased back pressure (for start-up and turn-down operations)
o Gas lift injection (if required)
• Liquid handling capacity at the topsides (~27 m3)
o High level pigging, start-up and ramp-up philosophies have been
developed

22. Special thanks to:
Questions?