1. Oceaneering Services (M), 10 APRIL 2014
STUDENT INDUSTRIAL PROJECT (SIP) VISIT
ICB 3047
Joeal Lim Guan Chin 15115
Host Company Supervisor : Mr. Afiq bin Abdul Aziz
University Supervisor : Mr. Saleem Qadir Tunio

2. Flow of Presentation
Introduction
Problem
Statement
Literature Review
Discussions
Conclusion and
Recommendations

3. RESEARCH PAPER
Investigating the Mechanism of
Corrosion in Oil and Gas
Production Pipeline and Possible
Mitigations

4. PROBLEM STATEMENT
Safety Money Environment

5. Literature Review

6. Internal Corrosion
• Reaction with water to produce Iron Sulfide
and hydrogen (acid attack)
• Iron sulfide sets up a galvanic cell which steel
pipe become anode

7. Internal Corrosion
Sour Corrosion to a drill pipe

8. Microbiologically Influenced Corrosion
• Aka: bacterial corrosion, bio-corrosion, or microbially induced
corrosion
• Associated with microorganism activity
• Aerobic bacteria:
 Acidithiobacillus thiooxidans,
 Thiobacillus thioparus,
 Thiobacillus concretivorus
• Anaerobic bacteria:
 Desulfovibrio
 Desulfotomaculum

9. Microbiologically Influenced Corrosion
Phase 1
Phase 2
Phase 3
Recognition of desirable site
Nodule formed over mature pit

10. Microbiologically Influenced Corrosion
MIC pits in carbon steel pipeline
Common bacteria found in o&g pipeline:
I. Acid-producing bacteria (APB)
II. Sulfate-reducing bacteria (SRB)

11. Sand Erosion-Corrosion
• Flow from the reservoir may consist:
Single phase flow (oil, gas, or water)
Two phase flow (oil-gas, gas-water)
Three phase flow (water-gas-sand, oil-
gas-sand)
Erosion

12. Sand Erosion-Corrosion
• Company will usually set the limit of velocity
that is flowing through the pipeline
𝑉𝐸 =
𝑐
𝜌
Where:
• VE = fluid erosion velocity (below which erosion will not occur)
• C = empirical constant
• ρ = gas-liquid mixture density at flowing temperature and
pressure

13. Sand Erosion-Corrosion
Service Water CO2 H2S O2 Sand
Upstream 1. Stage Separator – Well fluid/ unprocessed fluid
Tubing/ riser Likely Likely Most likely Unlikely Most likely
Pipelines/ manifold Likely Likely Most likely Unlikely Most likely
Downstream 1. Stage Separator - Top side piping
Oil Likely Likely Most likely Unlikely Most likely
Gas In parts Likely Most likely Unlikely Unlikely
Produced Water Likely Likely Most likely Unlikely Most likely
Processed Hydrocarbons
Gas/oil export – Gas Injection Seldom Likely Most likely Unlikely Unlikely
Water Systems
Water Injection Likely Unlikely Unlikely Likely Seldom
Fire/ Cooling/ Utility Likely Unlikely Unlikely Likely Unlikely

14. Discussions

15. Selection of Materials
• Based on pitting resistance equivalent number (PREN)
𝑃𝑅𝐸𝑁 = %𝐶𝑟 + 3.3 × %𝑀𝑜 + (16 × %𝑁)
Where:
Cr : Chromium
Mo : Molybdenum
N : Nitrogen
• The higher the value of PRE, the better the resistant to corrosion

16. Selection of Materials
Material specification Oil and gas applications
Carbon Steels Bulk fluids, crude pipelines, flow lines, water and steam
injection lines, production and test separators, KO drums,
storage tanks
Low- and medium-allow steels Well head items, chokes, manifolds and well components
with sour and high- temperature applications
Straight chromium steels (chromium 12% to 18%) Christmas trees, well heads, downhole rods, valves and
casing pipes
Chromium-nickel steels (chromium >18%, nickel >8%) Valve trims, instruments and materials of separators and
tanks, low-chloride levels
Nickel steels (2.5%, 3.5%, 9% nickel) Rarely used in oil and gas sectors, LNG storage tanks, piping
and pumps
Duplex stainless steels (22% chromium duplex, 25%
chromium super, duplex)
Piping, vessel and tank internals where a very high level of
chlorides is present
Nickel-chrome (inconels) Ni-Cr-Fe alloys Well head and flow lines, manifolds with high sour and
temperature applications
Nickel-iron (incolys) Ni-Fe-Cr alloys Well head and flow lines, manifolds with high sour and
temperature applications

17. Usage of Inhibitors
• Inhibitors protect the metal surface either by
merging with them or react with the
impurities in the environment that causes
corrosion

18. Usage of Inhibitors
Inhibitors Oil and gas applications
3-Phenyl-2-propyn-1-ol API J55 oil field tubing in HCl solutions over a wide range of conditions
Hydrazides and thiosemicarbazides of fatty acids with 11, 12,
and 18 carbon atoms Mild steel and oil well steel (N80) in boiling 15% hydrochloric acid solution
Mixture of ketones, quinolinium salts, and formic acid
Oil field tubular goods to temperatures as high as 400F (204C) in
hydrochloric
2-Undecane-5-mercapto-1-oxa-3, 4-diazole
Mild steel in 15% HCl at 105  2C and N80 steel in 15% HCl containing 5,000
ppm of 2-undecane-5-mercapto-1-oxa-3,4-diazole
2-Heptadecene-5-mercapto-1-oxa-3, 4-diazole
2-Decene-5-mercapto-1-oxa-3, 4-diazole
Dibenzylidene acetone
N80 steel and mild steel in HClDi-N-dimethylaminobenzylidene acetone
Methoxy phenol and nonyl phenol
N80 steel in 15% HCl at different exposure periods (6 to 24h) and
temperatures (30C to 110C)
N-(5,6-diphenyl-4,5-dihydro-[1,2,4] triazin-3-yl)-guanidine Mild steel in 1 M hydrochloric acid and 0.5 M sulphuric acid
6-Benzylaminopurine Cold rolled steel in 1.0 to 7.0 M H2SO4 at 25C to 50C
Mixture of synthetic magnetite and ferrous gluconate
Oil well steel (N80) in 50 mg/l sulfide concentration at various pH (5.5 to 11.5)
and at high temperature conditions
Rosin amide imidazoline N80 and P110 carbon steels in CO2-saturated simulated formation water

19. Use of Protective Coatings
• A later of barrier preventing a direct contact between the metal
and the corrosive environment
• Eg: paint, coating or a lining, or a metallic lining or metallic
sheets
• The most widely used coatings:
 Fusion-bonded epoxy (FBE)
 three-layer polyolefin (3LPO) (polyethylene or Polypropylene)

20. Use of Protective Coatings
Single layer FBE : North America, Saudi Arabia, UK
Dual layer FBE : Australia
3LPO: Rest of the world

21. Corrosion Monitoring and Inspection

22. Corrosion Monitoring and Inspection

23. Corrosion Monitoring and Inspection
0% 5 – 15% 15 – 30% 30 – 40% 40 – 55%
Hourly based Corrosion
Maintenance work
Hourly based Corrosion
Maintenance work with
advisory
Hourly based Corrosion
Maintenance with SOLV
Hourly based Corrosion
Maintenance work with
incentive and SOLV
Fixed price Corrosion
Maintenance with SOLV

24. Conclusion and Recommendations

25. Conclusion and Recommendations
• Research on:
 Inhibitors that will not degrade or harm the fluids flowing
in the pipeline
 Protective coatings and paints that will not wear out
 Materials that are completely resistant to corrosion yet
affordable
 Better way for corrosion monitoring and inspection

26. Thank You for Your Attention!
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Q & A