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Corrmagnet Consulting Inc. Sankara Papavinasam, Ph.D., Fellow of NACE, Fellow of ASTM, is the president of CorrMagnet Consulting
Inc. Over the past 25+ years, he has led several joint industry projects as well as individual client projects
with more than 50 Oil and Gas Companies globally and has developed solutions and insight to control
internal and external corrosion.
He has authored the book, “Corrosion Control in the Oil and Gas Industry” and developed several software
products. He has also appeared as subject matter expert before National Academy of Sciences Committee,
Washington DC, USA and Canadian Senate Committee, Canadian Parliament, Ottawa, Canada on crude oil
corrosivity.
EXPERIENCE
2013-Contg. President, CorrMagnet Consulting Inc., Calgary, Alberta, Canada
2008-2014. Adjunct Research Professor, Department of Civil and Environmental Engineering, Carleton
University, Ottawa, Ontario, Canada
1994-2013 CANMET, Ottawa/Hamilton, Ontario, Canada
2013-2013 Acting Program Manager (Oil and Gas Pipelines)
2008-2012 Group Leader, Materials Assessment Group (Corrosion and Characterisation)
1996-2013 Research Scientist
1994-1996 NSERC Visiting Fellow
1993-1994 Scientist, India/Sweden Research Project on Biosensors, Centre for Protein Engineering and
Biomedical Research, Madras, India.
1991-1993 Principal Investigator, Department of Science and Technology, Young Scientist’s Research
Project, "Studies on the Kinetics and Mechanism of Electropolymerisation of Conducting
Polymers by Electrochemical Techniques”, Bangalore University, Bangalore, India.
1990-1991 Lecturer, Department of Chemistry, St. Joseph's College, Bangalore, India.
EDUCATION 1990 Doctor of Philosophy, Bangalore University, Bangalore, India.
"Studies on Some Aspects of the Corrosion and its Inhibition of Pb-Sb Alloy, Pb, Cu and Al
in Aggressive Media and the Electrodeposition of Zn-Ni Alloy from a Chloride Bath".
1986 Master of Philosophy, Annamalai University, Chidambaram, India.
"Kinetics and Mechanism of Oxidation of Benzaldehydephenylhydrazone by Phenyl Iodine
(III) Acetate".
1984 Master of Science, Madurai Kamaraj University, India.
1982 Bachelor of Science, Madurai Kamaraj University, India.
AWARDS AND FELLOWSHIPS
2016 NACE International, Technical Achievement Award
2013 ASTM Francis L. LaQue Memorial Award (Highest by ASTM G01: Corrosion Committee)
2013 Natural Resources Canada, Department Award for Outstanding Contribution to the
development of Science on “Corrosivity of Crude Oils”
2013 Natural Resources Canada, Minerals and Metals Sectors’ Sector Award for Exceptional
Contribution to Science
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2012 NACE Materials Performance readers’ choice, Corrosion Innovation of the Year Award for
“Bio-Corrosion Probe”
2012 Natural Resources Canada, MMS, CanmetMATERIALS Division Award for Science
2011 ASTM International Fellow 2011 ASTM International Award of Merit
2009 JPCL Editor’s Award for the paper, “Testing Coatings for Pipeline – New Laboratory
Methodologies to Simulate Field Operating Conditions of External Pipeline Coatings”,
Journal Protective Coating and Liners.
2008 NACE International Fellow
2005 Minerals and Metals Sector Award for the contribution leading to the Development of two
new ASTM Standards, G184 and G185 for evaluating corrosion inhibitors to control internal
corrosion using rotating cage and rotating cylinder electrode respectively.
2005 Minerals and Metals Sector Team Award to the development of Intelligent System for
Pipeline Infrastructure Reliability (ISPIR) (with W Revie W. Zheng, G. Gu, G. Roy, G. Shen,
G. Williams, A. Doiron)
2003 CANMET-MTL Divisional Award for Advancing Technology for Managing Corrosion
2003 NACE International, Northern Area, Outstanding Service Award
2003 CIM/CANMET Technology Transfer Team Award
2000 ASTM Committee G01: Corrosion of Metals Award for outstanding contribution on the new
standard, "Evaluating and Qualifying Oilfield and Refinery Corrosion Inhibitors in the
Laboratory"
1999 Natural Resources Canada, Minerals and Metals Sector Award in recognition to the
exceptional contribution to the CANMET/Industry Consortium on “Development of
Standardised Methodologies for Evaluation and Qualification of Inhibitors for Sour Service”.
1998 CANMET Materials Technology Laboratory Team Recognition Award for achievement in
“Designing, Fabricating, and Testing an Atmospheric Pressure Rotating Cage System”
1996 Best paper award, First International Conference on Molecular Association, ICMA 96, India.
1994 NSERC (Natural Sciences and Engineering Research Council of Canada) Postdoctoral
Fellowship.
1992 Best Paper Award for paper Published in The Journal of Electrochemical Society of India, 41,
1992, P.43-50.
1991 Young Scientist Research Project, Department of Science and Technology, Government of
India.
1988 Best Paper Award for paper Published in The Journal of Electrochemical Society of India, 37,
1988, P.200-206.
1985 Department of Science and Technology Research Fellowship, Department of Chemistry,
Bangalore University, Bangalore, India
LEADERSHIP
2017-Contg. Technology Coordinator, TMG N1, NACE International, Houston (to oversee
development of corrosion control standards for oil and gas production and refinery industries)
2017 Co-Chair, ASTM Symposium on “Recent Advances in Electrochemical Techniques for
Corrosion Monitoring and Laboratory Corrosion Measurements”, Atlanta, GA, USA,
Nov. 13-14, 2017
2017 Round Table Participant, “Regulations and Standards in Corrosion”, CorCon 2017, Mumbai,
India, September 19, 2017.
2017 Round Table Participant, “Corrosion Monitoring”, CorCon 2017, Mumbai, India, September
18, 2017.
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2017 Tutorial Co-Organiser, “10-Year Progress on Internal Corrosion Control of Oil and Gas
Pipelines: What has Changed and What remains the same”, April, 3, 2017
2017 Organizer, “Pipeline Integrity Management (External Corrosion Control) Workshop, SSPC
2017, Pune, India, February 17, 2017.
2017 Technical Panel Discussion – Panel Participant, SSPC 2017, Pune, India, February 15, 2017.
2015-2017 Associate Technology Coordinator, TMG N1, NACE International, Houston
2014-Contg. Instructor, STEM-Corrosion in the Oil and Gas Industry, Online Course,
www.CorrMagnet.com
2014 Keynote address, “Role of Corrosion Management in Controlling Internal Corrosion of the
Oil and Gas Production Infrastructures”, InterCorr 2014, organised by ABRACO, Fortaleza,
Brazil, May 19-23, 2014.
2014 Subject Matter Expert, Round Table Discussion, “Pipeline Corrosion Issues Related to
Carbon Capture, Transportation, and Storage”, Materials Performance, 53 (5) 2014, p. 24-27.
2014 Chair, TEG 453x Symposium, “Carbon Capture and Storage”, NACE 2014.
2013 Appeared before Canadian Senate Committee on “Safe Transportation of Hydrocarbons in
Canada” as subject matter expert to explain the inhibitory nature of crude oil under pipeline
transportation conditions (http://www.parl.gc.ca/content/sen/committee/411/ENEV/36EV-
49937-e.HTM)
2013-2015. Chair, NACE STG 31: Oil and Gas Production – Corrosion and Scale Inhibition
2013 Co-Chair, Banff Pipeline Workshop 2013, Banff, Canada, http://banffworkshop.com
2013 Subject Matter Expert, Round Table Discussion, “Managing Corrosion of Pipelines that
Transport Crude Oils”, Materials Performance, 52 (5) 2013, p. 28-30.
2012, 2013 Appeared before National Academy of Sciences, Washington DC, to explain inhibitory
nature of crude oils under pipeline transportation conditions, The National Academies of
Press, TRB Special Report 311: Effects of Diluted Bitumen on Crude Oil Transmission
Pipelines (2013)
2012 Co-chair, NACE Northern Area Eastern Conference, Oct. 28-31, 2012, Toronto, Ontario,
Canada
2012 Interviewed by Canadian Newspaper, Globe and Mail “Study eats into oil-sands opponents’
corrosion claims”, Nov. 23, 2012 (http://www.theglobeandmail.com/report-on-
business/industry-news/energy-and-resources/study-eats-into-oil-sands-opponents-corrosion-
claims/article5578801/)
2012 Interviewed by EnergyWire, Washington DC, “Scientists find conventional crudes similarly
corrosive to oil sands mix”, Dec. 10, 2012 (http://www.eenews.net/stories/1059973549)
2011 Co-chair, NACE Northern Area Eastern Conference, Aug. 15-18, 2011, Ottawa, Ontario,
Canada
2011 Instructor, 5-M Course, University of Zulia, Maracaibo, Venezuela
2009 Session Chair, “Recent Advances in Pipeline Coatings”, NACE 2009, March 22-26, 2009,
Atlanta, Georgia, USA
2009 Instructor, 5-M Course, University of Zulia, Maracaibo, Venezuela
2008-2010 Program Coordinator - Science, NACE International
2008 Coordinator, Second Canada-India Workshop on ``Pipeline Integrity: Developing an
Integrity Management Plan”, Sept. 25-26, 2008, Calgary, Alberta, Canada
2008 Session Vice-Chair, “External Pipeline Coatings and Performance under High Operating
Conditions”, NACE 2008, March 16-20, 2008, New Orleans, Louisiana, USA
2007 Co-chair, NACE Northern Area Eastern Conference, Sept. 24-26, 2007, Ottawa, Ontario,
Canada
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2007 Coordinator, First Canada-India Workshop on ``Pipeline Integrity”, November 24, 2007,
Mumbai, India
2006-2008 Chairman, NACE STG 62: Corrosion Monitoring and Measurements
2005 Session Chair, NACE 2005, “Sour Gas Corrosion for Oil and Gas Production”.
2004-Cont. Vice-Chair, ASTM International G01: Corrosion Subcommittee
2004 Session Vice Chair, NACE 2004, “Corrosion Related Issues in Oil and Gas Production
Systems Resulting From the Presence of H2S and Other Sulfur Containing Compounds”,
March 28 - April 1, 2004.
2003 Session Chair, NACE 2003, San Diego, “Advances in Electrochemistry in Corrosion
Monitoring”, March 16-20, 2003
2002-Cont. Chairman, American Society for Testing and Materials (ASTM) G01-11: Electrochemical
Techniques in Corrosion
2002 Session Chair: Coating and Cathodic Protection, International Pipeline Conference, October
1-4, Calgary, Canada
2001 Rapporteur Banff Workshop “Managing Pipeline Integrity” Session #3 : Upstream
Pipelines: Inspection, Corrosion, & Integrity Management, April 9-12, Banff, Alberta.
2001 Invited to talk on, "Experience and Success of PICon" at NACE 059X Group, CO2 Corrosion
in Oil and Gas Production, March 13, Houston, Texas.
2001 Invited to demonstrate, “Hydrodynamics of Rotating Cage” at NACE 213X Group, Open
Forum on the Flow Effects on Corrosion, March 12, Houston, Texas.
2000-02 ASTM G01.11. Vice-Chairman, “Electrochemical Measurements in Corrosion Testing
2000-2012 Co-organiser, PICon (Pipeline Integrity Internet Icon) – An online journal to publish papers
on pipeline integrity
2000 Co-Chair, First Internet Conference on Pipeline Reliability (PICon),
http://www.nrcan.gc.ca\PICon
2000-Cont. ASTM G01.05.11.01.Technical Chairman: Multiphase Corrosion Inhibitor Testing
(Published: ASTM G170, G184, G185, G202, and G208)
1999 Instructor, CIM (The Canadian Institute for Mining, Metallurgy, and Petroleum) Course:
Corrosion and Corrosion Control, Quebec City
1999 Rapporteur Banff Workshop Session #4B: Risk Management and Assessment
1999 Committee member: NACE Northern Area Eastern Conference and Exhibition, October 24-
27, 1999, Ottawa.
1998 Vice-Chairman: NACE T-3U, “Computers in Corrosion”
1998-2001 Education Chairman, NACE Canadian National Capital Section (CNCS). Organised six
NACE Courses with over 75 students from Canada, U.S., Trinidad, and Saudi Arabia
1998 Instructor, CIM (The Canadian Institute for Mining, Metallurgy, and Petroleum) Course:
Corrosion and Corrosion Control in Pipelines, Calgary
QUOTED IN OIL AND GAS COMPANY WEBPAGES
2014 “Fact Vs Fiction: Dispelling the Myths of Transporting Dilbit”, Enbridge, March 24, 2014,
http://blog.enbridge.com/2014/March/Dilbit-safe-for-pipelines.aspx, ““We did not see any
difference whatsoever. We could not differentiate it from other types of oil,” research
scientist Sankara Papavinasam, a research scientist with Natural Resources Canada, told the
Globe and Mail in November 2012”.
2012 “Science Trumps Fiction on Oil Sands Corrosion Claims” ExxonMobil Perspectives, Nov.
29, 2012, http://www.exxonmobilperspectives.com/2012/11/29/science-trumps-fiction-on-
oil-sands-corrosion-claims-2/ “…According to lead researcher Sankara Papavinasam,
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quoted in The Globe and Mail, “We did not see any difference whatsoever” between crude
oil from oil sands and other crudes…”.
MEMBERSHIP
2008-Cont. Canadian Standard Association (CSA) – Pipeline Coating Technical Sub Committee on CSA
Z245.20 (Fusion-bonded epoxy), Z245.21 (Polyolefin), Z245.22 (Insulator), and Z245.30
(Field-applied coatings) standards.
2001-Cont. SSPC (The Society for Protective Coatings)
1999-Cont. ASTM International
1997-Cont. The Electrochemical Society, Inc.
1996-Cont. NACE International
CONFIDENTIAL/CLIENT REPORTS
Written over 100 confidential/client reports to several oil and gas production and transmission pipelines as
well as their service companies including: Gas Technology Institute, Pipeline Research Council
International, EnCana (Cenovus/Pan Canadian)*, Enbridge Pipelines*, Mobil Oil Canada*, TransCanada
Pipelines, Imperial Oil, AEC Pipelines*, Chevron, Gulf Canada Limited, Saudi Aramco, Southern California
Gas Company, Consumer Gas, El Paso Corporation, Dominion Transmission Inc., Devon Canada
Corporation*, Petro Canada, Numac, Korean Gas Corporation, Nalco Energy Chemicals*, Baker Petrolite,
Shaw Pipe Protection*, Specialty Polymer Coatings (SPC)*, Suncor Energy*, 3M Canada, Reilly Industries,
CANUSA, PolyGuard, Denso, Polythermic, and OZ Industries.
*Mutliple reports/projects
Client reports and their titles are confidential in nature, but some generic topics of reports are listed below:
1. Review of design, materials, and operational conditions to develop internal corrosion flow diagram for an
oilsand extraction facility (2015)
2. Review of operational and monitoring history of oilsands production facility (SAGD) and develop
potential damage mechanisms, internal corrosion types, and corrosion rate (2015)
3. Contribute to the development of corrosion control document to manage corrosion of oilsand production
(SAGD) facility (2015)
4. Review of materials for an oilsand production (SAGD) facility and recommended appropriate materials
based on experience gained in similar facility (referred to as equivalency study); creation of corrosion
loop circuits and recommendation of locations for sampling and monitoring activities for integrity
operational window (IOW) monitoring (2014)
5. Review of the corrosion characteristics of oilsand production (SAGD) facility (2014)
6. Elucidation of corrosivity and inhibitory nature of crude oils under oil transmission pipeline operating
conditions (2014)
7. Review and comment on application submitted to Regulatory Board to construct and operate oil
transmission pipeline (internal corrosion control portion of submission only) (2012)
8. Review and comment on application submitted to Regulatory Board to construct and operate gas
transmission pipeline (external and internal corrosion control portion of submission only) (2012)
9. Elucidation of corrosivity and inhibitory nature of crude oils under pipeline operating conditions (2012)
10. Investigation on the effect of operating temperature variations on internal corrosion rates of oil
transmission pipeline (2011)
11. Examination of the effect of sulfate-reducing bacteria (SRB) on internal corrosion rate of oil transmission
pipeline (2011)
12. Analysis of data-trend from internal corrosion monitoring techniques on oil transmission pipelines (2010)
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13. Evaluation of inline inspection data from three different runs performed over a 4-year time interval in an
oil transmission pipeline (2010)
14. Development of corrosion rate prediction based on field data analysis of oil transmission pipelines (2000)
15. Analysis of field operating condition variations of oil and gas production pipelines and their effects on
internal corrosion (2000)
16. Validation of internal corrosion prediction model using field data obtained from oil and gas production
facilities (2000)
17. Development of a method for controlling pitting corrosion of high water-cut and multiphase oil and gas
production pipelines based on field operating conditions (1998)
18. Analysis of internal corrosion failure incidences of oil and gas production pipelines (1998)
19. Elucidation of correlation between external pipeline coating performance and corrosion and stress-
corrosion cracking susceptibility (1998)
20. A 10-year assessment of performance of external coatings and cathodic protection of gas transmission
pipelines (1998)
21. A 5-year assessment of performance of external coatings and cathodic protection of oil transmission
pipelines (1998)
22. Review of pipeline failure analysis reports and identification for opportunities to improve performance
(1996)
PUBLICATIONS
BOOKS
1. S. Papavinasam, “Corrosion Control in the Oil and Gas Industry”, 1,020 pages (October 2013), Gulf
Professional Publication (Imprint of Elsevier), ISBN: 978-0-1239-7022-0.
2. “Corrosivity of Crude Oil under Pipeline Operating Conditions”, Ed. S. Papavinasam, J. Kish, S.
Williamson, J. Been, B. Buchanan, and D. Boisvert, 168 pages (2012), NACE International, ISBN: 157-
590-2575
3. “Advances in Electrochemical Techniques for Corrosion Monitoring and Measurement”, Ed. S.
Papavinasam, N. Berke, and S. Brossia, 240 pages (2009), ASTM International Publication, STP 1506,
ISBN: 978-0-8031-5522-0
BOOK CHAPTERS
1. S. Papavinasam, Chapter 3, “Corrosion Management” in Trends in Oil and Gas Corrosion Research and
Technologies – Production and Transmission” Ed. A.M. El-Sherik, Woodhead Publishing Limited
(Imprint of Elsevier), ISBN 978-0-08-101105-8, P. 53-77 (2017).
2. S. Papavinasam, Chapter 28, “Advancements in Modelling and Prediction – Pitting Corrosion” in Trends
in Oil and Gas Corrosion Research and Technologies – Production and Transmission” Ed. A.M. El-
Sherik, Woodhead Publishing Limited (Imprint of Elsevier), ISBN 978-0-08-101105-8, P. 663-688
(2017).
3. S. Papavinasam, Chapter 3: “Electrochemical Polarization Techniques”, in “Techniques for Corrosion
Monitoring”, Ed. L.Yang, Woodhead Publishing Limited, ISBN, 1-84569-187-3, p.47 to 85 (2008).
4. S. Papavinasam, Chapter 14: “Rotating Cage and Jet Impingement Techniques”, in “Techniques for
Corrosion Monitoring”, Ed. L.Yang, Woodhead Publishing Limited, ISBN, 1-84569-187-3, p.322 to 343
(2008).
5. S. Papavinasam, Chapter 59, “Corrosion Inhibitors” Uhlig’s Corrosion Handbook, Ed. R.W. Revie, ISBN
0-471-15777-5, John Wiley & Sons, Inc, N.Y. 2000, p.1089-1105.
6. S. Papavinasam, Chapter 67, “Evaluation and Selection of Corrosion Inhibitors” Uhlig’s Corrosion
7
Handbook, Ed. R.W. Revie, ISBN 0-471-15777-5, John Wiley & Sons, Inc, N.Y., 2000, p.1169.
PATENTS
1. S. Papavinasam, D. Gould, R.W. Revie, A. MacLeod, and M. Attard, “Biological Activity Probe for the
Detection of Sulphide and Sulphide Producing Microorganisms”, Canadian Patent, 2,376,549, January 5,
2010.
2. S. Papavinasam, D. Gould, A. MacLeod, R.W. Revie, and M. Attard, “Biological Activity Probe”, U.S.
Patent 6,673,222, January 6, 2004.
INTERNAL CORROSION CONTROL - PAPERS
Modeling
1. L. Yan, X. Pang, S. Papavinasam, N. Zaver, M. Arafin, “Material-Biodiesel Compatibility – Survey of
Industry Experience”, NACE Corrosion Conference 2017, paper #: 9434.
1. S. Malarvizhi, R. Shyamala, and S. Papavinasam, “Assessment of Microbiologically Influenced
Corrosion of Metals in Biodiesel from Jatropha Curcas”, CORROSION 2015, Paper #5772, NACE
International, Houston, TX (2015).
2. A. D. Turris, M.D. Romero, S. Papavinasam, and L. Ocando, “Synergistic Effect of Sulphate-Reducing
Bacteria and CO2 on the Corrosion of Carbon Steel and Chemical Treatment to Control it”,
CORROSION 2014, Paper #3749, NACE International, Houston, Texas (2014).
3. K.R. Kanimozhi, R. Shyamala, S. Papavinasam, and J. Li, “Effect of Sodium Chloride Concentration on
the Corrosion of Carbon Steels and Stainless Steels in CO2 Environment at Atmospheric Pressure under
Turbulent Flow Condition" CORROSION 2014, Paper #4074, NACE International, Houston, Texas
(2014).
4. K.R. Kanimozhi, R. Shyamala, S. Papavinasam, and J. Li, “Effect of Monoethanolamine (MEA) on the
Corrosion Rates of Carbon Steels and Stainless Steels in CO2 Saturated NaCl Solutions " CORROSION
2014, Paper #4241, NACE International, Houston, Texas (2014).
5. T. Haile, S. Papavinasam, and T. Zintel, “Validation of Corrosion Models using Field Data obtained from
Oil and Gas Production Pipelines”, CORROSION 2013, Paper #2170, NACE International, Houston,
Texas (2013).
6. A.D. Turris, M. D. Romero, S. Papavinasam, and R. Lastra, “Effect of SRB, CO2, crude oil, and
chemical treatment on the corrosiveness of synthetic produced water”, CORROSION 2013, Paper #2213,
NACE International, Houston, Texas (2013).
7. J. Collier, S. Papavinasam, and C. Shi, “Corrosion Performance of Automotive Fuel Tank Steel Systems
in Biodiesel”, CORROSION 2013, Paper #2356, NACE International, Houston, Texas (2013).
8. J. Collier, S. Papavinasam, J. Li, C. Shi, P. Liu, and J.P. Gravel, “Effect of Impurities on the Corrosion
Performance of Steels in Supercritical CO2”, CORROSION 2013, Paper #2357, NACE International,
Houston, Texas (2013)
9. X. Landry, A. Runstedtler, S. Papavinasam, and T.D. Place, “Computational Fluid Dynamics Study of
Solids Deposition in heavy Oil Transmission Pipeline”, Corrosion 68(10), p. 904-912 (2012).
10. S. Papavinasam, J.Li, A. Doiron, J.P. Gravel, K. Zanganesh, D. Emadi, C. Salvador, A. Shafeen, and A.
Pratt, “Materials Issues in CO2 Capture, Transport, and Storage Infrastucture”, CORROSION 2012,
Paper #1259, NACE International, Houston, TX (2012).
11. S. Papavinasam, A. Doiron, and T. Panneerselvam, “Integration of Localized Internal Pitting Corrosion
and Flow Models”, CORROSION 2012, Paper #23794, NACE International, Houston, TX (2012).
12. A.D. Turris, M. De Romero, T. Haile, S. Papavinasam, and D. Gould, “Correlation between the growth
of a mixed culture of SRB isolated from produced water and the corrosion of carbon steel”,
CORROSION 2012, Paper #1126, NACE International, Houston, TX (2012).
13. A. Runstedtler, S. Papavinasam, and T.D. Place, “Solids Deposition Modeling for Heavy Oil
8
Transmission Pipelines”, Paper #1, NACE Northern Area Eastern Conference Proceedings, “Corrosivity
of Crude Oil under Pipeline Operating Condition”, NACE International, ISBN: 1-57590-257-5, Houston,
TX (2012).
14. S. Papavinasam, P. Rahimi, and S. Williamson, “Corrosion Conditions in the Path of Bitumen from Well
to Wheel”, Paper #2, NACE Northern Area Eastern Conference Proceedings, “Corrosivity of Crude Oil
under Pipeline Operating Condition”, NACE International, ISBN: 1-57590-257-5, Houston, TX (2012).
15. J. Collier, S. Papavinasam, J. Li, C. Shi, P. Liu, and M. Podlesny, “Comparison of Corrosivity of Crude
Oils using Rotating Cage Method”, Paper # 6, NACE Northern Area Eastern Conference Proceedings,
“Corrosivity of Crude Oil under Pipeline Operating Condition”, NACE International, ISBN: 1-57590-
257-5, Houston, TX (2012).
16. A. D. Turris, S. Papavinasam, M. De Romero, R. Lastra, and W.D. Gould, “Effect of Venezuelan Crude
Oil on the Corrosivity of Synthetic Produced Water with SRB and CO2”, Paper #9, , NACE Northern
Area Eastern Conference Proceedings, “Corrosivity of Crude Oil under Pipeline Operating Condition”,
NACE International, ISBN: 1-57590-257-5, Houston, TX (2012).
17. S. Papavinasam, J. Li, A. Doiron, K. Zanganesh, D. Emadi, C. Salvador, A. Shafeen, and A. Prett,
“Materials Issues in CO2 Capture, Transport, and Storage Infrastructure, NACE, Northern Area Western
Conference, Feb. 6-8, 2011, Regina, Saskatchewan, Paper #1.
18. M.H.N. Paramesh, A. Anand, S.R. Krishnamurthy, S.R. Mani, and S. Papavinasam, “Corrosivity of
Pongamia Pinnata Biodiesel-Diesel Blends on a Few Industrial Metals”, Paper #: 18171, NACE 2011,
Houston, Texas.
19. A. Anand, M.H.N. Paramesh, S.R. Krishnamurthy, S.R. Mani, and S. Papavinasam, “Compatibility of
Metals in Jatrupha Oil”, Paper #18172, NACE 2011, Houston, Texas.
20. S. Papavinasam, A. Doiron, and R.W. Revie, “Model to Predict Internal Pitting Corrosion of Oil and Gas
Pipelines”, Corrosion 66 (3), 2010, p. 35006 (11 pages).
21. S. Papavinasam, J. Krausher, M. Paramesh, A. Anand, S. Mani, and S. Krishnamurthy, “Materials
Compatibility in Biofuels”, 218th Electrochemical Society (ECS) Meeting in Las Vegas, Nevada
(October 10 - 15, 2010)
22. S. Papavinasam, A. Doiron, J. Li, D.Y. Park, and P. Liu, “Sour and Sweet Corrosion of Carbon Steel:
General or Pitting or Localized or All of the Above?, NACE Corrosion Conference 2010, Paper #14054.
23. H.N. Meenaski, A. Anisha, R. Shyamala, R. Saratha, and S. Papavinasam, “Corrosion of Metals in
Biodiesel from Pongamia Pinnata”, NACE CORROSION 2010, Paper #14143.
24. S. Papavinasam, A. Doiron, and R.W. Revie, “Effect of Surface Layers on the Initiation of Internal
Pitting Corrosion in Oil and Gas Pipelines, Corrosion 65 (10), 2009, p.663-673.
25. R.D. Kane and S. Papavinasam, “Corrosion and SCC issues in Fuel Ethanol and Biodiesel”, NACE
CORROSION 2009, Paper #9528.
26. A. Demoz, S. Papavinasam, O. Omotoso, K. Michaelian, and R.W. Revie, “Effect of Field Operational
Variables on Internal Pitting Corrosion of Oil and Gas Pipelines, Corrosion 65 (11), 2009, p.741-747.
27. W. Sun, S. Nesic, and S. Papavinasam, “Kinetics of Corrosion Layer Formation. Part 2: Iron
Sulfide/Carbonate Layers in Carbon dioxide/Hydrogen Sulphide Corrosion”, Corrosion 64 (7), 2008,
p.586-599.
28. S. Papavinasam, A. Demoz, K. Michaelian, and R.W. Revie, “Further Validation of Internal Pitting
Corrosion Model”, Paper #08642, New Orleans, March 16-20, NACE, Houston, Texas, 2008.
29. R. Sooknah, S. Papavinasam, and R. W. Revie, “Validation of a Predictive Model for Microbiologically
Influenced Corrosion”, NACE 2008, Paper 8503, Houston, Texas.
30. S. Papavinasam, A. Doiron, V. Sizov, and R.W. Revie, “A Model to Predict Internal Pitting Corrosion of
Oil and Gas Pipelines (Part 1), Oil and Gas Journal, 105.44, Nov.26, 2007, pages 68-73.
31. S. Papavinasam, A. Doiron, V. Sizov, and R.W. Revie, “A Model to Predict Internal Pitting Corrosion of
Oil and Gas Pipelines (Part 2), Oil and Gas Journal, 105.45, Dec. 2007, pages 62-67.
9
32. S. Papavinasam, A. Doiron, and R.W. Revie, “Empirical Equations to Predict Conditions for Solid
Deposition”, Materials Performance, 46 (8), 2007, p.58-60.
33. S. Papavinasam, A. Doiron, T. Panneerselvam, and R.W. Revie, “Effect of Hydrocarbons on the Internal
Corrosion of Oil and Gas Pipelines” Corrosion 63 (7), 2007, 704-712.
34. R. Sooknah, S. Papavinsam, and R.W. Revie, “Modelling the Threat of Microbiologically Influenced
Corrosion”, Corrosion 2007, Paper #7515.
35. S. Papavinasam, A. Doiron, and R.W. Revie, “A Model to Predict Internal Pitting Corrosion of Oil and
Gas Pipelines”, Corrosion 2007, Paper #7658.
36. S. Papavinasam, R. W. Revie, W. Friesen, A. Doiron and T. Panneerselvam, “Review of Models to
Predict Internal Pitting Corrosion of Oil and Gas Pipelines”, Corrosion Reviews, 24 (3–4), 173–230
(2006).
37. S. Papavinasam and R. W. Revie, “Integrity Management: Internal corrosion control”, CORROSION
2006, Paper #6187, March 12-19, 2006.
38. S. Papavinasam and R. W. Revie, “Predicting Internal Pitting Corrosion of Oil and Gas Pipelines:
Hydrocarbon-Wet to Water-Wet Transition”, CORROSION 2006, Paper #6641, March 12-19, 2006.
39. W. Sun, S. Nesic, and S. Papavinasam, “Kinetics of Iron Sulfide and Mixed Iron Sulfide/carbonate scale
Precipitation in CO2/H2S Corrosion”, CORROSION 2006, Paper #6644, March 12-19, 2006.
40. S. Papavinasam, W. Friesen, R.W. Revie, A. Doiron, “Predicting Internal Pitting Corrosion of Oil and
Gas Pipelines: A Corrosion Engineering Approach”, Corrosion 2005, Paper #05643, NACE, Houston,
Texas, 2005.
41. S. Papavinasam, R.W. Revie, A. Doiron, “Predicting Internal Pitting Corrosion of Oil and Gas pipelines:
Review of Electrochemical Models”, Corrosion 2005, Paper #05644, NACE, Houston, Texas, 2005.
42. S. Papavinasam, R.W. Revie, A. Doiron, “Predicting Internal Pitting Corrosion of Oil and Gas Pipelines:
Review of Corrosion Science Models”, Corrosion 2005, Paper #05645, NACE, Houston, Texas, 2005.
Mitigation
1. S. Papavinasam, “Standards for Evaluating Oil Field Corrosion Inhibitors in the Laboratory”,
CORROION 2014, Paper #: 3980, Houston, TX, USA (2014).
2. A. Runstedtler, S. Papavinasam, E. Chui, “Computational Fluid Dynamics Model of Wall Shear Stress in
Rotating Cage Experiment and Correlation with Corrosion Rate”, 17th International Corrosion
Conference (ICC), Oct.6-10, 2008, Los Vegas.
3. S. Papavinasam, R.W. Revie, T. Panneerselvam, and M. Bartos, “Laboratory Evaluation of Oilfield
Corrosion Inhibitors”, Materials Performance 46 (5), 2007 p.46-48.
4. S. Taj, A. Siddekha, S. Papavinasam, and R.W. Revie, “Some Natural Products as Green Corrosion
Inhibitors”, Corrosion 2007, Paper # 7630.
5. S. Taj, S. Papavinasam and R. W. Revie, Evaluation of Green Inhibitors”, CORROSION 2006, Paper
#6656, March 12-19, 2006.
6. A. Demoz, T. Dabros, K.H. Michaelian, S. Papavinasam, and R.W. Revie, “A New Impinging Jet for
Corrosion Studies”, Corrosion 60(5), p.455 (2004).
7. S. Papavinasam, A. Doiron, G. Shen, and R. W. Revie, “Prediction of Inhibitor Behaviour in the Field
from Data in the Laboratory”, NACE/2004, paper #04622, Houston, March 2004
8. S. Papavinasam, R.W. Revie, and M. Bartos, Testing Methods and Standards for Oilfield Corrosion
Inhibitors, NACE/2004, Paper No. 4424, Houston, March 2004.
9. S. Papavinasam and R.W. Revie, “Review of Testing Methods and Standards for Oilfield Corrosion
Inhibitors” EUROCORR 2004, Long Term Prediction & Modelling of Corrosion "12 - 16 September
2004, NICE, France
10. S. Papavinasam, M. Attard, R.W. Revie, A. Demoz, and K. Michaelian, Comparison of Laboratory
Methodologies to Evaluate Corrosion Inhibitors for Oil and Gas Pipelines, NACE Corrosion, 59(10), p.
10
897 (2003).
11. S. Papavinasam, A. Doiron, and R.W. Revie, “Effect of Rotating Cage Geometry on Flow Pattern and
Corrosion Rate” NACE/2003, Paper No. 3333, Houston, March 2003.
12. A. Demoz, T. Dabros, K. Michaelian, S. Papavinasam, and R.W. Revie, “A New Impinging Jet Device
for Corrosion Studies”, NACE/2003, Paper No. 3322, Houston, March 2003.
13. S. Papavinasam, A. Doiron and R.W. Revie, “Evaluation of Green Inhibitors”, IPC2002, October 6-10,
2002, ASME, Calgary, AB, Canada.
14. S. Papavinasam, M. Attard, R.W. Revie, and J. Bojes, “Rotating Cage - A Compact Laboraotry
Methodology for Simultaneously Evaluating Corrosion Inhibition and Drag Reducing Properties of
Chemicals”, NACE/2002, Paper No. 2271, Houston, April 2002.
15. S. Papavinasam, R.W. Revie, A. Demoz and K. Michaelian, “Comparison and Ranking of Techniques
for Monitoring General and Pitting Corrosion Rates Inside Pipelines”, NACE/2002, Paper No. 2495,
Houston, April 2002.
16. S. Papavinasam, R.W. Revie, M. Attard, A. Demoz, J.C. Donini, and K. Michaelian, “Rotating Cage:
Top Ranked Laboratory Methodology for Inhibitor Evaluation and Qualification for Pipeline
Applications” NACE/2001, Paper No. 1061, Houston, March 2001.
17. S. Papavinasam, R.W. Revie, M. Attard, A. Demoz, H. Sun, J.C. Donini, and K. Michaelian, “Laboratory
Methodologies for Corrosion Inhibitor Selection”, Materials Performance, 39 (2000) p.58.
18. S. Papavinasam, R.W. Revie, M. Attard, A. Demoz, J.C. Donini, and K. Michaelian, “Standardized
Methodology For Inhibitor Evaluation And Qualification For Pipeline Applications”, IPC2000, Vol.1,
901, October 1-5, 2000, ASME, Calgary, AB, Canada.
19. S. Papavinasam, R.W. Revie, M. Attard, A. Demoz, H. Sun, J.C. Donini, and K. Michaelian, “Inhibitor
Selection for Internal Corrosion Control of Pipelines: Comparison of Rates of General Corrosion and
Pitting Corrosion under Gassy-Oil Pipeline Conditions in the Laboratory and in the Field”, NACE/2000,
Paper No. 55, Orlando, March 2000.
20. S. Papavinasam, R. W. Revie, M. Attard, A. Demoz, H. Sun, J. C. Donini, and K. Michaelian, Inhibitor
Selection for Internal Corrosion Control of Pipelines: 1. Laboratory Methodologies, Paper No. 1,
CORROSION/99, NACE International, Houston, Texas.
21. S. Papavinasam and R.W. Revie , “Synergistic Effect of Pressure And Flow on Corrosion Rates: Studies
Using High-temperature, High-pressure Rotating Electrode System”, Paper No. 30, CORROSION/99,
NACE International, Houston, Texas.
22. S. Papavinasam and R. W. Revie, Inhibitor Selection for Internal Corrosion Control of Pipelines,
Proceedings, International Pipeline Conference, Calgary, Alberta, Canada, American Society of
Mechanical Engineers, New York, 1998, Vol. 1, p. 225.
23. S. Papavinasam and R. W. Revie, High-Temperature, High-Pressure Rotating Electrode System,
International Pipeline Conference, Calgary, Alberta, Canada, American Society of Mechanical
Engineers, New York, 1998, Vol. 1, p. 341.
24. A. Demoz, J.C. Donini, S. Papavinasam, and W. Revie, “Lessons learned from an instrumented field
corrosion test loop” International Pipeline Conference, Calgary, Alberta, Canada, American Society of
Mechanical Engineers, New York, 1998, Vol. 1, p. 521.
Monitoring
1. B. Hedges, S. Papavinasam, K. Sprague, and T. Knox, “Monitoring and Inspection Techniques for
Corrosion in the Oil and Gas Production”, CORROSION 2015, Paper #5503, NACE International,
Houston, TX (2015).
2. T. Haile, S. Papavinasam, and D. Gould, “Evaluation of a Portable Online 4-Probe Sensor for
Simultaneous Monitoring of Corrosion Rate and SRB Activity”, CORROSION 2013, Paper # 2148,
NACE International, Houston, TX (2013).
11
3. S. Papavinasam, A. Doiron, and R.W. Revie, “Industry Survey on Techniques to Monitor Internal
Corrosion”, Materials Performance, 51(2), 2012, p.34.
4. S. Papavinasam, A. Doiron, M. Attard, A. Demoz, and P. Rahimi, “Non-Intrusive Techniques to Monitor
Internal Corrosion of Oil and Gas Pipelines”, CORROSION 2012, Paper #: 2012-1261, NACE
International, Houston, TX (2012).
5. T. Haile, S. Papavinasam, and W.D. Gould, “Further Evaluation of an Online Probe for Simultaneous
Monitoring of Corrosion Rate and SRB Activity: Influence of FeS Surface Layer”, Paper #18439, NACE
2011, Houston, Texas.
6. S.Soleimani, B.Ormeci, O.B. Isgor, and S. Papavinasam, “Evaluation of biofilm performance as a
protective barrier against biocorrosion using an enzyme electrode”, Water Science and Technology, IWA
Publishing 2011, 64.8, p.1736-1742.
7. T. Haile, R.Sooknah, S. Papavinasam, D. Gould, and O.Dinardo, “Simultaneous Online Monitoring of
SRB Activity and Corrosion Rate, NACE Corrosion Conference 2010, Paper #14183.
8. A. Demoz, S. Papavinasam, K. Michaelian, and R.W. Revie, ``Measurement of Corrosion Potentials of
the Internal Surface of Operating High-Pressure Oil and Gas Pipelines``, Journal of ASTM International,
Vol.5, No.6, Paper ID JAI 101244.
9. S. Papavinasam, A. Doiron, and R.W. Revie, “Abnormal Reading in Ultrasonic Measurement: Is it
Abnormal Growth of an Internal Pit or Measurement Error`` Materials Performance, Materials
Performance 47 (1), 2008, p .58-62.
10. R. Sooknah, S. Papavinasm, M. Attard, R.W. Revie, W.D. Gould, and O. Dinardo, “An Electrochemical
Biosensor Designed for Online Monitoring of Sulfate Reducing Bacteria”, Journal of ASTM
International, 5 (6), June 2008, Pages 10.
11. R.Sooknah, S. Papavinasam, and R.W. Revie, “A Sulfide Oxidase Biosensor for Monitoring Sulfide”,
NACE 2008, Paper 8656, Houston, Texas.
12. R.Sooknah, S.Papavinsam, and R.W. Revie, “Monitoring Microbiologically Influenced Corrosion: A
Review of Techniques”, Corrosion 2007, Paper #7517.
13. S. Papavinasam, M. Attard, R.W. Revie, A. Demoz, and K. Michaelian, Comparison of Techniques for
Monitoring Corrosion Inhibitors in Oil and Gas Pipelines, NACE Corrosion, 59(12), p.1096 (2003).
14. A. Demoz, K.H. Michaelian, J.C. Donini, S. Papavinasam, and R.W. Revie, “Corrosion Monitoring
Methods Evaluated on Gathering Lines,” Pipeline & Gas Industry, 84(10), p.48 (2001).
15. M. Attard, S. Papavinasam, R.W. Revie, A. Demoz, H. Sun, J.C. Donini, and K. Michaelian,
“Comparison of Pitting Corrosion Rates of Coupons with those of Pipe”, Materials Performance 39, #10
(2000) 58.
16. H. Sun, J.C. Donini, S. Papavinasam, and R.W. Revie, “Application of Quartz Crystal Microbalance to
Corrosion Investigation”, International Pipeline Conference”, Calgary, Alberta, Canada, American
Society of Mechanical Engineers, New York, 1998, Vol. 1, p. 215.
Management
1. S. Papavinasam, “Towards Zero”, World Pipelines – Coatings and Corrosion 2017”, October 2017.
2. S. Papavinasam, “Key Performance Indicators for Effective and Economical Corrosion Control” NACE
Corrosion Conference 2017, paper #: 8823.
3. S. Papavinasam, “Inspection, Monitoring, and Model: Past, Present, and Future”, CorCon 2017,
September 17-20, 2017, Mumbai, India (NACE International)
12
4. S. Papavinasam, “The 5-M Methodology to Control Internal Corrosion of the Oil and Gas Production
Infrastructure” 15th Middle East Corrosion Conference, Paper # 14188, Bahrain, Feb. 2-5, 2014.
5. S. Papavinasam, “Managing Internal Corrosion and Public Perception of Oil Transmission Pipelines”,
Paper #10, NACE Northern Area Eastern Conference Proceedings, “Corrosivity of Crude Oil under
Pipeline Operating Condition”, NACE International, ISBN: 1-57590-257-5, Houston, TX (2012).
6. S. Papavinasam, A. Doiron, and R.W. Revie, “A New Method for Pipeline Integrity Management”,
Materials Performance, 46 (1), 2007, p.42-44.
EXTERNAL CORROSION CONTROL - PAPERS
Modeling
1. S. Papavinasam, T. Panneerselvam, and A. Doiron, “Applicability of Cathodic Protection for
Underground Infrastructures Operating at Sub-Zero Temperatures”, Corrosion Journal 69 (9), 2013,
p.936-945.
2. S. Papavinasam, N. Zaver, M. Matchim, T. Pannerselvam, C. DrRushie, A. Doiron, and J. Pollock,
“Laboratory Methodologies to Evaluate the Compatibility between Mainline and Girthweld Coatings”,
NACE CORROSION 2013, Paper #2176, Houston Texas.
3. S. Papavinasam and M. Matchim, “Compatibility between Pipeline Anti-corrosion Coating and Thermal
Insulator in the Presence of Cathodic Protection”, NACE CORROSION 2013, Paper #2175, Houston
Texas.
4. S. Papavinasam and M. Matchim, “Compatibility between Concrete Coatings, Mainline Coating, and CP
System”, NACE CORROSION 2013, Paper #2174, Houston Texas.
5. S. Papavinasam and A. Doiron, “A 5-M Approach to Control External Pipeline Corrosion” NACE
CORROSION 2010, Paper #14151, Houston Texas.
6. S. Papavinasam and A. Doiron, ``Relevance of Cathodic Disbondment Test for Evaluating External
Pipeline Coatings at Higher Temperatures, NACE Corrosion Conference, 2009, Paper No. 9050,
Houston, TX (2009)
7. S. Papavinasam and A. Doiron, ``Methodologies for Evaluating and Qualifying External Pipeline
Coatings for Northern Pipelines``, NACE Corrosion Conference, 2009, Paper No. 9051, Houston, TX
(2009).
8. S. Papavinasam, M. Attard, and R.W. Revie, “Laboratory Methodologies to Simulate Field Operating
Conditions of External Pipeline Coatings”, Journal of Protective Coatings and Lining (February 2009).
9. S. Papavinasam and A. Doiron, “Relevance of Cathodic Disbondment Test for Evaluating External
Pipeline Coatings at Higher Temperatures”, Corrosion 2009/#4561 (March 2009.
10. S. Papavinasam and A. Doiron, “External Corrosion Control of Northern Pipelines: Influence of
Construction Conditions on the Performance of Coatings”, Corrosion 2009/#4563 (March 2009).
11. S. Papavinasam, A. Doiron, and T. Panneerselvam, “External Corrosion Control of Northern Pipelines”,
Proceedings of International Pipeline Conference (IPC 2008), IPC2008-64069 (Ranked among the top 30
papers presented at IPC 2008).
12. S. Papavinasam R. W. Revie, “Evaluating protective coatings”, Pipe Line and Gas Technology,
September 2007.
13. S. Papavinasam, M. Attard, and R.W. Revie, “Performance Evaluation of External Polymeric Coatings
for Pipeline Protection” Corrosion 2007, Paper #7021.
14. S. Papavinasam, M. Attard, and R. W. Revie, “Modes of failures of external polymeric pipeline
coatings,” Materials Performance, 45 (10), 28–30 (2006).
15. S. Papavinasam and R. W. Revie, “Protective Pipeline Coating Evaluation”, NACE CORROSION 2006,
Paper #6047, San Diego, March 12-17, 2006.
16. S. Papavinasam, A. Doiron, T. Panneerselvam, Y. Lafrenière, M. Attard, C. Derushie, R. Bouchard, B.
13
Eagleson, and R. W. Revie, Methodologies for evaluating and qualifying external pipeline coatings for
northern pipelines", Proceedings of IPC 2006, IPC2006-10347, 6th International Pipeline Conference,
Sept. 25-29, 2006, Calgary, AB, Canada.
17. S. Papavinasam, R.W. Revie, and M. Attard, “Selection of External Coatings for Northern Pipelines:
Laboratory Methodologies for Evaluation and Qualification of Coatings”, International Pipeline
Conference, IPC04-0244, ASME Publication (2004).
Mitigation
1. S. Papavinasam, B. Arsenault, M. Attard, and R.W. Revie (2012), “Metallic Under-Layer Coating as
Third Line of Protection of Underground Oil and Gas Pipelines from External Corrosion” Corrosion,
Vol. 68 (12), pp. 1146-1153 (2012).
2. S. Papavinasam, N. Zaver, and J. Pollock, “Comparison of International Standards to Evaluate Field-
Applied Pipeline Girth-Weld Coatings”, Corrosion Reviews, 30 (5-6), 2012, p. 171-197.
3. S. Papavinasam, J. Krausher, P. Ghods, and O.B. Isgor, “Evaluation of Compatibility between Thermal
Insulator, External Coating, and Cathodic Protection at 150oC”, Paper #18649, NACE 2011, Houston,
Texas.
4. S. Papavinasam and R.W. Revie, “Review of Standards for Evaluating Coatings to Control External
Corrosion of Pipelines”, Corrosion Reviews, 26 (5-6), 2008, p.295-370
5. S. Papavinasam, M. Attard, R.W. Revie, “Evoluation of External Pipeline Coatings for Corrosion
Protection – A Review”, Corrosion Reviews, 26 (5-6), 2008, p.371-438.
6. S. Papavinasam, M. Attard, B. Arseneult, and R.W. Revie, “State-of-the-art of Thermal Spray Coatings
for Corrosion Protection”, Corrosion Reviews, 26 (2-3), 2008, p.105-146.
7. S. Papavinasam and R.W. Revie, “Pipeline Protective Coating”, “Advanced Coatings R&D for Pipelines
and Related Facilities”, June 9-10, 2005, National Institute of Standards and Technology (NIST), NIST
Special Publication 1044, September 2005.
8. S. Papavinasam and R.W. Revie, Pipeline Coatings, White Paper, Proceedings, International Workshop
on Advanced Research & Development of Coatings for Corrosion Protection, Biloxi, Mississippi, April
14-16, 2004
Monitoring
1. S. Papavinasam, M. Attard, and R.W. Revie, “Aboveground Techniques for Monitoring External
Pipeline Coatings” Materials Performance, Vol. 49, 2010, April, pages 44-48.
2. S. Papavinasam, M. Attard, and R.W. Revie, “Electrochemical Impedance Spectroscopy Measurement
During Cathodic Disbondment Experiment of Pipeline Coatings”, Journal of ASTM International, Vol.6,
No.3, Paper ID. JAI 101247.
3. S. Papavinasam, M. Attard, and R.W. Revie, “Electrochemical Quartz Crystal Microbalance Technique
to Monitor Diffusion Through External Polymeric Pipeline Coating”, Journal of ASTM International
Vol.6, No.3, Paper ID. JAI 101246.
4. S. Papavinasam, M. Attard, and R.W. Revie, “Determination of Blister Formation of External Pipeline
Coatings Based on Current Spikes in the Cathodic Disbondment Test”, Corrosion 65 (10), 2009, p. 639-
644.
5. S. Papavinasam, M. Attard, and R.W. Revie, “Aboveground Techniques for Monitoring External
Pipeline Coatings” Materials Performance 49 (4), 2010, p. 44-48
Management
2. S. Papavinasam and A. Doiron, “A 5-M Approach to Control External Pipeline Corrosion”, NACE
Corrosion Conference 2010, paper #: 14151.
14
OTHERS
1. S. Taj, S. Papavinasam, and M.F. Ahmed; “Poly(benzimidazole) and Substituted
Poly(Benzimidazoles): Novel, Electroactive, and Conducting Polymers Possessing High Catalytic
and Coordination Properties”, J.Applied Polymer Science, 77 (2000) 112-115.
2. S. Taj, S. Papavinasam, and M.F. Ahmed, “Relationship between permselectivity and the acidity of
polyphenols pertaining to the pH response of Pt/polyphenol electrode”, Synthetic Metals 97 (1998)
p205-209.
3. N.Ahmed, S. Papavinasam, and G. Nagendrappa, “Electropolymerisation of trimethylsilylphenols to
silylated polyphenylene oxides and investigation of their properties. Enhanced conducitivity of PPO
by silyl group”, Journal of Applied Polymer Science 65 (1997) 1121-1126.
4. S. Taj and S. Papavinasam, “Electropolymerisation of 2-mercaptobentimidazole and electrowinning
of copper”, Bulletin of Electrochemistry, 13 (1997) 213-215.
5. S. Papavinasam, “Kinetics and Mechanism of Electro-polymerisation of m-Cresol in the presence of
Trimethylamine”, European Polymer Journal, 30 (1994) P.55-59.
6. S. Taj, M.F. Ahmed, and S. Papavinasam, “Electro-oxidation of p-chlorophenol and p-bromophenol
in aqueous medium”, J.Chemical Research (S) (1993) P.232-233.
7. S. Papavinasam, “Permeability and Electrocatalytic Properties of Film prepared by
Electropolymerisation of m-Aminophenol”, J. Polymer Science (Part A) Polymer Chemistry, 31,
1993, P.1105-1109.
8. S. Taj, M.F. Ahmed, and S. Papavinasam, Electropolymerisation of m-Cresol in the presence of
Trimethylamine; J.Applied Electrochemistry, 23, 1993, P.247-252.
9. S. Papavinasam, S. Taj, and M.F. Ahmed, Mode of Transport and Electrolysis of Hydroquinone,
Ferrocyanide and Ferrous ions on Poly(m-cresol) Modified Pt Electrode; Bulletin of
Electrochemistry, 9, 1993, P.569-575.
10. S. Papavinasam, Permeability and Electrocatalytic Properties of Film prepared by
Electropolymerisation of m-Aminophenol, Synthetic Metals, 58, 1993, P.173-185.
11. S. Taj, M.F. Ahmed, and S. Papavinasam, Electro-oxidative Polymerisation of m-Chlorophenol and
m-Bromophenol; J. Electroanalytical Chemistry, 356, 1993, P.269-274.
12. S. Taj, M.F. Ahmed, and S. Papavinasam, Permeability of Poly(m-Bromophenol) Modified Pt
Electrode for Electroactive Solutes; Indian J. of Chemistry. Section A, 32, 1993, P.521-524.
13. S. Papavinasam, S. Taj, and M.F. Ahmed, Permeability and Electrocatalytic Properties of Film
prepared by Electropolymerisation of m-Chlorophenol; Bulletin of Electrochemistry, 8, 1992, P.542-
544.
14. S. Papavinasam, F. Pushpanaden, and M.F. Ahmed, Tosylhydrazine and 4-Nitrobenzoylhydrazine as
Corrosion Inhibitors for Pb, Al, and Cu in NaOH; J. Electrochemical Society (India) 41, 1992, P.43-
50; (Received the Best Paper Award for the Year 1992).
15. S. Taj, S. Papavinasam, and M.F. Ahmed, Electro-oxidative Polymerisation of m-Aminophenol;
Synthetic Metals, 52, 1992, P.147-158.
16. S. Papavinasam, and M.F. Ahmed, Benzenethiols as Inhibitors for the Corrosion of Copper;
J.Applied Electrochemistry, 22, 1992, P.390-395.
17. S. Taj, M.F. Ahmed, and S. Papavinasam, Poly (p-Aminophenol): A New Soluble, Electroactive
Conducting Polymers; J.Electroanalytical Chemistry, 22, 1992, P.347-352.
18. S. Papavinasam, F. Pushpanaden, and M.F. Ahmed, “The Effect of some Brighteners on the Kinetics
of Zn-Ni Alloy Electrodeposition from a Chloride Bath”, Bulletin of Electrochemistry, 7, 1991,
P.351-354.
19. S. Papavinasam, and M.F. Ahmed, Piperidine, Piperidones and Tetrahydrothiopyrones as Corrosion
Inhibitors for Copper in Sulphuric Acid; Corrosion Science, 32, 1991, P.193-203.
20. S. Papavinasam, F. Pushpanaden, and M.F. Ahmed, Tosylhydrazine, 4-Nitrobenzoylhydrazine and
15
terephthalylhydrazine as Corrosion Inhibitors for Copper and Aluminum in Sulphuric Acid; J.
Applied Electrochemistry, 21, 1991, P.625-631.
21. S. Papavinasam, F. Pushpanaden, and M.F. Ahmed, Cis and Trans 2,6-
Diphenyltetrahydrothiopyrones as Corrosion Inhibitors for Mild Steel in Sulphuric Acid; Bulletin of
Electrochemistry, 7, 1991, P.14-17.
22. S. Taj, S. Papavinasam, and M.F. Ahmed, Electrooxidative Polymerisation of p-Aminobenzenethiol;
Trans. SAEST, 25, 1990, P.128-130.
23. S. Papavinasam, R.Raghunand, F. Pushpanaden, and M.F. Ahmed, Action of Battery Energizer (Bat-
Max) on the Cycle Life of Lead and its Alloys in sulphuric Acid; Bulletin of Electrochemistry, 6,
1990, P.873-876.
24. S. Papavinasam, F. Pushpanaden, and M.F. Ahmed, Tosylhydrazine as Protector for Lead in Acetic
Acid Vapours; J. Electrochemical Society (India), 39, 1990, P.255-256.
25. S. Papavinasam, F. Pushpanaden, and M.F. Ahmed, Diamines as Inhibitors for Lead in Acetic Acid
Solution; J. Electrochemical Society (India), 39, 1990, P.251-254.
26. S. Papavinasam, F. Pushpanaden, and M.F. Ahmed, Mercaptobenzothiazole and o-
Methoxysalicylaldehyde as Brighteners for Zn-Ni Alloy Electrodeposition from a Chloride Bath;
Metal Finishing, 87, 1989, P.9-11.
27. S. Papavinasam, F. Pushpanaden, and M.F. Ahmed, Dicarboxylic Acids as Inhibitors for the
Corrosion of Lead in Perchloric Acid; Bulletin of Electrochemistry, 5, 1989, P.319-323.
28. S. Papavinasam, F. Pushpanaden, and M.F. Ahmed, Hydrazine and Substituted Hydrazines as
Corrosion Inhibitors for Lead in Acetic Acid Solutions; British Corrosion Journal, 24, 1989, P.39-42.
29. S. Papavinasam, F. Pushpanaden, R.Raghunand and M.F. Ahmed, Bat-Max as Inhibitors for the
Corrosion of Pb-Sb Alloy in Nitric Acid, Acetic Acid, Perchloric Acid and Phosphoric Acid
Solutions; J. Electrochemical Society (India), 37, 1988, P.200-206.
(Received the Best Paper Award for 1988).
16
PROJECTS COMPLETED General Information
S.N
o.
Item Description Details
1. Name of company / firm CorrMagnet Consulting Inc.
2.
Registered address with
Telephone number and fax
6, Castlemore Street
Ottawa, Ontario, Canada K2G 6K8
Phone: 613-843-1717
Cell: 613-240-7520
3.
Contact Person, Designation and
Address including email ID
Sankara Papavinasam, Ph.D. FNACE, FASTM
President
6, Castlemore Street
Ottawa, Ontario, Canada K2G 6K8
Phone: 613-843-1717
Cell: 613-240-7520
Email: [email protected]
4. Length of experience in the field
of consultancy services of
Sankara Papavinasam
24 Years
5 years as President of CorrMagnet Consulting Inc.
19 years as scientific and technical led at
CANMET, Natural Resources Canada
5.
Names and Addresses of
Associated Companies to be
involved in the Project and
whether Parent/Subsidiary/others.
Nil
6.
In case the company is a
subsidiary, the involvement, if
any, of the Parent Company in the
project
Not applicable
7.
State whether the in-house
expertise is available for all
services/sub-systems.
In-house expertise is available
8.
Has the Bidder or any constituent
partner in case of partnership
firm, ever been convicted?
No
17
Specific experience in field of internal corrosion management of liquid hydrocarbon pipelines
S.No. Item Description
Details
Details
1.
Name of assignment Determining Corrosion Conditions
under the Deposits and Effectiveness
of Corrosion Inhibitors in Controlling
Underdeposit Corrosion
2.
Name and address of the
employer
Pipeline Research Council
International
3141 Fairview Park Drive | Suite 525
Falls Church, Virginia 22042 USA
+1-714-441-8744 | mobile +1-714-
882-0352
3.
Start Date (month/year)
Completion date (month/year):
March 2016
October 2017
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Sankara Papavinasam
President
5.
Name of associated Consultants,
if any:
PRCI contract was issued jointly to
CorrMagnet Consulting Inc. and
SouthWest Research Institute. Only
CorrMagnet work is described
6.
Narrative description of Project: The project objectives are to
rigorously evaluate the effectiveness
of various corrosion inhibitors
in mitigating underdesposit corrosion
(UDC), determine conditions leading
to severe corrosion under deposits, and
define conditions in which corrosion
inhibitors can be effectively and
economically used to control severe
UDC in oil transmission pipelines.
7.
Description of actual services
provided by Dr. Sankara
Papavinasam within the
assignment:
Dr. Sankara Papavinasam leads the
following activities:
Documenting the state-of-the-art
from the literature and case studies
from existing field data (from
Enbridge pipelines, TransCanada
Pipelines, ExxonMobil Pipelines,
Shell Pipelines and
ConocoPhillips)
Analysis and review of
experimental data to be produced
at SWRI
Developing a best practices
guidance document for oil
18
transmission pipeline users based
on the experimental results and
field experience in various
companies.
S.No. Item Description
Details
Details
1.
Name of assignment Development of Saudi Aramco’s
Integrated Flow, Internal Localized
Corrosion, MIC, and Solids
(S.Aramco- iFILMS) Software
2.
Name and address of the
employer
Dr. Abdelmounam Sherik
Saudi Aramco
Saudi Arabia
3.
Start Date (month/year)
Completion date (month/year):
January/2014
December/2016
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Sankara Papavinasam
5.
Name of associated Consultants,
if any:
Interlace India Pvt. Ltd develops the
computer program to develop the
software
6.
Narrative description of Project: To develop an user-friendly
software program for exclusive use
of Saudi Aramco to predict
localized internal pitting corrosion
in sour and sweet flow lines and
transmission lines
To validate the software using
Saudi Aramco’s operating
conditions of 5 oil transmission
pipelines.
7.
Description of actual services
provided by Dr. Sankara
Papavinasam within the
assignment:
Version 1: For CAPEX (capital
expenditure) optimisation
Development of scientific model
Field Data Collection and Model
Validation
Software Validation
Training – 2 day on version 1
(completed in Nov. 2015)
Version 2: For OPEX (Operating
expenditure) optimization
Development of scientific model
19
Field Data Collection and Model
Validation
Software Validation
Training – 3 day on version 2
(Planned for October 2016)
S.No. Item Description
Details
Details
1.
Name of assignment Corrosivity and inhibitory nature of
crude oils under pipeline operating
conditions
2.
Name and address of the
employer
Enbridge Pipelines
10201, Jasper Avenue
Edmonton, AB, Canada
3.
Start Date (month/year)
Completion date (month/year):
October 2013
December 2013
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Sankara Papavinasam, President
5.
Name of associated Consultants,
if any:
Enbridge contract was issued to
Cormetrics and Cormetrics issued sub-
contracted to Dr. Sankara
Papavinasam to carry out scientific
and technical analysis.
6.
Narrative description of Project: Elucidate how far the presence of
crude oil can decrease corrosivity of
water phase and correlate the
inhibitory property with properties
(viscosity, density, wettability, and
emulsion forming tendency) of crude
oils. More than 40 crude oils were
evaluated in this work.
7.
Description of actual services
provided by Dr. Sankara
Papavinasam within the
assignment:
Compiled and analysed test results
from Emulsion inversion point,
wettability, and influence of crude
oil on the corrosivity of aqueous
phase.
Developed trend of crude oil
inhibitory effects based on results
from ASTM G205 and of physical
properties (density, total sulphur,
TAN #, and salt content).
20
Development of a preliminary
method to rank crude oils based on
corrosivity/inhibitory properties.
S.No. Item Description
Details
Details
1.
Name of assignment Control of Oil and Gas Pipeline
Internal Corrosion
2.
Name and address of the
employer
Natural Resources Canada, Program of
Energy R and D
580 Booth Street, Ottawa, Ontario,
Canada
The total value of this project is:
540,000 Canadian Dollars.
Predominate oil and gas pipeline
companies involved in this 2-year
project include Enbridge pipelines,
TransCanada Pipelines, and Alliance
Pipelines.
3.
Start Date (month/year)
Completion date (month/year):
Start: April 2011
Completion: March 2013
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Dr. Sankara Papavinasam, Project and
technical lead
Ms. Jennifer Collier, Corrosion
Specialist
5.
Name of associated Consultants,
if any:
Nil
6.
Narrative description of Project: The project identified gaps in the
knowledge in consultation with stake-
holders from the industry, focussed on
filling the gap in the knowledge by
publically sharing the knowledge and
by developing standards
7.
Description of actual services
provided by Dr. Sankara
Papavinasam within the
assignment:
Internal corrosion direct
assessment of liquids pipelines is
advanced by contributing to the
development of NACE Standard
TG 315. Erosion and wear
components are incorporated into
the scientific model.
Methodologies for laboratory
simulation of internal corrosion of
heavy oil (from oil sands)
transportation pipelines are
21
developed. The effect of reservoir
souring (resulting in microbial
activity) on integrity management
of upstream and downstream
pipelines is determined.
The effects of solids (for example,
corrosion products, sand) on
internal pitting corrosion of oil
transmission pipelines are
determined, and control strategies
are developed. The influence of
upstream pipeline activities on
transmission pipeline integrity
management is determined
Techniques for monitoring heavy
oil transportation pipelines are
evaluated. An integrated approach
for controlling internal corrosion
and erosion from well to wheel is
established
Reviewed and commented on the
application submitted to
Regulatory Board to construct and
operate oil and gas transmission
pipelines on behalf of minister of
Natural Resources Canada
(external and internal corrosion
control portion of submission
only) (Mackenzie Valley Gas
Pipeline, Gateway Pipeline, and
Enbridge Line 9 reversal)
Appeared before Canadian Senate
Committee on “Safe
Transportation of Hydrocarbons in
Canada” as subject matter expert
(SME) to explain the inhibitory
nature of crude oil under pipeline
transportation conditions
(http://www.parl.gc.ca/content/sen/
committee/411/ENEV/36EV-
49937-e.HTM)
Appeared before National
Academy of Sciences, Washington
DC, USA to explain inhibitory
nature of crude oils under pipeline
22
transportation conditions, The
National Academies of Press, TRB
Special Report 311: Effects of
Diluted Bitumen on Crude Oil
Transmission Pipelines (2013)
Interviewed by Canadian
Newspaper, Globe and Mail
“Study eats into oil-sands
opponents’ corrosion claims”,
Nov. 23, 2012
(http://www.theglobeandmail.com/
report-on-business/industry-
news/energy-and-resources/study-
eats-into-oil-sands-opponents-
corrosion-claims/article5578801/)
Interviewed by EnergyWire,
Washington DC, “Scientists find
conventional crudes similarly
corrosive to oil sands mix”, Dec.
10, 2012
(http://www.eenews.net/stories/10
59973549)
“Science Trumps Fiction on Oil
Sands Corrosion Claims”
ExxonMobil Perspectives, Nov.
29, 2012,
http://www.exxonmobilperspective
s.com/2012/11/29/science-trumps-
fiction-on-oil-sands-corrosion-
claims-2/ “…According to lead
researcher Sankara Papavinasam,
quoted in The Globe and Mail,
“We did not see any difference
whatsoever” between crude oil
from oil sands and other
crudes…”.
“Fact Vs Fiction: Dispelling the
Myths of Transporting Dilbit”,
Enbridge, March 24, 2014,
http://blog.enbridge.com/2014/Mar
ch/Dilbit-safe-for-pipelines.aspx,
““We did not see any difference
whatsoever. We could not
differentiate it from other types of
oil,” research scientist Sankara
Papavinasam, a research scientist
with Natural Resources Canada,
23
told the Globe and Mail in
November 2012”.
S.No. Item Description
Details
Details
1.
Name of assignment Development of Corrosion and Erosion
Control Strategies of Heavy Oil
Transmission Pipelines
2.
Name and address of the
employer
Natural Resources Canada, Program
of Energy R and D
580 Booth Street, Ottawa, Ontario,
Canada
The total value of this project is:
1,190,000 Canadian Dollars.
Predominate oil and gas pipeline
companies involved in this 3-year
project include Enbridge pipelines,
TransCanada Pipelines (Both
Canadian and USA divisions),
PDVSA, Venezuela, and Alliance
Pipelines.
3.
Start Date (month/year)
Completion date (month/year):
Start: April 2008
Completion: March 2011
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Dr. Sankara Papavinasam, Project and
technical lead
Dr. Tesfa Heile, Microbiological
Scientist
Dr. Antonio De Turris,
Microbiological and Chemical
Scientiest
Mr. Allan Runstedtler, Fluid Dynamic
Scientist
5.
Name of associated Consultants,
if any:
Nil
6.
Narrative description of Project: To develop standardized
methodologies/best practices for
controlling the combined effect of
corrosion and erosion that may
provide a basis for development and
validation of new standards, especially
NACE TG 315 (Liquid ICDA), and
for regulations to manage heavy oil
transmission pipelines
7.
Description of actual services
provided by your staff within the
assignment:
The internal pit growth rates were
investigated using three inline
inspection (ILI) surveys conducted
24
in 1999, 2004, and 2008. Because
the technologies advanced rapidly,
matching pits from different ILI
runs proved to be very challenging
task. However, a computer
algorithm to align and match the
pits was developed. Using this
algorithm the pits from three runs
were matched and pit growth rates
were established. This algorithm
can routinely be used to compare
data from different ILI runs.
The corrosivity and inhibitory
properties of over 25 crudes were
determined using newly designed
and developed wettability
apparatus, emulsion inversion
point apparatus, and a rotating
cage. Based on these experiments,
an ASTM Standard Guide G205,
“Evaluating Corrosivity of Crude
Oil under Pipeline Operating
Conditions” was developed. This
standard is routinely used to
evaluate corrosivity and inhibitory
properties of crude oils under
pipeline transporting conditions.
Fluid simulation was performed in
order to understand the influence
of fluid velocity and properties on
the location of the deposition of
water under the oil transmission
pipeline operating conditions. The
outcome is used to determine
water accumulation locations in a
Canadian crude oil transmission
pipeline.
Canadian crudes contain larger
amounts of naphthenic acid. In the
refineries, in general, it is assumed
that higher the naphthenic acid the
higher the corrosion rate. Based
on tests and analysis of data from
Canada, USA, and Venezuela, it
was scientifically and technically
proven that this rule of thumb is
not applicable to oil transmission
pipeline operating conditions. As
25
part of this project, a Venezuelan
oil company sponsored a Ph.D.
student to work in this project in
Canada for two years.
S.No. Item Description
Details
Details
1.
Name of assignment Integrity Management - Internal
Corrosion Control
2.
Name and address of the
employer
Natural Resources Canada, Program
Energy R and D
580 Booth Street, Ottawa, Ontario,
Canada
The total value of this project is:
1,440,000 Canadian Dollars.
Predominate oil and gas pipeline
companies involved in this 4-year
project include Enbridge pipelines,
TransCanada Pipelines, and Alliance
Pipelines.
3.
Start Date (month/year)
Completion date (month/year):
Start: April 2004
Completion: March 2008
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Dr. Sankara Papavinasam, Project and
technical lead
Dr. R. Winston Revie, Program
Manager
Dr. Reeta Sooknah, Microbiological
Scientist
Mr. Allan Runstedtler, Fluid Dynamic
Scientist
5.
Name of associated Consultants,
if any:
Nil
6.
Narrative description of Project: The overall objective of this project is
to reduce the percentage of oil and gas
transmission pipeline incidents due to
internal corrosion by providing new
science and technological data on: (1)
identification of susceptible locations
in pipelines for internal corrosion to
occur; (2) evaluation of non-intrusive
techniques to monitor internal
corrosion in those locations; and (3)
validation of strategies to control
corrosion in those locations.
26
7.
Description of actual services
provided by your staff within the
assignment:
Based on the literature review,
discussion with technology provider
and the industry, six (6) non-intrusive
techniques were identified to monitor
internal corrosion of oil and gas
transmission pipelines. The techniques
are: handheld ultrasonic (UT) probe,
handheld UT probe, electrical probe,
hydrogen probe, spiral wound fibre
optic probe, and patch fibre optic
probe. The merits and limitations of
the probes were evaluated and
presented to the project sponsors.
Direction was also provided to
integrate non-intrusive monitoring
techniques with the pipeline SCADA
(Supervisory Control And Data
Acquisition) system.
An internal corrosion prediction
software [Systematic Treatment of
Pitting Sequence (SToPS)] software to
predict internal pitting corrosion rate
under both production and
transmission pipelines operating
conditions was also developed and 70
copies of the software were distributed
to oil and gas companies, consulting
companies, inhibitor suppliers and
other stake holders.
Specific experience in field of internal corrosion management of gas or other hydrocarbon pipelines
1.
Name of assignment Corrosion study of Fort Hills Primary
Extraction Project
2.
Name and address of the
employer
Suncor Energy Inc.
Fort Hills Primary Extraction Project
150 – 6th Avenue S.W.
Calgary, Alberta
3.
Start Date (month/year)
Completion date (month/year):
February 2016
June 2016
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Dr. Sankara Papavinasam, Technical
lead
5.
Name of associated Consultants,
if any:
Lloyd’s Register Energy Canada
Limited
First Street Plaza, Suite #400
27
138 – 4th Avenue S.E.
Calgary, AB, T2G 4Z6
(Lloyd is the primary contractor for
Risk Based Inspection (RBI) and
corrosion activities are sub-contracted
to Dr. Papavinasam)
6.
Narrative description of Project: The purpose of this Corrosion Study is
to define the principal degradation
concerns and identify Integrity
Operating Windows (IOWs) for
damage control for the Fort Hills
Primary Extraction Facility.
7.
Description of actual services
provided by Sankara
Papavinasam within the
assignment:
Through analysis of the current
operating conditions and based on the
client experience with similar
operating facility, identified nine (9)
damage mechanisms (DM) that
contribute to degradation, and
potentially cause equipment failure
within the plant.
1.
Name of assignment Corrosion study of Fort Hills Secondary
Extraction Project
2.
Name and address of the
employer
Suncor Energy Inc.
Fort Hills Secondary Extraction
Project
150 – 6th Avenue S.W.
Calgary, Alberta
3.
Start Date (month/year)
Completion date (month/year):
July, 2015
November, 2015
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Dr. Sankara Papavinasam, Technical
lead
5.
Name of associated Consultants,
if any:
Lloyd’s Register Energy Canada
Limited
First Street Plaza, Suite #400
138 – 4th Avenue S.E.
Calgary, AB, T2G 4Z6
(Lloyd is the primary contractor for
Risk Based Inspection (RBI) and
corrosion activities are sub-contracted
to Dr. Papavinasam)
28
6.
Narrative description of Project: The purpose of this Corrosion Study is
to define the principal degradation
concerns and identify Integrity
Operating Windows (IOWs) for
damage control for the Fort Hills
Secondary Extraction Plant. This
plant feeds oil onto transmission
pipelines.
7.
Description of actual services
provided by Sankara
Papavinasam within the
assignment:
Through analysis of the current
operating conditions and the
equipment inspection and failure
histories from similar facilities,
identified eleven (11) damage
mechanisms that contribute to
degradation, and potentially cause
equipment failure and downtime
events within the plant.
1.
Name of assignment Jackfish 03 – Corrosion Study
2.
Name and address of the
employer
Devon Energy Corporation
400-3rd Avenue S.W.
Calgary, Alberta Canada T2P 4H2
3.
Start Date (month/year)
Completion date (month/year):
Feb. 2015
Dec. 2015
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Dr. Sankara Papavinasam, Project and
technical lead
5.
Name of associated Consultants,
if any:
Lloyd’s Register Energy Canada
Limited
First Street Plaza, Suite #400
138 – 4th Avenue S.E.
Calgary, AB, T2G 4Z6
(Lloyd is the primary contractor for
Risk Based Inspection (RBI) and
corrosion activities are sub-contracted
to Dr. Papavinasam)
6.
Narrative description of Project: To perform corrosion review on the
operations of Jackfish 3 (JF 3) facility.
Jackfish 03 (JF 3) is a new plant and it
produces bitumen using steam assisted
gravity drainage (SAGD) process.
29
7.
Description of actual services
provided by Sankara
Papavinasam within the
assignment:
Reviewed operating conditions of
350 fixed equipment and 425
piping circuits
Identified 17 damage mechanisms
Deduced minimum, maximum and
range of corrosion rates in all
equipment and pipes.
1.
Name of assignment Firebag Insitu Production – Plant 91
2.
Name and address of the
employer
Suncor Energy Inc.
MacKay River 2, AB
150 – 6th Avenue S.W.
Calgary, Alberta
3.
Start Date (month/year)
Completion date (month/year):
Nov. 2014
March 2015
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Dr. Sankara Papavinasam, Technical
lead
5.
Name of associated Consultants,
if any:
Lloyd’s Register Energy Canada
Limited
First Street Plaza, Suite #400
138 – 4th Avenue S.E.
Calgary, AB, T2G 4Z6
(Lloyd is the primary contractor for
Risk Based Inspection (RBI) and
corrosion activities are sub-contracted
to Dr. Papavinasam)
6.
Narrative description of Project: The purpose of this project is to
develop Corrosion Control Document
(CCD) which:
defines the principal corrosion and
degradation concerns,
presents the materials selection
and corrosion control philosophy,
and
identifies Integrity Operating
Windows (IOWs)
7.
Description of actual services
provided by Sankara
Papavinasam within the
assignment:
Contributed to the
development of 21 corrosion
circuits
Identification of 23 damage
mechanisms
30
Development of 14 integrity
operating windows (IOWs)
1.
Name of assignment Corrosion Study Report for MacKey
River 2 Operations
2.
Name and address of the
employer
Suncor Energy Inc.
MacKay River 2, AB
150 – 6th Avenue S.W.
Calgary, Alberta
3.
Start Date (month/year)
Completion date (month/year):
August 2014
November 2014
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Dr. Sankara Papavinasam, Project and
technical lead
5.
Name of associated Consultants,
if any:
Lloyd’s Register Energy Canada
Limited
First Street Plaza, Suite #400
138 – 4th Avenue S.E.
Calgary, AB, T2G 4Z6
(Lloyd is the primary contractor for
Risk Based Inspection (RBI) and
corrosion activities are sub-contracted
to Dr. Papavinasam)
6.
Narrative description of Project: Based on a review of the sampling,
monitoring, inspection data, and
failure analysis available in MR1,
establish best corrosion control
practices for MR2
7.
Description of actual services
provided by Sankara
Papavinasam within the
assignment:
Reviewed operating parameters
and operating history of fixed
equipment and pipelines of MR1
and compared those with design
parameters for MR2 (equivalent
study)
Established corrosion mechanisms
and potential corrosion rates for
MR2
Identified areas for improvement
and locations for corrosion
monitoring
Recommended conditions to use
non-metallic pipes (e.g., high-
31
density polyethylene pipe or fiber-
reinforced plastic (FRP) pipes.
Suggested modifications for
internal coating evaluation,
selection, and application.
1.
Name of assignment Corrosion Study Report for MacKey
River 1 Operations
2.
Name and address of the
employer
Suncor Energy Inc.
MacKay River 2, AB
150 – 6th Avenue S.W.
Calgary, Alberta
3.
Start Date (month/year)
Completion date (month/year):
June 2014
Aug. 2014
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Dr. Sankara Papavinasam, Project and
technical lead
5.
Name of associated Consultants,
if any:
Lloyd’s Register Energy Canada
Limited
First Street Plaza, Suite #400
138 – 4th Avenue S.E.
Calgary, AB, T2G 4Z6
(Lloyd is the primary contractor for
Risk Based Inspection (RBI) and
corrosion activities are sub-contracted
to Dr. Papavinasam)
6.
Narrative description of Project: Review of corrosion states and
corrosion control strategies in Mackey
River 1: Oilsands production
operation.
7.
Description of actual services
provided by Sankara
Papavinasam within the
assignment:
Reviewed operating parameters
and operating history of fixed
equipment and pipelines
Established corrosion mechanisms
and potential corrosion rates
Identified areas for improvement
and locations for corrosion
monitoring.
1.
Name of assignment Biofuels Pipelines
32
2.
Name and address of the
employer
Natural Resources Canada, Program
Energy R and D
580 Booth Street, Ottawa, Ontario,
Canada
Partial funding from Pipeline
Hazardous Materials Safety
Administration (PHMSA), USA.
3.
Start Date (month/year)
Completion date (month/year):
April 2009
March 2013
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Dr. Sankara Papavinasam, Project and
technical lead
5.
Name of associated Consultants,
if any:
DNV, Columbus, Ohio, USA
6.
Narrative description of Project: Although standards specify
constituents of biodiesel, additional
impurities may be incorporated into
the biodiesel which may adversely
affect the biodiesel corrosivity, and
subsequently diesel pipelines. In order
to understand the nature and origin of
the contaminants an industry survey
was conducted. This survey was
partially funded by Pipeline
Hazardous Materials Safety Agency
(PHMSA).
A parallel study was initiated to
investigate durability and performance
of steel fuel tanks in Canadian
biodiesels in consultation with and
support from Strategic Alliance for
Steel Fuel Tanks (SASFT), USA.
7.
Description of actual services
provided by Sankara
Papavinasam within the
assignment:
Reviewed the current status of
biofuels pipelines is reviewed.
Collected and analysed the
industry experience with respect to
corrosivity of biodiesel and diesel
Developed a comprehensive report
on how to control corrosivity of
biodiesel and diesel
1.
Name of assignment CO2 Pipelines
33
2.
Name and address of the
employer
Clean Energy Fund (CEF)
Natural Resources Canada, Program
Energy R and D
580 Booth Street, Ottawa, Ontario,
Canada
3.
Start Date (month/year)
Completion date (month/year):
April 2010
March 2013
4.
Name of senior professional
staff of your consultancy
involved and functions
performed
Dr. Sankara Papavinasam, Project and
technical lead
5.
Name of associated Consultants,
if any:
Nil
6.
Narrative description of Project: Carbon capture, transportation, and
storage may be considered as a short-
to medium-term solution to reduce
green house emission while carbon-
neutral energy technologies are
developed. Several pilot plants have
been built in recent years to
demonstrate carbon capture and
storage, learn and optimize facilities
and processes involved. Extensive
industrial experience is already
available in CO2 pipelines for
enhanced oil recovery (EOR)
operations, but further experience is
needed for transporting CO2 in
presence of impurities resulting from
some capture processes. With all
these developments, carbon capture,
transportation, and storage (CCS)
infrastructure is becoming increasingly
possible. The CO2 captured from
various sources may contain many
impurities depending on the process
and capture technology. The influence
of impurities on material (corrosion)
properties under CCS operating
conditions was investigated.
7.
Description of actual services
provided by Sankara
Papavinasam within the
assignment:
A pilot plant to capture CO2 using
oxy-fuel technology was
established in a sister organization.
Sankara Papavinasam collected the
operating conditions and correlated
with materials behavior.
Corrosion literature on CCS was
collected and incorporated into the
34
software program (developed to
manage corrosion oil and gas
pipelines).
To help the development of
regulatory decisions for CO2
pipelines, Dr. Papavinasam
presented the materials R&D
achievements at the clean energy
fund (CEF) forum and participated
in the panel discussion
35