canmetmaterials - transportation research...
TRANSCRIPT
CanmetMATERIALS
Canada’s Natural Resources – Now and for the Future
Standard and Non-Standard Methodologies to Evaluate
Crude Oil Corrosivity Under Pipeline Operating
Conditions
Outline
Introduction
Internal Corrosion Control
Crude Oil Corrosivity under Pipeline
Transportation Conditions
Oil-Water Emulsion
Oil-Wet-Water-Wet Condition
Influence of Oil Phase on Water Phase
Recommendations for Consideration
Introduction
CANMET laboratories spread across Canada
CanmetMATERIALS is the largest research centre in Canada dedicated to metals and materials fabrication, processing and evaluation
CANMET laboratories have studied crude oil corrosivity under pipeline operating conditions since 1993
Over the past two decades about 100 crude oils have been used to understand their corrosivity under pipeline operating conditions
CanmetMATERIALS research contributed to the development of a new ASTM International Standard Guide (ASTM G205), which describes methodologies for determining the corrosivity of crude oil under pipeline operating conditions
Internal Corrosion Control Modeling
Prediction, mechanism, mechanistic models, and guidelines
Mitigation
Cleaning, corrosion inhibitors, biocides, and internal liners
Monitoring
Intrusive, non-intrusive, and inline Inspection
Maintenance
Equipment, workforce, data, and communication
Management
Risk
Most Corrosion Occurs by Electrochemical
Mechanism
Four things are needed
Anode: Sites where metal
is lost and electrons and
ions are produced
Cathode: Sites where
electrons are consumed
Metallic path: Conducts
electrons from anodes to
cathodes
Electrolytic path:
Conducts ions or source
for reactants
Metallic path
Ionic path
Electrolyte
Anode Cathode
Characteristics of Electrolyte
A liquid (sometimes a solid) that conducts
electricity by the flow of ions
The more ions the electrolyte has the higher its
conductivity and the higher the probability it
sustains corrosion
Seawater is conductive – sustains corrosion
Pure water is non-conductive – does not
sustain corrosion
Crude oil is non-conductive – does not sustain
corrosion
Internal Corrosion
Stage 3
Metal
Stage 4
Water
Stage 1 Stage 2
Metal
Oil Surface layer Repassivation
Prediction of Corrosion in an Oil
Transmission Pipeline
Identification of locations susceptible to corrosion
Water accumulation
Oil phase – water phase interactions in those
locations
Locations for Water Accumulation
(Standard Methods)
NACE – SP0208 - Internal Corrosion Direct Assessment Methodology for Liquid Petroleum Pipelines
Lists several models to predict locations where water may accumulate
NACE TG 447
To develop a state-of-the-art report on flow and corrosion modeling and to provide guidelines for selecting appropriate
models
Locations for Water Accumulation
(Non-Standard Method)
Water deposition in heavy
oil transmission pipeline
modelled
Computational fluid
dynamics (CFD)
Near-wall velocity of flow
in heavy oil is significantly
lower than in light oil
(a) Light oil turbulence model
(b) Heavy oil turbulence model
(c) Heavy oil laminar model
(a)
(b)
(c)
X.Landry, A. Runstedler, S.Papavinasam, and T. Place,
Corrosion Journal (2012), “Computational Fluid Dynamics
Study of Solids Deposition in Heavy Oil Transmission
Pipeline” – Available online
Oil phase – water phase interactions
Emulsion
Liquid-liquid physical interaction
Wettability
Liquid-liquid-solid interaction
Corrosiveness of the Aqueous Phase
Liquid-liquid chemical interaction
Influence of oil phase on water
phase corrosivity
Emulsion Water Droplets
Oil-Phase
Water-in-Oil Emulsion Oil-in-Water Emulsion
Water-Phase
Oil Droplets
Low conductivity
(Non-corrosive
electrolyte)
High conductivity
(Corrosive
electrolyte)
Inversion Point
Emulsion Inversion Point Determination
Non-Standard Methods
Electrical
Microwave
Radiation Scattering
Spectroscopic
Ultrasonic
Density-based techniques
Viscosity-based techniques
Emulsion Inversion Point
0
50
100
150
200
250
0% 10% 20% 30% 40% 50% 60% 70%
Water cut
Res
ista
nce
(K
-Oh
ms) 0
1
2
3
4
5
Inversion Point
Wettability – Spreading Method (ASTM G205)
Pins
exhibiting
high
conductivity
More than 15
of 20 pins
5 to 15 of 20
pins
Less than 5
of 20 pins
Wettability Water-wet Mixed-wet Oil-wet
Effect of Crude Oil on the
Corrosiveness of Aqueous Phase
What is the influence
of crude oil on this
water phase?
Preventive Inhibitive Neutral Corrosive
99.5% Oil and 0.5% Water and Solid
Effect of Crude Oil on the
Corrosiveness of Aqueous Phase -
Non-standard methods
Chemical analysis of fluids Acid number and water content were found
irrelevant to corrosivity
Optical spectroscopy
Iron concentration
pH, viscosity, and density Could not be correlated with corrosivity
Electrochemical measurement Unreliable
Microelectrodes
Conducting polymer method
Electrochemical quartz crystal microbalance
No Correlation between physical properties and crude corrosivity
(Non-Standard Methods)
0
1000
2000
3000
4000
5000
0 10 20 30 40 50 60 70Crude Oil Number
Wate
r co
nte
nt,
pp
m
0
1
2
3
4
5
Water Content
Acid Number
Ac
id N
um
be
r, , m
g K
OH
/g
.001 mpy
.001 mpy
.001 mpy
.001 mpy
Only 4 crudes showed somewhat measurable corrosion rate
Effect of Crude Oil on the
Corrosiveness of Aqueous Phase -
Standard methods ASTM G170: Guide for evaluating and qualifying oilfield
and refinery corrosion inhibitors in the laboratory ASTM G184: Practice for evaluating and qualifying oilfield
and refinery corrosion inhibitors using rotating cage ASTM G185: Practice for evaluating and qualifying oilfield
and refinery corrosion inhibitors using rotating cylinder electrode
ASTM G202: Test method for using atmospheric pressure rotating cage
ASTM D665: Test method for rust-preventing characteristics of inhibited mineral oil in the presence of water
NACE TM0172: Standard Test Method of determining corrosive properties of cargoes in petroleum product pipelines
Hierarchy of ASTM Standards
Standard Guide Provides general guide (ASTM G170)
Standard Practice
Prescribes procedure (ASTM
G184, G185, and G188)
Standard Test Method Prescribes procedure and expected
results (ASTM G202)
Precision developed based on round
robin tests
Based on 225 data points produced by
10 different laboratories around the
world (Canada, India, USA, and
Venezuela)
Bench-mark aqueous phase corrosion
rate established by round robin tests:
23 + 2 mpy or 0.58 + 0.05 mm/y
Rotating Cage
Corrosivity of Aqueous Phase in the
Presence of Different Crude oils
0
5
10
15
20
25
30
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21
Crude Oil Identification Number
Co
rro
sio
n R
ate
(m
py)
Inhibitive Crude Oil
Neutral Crude Oil
Corrosive Crude Oil
23 + 2 mpy
ASTM G205: Standard Guide for Determining
Corrosivity of Crude Oils
Emulsion
W/O
O/W
No Corrosion
Wettability
Oil-Wet
Mixed-Wet
Water-Wet
No Corrosion
Corrosivity of Brine in
the Presence of
Hydrocarbon
Less then 0.01 mpy (Preventive
Hydrocarbon)
Lower then Absence of Hydrocarbons
(Inhibitive Hydrocarbon)
No Change (Neutral Hydrocarbon)
Higher then Absence of Hydrocarbons
(Corrosive Hydrocarbon)
Reduced Corrosion
Aqueous Corrosion
Accelerated Corrosion
No Corrosion
Summary
No crude oil can sustain corrosion under pipeline
operating conditions
Absence of conductive electrolyte phase
Conductive water phase is required for corrosion to
occur
In the presence of water and oil phases three
properties should be evaluated
Emulsion
Wettability
Change in corrosivity of Aqueous phase by oil
phase
Recommendations
Crude oils should be tested as per ASTM G205
at the point of entry into the pipeline
Unless test shows that it is “neutral” or
“corrosive”, no new action is required with
respect to Dil-bit
Preventive
crude oil
Inhibitive
crude oil
Neutral
crude oil
Corrosive
crude oil