crude oil transportation and integrity...
TRANSCRIPT
Crude Oil Transportation and Integrity Management
National Academy of Sciences
Project Meeting: Pipeline Transportation of Diluted Bitumen
July 23, 2012
Jenny Been, PhD, P.Eng, PMP Corrosion Specialist, Pipe Integrity
Bruce Dupuis, P.Eng. Program Manager, Liquid Pipeline Integrity
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Outline
• Canadian petroleum imports into the USA
• What is Diluted Bitumen and its origin
• Crude oil properties
• Where corrosion may occur
• Regulatory measures
• Operational measures for quality preservation of
transmitted crude
• Internal corrosion management
• Prevention
• Mitigation
• Assessment
• Industry Collaboration
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US Imports by Country of Origin
• ~75% is crude oil
Petroleum Imports into the USA(Million Barrels per Day)
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Can
ada
Sau
di A
rabia
Mex
ico
Ven
ezue
la
Colom
bia
Kuw
ait
Iraq
Niger
ia
Bra
zil
Rus
sia
~ ~ ~
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Oil Sands Deposits in Alberta
• The Alberta Oil Sands represents 95%
of Canada’s proven oil reserves
• Alberta area: 255,540 sq. mile
• Oil Sands deposits area:
55,000 sq. mile
• Size of New York or Iowa
• Mineable oil sands area:
1,850 sq. mile (only 3% of total oil
sands land area - located mainly north
of Fort McMurray)
• Active oil sands mining area:
230 sq. mile (with 26 sq. mile under
active reclamation)
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Surface Mining &
Extraction
In-situ Production
(sub-surface)
Refining
(Canada, US
or International)
Upgrading
Conversion to
Synthetic Crude
(Alberta or US)
Petro-chemical
Products
How are Oil Sands Produced and Processed
Bitumen + Diluent = Diluted Bitumen (dilbit)
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OIL SANDS
MINING
NAPHTHA
RECOVERY UNIT
TRUCK
TRANSPORT
PRIMARY
SEPARATION
VESSEL
SECONDARY
SEPARATION
DEAERATOR
CRUSHER
BITUMEN RECOVERY
PROCESS
HYDROTRANSPORT
HOT
WATER +
CAUSTIC
SODA
FROTH
TREATMENT
PLANT
TAILING PONDS
STEAM
IN-SITU
CSS
SAGD
CHOPS
THAI
VAPEX
OR
UPGRADING
SITE
REFINERY
ASPHALT
OR
HOT
WATER
BIT
UM
EN
BITUMEN
DEAERATED
BITUMEN
FROTH
BITUMEN
FROTH
BITUMEN
FROTH
NAPHTHA
MIDDLINGS
TAILINGS
(SAND +
WATER)
MIDDLINGS
RESIDUE
AIR
OIL
SANDS
CRUSHED OIL
SANDS
SLURRY
RESIDUE
WATER,
SOLIDS +
NAPHTHA
AIR
RESIDUE WATER
+ SOLIDS
Typical Mining/Extraction Process
Dilbit
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Crude Oil Properties
• Crude oils are characterized and assessed to determine
their value and processability by refineries by:
• API gravity (related to density and correlated to viscosity)
• Percent of Sulfur
• TAN number
• Different organic fractions
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AP
I Gra
vity
TAN
(m
g K
OH
/g),
Su
lph
ur
(wt%
)TAN (mg KOH/g)
Sulphur (wt%)
• International Crude Oils
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15
20
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40
45
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4.5
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AP
I Gra
vity
TAN
(m
g K
OH
/g),
Su
lph
ur
(wt%
)TAN (mg KOH/g)
Sulphur (wt%)
• Cdn Dilbit and Dilsynbit in green
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Where Corrosion May Occur
• The characteristics of dilbit are not unique and are comparable to
conventional crude oils
• Crude oils entering transmission pipelines contain <0.5% Basic
Sediments & Water (BS&W)
• These crude oils (conventional and diluted bitumen) are generally non-
corrosive
• Internal corrosion can occur at locations where sediment and
water can precipitate
• Underneath deposited sediments, a corrosive water film can form
on the pipe wall
• Not unique to dilbit; has been observed on lines transporting
conventional crude
• Fully turbulent flow will promote the suspension of sediment and
water
• Localized deposition could occur in low pressure areas if the degree of
turbulence drops to lower levels
• No corrosion observed in the absence of sediment when exposed to
the crude only
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Crude Oil Properties
• Crude oil properties that are important for pipeline operation as
related to water and sediment drop-out:
• Basic Sediment and Water content (BS&W)
• Density of Oil
• Viscosity
• Petroleum quality requirements of crude are specified in NEB and
FERC Tariffs
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NEB and FERC Tariffs, Federal Regulations
FERC and NEB quality specifications of petroleum
• Basic Sediment and Water (BS&W) <0.5 volume percent
• Density at the receipt point shall not exceed 940 kg/m3 (58.7 lb/ft3)
• The kinematic viscosity shall not exceed 350 mm2/s (0.00377 ft2/s) at
the carrier's reference temperature
Federal Regulations, Paragraph 195.579
• The corrosive effect of the hazardous liquid on the pipeline must be
investigated and adequate steps must be taken to mitigate internal
corrosion considering inhibition and monitoring
PHMSA Special Conditions
• Limit BS&W to 0.5 percent by volume and report results to PHMSA in
annual report
• Run cleaning pigs twice in the first year and as necessary in
succeeding years
• Liquids / solids collected during cleaning pig runs must be sampled,
analyzed, and assessed with regard to internal corrosion mitigation
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Keystone Pipeline Overview
Keystone Pipeline – Current System
Hardisty, Alberta to
• Wood River, Illinois
• Patoka, Illinois
• Cushing, Oklahoma
Nominal velocity of 5.6 mph (2.5mps)
Batched operation
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Operational Measures for Quality Preservation
Batch Sizes and Batch Trains
• Minimum Batch Size of 100,000 bbls
• Larger Batch Sizes Minimize the Interface/Batch Volume
• Batch Trains of Similar Product Types are Scheduled in Sequence to
Minimize Adjacent Contamination.
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System Properties that Preserve Batch Quality
Bullet Line Design
• No Breakout Tankage for Mixing of Tank Bottoms
• Less Batch Cuts from Swing Points
• High Flowrates = High Reynolds Numbers = Tight Interfaces
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Internal Corrosion Management
Prevention
• Tariff enforcement
• Tariff Excursion Procedure
• in the event of product quality excursions
• staged escalation of warnings leading to prerequisite
testing
• enables Keystone to act without bias to any Shipper or
interconnected facility
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Internal Corrosion Management
Prevention
• Tariff enforcement
• Minimizing presence of dead legs
• Flow through barrels
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Internal Corrosion Management
Prevention
• Tariff enforcement
• Minimizing presence of dead legs
• Turbulent flow
• Operating at flow conditions well in excess of those required
for water entrainment as indicated by flow models
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Internal Corrosion Management
Prevention
• Tariff enforcement
• Minimizing presence of dead legs
• Turbulent flow
• Cleaning pigging
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Internal Corrosion Management
Assessment
• Thickness monitoring of potential deposition sites in
facilities
• Ultrasonic monitoring of the wall thickness at unavoidable
dead legs associated with by-pass line at barrel assemblies
• Should provide worst case conditions for sediment
accumulation
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Internal Corrosion Management
Assessment
• Thickness monitoring of potential deposition sites in
facilities
• In-Line Inspection
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Internal Corrosion Management
Assessment
• Thickness monitoring of potential deposition sites in
facilities
• In-Line Inspection
• Analysis of Deposit Samples
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Analysis of Deposit Samples
• Corrosion testing and
chemical analysis of
pipeline deposits
obtained from
cleaning pig runs
• The pipeline deposit
is an average sample
obtained over the
length of the pig run
and over the time
between pig runs
• No trend in
underdeposit
corrosion was
observed along the
line
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Underdeposit Crude Oil Only
Co
rro
sio
n R
ate
(m
py)
Error bars from max to min values
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Internal Corrosion Management
Assessment
• Thickness monitoring of potential deposition sites in
facilities
• In-Line Inspection
• Analysis of Deposit Samples
• PinPoint™ Continuous Monitoring
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Internal Corrosion Management
Mitigation
• Increase Flow
• Commercial objective of maximizing throughput, also
minimizes sediment deposition
• Increased Cleaning Pigging
• Ran twice in first year in consideration of non-turbulent flow
during line fill
• Continuing to run twice per in sections where flow alternates
• Frequency will be reviewed in terms of both ILI and deposit
analysis
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Internal Corrosion Management
Mitigation
• Increase Flow
• Commercial objective of maximizing throughput, also
minimizes sediment deposition
• Increased Cleaning Pigging
• Chemical treatment
• Necessity will be assessed in terms of both ILI and deposit
analysis
• Through an abundance of caution a chemical program is being
architected to facilitate a timely response should it be required
• Efficiency/frequency would be accessed on lab results, pin
point data and ILI run to run analysis
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• The Pipeline Integrity and Corrosion Management (PICoM) program
at Alberta Innovates technology Futures is directed by an Industry
Working Group addressing issues of pipeline corrosion and integrity
management
• Current focus on internal corrosion monitoring and mitigation of crude
oil pipelines
• Corrosion underneath pipeline deposits
• Base-lining and optimization of mitigation tools
• Laboratory experiments and pilot scale flow loop evaluating
monitoring technologies and mitigation effectiveness (cleaning pigs,
chemical treatment)
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Industry Collaboration