fac 2007 04 wax.pdf
TRANSCRIPT
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1April 2006 Pg 1
Wax / Paraffin
FLOW ASSURANCE & OPERABILITY
APR-2006 2
Flow Assurance and Operability
Definitions (2 20) Impacts on Facilities and Operations (21 25) Prediction and Design Strategies (26 50) Control and Remediation (51 69)
Wax / Paraffin
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2APR-2006 3
Flow Assurance and Operability
DEFINITIONSWhat is wax? Wide range of high molecular weight
paraffins (saturated hydrocarbons) Straight chain, branched, and cyclic
paraffins Slightly soluble in oil Solidifies from oil primarily due to a
decrease in temperature .
Wax / Paraffin
APR-2006 4
Flow Assurance and Operability
What is wax?
Wax / Paraffin
CH3CH2
CH2CH2
CH2CH2
CH2CH2
CH2CH2
CH2CH2
CH2CH3
CH3CH2
CH2CH2
CH2CH2
CHCH2
CH2CH2
CHCH3
CH2CH2
CH2CH3
CH2 CH3
CH3CH2
CH2CH2
CHCH2
CHCH2
CH2CH2
CH2CH3
CH2CH
CH2CH3
CH2
STRAIGHT CHAIN OR NORMAL PARAFFIN
BRANCHED OR ISO-PARAFFIN
CYCLIC PARAFFIN OR NAPHTHENES
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3APR-2006 5
Flow Assurance and Operability
What is wax?
Wax / Paraffin
ALKANES
-200
-100
0
100
200
300
400
0 2 4 6 8 10 12 14 16 18 20
Carbon Number
Tem
pera
ture
, C
0.3
0.4
0.5
0.6
0.7
0.8
0.9
Melting Point
Boiling Point
Specific Gravity
APR-2006 6
Flow Assurance and Operability
What is wax? Paraffin and wax are used interchangably As wax solidifies from oil, there are three major concerns:
Wax deposition on tubing and pipe walls Increases in viscosity due to wax particles suspended in the oil Gelling of the oil during shutdown
There are a number of parameters and terms used to describe wax behavior
Wax / Paraffin
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4APR-2006 7
Flow Assurance and Operability
Definition of Wax Terms Cloud point or wax appearance temperature Wax deposition Pour point Gel strength or yield stress Viscosity Wax Content Re-melt temperature Dissolution temperature
Wax / Paraffin
APR-2006 8
Flow Assurance and Operability
Cloud Point Temperature at which the first wax crystals form At the cloud point, only a small fraction of wax molecules
crystallize as the temperature continues to drop more crystallizes
Combine with thermal-hydraulic modeling to determine where wax can deposit
Also known as Wax Appearance Temperature (WAT)
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5APR-2006 9
Flow Assurance and Operability
Cloud Point In a live oil, cloud point is lowest at the bubble point
Light molecules, which act as solvent for waxes, are at their highest concentration in the oil at the bubble point
As the pressure increases above the bubble point, the cloud point increases
In a dead oil, cloud point is lowest at atmospheric pressure
Higher pressure favors crystal formation
Typically measure dead oil cloud point at atmospheric pressure
Wax / Paraffin
APR-2006 10
Flow Assurance and OperabilityWax / Paraffin
0
25
50
75
100
125
150
175
200
20 25 30 35 40 45 50 55 60Temperature (C)
Pres
sure
(bar
a)
LIVE OIL BUBBLE POINT
LIVE OIL CLOUD POINT
DEAD OIL CLOUD POINT
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6APR-2006 11
Flow Assurance and Operability
Wax Deposition When the pipewall temperature drops below the cloud
point, wax can deposit on the pipewall Most of wax does not deposit Relatively slow process Occurs during normal flow Very little deposition during
shutdown, i.e. no flow
Wax / Paraffin
APR-2006 12
Flow Assurance and Operability
Pour Point Lowest temperature at which an oil can be poured under gravity It is not the temperature at which oil stops in a flowing pipeline Below the pour point, wax crystals form a matrix structure or a gel in
static (not flowing) oil A yield force is required to break the gel and start the fluids flowing The pour point is defined by the
IP 15 or ASTM D97 methods Similar to cloud point, live oil
pour point < dead oil pour point
Wax / Paraffin
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7APR-2006 13
Flow Assurance and Operability
Gel Strength Also called yield stress The force required to break the gel developed below the
pour point Thermal and flow history can affect the gel strength It determines the pump pressure required to restart flow Gel strength will vary proportionally with the pipeline
length
Wax / Paraffin
APR-2006 14
Flow Assurance and Operability
Viscosity Is strongly dependent upon
temperature Above the cloud point the viscosity
of oil is only a function of temperature Newtonian behavior.
Below the cloud point, wax crystals suspended in the oil affect the viscosity, and thus viscosity is a function of temperature and of shear rate non-Newtonian behavior.
Shear rate = (4*Q)/(*r3), where Q = volumetric flow rate
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8APR-2006 15
Flow Assurance and OperabilityWax / Paraffin
Non-Newtonain Viscosity
10
100
1000
10000
100000
0 10 20 30 40 50Temperature (C)
Visc
osity
(cP)
1030507090110
Shear Rate (1/s)
Cloud Point
APR-2006 16
Flow Assurance and Operability
Wax Content The weight percent of wax in an oil sample (depends
upon test procedure) It is not a predictive parameter High wax content oils (over 10%) are likely to be viscous
and to have gelling and deposition problems Low wax content oils are less likely to have gelling and
viscosity problems but can still have wax deposition problems
Note: waxy oils (typically API > 30) are not heavy oils (API < 22)
Wax / Paraffin
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Flow Assurance and OperabilityWax / Paraffin
Wax Content
0
2
4
6
8
10
12
-40 -20 0 20 40 60Temperature (C)
Wax
Con
tent
(wt %
)
Cloud Point
APR-2006 18
Flow Assurance and OperabilityWax / Paraffin
0
10
20
30
40
50
60
0 1 2 3
WAX CONTENT
TEM
PER
ATU
RE
LOW MEDIUM HIGH
NO WAXPROBLEMS
LIKELY
WAX DEPOSITIONIS POSSIBLE,
NO WAX GELLING WAX DEPOSITIONAND WAX GELLING
ARE POSSIBLE
CLOUD POINT
POUR POINT
MINIMUM AMBIENTTEMPERATURE
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10
APR-2006 19
Flow Assurance and Operability
Re-Melt Temperature Temperature at which a sample of solid wax melts Soft waxes have melting temperatures in the range of 120
to 140F (49 to 60C) Harder waxes can have melting temperatures as high as
190F (88C) Defines temperature at which the pipewall needs to be
heated to remove (melt) solid wax deposits
Wax / Paraffin
APR-2006 20
Flow Assurance and Operability
Dissolution Temperature Temperature at which wax crystals re-dissolve in the oil Typically greater than the cloud point but less than re-melt
temperature Used for ensuring that all wax is re-dissolved in the oil
during operation or hot oiling
Wax / Paraffin
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APR-2006 21
Flow Assurance and Operability
IMPACT ON FACILITIES AND OPERATIONS Deposition High Viscosities Gelling
Wax / Paraffin
APR-2006 22
Flow Assurance and Operability
Wax Deposition Wax can deposit on tubulars and pipewalls
The build-up of wax reduces the internal diameter The wax deposit increases the surface roughness of the pipewall Diameter reduction and increased surface roughness reduces
flow capacity May eventually lead to blockage Potential to have a stuck pig
Wax can plug instrumentation lines
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APR-2006 23
Flow Assurance and Operability
High Viscosities Below the cloud point, viscosities can increase
significantly Wax crystals form a slurry in the bulk oil The viscosity depends on the flow rate (or shear rate)
Viscosity is higher at low shear rates (non-Newtonian flow)
At low flow rates the viscosity may be too high to maintain flow
Wax / Paraffin
APR-2006 24
Flow Assurance and OperabilityWax / Paraffin
Pipeline Transporting High Wax Content Oil
0
200
400
600
800
1000
1200
1400
1600
1800
0 10000 20000 30000 40000 50000Oil Flow Rate (BPD)
Pipe
line
Pres
sure
Dro
p (p
si)
High Viscosities
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APR-2006 25
Flow Assurance and Operability
Gelled Oil If a pipeline is shutdown and cools below the pour point, a
gel structure will form An initial yield force (i.e. pressure) must be applied to
break the gel structure and to start the fluids flowing.
The restart pressure may be greater than the pipeline and/or pump design pressure
Wax / Paraffin
APR-2006 26
Flow Assurance and Operability
PREDICTION AND DESIGN STRATEGIES1. Sample exploration/appraisal well (bottom hole sample
preferred)2. Perform laboratory analyses
Measure cloud point, pour point, wax content. Measure viscosities above and below cloud point.
3. Review production scenarios and oil/water/gas production rates over the life of the field
4. Perform steady state thermal-hydraulic modeling for system Consider all production scenarios Consider whole field life Determine operating temperatures and pressures
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APR-2006 27
Flow Assurance and Operability
PREDICTION AND DESIGN STRATEGIES5. Identify conditions and locations for wax deposition
(compare operating temperature to cloud point). Perform wax deposition lab tests if necessary Perform wax deposition modeling
6. Identify viscosity concerns Look at pressure drop over the range of flow rates
7. Determine if the pour point is above the ambient temperature
Measure gel strength if necessary Determine capability to restart gelled pipeline
Wax / Paraffin
APR-2006 28
Flow Assurance and Operability
PREDICTION AND DESIGN STRATEGIES8. Examine design/operating options to manage wax
Insulation or heat Chemical injection Pigging Other
9. Develop overall wax control and remediation strategies10. Monitoring
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APR-2006 29
Flow Assurance and Operability
PREDICTION AND DESIGN STRATEGIES Sampling for Wax Representative samples are needed (as always). Sample should be taken at a location above the cloud point. If initial evaluation shows a significant waxing potential, then
large sample quantities may be needed. Sample types
Bottomhole preferred but limited volume Separator large volumes which may be needed for deposition
and/or gelling tests
Sample handling Prevent loss of wax in sample containers
Wax / Paraffin
APR-2006 30
Flow Assurance and Operability
PREDICTION AND DESIGN STRATEGIES Lab Analyses for Wax Viscosity Cloud point Compositional analysis Wax deposition tests Pour point Gel strength
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APR-2006 31
Flow Assurance and Operability
Lab Analyses for Wax Viscosity Measure viscosity from above the cloud point to the
coldest operating temperature at a constant shear rate Measure at other shear rates anticipated in the field Viscometers considered appropriate are:
Concentric Cylinder Viscometer Cone and Plate Viscometer Model Pipelines
Wax / Paraffin
APR-2006 32
Flow Assurance and Operability
Lab Analyses for Wax Cloud Point Difficult to measure trying to detect first crystals A number of measurement techniques are available No industry standard method Very dependent on sample quality and handling Variations in measured cloud points can be 20F (11C)
or more for a given crude It is recommended that two different measurement
techniques be used
Wax / Paraffin
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APR-2006 33
Flow Assurance and Operability
Lab Analyses for Wax Cloud Point Direct Methods
Crossed Polar Microscopy Filtration Cold Finger Deposition
Indirect Methods Differential Scanning Calorimetry (DSC) Viscometry
Other Methods Infrared Detection Light Scattering NMR - Nuclear Magnetic Resonance
Wax / Paraffin
APR-2006 34
Flow Assurance and Operability
Lab Analyses for Wax Compositional Analysis A detailed compositional analysis of the oil
Required for modeling of wax deposition A quantitative compositional analysis out to C80+ (or higher) is
required
High temperature gas chromatography
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APR-2006 35
Flow Assurance and Operability
Lab Analyses for Wax Wax Deposition Tests Wax deposition models are most reliable if combined with
deposition rate measurements from the lab There is limited validation to real systems
Wax deposition is usually measured in the lab using flow loops or cold fingers
Output of tests is diffusion coefficient Testing of chemical inhibitors
Wax / Paraffin
APR-2006 36
Flow Assurance and Operability
Lab Analyses for Wax Wax Deposition Tests
Wax / Paraffin
Ref. Leontaritis, SPE, 2003.
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APR-2006 37
Flow Assurance and Operability
Lab Analyses for Wax Pour Point Lowest temperature at which an oil is observed to flow,
when cooled under conditions prescribed by test method ASTM D 97. The pour point is 3C (5F) above the temperature at which the oil in a test vessel shows no movement when the container is held horizontally for five seconds.
Wax / Paraffin
APR-2006 38
Flow Assurance and Operability
Lab Analyses for Wax Gel Strength Gel strength is usually measured using model pipelines or
controlled strain rheometers Consider the effects of
shear and thermal history Both test methods can be
used to test pour point depressants
Wax / Paraffin
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APR-2006 39
Flow Assurance and Operability
PREDICTION AND DESIGN STRATEGIES Predictive Modeling for Wax Wax deposition modeling Restart pressures
Wax / Paraffin
APR-2006 40
Flow Assurance and Operability
Wax Deposition Modeling Models are available for predicting deposition rates Ideally combined with deposition rate measurements from
the lab There is limited validation to real systems Deposition modeling errors can be large as much as a
factor of 3 Used to predict pigging frequency
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APR-2006 41
Flow Assurance and Operability
Wax Deposition Modeling There is some uncertainty about the deposition
mechanism Molecular diffusion primary mechanism Shear dispersion Other?
Wax deposits grow from the pipe/tube wall Deposits can be sheared off (sloughing) Flow regime can influence deposits
Wax / Paraffin
APR-2006 42
Flow Assurance and Operability
Wax Deposition Modeling
Wax / Paraffin
PIP
EWA
LL
HEATLOSS
LAMINARBOUNDARY
TURBULENTBULK FLOW
VELOCITYPROFILE
WAX CONCENTRATION GRADIENT
DIFFUSION OF DISSOLVED WAX
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APR-2006 43
Flow Assurance and Operability
Wax Deposition Modeling Diffusion Equation (Ficks Law)
Ji = A Di (ci/z) = A Di [(ci/T) (T/z)]
where Ji = diffusion rate of component iA = areaDi = diffusion coefficient for component i
Wax / Paraffin
Concentration gradient Temperature gradient
Solubility of component i as a function of temperature
APR-2006 44
Flow Assurance and Operability
Wax Deposition Modeling Wax deposition requires outward heat flux The wax deposition rate is proportional to the heat flux Deposition depends upon the oil viscosity, D 1/ Other
Shear effects Less deposit at high shear Softer deposit at low shear
Oil porosity of deposits (20 90%)
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APR-2006 45
Flow Assurance and Operability
Wax Deposition Modeling
Wax / Paraffin
Laminar Turbulent Annular Flow Stratified Slug
APR-2006 46
Flow Assurance and Operability
Wax Deposition Modeling
Wax / Paraffin
Distance
Low T
urbule
nce
Highly
Turbu
lent
Lami
nar
Deposition Rate Profile
Dep
osit
Thic
knes
s
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APR-2006 47
Flow Assurance and Operability
Wax Deposition Modeling
Wax / Paraffin
Wax Layer Thickness Profile - Oil Export Line50K BOPD, 3025 psi
0.00
0.01
0.02
0.03
0.04
0.05
0.06
0 20000 40000 60000 80000 100000 120000 140000Distance From Inlet (ft)
Wax
Lay
er T
hick
ness
(ft)
After 1-monthAfter 7-month After 3-month After 5-month
1 mon.
3 mon.
5 mon.
7 mon.
APR-2006 48
Flow Assurance and Operability
Wax Deposition Modeling
Wax / Paraffin
Wax Volume Accumulation - 16.124-in Export Line50K BOPD, 3025 psia
0
10
20
30
40
50
60
0 2 4 6 8 10 12 14Period (Month)
Wax
Vol
(bbl
)
0
0.2
0.4
0.6
0.8
1
1.2
Max
Wax
Thi
ckne
ss (i
n)
Wax Vol (bbl)Max Wax Thickness (in)
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APR-2006 49
Flow Assurance and Operability
Wax Deposition Modeling Pigging Frequency
Estimated from deposition modeling Wax thickness (2 4 mm) Total wax volume (depends upon facility capacity)
Wax / Paraffin
APR-2006 50
Flow Assurance and Operability
Restart Pressure Prediction Based on measured Yield Stress (Gel Strength) Conservative prediction versus actual pressure seen in
the field There are more sophisticated models under development
Wax / Paraffin
)()()(4)(
m Diameterbar Stress Yield m Length bar Pressure Restart =
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APR-2006 51
Flow Assurance and Operability
WAX CONTROL AND REMEDIATION Mechanical removal
Pigs
Thermal management Insulation Active heating
Chemicals Deposition inhibitors (minimize deposition) Pour point depressants (reduce pour point) Flow improvers (reduce viscosity)
Other
Wax / Paraffin
APR-2006 52
Flow Assurance and Operability
Pigging Most commonly used method for removing wax deposits Pigging can be successful and cost effective if regularly scheduled Pigs can become stuck in wax deposits when too much has
accumulated Pigs do not remove the entire wax deposit, but leave a smooth layer The pig should be specifically designed for paraffin removal Pigging frequencies should be optimized based
upon field observation A regularly scheduled pigging program should be
initiated upon commissioning, optimized based upon field experience, and followed religiously.
Wax / Paraffin
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APR-2006 53
Flow Assurance and Operability
Other Mechanical Removal Wireline Cutting
Wireline cutting of wax deposits in wellbores is a common Need to consider the frequency of wireline workovers and the
downtime For subsea wells, the cost may be cost prohibitive
TFL (Through Flowline Pigging) TFL pumps a cutting tool down the flowline and into the wellbore
to cut wax deposits. TFL is not a common practice It can remediate subsea flowlines and wellbores BP Pompano
Wax / Paraffin
APR-2006 54
Flow Assurance and Operability
Thermal Management Maintain fluid temperature above
cloud point Prevent deposition Prevent viscosity concerns
Minimize heat flux Minimize deposition
Provide cooldown time to pour point Provide operators with time to respond to shutdown
Wax / Paraffin
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APR-2006 55
Flow Assurance and Operability
Thermal Management Wellbore Insulation
Vacuum insulated tubing Gelled packer fluid
(e.g. Insugel by BJ Services)
Active heating Electrical heating Hot fluid circulation Not commonly applied
Wax / Paraffin
APR-2006 56
Flow Assurance and Operability
Thermal Management Flowline Insulation
Pipe-in-pipe Syntactic / other foam external insulation Buried pipe
Active heating Hot fluid circulation in bundle Electrically heated with insulation
Wax / Paraffin
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APR-2006 57
Flow Assurance and Operability
Paraffin Treating Chemicals Deposition Inhibitors Paraffin inhibitors can reduce wax deposition rates Inhibitors cannot completely prevent wax deposition Can reduce deposition rate by a factor of 5 Typically combined with pigging Inhibitors can create a soft deposit that is easily pigged or
sloughed off There is no universal wax deposition inhibitor Significant OPEX
Wax / Paraffin
APR-2006 58
Flow Assurance and Operability
Paraffin Treating Chemicals Deposition Inhibitors Wax inhibitors may be
wax crystal modifiers co-crystallize with the wax to prevent wax crystal from forming on the pipewall
dispersants coat wax crystals to keep them from agglomerating surfactants water wet the wax crystals so that the do not adhere
to each other or the pipe wall combination of all three
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APR-2006 59
Flow Assurance and Operability
Paraffin Treating Chemicals Deposition Inhibitors Wax deposition inhibitors should be selected using the
same procedures for measuring wax deposition rates. Inhibitor effectiveness can be temperature dependent Inhibitor may need to be changed after initial startup or
other time in the field life
Wax / Paraffin
APR-2006 60
Flow Assurance and Operability
Paraffin Treating Chemicals Pour Point Depressants Pour point depressants can reduce pour point, viscosity,
and/or yield stress Pour point depressants should be selected using the
same test procedures as used for measuring pour points, yield stress and viscosities
Flow improvers used to reduce viscosity
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APR-2006 61
Flow Assurance and Operability
Paraffin Treating Chemicals In general, all types of paraffin treating chemicals should
be applied at a location with a temperature greater than the cloud point (at least 10F or 5C above cloud point)
These chemicals are very crude oil specific no guarantee a suitable chemical can be found
Cannot predict inhibitor effectiveness lab testing is required
Must work with chemical vendors Injection rates as high as 100-1000 ppm are common
Wax / Paraffin
APR-2006 62
Flow Assurance and Operability
Other Methods of Deposition Prevention Do nothing if you have confidence that deposition rates
will not be significant over the lifetime of the well, flowline, or pipeline
Coatings yet to be effectively demonstrated Solvents not effective except at high temperatures or at
high solvent ratios Magnets some believe they can be effective, not
effective in controlled lab experiments
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APR-2006 63
Flow Assurance and Operability
Managing Gelled Restart Pipeline sizing
Pipelines are generally sized based upon maximum flow, but maximum pressure drop may be at low flow rates
Reduce the diameter and increase the flow velocity to have higher temperatures and lower viscosities, e.g. use two smaller pipelines rather than a single larger line
Chemical options Continuously inject pour point depressant
Wax / Paraffin
APR-2006 64
Flow Assurance and Operability
Managing Gelled Restart Insulation
Longer to cool during a shutdown
Active heating heat above pour point after shutdown Electrical heating Hot fluid circulation
Dilution Reduce viscosity and/or pour point by blending in diesel or a
lower wax content oil
Displacement During shutdown displace the oil with a lower wax content oil,
diesel, or water
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APR-2006 65
Flow Assurance and Operability
Managing Gelled Restart Core annular flow
Maintain a water layer at the pipewall: a very viscous oil flows as a solid core inside the water (has been done for heavy oils)
Oil-in-Water emulsions Form an oil-in-water emulsion with lower viscosity requires a
surfactant (has been done for heavy oils)
Other Maintain a low flow to prevent gelling Pulse oil to mitigate gelling
Wax / Paraffin
APR-2006 66
Flow Assurance and Operability
Remediation of Thick Wax Deposits Aggressive Pigs Progressive Pigging Wireline Cutting (wells) Coiled Tubing
Wells Coiled tubing has been used to jet out deposits in short sections
of flowlines
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APR-2006 67
Flow Assurance and Operability
Remediation of Thick Wax Deposits Coiled Tubing
Wax / Paraffin
Superior Energy Services
APR-2006 68
Flow Assurance and Operability
Remediation of Thick Wax Deposits Heat
Hot oil and hot water circulation can effectively melt deposits depending upon insulation and length
In-situ heat generation method (SGN) developed by Petrobras
Solvents Waxes are relatively insoluble in most solvents except at higher
temperatures A solvent may break down or soften the wax deposit so that it can
be more easily flushed or pigged out
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APR-2006 69
Flow Assurance and Operability
Remediation of a Gelled Pipeline If a oil in a pipeline cools below pour point and gels, and if
there is not sufficient pressure to break the gel and restart the pipeline, it may be difficult to recover.
Some potential solutions: Apply maximum pipeline pressure and wait Additional access points along the line can be used to apply
additional pressure Wait till summer, warmer temperatures Coiled tubing combined with heated solvent
Wax / Paraffin
APR-2006 70
Flow Assurance and Operability
Example Wax Management Guidelines
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APR-2006 71
Flow Assurance and Operability
Example wax control guidelines for subsea production system (low to medium wax content no gelling issues)
Operate the well at sufficiently high production rates to avoid deposition in the wellbore and tree
Consider using insulated tubing to maximize flowing wellhead temperatures
Note: very important not to have deposition in wellbore, too expensive to mobilize rig to scrape tubing
Remove wax from flowlines by pigging and pig frequently enough to ensure that the pig does not stick
Utilize insulation and chemicals to reduce pigging frequency
Wax / Paraffin
APR-2006 72
Flow Assurance and Operability
Example wax control guidelines for high wax content production system
Insulate wells and flowlines to minimize deposition and viscosity
Insulate to provide cooldown time to pour point Give operators time to restart or prepare system for long-term
shutdown
Inject pour point depressant to reduce pour point below minimum ambient temperature or to reduce gel strength
Provide restart capability Design pressure > restart pressure, or Displace flowlines with inert fluid following shutdown, before fluids
cool below pour point
Wax / Paraffin
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APR-2006 73
Flow Assurance and Operability
Viscosity
Wax / Paraffin