Presentation developed for SubseaSurvery IRM. Detailing methodology for the assesment of blockages in subsea pipelines. Presented by Fernando Hernandez for Wrights Well Control Services.

1. Developments in Internal Analysis
Technology for Enhanced IRM of
Hydrated or Blocked Subsea Pipelines
Presented by:
Fernando Hernandez
Subsea Operations Manager
Wright’s Well Control Ser ices
Services
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2. Introduction
Today I will describe a three-pronged approach to the
y three-p g pp
Inspection, Repair and Maintenance of hydrated or blocked
pipelines. This strategy encompasses the WWCS Hybrid
Valve Pack with the inclusion of Nucleonic Testing for
inspection, and the WWCS Hydrate Remediation System
for repair.
I will also touch on how all three technologies can
integrate for enhanced overall pipeline maintenance and
hydrate/blockage prevention.
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3. Subsea Inspection
Determining Factors for Inspection – Pressure Differential
 Th emergence of a pressure differential b
The f diff i l between two or more
transducers/sensors within the same circuit serves as a strong indicator of
the formation of a blockage
 Examples of such locations are on a:
• PLET • FLET
• Pipeline • PLEM
• Riser • Other Subsea Assets
Note: M lti l hydrates
N t Multiple h d t can f
form within a single circuit
ithi i l i it
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4. Subsea Inspection
Determining Factors for Inspection – Loss of Continuity
 Loss of continuity within the same subsea assets will reveal that there
is no longer a path from which product can flow interrupted.
 Complete loss of production, well no longer able to produce due to
complete isolation and inability to flow to intended location
 P
Pressure builds up when medium in pipeline i fl i i an i l t d
b ild h di i i li is flowing in isolated
region. Source of pressure can be attributed to a well, or operator
attempting to flow through pipeline.
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5. Inspection Equipment:
WWCS Hybrid Valve Pack
Technical Details:
 Builds on existing valve pack design that is used directly on ROVs and
for ROV tooling
 Valves used to control thrusters and ROV functions have been
replaced with d th compensated and 1 atmosphere pressure
l d ith depth t d d t h
transducers designed specifically for interpretation of pipeline internals
 In addition the HVP accommodates a digital flow meter for chemical
injection
 Equipped to read in absolute pressure and to register pressure
differential in pipeline independent of hydrostatic p
pp p y pressure
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6. HVP Integrated with ROV Porch
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7. Inspection Equipment:
WWCS Hybrid Valve Pack
y
How It Works:
 Internal/internal system, meaning the pipeline is accessed internally
system
to gather data on the internals of the pipeline
 Minimum foot print is required allowing an ROV to remain completely
outfitted with other tools that may be needed for simultaneous
f f
operations
 HVP does not have to travel to surface due to real time and logging
gg g
capabilities as well as recorded charts
 Data can be transmitted back to land via e-mail for additional analysis
e-
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8. Inspection Equipment:
WWCS Hybrid Valve Pack
y
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9. Hybrid Valve Pack Deployment
Internal/Internal Inspection
Deployment to access points on pipeline and assets
 HVP will interface with connection points of interest
 Intent is to compare pressure readings of as many sections as
possible to log pressure differentials and points of equalization
where applicable
 L
Logging d t t register i t
i data to i t internals of pipeline
l f i li
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10. Hybrid Valve Pack Deployment
Internal/Internal Inspection
Quantifying rig/topside facilities sensor interpretation
 By using the HVP readings registered on surface via sensors that
HVP,
communicate back to a topside facility can be verified and cross
referenced to determine accuracy
 This highly beneficial approach will finalize and determine if pressure
differential that a topside facility is encountering is due to a faulty
transducer
 Functions as a mobile transducer station where a topside facility may
have loss all communications with subsea pressure sensors
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11. Hybrid Valve Pack Deployment
Internal/Internal Inspection
Zeroing in on affected area
 Carrying out inspection with a HVP will allow for greater accuracy in
determining where blockage(s) are located
 Eliminates having to interface at access points that will not yield high
results due to data gathered
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12. HVP Schematic
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13. Inspection Equipment
Nucleonic Testing Hybridization
Technical Details
 External/Internal data will give you readings that were acquired externally
to interpret and identify blockages not designed to register pressure
 Utilizes nucleonic measurement to aid in locating blockages
 Radioactivity allows for the scanning of pipelines to recover data
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14. Inspection Equipment
Nucleonic Testing Hybridization
How It Works:
 Attaches and integrates with an ROV
g
 Small foot print and quick installation due to its compact size
 Tethers to a ROV due to scanning components being housed in a frame
g p g
external to the pipeline
 In lengthy pipelines/circuits the scans conducted by this system are
segmented and done in sections, however scans of the entire system
sections however,
are highly beneficial, but time consuming
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15. Nucleonic Testing Hybridization Deployment
External/Internal Inspection
Zeroing in on affected area:
 Not dependent on pipeline hydrate and/or pressure
access points
 Enhances detection
• Designed to locate an isolated and singular blockage
• Can d t t a single bl k
C detect i l blockage th t h di l d d and partitioned
that has dislodged d titi d
• Fully capable of scanning and locating multiple blockages in a
pp
pipeline
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16. Nucleonic Testing Hybridization Deployment
External/Internal Inspection
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17. Subsea Asset Repair
WWCS Hydrate Remediation System
Wright’s designed and built the system in 18 months for a major energy
company in response to a hydrate blockage.
On this first deployment, the Wright’s system:
 cleared 15 miles of 12” pipeline in 7,200’ WD
12 7,200
 removed 9000 barrels of hydrocarbons, condensate and other fluids
On a subsequent job, the system:
 cleared an asphaltene and paraffin blockage mixed with hydrates in 4,200’
WD
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18. How the Wright’s Hydrate Remediation
System Works – Pump Skid
 Self-contained system with redundant pump skid and motor assembly
Self-
placed on the mud line utilizing skirted steel mud mats
 Powered by filtered seawater from the surface via coiled tubing from a
Multi-
Multi-Service Vessel or rig or left on the ocean floor for later use
rig,
 Not limited by a Remotely Operated Vehicle’s (ROV) hydraulic energy
 Has a discharge rate of 1 bpm (designed to pump up to 2 bpm)
 Generates a suction that can bring pipeline pressure down to -12psi
 Can pump both fluids solids (10% sand) and gases with no damage
fluids,
to the pipeline asset or the pump
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19. How The Wright’s Hydrate Remediation
System Works – Gas Separator
 Deployed in a modular fashion as a independent system that is
designed to interface on the top of the hydrate pump skid, and
separates gas from the fluids
 The first coiled tubing line sends gas free
flowing to a surface gas separator and/or
flare boom
 The second coiled tubing return line
receives the processed hydrocarbons and
other fluids to the surface for additional
processing and containment
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20. How The Wright’s Hydrate Remediation System
Works – Gas Separator
 A methanol injection panel prevents the formation of additional hydrates
 Several injection points throughout the hydrate skid and separator are
able to receive methanol
 A ball check in the stack prevents fluid from filling the gas line
 The gas separator has a built in sand trap
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21. 3rd Party WWCS Systems Integration
The skid, gas separator and HVP are fully capable of
accommodating the following, as they adhere to API
following
standards:
 Additional ROV tooling/equipment:
g q p
 Can compliment or work in conjunction with any other methodology in
regards to tooling or systems that a client may want to use
 Interfaces with clients subsea assets/infrastructures:
clients’
 Operates with any API specification for hot stabs, connectors and
connection systems
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22. Develop Repair Strategy
Repair/Remediation Strategy – Identify which Hydrate
p gy y y
Access Point to Engage
 Determined by accessibility
 Establish root cause analysis for hydrate and review associated data with
operator
 Di
Driven by which HAP will b i a b tt result and i closer t th
b hi h ill bring better lt d is l to the
blockage
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23. HAP Engagement Via ROV
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24. Blockage Repair Engagement
Employing the HVP will provide the clearest picture of the
hydrate d/ blockage. Addi i nucleonic t ti will
h d t and/or bl k Adding in l i testing ill
further improve the analysis leading to the best overall
strategy for the repair engagement.
Result: The three prong approach to IRM for hydrate
remediation in action
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25. Three Repair Engagement Scenarios
Scenario 1 (Single Blockage)
 This is an ideal situation for engagement where the blockage is small
and removed as one unit. The valve pack will identify HAP pressure
compared to the opposite side of the blockage
 The WWCS Hydrate Remediation System will continue to pull a
vacuum until HAP pressure equals pressure reading on the other
side
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26. Three Repair Engagement Scenarios
 Before I discuss split or multiple blockages is it important to
note that the trapped energy/pressure behind the most
immediate blockage can not be quantified until it is removed
removed.
 Once this is accomplished the pressure/energy formally on
the other side blockage will affect pressure at the HAP
HAP.
 If the trapped energy volume and pressure is higher than
HAP pressure, this will immediately show a pressure spike
in the HVP charts.
 If the trapped energy/volume is lower, this will decrease
pp gy ,
pressure reading due to energy now being distributed over a
larger area with lower pressure.
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27. Three Repair Engagement Scenarios
Scenario 2 (Single/Split Blockage)
( g p g )
 A larger single-sized blockage is engaged, pressure from HAP is
single-
decreased and brought below hydrate curve pressure, and
increases,
increases but during vacuum does not affect pressure reading on
opposite end. This demonstrates that the blockage has partitioned.
 Pumping continues by pulling a vacuum. If pressure drops and
increases, and fails to equalize with pressure on the opposite end,
then the hydrate is still present.
 This can become highly repetitive during remediation operations
operations.
 Remediation is ongoing until pressure equalization occurs thus
demonstrating blockage has been completely removed
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28. HVP Single & Multiple Blockage
Screen Shots
Single Blockage Multiple Blockages
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29. Three Repair Engagement Scenarios
Scenario 3 (Multiple Blockages)
 Situation where scans of pipeline reveal that the p p
pp pipeline of interest
has multiple blockages.
 These fragmented blockages are liable to keep breaking in to smaller
sections.
sections
 Monitoring of charts is imperative to identify exact points at which
hydrates are breaking.
 Follow same remediation steps outlined in Scenario 2 (Single/Split
Blockage).
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30. Blockage Removed
 Use HVP to verify opposite end HAP pressure - to ensure
complete equalization has occurred
 Upon equalization all data is gathered and centralized for
presentation to the client
 Final step - flood pipeline with hydrate inhibitors and/or
nitrogen, or chemical train. This will ensure once pipeline
is brought back online, there is a safeguard against future
g , g g
hydrates
 Demobilize equipment
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31. Maintenance
Assisting the client with flow assurance planning
 Taking preventative measures
 Advising on what access points are most strategic
 Utilizing the data to assist in maintenance of the pipeline via flow
assurance
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32. The Outlook for Pipeline
IRM and Flow Assurance
Strategies for the future:
 B utilizing lessons learned, th HVP nucleonic testing and the
By tili i l l d the HVP, l i t ti d th
Hydrate Remediation System can be used in conjunction to remove
hydrates or other blockages at the first sign of formation and BEFORE
the asset is completely shut down
down.
 WWCS, in partnership with other service companies, is advising
operators on the strategic placement of connection/HAP points on their
pipelines during rehabilitation or new construction.
 These connection points will enable the HVP to provide a clearer
picture of the hydrate or blockage so the optimal remediation approach
can promptly be executed.
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33. The Outlook for Pipeline
IRM and Flow Assurance
Strategies for the future:
 The pump/skid will further be optimized by not having to draw a vacuum
or inject chemicals from longer distances to attack the blockage.
 WWCS is in discussions with operators domestically and abroad to have
the
th pump/skid l d
/ kid lay dormant subsea adjacent t hi h yield assets f even
t b dj t to high i ld t for
prompter deployment - further supporting this proactive maintenance
strategy.
 When strategic access points, a dormant pump skid, the HVP and other
testing techniques are used in an integrated approach, pipeline operators
can shift their resources to a new flow assurance model and away from
reactive hydrate remediation/blockage removal.
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34. Thank You
Wright’s Well Control Services
Office: 281-446-0273
281-446-
Technical Contacts:
Fernando Hernandez David Wright
fchernandez@wwcs911.com
fchernandez@wwcs911 com dcwright@wwcs911.com
dcwright@wwcs911 com
Project Managers:
John Kenny Tommy Johnson
jjkenny@wwcs911.com thjohnson@wwcc911.com
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35. Questions?
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