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Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
Subsea Survery Presentation
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Subsea Survery Presentation

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

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

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  • 1. Developments in Internal Analysis Technology for Enhanced IRM ofHydrated or Blocked Subsea Pipelines Presented by: Fernando Hernandez Subsea Operations Manager Wright’s Well Control Ser ices Services 1 of 4
  • 2. IntroductionToday I will describe a three-pronged approach to the y three-p g ppInspection, Repair and Maintenance of hydrated or blockedpipelines. This strategy encompasses the WWCS HybridValve Pack with the inclusion of Nucleonic Testing forinspection, and the WWCS Hydrate Remediation Systemfor repair.I will also touch on how all three technologies canintegrate for enhanced overall pipeline maintenance andhydrate/blockage prevention. 2 of 4
  • 3. Subsea InspectionDetermining 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 AssetsNote: M lti l hydratesN t Multiple h d t can f form within a single circuit ithi i l i it 3 of 4
  • 4. Subsea InspectionDetermining 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. 4 of 4
  • 5. Inspection Equipment: WWCS Hybrid Valve PackTechnical 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 5 of 4
  • 6. HVP Integrated with ROV Porch 6 of 4
  • 7. Inspection Equipment: WWCS Hybrid Valve Pack yHow 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- 7 of 4
  • 8. Inspection Equipment:WWCS Hybrid Valve Pack y 8 of 4
  • 9. Hybrid Valve Pack Deployment Internal/Internal InspectionDeployment 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 9 of 4
  • 10. Hybrid Valve Pack Deployment Internal/Internal InspectionQuantifying 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 10 of 4
  • 11. Hybrid Valve Pack Deployment Internal/Internal InspectionZeroing 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 11 of 4
  • 12. HVP Schematic 12 of 4
  • 13. Inspection Equipment Nucleonic Testing HybridizationTechnical 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 13 of 4
  • 14. Inspection Equipment Nucleonic Testing HybridizationHow 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 14 of 4
  • 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 15 of 4
  • 16. Nucleonic Testing Hybridization Deployment External/Internal Inspection 16 of 4
  • 17. Subsea Asset Repair WWCS Hydrate Remediation SystemWright’s designed and built the system in 18 months for a major energycompany 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 fluidsOn a subsequent job, the system: cleared an asphaltene and paraffin blockage mixed with hydrates in 4,200’ WD 17 of 4
  • 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 18 of 4
  • 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 19 of 4
  • 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 20 of 4
  • 21. 3rd Party WWCS Systems IntegrationThe skid, gas separator and HVP are fully capable ofaccommodating the following, as they adhere to API followingstandards: 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 21 of 4
  • 22. Develop Repair StrategyRepair/Remediation Strategy – Identify which Hydrate p gy y yAccess 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 22 of 4
  • 23. HAP Engagement Via ROV 23 of 4
  • 24. Blockage Repair EngagementEmploying the HVP will provide the clearest picture of thehydrate d/ blockage. Addi i nucleonic t ti willh d t and/or bl k Adding in l i testing illfurther improve the analysis leading to the best overallstrategy for the repair engagement.Result: The three prong approach to IRM for hydrateremediation in action 24 of 4
  • 25. Three Repair Engagement ScenariosScenario 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 25 of 4
  • 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. 26 of 4
  • 27. Three Repair Engagement ScenariosScenario 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 27 of 4
  • 28. HVP Single & Multiple Blockage Screen ShotsSingle Blockage Multiple Blockages 28 of 4
  • 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). 29 of 4
  • 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 30 of 4
  • 31. MaintenanceAssisting 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 31 of 4
  • 32. The Outlook for Pipeline IRM and Flow AssuranceStrategies 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. 32 of 4
  • 33. The Outlook for Pipeline IRM and Flow AssuranceStrategies 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. 33 of 4
  • 34. Thank You Wright’s Well Control Services Office: 281-446-0273 281-446- Technical Contacts: Fernando Hernandez David Wrightfchernandez@wwcs911.comfchernandez@wwcs911 com dcwright@wwcs911.com dcwright@wwcs911 com Project Managers: John Kenny Tommy Johnsonjjkenny@wwcs911.com thjohnson@wwcc911.com 34 of 4
  • 35. Questions? 35 of 4

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