1. Pipeline Flow Assurance
Flow Assurance Introduction
Flow Assurance Problems
Production Chemicals Used
HCD Multi Flow Advantage
HCD Multi Flow Case Studies
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2. Pipeline Flow Assurance
What is Flow Assurance?
“Transporting the fluid from well to facility with low risk.”
Flow assurance, also known as multiphase transport, involves the transport of a mixture of oil, gas, condensates and water in the same pipeline.
It refers to ensuring successful and economical flow of hydrocarbon stream from reservoir to the point of sale.
Besides network modeling & transient multiphase simulation, flow assurance involves effectively handling many solid deposits, such as, gas hydrates, asphaltene, wax, scale and naphthenates.
Flow Assurance is critical in every field development.
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3. Pipeline Flow Assurance
Flow Assurance is now synonymous with wide range of issues, for example:
System Deliverability - pressure drop versus production, pipeline size & pressure boosting.
Thermal Behavior - temperature changes, insulation options & heating requirements.
Production Chemistry - hydrates, waxes, asphaltenes, scaling, sand, corrosivity & rheology.
Operability Characteristics - start-up, shut down, transient behavior (e.g. slugging etc.).
System Performance - mechanical integrity, equipment reliability, system availability etc.
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More recently however, the Flow Assurance problems encountered in oil and gas production have become more onerous, leading to an increased overall awareness in the industry.
This is particularly in the offshore sector, where low temperatures, remote locations & often great water depths of subsea environments conspire to exacerbate problems such ass erosion/corrosion, blockages through hydrate formation or wax deposition or topsides’ facilities shutdown due to severe slugging.
Moreover, the ramifications of these issues can be serious incurring significant intervention costs and substantial losses in production.
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5. Pipeline Flow Assurance
Physical – Chemical Flow Obstruction
Multiphase flow may be obstructed by physical phenomena such as liquid slugs or surges, or by physical- chemical phenomena. Of the latter four of the commonest are listed below:
Asphaltenes- the heaviest components in the crude oils, which may aggregate and precipitate in response to changes in chemical composition, pressure or temperature. Precipitation or deposition may occur in reservoir rocks, wellbores and pipelines.
Wax- a natural constituent in most petroleum fluids, this may be deposited on cold surfaces such as pipeline walls, increase the viscosity of oil until it ultimately gels and settle out at the bottom of storage tanks.
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Emulsions - water droplets in oil, which tend to be stabilized by natural oil components and in the presence of certain solid particles. As a result, they obstruct flow and complicate separation of produced water from oil.
Gas Hydrates – resembling snow balls or slush, these are crystalline materials comprising a framework of water molecules with their cavities filled by gas. Small clumps are easily carried along with flow but large cohesive blocks can cause a partial or complete blockage.
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7. Pipeline Flow Assurance
Scale in Oil Production Facilities
Oilfield scale consists mainly of inorganic salts with calcium carbonates, barium and strontium sulphates as the commonest components.
Scale can from brine (formation water) as it undergoes changes in pressure and temperature, or where two incompatible fluids are intermingled.
Scale problems can arise in various circumstances:
During drilling and well completion, if the drilling mud or completion fluid is incompatible with the formation water.
At the commissioning stage of new injectors, if the injection water is incompatible with formation water.
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8. Pipeline Flow Assurance
During production, when a well starts to produce formation water with the hydrocarbons.
During well stream processing, when significant quantities of produced water put process equipment at risk.
Commingled production, where wellstreams from various formations, reservoirs or individual wells are mixed together, can make matters worse.
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9. Pipeline Flow Assurance
Predicting
Prevention
Monitoring
Problem Solving
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Production Chemicals:
Pour Point Depressant
Paraffin Inhibitor/ Wax Inhibitor
Asphaltenes Dispersant
Hydrate Inhibitor
Scale Inhibitor
Drag Reducer
Defoamer/ Antifoam
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11. Pipeline Flow Assurance
HCD MultiFlow (Pipeline Viscosity & Drag Reduction)
HCD MultiFlow is a revolutionary conditions specific deposit reliquification product designed specifically for oil transfer flow line deposition.
HCD MultiFlow was developed by HCD scientists and engineers to liquefy and remove asphaltene and paraffin deposits in oil flow lines.
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12. Pipeline Flow Assurance
How It Works:
The reliquification is accomplished by breaking down the chemical bonds which exist between individual carbon chains and substituting smaller carbon chains in their place carried by HCD Multi-Flow.
HCD Multi-Flow reliquifies the hydrocarbon chain in any deposits on contact, reducing asphaltene and paraffin flow restrictions in the transfer line.
This reduction aids in reducing under deposit corrosion, increases flow line size, increases flow rate and reduces sludge layers along pipe walls.
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Applications:
Flow line “pigging” substitute
Continuous flow line injection
Oil flow lines from ships and ship to shore transfer lines
Oil flow lines to holding tanks.
Benefits:
Rapid line clean-up
Removes the risk of a “stuck pig” incident
Reduce oil viscosity/ increase flow rate
Non-toxic
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14. Pipeline Flow Assurance
Biodegradable
Raises API specific gravity and reduces viscosity
No hazardous product handling
Reduces heating or steam line requirements.
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15. Pipeline Flow Assurance
The HCD Multi-Flow Additive introduces a carbon molecular blend to produced fluids that prevents like molecular aggregation of waxes, asphaltenes and resins.
This mechanism allows HCD to provide a uniquely long lasting flow assurance solution for pipeline and storage tank crudes.
HCD is not a Polymer, Surfactant or a conventional Flow Improver - HCD is a molecular Disaggregator.
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HCD attacks the root cause of the paraffin networking and asphaltene aggregation by interrupting the like molecular forces (London Forces) responsible for viscosity increase and solidification- freeing the individual molecules from these structures – resulting in liquefication and flow assurance.
HCD achieves rapid in-line separation of the water and oil phases, breaking emulsions and eliminating foam.
HCD MULTIFLOW will also prevent deposition of Hydrocarbon solids (sludge) on the flow line walls and in the cargo tanks.
HCD MULTIFLOW will also prevent Hydrocarbon deposition on Heat Exchangers, Hydro-Cyclones and other process equipment vulnerable to wax and asphaltene deposition.
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17. Pipeline Flow Assurance
HCD MultiFlow is a multi purpose additive – this single chemical additive replaces the need for:
Pour Point Depressants
BS&W Control Additives
De- Emulsifiers
Anti- Foaming
Anti- Waxing Agents (chemical ‘pigging’)
Heating (Savings on Steam & Heat Exchanger Requirements)
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HCD MultiFlow has the following advantages over alternative chemical additive regimes:
High Flash point of 97°C so it stays in the produced crude.
Hydrophobic non water based – so it does not contaminate the water phase.
Organic molecular blend (does not harm the crude or affect refinery processes)
Low toxicity (HSE)
Low volatility (HSE)
Easy to handle fluid
Prevents under deposit corrosion.
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The International Board of Environmental Health and Safety, Inc (IBOEHS) has awarded HCD Multi-Flow the Safety Product of the Year.
The HCD Multi-Flow was selected because it plays a vital role in reducing the need for harmful chemical additives in the extraction and transport of crude oil, as well as making oil production more efficient.  Furthermore, as HCD Multi-Flow is acknowledged for being non-toxic and replacing chemicals that cause harmful exposures to workers, their communities and the environment.  Chemicals that HCD replaces are highly toxic and they include conventional flow assurance additives such as Benzene, Toluene and Xylene blends (BTXs).  HCD Multi-Flow also replaces certain Polymer and Monomer technologies and Pour Point Depressants – many of which are extremely toxic to the marine environment and aquatic life.
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20. Pipeline Flow Assurance
HCD CARBON CHEMISTRY VISCOSITY TREATMENT
- Souedie Field, Syria: HCD Flow Assurance, 2010
Crude Oil Character
Paraffinic & Asphaltenic Heavy Oil – API 9 – 12
High Viscosity ,000 cps at 20°C
Client
SPC (Syria Petroleum Company)
Introduction: Transfer line Flow Assurance for Enhanced Oil Recovery Elimination on Paraffin and Asphaltene based Viscosity
Purpose: The purpose of the trial was to inject the HCD additive into the flow transfer line at the well head in a way that adequately mixes the chemical product with the high viscosity crude.
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21. Pipeline Flow Assurance
Results: Results were measured in terms of resistance in the line, Flow rate at the Gathering Station and sample readings for wax and asphaltene were taken from the valve at the end of the 5km pipeline run.
The well produces at a rate of 10m³ of liquid per day with a water cut of 20%. The API gravity of this crude is 9.0 to 12.0 (well data records)
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Summary of Results:
The HCD Molecular blend worked on the heavy paraffinic and asphaltic crude:
An initial drop in flow rates was due to the deposition on the walls of the pipeline being freed into suspension.
After three days pipeline flow size and flow rate had increased.
Even at temperatures averaging 12 deg C – some 53 degrees below the Pour Point - the additive reduced wax levels and ensured flow.
Asphaltenes were reduced with similar effectiveness
An API lift was observable in the treated crude from 11 to around 13.7 (600ppm) and around 15.2 (1000ppm)
Optimal cost effectiveness seemed to recommend dosages of around 600 PPM
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HCD PPE - Trial of HCD MultiFLow (PPE) for wax, asphaltene, BS&W control at Puteri platform and pipeline (PMO)
Puteri Crude has a very high pour point due to its high wax content.
Pour point of Puteri crude – 47 – 49 °C
Client: NEWFIELD (NFX)
PETRONAS CARIGALI SDN BHD (PCSB – PMO)
Site:
Oil wells (from -1300m to Well Head) and 14 km long Pipeline from Puteri Platform to BUK FPSO (PMO)
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Observations & Key Findings:
Flow Assurance:
HCD Multi-Flow outperformed Roemex at the same dosages.
Injection at the chemical mandrels proved to be very advantageous – optimizing the mixing of the HCD PPE additive.
The additional injection at the well-head made some impact but lacked the mixing the chemical mandrel injection points offer.
At higher dosages the Pour Point and the Remelt Temperature seemed to diverge. This may be partly due to the testing conditions and slower heating would provide more accurate analysis.
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29. Pipeline Flow Assurance
The thermodynamics of Puteri crude need to be assessed and applied to the analysis of the cooling times between different temperatures. For example, it may take longer to cool from 34 deg C to 32 deg C than it does from 36 deg C to 34 deg C. This will have strategic significance for the 3rd mode of production.
These results are on the co-mingled (Penara & Puteri) crude. If HCD PPE was being injected at both Platforms the Pour Point Readings at the Turret would be lower
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30. Pipeline Flow Assurance
BS&W:
The effect of HCD Multi-Flow on the Shake-Out tests – freeing the trapped water as the crude rises has major economic benefits.
The effect of HCD Multi-Flow in reducing BS&W readings after the third separator on the FPSO (by 3.5 times) has major economic implications, particularly in view of:
A) discounts incurred for off-spec crude.
B) Savings on the FPSO Water Separation Line (Savings on Surfactants; Demulsifiers; and Time & Energy)
These results are on the co-mingled (Penara & Puteri) crude. If HCD PPE was being injected at both Platforms the
BS&W readings could be on-spec even before the crude is processed at BUK FPSO
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