Process Engineering Solutions

Comparison between API 521,6th edition, 2014 & 5th, edition,2008

Posted on March 19, 2017 | in FLARES & RELIEF VALVES | by

What’s new in API 521, 6th edition, 2014

When  APIStd 521, 6th ed. Jan, 2014 was issued, the ISO 23251 was removed.

In this post, all major changes from  APIStd 521,5th, Jan 2007 (Addendum, May 2008 are enlisted.

Sec. 3.1 General update of Terms and definitions

Changes are given below as updates(in italics) & new definitions

3.1.5 availiability

3.1.7 balanced Pressure-relief valve

3.1.8 blowdown drum

3.1.11 buoyancy seal

3.1.15 burn-pit flare

3.1.16 choke valve

3.1.19 combustion efficiency

3.1.20 confined fire

3.1.36 fuel-controlled fire

3.1.44 lift-off (replaces blow-off)

3.1.51 open fire

3.1.58 pressure-relief device

3.1.60 pressure system

3.1.65 rated capacity

3.1.69 required relief rate

3.1.70 risk

3.1.85 ventilation-controlled fire

Sec. 3.2 Acronyms and Abbreviations (New)

Sec. 4.2.5 Operator Error / Effect of Operator Response

 

Section “Effect on operator response” and “Operator error “ has been combined

New paragraph added on items to consider when credit is taken for operator intervention

1 Alarm available

2 Sufficient time for the operator to diagnose the alarm

3 Operator is trained

4 Consequences of operator intervention are understood

5 Probability of alarm failure and/or ineffective operator intervention is evaluated.

 

 

Sec. 4.4.8.6Choke Valve Failure (New)

New Section added for Choke Valve Failure (Choke Collapse)

…The design flow should include the additional flow arising from a single failed choke as the worst case flow for overpressure calculations and system response requirements. A dynamic analysis may be required to determine these effects (see 4.3.3). The user should determine whether choke valve collapse is a basis for design or not credible.

Measures to consider for mitigating the consequences of a choke failure include:

1 Pressure-relief device;

2 Using multiple smaller valves

3 Selection of high integrity choke designs

4 Use of dedicated choke valves or change of choke trim

5 Perforated plate in the flow path.

Sec. 4.4.9.3Check Valve Leakage or Failure

Three reverse flow conditions and when these should be considered:

1 Complete Check Valve Failure

2 Severe Check Valve Leakage

3 Normal Check Valve Leakage

4.4.9.3.2.2 Severe Check Valve Leakage

The potential for overpressure caused by reverse flow through one or more check valves in series should beconsidered where the maximum operating pressure of the high-pressure system is greater than the low-pressureequipment’s corrected hydrotest pressure.

For certain rotating equipment such as reciprocating compressors and positive displacement pumps, the user maydetermine that significant reverse flow through the machinery will not occur. Overpressure due to normal check valveleakage should still be considered.

OLD TEXT 5TH EDITION

Required overpressure protection if the operating pressure of the high pressure system are greater than the design pressure (Refer Sec. 4.3.4.2, 5th ed.)

Where no specific experience or company guidelines exist, one may estimate the reverse flow through seriescheck valves as the flow through a single orifice with a diameter equal to one-tenth of the largest check valve’snominal flow diameter. A lower value may be used if a condition-monitoring system for the check valves (e.g.pressure indicators with appropriate volumes between the check valves) is installed to monitor the condition toensure that the leakage rate is below the capacity of the low-pressure side relief device.(Refer Sec. 4.3.4.4, 5thed.)

As per 5th ed. allowed the reverse flow through the check valves to be less than specified above for series of check valves provided with condition monitoring system.

In 6th ed., This has been deleted and in  Sec 4.4.9.3.3 Calculation of Reverse Flow Through Failed Check Valves recommends the estimation of reverse flow

  • Treat the check valve as an orifice with a diameter equal to 10 % of the check valve’s nominal flow diameter (i.e.orifice area equal to 1 % of the nominal flow area).The reverse flow is calculated using the orifice area, the relieffluid properties, the maximum operating pressure on the side normally downstream of the check valve, and theallowable accumulation on the side normally upstream of the check valve.
  • Treat the check valve as an orifice that is sized to pass 10 % of the normal forward flow. The orifice area is calculated using the normal fluid properties, maximum operating pressure on the upstream side of the checkvalve, and the maximum operating pressure on the downstream side of the check valve. To determine thereverse flow rate, this orifice is then rated using the relief fluid properties, the maximum operating pressure onthe side normally downstream of the check valve.

 

Sec. 4.4.16Overpressure Prevention During Maintenance

Sources of overpressure during maintenance are included in 6thed. These activities are generally part of precommissioning and commissioning. Use of administrative controls or a PRD is suggested to prevent overpressure in such case.

 

Sec. 5.4.4 Header Segregation (New)

Flare header should be segregated based on the sources to relief headers as well as their knockout drums

  • Pressure: to segregate the relief flows from high and low pressure sources to maintain backpressures on PRDs within allowable limits.
  • Temperature
  • Fluid Composition/ Physical Properties: New exhaustive list is provided in this Sec.
  • Water-wet fluids should be segregated from cold fluids to prevent ice/hydrate.
  • List of what to consider when designing the relief discharge from rupture discs…

Sec. 5.5.12Acoustic Fatigue (New)

 

Sec 5.5.12.1 Background

  • High pressure drops across valves e.g. PRV, orifice plates, changes in piping diameter or gas piping restrictions cause noise downstream
  • High-energy, high-frequency noise cause high-frequency vibration in pipe wall that can result in rapid fatigue
  • Fatigue screening method byCarucci and Mueller involved calculation of Sound Power level at the noise source

 

Sec 5.5.12.2 Sound Power Level

  • Guidance on calculation the Sound Power Level

Sec 5.5.12.3 Mitigation Options

 

Sec. 5.7.2.4Flame Stability (New)

Four stages of observable flame stability are given.

Sec. 5.7.3Combustion Methods

This section is restructured including with some new sections

Sec 5.7.3.2.10 Control of Fluid Injection for Smoke Suppression(New)

Methods of controlling steam (or compressed air, water and so on) for smokeless flare control are

1 Manual Operation

2 Video Monitoring with Manual Control

3 Feed Forward Control System for Pressure, Mass Flow or Velocity

4 Feedback System Using an Infrared Sensor

 

Sec 5.7.3.2.11 Noise Caused by Smokeless Flaring (New)

 

Sec. 5.7.9Flare Knockout Drums

Old 5th ed. Sec 7.3.2.1….Outlet nozzles should have adeflection plate or baffle to minimize carry-over.

New 6th ed. Sec 5.7.9.2….In general, vapor outlet nozzles should not be fitted with any devices (e.g. deflection plates, baffles, demister pads,vane packs, etc.), because of the potential for such devices to fail or plug and obstruct the outlet. Such devices shouldbe used only if the drum is equipped with an alternate outlet nozzle sized for the drum’s design vapor flow rate andfitted with a rupture disk (or buckling pin device) whose burst pressure is selected both to protect the drum againstoverpressure and to permit proper operation of the drum and relief system in the event the normal vapor outletbecomes obstructed.

Sec. 5.7.9.4 Droplet Size Criteria for Flare Drums

5th ed. Sec 7.3.2.1.2 …The vertical velocity of the vapour and gas should be low enough to prevent large slugs ofliquid from entering the flare. The presence of small liquid droplets increases thermal radiation fluxes and smokingpotential. Long-term field experience has shown that the dropout velocity in the drum may be based on thatnecessary to separate droplets from 300 μm to 600 μm in diameter. Droplets of larger size can result inincomplete combustion with excessive smoking, possible “burning rain”, and even flame-out.

6th ed. Sec 5.7.9.4 …guidance on droplet size and liquid loadings for several types offlare burners.

  1. Unassisted Flare Burners—Large liquid droplets cannot be handled smokelessly without smoke-suppressionequipment. Burning rain is generally considered possible in an unassisted pipe flare for liquid droplets with adiameter of 600 μm or larger.
  2. Steam-assisted and Air-assisted Flare Burners—Flare gases containing less than 1 % by mass of liquids up toa liquid droplet size of 600 μm can be handled smokelessly and without burning rain. Some air assisted burnerswith small ports and operated at significant pressures can handle larger amounts, and with larger droplet size,without smoke.
  3. High-pressure (i.e. Sonic Type) Flare Burners—If operated at gauge pressures of at least 200 kPa (30 psi),these flare burners can handle flare gases containing 1 % by mass of liquids up to a liquid droplet sizeof 1000 μm, without smoke.

 

Sec. 5.7.9.5Sizing (of Knockout drum)

Section 5.7.9.5 in 6th ed. Specifies sizing criteria for amount of liquid when liquid content cannot be estimated.

…If no valid liquid case exists and the vapor is either condensible or has a condensible component, then thedesign liquid case should be a minimum of 2 wt % of the maximum gas rate to the flare knockout drum.

Sec. 5.7.9.8Knockout Drums for Oil and Gas Production Facilities (New)

Section 5.7.9.8 Describes the challenges with designing Knockout Drums for overfill protection for oil and gas offshore platforms or onshore oil & gas installations compared to refineries or petrochemical plants.

…Sizing a knockout drumto contain 20 min to 30 min of this flow (the sizing basis suggested in 5.7.9.5 for a “typical” facility) is frequentlyimpractical for both transportation to and installation in an oil and gas production facility, whether onshore or offshore.

Design recommendations for overfill protection:

  • …the knockout drum surge capacity may be based on 1 min to 2 min of continued flow starting once thepoint is reached where the automatic shutdown is initiated by the flare knockout drum instrumentation. This timeconsiders a conservative estimate of the closure times of the shutdown valves. The flow rate to the knockout drumduring this period should consider the full production flow from all producing wells/flow lines.
  • …the flare knockout drum should have sufficient surge capacity (e.g. 20 min between the normal level and the LAHH (high-high liquid level alarm)) to avoid spurious trips during normal flaring.

 

 

 

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