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Handling Exchanger Bundles, Valves, and Pipe Spools

Heat-exchanger tube bundles, large valves, and pipe spools are the heavy components a refinery or gas plant removes, inspects, cleans, repairs, and reinstalls again and again over the life of a unit, and each one brings its own handling problem: a long cantilevered load, an offset center of gravity, or a flanged piece of a live piping system. UTEC Industrial designs, engineers, machines, fabricates, and installs custom material handling systems for aerospace and heavy industry from its Spokane Valley, WA facility, integrating Allen-Bradley PLC and motion control with in-house CNC machining, heat treating, and stress relief. This article covers which exchangers have a pullable bundle, the lifting-device and sling rules for the equipment that pulls and rigs these parts, the isolation and change control around each lift, and the controls a bundle extractor needs, along one build chain: design → engineering → parts machining → fabrication → assembly → weld fatigue → stress relief → drives → controls → tuning → monitoring.

Why do exchanger bundles, valves, and pipe spools dominate refinery maintenance handling?​

These three component families dominate because the mechanical-integrity paragraphs of OSHA's process safety management (PSM) standard, 1910.119(j)(1), name pressure vessels, piping systems, and valves, and the inspection and test rules that bring them out of service are covered in the turnaround handling article. A shell-and-tube exchanger is a pressure vessel, a valve is a named piping component, and a spool is a length of a piping system, and the records rule follows each of them through removal and repair: paragraph 1910.119(j)(4)(iv) requires each inspection and test to be documented with the date, the name of the person who performed it, the serial number or other identifier of the equipment, a description of the inspection or test, and its results.

OSHA's refinery findings show where the pressure falls. During the Petroleum Refinery PSM National Emphasis Program, OSHA found that failure to correct equipment deficiencies was one of the leading causes of PSM non-compliance in refining, and the equipment most commonly cited was relief devices, followed by piping circuits, pressure vessels, and alarm systems. Every bundle pulled, valve removed, and spool replaced is a physical step in closing out those inspection and deficiency requirements (OSHA 29 CFR 1910.119-2026, §1910.119 paragraphs j.1 and j.4.iv; OSHA 3918-08, 2017, pp. 17-18).

Which shell-and-tube exchangers have a bundle that can be pulled?​

Not every shell-and-tube exchanger has a removable bundle, and the handling plan starts by knowing which type sits in the unit. The Tubular Exchanger Manufacturers Association (TEMA) standard, in its 2026 edition, is the design and fabrication standard for shell-and-tube heat exchangers, and its nomenclature classifies each exchanger by its front head, shell, and rear head. Its rear-head types divide into fixed-tubesheet designs, in which both tube sheets are attached to the shell and the tube bundle is not withdrawn, and removable-bundle designs such as U-tube bundles and floating-head bundles, which can be withdrawn from the shell. That distinction decides whether the exchanger needs a bundle extractor at all.

Fixed-tube-sheet exchangers still matter to the handling engineer, because their cleaning and thermal behavior shape the work around them. Rößler et al. (2022) note that fixed-tube-sheet shell-and-tube heat exchangers are widely used in process plants, that even moderate temperature differences between shell and tube bundle can lead to failure mechanisms induced by thermal stress, and that design codes require an analysis of the transient response during special operating conditions. Among the scenarios they simulate is shell-side steaming-out, a cleaning procedure that removes hydrocarbon residues with steam.

For a removable bundle, the owner supplies:

  • The rear-head type and the pulling end. A U-tube bundle and a floating-head bundle present different faces to the extractor.
  • The bundle's weight, length, and tube-sheet diameter, from the exchanger's data sheet or nameplate, not from a comparable unit.
  • The exchanger's elevation and the clear space in line with the shell axis, since the bundle leaves along that axis.

The data sheet, not the extractor, sets the load (TEMA Standards, 2026 ed., Section 1 Nomenclature, Figure N-1.2; Rößler et al. 2022).

What does a bundle extractor have to control while it pulls?​

A bundle extractor has to grip the bundle, pull it along the shell axis, carry it as it leaves the shell, and land it on supports. Wherever part of that sequence is rigged or crane-suspended, the sling standard sets limits the extractor has to be designed around:

  • No shock loading. Paragraph 1910.184(c)(11) prohibits shock loading, so the pull has to be controlled so that no sudden load reaches the rigging.
  • Rated capacity. Under (c)(4), slings are not loaded in excess of their rated capacities, so the loads the pull and the carry put into the rigging have to be known.
  • People clear. Paragraph (c)(9) requires all employees to be kept clear of loads about to be lifted and of suspended loads, which limits where the crew guiding the tube sheet out of the channel can stand.
  • Obstructions. Under (c)(8), suspended loads are kept clear of all obstructions along the bundle's path.

The engineering answer is a machine that measures pull force and bundle position, so the pull can be slowed or stopped before the rigging sees a sudden load or a load beyond its rating (OSHA 29 CFR 1910.184-2019, §1910.184 paragraphs c.4, c.8, c.9, and c.11).

How are bundle extractors and lifting beams classified as below-the-hook lifting devices?​

Many bundle extractors hang from a crane hook, and so do the lifting beams, spreader beams, and custom fixtures used to lift valves and spools. Those devices fall under two ASME documents: ASME BTH-1-2023, Design of Below-the-Hook Lifting Devices, and ASME B30.20-2025, Below-the-Hook Lifting Devices, which is the safety standard for such devices. The first is the design basis; the second includes provisions for the marking, construction, installation, inspection, testing, maintenance, and operation of those devices.

BTH-1 assigns each device two classifications, and the owner or the designer should settle both:

  • Design category. BTH-1 assigns each device a Design Category, A or B, and Category B applies where the magnitude and variation of loads are not predictable or where the environment is severe or not accurately defined. Category B carries the higher design factor on static strength, 3.00 against 2.00 for Category A. An extractor pulling bundles of uncertain fouling, in outdoor conditions, is the kind of device a specifier should examine against Category B.
  • Service class. BTH-1 also assigns a Service Class by the number of load cycles over the device's life, beginning with Service Class 0 for up to 20,000 cycles, and the higher classes govern fatigue design of welded details. Because every pull and lift is a load cycle, the service class, weld detailing, and stress relief of the frame belong in the specification rather than being left to the fabricator.

B30.20 requires the rated load to be marked on the device and requires a new, altered, or repaired device to be load tested before first use at 125 percent of its rated load. Those markings and test records are what a refinery's contractor-evaluation and rigging procedures ask to see before a crane-suspended extractor goes into the unit (ASME BTH-1-2023, Chapter 2 Lifting Device Classifications and §3-1.3; ASME B30.20-2025, Chapter 20-1 §20-1.1.2 and §20-1.3.8).

What sling rules apply when rigging valves and pipe spools?​

Most valves and spools are rigged with slings, and OSHA 29 CFR 1910.184 sets the limits a refinery rigging plan works within. Several of its requirements bear directly on flanged, heavy, and sometimes contaminated components:

  • Sharp edges and balance. Paragraph 1910.184(c)(7) requires slings to be padded or protected from the sharp edges of their loads, which includes flange faces and bolt holes. Under (c)(5), slings used in a basket hitch must have the loads balanced to prevent slippage, and (c)(6) requires slings to be securely attached to their loads.
  • Removal criteria. Beyond the daily inspection and broken-wire limits the turnaround handling article covers, alloy steel chain slings are removed from service if hooks are cracked, opened more than 15 percent of the normal throat opening, or twisted more than 10 degrees from the plane of the unbent hook, under (e)(9)(ii), and a wire rope sling is removed at wear or scraping of one-third the original diameter of outside individual wires, under (f)(5)(ii).
  • Chemical exposure. Paragraph 1910.184(i)(6) prohibits nylon web slings where fumes, vapors, sprays, mists, or liquids of acids or phenolics are present, and polyester and polypropylene web slings where those of caustics are present. A valve pulled from an acid or caustic service can carry residue onto the rigging.
  • Temperature. Under (i)(7), nylon and polyester web slings are not used above 180 °F and polypropylene web slings not above 200 °F; fiber-core wire rope slings exposed above 200 °F are permanently removed under (f)(3). A spool or valve still warm from steam-out can exceed the synthetic limits.

These are the rules that a custom lifting beam or valve fixture, designed with rated attachment points, helps a crew meet on every lift instead of improvising around a flange (OSHA 29 CFR 1910.184-2019, §1910.184 paragraphs c.5 to c.7, e.9.ii, f.3, f.5.ii, i.6, and i.7).

Why does a heavy valve need a different handling approach from a spool?​

A pipe spool is usually a long load that can be slung along its length; a large valve is compact, with a bonnet, yoke, gearbox, or actuator mounted above the body. The rigging plan has to find a secure, rated attachment on the valve itself rather than on whichever of those parts protrudes.

The sling standard frames the fix. Paragraph 1910.184(c)(6) requires slings to be securely attached to their loads, and (e)(2)(i) requires hooks, rings, links, and other attachments on a chain sling to have a rated capacity at least equal to that of the chain, or the sling cannot be used beyond the rated capacity of its weakest component. Makeshift links or fasteners formed from bolts or rods are prohibited under (e)(2)(ii). On a valve, that points to purpose-built attachment points: rated lifting lugs on the body, a bolt-on lifting fixture that uses the flange bolt holes, or a cradle that carries the body and lets the valve be turned without re-rigging.

Two practical consequences follow for equipment design:

  • Turning is a separate operation. A valve removed with its stem vertical often has to be laid down, turned, and set on a repair stand. A turnover fixture or positioner that controls the rotation avoids an uncontrolled roll on the sling.
  • Actuators come off first or stay on by plan. The rigging plan states whether the actuator travels with the valve, because the answer changes the weight and the center of gravity.

The weight used for rigging should come from the manufacturer's data for the specific valve or from a weighed lift, not from a comparable valve (OSHA 29 CFR 1910.184-2019, §1910.184 paragraphs c.6, e.2.i, and e.2.ii).

What isolation has to be in place before a valve or spool is unbolted?​

Removing a spool or valve from a hydrocarbon system is, in OSHA's terms, line breaking, and the isolation has to be finished before the handling equipment is attached. The permit-required confined space standard defines line breaking as the intentional opening of a pipe, line, or duct that is or has been carrying flammable, corrosive, or toxic material, an inert gas, or any fluid at a volume, pressure, or temperature capable of causing injury. The same standard defines the isolation methods a refinery uses:

  • Blanking or blinding: the absolute closure of a pipe, line, or duct by fastening a solid plate, such as a spectacle blind or a skillet blind, that completely covers the bore and withstands the maximum pressure of the line with no leakage beyond the plate.
  • Double block and bleed: closing and locking or tagging two in-line valves and opening and locking or tagging a drain or vent valve between them.

PSM makes this a written work practice. Paragraph 1910.119(f)(4) requires safe work practices covering lockout/tagout, confined space entry, opening process equipment or piping, and control over entrance into the facility by maintenance, contractor, and other support personnel. Under the lockout standard, 1910.147(d)(5)(i) requires all potentially hazardous stored or residual energy to be relieved, disconnected, restrained, and otherwise rendered safe after lockout devices are applied, and (d)(6) requires the authorized employee to verify isolation and deenergization before work starts.

Where a line cannot be taken out of service, the owner may choose to hot tap it instead of removing a spool; API Recommended Practice 2201, 5th edition, addresses safe hot tapping practices in the petroleum and petrochemical industries, and that choice changes the handling task from removing a spool to supporting a tapping machine on a live line (OSHA 29 CFR 1910.146-1993, §1910.146 paragraph b; OSHA 29 CFR 1910.119-2026, §1910.119 paragraph f.4; OSHA 29 CFR 1910.147-1989, §1910.147 paragraphs d.5.i and d.6; API Recommended Practice 2201, 5th ed., 2003).

What does the Chevron Richmond rupture mean for spool replacement and handling?​

After sulfidation corrosion ruptured a low-silicon carbon steel line at the Chevron refinery in Richmond, California, on August 6, 2012, the U.S. Chemical Safety and Hazard Investigation Board (CSB) recommended that the American Petroleum Institute (API) revise its sulfidation-corrosion guidance to require users either to inspect every component in an at-risk piping circuit or to replace the at-risk carbon steel piping with a more sulfidation-resistant alloy; the turnaround handling article covers the case.

That finding changes the handling job in two ways:

  • Scope grows by circuit, not by spool. A decision to replace a circuit in a more resistant alloy turns one damaged spool into many spools, fittings, and supports that have to be removed, laid down, and replaced, often in a single outage.
  • Component identity becomes a safety requirement. A low-silicon component looks like any other carbon steel spool. Handling, laydown, and staging have to keep each removed and replacement spool tied to its tag and material record, because a replacement mixed up with a removed part puts the same hazard back into service.

The PSM quality-assurance paragraph supports the second point: 1910.119(j)(6)(iii) requires the employer to assure that maintenance materials, spare parts, and equipment are suitable for the process application for which they will be used (U.S. Chemical Safety and Hazard Investigation Board, Chevron Richmond Refinery Pipe Rupture and Fire, 2015; OSHA 29 CFR 1910.119-2026, §1910.119 paragraph j.6.iii).

How does PSM change control apply to a replacement bundle, valve, or spool?​

The owner's management-of-change (MOC) procedure under 1910.119(l) decides whether a replacement component is a replacement in kind or a change that needs review; the turnaround handling article sets out the MOC and pre-startup review rules.

Replacement bundles, valves, and spools often cross that line in ways the handling plan has to anticipate:

  • A retubed or rebuilt bundle in a different tube material, or with a different tube count, is not automatically in kind.
  • A replacement valve with a different face-to-face dimension or actuator changes the piping and its supports.
  • An alloy upgrade spool, like the replacement option in the CSB's Richmond recommendation, is a change in equipment.

Because the pre-startup safety review under 1910.119(i)(2)(i) confirms that construction and equipment are in accordance with design specifications, handling equipment has to set a bundle or spool back undamaged and aligned (OSHA 29 CFR 1910.119-2026, §1910.119 paragraphs i.2.i and l.1).

How should sensing, PLC logic, and interlocks be applied to a bundle extractor or valve-handling machine?​

The intelligence layer is what turns a bundle extractor from a winch with a frame into a machine that knows the load. A well-specified extractor or valve-handling machine carries:

  • Force sensing on the pull axis. A load cell in the pulling line, or a pressure transducer on a hydraulic pull cylinder, measures extraction force continuously. The PLC compares it with a set limit for that bundle and slows or stops the pull as force approaches the limit, so a rising pull force is caught as a trend rather than after the fact.
  • Position sensing. An encoder on the extraction travel tracks how far the bundle has left the shell, which lets the controls match speed and support to the bundle's position and slow before the tube sheet reaches the end of travel.
  • Level and alignment sensing. Inclination sensing on the carrier keeps the bundle on the shell axis, and load cells at the support points can flag an uneven reaction before the carrier tips.
  • Zone interlocks. A light curtain or gated zone around the extraction path holds motion while personnel are inside it, and a permissive from the crane or support carrier confirms the bundle is supported before the pull continues.
  • Safety-rated logic and drives. Emergency stop and guarded-zone functions run in a safety controller. Rockwell Automation rates a GuardLogix 5580 primary controller with a safety partner for safety applications up to SIL 3 and PL e (Cat. 4). Logix 5000 controllers organize code into continuous, periodic, and event tasks, so force monitoring can run at a fixed period. The Kinetix 5700 procedure includes a tuning step for each servo axis, and autotuned loop bandwidths can require adjustment once the motor and load are connected, so a pull axis tuned empty should be checked with a loaded bundle.
  • Standards basis. ISO 12100:2010 covers risk assessment and risk reduction, ISO 13849-1:2023 covers the design of safety-related parts of control systems, and IEC 60204-1:2016 covers the electrical equipment of machines.

Every device on a machine entering a classified area must also suit that area's classification. UTEC Industrial, a Rockwell Automation Recognized System Integrator, builds UL 508A panels around Allen-Bradley ControlLogix and CompactLogix controllers with VFD and servo drives (Rockwell Automation 1756-RM012J-EN-P-2025; Rockwell Automation 1756-RM094N-EN-P-2025; Rockwell Automation 2198-UM002E-EN-P, Kinetix 5700; ISO 12100:2010; ISO 13849-1:2023; IEC 60204-1:2016).

How is stored energy controlled on the handling machine itself?​

The process side is isolated before the lift; the handling machine brings its own stored energy to the job. A bundle held on extraction cables, a hydraulic pull cylinder under pressure, a raised carrier, and a brake-held axis are all energy the machine can release. Paragraph 1910.147(d)(5)(i) requires all potentially hazardous stored or residual energy to be relieved, disconnected, restrained, and otherwise rendered safe after lockout devices are applied, and (d)(5)(ii) requires verification of isolation to continue until the work is complete if stored energy can reaccumulate to a hazardous level.

Under the lockout standard's definition of an energy isolating device, which the refinery and gas-plant handling overview explains, an emergency stop on an extractor is not a lockout point.

For a bundle extractor or valve-handling machine, that translates into design features the specifier should ask for:

  • A lockable main disconnect and lockable hydraulic isolation valves.
  • Mechanical blocking positions for any carrier or boom that can hold a load aloft.
  • A means to relieve and verify zero pressure in pull cylinders and accumulators.
  • Load-holding valves on cylinders that support a bundle, so a hose failure does not drop it.

No crew should have to work beside a bundle held only by a winch brake or a pressurized cylinder; blocking points designed into the machine remove the reason to do it (OSHA 29 CFR 1910.147-1989, §1910.147 paragraphs b, d.5.i, and d.5.ii).

How is a bundle extractor or handling fixture built and qualified before it reaches the unit?​

The equipment that handles a bundle, valve, or spool is itself a heavy welded and machined structure. Design fixes the lifting-device classification, rated load, and load path; machining sets the pulling head, pin bores, and attachment points that carry the load; and weld fatigue and stress relief matter because an extractor or lifting beam sees a load cycle on every pull and lift over its life.

A specifying engineer can hold the builder to that chain with specific deliverables:

  • Design basis: the rated load, the design factor, and the design criteria applied, since ASME BTH-1-2023 sets minimum structural, mechanical, and electrical design criteria for below-the-hook lifting devices.
  • Fabrication records: weld procedures, NDT results, and stress-relief records for the primary frame.
  • Dimensional records: inspection of machined pulling and lifting features against the drawing.
  • Marking and test: the rated-load marking and the load-test record, since B30.20-2025 includes provisions for the marking and testing of these devices.
  • Factory acceptance test: a documented demonstration of the pull, force limit, interlocks, and stops before the machine ships.

UTEC Industrial stress-relieves and CNC-machines the welded frames it builds, inspects them with NDT and CMM, and runs factory acceptance testing before shipment, so these records exist when the owner's contractor-evaluation process asks for them (ASME BTH-1-2023; ASME B30.20-2025).

What should a specifying engineer define before requesting bundle, valve, or spool handling equipment?​

A request that names only a capacity and a stroke leaves out most of what governs a bundle extractor or valve-handling machine. A complete specification defines:

  • The components: each exchanger's type and rear head, bundle weight, length, and tube-sheet diameter, and each valve's and spool's weight, dimensions, and center of gravity, from manufacturer data or weighed lifts.
  • The site: exchanger elevations, clear space in line with each shell, deck and structure capacity, crane access, and the area classification of every place the equipment works or parks.
  • The lifting-device basis: whether the device is crane-suspended, its BTH-1 Design Category and Service Class, its rated load, and the marking and load test required.
  • The rigging interface: rated attachment points, sling types permitted for the service, and any chemical or temperature exposure that rules out synthetic slings under 1910.184(i)(6) and (i)(7).
  • Controls and safety: force and position sensing, interlocks, safety functions, the controller platform the site standardizes on, and lockout and blocking provisions.
  • Records: the fabrication, inspection, test, and acceptance documents the owner's mechanical-integrity and contractor procedures require (OSHA 29 CFR 1910.184-2019, §1910.184 paragraphs i.6 and i.7; ASME BTH-1-2023).
Related Articles

References​

  • OSHA 29 CFR 1910.119-2026: Process Safety Management of Highly Hazardous Chemicals. U.S. Department of Labor, 2026.
  • OSHA. Process Safety Management for Petroleum Refineries: Lessons Learned from the Petroleum Refinery Process Safety Management National Emphasis Program. OSHA 3918-08, U.S. Department of Labor, 2017.
  • TEMA: Standards of the Tubular Exchanger Manufacturers Association, 2026 ed. Tubular Exchanger Manufacturers Association, 2026.
  • Rößler, F., Krumova, V., Gewald, S., Bauernfeind, A., Freko, P., Thomas, I., Zander, H.-J., Rehfeldt, S., Klein, H. (2022). "Hazard Analysis of Fixed-Tube-Sheet Shell-and-Tube Heat Exchangers." Chemie Ingenieur Technik, 94(5), 727-737. DOI 10.1002/cite.202100186.
  • OSHA 29 CFR 1910.184-2019: Slings. U.S. Department of Labor, 2019.
  • ASME BTH-1-2023: Design of Below-the-Hook Lifting Devices. ASME, 2023.
  • ASME B30.20-2025: Below-the-Hook Lifting Devices. ASME, 2025.
  • OSHA 29 CFR 1910.146-1993: Permit-Required Confined Spaces. U.S. Department of Labor, 1993.
  • OSHA 29 CFR 1910.147-1989: The Control of Hazardous Energy (Lockout/Tagout). Occupational Safety and Health Administration, 1989.
  • API. Recommended Practice 2201: Safe Hot Tapping Practices in the Petroleum and Petrochemical Industries, 5th ed. American Petroleum Institute, 2003.
  • U.S. Chemical Safety and Hazard Investigation Board. Chevron Richmond Refinery Pipe Rupture and Fire. Investigation Report No. 2012-03-I-CA, 2015.
  • Rockwell Automation 1756-RM012J-EN-P-2025: GuardLogix 5580 and Compact GuardLogix 5380 Controllers Safety Reference Manual. Rockwell Automation, 2025.
  • Rockwell Automation 1756-RM094N-EN-P-2025: Logix 5000 Controllers Design Considerations. Rockwell Automation, 2025.
  • Rockwell Automation 2198-UM002E-EN-P (2018): Kinetix 5700 Servo Drives User Manual. Rockwell Automation, 2018.
  • ISO 12100:2010: Safety of machinery — General principles for design — Risk assessment and risk reduction. ISO, 2010.
  • ISO 13849-1:2023: Safety of machinery — Safety-related parts of control systems — Part 1: General principles for design. International Organization for Standardization, 2023.
  • IEC 60204-1:2016 (Ed. 6.0): Safety of Machinery -- Electrical Equipment of Machines -- Part 1: General Requirements. International Electrotechnical Commission, 2016.

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