# Offshore Pipeline Market

> Offshore Pipeline Market Research Report By Product Type (Oil, Gas), By Line Type (Export & Trunk Lines, Flowlines & Tie-in Spools, Risers & Umbilicals), By Water Depth (Shallow Water (1,500 m)) and By Regional (North America, Europe, South America, Asia Pacific, Middle East and Africa) - Forecast to 2035

- **Forecast Period:** 2026-2035
- **CAGR:** 7.60%
- **2025:** USD 18.02 Billion
- **2035:** USD 37.51 Billion
- **Key Players:** Saipem S.p.A., Subsea7 S.A., TechnipFMC plc, Allseas Group S.A., McDermott International, Tenaris S.A., Nippon Steel Corporation, Sapura Energy Berhad

**Report ID:** MRFR/EnP/6225-CR · **Pages:** 155 · **Author:** Chitranshi Jaiswal · **Last Updated:** September 15, 2026

**URL:** https://www.marketresearchfuture.com/reports/offshore-pipeline-market-7694

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## Market Summary

## Offshore Pipeline Market Summary

The Offshore Pipeline Market was valued at USD 18.02 billion in 2025 and is projected to open the forecast window at USD 19.39 billion in 2026 before reaching USD 37.51 billion by 2035, expanding at a 7.60% CAGR between 2026 and 2035. Two catalysts anchor that trajectory. The first is the return of sanctioned deepwater capital after a decade of restraint — Brazil's pre-salt and the US Gulf of Mexico alone absorbed more than USD 42 billion of upstream commitments across 2024–2025 [[2]](https://woodmac.com)[7]. The second is gas monetization policy, where LNG feed-gas trunk lines in Qatar, Mozambique and Australia now carry state-backed offtake guarantees [[3]](https://qatarenergy.qa).

Engineering practice inside the Offshore Pipeline Market has shifted decisively. Carbon-[steel](https://www.marketresearchfuture.com/reports/steel-market-5465) rigid lines welded on conventional lay barges are giving way to reeled rigid systems, corrosion-resistant alloy-clad pipe and electrically heat-traced flowlines rated for sub-4°C seabed conditions. Operators redirected roughly USD 6.8 billion toward integrity, monitoring, and flow-assurance upgrades in 2024, a response to tightening leak-detection thresholds [[5]](https://dnv.com)[[10]](https://oeuk.org.uk).

Regionally, North America holds 33.5% of 2025 revenue on the strength of Gulf of Mexico tiebacks and Canadian east-coast development. Asia-Pacific compounds fastest at 8.9% through 2035, while Europe remains the second-largest contributor at 19.5%, propelled by interconnector security policy. Over the coming decade, the Offshore Pipeline Market will be defined less by new trunk-line mileage than by how efficiently existing corridors are repurposed.

## Key Report Takeaways

### • By Product Type

- Oil-service pipelines command 57.0% of Offshore Pipeline Market revenue in 2025, sustained by long-distance crude export corridors
- Gas-service pipelines post the faster 8.4% CAGR through 2035 as LNG feed-gas demand compounds

### • By Line Type and Water Depth

- Export and trunk lines represent USD 8.29 billion of 2025 spend within the Offshore Pipeline Market
- Flowlines and tie-in spools account for 31.5% of installed value, tracking subsea tieback counts
- Ultra-deepwater systems beyond 1,500 metres grow at 9.6% CAGR, the fastest depth class

### • By Region

- North America leads the Offshore Pipeline Market with 33.5% revenue share in 2025
- Asia-Pacific advances at 8.9% CAGR, the fastest-growing region
- South America contributes USD 1.35 billion in 2025, concentrated in Brazilian pre-salt

## Market Size and Forecast (2021–2035)

Estimates blend bottom-up EPC contract award tracking, pipelay vessel utilisation logs, [line pipe](https://www.marketresearchfuture.com/reports/line-pipe-market-27862) mill shipment data, and operator capital disclosure, then reconcile against national regulator filings and IEA upstream investment aggregates. Historical years are actuals; forecast years apply sanctioned-project backlog conversion rates by region.

## Market Drivers

## Driver Impact Analysis

| Driver | ~% Impact on CAGR | Geographic Relevance | Impact Timeline | Ref |
| --- | --- | --- | --- | --- |
| Asia-Pacific crude and gas import demand | +1.4 pp | China, India, ASEAN | Medium-term (2–4 yr) | [1][4] |
| Deepwater and ultra-deepwater FID recovery | +1.2 pp | Brazil, GoM, West Africa | Long-term (≥4 yr) | [2][7] |
| LNG feed-gas trunk line construction | +1.1 pp | Qatar, Mozambique, Australia | Medium-term (2–4 yr) | [3] |
| Aging asset replacement and integrity capex | +0.9 pp | North Sea, GoM | Short-term (≤2 yr) | [5][9] |
| Energy security interconnector policy | +0.8 pp | Europe | Short-term (≤2 yr) | [6] |
| CCS and hydrogen-ready trunk lines | +0.6 pp | Norway, Netherlands, US | Long-term (≥4 yr) | [8][12] |
| Digital integrity and monitoring adoption | +0.5 pp | Global | Medium-term (2–4 yr) | [10] |

### Asia-Pacific Import Demand

China and India together added roughly 1.9 million barrels per day of incremental crude import requirement between 2021 and 2025, and the IEA projects Southeast Asian gas import dependency rising above 40% by 2035 [[1]](https://iea.org)[[4]](https://iea.org). That structural gap converts directly into subsea infrastructure orders across the Offshore Pipeline Market, because regional receiving terminals increasingly favour seabed connections over shuttle logistics on both cost and emissions grounds. India's Directorate General of Hydrocarbons cleared exploration acreage covering 244,000 square kilometres under OALP rounds, much of it offshore Krishna-Godavari and Andaman [[11]](https://petronas.com).

### Deepwater Sanctioning Recovery

Deepwater breakevens have fallen to the USD 28–35 per barrel band for tieback-led developments, roughly 40% below 2014 levels [7]. Petrobras alone committed USD 111 billion of 2025–2029 capital, with the majority directed offshore [[13]](https://petrobras.com.br). Lower thresholds pull marginal accumulations into the economic range, and each tieback carries flowline, riser, and umbilical scope disproportionate to its barrel count.

### Integrity and Replacement Capex

Roughly 34% of North Sea and Gulf of Mexico trunk lines now exceed 30 years of service [[5]](https://dnv.com). The US Bureau of Safety and Environmental Enforcement decommissioning backlog covers more than 2,700 kilometres of idle offshore line, and enforcement of removal obligations has tightened materially since 2023 [[9]](https://bsee.gov). Replacement rather than greenfield expansion increasingly drives order books.

## Restraints

## Restraints Impact Analysis

Restraint weightings are directional drags on growth, estimated from project deferral rates, cost escalation indices, and permitting duration data. They are not additive and should not be subtracted directly from the headline growth rate of the Offshore Pipeline Market.

| Restraint | ~% Impact on CAGR | Geographic Relevance | Impact Timeline | Ref |
| --- | --- | --- | --- | --- |
| EPC and installation cost inflation | −1.1 pp | Global | Medium-term (2–4 yr) | [14] |
| Pipelay vessel and welding spread scarcity | −0.8 pp | Asia-Pacific, West Africa | Short-term (≤2 yr) | [15] |
| Permitting and environmental review duration | −0.7 pp | North America, Europe | Long-term (≥4 yr) | [9][16] |
| Line pipe and coating input volatility | −0.6 pp | Global | Short-term (≤2 yr) | [17] |
| Transition-driven capital reallocation | −0.5 pp | Europe | Long-term (≥4 yr) | [18] |

### Installation Cost Escalation

Offshore EPC unit rates climbed approximately 29% between 2021 and 2025, outpacing general industrial inflation by a wide margin [[14]](https://rystadenergy.com). Welding consumables, clad pipe and specialist labour absorbed most of that increase. Contractors have responded by shifting risk back to operators through reimbursable and hybrid commercial models, which in turn lengthens sanction timelines because operators must underwrite more residual exposure.

### Installation Fleet Constraints

In water deeper than 1,500 meters, fewer than 30 boats globally are able to install rigid line, and until 2025, the class's utilization topped 88% [[15]](https://clarksons.net). Day rates for premium units over USD 550,000 and booking windows spanning 18 to 24 months are indicative of scarcity. Integrated contractors working for national oil firms take precedence over smaller operators in scheduling.

### Permitting Duration

Median federal permitting duration for US offshore pipeline rights-of-way now runs 26 months, and European consenting for cross-border routes frequently exceeds three years where multiple exclusive economic zones intersect [[9]](https://bsee.gov)[[16]](https://eur-lex.europa.eu). Delay compounds cost escalation, since contractor pricing is rarely held beyond twelve months.

## Opportunities

## Offshore Pipeline Market Opportunities

### Carbon Dioxide Transport Corridors

Repurposing depleted-field infrastructure for CO₂ transport represents the single largest adjacency for the Offshore Pipeline Market. Northern Lights and Porthos together underwrite more than 7 million tonnes of annual injection capacity by 2030, and the European Commission's Net-Zero Industry Act sets a 50 million tonne annual injection target [[8]](https://norlights.com)[[12]](https://commission.europa.eu). Dense-phase CO₂ imposes different fracture-arrest and impurity specifications, creating premium engineering scope.

### Emerging Basin Entry

Guyana, Suriname, Namibia and Mozambique collectively lack mature seabed corridors, meaning each new development builds infrastructure from zero rather than tying back. Guyana's Stabroek block alone supports six sanctioned developments with associated gas evacuation now advancing under the Wales Gas-to-Energy scheme [[19]](https://nre.gov.gy). Early corridor ownership confers durable tariff positions.

### Integrity Data Monetisation

Instead of selling survey days, contractors are turning inspection archives into subscription analytics and providing remaining-life projections. In this area of the offshore pipeline market, recurring revenue binds operators into long-term contracts and has gross margins that are almost twice as high as those of installation work [[10]](https://oeuk.org.uk). These models are immediately fed by cathodic protection telemetry from offshore pipelines.

### Hydrogen-Ready Specification

North Sea operators are specifying new trunk lines to tolerate blended hydrogen at up to 20% by volume, adding modest capital cost against significant option value. The Netherlands and Germany have both committed public funding to offshore hydrogen backbone studies exceeding EUR 1.2 billion combined [[18]](https://irena.org).

### Shallow-Water Brownfield Revival

Producible reserves are still present in mature shelf areas in the Malay Basin, Bohai Bay, and the Gulf of Suez, but the infrastructure is deteriorating. Advances in deepwater pipeline insulation coating have reduced the cost of re-lay, and multi-year shelf renewal programs have been flagged by national operators in China and Egypt [20].

## Future Outlook

## Offshore Pipeline Market Future Outlook

### Autonomous Inspection and Predictive Integrity

Resident autonomous vehicles docked at subsea garages are displacing campaign-based survey vessels, cutting inspection cost per kilometre by an estimated 45% while raising survey frequency fourfold [[10]](https://oeuk.org.uk). Continuous data streams enable condition-based rather than calendar-based intervention. Over the next decade, the Offshore Pipeline Market will treat integrity as a subscription service rather than a periodic project.

### Installation Fleet Renewal

Roughly 40% of the global pipelay fleet exceeds 25 years of age, and newbuild orders remain thin because yard slots compete with [offshore wind](https://www.marketresearchfuture.com/reports/offshore-wind-market-3284) installation vessels [[15]](https://clarksons.net). Scarcity will keep installation pricing elevated through at least 2030, transferring value from operators toward contractors and favouring integrated EPCI models over unbundled procurement.

### Carbon Transport Convergence

Under announced-pledges assumptions, IEA models provide for around 1.2 gigatonnes of CO2 capture annually by 2035, with offshore storage carrying a disproportionate share of that volume [[1]](https://iea.org)[[8]](https://norlights.com). Conventional hydrocarbon specifications do not give the running-ductile-fracture control required by dense-phase transport, which will result in a technically unique product line rather than a straightforward expansion of current capacity.

### Emissions Disclosure and Methane Regulation

The EU Methane Regulation and comparable US rules now require quantified leak reporting across imported and domestic supply chains [[16]](https://eur-lex.europa.eu)[[18]](https://irena.org). Compliance pushes operators toward continuous fibre-optic and acoustic monitoring on new installations, adding an estimated 3–5% to installed system cost while lowering long-run intervention exposure.

## Segment Insights

## Offshore Pipeline Market Segmentation

### By Product Type

| Segment | Metric | Primary Demand Driver |
| --- | --- | --- |
| Oil | 57.0% share (2025) | Long-distance crude export corridors |
| Gas | 8.4% CAGR (2026–2035) | LNG feed-gas and import diversification |

Oil service retains the larger share of the Offshore Pipeline Market because crude export lines run longer and use larger diameters, both of which raise installed value per kilometre. Gas closes the gap steadily. Every LNG train sanctioned between 2023 and 2025 carried associated offshore gathering and feed scope, and gas-service systems also dominate the emerging CCS adjacency where transported fluid behaves closer to a compressed gas than a liquid.

### By Line Type

| Segment | Metric | Primary Demand Driver |
| --- | --- | --- |
| Export & Trunk Lines | USD 8.29 Billion (2025) | Field-to-shore evacuation |
| Flowlines & Tie-in Spools | 31.5% share (2025) | Subsea tieback proliferation |
| Risers & Umbilicals | 9.1% CAGR (2026–2035) | Floating production unit additions |

Trunk lines lead the Offshore Pipeline Market on absolute value, yet flowlines generate more contract events because each incremental tieback requires its own spool, jumper, and tie-in. Riser scope grows fastest, tracking the FPSO orderbook — 27 floating units were on order globally at the end of 2025, each carrying dynamic riser and umbilical packages that scale with water depth [[15]](https://clarksons.net).

### By Water Depth

| Segment | Metric | Primary Demand Driver |
| --- | --- | --- |
| Shallow Water (<500 m) | 46.5% share (2025) | Shelf brownfield renewal |
| Deepwater (500–1,500 m) | USD 6.14 Billion (2025) | Tieback-led field development |
| Ultra-Deepwater (>1,500 m) | 9.6% CAGR (2026–2035) | Pre-salt and Orange Basin expansion |

Shallow water still supplies the largest revenue base for the Offshore Pipeline Market, largely through replacement of corroded shelf infrastructure in the Gulf of Suez, Bohai Bay and the Persian Gulf. Ultra-deepwater grows fastest but from a narrow base, and its economics depend heavily on installation vessel availability rather than reservoir quality.

## Regional Market Share Analysis

## Regional Market Share Analysis

| Region | Metric (2025) | Primary Investment Themes |
| --- | --- | --- |
| North America | 33.5% share | GoM tiebacks, decommissioning, CO₂ corridors |
| Europe | 19.5% share | Interconnector security, hydrogen readiness |
| Asia-Pacific | 8.9% CAGR (2026–2035) | Import corridors, shelf renewal |
| South America | USD 1.35 Billion | Pre-salt expansion, Guyana greenfield |
| Middle East & Africa | 8.1% CAGR (2026–2035) | LNG feed-gas, shelf rehabilitation |
| Total | USD 18.02 Billion (2025) | — |

Regional performance in the Offshore Pipeline Market diverges sharply between replacement-led mature basins and greenfield-led emerging ones.

### North America

| Country | Metric | Key Driver |
| --- | --- | --- |
| US | 78.5% of regional revenue | Gulf of Mexico deepwater tiebacks |
| Canada | USD 0.91 Billion | Newfoundland offshore expansion |
| Mexico | 6.4% CAGR | Zama and Trion development scope |

Dominance here rests on installed base as much as new build. The Offshore Pipeline Market in the United States benefits from more than 43,000 kilometres of active Gulf of Mexico line requiring continuous integrity spend, while Shell's Sparta and Chevron's Anchor extensions add fresh deepwater scope [7][[9]](https://bsee.gov). Canada's Bay du Nord timing remains the region's principal swing variable.

### Europe

| Country | Metric | Key Driver |
| --- | --- | --- |
| Germany | 11.2% of regional revenue | Import terminal seabed connections |
| UK | USD 0.94 Billion | North Sea integrity and decommissioning |
| France | 7.1% of regional revenue | Mediterranean interconnector studies |
| Italy | 6.9% CAGR | Adriatic and East Med gas routing |
| Spain | 5.4% of regional revenue | Iberian corridor feasibility work |
| Nordic Countries | 9.8% CAGR | CO₂ transport and Norwegian trunk lines |
| Russia | 4.2% of regional revenue | Sanctioned-scope contraction |
| Rest of Europe | USD 0.41 Billion | Black Sea and Baltic connections |

European spending follows policy more closely than price. REPowerEU redirected roughly EUR 210 billion toward supply diversification, of which offshore connection infrastructure captured a meaningful slice [[6]](https://commission.europa.eu). Norwegian continental shelf operators simultaneously advanced CO₂ export lines under state co-funding [[8]](https://norlights.com).

### Asia-Pacific

| Country | Metric | Key Driver |
| --- | --- | --- |
| China | 34.8% of regional revenue | Bohai and South China Sea programmes |
| India | 10.4% CAGR | KG basin and OALP acreage awards |
| Japan | USD 0.38 Billion | Import terminal seabed links |
| South Korea | 6.8% of regional revenue | Donghae CCS and terminal connections |
| ASEAN | 21.5% of regional revenue | Malaysia, Indonesia, Vietnam gas evacuation |
| Rest of Asia-Pacific | USD 0.29 Billion | Australian shelf maintenance |

Growth leadership within the Offshore Pipeline Market belongs to this region for structural reasons. CNOOC's annual capital budget has held above CNY 125 billion since 2023, with offshore development its largest line item, and Malaysia's Petronas sanctioned multiple gas evacuation packages serving Sarawak processing hubs [[4]](https://iea.org)[[11]](https://petronas.com). Import dependency, not resource abundance, drives the spend.

### South America

| Country | Metric | Key Driver |
| --- | --- | --- |
| Brazil | 81.5% of regional revenue | Pre-salt Búzios and Sépia expansion |
| Argentina | 9.6% CAGR | Argerich and offshore Austral exploration |
| Rest of South America | USD 0.13 Billion | Guyana and Suriname greenfield corridors |

Brazil anchors the region through sheer project density. Petrobras plans 14 new production units by 2029, each requiring substantial risers, flowlines, and export connections [[13]](https://petrobras.com.br). Guyana's associated-gas evacuation scheme adds a second growth pole with no legacy infrastructure to leverage [[19]](https://nre.gov.gy).

### Middle East & Africa

| Country | Metric | Key Driver |
| --- | --- | --- |
| Saudi Arabia | 29.4% of regional revenue | Marjan and Berri offshore increments |
| UAE | USD 0.51 Billion | Hail and Ghasha sour-gas connections |
| South Africa | 8.7% CAGR | Orange Basin exploration follow-through |
| Egypt | 13.2% of regional revenue | Zohr maintenance and shelf rehabilitation |
| Rest of MEA | USD 0.44 Billion | Mozambique and Qatari LNG feed lines |

Sour service dominates the specification challenge here. ADNOC's Hail and Ghasha development handles gas with high hydrogen sulphide content, requiring clad line pipe that costs roughly 2.4 times conventional carbon steel [20]. Qatar's North Field expansion carries the region's largest single feed-gas connection scope [[3]](https://qatarenergy.qa).

## Competitive Benchmarking

## Competitive Benchmarking

Concentration is moderate. The estimated Herfindahl-Hirschman Index for the Offshore Pipeline Market sits near 780, with the top five contractors holding a combined 44–50% of installation and EPCI revenue. Consolidation accelerated sharply in 2025, and the remaining field splits between integrated EPCI contractors, specialist installation owners, and line pipe manufacturers who compete on a different value axis entirely.

| Company | Est. Revenue Share Range | Key Offerings for Offshore Pipeline Market | Strategic Positioning |
| --- | --- | --- | --- |
| Saipem S.p.A. | ~12–15% | J-lay/S-lay installation, trunk lines, EPCI | Scale leader; merging with Subsea7 |
| Subsea7 S.A. | ~10–13% | Reeled rigid lay, flowlines, risers | Tieback specialist; deepwater depth |
| TechnipFMC plc | ~8–11% | iEPCI integrated subsea systems | Configure-to-order standardisation |
| Allseas Group S.A. | ~6–9% | Ultra-heavy lay, deepwater trunk lines | Owner-operator of unique tonnage |
| McDermott International | ~5–8% | EPCI, shallow-water fabrication | Middle East shelf concentration |
| Tenaris S.A. | ~4–7% | Seamless line pipe, clad and CRA products | Upstream materials integration |
| Nippon Steel Corporation | ~4–6% | High-grade line pipe, sour-service steel | Metallurgy and specification leadership |
| Baker Hughes Company | ~3–5% | Flexible pipe, flow assurance, monitoring | Technology and services blend |
| Sapura Energy Berhad | ~3–5% | Installation, T&I, Asia-Pacific EPCI | Regional cost position in ASEAN |
| National Petroleum Construction Co. | ~2–4% | Shallow-water EPC, Gulf shelf works | Anchored to Gulf national operators |
| Larsen & Toubro Limited | ~2–4% | Offshore EPC, platform and line packages | India and Middle East delivery base |

## Recent News & Developments

## Recent News & Developments

- Petrobras (March 2025): Approved a USD 111 billion five-year capital plan with the majority allocated to pre-salt development, underwriting sustained Brazilian riser and flowline demand [[13]](https://petrobras.com.br).
- European Commission (February 2025): Advanced Net-Zero Industry Act implementing measures setting binding CO₂ injection capacity targets, clarifying the commercial case for offshore transport corridors [[12]](https://commission.europa.eu).

- Northern Lights (2024–2025): Confirmed phase two expansion of CO₂ transport and storage capacity offshore Norway following incremental commercial offtake agreements [[8]](https://norlights.com).
- QatarEnergy (2024): Continued North Field expansion works including offshore gathering and feed-gas connection packages supporting LNG capacity growth toward 142 million tonnes annually [[3]](https://qatarenergy.qa).
- US BSEE (2023): Tightened enforcement of idle offshore infrastructure decommissioning obligations, expanding near-term removal and replacement scope across the Gulf shelf [[9]](https://bsee.gov).

## Report Scope

| Parameter | Detail |
| --- | --- |
| Market Scope | Global Offshore Pipeline Market covering export/trunk lines, flowlines, risers and umbilicals across oil and gas services |
| Study Period | 2021–2035 (Historical 2021–2024; Base Year 2025; Forecast 2026–2035) |
| CAGR | 7.60% (2026–2035) |
| Market Size Checkpoints | USD 18.02 Billion (2025); USD 19.39 Billion (2026); USD 26.00 Billion (2030); USD 37.51 Billion (2035) |
| Fastest Growing Segments | Ultra-Deepwater (9.6% CAGR); Risers & Umbilicals (9.1% CAGR); Gas Service (8.4% CAGR) |
| Companies Profiled | 11 major contractors and materials suppliers benchmarked |
| Valuation Currency | USD Billion, constant 2025 terms |
| CAGR Driver Disclaimer | Driver and restraint impact percentages are directional analyst weightings; they are not additive to the headline growth rate |

## Frequently Asked Questions

**Q: How should buyers evaluate contractor risk when procuring within the Offshore Pipeline Market?**
A: Prioritise fleet ownership over chartered capacity, since owner-operators control schedule during peak utilisation. Review the contractor's backlog concentration — anything above 35% with a single client signals delivery risk [15].

**Q: Does lump-sum or reimbursable contracting deliver better outcomes offshore?**
A: Reimbursable models now dominate deepwater scope because contractors refuse fixed pricing on weather-exposed installation. Lump-sum remains viable for shallow-water work under 200 metres where schedule variance is predictable [14].

**Q: What integration challenges arise when tying new lines into legacy Offshore Pipeline Market infrastructure?**
A: Legacy systems often lack accurate as-built survey data, forcing pre-tie-in inspection campaigns. Pressure rating mismatches and differing wall-thickness standards frequently trigger unplanned spool redesign [5].

**Q: How do flexible and rigid pipe compare on lifetime cost?**
A: Flexible pipe carries roughly 2.5 times the capital cost per metre but installs faster and tolerates dynamic motion. Rigid steel wins on long static runs; flexible wins on risers and short dynamic connections [15].

**Q: Which regulatory nuance most often delays Offshore Pipeline Market projects?**
A: Transboundary consenting. When a route crosses two exclusive economic zones, each jurisdiction applies separate environmental assessment standards, and neither timeline binds the other [16].

**Q: Are decommissioning liabilities transferable when acquiring offshore assets?**
A: Only partially. US and UK regimes retain residual liability with prior owners if the acquiring party defaults, so buyers should price contingent exposure into acquisition models [9].

**Q: What emerging use case deserves the most attention from investors?**
A: Repurposing depleted-field lines for carbon dioxide transport. Existing corridors already hold rights-of-way, which removes the single longest item from any new project schedule [8][22].


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