An Interactive 5-Day Training Course
CCUS Surface Facilities: Capture, Compression, Transport and Injection
Practical CCUS facility engineering from capture to injection
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Duration
5 Days
Price
$ 4,000
Starting From
13 Dec 2027
CCUS Surface Facilities: Capture, Compression, Transport and Injection
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CCUS Surface Facilities: Capture, Compression, Transport and Injection - SF-CCUS-PEA27
| Code | Date | Time | Duration | Location | Currency | Early Bird Fee Per Person |
|---|---|---|---|---|---|---|
| SF-CCUS-PEA27 | 13 - 17 Dec 2027 | 10 AM CST | 5 Days - 4 Hours / Day |
Online |
USD |
4000 |
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CCUS Surface Facilities: Capture, Compression, Transport and Injection
This training covers the surface facilities in a carbon capture, utilisation and storage chain. It works through capture technologies and their integration with a source, CO2 conditioning and dehydration, compression and dense phase behaviour, pipeline transport, injection facility design and the well interface, materials selection for CO2 service, measurement and monitoring requirements, and the process safety topics specific to concentrated CO2.
Description
A CCUS chain is a set of connected facilities: a capture plant that separates CO2 from a gas stream, a conditioning and compression system that brings it to transport condition, a pipeline or shipping route that moves it, and an injection facility that delivers it into a storage formation. Each stage imposes specifications on the ones around it, and the specification that matters most is water content, because wet CO2 is aggressively corrosive to carbon steel and forms hydrates. This training covers the engineering of that chain.
Capture technologies are covered first, including post-combustion amine absorption, pre-combustion capture, oxy-fuel combustion and the separation of CO2 from natural gas processing and industrial streams, with their energy penalty, integration requirements and applicability. Conditioning follows: dehydration to pipeline specification, removal of oxygen, sulphur species and other impurities, and the effect each impurity has on phase behaviour, corrosion and storage. Compression is then developed with CO2 phase behaviour, dense phase operation, compressor configuration and the particular difficulties of compressing a fluid near its critical point. Pipeline transport covers design, operation, depressurisation behaviour and running ductile fracture. Injection facilities, well interface, materials selection, measurement and monitoring for verification, and CO2 process safety complete the training.
Water content is the controlling specification in a CO2 system. Dry CO2 is compatible with carbon steel. Wet CO2 forms carbonic acid and corrodes carbon steel at rates that make it unusable, and at pipeline conditions the water can also form hydrates that block lines. The dehydration requirement is therefore not a quality preference but the condition under which the entire transport system can be built in conventional materials. Failures of the dehydration unit have direct and rapid integrity consequences downstream.
CO2 phase behaviour makes the fluid awkward to handle. Its critical point sits at conditions close to those of practical pipeline operation, and its properties change sharply nearby: density varies strongly with small pressure and temperature changes, which affects metering, compression, pump behaviour and hydraulic calculation. Impurities shift the phase envelope, so a stream containing nitrogen, oxygen, methane or hydrogen behaves differently from pure CO2, and the specification for those impurities has to be set with the transport conditions in mind.
Depressurisation is a distinctive hazard. When a CO2 pipeline or vessel depressurises, the fluid cools sharply through the Joule-Thomson effect and can form solid CO2, while the steel cools to temperatures at which carbon steel becomes brittle. Blowdown systems, valve selection and material choice all have to account for this. A CO2 pipeline rupture also has a specific failure mode, running ductile fracture, which requires either toughness control or crack arrestors along the line.
Finally, CO2 is an asphyxiant that is denser than air. A release accumulates in low areas, does not disperse the way a buoyant gas does, and is not detected by sight or smell at hazardous concentrations. This changes detection philosophy, layout, drainage, confined space management and emergency response throughout a CCUS facility, and it is the safety topic most often underestimated by teams whose experience is in hydrocarbon service.
By the end of this training, participants will be able to:
- Describe the complete CCUS chain and the specifications each stage imposes on the others
- Compare capture technologies against source stream, capture rate, energy penalty and integration requirements
- Specify CO2 conditioning requirements including dehydration, oxygen and impurity removal
- Analyse CO2 phase behaviour and evaluate the effect of impurities on the phase envelope
- Design CO2 compression systems including configuration, staging and dense phase pumping
- Specify CO2 pipeline design including materials, wall thickness, fracture control and operating conditions
- Design injection facilities and define the interface with injection wells and the storage formation
- Select materials for CO2 service and specify corrosion control appropriate to the water specification
- Establish measurement, monitoring and verification requirements for a CCUS project
- Apply CO2-specific process safety requirements including release behaviour, detection and depressurisation hazards
The training follows CO2 from the source stream through capture, conditioning, compression, transport and injection into the storage formation, so that each specification is understood in terms of the downstream requirement it exists to satisfy. Phase behaviour, compression duty, pipeline hydraulics, dehydration requirement and injection pressure calculations are worked through numerically for representative CO2 streams including impurities. Capture technologies are compared on energy penalty and integration using process data. CO2 release behaviour, depressurisation cooling and fracture control are examined with reference to documented incidents and industry test programmes.
Organisations sending participants to this training will:
- Build internal capability to evaluate and develop CCUS projects rather than relying wholly on external specialists
- Reduce integrity risk in CO2 systems through correct specification and materials selection
- Improve capture technology selection and its integration with the source facility
- Strengthen process safety management for concentrated CO2 handling
- Improve the technical quality of CCUS project cost and feasibility assessment
- Support decarbonisation commitments with credible engineering assessment
Participants will:
- Understand the full CCUS chain and the engineering constraints at each stage
- Specify CO2 stream quality and understand the consequence of each impurity
- Design and assess CO2 compression, transport and injection systems
- Recognise the safety hazards specific to concentrated CO2 and design against them
- Evaluate CCUS project proposals with technical judgement
- Build capability in a field with expanding project activity
- Facilities, process and project engineers working on CCUS projects
- Production and operations engineers on assets with CO2 handling
- Gas processing engineers extending into carbon capture
- Pipeline and integrity engineers working on CO2 transport
- Reservoir and subsurface engineers interfacing with injection facilities
- HSE and process safety practitioners covering CO2 facilities
- Technical and commercial staff evaluating decarbonisation projects
Module 1 - CCUS Chain and Project Framework
- CCUS chain elements: capture, conditioning, transport, injection, storage, monitoring
- Source types: power generation, industrial process, natural gas processing, hydrogen production
- Capture rate targets and their engineering consequences
- Utilisation options and enhanced oil recovery with CO2
- Regulatory frameworks and storage permitting
- Chain integration, interface specifications and contractual boundaries
- Project economics, cost drivers and incentive mechanisms
- Scale, phasing and hub development concepts
- Cross-chain risk allocation
Module 2 - CO2 Properties and Phase Behaviour
- CO2 physical properties across gas, liquid, dense and supercritical phases
- Phase diagram, critical point and triple point
- Dense phase and supercritical operation and their definitions
- Density, viscosity and compressibility variation near the critical point
- Joule-Thomson behaviour and cooling on expansion
- Solid CO2 formation conditions
- Effect of impurities on the phase envelope: nitrogen, oxygen, methane, hydrogen, argon
- Water solubility in CO2 and hydrate formation
- Equations of state for CO2 systems and their accuracy
- Implications of phase behaviour for design and operation
Module 3 - Capture Technologies
- Post-combustion capture by amine absorption
- Solvent selection, degradation and reclaiming in flue gas service
- Oxygen and flue gas contaminant effects on solvents
- Energy penalty, steam demand and integration with the host facility
- Pre-combustion capture and its process configuration
- Oxy-fuel combustion and its flue gas characteristics
- CO2 removal from natural gas processing streams
- Industrial process capture: cement, steel, hydrogen, ammonia
- Membrane, adsorption and cryogenic separation options
- Direct air capture in outline
- Capture technology selection and comparison
Module 4 - CO2 Conditioning and Purification
- CO2 stream specification for transport and storage
- Dehydration requirement and the corrosion basis for it
- Dehydration technologies: glycol, molecular sieve, and their selection for CO2 service
- Water specification levels and their design margin
- Oxygen removal and its importance for corrosion and storage
- Sulphur species, nitrogen oxides and their removal
- Non-condensable removal and its effect on transport
- Particulate and trace contaminant removal
- Specification setting across a shared transport network
- Analysis and monitoring of CO2 stream quality
Module 5 - Compression and Pumping
- Compression duty and power requirement for CO2 service
- Multistage compression configuration and intercooling
- Integrally geared and barrel compressor selection
- Discharge temperature limits and interstage cooling requirements
- Compression to dense phase and the transition point
- Dense phase pumping as an alternative to compression
- Sealing systems for CO2 service and elastomer compatibility
- Lubrication and CO2 solubility effects
- Anti-surge and capacity control
- Compressor operation near the critical region
- Energy consumption and its contribution to the capture penalty
Module 6 - Pipeline Transport
- CO2 pipeline design codes and their application
- Operating pressure and temperature selection to remain in a single phase
- Hydraulic design and pressure drop for dense phase CO2
- Booster station requirements and spacing
- Wall thickness, material grade and toughness requirements
- Running ductile fracture: mechanism, and control by toughness or crack arrestors
- Depressurisation behaviour, cooling and material embrittlement
- Valve selection, spacing and isolation philosophy
- Internal corrosion control and the dependence on dry operation
- External corrosion protection and cathodic protection
- Pigging, inspection and integrity management for CO2 lines
- Shipping and intermediate storage as a transport alternative
Module 7 - Injection Facilities and Well Interface
- Injection facility configuration and layout
- Pressure and temperature conditioning at the injection site
- Heating requirements to avoid cold injection and thermal stress
- Injection pumps, boosters and their control
- Metering, allocation and rate control across multiple wells
- Wellhead and tree requirements for CO2 injection
- Annulus monitoring and well integrity requirements
- Injection well materials and completion design considerations
- Injectivity, formation response and pressure management
- Shutdown, restart and transient behaviour at the well
- Interface between surface facility and subsurface storage plan
Module 8 - Materials and Corrosion in CO2 Service
- Corrosion mechanism of wet CO2 and carbonic acid formation
- Water content limits and their safety margin
- Carbon steel use in dry CO2 service and its conditions
- Corrosion resistant alloys and where they are justified
- Effect of oxygen, sulphur species and other impurities on corrosion
- Elastomer and polymer compatibility with dense phase CO2
- Explosive decompression damage to elastomers
- Low temperature material requirements for depressurisation cases
- Corrosion monitoring in CO2 systems
- Materials selection across the chain
Module 9 - Measurement, Monitoring and Verification
- CO2 metering technologies and their performance in dense phase
- Density measurement and its criticality near the critical point
- Composition analysis and impurity monitoring
- Measurement uncertainty and its commercial and regulatory significance
- Custody transfer arrangements across chain boundaries
- Accounting for captured, transported, injected and stored volumes
- Leak detection on CO2 pipelines and facilities
- Monitoring, measurement and verification requirements for storage
- Reporting obligations under regulatory and credit schemes
- Chain-wide mass balance and reconciliation
Module 10 - CO2 Process Safety
- CO2 toxicity, asphyxiation and exposure limits
- Physiological effects at increasing concentration
- Dense gas dispersion behaviour and accumulation in low areas
- Release scenarios: pipeline rupture, vessel failure, valve leak
- Dispersion modelling for CO2 releases
- Cold burn and cryogenic exposure hazards
- Solid CO2 formation during release and its consequences
- Detection systems and their placement for a dense gas
- Layout, drainage and confined space considerations
- Emergency response, evacuation and rescue for CO2 releases
- Public safety, land use and pipeline routing considerations
- CO2 incident case histories and their lessons
Upon successful completion of this training course, delegates will be awarded an official Certificate of Completion issued by the Petroleum Engineers Association (PEA), an ISO 9001:2015 certified training organization. The certificate carries 10 Credits and formally records the total learning hours completed.
Each certificate is signed by the Course Facilitator and the CEO of the Petroleum Engineers Association, and serves as verifiable proof of professional training that delegates can present to employers and professional bodies worldwide.
This course is led by a CCUS and facilities engineering specialist with more than 20 years in the oil and gas industry, built on engineering the chain that takes CO2 from a source to a storage formation.
He currently holds CCUS project engineering leadership responsibility with a major operator developing carbon capture and storage assets, covering CO2 conditioning, compression and pipeline transport — the disciplines that connect capture to permanent storage. Earlier in his career he served as a facilities engineer on major gas processing and pipeline developments, leading design and integration work on high-pressure CO2 systems across some of the industry's earliest large-scale CCUS projects. Across two decades he has taken several capture and injection projects from concept through commissioning into safe, reliable operation.
That operating background shapes how he teaches. Delegates learn not only how CCUS facilities are designed to work, but how they behave in the field — where capture technologies actually lose efficiency, why CO2 phase behaviour complicates compression and transport, what makes injection wells and reservoir interfaces succeed or fail, how materials perform under CO2-specific conditions, and how engineering and operations teams manage CO2-specific process safety together. Every module is anchored in real project data, design decisions and lessons from operating CCUS chains.
His subject coverage spans the full CCUS value chain: capture technologies and integration, CO2 conditioning and dehydration, compression and phase behaviour, pipeline transport, injection facilities and well interface, materials selection, measurement and monitoring, and CO2-specific process safety.
He has delivered CCUS and facilities engineering training for many years across the Middle East, North America and Europe, working with mixed groups of engineers, project teams and technical management at every level of experience. He is an active contributor to industry forums on carbon capture, utilisation and storage.
His approach is practical, discussion-led and grounded in real CCUS project experience — not the textbook.
Frequently Asked Questions
All course bookings made through PEA are strictly non-refundable. By registering for a course, you acknowledge and accept that all fees are payable in full and are not subject to refund under any circumstances, including changes in personal or professional commitments or partial attendance.
PEA reserves the right to make reasonable adjustments to course content, trainers, or schedules where necessary, without entitling delegates to a refund. Comprehensive details of each course — including objectives, target audience, and content — are clearly outlined before enrolment, and it is the responsibility of the delegate to ensure the course's suitability prior to booking.
For any inquiries related to cancellations or bookings, please contact our support team, who will be happy to assist you.
