An Interactive 5-Day Training Course
Water Management & PWRI for Reservoir Engineers
Produced water management and injection for reservoir engineers
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Duration
5 Days
Price
$ 4,000
Starting From
06 Dec 2027
Water Management & PWRI for Reservoir Engineers
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Water Management & PWRI for Reservoir Engineers - RE-PWRI-PEA27
| Code | Date | Time | Duration | Location | Currency | Early Bird Fee Per Person |
|---|---|---|---|---|---|---|
| RE-PWRI-PEA27 | 06 - 10 Dec 2027 | 10 AM CST | 4 Hours Per Day |
Online |
USD |
4000 |
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Water Management & PWRI for Reservoir Engineers
This training covers reservoir engineering aspects of water management. It works through water production forecasting, water source selection and compatibility, injection water quality specification and injectivity, produced water reinjection including thermal fracture behaviour, disposal well performance and injectivity decline, reservoir souring, scaling, water shut-off options and the economics that determine when water handling ends field life.
Description
Water determines the economic life of most oil fields. Production rises through field life until the cost of lifting, separating, treating and disposing of it exceeds the value of the oil produced with it, and that point rather than reservoir depletion is what usually ends production. Managing water is therefore a reservoir engineering responsibility as much as a facilities one, and the decisions that matter, where water is produced from, where it goes, whether it is reinjected and how injectivity is maintained, are reservoir decisions.
This training covers them. Water production forecasting is developed first, covering breakthrough prediction, water cut development, the mechanisms behind early water and the distinction between swept water and channelled water. Water sourcing follows, including seawater, aquifer water, produced water and blends, with the compatibility assessment that determines whether they can be mixed or injected. Injection water quality specification is then developed against the injectivity it must sustain, covering solids, oil content, bacteria and oxygen. Produced water reinjection is covered in detail, including its particular quality difficulties, thermal fracturing behaviour and the fracture growth that determines whether injection is sustainable. Disposal well performance, injectivity decline mechanisms and remediation follow. Souring, scaling, water shut-off options and water handling economics close the training.
Produced water reinjection is where most water management difficulty concentrates. Produced water carries oil, solids, bacteria and dissolved species that surface treatment reduces but does not eliminate, and injecting it into a formation plugs the near-wellbore region progressively. The response in practice is that injection pressure rises until the formation fractures, after which injection continues into a growing fracture rather than through the matrix. That is not necessarily a problem, and it is frequently how PWRI actually works, but it changes the injectivity, the fracture geometry and the risk of out of zone injection.
Thermal effects compound this. Injected water is usually cooler than the formation, and cooling reduces the rock stress around the injector, which lowers the fracture pressure. A well that fractures at one pressure when injection begins fractures at a lower pressure after months of cooling, and the fracture grows accordingly. Predicting fracture length and height growth over the life of an injector, and confirming that it stays within the intended interval, is a reservoir engineering calculation with integrity and regulatory consequences.
Souring is a slow consequence of water injection that arrives years later. Sulphate in injected seawater feeds sulphate reducing bacteria in the reservoir, which generate hydrogen sulphide that appears in produced fluids. A field designed and constructed to sweet specification then produces sour fluid, with materials, safety and facility consequences that were not planned for. Predicting souring, monitoring for it and managing it through sulphate removal or biocide treatment are all better handled before it appears.
Finally, water shut-off is usually a better answer than more water handling capacity. A well producing at ninety percent water cut from a channelled zone while an oil-bearing interval is bypassed is a candidate for intervention rather than for additional treatment capacity. Distinguishing water that must be produced because it is displacing oil from water that is simply recycling is what makes water shut-off candidate selection effective.
By the end of this training, participants will be able to:
- Forecast water production including breakthrough timing and water cut development
- Distinguish swept water, channelled water, coned water and injected water recycling
- Assess water source options and their compatibility for injection and blending
- Specify injection water quality requirements against the injectivity to be sustained
- Evaluate produced water reinjection including its quality difficulties and treatment requirements
- Predict thermal fracture initiation and growth in injection wells
- Assess injectivity decline mechanisms and design monitoring and remediation
- Evaluate disposal well performance and formation selection
- Predict, monitor and manage reservoir souring
- Select water shut-off candidates and evaluate treatment options
- Assess water handling economics and its effect on field economic life
The training follows water through the system from the reservoir to disposal, with reservoir engineering calculations worked through numerically: breakthrough prediction, injectivity, fracture pressure with thermal effects, fracture growth, souring prediction and water handling economics. Field water production and injection data is used for diagnosis exercises. Injection well performance histories are analysed for fracture behaviour and injectivity decline. Water shut-off candidate selection is practised on real well data, and water handling economics are worked through to establish economic limit.
Organisations sending participants to this training will:
- Extend field economic life through better water management
- Maintain injectivity and reduce injection well replacement
- Reduce water handling cost through targeted water shut-off rather than capacity addition
- Anticipate souring and manage it before it affects operations
- Improve confidence that injected water remains within the intended formation
- Improve water production forecasting and facility capacity planning
Participants will:
- Forecast water production and understand what drives it
- Specify injection water quality with a technical basis
- Predict and monitor thermal fracture behaviour in injectors
- Diagnose injectivity decline and select remediation
- Identify water shut-off candidates that will deliver
- Understand the economics that end field life
- Reservoir engineers on waterflooded and mature assets
- Production engineers managing water production and injection wells
- Water injection and disposal engineers
- Production chemists supporting water treatment programmes
- Facilities engineers sizing water handling systems
- Well intervention engineers selecting water shut-off candidates
- Technical staff planning field life extension
Module 1 - Water in the Reservoir System
- Water sources: connate, aquifer, injected, coned, channelled
- Water production through field life and typical profiles
- Water cut, water oil ratio and their behaviour
- Economic limit and its dependence on water handling cost
- Water as the driver of field economic life
- Water handling cost components
- Field examples of water-limited production
- Framing water management as a reservoir engineering responsibility
Module 2 - Water Production Forecasting
- Breakthrough time prediction in waterfloods
- Water cut development after breakthrough
- Fractional flow and its use in water cut prediction
- Coning and cusping prediction
- Channelling and its signature
- Distinguishing displacement water from recycled water
- Layer and zone contribution to water production
- Production logging for water entry identification
- Field level water production forecasting
- Facility capacity planning from water forecasts
- Forecasting water for facility and disposal planning
Module 3 - Water Sourcing and Compatibility
- Source options: seawater, aquifer, produced water, surface water, blends
- Volume availability and its reliability
- Water composition analysis and its interpretation
- Compatibility between injection water and formation water
- Scaling prediction from mixing incompatible waters
- Compatibility with formation minerals and clay sensitivity
- Sulphate content and its souring and scaling implications
- Sulphate removal technology and its application
- Blending strategies and composition control
- Water sourcing cost and its effect on project economics
Module 4 - Injection Water Quality and Injectivity
- Quality parameters: solids, oil in water, bacteria, oxygen, particle size
- Relationship between water quality and injectivity decline
- Filtration requirements and rating selection
- Membrane filter and millipore testing
- Deaeration and oxygen scavenging
- Biocide programmes and bacterial control
- Setting quality specifications from injectivity requirements
- Cost of treatment against cost of injectivity loss
- Monitoring water quality at the wellhead rather than at the plant
- Quality excursions and their consequences
Module 5 - Injectivity and Formation Damage
- Injectivity index and its measurement
- Hall plot construction and interpretation
- Injectivity decline mechanisms: external filter cake, internal filtration, deep bed
- Particle plugging and its depth of penetration
- Oil in water and relative permeability damage
- Bacterial plugging and biofilm
- Scale precipitation in the near-wellbore region
- Clay swelling and fines migration
- Diagnosing injectivity decline from pressure and rate data
- Remediation: acidising, backflushing, recompletion, refracturing
- Injectivity monitoring programme design
Module 6 - Produced Water Reinjection
- PWRI drivers: disposal cost, environmental, pressure support
- Produced water quality and its variability
- Treatment requirements for PWRI
- Achievable quality against required quality
- PWRI injectivity behaviour and its typical decline
- Matrix injection against fracture injection in PWRI
- Accepting fracture injection as the operating mode
- Well count and capacity planning for PWRI
- Commingling produced water with other injection sources
- PWRI operating experience and its lessons
- PWRI economics against alternative disposal
Module 7 - Thermal Fracturing and Fracture Growth
- Fracture initiation pressure and its determination
- Thermal stress reduction from cool water injection
- Fracture pressure decline over injection life
- Fracture length and height growth prediction
- Poroelastic effects and their contribution
- Containment: barrier requirements and out of zone risk
- Monitoring fracture growth: step rate tests, temperature logs, microseismic
- Step rate test design and interpretation
- Regulatory requirements for injection containment
- Managing injection to control fracture growth
- Consequences of uncontrolled fracture growth
Module 8 - Disposal Wells and Formation Selection
- Disposal formation selection criteria
- Confining layer requirements and integrity
- Disposal capacity estimation
- Pressure build-up in the disposal formation
- Well design and completion for disposal service
- Well integrity and annulus monitoring requirements
- Regulatory framework for disposal wells
- Monitoring and reporting obligations
- Disposal well failure modes and their consequences
- Contingency planning for loss of disposal capacity
Module 9 - Souring, Scaling and Water Chemistry Management
- Reservoir souring mechanism and sulphate reducing bacteria
- Souring prediction models and their inputs
- Timing of souring onset after injection begins
- Souring consequences: materials, safety, facilities, product specification
- Souring mitigation: sulphate removal, biocide, nitrate treatment
- Monitoring for souring onset
- Scale types and their prediction
- Scale inhibition: continuous injection and squeeze treatment
- Squeeze design, placement and return curve monitoring
- Corrosion in water injection and production systems
- Integrated water chemistry management programme
Module 10 - Water Shut-Off and Economics
- Identifying wells where water production can be reduced
- Distinguishing productive water from recycled water
- Diagnosis: production logging, tracers, pressure analysis
- Mechanical water shut-off: plugs, straddles, recompletion
- Chemical water shut-off: gels, relative permeability modifiers
- Candidate selection criteria and screening
- Expected benefit and its evaluation
- Water shut-off success rates and their drivers
- Water handling cost per barrel and its components
- Economic limit calculation with water handling cost
- Field life extension through water management
- Deciding between shut-off, capacity addition and abandonment
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.
Your expert course leader is a senior petroleum engineering consultant, certified trainer and university lecturer with more than 25 years of experience, specialising in water management and produced water reinjection for reservoir engineering.
His technical expertise covers water production forecasting and its drivers, water sourcing and compatibility, injection water quality and injectivity, produced water reinjection and thermal fracturing, disposal well performance, souring and scaling management, water shut off and the economics of water handling.
He has provided consulting and technical support to international operators and national oil companies across the Middle East, North Africa, Asia Pacific and the Americas, working on water management strategy studies, injection and disposal well performance reviews, souring and scaling mitigation and water handling economic evaluation projects across mature and waterflooded assets.
He has designed and delivered technical training programmes on water management and produced water reinjection topics for operating companies and service providers, conducting both classroom and online sessions for engineers and technical staff across the Middle East, Asia Pacific, Africa and Europe.
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.
