Production Forecasting and Nomination Scheduling Training Course – Dubai, 27 Dec 2026 – 7 Jan 2027

Production Forecasting and Nomination Scheduling is a 2-week training course for production planners, petroleum engineers and hydrocarbon accounting leads in upstream operations, built around a rolling field forecast and lifting nomination file that each participant drafts for a case asset. As fields mature and buyers expect firmer cargo commitments, the gap between forecast barrels and nominated barrels now carries direct commercial cost. Jupiter Prime Training delivers this course on Production Forecasting and Nomination Scheduling.

Why Production Forecasting and Nomination Scheduling Matters Now

Three pressures shape the subject today. Ageing reservoirs decline faster and less predictably, so profiles built once a year no longer hold for a quarter. Offtakers, pipeline operators and terminal schedulers want earlier, firmer nominations and penalise late changes. Partners in joint ventures expect each barrel lifted to match its equity entitlement. An operator that forecasts well commits cargoes it can fill, protects reputation with buyers and avoids overlift disputes; one that forecasts poorly ships short, pays demurrage or carries unwanted inventory. The course rests on the Society of Petroleum Engineers Petroleum Resources Management System (SPE PRMS) for linking forecasts to reserves categories.

Who Gains Most from Production Forecasting and Nomination Scheduling

• Those who build well and field potential profiles from decline trends and test results
• Those who set monthly and annual production targets and defend them to asset leadership
• Those who prepare nominations to terminals, pipelines and offtakers and handle late revisions
• Those who track partner entitlements, overlift and underlift balances and cargo allocation
• Those who schedule shutdowns, workovers and well interventions against production commitments

Asset groups gain most when the reservoir engineer, the production planner and the lifting coordinator of the same field attend together and leave with one shared forecast logic.

Production Forecasting and Nomination Scheduling Capabilities

The outcomes below connect reservoir behaviour to the barrels that are promised, lifted and invoiced, so every number has an owner and a trail.

• Calculate decline rates and remaining potential with Arps exponential, hyperbolic and harmonic fits — asset forecast sign-off
• Build a deferment register that separates planned, unplanned and constrained losses — operations leadership
• Design a short-term forecast that rolls forward daily and weekly against actual flow — the field planner
• Specify nomination volumes with tolerance bands for each export route — terminal and pipeline schedulers
• Apply entitlement and lifting rules to sequence cargoes among partners — joint venture commercial leads
• Communicate plan-versus-actual variances with root causes and recovery actions — senior asset management

Key Production Forecasting and Nomination Scheduling Terms

• Decline curve analysis — fitting a mathematical trend to historical well rates to project future output and remaining recoverable volumes.
• Production potential — the rate a well or field could deliver with no deferment, used as the ceiling for every forecast.
• Deferment — volume not produced because of planned work, trips, constraints or downtime, recorded so it can be recovered or explained.
• Nomination — the volume an operator commits to deliver through a terminal, pipeline or buyer for a set period.
• Lifting entitlement — the share of produced crude or condensate each partner may take, based on equity and agreed rules.
• Overlift and underlift — the balance when a partner lifts more or less than its entitlement, settled in later cargoes or in cash.

Production Forecasting and Nomination Scheduling Day by Day

Day 1: The Forecast Chain From Reservoir to Cargo

• Forecast Horizons From Daily to Life of Field — Matching Purpose to Method
• Reserves Categories Under SPE PRMS — Linking Profiles to Booked Volumes
• Stakeholders of the Forecast — Reservoir, Operations, Marketing and Partners
• Forecast Error Sources — Reservoir, Facility and Commercial Uncertainty
• Asset Production Calendar — Aligning Budget, Nomination and Reporting Cycles

Day 2: Decline Curve Analysis

• Arps Exponential, Hyperbolic and Harmonic Models — Choosing the Fit
• Rate-Time and Rate-Cumulative Plots — Spotting Regime Changes
• Type Curves for New Wells — Forecasting With Limited History
• Water Cut and Gas-Oil Ratio Trends — Adjusting Oil Rate Outlooks
• Decline Fit Quality Checks — Avoiding Over-Optimistic Tails

Day 3: Well and Field Potential

• Well Test Validation — Accepting or Rejecting Rate Measurements
• Inflow and Outflow Performance Curves — Setting Well Capacity Limits
• Field Potential Roll-Up — Summing Wells Against Facility Constraints
• Back-Allocation Factors — Reconciling Well Rates to Fiscal Meters
• New Well and Workover Additions — Timing Incremental Barrels

Day 4: Deferment and Shutdown Windows

• Deferment Categories and Codes — Planned, Unplanned and Constrained Losses
• Deferment Register Design — Capturing Volume, Cause and Owner
• Planned Shutdown Window Selection — Minimising Lost Barrels
• Workover and Intervention Sequencing — Protecting Monthly Targets
• Deferment Recovery Plans — Prioritising Wells for Restoration

Day 5: Short-Term and Annual Production Plans

• Rolling Thirteen-Week Forecasts — Weekly Updates From Actual Flow
• Annual Production Profiles — Budget Targets and Uptime Assumptions
• Probabilistic Ranges P90, P50 and P10 — Communicating Forecast Confidence
• Scenario Cases for Facility Outages — Testing Target Resilience
• Forecast Sign-Off Workflow — Reservoir and Operations Agreement

Day 6: Nomination Scheduling

• Monthly and Weekly Nomination Cycles — Lead Times for Each Route
• Tolerance Bands and Renomination Rules — Managing Late Changes
• Terminal Tank Inventory Projections — Ullage and Cargo Readiness
• Pipeline Capacity Bookings — Firm and Interruptible Throughput
• Gas Nominations and Daily Contract Quantity — Swing and Make-Up Choices

Day 7: Lifting Schedules and Entitlement

• Lifting Agreement Principles — Equity Shares and Cargo Sizes
• Entitlement Calculation From Production Allocation — Partner Volumes
• Overlift and Underlift Balances — Settlement by Cargo or Cash
• Cargo Sequencing Methods — Fair Rotation Among Partners
• Laycan Windows and Demurrage Exposure — Vessel Arrival Decisions

Day 8: Export Allocation and Hydrocarbon Accounting

• Fiscal Metering and Custody Transfer Points — Volume Ownership Boundaries
• Commingled Stream Allocation — Sharing Exports Among Fields
• Quality Bank Adjustments — Valuing Blend Differences Between Streams
• Monthly Production Statements — Partner and Authority Reporting
• Shrinkage and Loss Accounting — Reconciling Wellhead to Export

Day 9: Plan-Versus-Actual Reconciliation

• Daily Production Reports — Rates, Losses and Comments in One View
• Variance Waterfall Charts — Explaining Gaps by Cause
• Forecast Accuracy Metrics — Bias and Error Tracking Over Time
• Recovery Action Logs — Assigning Owners to Shortfalls
• Forecast Recalibration Triggers — When to Rebuild the Profile

Day 10: Practising the Rolling Field Forecast and Lifting Nomination File

• Case Field Decline and Potential Build — Applying Days 2 and 3
• Deferment and Short-Term Plan Assembly — Applying Days 4 and 5
• Nomination and Cargo Sequence Draft — Applying Days 6 and 7
• Peer Challenge of Forecast Assumptions — Testing Each Variance
• Rolling Field Forecast and Lifting Nomination File — Final Presentation

Applying Production Forecasting and Nomination Scheduling After the Course

• Refit decline curves for the ten highest-rate wells of an asset and compare the new profile with the current monthly target.
• Lead a variance waterfall session on last month's plan-versus-actual gap and set owners for each deferment recovery action.

Production Forecasting and Nomination Scheduling Questions (FAQ)

What is production forecasting and nomination scheduling and why does it matter now?

Production forecasting and nomination scheduling links reservoir outlooks to the volumes an operator commits to terminals, pipelines and partners. It matters now because maturing fields decline less predictably while buyers and schedulers expect earlier, firmer commitments.

Which roles gain most from production forecasting and nomination scheduling training?

Production planners, petroleum engineers and lifting or hydrocarbon accounting leads gain most. You benefit if you build field profiles, set monthly targets, prepare nominations or settle partner entitlements on an oil or gas asset.

How does production forecasting and nomination scheduling training differ from maintenance planning training?

Production forecasting and nomination scheduling training centres on barrels: decline trends, deferment, nominations and liftings. Maintenance planning training centres on work orders, crews and spares, touching production only through shutdown timing.

What do you bring back from production forecasting and nomination scheduling training?

You bring back a forecast and nomination file for a case asset, plus decline fitting, deferment coding and variance methods you can apply to your own field in the first monthly cycle after returning.

Production Forecasting and Nomination Scheduling: The Way Forward

The rolling field forecast and lifting nomination file joins well potential, deferment, nominations and partner liftings in one traceable record. Its first use is setting next month's nomination with a defensible tolerance band. Planners, lifting coordinators and asset leaders rely on it, and its decline assumptions deserve a fresh look after the first quarter of actual flow.