Unconventional reservoirs make geoscience more consequential, not less. Because the rock has no effective matrix permeability, the difference between a good well and a poor one lies almost entirely in the rock properties that control stimulation and in the placement of the lateral within them. Organic content, mineralogy, porosity, saturation, mechanical stratigraphy, stress profile, natural fracture density and orientation, and the presence of barriers above and below the target all vary at scales that geoscience is equipped to map and engineering is not.

The difficulty is translation. Engineering decisions are made in terms of stage spacing, cluster count, proppant loading, lateral length, well spacing and drawdown. Geological descriptions are made in terms of facies, sequences, maturity, mineralogy and structure. Neither vocabulary automatically produces the other. A geoscientist who can express a mapped property in terms of its consequence for fracture height growth or drainage geometry will have influence on the well plan. One who cannot will produce a map that is acknowledged and then set aside.

Some widely used shortcuts also need scrutiny. Brittleness indices computed from mineralogy or from elastic logs are convenient but do not reliably predict stimulation response, and they are frequently used as though they do. Stimulated reservoir volume estimated from microseismic clouds measures where rock cracked, not where hydrocarbon flows. Understanding the limits of these proxies is part of contributing usefully to development decisions.

Finally, unconventional development generates an unusual quantity of feedback. Hundreds of wells with recorded completion parameters and production histories exist in most developed plays, which allows the relationship between rock properties and performance to be tested empirically rather than assumed. Geoscientists who engage with that data set can demonstrate which of their mapped properties actually matter.

By the end of this training, participants will be able to:

• Evaluate organic-rich mudstones petrophysically and explain the limitations of conventional log interpretation in these rocks
• Determine mechanical properties and in-situ stress state from log, core and field test data
• Assess mechanical stratigraphy and predict hydraulic fracture height containment
• Explain hydraulic fracture initiation, propagation and interaction with natural fractures in layered rock
• Interpret fracture diagnostic data including microseismic, tracers, fibre optic and pressure analysis
• Identify the flow regimes present in fractured horizontal wells from production data
• Apply production analysis and decline methods to relate well performance to subsurface properties
• Evaluate the reliability of common proxies such as brittleness index and stimulated reservoir volume
• Translate geological and geophysical observations into inputs that change landing zone, completion and spacing decisions

The training is built to move from subsurface description toward engineering consequence at every stage, so that each geoscience topic ends with the decision it informs. Log suites, core data, stress test results, microseismic surveys and production data sets from developed plays are used as working material, with participants interpreting them and following the interpretation through to its completion and spacing implications. Empirical relationships between mapped rock properties and well performance are examined using multi-well data. Common proxies are tested against outcomes to establish where they hold and where they fail, and participants are encouraged to bring play-specific questions from their own areas.

Organisations sending participants to this training will:

• Improve integration between geoscience and engineering on unconventional development decisions
• Increase the influence of subsurface characterisation on landing zone and completion design
• Reduce wells placed in zones that cannot be effectively stimulated or that lack fracture containment
• Improve the quality of subsurface inputs to production forecasting and spacing evaluation
• Reduce reliance on unvalidated proxies in development decision making
• Build multidisciplinary capability that shortens the learning cycle in new plays

Participants will:

• Understand how engineers use subsurface descriptions and what makes them actionable
• Interpret stress, mechanical property and fracture diagnostic data with confidence
• Relate rock properties to well performance using production data rather than assumption
• Recognise where widely used industry proxies are unreliable and argue the point technically
• Contribute effectively to landing zone, completion and spacing discussions
• Extend professional capability across the geoscience and engineering boundary

• Geologists working on unconventional resource plays
• Geophysicists supporting shale and tight resource development
• Petrophysicists evaluating organic-rich mudstones
• Geomechanics and structural specialists in unconventional teams
• Exploration and development geoscientists moving into resource plays
• Reservoir engineers seeking a stronger subsurface characterisation grounding
• Technical supervisors managing integrated unconventional subsurface teams

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.