An Interactive 5-Day Training Course
Reservoir Characterization for Mudrock Reservoirs
Describing Mudrock Reservoirs for Development
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Duration
5 Days
Price
$ 3,500
Starting From
05 Apr 2027
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Reservoir Characterization for Mudrock Reservoirs
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Reservoir Characterization for Mudrock Reservoirs - GG-MUDR-PEA27
| Code | Date | Time | Duration | Location | Currency | Early Bird Fee Per Person |
|---|---|---|---|---|---|---|
| GG-MUDR-PEA27 | 05 - 09 Apr 2027 | 10 AM CST | 4 Hours Per Day |
Online |
USD |
3500 |
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Reservoir Characterization for Mudrock Reservoirs
This training covers reservoir characterisation specifically for mudrock reservoirs. It works through mudrock facies schemes, stratigraphic framework construction at high resolution, lateral and vertical heterogeneity, property characterisation and its uncertainty, mechanical property distribution, stimulated reservoir volume concepts, modelling approaches for mudrocks, dynamic data interpretation and the delivery of a mudrock reservoir description that supports development decisions.
Description
A mudrock reservoir description serves different purposes from a conventional one. It does not need to define a trap or map a contact; it needs to say where in the vertical section the well should land, how far apart the wells should be, what the mechanical properties are along the lateral, which intervals will contribute and how much hydrocarbon the stimulated volume holds. Building a description that answers those questions requires a framework at much finer resolution than conventional work and property distributions whose uncertainty is honestly stated.
This training covers the characterisation workflow for mudrocks. Mudrock facies schemes are established first, covering the subdivision of apparently uniform successions and the criteria that produce useful distinctions. Stratigraphic framework construction at high resolution follows, covering correlation of thin units over large areas and the markers that make it possible. Lateral and vertical heterogeneity are then developed, covering the scale and magnitude of property variation. Property characterisation and its uncertainty follow. Mechanical property distribution is then addressed as a product the completion design requires. Stimulated reservoir volume concepts are developed, covering what is actually drained. Modelling approaches for mudrocks follow, since conventional geostatistical modelling is a poor fit. Dynamic data interpretation is then addressed. The training closes with delivery.
Mudrock successions that look uniform are not, and the subdivisions matter. A two hundred metre organic-rich mudrock interval will contain variation in organic content, in carbonate content, in clay proportion and in mechanical properties, often organised into units of a few metres that can be correlated over tens of kilometres. Those units differ in productivity and in how they respond to stimulation. A description that treats the whole interval as one layer cannot address landing depth, which is one of the main decisions the description exists to support.
The drained volume is not the geological volume and the ratio is not well known. What a mudrock well produces from is the volume connected to the hydraulic fracture network, which is smaller than the stimulated volume indicated by microseismic and much smaller than the volume within the well spacing. Estimating the recovery therefore requires an estimate of this connected fraction, which is obtained from production analysis rather than from the geology, and which varies with the completion design. A geological in-place volume alone does not constrain the recovery.
Lateral property variation along a horizontal well is measurable and usually ignored. A two-kilometre lateral crosses rock whose organic content, mineralogy and mechanical properties vary measurably, and the variation is recorded by the logging while drilling data and by cuttings. Using that variation to design the completion, placing more stages and more fluid where the rock is better, is a well-established approach that requires the characterisation to be delivered along the lateral rather than as a single average per well.
Finally, conventional geostatistical modelling adds little in mudrocks and can mislead. The reservoir is continuous and laterally extensive, the wells are closely spaced along laterals and widely spaced between them, and the properties vary gradually rather than in discrete bodies. Layer-based property mapping, conditioned to the dense well data, represents this better than a variogram-based three dimensional simulation, which will generate spatial structure that the data does not support. The appropriate modelling approach is simpler than the conventional one, and recognising that saves considerable effort.
By the end of this training, participants will be able to:
- Design mudrock facies schemes that produce useful distinctions
- Build high resolution stratigraphic frameworks in mudrock successions
- Correlate thin units across play areas
- Characterise vertical and lateral heterogeneity and its magnitude
- Characterise properties and state their uncertainty honestly
- Distribute mechanical properties for completion design
- Apply stimulated and drained volume concepts
- Select modelling approaches appropriate to mudrock reservoirs
- Interpret production and diagnostic data against the description
- Deliver a description that supports landing, spacing and completion decisions
The training works on mudrock play data sets with dense well coverage and production histories. Participants build facies schemes and high resolution frameworks, characterise heterogeneity and distribute properties. Descriptions are tested against production data and against landing depth and spacing outcomes from the same area. Modelling approaches are compared for what each adds.
Organisations sending participants to this training will:
- Subdivide mudrock successions usefully for landing decisions
- Deliver property characterisation along laterals
- Support completion design with mechanical property distributions
- Avoid modelling effort that adds nothing in mudrocks
- State characterisation uncertainty honestly
- Link descriptions to development decisions
Participants will:
- Build mudrock facies and stratigraphic frameworks
- Characterise mudrock heterogeneity
- Distribute properties appropriately
- Select fit for purpose modelling approaches
- Interpret production against the description
- Deliver descriptions that support decisions
- Geoscientists characterising mudrock reservoirs
- Petrophysicists in unconventional assets
- Reservoir modellers working mudrock plays
- Reservoir engineers using mudrock descriptions
- Completion engineers requiring property distributions
- Development geologists in unconventional plays
- Technical staff reviewing unconventional descriptions
Module 1 - Mudrock Facies Schemes
- Subdividing apparently uniform mudrocks
- Criteria for useful facies distinction
- Compositional facies definition
- Organic content as a facies criterion
- Carbonate and silica content
- Texture and fabric distinctions
- Lamination and bioturbation
- Core based facies description
- Log based facies prediction
- Facies and productivity relationships
- Scheme design for development decisions
- Documenting the scheme
Module 2 - High Resolution Stratigraphy
- Framework requirements in mudrocks
- Marker identification in mudrock successions
- Chemostratigraphic correlation
- Elemental and isotope markers
- Bentonite and ash bed markers
- Biostratigraphic constraints
- Sequence stratigraphy in mudrocks
- Condensed sections and their correlation
- Correlation over large areas
- Unit thickness and resolution limits
- Framework consistency across the play
- Framework updating with new wells
Module 3 - Heterogeneity
- Vertical property variation
- Variation scale within intervals
- Lateral variation across a play
- Variation along a lateral
- Organic content variation
- Mineralogical variation
- Porosity and saturation variation
- Mechanical property variation
- Stress variation
- Pressure variation across a play
- Measuring and mapping variation
- Variation magnitude relative to measurement error
Module 4 - Property Characterisation
- Porosity characterisation and its protocol dependence
- Saturation characterisation and its uncertainty
- Hydrocarbon in place per unit volume
- Permeability characterisation
- Adsorbed and free hydrocarbon partitioning
- Organic content mapping
- Mineralogy mapping
- Core to log calibration in mudrocks
- Log based property prediction
- Property uncertainty quantification
- Honest uncertainty statements
- Property deliverables and their format
Module 5 - Mechanical Properties
- Elastic property distribution
- Anisotropic property characterisation
- Strength and brittleness distribution
- Stress profile construction
- Stress barrier mapping
- Mechanical stratigraphy
- Property variation along laterals
- Seismic derived mechanical properties
- Calibration against core measurements
- Deliverables for completion design
- Stage design input from properties
- Property based completion optimisation
Module 6 - Stimulated and Drained Volume
- Stimulated reservoir volume concept
- Microseismic defined volume
- Pressure defined volume
- Drained against stimulated volume
- Connected fraction estimation
- Fracture half length estimation
- Fracture height and containment
- Effective conductivity of the network
- Rate transient analysis for volume
- Diagnostic fracture injection tests
- Interference and tracer evidence
- Volume estimates and their uncertainty
Module 7 - Modelling Approaches
- Modelling requirements in mudrocks
- Layer based property mapping
- Mapping against three dimensional simulation
- Dense lateral data conditioning
- Wide spacing between laterals
- Geostatistics and its limited value
- Seismic conditioning of property maps
- Mechanical earth models
- Discrete fracture network models
- Dual porosity and dual permeability approaches
- Unstructured grids for fracture representation
- Fit for purpose model selection
Module 8 - Dynamic Data and Delivery
- Production data analysis in mudrocks
- Rate transient analysis
- Decline behaviour and its interpretation
- Linear flow and its diagnostic value
- Production allocation along a lateral
- Production logging in horizontal wells
- Fibre optic and tracer diagnostics
- Interference between wells
- Testing the description against production
- Deliverables for landing depth decisions
- Deliverables for spacing decisions
- Reviewing a mudrock characterisation
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.
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.
