Read Flow Regimes from Production and Pressure Data and Extract What the Reservoir Is Actually Telling You
Rate and Pressure Transient Analysis for Unconventional Reservoirs
Applied transient analysis for fractured horizontal wells, covering diagnostic plots and flow regime identification, straight-line and type curve methods, DFIT interpretation, flowing material balance, contacted volume and fracture property estimation, forecasting and the interpretation of interference and multi-well effects.
Rate and Pressure Transient Analysis for Unconventional Reservoirs
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Rate and Pressure Transient Analysis for Unconventional Reservoirs - PEA-PRTAUC-PEA27
| Code | Date | Time | Duration | Location | Currency | Early Bird Fee Per Person |
|---|---|---|---|---|---|---|
| PEA-PRTAUC-PEA27 | 13 - 17 Sep 2027 | 10 AM CST | 4 Hours Per Day |
Online |
USD |
4000 |
Boost your team's skills and your budget! Enjoy group discounts for collaborative learning. Send an inquiry to info@peassociations.com.
Rate and Pressure Transient Analysis for Unconventional Reservoirs
This training covers rate and pressure transient analysis applied to unconventional wells. It works through the flow regimes present in multi-fractured horizontal wells, diagnostic plot construction and interpretation, straight-line and type curve analysis methods, DFIT interpretation, flowing material balance, and the estimation of fracture half-length, conductivity, permeability and contacted pore volume. Forecasting and multi-well interference interpretation are covered throughout.
Description
Production and pressure data from an unconventional well contain a measurable record of the fracture system that was created and the rock volume it contacts. Extracting that record requires transient analysis methods adapted to multi-fractured horizontal geometry and to the extremely long transient periods that ultra-low permeability produces. This training covers those methods in working detail, from diagnostic plot construction through to the parameter estimates and forecasts that development decisions depend on.
The training develops the flow regime sequence in a multi-fractured horizontal well: wellbore storage, fracture linear flow, bilinear flow, formation linear flow, compound linear flow between fractures, and eventual boundary dominated flow. Each regime has a diagnostic signature and an associated straight-line analysis that yields specific parameter groups, and the training works through both the identification and the calculation. Type curve methods, including the standard unconventional type curves and their assumptions, follow. Pressure transient methods are covered for the buildup and fall-off data available in these wells, including DFIT interpretation for closure pressure, permeability and pore pressure. Flowing material balance and its unconventional variants are then applied to contacted volume estimation. The training closes with forecasting from transient analysis, interference and multi-well interpretation, and the practical data quality problems that dominate real analysis work.
Conventional well test analysis assumes that a radial flow period will appear and that permeability can be read from it. In an unconventional well it usually does not. Permeability in the hundreds of nanodarcies means the transient never reaches the point at which radial flow develops around the fracture system, and the well may produce for its entire commercial life in linear or compound linear flow. Methods built on the expectation of radial flow therefore return either nothing or a wrong answer, and the analyst has to work with the regimes that are actually present.
Linear flow, however, is informative. The straight line on a square root of time plot yields the product of fracture half-length and the square root of permeability, and when combined with an independent estimate of one of them it gives the other. The end of linear flow, when it can be identified, constrains the spacing between effective fractures and therefore the number of clusters that are actually contributing. These are directly useful results: cluster efficiency measured from production data is more reliable than cluster efficiency assumed from completion design.
Rate transient analysis has largely displaced conventional pressure transient testing in these wells, because shutting in a well for a buildup long enough to be diagnostic is expensive and often still inconclusive. Analysis therefore works with flowing data, which requires accurate flowing pressure measurement and careful handling of the rate variation and operational interruptions that characterise real production histories. Data quality is not a side issue in this work; it is frequently the limiting factor.
Finally, transient analysis provides the physical basis for forecasting. A decline curve fitted through transient linear flow and extrapolated forward has no physical constraint on it. A forecast built from an identified flow regime, a contacted pore volume and a terminal decline behaviour has one. The difference shows up in reserves that hold rather than requiring revision.
By the end of this training, participants will be able to:
- Identify flow regimes in multi-fractured horizontal wells from diagnostic plots of rate and pressure data
- Construct and interpret square root of time, quarter root of time, log-log and derivative diagnostic plots
- Apply straight-line analysis to linear and bilinear flow to estimate fracture half-length, conductivity and permeability groups
- Determine effective fracture spacing and cluster efficiency from the end of linear flow
- Apply type curve methods appropriate to unconventional geometry and state their assumptions
- Interpret diagnostic fracture injection tests for closure pressure, permeability and reservoir pressure
- Apply flowing material balance methods to estimate contacted pore volume and original fluid in place
- Construct physically constrained production forecasts from transient analysis results
- Diagnose interference, multi-well effects and data quality problems in production and pressure data sets
The training is calculation-led. Each flow regime is established theoretically, then identified on real data sets, then analysed numerically to extract the parameters it yields, so that participants build the full path from raw data to result. Diagnostic plots, straight-line analyses, type curve matches, DFIT interpretations and flowing material balance calculations are worked through on production and pressure data from producing unconventional wells. Ambiguous and poor quality data sets are included deliberately, since these represent the majority of real analysis work. Interpretation results are compared against known completion parameters and subsequent well performance, and participants are encouraged to bring their own well data for group analysis.
Organisations sending participants to this training will:
- Improve forecast and reserves reliability through physically constrained rather than empirical extrapolation
- Measure cluster efficiency and effective fracture geometry from production data rather than assuming completion effectiveness
- Evaluate completion design changes quantitatively against their reservoir contact outcome
- Improve well spacing decisions using measured drainage and interference evidence
- Reduce dependence on external consultants for routine transient analysis work
- Strengthen the technical basis of reserves submissions and partner or regulatory review
Participants will:
- Identify flow regimes confidently and know what each one can and cannot yield
- Extract fracture and reservoir parameters from production data independently
- Recognise when an analysis is not supportable and say so with technical reasoning
- Build forecasts with a physical basis rather than a curve fit
- Interpret DFIT and buildup data in low permeability settings
- Build a quantitative specialism that is in demand across unconventional operators
- Reservoir engineers working unconventional and tight assets
- Production engineers analysing well performance
- Reserves and evaluation engineers preparing forecasts and bookings
- Completion engineers assessing design effectiveness from production response
- Well test and surveillance engineers
- Geoscientists working closely with production analysis
- Technical staff supporting acquisition, divestment and portfolio evaluation
Module 1 - Fundamentals and Reservoir Context
- Diffusivity equation and its solutions relevant to fractured horizontal wells
- Ultra-low permeability behaviour and the timescale of transient flow
- Storage and flow mechanisms in nanoporous rock
- Adsorption and desorption in shale gas systems
- Stress-dependent permeability and fracture conductivity
- Multi-fractured horizontal well geometry and its idealisation
- Pseudo-pressure and pseudo-time and when each is required
- Material balance time and superposition time functions
- Contrast between conventional and unconventional transient behaviour
Module 2 - Data Requirements and Quality Control
- Data needed for transient analysis: rates, flowing pressures, fluid properties, completion parameters
- Flowing bottomhole pressure: measurement, calculation from wellhead, and error sources
- Multiphase flow correlations for pressure conversion and their uncertainty
- Rate allocation, measurement error and their effect on analysis
- Shut-ins, operational interruptions and their handling
- Choke management, drawdown strategy and its imprint on the data
- Data smoothing, filtering and the risk of removing signal
- Assessing whether a data set can support an interpretation
- Common data problems and their diagnostic appearance
Module 3 - Flow Regimes and Diagnostic Plots
- Flow regime sequence in a multi-fractured horizontal well
- Wellbore storage and early-time behaviour
- Fracture linear flow and its signature
- Bilinear flow and finite conductivity fractures
- Formation linear flow perpendicular to fracture faces
- End of linear flow and compound linear flow between fractures
- Elliptical, radial and boundary dominated flow and their rarity or timing
- Log-log rate normalised pressure and derivative plots
- Square root of time and quarter root of time plots
- Blasingame, Agarwal-Gardner and normalised rate plots
- Systematic flow regime identification workflow
Module 4 - Straight-Line Analysis Methods
- Linear flow analysis and the fracture half-length permeability product
- Extracting fracture half-length with independent permeability estimate
- Extracting permeability with independent fracture length estimate
- Bilinear flow analysis and fracture conductivity determination
- Skin and near-wellbore effects on early-time data
- End of linear flow analysis and effective fracture spacing
- Cluster efficiency estimation from effective spacing
- Compound linear flow analysis and its parameter yield
- Uncertainty in straight-line results and sensitivity to input assumptions
- Worked analyses on field data sets
Module 5 - Type Curve and Model-Based Analysis
- Type curve principles and dimensionless variable groups
- Type curves for infinite and finite conductivity fractures
- Multi-fractured horizontal well type curves and their assumptions
- Trilinear and linear dual porosity models
- Type curve matching procedure and non-uniqueness
- Analytical and semi-analytical model construction
- History matching production data with a reservoir model
- Numerical simulation as an interpretation tool and its cost
- Comparing straight-line, type curve and model-based results
- Reconciling inconsistent results between methods
Module 6 - Pressure Transient Testing in Unconventional Wells
- Practicality and value of buildup testing in low permeability wells
- Buildup design: duration, gauge placement, rate history requirements
- Superposition and rate history effects on buildup interpretation
- Derivative analysis in the absence of radial flow
- Fall-off testing and injection-based methods
- Interference and pulse testing between wells
- Deconvolution and its application to variable rate data
- Permanent downhole gauge data and its analysis
- Limits of what pressure transient testing can resolve in these reservoirs
Module 7 - Diagnostic Fracture Injection Tests
- DFIT purpose, design and execution
- Injection sequence, volume and shut-in requirements
- Fracture closure identification methods and the debate around them
- G-function analysis and its interpretation
- Square root of time and log-log analysis of falloff data
- Determining closure pressure and minimum horizontal stress
- After-closure analysis for permeability and reservoir pressure
- Leak-off behaviour: normal, pressure dependent, height recession, tip extension
- Common misinterpretations and their consequences
- Using DFIT results in completion design and transient analysis
Module 8 - Flowing Material Balance and Volume Estimation
- Material balance principles applied to unconventional reservoirs
- Flowing material balance method and its requirements
- Boundary dominated flow identification as a prerequisite
- Contacted pore volume and original fluid in place estimation
- Corrections for desorption in shale gas systems
- Corrections for stress-dependent properties
- Multiphase and condensate effects on material balance
- Comparing contacted volume with geometric drainage estimates
- Recovery factor determination from contacted volume
- Limitations and common errors in unconventional material balance
Module 9 - Forecasting from Transient Analysis
- Building a forecast from identified flow regime and estimated parameters
- Constraining decline curve fits with transient analysis results
- Terminal decline determination and boundary dominated flow onset
- Effect of drawdown strategy on forecast
- Model-based forecasting and its assumptions
- Probabilistic forecasting and uncertainty propagation
- Comparison of forecasting methods against long producing histories
- Reserves classification and the supporting evidence transient analysis provides
- Documenting an interpretation so that it can be reviewed and defended
Module 10 - Multi-Well and Interference Interpretation
- Interference signatures in production and pressure data
- Parent-child pressure communication and its analysis
- Frac hit identification and quantification from offset well response
- Multi-well pressure interference testing design
- Estimating drainage geometry and well spacing adequacy from interference
- Depletion mapping from repeated pressure measurement
- Analysing wells in a developed pad as a system
- Distinguishing interference from completion and operational effects
- Applying interference results to spacing and sequencing decisions
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.
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