Wednesday, April 26
Refreshments, Registration, Badge Collection, and Hotel Safety and Security Briefing
Surface data analysis can be divided into hard data such as fluid and rock sampling; and soft data which would include pressure, temperature, rate of penetration, weight on bit, etc. New and improved sensors and workflows allow for the prediction of downhole petrophyiscs with this data collected on surface.
The representativeness of the data together with the validity and applicability of the interpretative methods challenge the use of surface data petrophysics. The relative low cost, readiness and accessibility of the data however, makes this branch of petrophysics very appealing. Integration of surface data of petrophysics to reservoir models could provide a necessary element to decrease the uncertainty in asset valuations.
Formation Testing Tools (FTT) have spurred tremendous innovation in several different disciplines in recent years, and the FTT session will consider papers in all these areas. Measurements of fluid properties in real-time at many points in the reservoir have enabled determination of vertical and lateral gradients of fluid columns. Thermodynamic analysis of these gradients establishes whether thermodynamic equilibrium applies. Such analyses help to account for reservoir connectivity and baffling, heavy oil and tar formation, GOR gradients, and biodegradation among other processes.
Vertical interference testing using FTTs provides dynamic determination of vertical and horizontal permeability of reservoirs often at the tens of metres length scale helping to bridge the gap between core permeability and well testing. These measurements address barriers in a stringent manner beyond excess pressure analysis of static pressure surveys of FTTs.
Stress testing using FTTs can establish critically important rock strength parameters not only in unconventional shales but in conventional reservoirs as well. Stress testing can aid in guiding well placement, optimising safe injection rates and managing perforation strategy.
Petrophysical models for reservoir appraisal and development draw on a variety of disparate data sources but core data should be the foundation upon which formation evaluation rests. Geomechanics has an important role to play in assessing formation integrity during well construction and completion, and in the response of the reservoir to oil production, water injection, and depletion. The nature and quality of the petrophysical and geomechanical model input data change throughout the lifetime of a field so it is important to ensure effective quality control of test data to minimise data uncertainties.
This session will cover best practice workflows and methods for the acquisition and interpretation of reservoir rock petrophysical and geomechanical properties based principally on core. The topics covered will include recent technological advances in continuous core data measurements and imaging; sample selection criteria and optimisation; the advantages and limitations of different geomechanical approaches to understanding of formation behaviour; and modelling the subsurface stress field.
Session attendees will gain unique insights into latest core test and modelling developments, appreciate the importance of a rigorous and consistent petrophysical interpretation of core data, and be better placed to assess the quality and reliability of rock property data input to reservoir evaluation and geomechanical characterisation.
Thursday, April 27
This session will address the diversity in the definition, workflow and application of rock typing, which unequivocally varies among the geoscience disciplines. Several have worked hard in search of an effective way to characterise the rock and fluid properties and their relationship with well logs, whilst others have focused on the inherent issue of upscaling from the micro to the macro scale. To be predictive, rock typing must review data acquired at all scales and investigate methods of integrating physical and measurable properties.
The objective of this session is to show rock typing from different angles with meaningful workflows to achieve a practical application of such an important technique and procedure for the petrophysical and geoscience community in general.
The session will focus on quantifying recoverable hydrocarbon volumes in complex carbonate formations. Presentations will cover carbonate formation evaluation, importance of rock/pore typing methods in characterising recoverable hydrocarbon volumes in complex carbonates (e.g. Santos Basin, Brazil), and practical methods for estimating hydrocarbon recovery factors in carbonate fields; what works and what doesn’t.
Fluid and rock interactions happen trougout the entire reservoir drainage area. The manifestations of these interactions however, can only be seen coarsily via surface mapping, such as with the use of seismic data, or much more precisely but with very limited coverage, via wellbore sensors. Some wellbore data can be obtained continuosly with permanently deployed via fiber optics or sporadicly with the use of wireline logging tools.
Reservoir surveillance can be done in active wells: producers and injectors; or in passive wells, i.e. monitoring wells. The analytical methods differ and must be properly understood to achieve the ultimate goal of increasing the recovery factor of the reservoir.