SPWLA HAHZ SIG 2026 Workshop 1
About
Welcome to SPWLA HAHZ SIG's Workshop for 2026.THIS EVENT IS A VIRTUAL EVENT, ATTENDANCE WILL BE VIA TEAMS MEETING
WORKSHOP 1 will be hosted online to correspond with Europe and Asia Time Zone.
Wednesday 15th April, 3am Houston, 10 am Paris, 12pm Dubai, 4pm Singapore
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WORKSHOP 2 PRESENTERS:
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Marie Van Steene, SLB - Pore Network Characterization Utilizing LWD Acoustic Pore Aspect Ratio and NMR Rock Typing for Enhanced Well Placement
Siti Najmi Farhan Zulkipli, PETRONAS - Simultaneous Reservoir Development of Shallow and Deep Hydrocarbon Resources In Offshore Peninsular Malaysia Through Strategic Reservoir Insights and Multi-Physics Data Integration
Hamed Soroush, Teverra - Beyond Well Logs: Transforming Geomechanical Analysis with Drilling Dynamics Data
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ABSTRACTS:
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Pore Network Characterization Utilizing LWD Acoustic Pore Aspect Ratio and NMR Rock Typing for Enhanced Well Placement
Marie Van Steene, SLB
Pore aspect ratio (PAR) is defined as the ratio of the short axis to the long axis of an oblate ellipsoid that represents the average pore shape . In carbonate reservoirs, a combination of Nuclear magnetic resonance (NMR) rock typing, through classification using T2 (or T1) and porosity, and acoustic PAR provides an indicator of the effect of dolomitization on rock quality. Integration of these analyses indicates that dolomitization alters rock quality through changes to pore structure, including PAR, pore size, and porosity. The main objective of this study is to further test the above hypothesis in situ and explore its applications for enhanced well placement.
In this study, the average acoustic PAR was computed from logging-while-drilling (LWD) acoustic logs, using an established methodology (Ma et al., 2023). Formation rocks types are classified based on another established method (Hursan and Van Steene, 2023), which classifies rocks into four types represented as four quadrants in the NMR T2 logarithmic mean) (T2LM) and porosity domain. Rock type 1 (RT1) and rock type 2 (RT2) have the highest porosity with T2LM varying from high to low, while rock type 3 (RT3) and rock type 4 (RT4) have lower porosity than RT1 and RT2, also with T2LM from high to low. Since both T2LM and porosity are statistically proportional to permeability, RT1, the highest quality rock, would have the highest permeability, while RT4 the lowest permeability. RT3 may have higher permeability than RT2, even though RT2 has higher porosity, if the influence of T2LM is more dominant than porosity on permeability. With dolomite volume obtained from log analysis, data cross plotted between dolomite volume and acoustic PAR can be grouped by NMR rock types, illustrating the effects of dolomitization and its diagenesis on rock quality in terms of changes in porosity and permeability.
The above method of analyzing and integrating data of acoustic, NMR, and other logs is applied to LWD data in a vertical well that crossed multiple reservoirs and in a dual-lateral horizontal well placed in carbonate formations, where the highly dolomitized rocks have a higher average PAR, indicating that the pores are more spherical than in the more calcitic rocks. The dolomitized zones mostly belong to RT1 and RT3 with longer T2LM, associated with larger pore size, indicating that dolomitization has increased the rock quality in terms of pore size and also PAR, though not necessarily porosity. This effect of dolomitization occurred in both high and lower porosity rocks. The better reservoir quality in the dolomitized zone was confirmed by high mobility from formation testing data.
In this study we present a novel approach analyzing and integrating acoustic, NMR, and other logs to provide quantitative information about the diagenetic process of dolomitization and its effect on rock quality, supporting rock typing and rock quality definition in situ in real time for enhanced well placement.
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Simultaneous Reservoir Development of Shallow and Deep Hydrocarbon Resources In Offshore Peninsular Malaysia Through Strategic Reservoir Insights and Multi-Physics Data Integration
Siti Najmi Farhan Zulkipli, PETRONAS
Monetizing the newly discovered hydrocarbon resources in a mature field environment involving shallow prospects with uncertain lateral extent and deeper prospects with tight reservoir condition, high pressure and high temperature envelope will require an intense planning and strategic move not only to optimise cost but also to mitigate the risks. This presentation will highlight an exemplary case study combining both exploration and development scopes to fast track the maturation of shallow and deep reservoir potentials and some recommended best practices in data synergy and reservoir performance for strategic development monetisation.
Two exploration wells had been drilled near the field crest targeting both shallow and deep reservoir targets in which extensive LWD and wireline logs, side wall cores and 2 well test operations are conducted in the first well to assess maximum well productivity. Integrated reservoir evaluation incorporating advanced sonic, NMR and image logs, core data, micro frac operation and pressure transient analysis from the advanced formation tester tool have been performed to provide extensive inputs for subsurface study. Extended reach horizontal well drilling with reservoir geosteering play a key role in bridging the uncertainty gap in lateral reservoir extent and boundary while full hydraulic fracturing job is being considered among the various development concepts for deep and tight reservoirs. In both cases extensive 1D geomechanics study are conducted to mitigate potential drilling risks, wellbore instabilities and uncontrolled fracture growth. Advanced sonic, image log and rock mechanics data are utilised to validate the stress components at the well location and optimise the geomechanics inputs for the frac model.
During the extended reach horizontal wells drilling results indicate smooth drilling events without much wellbore stability issues despite of shallow penetration depth. Significant oil pay zones are discovered along the navigated reservoirs with actual post drill production exceeding 7000 bopd. The accuracy of the 1D geomechanic model has been validated from micro frac operation which indicates sufficient stress contrast and barrier for fracture containment. Hydrocarbon presence and the extent of maximum column height in the field have been successfully delineated through extensive core data and advanced formation tester application for the ultra-tight reservoir environment resulting into 165m and 230m column height in shallow and deep reservoirs respectively which justify for fast-track development opportunity in this frontier area.
In conclusion, monetizing the discovered hydrocarbon resources in a geomechanically challenged and tight reservoir environment requires a close synergy not only from production perspective but also stretching the boundary to unlock the nearby field upside potentials. Economic development plan with maximum ROI values can be achieved provided the right timing, right strategy and right data insights are generated from the robust data acquisition plan to develop and derisk these frontier reservoirs.
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Beyond Well Logs: Transforming Geomechanical Analysis with Drilling Dynamics Data
Hamed Soroush, Teverra
Introduction
As the energy sector continues to push the boundaries of drilling in increasingly complex geological environments, the need for accurate geomechanical characterization has become more critical than ever. Wellbore stability, completion design, and production efficiency all depend on a detailed understanding of in-situ stresses and rock mechanical properties. However, traditional methods of geomechanical estimation rely heavily on well logs and field tests, which are often unavailable or limited in resolution, particularly in horizontal wells and unconventional reservoirs.
This study introduces Drilling Dynamic Geomechanics (DDG™), an innovative approach that leverages drilling dynamics data to provide continuous, real-time insights into subsurface geomechanics. The goal of this study is to demonstrate how DDG™ can enhance drilling efficiency, optimize completion strategies, and improve well construction safety by offering a cost-effective and high-resolution alternative to conventional logging techniques.
Methodology
DDG™ is based on the integration of high-frequency drilling vibration data recorded downhole and Electronic Drilling Recorder (EDR) data captured at the surface. This data is processed using a combination of advanced signal processing techniques and machine learning algorithms to derive key geomechanical properties, including:
• Rock strength and mechanical properties
• Pore pressure and in-situ stress profiles
• Collapse and fracture gradients
By continuously analyzing these parameters along the entire wellbore trajectory, DDG™ enables the identification of wellbore instability risks, casing deformation hazards, and optimal hydraulic fracturing strategies. Unlike conventional well logs, this method does not require additional acquisition time and is applicable to all wellbore sections, including laterals.
Results and Conclusions
Field applications in both conventional and unconventional reservoirs have demonstrated the effectiveness of DDG™ in enhancing drilling efficiency, reducing instability risks, and improving overall wellbore integrity. The technology has been successfully implemented to:
• Optimize stage placement and fracturing design
• Identify casing deformation risks before stimulation
• Reduce non-productive time and drilling-related failures
• Improve decision-making through real-time geomechanical monitoring
The results confirm that DDG™ provides a cost-effective solution for subsurface characterization, offering significantly greater data coverage than conventional logging methods. By integrating DDG™ into their workflows, operators can make proactive, data-driven decisions, adjust operational parameters on the fly, and ultimately enhance the safety and economic performance of their wells.
This study highlights the transformative potential of DDG™ in modern drilling operations, paving the way for a new era of fast geomechanical analysis and optimized well construction strategies.
Date
Wednesday 15 April 2026 10:00 AM - 12:00 PM (UTC+02)Location
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