Presenter:

Andrew Dean

Andrew is a Reservoir Engineer at QGC in Brisbane working in the reservoir modelling team, he holds BSc in Petroleum Engineering from University of Adelaide (Class of 2016). Prior to QGC Andrew worked for Origin.

Short Presentation Abstract:

Current full-field models at Queensland Gas Company (QGC) typically contain thousands of coal-seam gas (CSG) wells, spanning ~4,000 sq.km. The goal of history matching individual wells in these models at a well level can present a significant challenge. Previous methods applied in QGC were to history match to a field level and more recently to apply well level property modifiers in a semi-automated workflow to match produced volumes at a well level. The new method, implemented through python, can attempt to minimise multiple match metrics (pressure mismatch, rate mismatch, etc.) through the modification of multiple different reservoir grid properties in a single iteration, at a well-level, resulting in fewer iterations to converge on a satisfactory history-match.

Presented by Peter Behrenbruch – Bear and Brook Consulting

Abstract:

The presentation discusses a fully automated, universal and comparative analysis approach for defining formation characteristics: based on geological and core description, linked to logs and pore structure – pore throat size and sorting, and based on hydraulic parameters. It is shown how such analysis leads to greater understanding, more meaningful data integration while ensuring consistency. Methodologies employed make use of cluster analysis and pattern recognition, utilising a 6-parameter model space, a nomograph called ‘Global Characteristics Envelope’ (GCE): displaying porosity, permeability, hydraulic radius, porosity group (porosity/ grain volume), flow zone indicator (linked to grain size) and grain sorting. The approach gives greater insight than more conventional methods. A catalogue of models is presented, which can universally be applied to all conventional formations, clastics and carbonates. Zones are identified according to different cluster situations exhibited in GCEs: consistent diagenetic intervals (base model); very uniform intervals (3 models) – uniform porosity or permeability, or both (cluster); more heterogeneous intervals (4 models) – highly varying diagenetic intervals, interbedded diagenetically-driven intervals (e.g. pyritisation), alternating thinly-bedded intervals of different rock types, and fining sequences. Outliers can be identified, e.g. shale plugs or fractures (natural or induced). Examples and a detailed comparative case history are presented.

Biography

Peter is currently Managing Director of Bear and Brook Consulting (Company) and has more than 40 years of petroleum engineering related experience, most notably employed by Shell International (8 years) and BHP Petroleum (16 years). He has held positions as engineer, technical manager, project manager, academic and consultant, and in general management, including member of management boards. His expertise is in field development planning and reservoir management. Peter has been Project Manager for three Australian FPSO projects. Since establishing the Company in 2003, he has engaged in numerous consulting activities. In the last 10 years alone, he has conducted 98 short courses, workshops and seminars, given to 38 organisations. Peter has led core-related research since 2002 and is presently commercialising this research. He has published more than 60 technical and managerial papers. He was the SPE Regional Director for Asia-Pacific, serving on the SPE Board in the late ‘90s.

Agenda

Morning:  “Logging Through the Ages” in the morning, with an assessment of what you can get from the logs acquired in some of the wells we encounter (1960s, SP, IND to 2020 NMR etc) and how modern logs improve our understanding of the sub-surface

• 1960s:   SP-IND only, some early Sonic logs
• 1970s:   Introduction of the Density and neutron logs
• 1980s:   Litho-Density
• 1990s and beyond:        
• Image logs, NMR, Full Wave Form sonic etc

Afternoon: Coal, definition and productivity from subsurface data

• Data Acquisition (Logs and core)
• Use of the log data
• Use of the core data
• Proximate analysis
• Langmuir analysis
• Pulling it all together 

 Biography

Andy Hall has 31 years of experience in the upstream oil and gas industry as a Petrophysicist and Exploration / Development Geologist in Coal Seam Gas (CSG), Shale Gas and Conventional oil and gas plays.  He has diverse experience, working for companies such as Origin, Roc Oil, Candecca, and AEA Technology.

Speaker: Vibhas Pandey – ConocoPhillips

Abstract: 

Accurate prediction of fracture height growth from hydraulic fracturing treatments, especially in highly layered or laminated formations, is crucial not only from well performance perspective but also from planning and treatment design viewpoint.  Understanding of critical parameters that govern the fracture height growth in heterogenous formations is essential to developing suitable well completion strategies that are specific to the reservoir.

This presentation reviews the typical fracture heights observed during the treatments, and then describes the construction of a semi-analytical fracture height prediction model and its application to several real-world cases covering a variety of reservoirs ranging from traditional low permeability sandstones to coalbed methane and shale reservoirs worldwide.  The treatment types include conventional fracturing treatments, foamed fractures and slickwater fracturing treatments.

The model-predicted fracture heights agree reasonably with those determined from field measurements such as tracer and micro-seismic survey in vertical and horizontal well completions. With the introduction of fluid flow induced pressure distributions in the fracture, along with the velocity-based fracture toughness calculations, the traditional uncertainties in input data are mostly  eliminated, and accurate predictions can be made.  The analysis also reveals typical fracture growth patterns that are dependent on injection rate and corroborated with interesting observations in the field.

Key Takeaway: The critical parameter of fracture height can be predicted with reasonable accuracy even in highly layered formations and the designed fracture heights can be achieved in the field with implementation of formation-specific hydraulic fracturing treatment designs.

Biography:

Vibhas Pandey has over 30 years of experience in oil and gas industry and currently works as an Engineering Fellow with ConocoPhillips in their Global Completions Engineering group in Houston.  He is a well-stimulation expert primarily foccused on hydrualic/acid fracturing modeling, treatment design, field support and optimization, and has authored several technical papers including 2 chapters in recently published SPE Monograph. Mr. Pandey holds Bachelor’s and Masters’ degree in Mechanical Engineering (India), Master’s degree in Petroleum Engineering (Univerity of Oklahoma), and is currently pursuing PhD in Petroleum Engineering from Unversity of North Dakota where he also serves as Adjunct Faculty.

Rescheduled to 30 September 2022

12:30pm Brisbane time

Presented by: Drew Pomerantz – Schlumberger (SPE Distinguished Lecturer)

Abstract

The world has entered an energy transition where the future role of energy sources will depend partially on their greenhouse gas footprint.  While that transition is expected to take a generation, some changes will occur quickly.  One of the fastest ways to combat climate change is to reduce emissions of methane, not carbon dioxide.  Methane is the main component of natural gas and a more potent greenhouse gas than carbon dioxide.  The oil and gas industry handles a large quantity of methane, and a small amount of that methane leaks to the atmosphere.  Because methane is such a potent greenhouse gas, those emissions are small in volume but large in environmental impact: methane is the dominant source of our industry’s direct greenhouse gas emissions, above other sources like flaring.  This lecture describes the main sources of methane emissions, the market and political drivers to reduce methane emissions, and the new technologies being developed to find and fix methane leaks.

 Biography

Andrew (Drew) E. Pomerantz is an Energy Transition Technology Advisor at Schlumberger, based in Boston, Massachusetts.  He focuses on new technologies that reduce direct greenhouse gas emissions from the upstream and midstream oil and gas industry, particularly novel methods to detect fugitive methane emissions.  Drew graduated from Stanford University with a PhD in chemistry in 2005 and has co-authored 100 peer-reviewed publications and 25 granted US patents.  He founded the Boston chapter of the Society of Petrophysicists and Well Log Analysts (SPWLA).

Presented by: 

Andrew Murdoch – Managing Director Arche Energy

“The last few months on the national electricity market gave us a taste of what energy supply restrictions feel like. In this presentation, Andrew Murdoch unpacks some of the events, their causes and some of the reactions. We’ll work through some hot topics such as capacity markets, gas reservation policies, level of competition, government intervention, moratoria on gas exploration and green tape risk and then look at some simple fixes that might have avoided some of the hysteria”.

Biography

Andrew has been operating in technical-commercial roles in the Queensland NEM Zone since it was first founded over 20 years ago. In 2017, he founded Arche Energy to provide a high-quality clean energy, power and infrastructure consultancy to facilitate investment in the clean energy sector. He is an experienced general manager, project director and engineer operating in renewable power, power generation, energy, ports and heavy infrastructure.

His experience spans business development activities, major approvals, project execution, operations and maintenance and decommissioning. Andrew is an innovator and optimiser thriving in changing environments through the adaptation and integration of emerging and innovative technologies into business applications.

Key experience includes:

• Founder, New England Link
• Lead Developer, Lockyer Energy Project
• Technical Director, CopperString 2.0
• Technical Advisor, Galilee Power Project
• Project Manager, Expansion, Wiggins Island Coal Export Terminal
• Project Manager, Construction, Braemar Power Project, OCGT
• Project Manager, Owner’s Engineer, Construction, Condamine Power Project, CCGT

Independent Engineer, Construction, Newman Power Plant Expansion

Reservoir Engineering Special Interest Group

Presenter:  Gerardo Guillen Falcon, Senior Reservoir Engineer, Santos

Flowing Material Balance and Decline Curve Analysis: A Hybrid Approach for Better EUR and Decline Profile Predictions for CSG Wells

Presented by: Barbara Pribyl

Abstract

This talk will discuss the current state of the principal resource classification and management systems and thoughts on their future direction. These systems include the SPE Petroleum Resource Management System (PRMS) and Storage Resources Management System (SRMS), the United Nations Framework Classification for resources (UNFC) and the evolving United Nations Resource Management System (UNRMS). Specifically, how they apply to the broader energy and storage sector to facilitate informed and reliable policy and investment decisions.

The last few years has seen improvement in the market fundamentals for the petroleum industry and merger and acquisition activity has increased. However, market volatility and project investment trepidation are expected to continue as the world adjusts to the ‘new normal’ of the societal, environmental, and economic impact of living with COVID, geopolitics and the challenge of maintaining our standard of living and a healthy planet. Governments and organisations around the world are announcing net-zero emission targets and other policy initiatives for reaching sustainable development goals. These targets have broad implications for the energy sector. Pressure to address environmental, social, and corporate governance (ESG) issues increasingly impacts the commercial viability of projects and their corresponding chance of development.  Moreover, the industry will need to demonstrate they are developing in sustainable manner and provide credible, measurable, and transparent data to maintain legitimacy.

Biography

Barbara and has over 30 years experience as a geologist, managing reserves and resources and advisory in the international energy industry and developed insights of key projects and geological basins across onshore Australia and Asia-Pacific. This experience has included management roles at Santos and Arrow Energy. Her professional focus has been on resource advisory in resource classification, management and reporting, project assurance, developing guidelines and training and the co-ordination of reserve reviews and audits. She is the Chair of the Society of Petroleum Engineers (SPE) Journal of Petroleum Technology Editorial Board, a prior member of the SPE Oil and Gas Reserves Committee (OGRC) 2014-2018, member of the OGRC Examples Subcommittee and Chair of the Petroleum Working Group (PWG) of the United Nations Economic Commission for Europe (UNECE) Expert Group on Resource Management (EGRM). Barbara is also a Vincent Fairfax Fellow in Ethical Leadership.

Abstract

Over the last decade, laboratory research and modelling have shown the benefits of the application of GPI to keep pre-existing natural fractures and induced fractures open during production. The purpose of this talk is to summarise key findings of the NERA Project “Converting tight contingent CSG resources: Application of graded particle injection in CSG stimulation”.  Recent laboratory studies have provided insights on the potential mechanisms and key factors, including proppant size and optimum concentration, that contributing to the success of a micro-proppant placement.  Accompanying numerical modelling studies will be presented that describe the likely fluidized behaviour of micro-proppants (e.g., straining models, DLVO effects, and screen out prediction) as well as the potential benefit under varying conditions (e.g., vertical well, horizontal well mult-stage, indirect, etc.) This talk will outline the necessary fluid, treatment design considerations, and numerical modelling design inputs necessary to achieve practical results relative to this study.  

Biography

Prof Raymond Johnson Jr. is currently Professor of Well Engineering and Energi Simulation Co-chair in the University of Queensland, Centre for Natural Gas. Prof Johnson’s 41 years of petroleum engineering and management experience has focused on integrating elements of reservoir engineering, geomechanics and hydraulic fracturing to improving appraisal and development strategies for unconventional resources such as gas from coal as well as oil and gas from shales and naturally fractured reservoirs.

Prof Johnson is a Life Member of the Society of Petroleum Engineers (SPE), past Queensland SPE Section chair, twice co-Chair of the SPE Unconventional Reservoir Conference Asia Pacific, 2019 co-Chair and 2021 Advisor of the URTeC Asia Pacific Conference, and twice SPE Regional Technical Award Recipient (Production Operations 2011 and Management and Information 2017).  Prof Johnson has recently been admitted and recognised as a Fellow in Engineers Australia.